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Home My WebLink About181-018 Ima, ect Well History File Cover ge X HVZE 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. L X RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other. No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other Project Proofing BY: ~OBIN VI"CENT S.ERYL MARIA WINO¥ DATE,~~ ~SI Scanning Preparation x 30 = + = TOTAL PAGES . BY: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: 7Z~ YES BEVERLd~ V,.CENT S.ERYL MAR,A V",..¥ OATE:/--Z~-,~.~'S' ~ NO Stage 2 IF NO IN STAGE1, PAGE(S) DISCREPANClES WERE FOUND: /~,,,~/~/YES NO RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is/ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned,wpd • Maunder, Thomas E (DOA) Prom: Maunder, Thomas E (DOA) Sent: Wednesday, August 06, 2008 10:16 AM To: 'Schmoyer, AI' Cc: Rose, John G (FAIRWEATHER); Hobbs, Greg S (ANC) Subject: RE: PBU Y-07 (181-018) and Y-07A (207-105} -- Again Page 1 of 2 • AI, Sorry we haven't been able to hook up. Thanks for the reply and assessment. 1 agree with your conclusions. Bottom line, when all available information is/was considered, sufftcient isolation was determined to allow completion of the well. Call or message with any questions. Tom Maunder, PE AOGCC From: Schmoyer, AI [mailto:Al.Schmoyer@bp.com] Sent: Wednesday, August 06, 2008 10:05 AM To: Maunder, Thomas E (DOA) Cc: Rose, John G (FAIRWEATHER); Hobbs, Greg S (ANC) c~'~~~~~ ~,(~~ ~ ~ ZQQ$ Subject: RE: PBU Y-07 (181-018) and Y-07A (207-105) -- Again Tom, We are in agreement that the cement outside the 4.5" liner is not as good as expected given the "best practices" and operations. Our observations as we reviewed the 5-2-2008 SCMT log: • cement bond improved significantly over that shown on the 2-3-2008 SCMT log • there is up-hole isolation with >100' strong cement bond across the Shublik and Sag . there is ~15' (14,598'-14,613') acceptable bond/compressive strength across the HOT/tar-mat In general the cement quality is not ideal, probably better than it looks on the log, good enough so that we really can't do anything about it (sqz cement), The reservoir section is thin and the standoff from the HOT is ~10'. The cement bond should provide near well injection containment across the Tar-mat. The tar mat is going to provide injection cantainment as the flood moves out into the matrix. Hope that helps. Call if you have any further questions, Alk From: Hobbs, Greg S (ANC) Sent: Thursday, July 31, 2008 2:17 PM To: Schmoyer, AI Cc: Rose, )ohn G (FAIRWEATHER); Maunder, Thomas E (DOA) Subject: FW: PBU Y-07 (18i-018) and Y-07A (207-105) -- Again AI- Could you provide feedback on Y-07 to Tom? Thanks! Greg 8/6/2008 Page 2 of 2 • From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, July 31, 2008 11:41 AM To: Hobbs, Greg S (ANC) Subject: RE: PBU Y-07 (181-018) and Y-07A (207-105) -- Again Greg, Would you forward to the production engineer responsible for Y-07A? The SCMT log from 2/3!08 portrays a pessimistic picture of the cement quality outside the 4-1/2" liner. I would have expected better quality cement given the operations summary. It appears that best practices were employed. According to the post-rig work summary, another SCMT was run May 2 and it is noted "Cement in area of interest 14545 - 14585 not good. PE decided not to pert pending further review of log." I would agree that section is not the best quality of the interval logged. On May 10, perforations were shot 14545 -145$5. am curious what the assessment of the "bond" is over the 4/1/2" liner? The presentation from 5/2 in general indicates better quality than the 2/3 log. Thanks in advance. I look forward to the reply. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Thursday, July 31, 2008 10:50 AM To: Hobbs, Greg S (ANC); 'Rose, John G (FAIRWEATHER)'; Elmore, Gary 0 (Schlumberger); 'Hubble, Terrie L' Cc: Engel, Harry R; Saltmarsh, Arthur C (DOA); Davies, Stephen F (DOA); Christine Mahnken Subject: PBU Y-07 (181-018) and Y-07A (207-105) All, I am reviewing the completion report for Y-07A. As part of the review for injection wells, I also examine the "bond logs". In the AOGCC file I found a USIT dated 12/18/07 and a SCMT dated 2/3/08. The well name on both logs is Y-07A. The name on the 12/18/07 log is incorrect. This log is of the 9-5l8" casing set in the well in 19$1, a portion of which was cu# and pulled shortly after this log was run. Window milting to begin Y-07A was not commenced until late on 12/25/07. The correct well name for USIT log is Y-07. The convention employed by AOGCC is that the new well or redrill is not "spudded° until new formation is drilled beyond the window. It would be appreciated that those responsible for logging operations such as this would be informed of this. It is not necessary to send renamed copies of the USIT log. I will make the necessary correction. Thanks in advance for you attention to naming matters. Call or message with any questions. Tom Maunder, PE AOGCC 816/2008 Page 1 of 1 Maunder, Thomas E (DOA) • From: Maunder, Thomas E (DOA) Sent: Thursday, July 31, 2008 10:50 AM To: Hobbs, Greg S (ANC); 'Rose, John G (FAIRWEATHER) ;Elmore, Gary O (Schlumberger); 'Hubble, Terrie L' Cc: Engel, Harry R; Saltmarsh, Arthur C (DOA); Davies, Stephen F (DOA); Christine Mahnken Subject: PBU Y-07 (181-01$) and Y-07A (207-105) All, I am reviewing the completion report for Y-07A. As part of the review for injection wells, I also examine the "bond logs". In the AOGCC file I found a USIT dated 12/18/07 and a SCMT dated 2/3/08. The well name on both togs is Y-07A. The name on the 12/18/07 log is incorrect. This log is of the 9-5/8" casing set in the well in 1981, a portion of which was cut and pulled shortly after this log was run. Window milling to begin Y-07A was not commenced until late on 12125/07. The correct well Warne for USIT log is Y-07. The convention employed by AOGCC is that the new well or redrilf is not "spudded" until new formation is drilled beyond the window. It would be appreciated that those responsible for logging operations such as this would be informed of this. It is not necessary to send renamed copies of the USIT log. I will make the necessary correction. Thanks in advance for you attention to naming matters. Call or message with any questions. Tom Maunder, PE AOGCC ~~~ JUL 3 ~ X008 7/31/2008 STATE OF ALASKA ~~`°° .ALASKA OIL AND GAS CONSERVATION COM SION ~~~ JAN 2 ~ 2~~8 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Ai- t~ $~ Gla~ts, Commissi~t 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Clas C ~r8~$ ^ Development ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Ab ~ 12/25/2007 ~ 12. Permit to Drill Number 181-018 ~ 306-001 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 04/22/1981 13. API Number 50-029-20560-00-00 4a. Location of Well (Governmental Section): Surface: 1 41' FN 118' WL C 7. Date T.D. Reached 05/14/1981 14. Well Name and Number: PBU Y-07' 3 L, F , SE . 34, T11N, R13E, UM Top of Productive Horizon: 1877' FNL, 2110' FWL, SEC. 34, T11 N, R13E, UM 8. KB (ft above MSL): 86.8' Ground (ft MSL): 49.96' 15. Field /Pool(s): f Prudhoe Bay Field / Prudhoe Bay Total Depth: 1969' FNL, 2249' FWL, SEC. 34, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD) 9906 9519 P°ol 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 644933 y- 5948917 Zone- ASP4 10. Total Depth (MD+TVD) 10075 ~ 9684 ~ 16. Property Designation: ADL 028287 _ _ __ TPI: x- 646936 y- 5948420 Zone- ASP4 Total Depth: x- 647077 y- 5948330 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic nd tinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIL / SP ! GR, DIL / BHCS ! GR, FDC ! CNL / SP / GR, HDT, CBL / VDL / CCL / GR, Gyroscopic Survey 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH M0 SETTING DEPTH TVD HOLE AMOUNT Wi. PER FT. GRADE TOP BOTTOM TOP BOTTOM :.SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2685' Surface 2685' 17-1/2" 3720 cu ft Permafrost If 9-5/8" 47# L-80 Surface 9187' Surface 8818' 12-1/4" 1271 cu ft Class'G' 130 cu ft PF C 7" 29# L-80 868 ' 10063' 8331' 9673' 8-1/2" 425 cu ft Class'G' 23. Open to production or inject ion? ^ Yes ®No 24. TUBING RECORD If Yes, I1St each Interval Open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2", 12.6#, L-80 2616' - 8602' 8602' MD TVD MD TVD 3-112", 9.2#, L-80 8602' - 8713' 25. ' ACID, FRACTURE, CEMENT SQUEEZE, ETC. yyly~ r~~ ~ ~~~~ „ , DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED ~ 1 ~ '~~~ t°' 8400' P&A w! 50 Bbls Class 'G' Cement 2050' Set EZSV 2020' Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Injection Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED Z4-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac wired? ^ Yes ®No 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 250.071. CO;~i~~.~T10N I None ~~o.(~-d J]~' A rt n ` •~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE / 28. GEOLOGIC MARKERS LIST ALL FORMATIONS A KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 9288' 8915' None Shublik 9313' 8940' lvishak 9395' 9019' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. d~ / Signed Terrie Hubble Title Drilling Technologist Date ~ ~~ PBU Y-07 181-018 306-001 Prepared By Name/Number.~ Terrie Hubble, 564-4628 Well Number Permit No. / A rOV81 NO. Drilling Engineer: John Rose, 564-5271 INSTRUCTIONS GeNew-~: This form 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 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: 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. Form 10-407 Revised 02/2007 submit Original only Digita'1 Well File ~ ~ Page 1 of 2 ~l1/ell: Y-07 Well History Well Date Summary Y-07 10/5/2007 T/I/0=0/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC INCONCLUSIVE). Pre rig. PPPOT-T: Stung into test port to check pressure (100 psi), bled to 0 psi. Functioned LDS, all moved freely with no sign of bent or broken pins. Pumped through void until clean fluid was achieved. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). PPPOT-IC: Stung into test port to check pressure (0 psi). Functioned LDS, all moved freely with no sign of bent or broken pins. Unable to pump through void, possibly frozen. **NOTE: Well head and tree are not 2 bolted.*** Y-07 10/6/2007 T/I/0=0/0/0, Temp=Sl. PPPOT-IC (PASS), Pre rig. Heater installed on wellhead. Job continued from 10-5-07. PPPOT-IC: Stung into test port to check pressure (0 psi). Re torqued LDS to 550 psi. Pumped through void until clean fluid was achieved, returned what appeared to be arctic pack. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). **NOTE: Well head and tree are not 2 bolted.*** Y-07 11/15/2007 ***WELL S/I UPON ARRIVAL*** (SIDETRACK) ATTEMPTED TO PULL P-PRONG. UNABLE TO LATCH. A 2 .25" PUMP BAILER 5 TIMES TO 8637" SLM. (RETURN: 4 GAL. OF FILL.) *** CONT WSR ON 11/16/2007*** Y-07 11/16/2007 *** CONT WSR FROM 11/15/07 *** (SIDETRACK ) RAN 2 1/4" PUMP BAILER TO 8638' SLM APPROX. 1 GAL. OF RETURN. PULL PX PRONG ~ 8640' SLM.. RAN 3.5" GR PULLING TOOL S/D C~ 8,643 SLM. UNABLE TO LATCH PLUG BODY. MADE MULTIPLE BAILER RUNS TO TOP OF PLUG BODY, RECOVERED APROX 2 GAL OF FILL RIG DOWN FOR WEATHER ***WELL LEFT S/I, NOTIFIED DSO*** Y-07 11/17/2007 ***WELL S/I ON ARRIVAL*** (SIDETRACK) RIG UP SLICKLINE. ***CONT. WSR ON 11/18/2007*** Y-07 11/18!2007 CONT. WSR FROM 11/17/2007 RAN 2.25" PUMP BAILER W/ SNORKLE BTM. 1/4 OF GAL. OF FILL RAN 3" GR PULLING TOOL & PULLED 2.75" PLUG BODY. 2.5" ENT/TEL/SB. TAGGED TT @ 8,680' SLM + 18' = 8,698' CORK ELM. TAGGED BTM C«? 9873' CORR ELM. HAVE 431' OF RATHOLE. NO SAMPLE RECOVERED. ***WELL LEFT S/I, NOTIFIED DSO*** Y-07 11/19/2007 TIO = 200/100/0+. Temp = SI. T & IA FL (pre-rig work). T FL @ 120'. IA FL @ surface. Y-07 12/5!2007 CTU #8 (P&A pre-sidetrack) MIRU ***Job in progress*** Y-07 12/5/2007 CTU #8 (P&A pre-sidetrack) MIRU - MU 2" BDN/ Kill well - **** Continued on 12/6/07 WSR **** Y-07 1216/2007 **** Continued from 1215107 **** CTU 8 **** RIH with 2" BDN -Tag at 9888' ctm. PU above perfs -Pump 1 % KCL down coil to keep hole full -Safety meeting -Prime up cementers -Mix and um 50 bbls 15.8 Class 'G' cement - PT cement 300 -held 250 (30 min) -Drop ball and clean down to 8400'. pooh an P well rom 2500' to surface. Est TOC 8400' ***job complete*** **** Note: Refer to Candi English a-mail of 10/30/07 for SLB contract cement pump unit charges. **** Y-07 12/6/2007 **** Continued from 12/5/07 **** CTU 8 **** RIH with 2" BDN -Tag at 9888' ctm. PU above perfs -Pump 1%KCL down coil to keep hole full -Safety meeting -Prime up cementers -Mix and pump 50 bbls 15.8 ppg Class 'G' cement - PT cement 300 -held 250 (30 rnin) -Drop ball **** Job in progress **** Y-07 12/9/2007 ***WELL S/I ON ARRIVAL*** airr.Fn nn~nmi ni iF rn cnnni i nRip mi ccv http://digitalwellfile.bpweb.bp.com/WIInfolReports/ReportViewer.aspx 1/22J2008 Digital Well File ~ ~ Page 2 of 2 V " v vv ***CONT ON WSR 12/9/07*** Y-07 12/10/2007 *** WELL SHUT IN ON ARRIVAL*** WINDS TO HIGH RIGGING DOWN TRAVELING TO ANOTHER PAD. CLOSED PERMIT WITH DSO. Y-07 12/10/2007 (SSV Repair) Repaired SSV ***Job Complete*** Pulled powerhead off Otis Big Bore Actuator, redressed with new seals. Installed and functioned on Cameron 6 3/8" valve, tested to 5,000 psi. NOTE: Drift is 1 3/4" from end of barrel, valve technician marked actuator. Y-07 12111(2007 LRS #46 Load and travel to location- Stand by for E-line and Hardline rig-up *`*Continued on 12-12-07*** Y-07 12/11/2007 ***WELL SHUT IN ON ARRIVAL*** INITIAL TI it O = 80/ 550/ 25 PSI PREPARE TO JET CUT TBG C~ 2600'. BEGIN RIG-UP. ***JOB INCOMPLETE. CONTINUED ON 12-DEC-2007*** Y-07 12/11/2007 ***WELL S/I ON ARRIVAL*** (pre sdtrk) TAGGED TOC W/ 3.70" CENT & S-BAILER @ 8412' SLM. NO SAMPLE RECOVERED. RAN 2.25" P-BAILER TO 8427' SLM, RECOVERED SAMPLE OF CEMENT & SCHMOO. PERFORMED CMIT TxIA 2200 PSI (PASSED) ** L Y-07 12/12/2007 Set 6 3/8"CIW BPV for Pre rig. Tubing PSI 501b. BPV#415 set good Y-07 12/12/2007 ***CONTINUED FROM PREVIOUS DAY*** WELL SHUT IN ON ARRIVAL -INITIAL T/ I/ O = 80/ 550/ 25 PSI. JE7 CUT TUBING AT 2616' USING SLB 3.65" POWERCUTTER. POSITIVE INDICATION OF CUT N E. FINAL T/ I/ O = 150/ 375/ 25 PSI. ***JOB COMPLETE*** Y-07 12/12/2007 T/I/0=240/240/0 Circ Out Tx IA, CMIT TxIA PASSED to 3500 psi ,MIT OA PASSED to 2000 psi. [Pre Drilling] Pumped 10 bbls meth followed by 270 bbls 20*F diesel down IA taking returns up Tbg through hardline to Y-32 flowline. Pumped 7.3 bbls diesel down IA to pressure up TxIA. T/IA lost 60/40 psi 1st 15 min and 0120 psi 2nd 15 min. Pass. Pumped 5.5 bbls diesel down OA to reach test pressure. OA lost 60 psi in 1st 15 min and 10 psi in 2nd 15 min. FWHP's=0/0/0 Annulus valves open to gauges, Tags hung Y-07A 12/16/2007 Pull 6" CIW J BPV. Print Date: 1/22!2008 Page 1 of 1 http:!/digitalwellfile.bpweb.bp.comlWIInfo/Reports/ReportViewer.aspx 1/22!2008 • BP EXPLORATION Page 1 of 16 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: 2ES Date 12/14/2007 12/15/2007 112:00 - 23:00 I 11.001 RIGU { P 12/16/2007 00:00 - 01:00 1.00 WHSUR P 01:00 - 03:00 2.00 WHSUR P 12/17/2007 ~ 00:00 - 03:30 ~ 3.50 ~ BOPSUF( P From - To ;Hours ' Task Code NPT , Phase Description of Operations PRE Rig released from 02-09C on 12/14/07 at 12:00 hours. Rig down and prepared to move. Moved shop, pit module and camp to Y-Pad (ETA on Y-Pad -24:00 hrs). PRE Continue to mobilize rig flDS02 and RU rig-up on Y-07Ai location. DECOMP Rigged-up on well. Take on seawater. Commence well operations as follows: 1. Noted well pressures / OA = 200 psi, IA = 75 psi. 2. Rigged-up to bleed off pressure. Accept rig at 23:00 hrs on 12/15/2007. 3. Held pre-spud meeting at tour change meeting at 23:30 hours. 4. Mobilized DSM to pull BPV. DECOMP Bleed IA (75 psi) and OA (200 psi) to zero. DECOMP PU & RU DSM lubricator, test to 500 psi and pull BPy. LD lubricatior. DECOMP PJSM, RU circulation lines to OA and top of tree to cuttings tank. Reverse circulate through the tubing cut and circulate out diesel until clean seawater returns at surface (5.5 bpm at 500 psi). While monitor well for 1 hour to confirm well "dead", pressure tested the OA to 2000 psi f/30 minutes (good test). DECOMP Blow down lines and remove from tree and dry rod in TWC (Cameron). Hook lines back up and test TWC from above and below to 1000 psi (good tests). DECOMP PJSM, ND tree/adapter flange & removed from cellar. Functioned all LDS & thread hanger XO in by hand (7" IJ4S threads). DECOMP NU BOP stack CO outside lower mud cross vavle and install secondary annulus valve. DECOMP RU 4-1/2" & 5" test joints & other BOP testing equipment. DECOMP Be in testin BOP' I r psi high, hydril to 2500 psi. Tests witnessed by WSL's D. Maskell, J. Rose & C. Kobuck and by NAD TP's C. Henley & B. Simonson. Test witness waived by AOGCC J. Crisp. DECOMP Continue BOP test (250 low/4000 high - 2500 on the bag). Testing witnessed by WSL J. Rose and NAD TP Bruce Simonson (witness waived by AOGCC). DECOMP PJSM w/DSM, pull TWC w/lubricator (tested lubricator to 500 psi). DECOMP PJSM, PU & RU tubing equipment, MU landing jt & floor valve, steam wellhead in preparation to pull 4-1/2" tubing from pre-rig cut at 2616' MD (Cameron & Camco on location). DECOMP BOLDS ull han er free at 90K free up 55K, pull hanger to rig floor, break-out landing joint & hanger, re-hang rig tongs, LD 4 joints of tubing, well started to flow from tul2l.r_1g DECOMP Install floor valve & shut-in well, initial SICP = 15 psi. MU top drive, line up to open bleeder & observed once fluid packed. SIDPP = 10 psi, SICP went to 0 psi. Clean pits (suck diesel out w/vac truck) while monitor shut in pressures. DECOMP PJSM, circulate 255 bbls seawater taking returns through the choke at 5 bpm / 410 psi holding 200 psi back-preasure (overboard all returns to the cuttings tank). Open choke and bleeder, monitor well 15 minutes, open rams, blow down top 12:00 - 00:00 I 12.001 MOB P 23:00 - 00:00 I 1.001 WHSUR I P 03:00 - 06:00 I 3.001 KILL I P 06:00 - 07:30 I 1.501 BOPSURP 07:30 - 10:30 ~ 3.00 ~ BOPSUp P 10:30 - 14:00 I 3.501 BOPSUR P 14:00 - 15:00 1.00 BOPSU~P 15:00 - 00:00 9.00 BOPSU P 03:30 - 05:00 I 1.501 BOPSUFI P 05:00 - 06:30 I 1.501 PULL I P 06:30 - 09:00 I 2.501 PULL I P 09:00 - 09:30 ~ 0.50 ~ PULL ~ P 09:30 - 12:00 ~ 2.50 ~ PULL ~ P Printed: 1/14/2008 8:47:25 AM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date i From - To 12/17/2007 09:30 - 12:00 12:00 - 16:00 Y-07 Y-07 REENTER+COMPLETE NABOBS ALASKA DRILLING I NABOBS 2ES Hours I Task Code ~ NPT 2.50 PULL 4.00 PULL P Start: 12/1 /2007 Rig Release: Rig Number: 2ES Page 2 of 16 Spud Date: 4/22/1981 End: Phase Description of Operations DECOMP drive and choke lines. Well dead. DECOMP LD 4-1/2", 12.6 #, L-80 tubing from 1824', clean & clear rig floor(pulled 62 joints - SSSV & 10.95' cut joint). DECOMP PJSM, MU 5" test joint & install test plug, test lower pipe ra 16:00 - 17:00 1.OO BOPSUF(P 17:00 - 20:30 20:30 - 22:00 22:00 - 23:00 23:00 - 00:00 12/18/2007 00:00 - 06:00 06:00 - 07:00 07:00 - 09:00 09:00 - 17:00 17:00 - 20:00 20:00 - 22:30 22:30 - 23:30 23:30 - 00:00 12/19/2007 00:00 - 05:30 requirements 3.50 CLEAN P DECOMP 9-5/8" clean-out run, MU 8-112" bit, bit sub & 9-5l8" scraper on 5" DP and RIH to top tubing stub at 2610'. 1.50 CLEAN P DECOMP Circulate BU w/seawater the surface to surface with 30 bbl HVS at 410 gpm ~ 250 psi. Saw some debris on the initial BU. Well cleaned-up with return of the HVS. 1.00 BOPSU P DECOMP LD 2 joints DP and rack back 1 stand in the derrick, MU storm packer and set 32' below RKB, tested the packer to 1000 psi 1.00 BOPSU P 6.00 BOPSU P 1.00 BOPSU P 2.00 DHB P 8.00 EVAL P 3.00 STCTPL P 2.50 STCTPL N 1.00 STCTPL P 0.50 STCTPL P 5.50 STCTPL P 05:30 - 07:30 2.00 STCTPL P 07:30 - 08:30 1.00 STCTPL P 08:30 - 09:00 0.50 STCTPL P 09:00 - 10:00 ~ 1.00 ~ STCTPL ~ P 10:00 - 19:30 ~ 9.50 STCTPL ~ P DECOMP Begin ND process to swap t e existing tubing spool for a full spacer spool (need full bore spacer spool to pull the 9-5/8" casing). DECOMP Split stack and ND. Remove secondary annulus valve. Remove tubing spool from cellar. Bring in spacer spool and install. Set stack and NU. Clean up cellar. DECOMP PJSM. Make up retrieving tool and TIW valve. Screw into storm packer. Open T{W. Close pipe rams and body test breaks to 2000 si - OK. DECOMP Pull RTTS. Break and lay down single and RTTS. POOH. Break and lay down bit, bit sub and scraper. DECOMP PJSM. Spot and rig up E-Line. Make up tools. RIH with EZSV. Set at 2560' WLM. POOH with wireline. Test EZSV to 2500 osi for 10 minutes - OK. Make up USIT/CCUGR, RIH to 2550' and log up. POOH and rig down E-Line. Top of cement at 2204'. DECOMP PJSM. Make up 9-5/8" casino cutter. RIH to 2140'. Make up blower hose and top drive. WAIT DECOMP Waiting on LRS, to displace arctic pack with diesel. DECOMP Pump at 150 gpm with 430 psi. Open knives on cutter and check for collar. Set cutters on depth at 2140'. ut 9-518" casin .Shut down, close Hydril and open OA. Stage pressure up to 750 psi to break circulation. Returns to cuttings tank. Shut down. DECOMP Lay down single. Blow down top drive. Rig up head pin, cement hose and LRS. PJSM for displacement of arctic pack. DECOMP PJSM. Pressure test LRS lines to 4000 psi. Displace drill pipe with 34 bbls of treated diesel. Shut down, close Hydril, open annulus and pump 105 bbls of diesel. Pump at .5 to 2 bpm with 300 to 2150 psi. Pump last 20 bbls of treated diesel. Shut down, swap over to rig pumps and pump heated seawater at 100 gpm with 2550 psi. Bleed off, rig down and blow down. DECOMP PJSM. POOH with casing cutter. DECOMP PU and MU 9-5/8" spear and sinole. DECOMP Engage hanger, confirm latch. Back out lock down screws. MU top drive. Unseat hanoer with i 10k uo. Pull to 185k._ DECOMP Break circulation. Close Hydril, pump through OA at 400 gpm with 900 psi for 2 bottoms up. Open bag, blow down lines. DECOMP Pull hanger to rig floor with 135k. Rig up false bowl and casing equipment. Release spear and lay down. Blow down top drive. Printed: 1/14/2008 8:47:25 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-07 Y-07 REENTER+COMPLETE NABOBS ALASKA DRILLING I NABOBS 2ES Start: 12/1 /2007 Rig Release: Rig Number: 2ES Page 3 of 16 ~ Spud Date: 4/22/1981 End: Date ~ From = To 12/19/2007 10:00 - 19:30 19:30 - 21:30 21:30 - 23:00 23:00 - 00:00 12/20/2007 ~ 00:00 - 03:30 03:30 - 04:30 04:30 - 08:00 08:00 - 11:00 Hours Task Code' NPT 9.50 STCTPL P 2.00 STCTPL P 1.50 BOPSU P 1.00 CLEAN P 3.50 CLEAN P 1.00 CLEAN P 3.50 CLEAN P 3.00 CLEAN P 11:00 - 14:00 3.00 CLEAN P 14:00 - 14:30 0.50 CLEAN P 14:30 - 16:30 2.00 CLEAN P 16:30 - 17:30 1.00 CLEAN P 17:30 - 19:00 1.50 CLEAN P 19:00 - 20:00 1.00 CLEAN P 20:00 - 22:30 2.50 CLEAN P 22:30 - 23:30 1.00 CLEAN P 23:30 - 00:00 0.50 CLEAN P 12/21/2007 00:00 - 03:00 3.00 CLEAN P 03:00 - 08:30 I 5.501 CLEAN I P 08:30 - 09:30 I 1.001 CLEAN I P 09:30 - 10:30 i .00 CLEAN P 10:30 - 14:00 3.50 CLEAN P 14:00 - 17:30 I 3.501 CLEAN I P 17:30 - 18:00 I 0.501 CLEAN I P Phase ~ Description of Operations DECOMP Break and lay down hanger. Pull and lay down 9-5/8" casing form 2140'. Recovered 54 full joints, 1 cut joint at 8' and hanger. DECOMP Rig down casing equipment. Clear and clean floor. DECOMP Make up 5" test joint. Install test plug. Test spacer spool flanges to 250 psi low, 4000 psi high as per AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Bruce Simonson. RD test equipment. DECOMP Pick up mill and scraper BHA to rig floor. Service break 9-5/8" spear assembly and lay down. DECOMP PU and MU 13-3/8" scraper/mill BHA. PU 9 drill collars and 11 HWDP. Tag tight spot at 613'. DECOMP Drift through with 25k down and 25k over. Install blower hose. Wash and ream through tight spot. Free torque 2k, max torque 6k at 35 rpm. Remove blower hose. Blow down top drive. Cement and scale back on BU. DECOMP Continue to PU HWDP. Tag tight spot at 796'. Wash and ream throught tight spot. Cement back at BU. Continue picking up HWDP and washing throught tight spots at 827' and 846' to 867'. Torque 3-10k at 60 rpm. Pump at 625 gpm with 550 psi. WOB ik. Some metal shavings back to surface. DECOMP Lay down single of HWDP and POOH. Break and LD scraper, double pin XO and upper mill. Lay down Flex joint, lower mill and starter mill in pipe shed. DECOMP Wait on tools. Clear and clean floor. DECOMP PU 11-7/16" swedge and jars to rig floor. Prep tools. DECOMP Make up BHA to 946'. DECOMP RIH to 2139' with no problems. Up weight 110k, down 115k. DECOMP Circulate hot seawater surface to surface. Pump at 500 gpm with 500 psi. DECOMP POOH to 946' with no problems. DECOMP POOH with BHA. Lay down 11-7/16" swedge. Make up 12" stabilizer. Clear floor. RIH with stabilizer BHA to 945'. DECOMP RIH to 2139' with no problems. Up weight 110k, down 115k. DECOMP POOH to 945'. DECOMP POOH with BHA. Lay down 12" stabilizer. PU 12-1/8" swedge. RIH with BHA to 944'. DECOMP RIH with HWDP. Run past previous tight spots with no problem. Hit tight spot at 1131'. Work swedge through till smooth. RIH and work throught tight soots at 1161'-1167', 1275', 1469' and 1548'. RIH to 2139'. DECOMP Circulate hot seawater surface to surface at 625 gpm with 710 psi. DECOMP POOH to 944'. DECOMP POOH with swedge BHA. Lay down 12-1/8" swedge, XO and bull nose. Bring up tools for mill run. Make up double pin XO and bull nose with 12-1/8" mill BHA to 959'. DECOMP RIH and tag at 1137'. Ream and mill tight spots at 1137', 1162-1185', 1277', 1471', 1534', 1548', 1563', 1709-1716' and 1836', then running to bottom at 2139'. Pump at 310 gpm with 185 psi. Torque at 1.5k to 6k rotating at 75 rpm. WOB 1 k. Up weight 110k, down 115k. DECOMP POOH to 959'. Printed: 1!14!2008 8:47:25 AM • • BP EXPLORATION Page 4 of 16 ~ Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date I Name: Y ell Name: Y e: Name: From - To -07 -07 REENTE NABOBS NABOBS Hours R+COM ALASK 2ES Task I PLET A DRI Code E LLING NPT ~ Start I Rig Rig Phase Spud Date: 4/22/1981 : 12/1/2007 End: Release: Number: 2ES Description of Operations 12/21/2007 18:00 - 20:30 2.50 CLEAN P DECOMP POOH with 12-1/8" mill BHA. Change out with 12-1/4" mill BHA and RIH, tagging at 675'. 20:30 - 00:00 3.50 CLEAN P DECOMP Ream and mill tight spots at 675'-691', 776'-788', 806'-809', 848'-853', 861'-863', 869'-874', 942'-947', 953-961' and 971'-975'. Pumping at 325 gpm with 175 psi. Rotate at 50-85 rpm with 3-7k torque on, 1.5k torque off. WOB 1-3k. 12/22!2007 00:00 - 18:00 18.00 CLEAN P DECOMP Ream and mill tight spots at 971'-1008', 1016'-1021', 1027'-1028', 1033-1035', 1043'-1047', 1101'-1103', 1116'-1125', 1133'-1143', 1146-1183', 1190'-1194' and 1212'-1215'. Pumping at 325 gpm with 180 psi. Torque 2-8k at 50 rpm. WOB 1-3k. Up weight 110k, down 115k, RT 100k. Work through each tight spot with no rotary using 2k or less down drag. Added safe tube to reduce pipe chatter. 18:00 - 19:00 i .00 CLEAN P DECOMP Service top drive. 19:00 - 00:00 5.00 CLEAN P DECOMP Continue milling in 13-3/8" casing, with 12-1/4" watermellon mill, working through tight spots at 1272'-1277', 1283'-1292', 1313'-1318' and 1328'-1330'. Continue to pump at 325 gpm with 175 psi. Torque 3-5k at 90 rpm. WOB 1-3k. Up weight 105k, down 100k, RT 100k. 12/23/2007 00:00 - 09:00 9.00 CLEAN P DECOMP Milling through 13-3/8" casing with 12-1/4" watermellon mill, working through tight spots at 1337'-1340', 1361'-1369', 1389'-1392', 1429'-1441', 1467'-1480', 1499'-1503', 1506'-1508', 1517'-152i' and 1545'. Pumping at 325 gpm with 155 psi. Torque 2-7k at 90 rpm. WOB 1-3k. Up weight 100k, down 105k, RT 103k. Pumping tubes and sweeps as needed. 09:00 - 09:30 0.50 CLEAN P DECOMP Pump sweep at 1545', pumping at 330 gpm with 150 psi. Install rubbers and blow down top drive. 09:30 - 10:30 1.00 CLEAN P DECOMP PJSM. POOH to 947'. 10:30 - 14:30 4.00 CLEAN P DECOMP PJSM. Rack back drill collars, HWDP and jars. Inspect mill. Mill 1132" undergauge. Cutting structure was in good shape. Break bull nose and mill. LD beaver slide. Clean and clear floor. ~_ new 12-114" watermellon mill, make up with bull nose to jars. RIH with HWDP and drill collars to 947'. 14:30 - 15:30 1.00 CLEAN P DECOMP PJSM. Cut and slip 90' of drilling line. Inspect brakes, chains and hoses. Lube Elmago splines. 15:30 - 16:00 0.50 CLEAN P DECOMP Service top drive. 16:00 - 16:30 0.50 CLEAN P DECOMP RIH to 1481' and tag up. 16:30 - 20:30 4.00 CLEAN P DECOMP Ream casin from 1481'-1485' and 1530'-1569'. Pump at 325 gpm with 135 psi. Torque 3-8k at 90 rpm. Wash and ream from 1569'-2139' at 90 rpm with short areas easily reaming clean, at 2-3k torque. 20:30 - 21:30 1.00 CLEAN P DECOMP Pump hi-vis sweep at 650 gpm with 575 psi. Pump hi-vis spacer and displace well with hot seawater. 21:30 - 22:30 1.00 CLEAN P DECOMP Blow down top drive. Remove blower hose. POOH to 947'. 22:30 - 00:00 1.50 CLEAN P DECOMP Stand back HWDP and drill collars. Break and lay down jars and bumper sub. Break bull nose and lay down mill. Mill in gauge with no wear. Clear and clean floor. Bring EZSV up beaver slide. 12/24/2007 00:00 - 00:30 0.50 CLEAN P DECOMP PJSM. Lay mill down beaver slide. Blow down choke and kill lines. Clear and clean floor. 00:30 - 01:00 0.50 DHB P WEXIT PJSM. PU a stand of drill pipe. Make up EZSV running tool and 13-3/8" EZSV. Printed: 1/14/2008 8:47:25 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES I Start: 12/1 /2007 Rig Release: Rig Number: 2ES Date ~ From - To ; Hours ~ Task Code NPT Phase _, - __ 12/24/2007 ~ 01:00 - 02:30 1.50 DHB P I I W EXIT 02:30 - 03:00 I 0.501 DHB I P 03:00 - 03:30 0.50 DHB P 03:30 - 05:00 1.50 DHB P 05:00 - 09:00 4.00 BOPSU P 09:00 - 12:00 3.00 BOPSU P 12:00 - 18:00 6.00 BOPSU P 18:00 - 20:30 I 2.501 CLEAN I P 20:30 - 23:00 23:00 - 23:30 23:30 - 00:00 12/25/2007 00:00 - 02:00 2.50 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 2.00 CLEAN P 02:00 - 02:30 02:30 - 06:00 06:00 - 07:00 07:00 - 09:00 09:00 - 09:30 09:30 - 10:00 10:00 - 12:00 12:00 - 14:30 0.50 STWHIP P 3.50 STWHIP P 1.00 STWHIP P 2.00 STWHIP P 0.50 STWHIP P 0.50 STWHIP P 2.00 STWHIP P 2.50 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Page 5 of 16 Spud Date: 4/22/1981 ' End: Description of Operations PJSM. RIH with 13-3/8" EZSV to 2055' at 60 fpm as per Halliburton Rep. Make up top drive and pump at 125 gpm with 85 psi. Circulate 1 drill pipe volume. Bleed off. Pull up and spot top of EZSV at 2050'. Rotate pipe 35 turns to the right. Pick up 15k over. Wait 1 minute. Pick up in 3 stages to 60k over and set EZSV. Pick up 10' and rotate 20 turns to the right. Shut down, slack off and set 25k down on plug. Set verified. Rack back 1 stand. Make up top drive. PJSM. Test 13-3/8" casing and EZSV to 2000 psi for 30 minutes - OK. Bleed off. Break out and blow down top drive and kill line. PJSM. POOH with EZSV running tool and lay down. PJSM. Clear and clean floor. Remove mousehole. Remove riser. Nipple down stack and spacer spool. Set stack back. Remove spool from cellar and bring in new spacer spool. Casing head in good shape. Set spacer spool on stack and check wear ring measurements. All ok. PJSM. NU stack and spacer spool. Install mousehole, riser and turnbuckles. Run in test plug. Fill stack and check for leaks. Fill choke. Clear and clean cellar. Test BOPE to 250 psi low, 4000 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL Bill Decker and Toolpusher Cleve Coyne. Pull test plug. Install wear ring. Blow down. PJSM. Pick up and MU motor, bit, float sub, flex stabilizer, 1 stand of drill collars, jar and HWDP to 816' for drift run. PJSM. PU drill pipe and RIH. Tag rough spots at 1118', 1128'-1163', 1928' and 1518'. Drifted through all with 15k down drag. Tag EZSV at 2050'. POOH to 816'. Stand back HWDP. Lay down jars. PJSM. Lay down drift run BHA. Break bit. LD motor. Clear and clean floor. Blow down kill fines. PJSM. Pick whipstock BHA up beaverslide.. PJSM. PU bumper sub, XO and UBHO. Make up window mill. Orient mill to UBHO. Verify gyro will seat. Lay down. Pick up whipstock slide and run in hole. Pick up mill/UBHO assembly and tie into slide. RIH with drill collars and HWDP to 962'. PJSM. RIH to 2017'. PJSM. Rig up gyro sheaves and tool. PU single. RIH with gyro to 1983'. Work pipe and orient whipstock slide. Tag UBHO with gyro tool on seat. POOH with gyro. Verify punch. Whipstock slide oriented to 313 degrees. Tie gyro in derrick and secure lines. PJSM. Pick up drill pipe single. Slack off and set whipstock anchor down on EZSV with 35k. Set anchor and shear off at the same time. Lay down 2 drill pipe singles. PJSM. POOH to 962'. PJSM. POOH with HWDP and drill collars. Break mill, bit sub, XO and UBHO sub. Lay down bumper sub. Clear and clean floor. PJSM. Make up window mill, lower mill, flex joint, upper mill, Printed: 1/14/2008 8:47:25 AM BP EXPLORATION Page 6 of 16 Operations Summary Report Legal Well Name: Y-07 Common Well Name: Y-07 Spud Date: 4/22/1981 Event Name: REENTER+COMPLETE Start: 12/1/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 2ES Rig Number: 2ES Hours~Task Code I NPT I Phase II Description of Operations Date ~ From - To_ lil _ _ -- - - -- - --- 12/25/2007 12:00 - 14:30 2.50 STWHIP P WEXIT float sub, drill collars and HWDP to 946'. 14:30 - 16:00 1.50 STWHIP P WEXIT RIH picking up drill pipe to 1983'. Install blower hose. Make up stand and to to of whi stock at 2020'. 16:00 - 17:00 1.00 STWHIP P WEXIT Pump 40 bbl hi-vis spacer and displace well with 290 bbls 9.3 ppg LSND milling fluid. Pump at 650 gpm with 450 psi. Up 7 ~ weight 110k, down 112k, RT 112k. 17:00 - 23:00 6.00 STWHIP P WEXIT Mill 12-114" window in 13-3/8" casing from TOW at 2020' to 2024'. Pump at 650 gpm with 470 psi. Rotate at 75-90 rpm with torque 10-16k. WOB 5-15k. With WOB at 13k and torque of 12-14k there was a loud cracking noise and the pipe had a sudden and severe bounce. The torque went to the free torque of 1200 and the pump pressure dropped 50 psi. Pull up out of window and run back through with no torque or drag. Tag up at 2024' with 2k WOB and experience severe bounce with no torque. Pull up immediately. 23:00 - 00:00 1.00 STWHIP N DFAL WEXIT Monitor well while mixing dry job. Pump dry job. Blow down top drive. Remove blower hose and POOH to 1323'. Mud weight in and out 9.3 ppg. 12/26/2007 00:00 - 00:30 0.50 STWHIP N DFAL WEXIT PJSM. POOH to 946'. 00:30 - 04:00 3.50 STWHIP N DFAL WEXIT PJSM. Rack back HWDP and drill collars. PU and inspect upper mill, lower mill parted at the base. Left window mill and fishing neck in hole at 5.13'. Break out mills and float sub. Clear and clean floor. Lay mills down beaverslide. 04:00 - 05:00 1.00 STWHIP N DFAL WEXIT PJSM. Service top drive. Inspect brakes and draworks. Lube Elmago Splines. 05:00 - 06:00 1.00 STWHIP N DFAL WEXIT PU bumper sub and jars for fishing run. 06:00 - 07:00 1.00 FISH N DFAL WEXIT PJSM. MU spear on a stand of HWDP and RIH to 646'. 07:00 - 07:30 0.50 FISH N DFAL WEXIT PJSM. RIH to 1969'. PU stand. MU top drive. Establish circulation at 200 gpm with 400 psi. Up weight 85k, down 85k. Slack off to top of fish at 2019'. Shut off pump. Slack off 10k down. Engauge fish. PU 100k and break fish free at 105k. 07:30 - 08:30 1.00 FISH N DFAL WEXIT PJSM. POOH to 646'. Rack back HWDP. Remove bushings and pull fish to rig floor. 08:30 - 10:30 2.00 FISH N DFAL WEXIT PJSM. Release grapple from fish. LD fish and spear. Clear and clean floor. 10:30 - 13:00 2.50 STWHIP N DFAL WEXIT PJSM. MU window mill and upper mill. Pick up 1 stand HWDP, Make up drill collars and HWDP to 967'. 13:00 - 14:00 1.00 STWHIP N DFAL WEXIT RIH to 2018'. 14:00 - 00:00 10.00 STWHIP P WEXIT Fill pipe. Up weight 110k, down 112k, RT 112k. Ream to 2024'. Free torque 1 k, torque on 2-5k at 90 rpm. Pump at 625 gpm with 430 psi. WOB 1-2k. Mill window to 2043'. Torque 1-8k at 90 rpm. WOB 2-7k. Pump at 630 gpm with 460 psi. 12/27/2007 00:00 - 04:00 4.00 STWHIP P WEXIT Mill from the middle of the 12-1/4" window plus 20' of new formation to 2052'. Work window -clean, Total steel recovered - 730 Lbs. 04:00 - 05:30 1.50 STWHIP P WEXIT Circulate "Super Sweep". Mud wt. in and out 9.3 ppg. 05:30 - 06:00 0.50 STWHIP P WEXIT Perform FIT to 12.6 ppg. EMW w/ 350 psi. ~ surface 06:00 - 07:00 1.00 STWHIP P WEXIT PJSM. POOH to 967'. Rack back HWDP. 07:00 - 09:00 2.00 STWHIP P WEXIT PJSM. Lay down drill collars. Stand back HWDP. Inspect window mill and upper mill - in gauge. Clear and clean floor. 09:00 - 10:30 1.50 STWHIP P WEXIT Pick up running tool, run in and pull wear ring. Make up stack flushing tool. Flush stack at 800 gpm with 170 psi. Function all BOPE. Blow down choke and kill lines and top drive. Lay down Printed: 1/14/2008 8:47:25 AM TREE _ 6" CM/ WELI,.HEAD = GRAY ACTUATOR = OTIS KB. ELEV - 86.76' BF. ELEV - 51.46' KOP = 3100' Max Angle = 25 @ 5100' Datum MD = 9258' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 2.635" @ 8680' 3-1/2" OTIS XN NIPPLE Y-~ ~ NOTES: 20 sa • Sit Zs v s Told x.140' Cud f~c ~~ (1 `~'S/8'` C~Si (~ 2600 9-5/8" DV PKR 2616' POWER JET CUT (12/12/07) t~ Yu ~~ 840~~TOP OF CEMENT (12/06/07) 8524' 4-112" SLD SLV, ID = 3.813" ' 8587' ~4-1/2" TBG SEAL ASSY 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 1D = 3.958" 8602 $602' 9-5/8" x 4-1/2" TM/ HBBP PKR, ID = 4.0" 8602 4-1/2" X 3-1/2" XO, lD = 2.992" 8647' 3-1/2" OTIS X NIP, ID = 2.75" 8680' 3-1/2" OTIS XN NIP, ID = 2.635" TOP OF 7" LNR 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY REF LOG: BHCS ON 05/14/81 ANGLE AT TOP PERF: 14 @ 9288' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 9288 - 9314 S 12/06/07 2-1/8" 4 9398 - 9442 S 12/06/07 L-- 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" { 8713' ~-{3-1/2" SHEAROUT SUB 8713' 3-1/2" WLEG, ID=2.992" 8698' ELMD TT LOGGED 09/25/90 9310' H MARKER JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS 12/05/85 ORIGINAL COMPLETION 12/19/07 JMF/PJC JET CUT (12/12/07) 06/24/01 RNITP CORRECTIONS 06/28/03 JRC/KK CORRECTIONS 11/06/05 WTSlTL SET PXN PLUG (10/31105) 11/19/07 GJF/PJC PULL PXN @ 8680' 12/15/07 RMH/PJC CEMENT (12/06/07) PRUDHOE BAY UNfI- WELL: Y-07 PERMff No: 1810180 API No: 50-029-20560-00 SEC 34, T11N, R13E,1341' SNL & 118' EWL BP Exploration (Alaska) • ~ Maunder, Thomas E (D©A) Page 1 of 2 From: Hobbs, Greg S (ANC} [Greg.Hobbs@bp.com] Sent: Monday, December 17, 2007 1:50 PM To: Maunder, Thomas E (DOA} Cc: NSU, ADW Drlg Rig Zes Subject: RE: Y-07 (181-018} Fluid Balance Issue Thank-you Tom- We feel the same about the diesel- ~,.,~~~, DES ~ 12fl07 I agree with the lesson here- It could be worth apre-rig tubing punch deep to circulate the tubing deep prior to a shallow cut as in this case- the freeze protect seems to have its own mind at"tir`iies. Dick- Please note Tom's comment on testing the rams below- Greg From: Maunder, Thomas E (DOA) [mailto:tom.maunder@aiaska.gov] Sent: Monday, December 17, 2007 12:31 PM To: Hobbs, Greg S (ANC) Cc: Schultz, Mikeh, NSU, ADW Drlg Rig Zes; AOGCC North Skfpe Office Subject: RE: Y-07 (181-Oi8} Fluid Balance Issue Greg, Thanks for the information. Appears the diesel must have got strung out. Might be a function of the shallow cut. Maybe a lesson learned for future shallow cuts. Your plan forward is acceptable. There is no need to re-test the 4-1/2" rams after the tubing is laid down. Call or message with any questions. Tom Maunder, PE AOGCC From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs@bp.comJ Sent: Monday, December 17, 2007 12:04 PM To: Maunder, Thomas E (DOA} Cc: Schultz, Mikel, NSU, ADW Drlg Rig gas Subject: RE: Y-07 (181-018} Fluid Balance Issue Tom- This morning, while pulling 2600' of 4.5" tubing from well Y-07AI, slight flow was noted up the tubing after four joints were pulled. A valve was stabbed in the tubing, and the 4.5" rams were closed. Initially, there was 20 psi on the 9 5/8" gauge and 0 psi on the tubing. This then became 0 psi on the 9 5/8" and 10 psi on the tubing. We are still getting diesel in returns, so it appears to be a fluid balance issue. Dick Masked is circulating the well as we speak, and forward plans are to insure the well is stable, pull the tubing, and run a 9 5/8" plug above the tubing stub per the well plan. Greg From: Maunder, Thomas E (DOA} [mailto:tom.maunder@alaska.gov] Sent: Monday, December 17, 2007 11:49 AM To: Hobbs, Greg S (ANC) i 2n ~izoa~ • • Subject: Y-07 (181-018} Fluid Balance Issue Greg, I received your voice message. Could you please respond to this message with a written summary. Thanks in advance. Tom Maunder, PE AOGCC Page 2 of 2 12/17/2007 4~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, December 17, 2007 12:31 PM To: 'Hobbs, Greg S (ANC)' Cc: Schultz, Mikel; NSU, ADW Drlg Rig 2es; AOGCC North Slope Offrce Subject: RE: Y-07 (181-018) Fluid Baiance Issue Greg, Thanks far the information. Appears the diesel must have got strung out. Might be a function of the shallow cut. Maybe a lesson learned for future shallow cuts. Your plan forward is acceptable. There is no need to re-test the 4-1/2" rams after the tubing is laid down. .Call or message with any questions. Tom Maunder, PE AOGCC From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs@bp.com] Sent: Monday, December 17, 2007 12:04 PM To: Maunder, Thomas E (DOA) ~E(~ ®EC ~ ~ 207 Cc: Schultr, Mikel; NSU, ADW Drlg Rig 2es Subject: RE: Y-07 (181-018} Fluid Balance Tssue Tom- This morning, while pulling 2600' of 4.5" tubing from well Y-07AI, slight flow was noted up the tubing after four joints were pulled. A valve was stabbed in the tubing, and the 4.5" rams were closed. Initially, there was ZO psi on the 9 5/8" gauge and 0 psi on the tubing. This then became 0 psi on the 9 5/8" and 10 psi on the tubing. We are still getting diesel in returns, so it appears to be a fluid balance issue. Dick Maskell is circulating the well as we speak, and forward plans are to insure the well is stable, pull the tubing, and run a 9 5/8" plug above the tubing stub per the well plan. Greg From: Maunder, Thomas E (DOA} [mailto:tom.maunder@aiaska.gov] Sent: Monday, December 17, 2007 11:49 AM To: Hobbs, Greg S (ANC) Subject: Y-07 (181-018} Fluid Balance Issue Greg, I received your voice message. Thanks in advance. Tom Maunder, PE AOGCC Could you please respond to this message with a written summary. 12/17/2007 01/08/2007 Schlumberger NO. 4103 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth scANNED JAN 1 0 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 UIL!. / 1f1-o/~ Field: Prudhoe Bay Well Job# Log Description Qaœ, BL Color CD Y-07 11076494 CH EDIT SDCL GR 01/12/06 1 GNI-02A 11536185 CH EDIT USIT (PDC-GR) .. 12/08/06 1 1 L-02A 40010950 OH EDIT MWD/LWD 12/15/04 2 1 L-02A PB1 40010950 OH EDIT MWD/LWD 12/25/04 2 1 E-37A 40011299 OH EDIT MWD/LWD 01/23/05 2 1 E-37APB1 40011299 OH EDIT MWD/LWD 01/22/05 2 1 olV"',"n PLEASE A~KNOWLEDGE RECEIPT BY SIGNING AND RETU=.:~(~~rE,'~~~tt~~I~!fJPf~' BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 \\ t, \,".<.<: \'\\ t ,\ ' '\.. .\~-" ',.. Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth \~ ~'f~0~T~\~}~~)Ü\~ Date Delivered: Received by: ,~\\,9YS~?'~}, ()I)~' 1 . . e ~ e A.LA.S1iA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKJ, GOVERNOR Dave Wesley Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 \c¿ \J 0 \~ Re: PBU Y -07 Sundry Number: 306-001 J r; ( U t1: Dear Mr. Wesley: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisJ> day of January, 2006 Enc!. W61t- Ii "3[1..00c. . STATE OF ALASKA . (J(f ¡---3""O¡' ALASKA oT AND GAS CONSERVATION COMMiSSION f) r;j 1/5 / ~ APPLICATION FOR SUNDRY APp~ef:ËIVED 20 AAC 25.280 .Jþ,N 0 3 ZOQ5 1. Type of Request: III Abandon / o Suspend o Operation Shutdown o Perforate 0 Other . . ,rtI1Jrãfl"c9¡~~ª,'~ ~ons. CI.1I11I11ISSlIm o Alter Casing o Repair Well [J Plug Perforations o Stl ... - r uspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver 0 Tlm~5Pè~~'&f 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. o Development o Exploratory 181-018 /' 3. Address: o Stratigraphic 1m Service / 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20560-00-00 7. KB Elevation (ft): 86.8' 9. Well Name and Number: PBU Y-07 / 8. Property Designation: 10. Field / Pool(s): ADL 028287 Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10075 9684 9906 / 9519 None None Casino Lenath Size MD " TVD Burst Collapse Structural 110' 20" x 30" 110' 110' 2685' 13-3/8" 2685' 2685' 4930 2670 9187' 9-5/8" 9187' 8818' 6870 4760 LinAr 1380' 7" 8683' - 10063' 8331' - 9673' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: l Tubing MD (ft): 9288' - 9442' / 8915' - 9065' 4-112",12.6# x 3-112", 9.2# ./ L-80 8713' Packers and SSSV Type: 9-5/8" x 4-1/2" TIW 'HBBP' packer Packers and SSSV MD (ft): 8602' ,/ / 12. Attachments: 13. Well Class after proposed work: ,,-/ 1m Description Summary of Proposal o BOP Sketch o Exploratory o Development 1m Service o Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: / Commencing Operations: January 12, 200fif (ç o Oil o Gas o Plugged 1m Abandoned 16. Verbal Approval: Date: o WAG OGINJ DWINJ o WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ken Allen, 564-4366 Printed Name ~ve Wesley Title Senior Drilling Engineer Sionature &1"(. /h/ /;:. Y. Prepared By Name/Number: Phone 564-5153 Date I zho~~~:> Terrie Hubble, 564-4628 v Commission Use Only I Sundry Number: '3v{ø-OO I Conditions of approval: Notify Commission so that a representative may witness œ"Plug Integrity Œ"'BOP Test o Mechanical Integrity Test o Location Clearance Other: Te.~ t- 1SDI)~ '0 4000 y?W. RBDMS 8Ft ,íAN 0 4 20n6 s"..eq"ent~ 0 07. APPROVED BY Date /-3 ~b Approved Byf A COMMISSIONER THE COMMISSION Form 10-403 ~ed'91~ ~ Submit In Duplicate ORIGINAL e e To: Winton Aubert - AOGCC Date: December 29, 2005 From: Ken Allen - BPXA GPB Rotary Drilling rIt~ tØ;1~1°1o Approval is requested for the proposed P&A of PBU well V-OJ. Well V-07 is an Ivishak water injector that is currently shut-in for ineffective injection. It appears to be injecting into an isolated fault block with no off take. The wellbore is providing no iniection or value to the field as it currently sits. Subject: Y-07 Application for Sundry Approval- P&A for Sidetrack Operations Well V-07 was drilled in May 1981 into a structurally low part of the WPWZ area, encountering only 32' of LOC. Due to minimal light oil column, the well was suspended without tubing and has been used since that time as a utility well for North Slope CTU and wireline operations. The well was then completed as a water injection well on 12/5/86 and put on injection on 12/12/86. The well was then SI in 1998 since considered as ineffective injector due to injecting in an isolated fault block with no off take. Several MIT-IA test post SI showed a failed MIT-IA 10/17/98 and again on 04/12/99 with LLR 0.3 BPM at 1500#.The existing 9-5/8" casing will be cut and pulled. The new 9-5/8" casing will be set and cemented to surface. This should mitigate the current MIT-IA failure. The plan is to exit the parent V-OJ wellbore at -2,150' md. This will require cutting and pulling the 9-5/8" casing just above the top of cement above a DV collar. A whipstock will be run and a 12- 1/4" window will be milled in the 13-3/8" casing. A 12-1/4" hole will then be drilled to just above the Ugnu formation at -4,563' and 9-5/8" casing will be run and cemented to surface. An 8-3/4" hole will then be drill to the Top of the Sag River formation. A 7" liner will then be run and cemented in 2 stages. A 7" tieback will then be stung into the top of the previous 7" liner top and brought to surface. The 6-1/8" wellbore then builds to horizontal landing in the Ivishak Zone 4. The planned well then turns East/Southeast and runs horizontally for about 1,141' staying within the Zone 4 formation. A solid 4-1/2" liner will be cemented in place throughout the 6-1/8" interval. The V-07 A sidetrack is currently scheduled for Nabors 2ES beginning around 04/14/06, after / completing the E-15C sidetrack. The pre-rig work for this sidetrack will be priority scheduled immediately after the Application for Sundry is approved. Y-07 Application for Sundry Version 1.1 e e V-07A Operations Summary Pre-Ria Work: 1. Rig up slickline. Drift 4-1/2" x 3-1/2" tubing through WLEG. Tag and record PBTD below WLEG. 2. Rig up e-line. Run a GR/CCL jewelry log from the WLEG to surface. 3. Fluid pack the tubing and inner annulus. 4. P&A perfs in 7" liner from ih~B,{D up to just above the production packer. RIH with coil to . PBTD (-9,906' MD). Lay i 52 Is of cement to -8,500' MD (Above top of production ./" packer). Wash down to co rm TOC is:5 8,500'. POH with coil. a. Cement Calculations: · 7" liner = 9,906' - 8,713' or 1,193' (-44.4 BBLS) · 3-1/2" tubing = 8,713' - 8,602' or 111' (-1 BBLS) · 4-1/2" tubing = 8,602' - 8,500' or 102' (-1.6 BBLS) · Excess volume (Squeeze) = -5 BBLS ,,/ · Total cement volume of 52 BBLS 5. Rig up slickline, drift 4-1/2" tubing. Tag & reco.~TOC. 6. Jet cut the 4-1/2" tubing at - 2,600' MD. 7. Pressure test T X IA to 3,500 psi for 30 minutes. Pressure test the OA to 2,000 psi for minutes. 8. Circulate the well to sea water through the cut. Freeze protect the IA and tubing with diesel to -2,200' . 9, Bleed OA, IA & TBG to zero. Test the 9-5/8" pack-off to 3,500 psi and tubing hanger seals to 5,000 psi. Function all lock-down screws. Repair or replace as needed. 10. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 11. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. Ria Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. / 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 4-1/2" tubing from the pre-rig cut -2,600'. Spool up SSSV control lines. 5. MU 9-5/8" casing scraper assembly. RIH picking up 5" DP to -2,600' & circulate well bore. 6. MU a 9-5/8" CIBP on DP & set -2,550'. POOH. / 7. C/O to 9-5/8" Rams. 8. MU a Baker 9-5/8" casing cutting assembly. RIH to -2, 185'md and cut the 9-5/8" casing per Baker representative instructions. POOH and LID assembly. 9. MU a 9-5/8" casing spear assembly and unseat the casing. Circulate the Arctic Pack from the /~ annulus with warm diesel followed by sea water and detergent sweeps. Pull the 9-5/8" casing from the cut at -2,185'. 10. RU e-line. Run Gauge Ring / Junk basket and Gamma Ray tool for 13-3/8", 72# casing with CCL to casing stub - 2,185'. I 11. RIH with 13-3/8" EZSV on e-line. Set EZSV at -2,180 to avoid cutting a casing collar during window milling operations. RD e-line. 12. C/O to variable Rams. 13. Close rams and pressure test the 13-3/8" casing and bridge plug to 2,000 psi for 30 minutes. 14. PU 13-3/é" whipstock and bottom trip anchor with a 12-1/4" window milling assembly. BHA Tiùs 10 ~ ;:{o3 will contain a UBHO sub and G/MWD tool for whipstock orientation. RIH on 5" DP to EZSV. to Wv l Orient and set the whipstock. Swap well over to 8.8 ppg milling fluid. ~ r c".. 15. Mill a window in the 13-3/8" casing at ±2,150' MD plus 20' from mid window. Perform FIT to 10.8 ppg. POOH for Drilling BHA. Note: Verify that the mud weight is 8.8 ppg prior to cutting the window. 16. MU the 12-1/4" drilling assembly with DIR(G/MWD)/GR and RIH. Kick off and drill 12-1/4" interval to 9-5/8" casing point at the thick shale interval just before the Top Ugnu 4 (-3,775' / Y-07 Application for Sundry Version 1.1 e e ssTVD / -4,563' MD). Short trip and condition wellbore for 9-5/8" casing. POOH. The G/MWD surveys will be used until clear of magnetic interference. 17. Run a 9-5/8" BTC-M casing throughout the 12-1/4" hole and back into the 13-3/8" casing to surface. Cement will be brought up to surface. 18. MU the 8-3/4" RSS drilling assembly with DIR/GR/PWD and RIH to the landing collar. 19. Pressure test wellbore to 3,500 psi for 30 minutes. 20. Drill shoe track. Ensure good 8.8 ppg mud throughout system and drill 20' of new formation. Perform FIT to 11.5 ppg. 21. Continue drilling 8-3/4" interval holding inclination _610 and then dropping to _420 above the THRZ Formation at -11,254' MD. Mud weight will be increased to 10.9 ppg before drilling into the THRZ. Drill ahead holding angle until 7" casing point -13,585'. Short trip and condition hole for 7" liner run. POOH racking back as much 5" drill pipe as possible to limit the amount of time before running 7" liner. 22. Run and cement a 7" drilling liner throughout the 8-3/4" hole and back into the 9-5/8" casing 150' to -4,413' MD, Cement will be pumped in two stages. Set hanger / liner top packer and displace cement with mud. POOH laying down the 5" DP. LD all 5" DP from Derrick. 23. RU and run a 7" L-80 Tie-back liner to surface. Cement will be brought up -1,000' MD above the 7" liner top. The top 2,200' of 9-5/8" by 7" annulus will be freeze protected to surface, 24. MU 6-1/8" clean out BHA with used bit. RIH picking up 4" DP to the 7" tieback landing collar. 25. Pressure test wellbore to 4,000 psi for 30 minutes. 26. Drill out 7" tieback float equipment. 27. Continue to RIH picking up 4" DP to the 7" ES cementer. Drill out 7" ES Cementer equipment. 28. Continue to RIH picking up 4" DP to the 7" drilling liner landing collar. 29. Pressure test well bore to 4,000 psi for 30 minutes. 30. Drill out shoe track. Swap over to 8.4ppg FloPro mud. POOH for USIT logging tools. 31. RU e-line. RIH w/USIT to 7" shoe. Log USIT from 7" shoe to TOC in tieback -3,400'. POOH RD e-line. 32. MU 6-1/8" BHA with DIR/GR/RES and RIH to the 7" shoe. Drill at least 20' (not more than 50') of formation sliding for build. 33. Perform FIT to 10.3 ppg. 34. Drill the 6-1/8" build interval as per directional plan building to _950 (estimated -14,180' MD). POOH for horizontal assembly. 35. MU 6-1/8" BHA with DIR/GR/RES/ABI with formation tester and RIH. Drill horizontal interval to an estimated TD of -15,069' md. Condition well bore for the 4-1/2" solid, cement liner. POOH racking back DP. LD drilling assembly. 36. Run and cement a 4-1/2" solid production liner extending the liner lap 1 00' into the drilling liner. Set liner top packer and displace well to clean seawater above the liner top. POOH. Note: A perf pill will be left in the 4-1/2" liner. 37. RIH with DPC perf guns, Perf intervals to be determined from LWD logs. Plan to perforate overbalance. POOH, LD DP and perf guns. 38. Run the 4-1/2", 12.6#, L-80 TC-II completion tying into the 4-1/2" liner top. 39. Set packer and individually test the tubing to 4,000 psi and annulus to 4,000 psi for 30 minutes each. 40. Set and test TWC. 41. ND BOPE. NU and test the tree to 5,000 psi. 42. Freeze protect the IA and Tubing to -2,200' and secure the well. 43. RDMO. Post-RiQ Work: 1, Install well house and flowlines. New "s" Riser will be manufactured. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. Estimated Pre-Rig Start: Estimated Spud Date: 04/01/06 04/14/06 Y-07 Application for Sundry Version 1.1 e e Ken Allen Operations Drilling Engineer 907.564.4366 Y-07 Application for Sundry Version 1.1 TREE = WB.LHEAD = ACTUATOR = KB. B.EV = BF. ELEV = KOP= Max Angle = Datum MD = Datum 1VD = 6" CrN GRAY OTIS 86.76' 51.4 3100 25 @ 5100' 9258' 8800' SS e Y-07 13-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 2.635" @ 8680' 3-1/2" OTIS XN NIPPLE 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" H I TOP OF 3-1/2" TBG TAIL H 8602' 8602' 3-1/2" TBG, 9.2#, L-80, 0.0087 bpf, ID = 2.992" I 9-5/8" CSG, 47#, L-80, ID = 8.681" I PERFORATION SUMMARY REF LOG: BHCS ON 05/14/81 ANGLE AT TOP ÆRF: 14 @ 9288' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/8" 4 9288 - 9314' 0 12/05/86 2-1/8" 4 9398 - 9442' 0 12/05/86 I PBTD I 10075' 9906' 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" DATE 12/05/85 06/24/01 06/28/03 REV BY COMMENTS ORIGINAL COMPLETION RNITP CORRECTIONS JR0KK CORRECTIONS DATE REV BY Current . I SAe NOTES 2134' ~4-1/2" OTIS SSSV NIP, 10 = 3.813" -2,200' - Calc TOC 2600' H 9-5/8" DV PKR I - 5,286' - Calc TOC (zero excess) 8524' 1~4-1/2" SLIDING SLEEVE ID = 3.813" I I COMMENTS 8587' 1~4-1/2" TBG SEAL ASSY I 8602' 8602' 8647' 9310' 19-5/8" x 4-1/2" TrN HBBP PKR, ID = 4.0" I 14-1/2" X 3-1/2" XO I ~ 3-1/2" OTIS X NIP, ID = 2.75" 13-1/2" OTIS XN NIP, ID = 2.635" 3-1/2" SHEAROUT SUB -3-1/2"WLEG - ELMD TT LOGGED 09/25/90 I I MARKER JOINT I PRUDHOE BA Y UNIT WELL: Y -07 PERMIT No: 1810180 API No: 50-029-20560-00 SEC 34, T11 N, R13E, 1341' SNL & 118' EWL BP Exploration (Alaska) Y-07 Pre-Rig Calc TOC (zero excess) - -5,286' TOC - -8,500' PERFORA TION SUMMARY REF lOG: SHCS ON 05114181 A NGlE A T TOP PERF: 14 @ 9288' Note: Refer to Production DB for historical perf data IZE OpnlSqz DA TE o î 2105186 o 12105186 COMMENTS PRUDHOE BA Y UNIT WELL: Y -07 PERMIT No: API No: 50-029-20560-00 SEC34, T11N. R13E,1341' SNl & 118' EWl Sf' Exploration Y 7A Proposed Completion -2150' - Top of Whipstock -2,200' HES 4-1/2" X Nipple 10 = 3.813" 7", 26#, L-80, TC-II Tieback 4-1/2",12.6#, L-80, TC-II TBG 13-3/8" HES EZSV - -2180' 9-5/8" Mechanical Cut - -2185' Calc TOC - -2200' 9-5/8" HES CI8P - -2550' Jet Cut T8G - 2600' 9-5/8" DV PKR - - 2600' -3413' - TOC -4416'-7" S¡;¡¡¡I assy -4413' - BKR HGR & LTP wITB sleave -4563' - 9-5/8", 40#, L-80, BTC-M / -8923' , 7" HES EZ eMTR -13,406' HES 4-112" X Nipple 10 = 3.813" -13,426 BKR 7" x 4-1/2" BKR PKR -13,446' HES 4-1/2" X Nipple ID = 3.813" -13,466' HES 4-112" XN Nipple ID = 3.725" -13,488' 4-1/2" WLEG -13485' - BKR HGR & LTP wITB sleave Calc TOC (zero excess) -5,286'- -13585' - 7",26#, L-80, BTC-M PBm - -14969' 4-1/2", 12.6#, L-80, IBT-M - -15069' OA TE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: Y-07 ÆRMIT No: 1'1810180 API No: 50-029-20560-00 SEC34, T11N, R13E, 1341' SNL & 118' EWL SP BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date: 10116~90 T#:81597 FROM: Information Control Well Records LR2-1 SUBJECT: BP C..A,.,~ED HOLE FINAL.~ Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. .-~=05 COLLAR 10/12/90 #1 10900-11168 ATLAS 5" ...~:05 GR 10/12/90 .# 1 10800-11043 ATLAS 5" INJ ' 09/28/90 #1 9550'9895 CAMCO 5" INJ 09/28/90 #1 10650-10845 CAMCO 5" INJ 09/25/90 #1 8450-9887 CAMCO 5" ~ PROD-F 09/26/90 #1 9800-10174 CAMCO 5" ,,~3 PERF 10/10/90 #1 9300-9684 SCH 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS "-A'~CHIVES RECEIVED j/ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anct~oracJe, Alaska 99519-6612 (907) 561-5111 TO: HOUSTON ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS ARCHIVES DATE: 09/06/89 T$: 80333 BP FINAL DATA - PRESSURE SURVEY DATA Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. W-05 Static Gradient 08/16/89 Camco C-26 BHP Survey 08/22/89 HRS U-09 BHP Survey 08/21/89 HRS Y-07 BHP Survey 08/.21/89 HRS Y-08A BHP Survey 08/19/89 HRS Information Control Well Records LR 2-1 J. Dietz/S. McCurry Oil & Gas C ns. Comm[ss[o[ A;tch0rag Slanda~d Alaska Production Company P.O. 8o, 196612 Ancho~acje. Alaska 99.519-6612 (907) 564-~ I I 1 HOUSTON ARCO CHEVRON EXXON TEXACO TO: MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES RES ERVO I R REFERENCE: ARCHIVES SAPC CASED HOLE FINAL LOGS INDEXED STANDARD ALASKA PRODUCTION Da're: 11-18-88 TI: 79557 The following ma,erlai is being submitted herewith. Please acknowledge receipt by slgnlng a copy of thls letter and returning it to this office: C-29 Y-07 C.NL/GR #1 11-13-88 10900-11928 Atlas 5" PLS #1 11-13-88 9878-9883 Atlas 5" Received Date ,..~. ~nch0rage A un~! of the o~g;~ol Slondo,d (~1 Coml~)43ny Founded in Cle~,elond. C)h;o. Jn 1870. Shirley R. McCurry INFORMATION CONTROL Well Records LR2-i Standard Alaska (~ Production Company 900 Eost Be.son Boulevard P.O Bo,, 19661? A-(hotoge. Alos[.o 99519.66 ¢9071 564-5 I I I INDEXED DALLAS ARCO CHEVRON STANDARD ALASKA PRODIJC'[ION EX~ON 04~30~87 TEXACO Date: TO: MOBIL TI: 77855 PHILLIPS STATE OF ALASKA. GEOSC IENCES REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: G-26 Prod..Profile 04/13/87 H-22 Prod.. Profile 04/12/87 N-11~ Pr od. Profile 04/22/87 S-il Injection Profile 04/20/87 Y-7 Injection 'Profile 04/21/87 #1 10300-10500 Camco 5" #1 9400-9946 Camco 5" # 1 10 200-10 4 20 Camco 5" # 1 9 200 - 9650 Camco 5" #1 9 200-9800 Camco 5" E ' El),' .~~Alaska 0il & Gas Cons. Commission ~a./te_?/ ........ Anchorage [ou-ded ,,~ Cle.elond. Oh,o. in 1870 Celina Plack I NFORHAT I ON CONTROL Wel I Records LR2-1 Sfondo~'d Alasl~a ~ P~oclucHon Compon¥ [ 900 Eo,t ~n~on ~ulev~. Ant ho~ og e. AJosk o 99519-66 INDEXED =,, DALLAS ARCO CHEV O STANDARD ALASKA P ODUETION ~,'~D(ON TEXACO Date: 02/20/87 TO: MOBIL TI: 77727_ PHILLIPS f STATE OF ALASKA' GEOSCIENCES REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: B-23 Completion Record 09/23/86 #2 F-17 MWP-Measurement While Perf. 02/05/87 F-17 Perf. Record 02/05/87 #1 H-13 Completion Record 01/31/87 H-26 Completion Record 09/13/86 J-1 Junk Basket 09/30/85 N-3 Tubing Puncher 09/28/86 N-3 Collar Record 10/11/86 N-8 EPL 07/10/86 S-18 Completion Record 09/26/86 T-7 Completion Record 09/25/86 Y-7 Completion Record 05/14/86 Y-13 Completion Record 09/14/86 Y-24 Prod. Logging 02/02/87 8340-9966 Sch 5"' #1 10800-11374 Sch 5" 10800-11374 Sch 5" #1 9200-9651 Sch 5" #1 9462-9989 'Sch 5" #1 8900-9128 Sch 5" #1 9145-9600 Sch 5" #1 8172-9331 Sch 5" #1 9595-9970 Sch 5" #1 11200-12003 Sch 5" #2 8900-9600 Sch 5" #1 8450-9845 Sch 5" #1 9590-10620 Sch 5" #1 3100-13416 Dres 5'" Rece i ved Date A un~! el the o,;9;no! Sfo~do,d Oil Compon¥ · founded in Cle~elond. O~o. in 1870 Victoria Aldridge INFORMATION CONTROL Well Records LR2-1 Standard Alaska j Production Compa~ 900 East Benson Bob, .~rd P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUdTION January 2, 1987 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Well Y-Ti (22-34-11-13) PBU Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the abOve-named well. This contains our subsequent report of perforating the well. · Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 Y-7 Well File Yours very truly, P. F. Barth, Supervisor Reservoir/Production Surveillance Unit I RE.CEIVE ) A unit of the or,ginal Standard Oil Company Founded in Cleveland Ohio in 1870, / ,' STATE OF ALASKA ALASK( ~ AND GAS CONSERVATION COMM(r' ....DN REPORT OF SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown~ ,~ Stimulate © Plugging,_~ Perforate ~ Pull tubing Alter Casing ~ Other ~ 2. Name of Operator STANDARD ALASKA PRODUCTION COMPANY 3. Address P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 4. Location of well at surface 1341' SNL, 118' EWL, Sec. 34, TllN, R13E, UPM At top of productive interval N/A - water injection well At effective depth 1943' SNL, 2223' EWL, Sec. 34, TllN, R13E, gPM At total depth 1962' SNL, 2251' EWL, Sec. 34, TllN, R13E, UPM 5. Datum elevation (DF or KB) KBE = 86.76 6. Unit or Property name Pruclhoe Bay Unit 7. Well number Y-7 (22-34-11-13) PBU 8. Approval number 546 9. APl number 50-- 029-20560 10. Pool Prudhoe Oil Pool Feet 11. Present well condition summary Total depth: measured true vertical 10075 feet Plugs (measured) 9684 feet BKB Effective depth: measured true vertical 9906 feet Junk (measured) 9518 feet BKB Casing Length Size Structural -- Conductor 59 ' 20"×30,' Surface 2634 ' 13 3/8" Intermediate 9136 ' 9 5/8" Production -- Liner 1380 ' 7" Perforation depth: measured Cemented 8 cu.yds, 3720 c.f. 1401 c.f. 425 c.f. 9288' - 9442' '(two interVals) true vertical(subsea) 8829" - 8978' Measured depth 110' 2685' 9187' 8683'-10063' True Vertical depth BKB 110 ' 2685 ' 8817 ' 8330'-9672 ' Tubing (size, grade and measured depth) 4 1/2" L-80 to 8602' with 3 1/2" tailpipe to 8713' Packers and SSSV (type and measured depth) 9 5/8" TIW .packer at 8602'; no SSSV 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas'Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 2200 -- 1900 14. Attachments Daily RePort of Well Operations [] Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge (~,_~/~- ~' ~- ~ Signed · TitleSupvr. Res/Prod. Surveillance I Date Form 10-404 Rev. 12-1-85 Submit in Duplicate PERFORATING DATA - Injection Well Y-7 (22-34-11-13) PBU 12/4/86 Pressure tested tubing and inner annulus. 12/7/86 Installed and tested lubricator to 3500 psi for all well work. Rigged up Schlumberger and perforated the following intervals for initial water injection using 2 1/8" Hyperdome guns at 4 spf: 9288' - 9314' MD BKB (8829' - 8854' TVDss) 9398' - 9442' MD BKB (8935' - 8978' TVDss) Ail depths are referenced to BHCS/GR, 5/14/81. 12/12/86 Put well on initial source water injection and tested. jR 12/23/86 ALASK~ tlL AND GAS C. V~ ¢~atterton Chai,~l.~ n Lonnie C. Smith Commissioner Bobby D. Foster Petroleum Inspector CONSERVATION COMMISSION December 16, 1986 D.BDF.89 Mech Integrity Test SAPC PBU Pads S, M, U, R, N, T, Y, H, F, X Prudhoe Oil Pool Wednesday~ November 19~ 1986: The tests began at 7:00 a.m. and were concluded for the day at 4:30 p.m. with 10 wells being tested. Thursday, November 20~ 1986: The tests began at 7:00 a.m. and were concluded for the day at 7:00 p.m. with 14' wells being tested. Friday, ~ovember 21~ 1986: The tests began at 6:30 a.m. and were concluded for the day at 4:30 p.m. with lO.wells being tested. c-'oL Saturday~ November 22~ 1986: The tests began at 6:30 a.m. and were concluded at 1:00 p.m.; and were resumed at 6:00 p.m. and concluded the day at 9:00 p.m. ~ 0~'~O. for As the attached mechanical integrity test ~ports show, 3~9~ei~l~s were tested, all of which met theJAOGCC regulations. In summary, I witnessed the mechanical integrity tests on Standard Alaska Production Company's injections wells listed on the attached test forms. Attachments AI2%SKA OIL AND CAS O0NSERVATION CObIMISSION PRMi'5b~f STAKE 15 MIN 30 MIN *p *I TYPE OF PKR CASING TBG REQ TBG TI~. TIb~, W~ L *S --- ANNULUS TVD SIZE/WT/GRADE SIZE TEST CSG TBG TBG TBG CCI~MENTS *M *N FLUID MD PRESS PRESS CSG CSG CSG PRESS PRESS PRESS P - PRODUCE WATER IN3 DIESEL S '" SALT WATER INJ GLYCOL M '" MISCIBLE IlqJECTION SALT WATER I "INJECI/lqG DRTTLING ~ -;t~ : OTHER. .:., D.EW~.06 A" Standard Alaska Production Company t' 900 East Benson BoulevaJ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 October 30, 1986 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well'Yz7 (22-34-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to Perforate the'well for initial source water injection forthe WPWZ Waterflood Project. PFB: JAM ~ Enclosures (9) cc: J. L. Haas, MB12-1 Y-7 Well File Yours very truly, P. F. Barth, Supervisor Re servoir/Production Surveillance Unit I RECEIVED NOV 0 ~ 1986 Alaska Oil & Gag Cons. Commission An:h0rage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. jr STATE OF ALASKA ALASK(' .L AND GAS CONSERVATION COMIV~ ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ;-~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing :- Time extension- Change approved program--_ Plugging ~ Stimulate ? Pull tubing '~ Amend order ~_ Perforate X Other 2. Name of Operator 5. STANDARD ALASKA PRODUCTION COMPANY 3. Address 6. P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 4. Location of well at surface 7. 1341' SNL, 118' EWL, Sec. 34, TllN, R13E, UPM At top of productive interval (top Ivishak/Sadlerochit) 1883' SNL, 2133' EWL, Sec. 34, TllN, R13E, UPM At effective depth 1943' SNL, 2223' EWL, Sec. 34, TllN, R13E, UPM At total depth 1962' SNL, 2251' EWL, Sec. 34, TllN, R13E, UPM Datum elevation (DF or KB) KBE = 86.76 feet Unit or Property name Prudhoe Bay Unit Well number Y-7 (22-34-11-13) PBU 8. Permit number 81-18 9. APl number 50_029-20560 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 10075 feet Plugs (measured) 9684 feet BKB Effective depth: measured 9906 . feet Junk (measured) true vertical 9518 feet BKB Casing Length Size Cemented Measured depth Structural · -- Conductor. 59 ' 20'"X30" 8 cu.yds. 110 ' Surface 2634" 13 3/8" 3720 c.f. 2685' Intermediate 9136' 9 5/8" 1401 c.f. 9187' Production __ Liner 138'0 ' 7" 425 c. f. 8683 ' -10063 ' Perforation depth: measured true vertical True Vertical depth BKB 110' 2685' 8817' 8330' -9672 ' RECEIVED Tubing (size, grade and measured depth) NOV 0 1986 4 1/2"' L-80 to 8602" with 3 1/2"' tailpipe to 8713' Packers and SSSV (type and measured depth) Alsska 0il & Gas Cons. Commission Anchorage 9 5/8" TIW packer at 8602"; 4' 1/2" ball valve nipple at 2134' 12.Attachments Description summary of proposal [] Detailed operations program ~.' BOP sketch ~ 13. Estimated date for commencing operation November/December 1986 14. If proposal was verbally approved Name of approver Date approved Sig%~ed Title Su[ovr. Res/Prod. Surveillance I P. 1~. Barth ' ' Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Locatio~n~J,~lrance Approved by ~-/. ~~~ Commissioner Form 10-403 Rev 12-1-85 Date Approval No. Well Y-7 (22-34-11-13) PBU INITIAL PERFORATING PROPOSAL We propcse to perforate the following intervals for initial source water injection in November, 1986 at 4 spf: 9288' - 9314' MD BKB (8829' - 8854' TVDss) 9398' - 9442' MD BKB (8935' - 8978' TVDss) Note: Ail depths are referenced to BHCS/GR, 5/14/81. A lubricator will be installed and tested to 3500 psi for all well work. Subsequent to perforating operations, the well will be put on injection for the WPWZ Waterflood Project approximately late-November/early- December, 1986. jm 10/29/86 RECEIVED NOV 0 ~ ~86 oil & Et~ i~on~, commj,sto. FLOW TUBES & PACKOFF FLOWLINE FLOWLINE VALVE BOWEN PAC(i,,,O F F ~,,~.~~~::~ }.._. H A N D PUMP GREASE SEAL FLOWTUBE GREASE LINE RISER GREASE -MANIFOLD , _ ..-GREASE RESERVOIR BOP 31, 1986 Mr'~~''R.' S. "Alla~- ~'~" ~ -.. . .Telecopy No. Standard Alaska ProduCtion Company (907) 276-7512 P.* O.' Box 6612 . . Anchorage, AK-99502-0612 - Re: Extension of Suspended Status Put River BP 33-11-13 PBU C-35 ., Dear Mr. Allan: I review of our records shows that the above referenced wells are suspended. None of the wells have been perforated, and only PB1J Y-7-and Term Well C have tubing and packer installed. .? Section I10(a) of the regulations states the Commission wi,il, in its discretion, approve the suspension of a well if the well is' capable of producing hydrocarbons in paying quantities or is reasonably demonstrated to have future value as a service well. Section lOS(e) states that "[e]ach well to be abandoned or suspended must be plugged...to prevent the movement of fluid either, into or between freshwater and hydrocarbon sources and to prevent all other fluid migration within the well bore.''~ . "[tlhe In compliance with Section 170(al of the regulations, location of an abandoned, well onshore or upon a historically stable island must be cleared within one year following well abandonment.;.." Section 170(b) provides the means for an extension of time if. a valid reason exists, and the well bore is properly plugged. We are, therefore, requesting you to submit Form 10~403, Application for Sundry Approval,. for a one-year extension of suspended status for the above referenced wells together with justification for keeping the wells in suspended status. Please call Harold J. Hedlund at (907) 279-1433 if you have any questions. Sincerely, /~ Lonnie C. Smith Commissioner j o/A.l~l~. 06/07 SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 January 6' 1986 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage' Alaska 99501 Attention' Mr, C.V, Chatterton Well Y-7 (22-34-11-13) PBU Gentlemen' Enclosed in duplicate, is Form 10-403, Sundry Notices and Reports on Wells' for the above-named well, This gives notice of completion of work performed as outlined in our Sundry Notice dated October 25, 1985, Yours very truly, R. S. Allan Division Drilling Engineer RSA/MAW/dg/O140D Enclosures cc: S. R. Bundy Drilling Well File #17 O~I'L STATE Of ALASKA L ALASKA AND GAS CONSERVATION CO MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL IXl OTHER [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address P. O. Box 196612, Anchorage, Alaska 4. Location of Well At Surface- 1341' SNL, 9951 9-661 2 ll8' EWL, Sec. 34, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) __ KBE : R6:76' AMSL 12. 6. Lease Designation and Serial No. A~I ?8287 7. Permit No. 81-18 8. APl Number 50- 029-20560 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number Y-7 (22-34-11-13)PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following work was performed during the well Y-7 workover: l, 2. 3. 4, 5. 6. 7. 8. 9. The Moved in rig; Set 2-way check. Removed tree. Nippled up and tested BOPE to 5000 psi g. Pull ed 2-way check. Pulled 7" tubing. Cleaned out to 9906' with 6" bit and 7" casing scraper. Circulated and filtered brine. Tested 9-5/8" casing and 7" liner lap to 2500.psig. Ran 4-1/2" tubing. Landed tubing with BVN at 2134' and packer at 8602' Installed BPV. Removed BOPE. Installed and tested tree to 5000 p~ig. Removed BPV. Changed 4-1/2" over to diesel. Installed BPV. x 9-5/.8" annulus over to 9.6 Set packer and sheared out. Moved off rig. workover was completed on 12/6/85. ppg NeC1 and 4-1/2" tubing RFr'F- VED JAN o ? 1986 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed I~ - (~'~' ~.--~~-~ Title L,~ I ¥ I The ~pace below for Commission use Anchorage Date Conditions of APproval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561.5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 October 25, 1985 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention. Mr, C. V, Chatterton Well Y-7 (22-34-11-13) PBU Gentlemen. Enclosed in triplicate, is Form 10-403; Sundry Notices and Reports on Wells, for the above named well This gives notice of intention to workover the well RSA/MSS/hh/O628H Very truly yours, SOHIO ALASKA PETROLEUM COMPANY R~ S~ Allan Divfsion Drilling Engineer Enclosures cc: S, R, Bundy Well Records' LR2-1 Drilling File #17 RECEIVED Alaska Oil & Gas Cons. Commissio. Anchorage SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] Name of Operator Sohio Alaska Petroleum Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Location of Well At surface: 1341' SNL, 118' EWL, Sec. 34, TllN, R13E, UPM 7. Permit No. 81-18 8. APl Number 50--029-20560 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 5. Elevation in feet (indicate KB, DF, etc.) KBE=86 . 76 ' AMSL 6. Lease Designation and Serial No. ADL 28287 Y-7 (22-34-11-13) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Well Y-7 is not perforated and does not have tubing. It is proposed to run 4%"' tubing in this well in preparation to complete it as a water injector. The following is a summary of the proposed procedure. . . Install BPV. Move in rig. Remove tree. Install and test BOPE to 5000 psig. Pull tubing hanger. RIH with 6" bit, 7" scraper, and 9-.5/8"scraper. Clean out to PBTD. POH. RIH with 7" RTTS. Set RTTS 50' inside 7" liner, Test 9-.5/8"' CSG. and liner lap to 2500 psig. Run 4%" tubing with 9-5/8" packer set at 8630'. Change 4%" TBG. and annulus over to filtered 9.6 ppg NaC1. Install BPV. Remove BOPE. Install and test tree 'to 5000 psig. Secure well. Move rig off. This work is scheduled to commence late October 1985. RECEIVED OCT 5 ]985 AlasKa 0il & Gas Cons. commission Anch0ra.~;3~ 14. i hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.-/~ r ~ Title Di~±.sion' Drilling Engineer The space below for Commission use Conditions of APproval, if any: Approved by Jf ii~,!11t' 11, l[IJ/[l' COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOH I 0 CONF I DENT IAL SOHIO ALASKA PETROLEUM COMPANY TO:.. SFO/UNIT-/STATE Mo~ . ,' , · ~ P~llil~ _ .~, _ , ~ i_ ~1 Ii i i i L ~1 15 , , i i -- - -' . 3111 "C" STREET ANCHORAGE, ALASK TELEPHONE (907) 265-0 · MAIL: POUCH 6-612 ANCHORAGE, ALASKA 9! Date: 7/1/81 CONFER: ~F,I[F~-,.., ~ . _ REFERENCE: A-1 B-9 ; B-9 B-9 B-16 D-4 E-2. E-2 F-3 F-6 F-8 F-14 G-2 G-3 H-8 J-6 M-8 N-1 R-2 R-4 X-12 MPC (11) 33-11-12 SOHIO F. INAI, DATA CASED HOLE The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- CCL/Perf CCL/Perf . CCL/Perf Spinner CCL/Perf CNL CNL CNL CNL CNL CNL DDNLL CNL CNL Spinner CNL CNL CBL/VDL TDT-M EPL CNL CBL DDNLL CBL/VDL (Sch) 4/14/81 (Sch) 4/26/81 i/3 (Sch) 4/22/81 (Camco) 5/14/81 (Sch) ' 4/20/81 (Sch) 5/2/81 ,~t5 "(Sch) 4/28/81 (Sch) 4/28/81 (Sch) 5/1/81 .~/6 (Sch) 5/8/81 (Sch) 4/29/81 f~4 (Dres) 4/23/81 ~/1 (Sch) 4/30/81 (Sch) 5/1/81 (Camco) 5/25/81 ,"'/-- (Sch) 11/23/80 (Sch) 5/8/81 i/2 (Sch) 5/6/81 ('Sch) 4/23/81 it3 (Sch) 4/17/81 (Sch) 5/7/81 ~/2 (Go) 6/19/81 (Dres) 4/21/81 ~1 (Sch) 4/21/81 ltl 5" 5'~ 5" 5~ 5~ 5" 5~ '7 ! 5~ 5" 5~ 5~ 5~ 5~ 5~ 5~ 5~ 5" DATE Alaska 0it & Gas Cons. Anch0rag~ Well Records · SOH I 0 COi' F I DENT IAL SOHIO ALASKA PETROLEUM COMPANY ~o:. SFO/UNIT/ST: i,ii i i i _ -- ILL I I~ II I I Logs J C©MM I RES ENO 3111 "C" ANCHORAGE.- _ 3~'N~ ] GEOL ANCHORAGE, ALA 1/~ 3 GEOL STAT TE_C_ ~ STAT TEC Date: 6/18~8' ! .... ~_867,,' i CONFERp- ' : F!LF: REFERENCE: B-11 F-Il G-8 H-10 J-6 J-10 Y-2 R-5 SOHIO FINAL DATA The following material is being,' ~ubmitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- SFO/UNIT/STATE(-Marathon) FINAL CASED HOLE DATA CCL (Go) 5/29/81 ccL (Go) 5/30/81 ACBL/VDL (Dres) 5/13/81 CCL (Go) 6/2/81 Spinner (.Go) 5/27/81 CNL/MS (Dres) 5/24/81 Diff.Temperature Log (Go) 5/30/81 ACBL/VDL (Dres) 5/21/81 60 Arm Casing Insp.Log. (Go) 6/9/81 5!1 5" 5" 5:' 5~' 5" 5'I DATE 19 C~rol Xrif Development Geol.ogy Well Records SOH I GONF I DENT I AL SOHIO ALASKA PETROLEUM COMPANY TO:. SFO/UNIT/ST: MAIL: P( ANCHORAGE · .... ~ Date .- 6, --. i. ii i ii i iii. _ II . I __.1. _~ I STAT TEC '- FILF: STATE ONLY: REFERENCE: - SOHIO FINAL DATA The following material is being' ~ubmitted 'herewith. Please acknowledge receipt by signing a copy of this letter and returning it .to this office:- SFO/UNIT/STATE: DIL/SFL (Sch) 5/9/81 & 5/14/81 #1&2 BHCS (Sch) 5/14/81 #2 FDC (Sch) 5/14/81 #2 FDC/CNL (Sch) 5/14/81 #2 FX. I.D. Log (Sch) 5/15/81 #2 2" & 5" 2" & 5" 2" & 5" 2" & 5" 5" Magnetic Single Shot Directional Survey Gyroscopic Directiona~u~.e~v~l~. ~ 5/22/81 '~as~ 0il & Gas Cons. 4/22-5/14/81 Job#AL4-81-D10 Job#16807 Carol Krieter Development Geology Well Records SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAI L: POUCH 6-612 ANCHORAGE, ALASKA 99502 June 17, 1981 Alaska Oil & Gas Conservation Commission' 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well Y-7 (22-34-11-13) Enclosed, in duplicate, is Form 10-407, Completion Report, for the above-named well together with the Well History, Well Logs, and Directional Surveys. This well has been suspended without tubing. RHR: ja Enclosures cc: Well File #17 Geology Yours very truly, R. H. Reiley District Drilling Engineer RECEIVED JUN ! 71981 Oil & Sas Cons. r, oaalllllil~ STATE OF ALASKA ALASKA _ = AND GAS CONSERVATION C MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum Company 81-18 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20560 4. Location of well at surface 9. Unit or Lease Name 1341' SNL, 118' EWL, Sec. 34, TllN, R13E, UPM Prudhoe Bay Unit At Top Producing Interval top of Sa9 R. SST. 10. Well Number 1869' SNL, 2112' EWL, Sec. 34, TllN, R13E, UPM Y-7 (22-34-11-13) At Total Depth 11. Field and Pool 1962' SNL, 2251" EWL, Sec. 34, TllN, R13E, UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 86.76 ' AMSLJ ADL 28287 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 4/22/81 5/14/81 5/19/81 feet MSLI None 17.1otal Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey 20. Depth whereSSSV set I 21. Thickness of Permafrost 10075'MD 9684'TVD 9906'MD 9518'TVD YES [] NO [] none feet MDI 2056' 22. Type Electric or Other Logs Run DIL/SP/GR, DIL/BHCS/GR, FDC/CNL/SP/GR, HDT, .._CB..~../VDL/CCL/GR, Gyroscopic survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20" × 30"Tnsulated Conducto] Surface 110, 36,, 8 cu.yds, concrete · 13 3/8" 72~ L-80 Surface 2685' 17 1/2" 3720 cu. ft. Permafr¢,st II 9 5/8" 47# L-80 Surface 9187! .12 1/4" 1271 cu.ft. Class G;130 cu.ft. PFC 7". 29# L-80 8683' 10063' 8 1/2" 425 cu.ft. Class G w/18% salt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD ' interval, sizeand number) SIZE DEPTH SET (MD) PACKER SET (MD) None None "26. ACID, FRACTURE, CEMENT SQUEEZE, ETC, ' ~ ' ~ : r DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED , · · ,. . · . 27. pRoDuCTiON'T%1~ Date. First Production.·. ' ' I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO ~' ,. ~ ,, · TEST.PERIOD ~ I , Flow.Tubing OasingPressure . CALCULATED i~ OIL~BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) 'Press. ' 24-HouR RATE-r 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' ' ' ' RECEIVED None .' . , . , . ~,, , , "JUN 1, 7 ]98! :" ' , .' ' ' Alaska Oil & Gas Cons. Commissio~ .,. .. ~ch_o. rage , , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERs FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. I BKB ,: Subsea Sag River SST 9288' 8828, ~ Shubtik 9314 ' 8853 ' Ivishak 9395 ' 8932' :'!~:~.. , 31; LIST OF ATTACHMENTS Well History, Well Logs, Directional Surveys 32,. I hereby certify that the foregoing is true and correct to the best of my knowledge Y~M:ja Signed Title District Drillina Date ...... ~ "- ~-- ~_I Engineer ~ INSTRUCTIONS General: This form is designed for submitting a complete a'nd correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is Used as reference (where not otherwise shown) for depth measurements , . given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate i'~roduction from more than one interval (multiple completion), so state in item 16, and inJtem 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records.for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Well Y-7 (22-34-11-13) HISTORY Spudded well at 1200 hours, April 22, 1981. Drilled 17 1/2" hole to 2700'. Ran 69 jts. 13 3/8" 72# L-80 Buttress casing to 2685'. Cemented with 3720 cu. ft. Permafrost II cement. Installed and tested BOPE. Cleaned out to 2644', tested casing to 3000 psi, okay. Drilled out to 2714', ran leak-off test to 0.61 psi/ft, gradient. Directionally drilled 12 1/4" hole to 9202'. Ran 239 jts. 9 5/8" 47# L-80 Buttress casing to 9187'. Cemented in two stages: First stage with 1271 cu. ft. Class G cement; second stage through D.V. packer at 2600' with 130 cu. ft. Permafrost C cement preceded by Arctic Pack. Cleaned out to 9070', tested casing to 3000 psi, okay. Directionally drilled 8 1/2" hole to 10075'. Ran open hole logs. Ran 35 jts. 7" 29# L-80 Buttress liner to 10063'. Cemented with 425 cu. ft. Class G cement with 18% salt. Cleaned out to 9906', tested casing to 3000 psi, okay. Changed well over to NaC1. Installed tubing hanger with one joint 7" tubing. Installed and tested 6" tree. Top 200' of hole displaced to diesel. Released rig at 0001 hours, May 19, 1981. Ran CBL and gyroscopic survey, secured and tested wellhead May 22, 1981. MC~: ja RECEIVED JUN 1 7 1981 Alaska 011 & Gas Cons. Commissio. r~ A~chorage. Mr. Gary Plisga Sohio Alaska Petroleum Company 3111C. Street Anchorage, Alaska 99503 May 26, 1981 Re: Our Boss Gyroscopic Survey Job No. Boss-16807 Well No. Y-7 (SEC34 TllN R13E) ~,c~'~ Prudhoe Bay Field North Slope, Alaska / Survey Date: May 22, 1981 ~ Operator: John Samec Dear Mr. Plisga:. Please find enclosed the "Original" and seventeen (17) copies of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Yours very truly, SPERRY-SUN, INC. KA/pr Enclosures SOHIO ALASKA PETROLEUM COMPANY Y-7 (SEC 3/4 TllNR15E) PRUDHOE BAY MEASURED DEPTH ':: A N C H 0 R A G E, A L:.A $ KA::i?.;!!:?:?:;:7::.:!> ;::; ;;i::i...i>!i .::.: · :: ! ' ' : :::.:;. ':':'~.":' DATE OF' SURVEY MAY 22, 1981 COMPUTATION DATE BOSS GYROSCOPIC '$-U-~'~'E-Y ' MAY 26, 1981 dOB NUMBER BOSS-16807 KELLY BUSHING ELEV. : 86.76 FT. DEPTH DEPTH DEG MIN DEGREES BEG/lO0 NORTH/SOUTH EAST/WEST SECTION ¸0 0 100 99 200 199 ~r ~ 300 299 /400 399 600 599 '7007. ' 699.93 '.::? 7613"'177'i:, :'. ~:o._o-- ........ ? _~..9 _,..~..~ i..: :'. '? .' i: i. 73_73J': 900 899,92 8i3.i6 looo ~.~e ~i~.i6 ~ ilOO lo~.~e ioi~.16 Y2-o'o '-'~:: fi~T:~ l:.:':: ;/':~ Ffi:~ ;i.~S: ~ ~oo :~2~9,~z' · 97 213.21 0 53 .95 313.19 0 55 .9/4 __/413 · i 8 ..... 0 .5_.3 .9 ~ · ::':: :5 i 3 'I17 !::::':i.:. o ~ 7 S 14.39 W .07 S 1/4.79 W .03 0 2/4 0 23 0 23 0 28 0 30 0 19 0 17 0 19 0 9 S S N 63.19 E ,10 86.69 E .20 71.80 E .19 /4.47 N 2.92 N · ::;::::.. 1-63N ~., S 13.39 E .47 . o. o o - 2'7g0--- ..14 E -2.44 · :::::.16 :E -1.9~ .11 U -1-.-75 .46 W -1.69 · 86 W -1.64 · 21 S .30 W .38 S .42 E · 27 S 1.26 E -1.57 -1.35 -.87 -.23 .51 1.29 .73 N 1.70 . 82 N ..... ' '" ..... i".-8-g--E' ................... 1%-5'5 1600 1599.91 i5i3.i5 0 21 S 8.19 E .20 .>8 N 1.93 E 1.75 1.700 1699,91 1613,15 0 36 S 8.30 E .2~, .45 S 2.05 -_- 2.1o ................ . s '~'o-i%%-i-~ ............ ~- ,~'~. 's--Zg::-~::''`::'':': ........... · ":'"~'~'" :':'::': ..... ...... 5To'~--~ ...... :':' ...... ' ....... :":~'~:'E'"~ .............. r~o': 2100 2099 8 .... ~. - ~ 2200 2199.87 2113.11 0 57 S 32,50 W .14 6.~b b ..l so . 2.65 2299.85 2213.09 1 0 S 28. 0 W .09 2300 2400 2399-.-8'4 2313' 08: ': :.:: :: :' 0 :: 48 2500 24 99 · 83 -: :2413 :. 07;i.i:.~:: : ::::.:i :: 0':: 41 · : . ................. 2..6.0 0____2,%9-9-'8-2 r',2513.0677 ': 07' 43 2700 2699.81 2613.05 0 q8 2800 2799.80 271~.04 0 37 29_.0_0 ............ 2899_._7._3 __ 2812.9 7__ 3 ....... 0 3000 2999./43 ' 2912.67 · 5 47 . .. : · . · S 12.39 E .12 N 90. 0 E .91 N 84. 9.E 2.37 ~ Y-7 (SEC 34 TlINR13E) I PRUDHOE BAY · .S P E R R :Y's U N; U E. L; L:":i.. S u~. V EY:I:N;,;. COMPUTATION DATE MAY 26~ 1981 iT E ::0 F.: S U R V E Y ': M__A Y 2 2, i :,.19 81 BOSS GYROSCOPIC SURVEY dOB NUMBER BOSS-16807 KELLY BUSHING ELEV. = 86.76 FT. R A T 0 R-U 0 HN....SA M E C(:~'~C'::; MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY 'DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/IO0 . ':: ':. ' '::': .' :~: :.:;. ' · :".:' · :::<~.:~);.:-:!.~:~:~:.':/;{~::~!~ 7 ( :' . 3~oo ~o.~ ~o~.~ ~7 ~2. s ~.5o E 2.~ ~5oo ~B5.52 ~B.TG ~B ~ s ~.~ E ~.70 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERTICAL SECTION 17,63 S 91,45 E 21,58 S 122,12 E 25,92 43,37 ................. 92,7:. 123,28 4000 3946,60 3859,84 23 47 S. 80.30 E .'22 52.60 S 312,47 E 4100 4038,16 3951,40 23 37 S 80,50 E ,17 59,38 S 352,10 E ........ 9_20~0~.ZL1.2~_,..8.5_ ..... ~.0.4.3..,._0.7~_ ..... 25.__5.0 .... S~8..0_.~3~9 E .13 66,08 S 391,51 E 4~00 ,- '4221.47: ( ::~: ~13~.71 ~. ": S 80 72.72 .S. ::':',:' 92.96 S 550.22 100.2~ s 590.82 Lo_7._._8_9_s 6 s 1.4 o 116.03 S 671,75 12~.67 S 133.78 S.. '.' 752.79 314,72 354,66 394.37 ~ s--~-'~ 474.08 513.98 E 554,27 E 595,28 E 636.39 677.4~ 718,5 760,17 5200 5300 i 5500 ~ 5600 L__ ........ 5.7.0_0 5800 5900 6100 5042.00 4955,24 24 51 5152.81 5046.05 24 39 ............. 5223.79- 5137.03 2~ 23 5314.871: :!.!;.,5228'1I.:~. ~ 24 23 5406.03 !~i/!:5319"27 : 24 8 s 77, 0 E ,12 143,17 S 793,81 E 802.19 S 77. 9 E ,19 152.56 S 834,62 E 844.00 S 77.39 E .30 161.72 S 875.11 E 885.43 · .s 17-0-.762 ~s'- ~ 915-~%-~ .-- 926-,'6-3 ........ S:'!:'77'' 6 97:E;i;i;ii'~ii:;iii::i::i:i!i!!!i~ii~:i':;:,':25:'i i. ':: 7 9,38 .':!. S:( ::' 955 ', 5 8::E ;:.'::: :i ": 9 57,63 .s -3.8-"--~ 0 :~_6 ':...:.. ;.;;: L.~7~my_s. i.'. _~: .. 'i.i., _~_%5_._5_2 '_E : , 1 o o s. ~ ~ 5588.77 5502.01 2~ 39 5680,44 5593,68 2;:5 25 586~o25 ': 5'77:7o~9 22 55 · S 78.39 E .40 196,03 S 1035,14 E 1048.67 S 78.39 E .23 204.07 S 1074~.27 E 1088.49 S 78,50 E ,17 212,00 S 1113,09 E 1127.98 s 78.69;: 9 "75'::s :.~ ~';; ;.11,5 i..5 ~ :: E.; ::. i 167'. 0 6 L~.~O.H~_Q. _~U~.S.K~A. ,_,~T R OL E UM Y-7 (SEC 34 TiINR13E) PRUDHOE BAY ALASKA ' :sPE~R-Y:S"UN WELL· SU~VEYING.?:COMPANY.'"~ ::'~':'~ · :.:,:... :.. , P'A-6E -3 i :,, . ANCHORAGE, ALASK'Ai::i:'..ii::.,::: ' · . , cOMPANY ' 'L ~' .: :i'. OF SURVEY MAY 22, 1981 · ~ .......... COMPUTATION'--- '= ............ "~-DATE'"'"-":"'~'~' ....... ~:'~"" ~:~:~'~'~:'~ .... ~Bb-S-S--~Y'KO'S'dO"Fi-C-'S-O'KV'E~ MAY 26~ 1981 JOB NUMBER BOSS-16807 KELLY BUSHING ELEV, = 86,76 FT, MEASURED VERTICAL DEPTH DEPTH VERTICAL INCLINATION DIRECTION SEVERITY R E-C-T-A-N~G-O'JA R ...... C-O-O-R'DTN-A-T'E'~ ......... V-ERTI-C AC DEPTH DEG MIN DEGREES DEG/iO0 NORTH/SOUTH EAST/WEST SECTION 6200 5956 59 5869'65 '::':': :; .22 A7 ! S 78,59 'E AO S 11'~-~,63 E 6300. 6048.75 S 78.59'E!i?::iiili!!:i:!'!ii~:i:'52~:i!~iii:ii:'?!'!:":?:ii'ii:'23~'98 S 1227.20 E 6500 6234.A5 614.7,69 21 15' S 78,50 E ,57 249,69 S 1300,00 E ......... 6600 6327.78 624:1.02 20 49 S 78,89 E .~5 256.72 S 1335,22 E 6.~_0.0~.6~.2.1,~2 ....... 63~6,66 20 1~ S 78.80 E ,59 263.51 S__1369,63 _ 6800 6515"55 6q28'79:;.;:...::'~':' i;;] 270.37 S 6900 ] ]6610.22 18 22 277.15 S 7100 6800.81 6714.05 16 51 S 77.69 E .80 289.87 S 1A93.38 E 7200 6896.65 6809,89 : 16 19 S 77.69 E .52 295.95 S 7300 699.2~..79~ 6906,03 15 37 S 76,50 E ,78 302°09 S~ 7 ~ o o o 89.20 7002'..~ ' :..:. 1'5 ....... f'o ...... :'s:: 76- 8.0i...: :E,i i:?%i!i.:i~'~!.ii??.?~:.:!:~.:i.' ~+6:~i:::;.~:i:.;~?!:.i'~-:I 308 · 22 S 750 O' :~ 7185.89 7099 '115'!;i.::':i!~!:::~ 14 22 ' S~:; 7-5::::~' 50';~' ! E~?~iiiiii?i?'~.:iii~ii~i:;ii'!i!!"88'i~i?~!ii:ii??:': ::131 ~+'. 36 S ~_6_0~.: ..... --7.2~.2'_9.2 ...............7196 "16: ::' . 13 36 S '82:..~::?.~?::;;: ;-: 320 · 7 ~ S :..:: .:;,. ;: ::,,' ;...;>.:.. ,::.:.. ,~.,. ~;.~L;:?¢. ,7.'::' .:%;~:: ~ 7700 7380,19 7293,~3 13 1~ S 72,80 E ,48 327,35 S 7800 7900 1521.28 r 15A8.10 E 8000 81oo I ..... 8500 7477.62 7390.86, 12 4-5 S 71. 0 E .63 334..33 S 7575.20 7488.44 12 31 S 68.69 E .56 34.1.86 S 7672 · 72 :.. 7585.96 ::': :~ f5 ........ 3 s: :& 4:~:'; 69 5 o. 62 s~ ~;~ .:.~.¢.: ::.:.:.:.....:...:.:::., ~. ...:,:,.~ ,:..:., .:.~;~.;:. ~ 7962.02 7875.26 17 ~3 S 55. 9 E ~.98 390.5~ S 1665.65 E 1686.19 E 1¥06.49!:;E..~.!: ', · 1727 .. 65 "i. E:. :' 1750'.52 E .::'- l'f-~'4.56 E ................ 8400 8057.52 7970.56 17 8500 8153,25 8066,49 15 8600 82~9.85 .::i :.:.18.163'09 ': ,i 14 8700 :: 83~6.62 825.9' 861 ?.~': :'.1~ 8900 8559,85 8455,09 15 9000 8656'45 85~9,69 14 9100 8735.1~ 86~&.38 1~ 9200 8829.8~, 8745.08.. lA 32 11 53 3 7 51 45 ~+8.50 E 2.01 4.09.23 S 1798.5~ E 51.39 E 2.49 4.27.39 S 1819.86 E 6'4.' 5' 8 · . 1862'12 ;:;E"~ :"":::." 2 s 8 ..,.. 6~.80 E .~0 ~77.19 S ~09.05 2 61.30 E .70 ~88.70 S ~93~.~0 E 58.59 E .~5 50~.28 S 1~5~.~0 E f2-o-5-JT7 ....... 1245.97 rs-f-T,-9'8 1353.75 1388.69 f~-f2.3 3 1454.46 1~85.30 16-f~L-~ s 1543.56 1570,84 15977~'5 1622.83 16~+7.01 £E~O72-2 1692.70 17~6.53 1 ~759.7'~ 1785.26 1841,04 1866,78 f~-g-o%-g-o 1915.~1 19~0.58 1966,34 1991,78 2016.,62 :2-0-4-079-0' , ~, ': ~: "..:!::ii , ANCHORAGE~'ALASK i i. :':. Y-7 (SEC ~A TiiNRZ3E) COMPUTATION DATE BOSS GYROSCOPIC SURVEY . PRUDHOE BAY MAY 2Ge Z98~ JOB NUMBER BOSS-16807 MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH DEPTH DEG MIN DEGREES DEG/tO0 NORTH/SOUTH EAST/WEST SECTION 9600 9218,85 9132,09 12 17... S 56,39 E '.48 567.80 S 2052,3A E 2129.24 9700 9316,62 9229,86 11 57 S 55.89 E ,35 579,50 S 2069,78 E 2149,26 9_.8_.0_0 ...... 9.A 1.fl_,.50. 9_~.~,.7_~ .......... ~3_9 ..S_5.7_,__9__E ................. ,_3~ .. 5_9_0_,_8_0~S ....~0_8_~,~_5_~.E 2 kE8_,.8_O ..... 9850 9463.48' :~.::.9376 ;:::: 33 . S:56.80;;'.'E~:~¢~:~ 28~::/S ;~'~:,;~j:::';:~;:~ 2'0 95.28.. E:~::.;;?:- ::..:~' 2178. ~ 3 ;.~9~ o o:~;::. ~5i e. ~ 7~ ~ ~. :. 2 ~. o ~ i0075 9685.92 9597.i6 11 55 S 56.80 E O.OO 620.95 S 2132.97 C 2221.52 i T HE:': :.CA L c'uLA T'] ON PR 'B';A::'S::E D'ON N'A~ CuR HiE TH ODD i SPERRY-SUN WELL. SU~VEYING,:.COMPANY. i ANCHORAGE~:~ ALA .~ ~. ].' i_,_S 0 H,I,O , &L_A_$,K,A,.,_P~E, T_ R Q.L E u__M._.,C_.O_~_P~A__N_Y_ ......................................... ~-,--;.' ',~ :: :::i: ~:. ~ .i"?.i~iiiii;i;:.i !i:'.i :i:' i.i;]..:....,i, ~: !.. :i~.: .:.~._D A.TE i~0. F.~ S. U R V,E Y , Y-7 (SEC 3~+ TllNR13E) COMPUTATION DATE PRUDHOE ALASKA MAY 22~ BAY MAY 26, 1981 dOB NUMBER B0SS-16807 KELLY BUSHING ELEV. : INTERpOLATEB VALUES FOR' EVEN 21 DEPTH ' 1981 86.75 FT. TRUE SUB-SEA TOTAL ~___M_E.A..S_Ug_E D V E.R~T_I_C.A._L____V_.E_~?.,~..A.L .........~E.~C~_.~9_.~...W.L~.A R COORD INA TE S MD- TVD DEPTH DEPTH . DEPTH NORTH/SOUTH EAS:T/WES::T:":.:':L::~;'~DIFFERENCE 1000 999,92 913,16. .58 S ,42 E .o8 2000 1999.89 1913.13 3.86 s 2.16 E .11 .... ~00~0_____2.9_99_._4.3 2912.67 12.96 S lO.6A E .57 7 ~ .'." . ' "' 5000 4860,~1 ~72.73,65 : ~: ::~ ::.:~ 124,67 S 7.12,07 ~:~ 159,59 600~ ..... 57.72.,26 56'85'50'~~: ,.::~ ['~.1,,2~.0.0 S :1113'- ~"227,76' 7000 6705.31 6618,55 283,61 S 1464,~0 E 29~,&9 8000 7672,72 7585,96 : 350.62 S 1706,~9 E 327.28 9000 ............. ¢63.6.,?.5 8549,69 488,70 S 1932,20 E 363.55 VERTICAL CORRECTION .08 : · '~".'.' 88.26 E6~-9'4 32,60 36,27 .............................................................................................. sPERR~Y-suN WELL SURVEYINGS?COMPANY PAGE ANCHORAGE, ALAS L S 0 H.I..O_... A.L. A S K A ~..RET R 0 L E U M. _C 0 M P_A~ NY ............................................... ,.~'~-_, i,~i :~ ~:ii, i: !i i:~:, ~.:i~: ~:: i:'~ D_~_%E_Q, F.~, S.~ R~V_EJ_~_.A_Y_2_2_Lkg_8~I ........... Y-7 (SEC PRUDHOE'BAY .... ALAS. K_L ........... . TllNR13E) COMPUTATION DATE MAY 26, 1981 JOB NUMBER BOSS-16807 .K_EL LY__~_U._S..H.I.~.J.G_E. LE_V_,...: =8_6_,_7_6--F-T ......... TRUE SUB-SEA TOTAL ~__M EkS U. FLE Q .... _V_E R_T. LCA L .... V_E~LLIC. A L _- RE C_T_ArN6,U. LA_g ....... _C_O_O.R..DIJ~JLTLE.S ..... DEPTH . ,DEPTH... : ,DEPTH NoRTH/SOUTH i: ............... --~oi ................ i.-,.....o.'.o,o '~ =.~.~;.-7~.,_--~:~:~.o, o o] ~.., .' :'°~'Lo?~~ 86 86,76 0,00 9,~i N ,iO.E ,00 186 186.76 100.00 7.81 N .19 E .02 __ 286 ........2.8.6_,_7_6 _ .2~00_,.0_0 ................6 · 2.3 _. N ..... ,_0_7__W ................ 386 386-76 300,00 :::: · ~,67 N z+86 z~86,76: ::.z~00'00::: ::' ,5.12 N~ 686 686,76 G00,00 ,B~ N 1,21 W ,0T 786 786,76 T00,00 '. ,23 N ,92 W ,07 886 ............. 886,_.76 ....... 8.0_0_,..0.0 ...................... · 17_S_ ,.3_8 W ,_0_8 986 ~8~.76 :~:: ~oo'.oo .~8 ........... _V_E.g_T_LC_4._L . CORRECTION .00 .01 ·...J0~ :.., A ,:;::: ...... ' '00 '00 1286 1286.78 1200.00 .18 N 1386 1386.76 1300.00 .67 N _L~.86 ......... 1.~..86...,16_ l~O..O,O0 .,86 N 1586 1586'76 ~.1500,00 ,~6.N.:/. 1686 1686,76 :lGO0. O0 .32 ....... -1186 ......... 2,19'E 2.O2 E 1 · · 09 .00 ,09 .00 · 09 .%0 '.09 ,00 . ANCHORAGE,.?'ALASK'A::ii:'::~'. :' :: -' !LSOHIO ALASKA PETROLEUM COMP ANY ................. .... ' .....i.. :~.,L.DATE OF Y-7 (SEC 3~ PRUDHOE BAY ALASKA TI1NR13E) COMPUTATION.DATE MAY 26, 1981 SURVEY MAY 22, 1981 JOB NUMBER BOSS-16807 KELLY BUSHING ELEV. : PAGE · :" I N T E'R P 0 L A T E O V A L U E S FO R C E!:rvE:N ;i :1"!0' 0 i:!i'F rET" oF FT. TRUE SUB-SEA TOTAL ~__MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH ! DEPTH . DEPTH N OR T H/SOUTH ii:!.L:.~.;i~ EAST/WES T. ......... o 1986 1986.76 1900.00 3.72 S 2.18 E .11 .01 2086 2086,76 2000,00 4.84 S 1.81 E .12 .01 2.1_8.6 ......... 2.186 ...76 2..19.0.,9.0 6 · 16 S 1.03 E .15 2286 2286.76 2200.00 :. ,.~__2_~,8~.6,2386 ..... 2386,762,~8.6..,7~..6 .............. 25002 ~,.O 01,'"0_ 0'00 ]' 1:9 e 0 9 iilS';"i 'i: :i ;iii ' 0,. 5~6.~$~, :i:., ' 5 2]' 'i.95-"W i]i:~ ' .... :':i]:. "i:, .--_ ......., 1_7' 2586 2586.76 2500.00 11.55 S 1.09 W .18 2686 2686.76 2600.00 ' 12.85 S .90 W .19 ....... 2_7.~.8.6 2786,76 2700,00 15.72 S ,50 W ,19 288.7 ' 2886 · 76 2800:. O0 "-" .: ;1,-3~'T5~2 S~.:, ~:: ~:;'2.'52 E 5 2987 . 2986,76 2900'00 ;:;'i; :;;;;: :i'ii'.:'13' 9. 5189 3186,76 $100,00 13.29 S 39.16 E 2.82 3292 3286.76 3200.00 14.82 S 62.27 E 5.~,9 3396 3386.76 5300.00 17.51 S s 0'7 ssoo.oo .01 .01 .01 .01 1.56 2.67 3.91 8,26 i ~ : ~ SPERRY-SUN wELL'SUr~VEYING :cOMpANY. i.::': i'~ PAGE ,:L '~'~ : :ANCHORAGE,*:'AEA t SOHIO ALASKA ..... RE..TROLEuM' COMP ANy . L' ~:':' ,-i i ,. 2LL2~.,_:S.~:~-LLS. L.i; Y-7 (SEC 34 PRUDHOE BAY _A,LA~$i~A_ TllNR13E) COMPUTATION DATE MAY 26, 1981 JOB NUMBER BOSS-16807 KELLY BUSHING__E_L_E_V. : 86.76 · : : .' ,.. : i ]i'.::ii:-i:i: ]ii;~'i~~I ~'P'E'R A T 0 R- U OHN: S A ME C' .,i FT. TRUE SUB-SEA TOTAL· __~E.A.S_U~ED.~_V£R_T_L¢.&L____V_F.R.LI.C.A.L..___RE.CJ..A.NG~.UL A_R .... ~C-O-O~D ~.~TJE_~M_D-__T_V_D_~_V.E.R._T_I_C. AL, . 3934 A043 3986.76 3900.00 4262 ~ 4186.76 4100'00~ 4371 · 4286,76 /+200. O0 .i:~ ............. 4~480 ...... ,~4 386., 7, 6,---::L..4.3 0.07 ~00:~L- ~589 4~86.76 4400.00 3886.76 3800.00 4 8.21 S 286.44 E 47.83 9.34 55.58 S 329.92 E 57.12 9.29 .62..95 ...... S ............. 3~..0_4__E ........... 6.~._~7 ....... ~k5 : :~:!'i ..:: ?~!:'.:~ ::.:::':::.': . ' ~ '-' i::.: :'.-.::'i :.: ~.;'- e' :: "; :':' ' 70.20 S .::.41.5..96~:.E:~:::,.'::.:.....: 7~.3~ 06 .. . 77, ~ 6 S :i' ' !::;!i!'i1459'i26:'iiiii:Ei!ii.:~?iii!i!;!?!:?'i'" !:84.5· 21 ':::'!::':' !i:i!: :::i:!: 92,24 S 546,12 E 10~.10 9.33 4699 z~586.76 4500.00 ~ 100.20 S 590.66 E 112.86 9.76 _~,8.0.9 .... _~+.6 86.,,.76 ....... /+,.600..,~0.0~ . ..1.,05 · 63 ,._S ~6_3.5_,_2_0_E ................... 1.22_._6_6 ...... 9__8_0 4919 4786.76 4700.00 :: :i::1117'64 S 9.73 '."::: 5028 4886.76 4800.00" 127.24 723"74:::'i:::5::.' i~2.17':':::;':' :':' :' 9.78':::" :.: ............ 5_Z.3.9 ........ ~9.8.6_,.7.6.~.-- .... 49:0..0..~'~q..0..: 52~9 508~.75 5000.00 1~7.83 s 813.99 E 162.56 10.20 5359 5~86,76 5100,00 158,06 s 858,72 E 172.58 10,02 ............ 5.A..6.9 ....... 5286..~6 ............ 5.20.0 5578 5386.76 5300'00 :.~. 5688 5486'76 ::::: ::::'5~00.0 .......... 51~.7 .............. 5.5~8..6._.~7...~....' %0..oA-Q.~ :.::: ::_. _ i:::,:.:--~!~_"_~ 6:::::'::,~. :.:'_~:~ '/: !-°'~-% :-~-8'::"~:~: E'. :_ .: '__._~3.?_0_S L':: ~. :::. :: :.:::: .: :.:9--' ~' 7 · : . · · . ~ ' SPERRY-SUN' WELL;'SU~VE'YING:::;!iC.OMPANY";:~. ' · ' i SK A:;?.-:::i;,: ::'::": ;: i':: ':'.? ::.: :" · ~S 0 H !.O.A.L_A..S.K,A.__.P..~.T_R,.O._L E..U.~ :.~c..9?p A ~_y~: ............... :'-:.',_._:.:~_~ :': 'r:'~ ::: :'--'::.'::L. L ~i: :::" :::: :f' . D AT E' 0 F 'S U RV E Y M A Y 22, , Y-7 (SEC 54 TllNR13E) COMPUTATION DATE PRUDHOE BAY MAY 26, 1981 dOB NUMBER BOSS-16807 1981 KELLY BUSHING ELEV. = 86,76 FT. : .::~ i;!ii::.": :' i/i]i~:: :: ::: 'i: i: :~;: ::: 'i E R A T 0 R - d 0 H N :.S ~ M'~'C . iNTERpOE::ATED: VA:LOES :FOR~ ' . .. TRUE SUB-SEA TOTAL ,_._.M..E.A.$.U R E D VERTICAL VERTICAL RECTANGULAR COORDZNATES MD-TVD VERTICAL ! · EPTH ' :'oE'P-T~H .... CORRECTION :':. :'.: ':: : i : · .' .' -'; :::-:-4 :: ::: :: : ;. ',.:: ': ' 7:'::;~ 'i !~,:,,:' ~!:::::;';.'%i:'?:::':;::~:r.:,';;::' . ':? ' 08 :':i ' i s- oo.oo s E 6124 5886,76 5800,00 221,6 .... 62.5.2 .... _5_9.8_6.,Z6 63A1 : 60'86.76' '~'i~ 6:000,00. 258.0 64A8 6186.76 6556 ....... 62.,86~,.!6'. ; :. 253.7 2 S 1160.87 E 237.68 8,66 2 S 1202.14 E 246.18 8,50 5 $ i.: ::'::%i':242:,;'416i:E!i:i.::t!.i:i.:!i~:!!'..::.:?:i?i:254:. ~ 1 . : :~:!..: f~ 8.113..::.::i::.i: i L.i '. 8s ::' :'ii:1:.2'8:::1'::7:6~:::E?':i?~i?;1'2~ 21. o s "::: :~:: ::: !i?: ~ ii! 7' ::7 ,~ ::::i:!?:: ~.f.i::::.;::i:: ::::::' 6665 6386,76 6300,00 261,02 S 6769 6486,76 6400,00 : 268,23 S 6._8_7.. 5 .....6586.76 6500.00 275.53 S 6980 6'686.76 6600'00..~.::::... 7085 6786'76 · 67~0.00 .:::::;i":;::. 288.97 S 718 9 . ],':': ...... ' 2.9 5.,9.4 s 729:5 6986.76 6900.00 30:I .70 S 7597 7086.76 7000.00 308.07 S 7605 7706 7809 314.42 S 1357.09 E 276.30 6.95 1392.87 E 282.75 6.45 1~26.53 E 288.52 5,77 8.56 ~ ,~ ::.. ?..4-79, .,::i~ 1546.47 E 506.98 4.05 1573.29 E 510.71 1598,90 E 314.14 3.43 . S ERRY SUN WELL· SUn'VEYING COMPANY.'~,:!.::: :' : PAGE lO- i · ~ '' ".". ~]~ ~. '~: ANCHORAGE,{ALASKA~ :] ~:] ''~ ]:] ~_SOH. IO ALASKA PETROLEuM iCOMPANY ~: '~ '.i~OATE OF SURVEY MAY .22_3_ .1.9,8.1 . ' ~ Y-7 (SEC ~A T~NR~E) PRUDHOE BAY · COMPUTATION DATE MAY 26~ 1981 JOB NUMBER BOSS-16807 K..E.L_L~B_U_S H__I_N,.._.6.._,.E_L,.E V · : 8 6_. 76 F T o TRUE SUB-SEA TOTAL ~M.EA_S.U.EF_J3~~V_ER.T%CA L_ _._..ME P~T.I_C A L__R E.CJ.A .N G U LAR _.~,:. CQ.OR D_Z NA.T_F. S_____.r&D_-._T_VJ3________V_E_R..T~ L _ DEPTH· , , . DEPTH DEPTH.,.i::.~:/NOR;TH/SOUTH .':.::EAST/WEST: ·:CORRECTION. ~~7.9.1.1~,.,~._ ,'7586..7 6 ............. 7. 5.0_0.'.00 _]3142. ',19~.S.~!~6.88_'--5_8_.~3:2~5-'-0.8_,..i: :...._. :: 8014 7686.76 7600.00 352.01 S 1709.~3 E 327.65 2.57 8117 7786.76 7700.00, 363.52 S 1731.~+~+ E 550o70 3.05 ,~._ 8.2.21 .7886.. ~.76 ........ Z8.0..O_ .~0..0 ..... 3.7.7 ..~ 68 _ S.__.__.1._7_5_5_o _3_1_..J~ 3_3 ~_,_4.9_ 8325 7986,76 7900'00 ':]~.' :: ];395.06 S:: 1781'051~E;i'.~i?iii/~i~;;?!~?;i~i}:;3~-9o2'2: 8638 8286.76 8200.00 z~8.36 S 18~8oZ~8 E 351.~9 8741 8386.76 8300.00 , 460.28 ¢._____8~8_~.5_~ 8486.76 ....... _8~00,00 .~71.13 8948 , 8586.76 ' :'.8500'00: '~,i ::.482.62 9052 8686.76 :.}::i :8600'00{' 9258 8886,76 8800.00 525.9~ 9361 8986,76 8900.00 557.97 9.46.4 .... 9. 0.8.6.._7 E ........ %0_.0_0....,.00 551 · 9567 9186,76 9100,00 '..'.: 56~, 9669 9286,76' :~.: 575, 8 .41 :~ : ~' 372.07 3.38 375.17 3.:10 377.89 2.72 S ~:~:. 2,0 ~ 6 ,:-51:/:!': E~: :..~/: ~:: 3 80 .~ 0 ' : ,i. :..: ..~: 2 · 50 ::... · LSQH.!.O.A.L_A.S.K~_~.E_TRO_LEUM COMPANY Y-7 CSEC 34 TllNRlSE) PRUDHOE BAY ALASKA · INTERPOLATED i : ~ :. :i:::~'DATE OF SURVEY VALUES MAY 22 e COMPUTATION DATE MAY 26~ 1981 JOB NUMBER BOSS-16807 KELLY BUSHING ELEV, = · ~.. :. ,:~:~ :.::~ ::0 P E R A T 0 R- O 0 H N--~A-M-E-C: FOR::EvEN lOO ........... .. ............ PAGE ,. 1981 86,76 FT, TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH ~ ,.,..DEPTH:i~ N'O-R~'F~TS~O'UTH EAST D:IFFERENC~':: CORRECTIO: ...... ,.9.!,75 9~86'76 9~00.00 598.89 S __: . ,,., ~,..,....... ~....~., ...... ,,__.._ 2.09 '::'... ::,:. 9975 9586.76 9500.00 610.08 S 2116,56 E 589,07 2.0~" 10075 9683.92 9597.16 620.95 S 2152.97 E ~91.08 2.01 THE CALCULAT I ON PR OC EDUR, E.S; u~'E-~A--['I"N-~-A"RC'~'~Ni~TP~O~D~ T H E,N E A R E S T 20: FO 0 T;: M'D': ( FR 0 M R A D I U S 0 F 'C U ( REPORT OF SUB-SURFACE DIR-£CT!0NAL SURVEY SOHIO COMPANY Y-PAD WELL ~7 AL 4-81 WELL NArvl E PRUDHOE BAY,~ ALASKA LOCATION D10 Single Shot 5-20-81 JOG NUf'tiBER TY?E SURVEY- DATE · NAME TTTLE SI GNATURE DEPTH 28]_9 ! 007 5 ~'~OM TO 4-22-81 5--14-8! DATES SURVEY 'WAS TAKEN FROM TO GF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a ." locked file and are held in strictest confidence, Additional copies of your. survey report: can .be made. from the or!§inal by any blueprint company, JUN 1 7 198t 0il & Gas Cons. A~chorag~ ....... ' NaSk~ Oil ~ ~a RECORD OF SURVEY ..... ..' ~.~Co~s. Co~m;~, · TRUE. DOG LEG ~ MEAS. DRtFT VERTICAL SUB DRIFT TOTAL COORDINATES C L O 5 U R E 'S .. SEVI~RIT¥ SEC. '-'D~EISTF]'~ ~ ~'~"E'E .... D~ P T-k'f ............. SE'A ............ ~"j~'EC .................................................................. -~'l' ~t ANt E- ............ A-N~ ~ .... DEG/IO0'FT ........... D'[sT A~CE D M DEG~ D M S 0.00-6 .... o 'o' 'ci ......... 5 ~-60 ..... :~"zSC. ?E~ ..... ~" '6;'6b'E ............ 0;0'6 '"~"i .......... O-;"o'b"'W ................. 6-;60--'~s ......... 6-- o o w .. .AS SUrE .D..yE..R.!..~...C_h_L .... .T..O..._ ~._8_t.?...._ ..................................................... - -- 2819 0 0 2819,00 2732,24 N O,OOE 0,00 5 0,00 W O,O0 S 0 0 0 IH 0,000 0,00 2840 I 30 2839,99 2753,23 NT2.00E 0,20 N 0'15 E 0,25 N 36 0 0 E __7,147 .... 0.09 2'~/0 ~ ...... 3 ...... 0 ...... ;~'~'6 i-,-'rf'~; ..... -2-~'~'5";":['8' ..... ~'~i'~-;-6-O-E ........... 0-,-6~ ...... N' ............. i"Z-,-~':~-~ ............ 2-;%-~:-N-'?~;"%2 Z ~. E 2 · ~Zi~ ........... 2'.'Z 2965 4' 45 2964,80 2878,04 N83,00E 1.1'5 N 6,76 E 6.85 N 80 27 26 E. 2,778 6,27 3u.~8 6 30 3027'49 294.0,73 N84.00E 1.83 N 12,90 E 13.03 N 81 53 .55 E 2.778 12,0/~ 3089' 8' 30" ':~087';"97' 3'CiOi';'Z'i ........ N'8'5";'00£ ........... 2,59 .... N ............ 2-0";"8'2--~ ........... 20";'~8'-N"-'~;f'-~-3----6 E 3.?/"~)- ............... 3149 10 15 314.7,16 3060,40' N89.00E 3.11 N 30,58 E 30,74 N 8~. 11 3]. E 2,924' 28.86 3256 12'30 3252.05 3165.29 $87,00E ' 2.74 N 51,67 E 51.75 N 86 57 43 E 2.110 "~"373 'i'5 30 3-'3'65'";57 .... 3278-'81 ..... ~8';~;OOE' ........ 1".01' "N ......... 7'9'-;"9-~"-E ............... 79';93-'"N--g'g--~'b'~--"2-~-~--~~ '~-;~6'~' ...............7 '~-~" 3495 lB 30 3~82.22 3395,fl6 584',00E 2,09 S 115,~5 E 115,t~7 S 88 57. ~0 I~.." 2,/~65 112,37 3588 20 0 3570.02 3~83,26 S8~.00C '~.29 S 1~5,94 E 146.04 S 87 55 ~5."F.'" 1,6]~ 1~2,71 "36~9' 2'3' .... 0 ..... 3'6'2-6"7~ .......:~"5"~"0"~0i' ....... S8~;'O'OF .......... 7'6'~ ....S ....... li'6'8-;'i'Y'"E .............. i'6'~";55--5"'8'7---2-Z~ ..... 2-'E- 4.9-i'8 ............... 3805 23 30 3770,10 3683,34- 582,00E 15,13 S 229.29 E 229.79'5 86 13 21 E 0,~80 3959 23 30 3911.33 382~,57 583,00E 23.15 S 290.17 E 291,09 5 85 26 16 E 0,259 ..... Z;'i?t~' 23' '~3"0 ....... '4-'~."0'~';"~-9 ...... ~'-0'2~-* 73 ....... S-~'-2;'OOF. .........~4~;-3'~ .... S' .......... ~'~5;-~'T-'~ ........ ~76-;'7~ S 8~ '~~ E' '.:' 0.185 ~S3 23 30 ~391,87 A305,11 582,00E 5~,~9 S ~97.18 E ~99,8~ $ 8~ 5' ~3'E" "O,OOO ~976 z,, 0 ~843.~ ~756.3% ....... s~otgP.E_ ......... ~.9Z.35.~...s ....... 9.~.~..,_.Z.e..~. ......... 6..98~8 s 83 x~ 3~ E'...' .o.lzz ..... ~'Z'S'~'-~'~+"'~Y ..... 5i'~'i';~-~ .......... ~6'~5.0~ s79.00E ~0~.56 s 8~7.~5 E ~z4.2.~ s ~2 ss ~ E o.zsz ~-~ z4 0 ~39.9z ~4~.z~ SsO.ooE Z40.0s s zoq~.Tz ~ zo~3.4~, s 8~ 3 z~ E O.Z~7 6260 22 0 6017,64 5930,88 SSO.OOE 175,29 S 12Q3,41 E 1216,11 S 81 42 43 E 0,385 ......... 669 ~' 2 i "' 0 ...... 64 %P e"5 ? .... 6'3'3'2', 8'~ ....S'80e-'OOE .........202'; 79' S .... 1'3~'9";"33-"'E ........ 1'374';'37'"5 225,90 286.87 494,45 692.14 ~18,14 1007,14 1209.34 I367,-22' ].9 MAY 81 RECORD, OF sURVEY TRUE DOG LEG DEPTH ANGLE DEPTH SEA DIREC DISTANCE ANGLE DEG/IOOFT D I S TA~L.~ E .. O.. ~ ........................... ~EG:_ .......... D M $ . . .............. 715~ 16 15 6857~25 6770,~',9 578,OOE 230,93 S 150z~,12 E 1521,74 S 81 16 16 E 1,02.9 7402 15 30 7095.79 7009,,03 S79..00E - 244.46 S' 1570.59 E 1589.51 S 81 9 JO E 0.304 1582.22 77 ~ 7 ~ ~' 30" ~Z~ 00". ~ ~ ...... ~'31-~-.'9 ~ ....... S74','6b~ .......... Z 6 Z ;8-6 S" '1~4'7 ,'2 ~' E ...... i e~. 10 "S' ~'0 '-~-6 .... ~----~ .......... b-;-~i~ ........ 7821 13 0 7501.97 7415.2~ 574.00E 269.43 S ~670.17 E 1691,76 S 80 50 9 E 0,481 1684,88 7916 i2 30 759~.63 7507.87 S69.00E 276.08 S 1690.05 E X712.~5 S 80 ~3 X9 ~ 0,581 1705.79 SI01 i3 30 777~.89 7688,13 S64.00E 292.51 S I728.26 E 1752,8~ S 80 23 ~6 ~ 0,572 17~6,88 8218 16 15 7887.96 7801,20 S59.00E 306.8/~ S 175~.65 E 1781,27 S 80' ~ ~0 E 2,~7~ 1775.99 83~7 1~ 0 8030,19 7943,~ SS~,OOE ~31,73 S 1791,35 E 1821,80 S 79 ~0 ~0 E 0,572 1817,71 ~30' 17' 0 8090.23 8~f47 ..... S~8,00[ "3~3"91"S""1806'[02 ..... [ .......... 18'3'8','-~'~'-'S--'~ .... ['3---~--E'--~ ...... 2-['f(~l- 8534 15 15 81g0.14 8103,3~ 553,00E 362.28 S 1828,30 E 1863,85 S 78 47 ~0 E 1,715 1861.07 8616 14 45 8269,3~ 8182,58 S59,00E 374,1~ S 18~5,89 E 1883,~2 S 78 ~2 ~0 [ 0,773 1881,05 ~7~6 16 0 8433,~4 83~6~68 S69,00E 393,i3 S 1885,96 ~ 1926,50 S 78 13 ~0 [ 1,137 9142 15 15 8776.28 8689.52 S59.00E ~35,11 S 1972.0~ E 2019,~7 S 77 ~ 26 g 0,287 2018,37 ~ ~ ,..:..- ., ,' . . BOT'I'Og HOLE CLOSURE 222I,~9 FEET AT S 75 39 58 E ~":~:' .."7' .................................................................................................................................................. . ..... ': NEASURED DEPTH' AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB ,SEA DEPTH. 19 NAY 81 TRUE MEASURED VERTICAL SUB MD~TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION. "-TOTAL COORDINATES 187 187. 100 0 0 0.00 S 0.00 W 287 287. 200 0 0 0.00 S 0.00 W .... 38'7 ........... :~iS'i'; ............. ~'00 ........... 0 ................... 0 ................. O.Ob- $' .............. t+87 487, 400 0 0 0,00 S 0,00 587 587, 500 0 0 0.00 $ 0.00 687 687. 600 0 0 ' ....... 0','0~)'-"~ ................ ~;00 W 787 787. 700 0 0 0.00 S 0,00 W 88.7 ............. ~..~ 77. ............. 300 .......... 0 ............ o o. oo s o. oo w 987 987, 900 0 0 0,00 S 0,00 W 1087 1087, 1000 0 0 0,00 $ 0,00 W 1187 1i87, 1100 0 0 0.00 S OeO0 W' 1287 1287, 1200 0 0 0.00 S 0.00 1387 1387. 1300 0 0 0.00 $ 0,00 1487 1487. lz+O0 0 0 0.00 $ 0,00 1687 1687, 1600 0 0 0.00 S 0,00 1787 1787. 1700 0 0 0.00 S 0.00 1887 1987 2O87 228'1 2387 2587 2687 '~."60 0.00 0.00 1987. 1900 0 0 0.00 S W 2087, 2000 0 0 0,00 S W ~i'ST" ........ 21b~ ......... 0 .............................................. o O-;'-~'b"'~ O,OO.. W 2287, 2200 0 0 0,00 S 0,09. W .2387. 2300 0 0 0.00 S 0,00 W ....................24B7~ ............................................................................................................. 2400 0 0 O-'~O0 S 0,00 W 2587, 2500 0 0 0,00 S 0,00 W 2687, 2600 0 0 0,00 S 0,00 W 2787 2787, 2700 0 0 0,00 $ 2887 2887, .2800 0 0 ' 0,58. N 2987 2987, 2900 0 0 1.36 'N 30.~8 3087. 3000 3189 3187, 3100 3292 3287, 3.200 ~ ~'9-5 ........................... 3'3'8-"/, ......... 5300 ............... 3500 3~87 . ~00 13 5 3606 3587, 3500 19 6 '8,69.. E ..':'.' ·" 2.58 N 20,6t~ E 3,1~ N 37,99 E 2.30 N 59,65 E O%-. -57-N BS'q-5~E. ;,i.!i,i. '" '~' 2,25 $ 501410 WcuL Y- 7 SINGLE SHOT SUN'VEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, 1'9, MAy 81 TRUE DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 3714 3687, 3600 27 3823 3787, 3700 36 ........ 3932 ............. 3'8~"~'~-':'"3~0 .... 45 .... ~0~1 3987 · 3900 54 4150 4087* 4000' 63 8 10,48 S 193,5'2 E 9 16,13 .% 236,40 E 9 27.24 S 322,61 £ ,'=" 9 33,02 S 365,69 E 4259 .................. '~-i ~'V;": ......... 4'i'/30 ........7'2 ........................................................ 9 'J~-,'06-"~ .............. ~368 4287~ 4200 81 9 45,11 S 451,77 E 4477 4387, 4300 90 9 51,15 $ 494,81 E 4586 44'8'7' ..... 4400 ....... 99' ............................ 9 : ............. 5'7" 37- S 4696 4587~ 4500 109 10 63,98 S 4805 4687' 4600 118 9 70,93 S 621+,95 5024 4887, 4800 137 10 85,96 $ 712,47 E 5133 4987, 4900 146 9 94,00 $ 756~59 E .... .'5~ 7 ................ i"B 08'7-'i ....... ~'6-6-0- ..... l ~'~ ................................. i-6 ............................... i'b~';"4-?-S- ........ 5353 5187, 5100 166 10 111.18 S 846,57 E 54.63 5287, 5200 176 10 119,68 S ...... 5'573 ........... 5387. ...... 5'30-6 ..... 186 ................................................... 10 ~'2-?,.95 S .... 936,16 E 56.83 5487, 5400 196 10 135.94 S 980,35 E 5792 5587, 5500 205 9 143,69 S 1024,15 E 590i ........ 568'~.'. ...... .~6~0 ...... 2i~ ............................................. 9 ~"~.-i-~"7"-~ .......... i067,16'.~.~, · 6010 5787, 5700 223 9 158,70 S 1109,3~ E" ... 6119 5887, 58.00 232 9 165,99 S 1150,627 ~'...":i. ,. 622'7 5°,87, 5900 240 8 173,12 S 6334 6087, 6000 247 7 180,09 S 6~42 6187, 6100 255 8 187,03 S .......... ' ................................ 6550 &-~-8-?; ..... ~":'"6 ~'O'O ........ ~'6-~ .................................... 8- ..... : .................. 6657 6387, 6300 270 7 200,59 S 6764 6487, 6400 277 7 207,25 ...... 687'0' ............. 6'5'8 7'~ ....... 65~0 .... 2~'~ ............................. ~ ..................... '""' .......... 2 '1':~-~"~'~'-'-'~- .... 1~.19 · t+8 E 6976 6687, 6,500 289 6 220,26 5 1452,.58 7080 6787, 6700 293 4 226.57 S 1483,55 E ...... 7 i~'5 ................ 6~'8'?; .......... '6800 ...... ~'9ft ......................... :'5 .............................. ,:r'.J-2T7 O- -:; ....... I51-2~-5~E:~?.,. · :. ,.. 6987, 6900 302 4 238,50 5 72~9 7393 7087, 7000 306 4 243,98 S 1568,13'. E' 119 1230,61. E 12.69,99 E 1308 ~ 6'9 .,,El:i: 13/+6 · 90!:i,'"E ':::.':'::: ,,- :..: , ,, 13 84,2 3 ' SOHIO WELL Y- 7 .~ SINGLE SHOT SURVE.Y :':'~ MAY · ,, · ... ,',: ..., .~,~,~ P1EAsuRED DEPTH AND OTHER DATA FOR EVERy EVEN 100 FEET OF sUB SEA DEPTH, TRUE DEPTH ? DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES . !.;' 7~96 7187, '7100 309 3 . 249.~9 $ 1594,79 7600 7287, 7200 313 4 255,49 S 1620,09 ':. ' ........... ."?'~6'3' ........... : .......... ~--~ ~'f;'~ ...... ~-~-6~ ........ ~"~-& ........................................................... 7805 7487,. 7400 ~8 2 268.44 S 1666,70..' E · 7908 7587, 7500 ~21 ................. $ b~'b .......................... 7%-S 7-; ....... ~"~'bO ......... 3-~"~- .......................... s~s 77~7. 7700 3z6 ....... 8.2.1.7~ .....................7.8_8_!.~.~ .......... 7_~99 ....... ~.~9.. 8321 . 7987,~ 7900 3~4 4. 8426 8087, ' 8000 339 5 343,13 S 8530 8187~ 8100 34~ 8634 8287, 8200 347 4 8737 8387, 8300 350 3 388.08 S 1873,68 8841 8487, 8400 35~ 9049 8687, 8600 S62 4 '422,89 S 1950,67 'E 9153 8787, 8700 366 ...........................................................9256 8"~' ~' 7 '~ ....... 8 ~-0-6 ........... -3-~ 9 .......................... 9360 8987. 8900 973 4 45~,0! 9463 9087, 9000 376 3 ~77.28 ................. ~'~-~ ................... 9~ ............................................................................................................... 87, 9100 379 ~' ~'~'~-~' 9668 9287, 9200 ~81 2 502.89 9771 '9387', 9300 384 ~ 515,22 9873 9487, 9400 386 2 527.~2 S 2019,48 2040,81 E ,. 2100.~9 '~118,~6 'E 9976 9587, 9500 389 3 538,90 S 2135,97 E WELL Y- 7 SINGLE SHOT SURVEY 'MAY r.,~,POLATED VALU.,.:S '-~'-(JR ..... EVEN .... i0-00-FEE'[ ..... OF'"HEA-[(JR-ED-'D'EPTi~. TRUE DEPTH 1000 2000 2000, 1913. 0.00 S 0,00 W 3000 2999, 2912. 1.51 N 9.93 E '4000 ....l ............. 39"~'~'~ ......... 38 62 ~ '-] ............... ~ 5,17 '-~' ...... ." ~'06' *'~O"-E- .................................... , 5000 6000 7000 8000 9000 10000 DEPTH SEA TOTAL COORDINATES .......... i ib'~'O"; ................................................. ' ............ "' ' "-:'::~:" ................ .......... 913. (~o 0" O0 w 4865. z+778. 8~.25 S 702,91 E 5777. 5690, 158.02 S 1105.~2 E 6710,, ..... 6623. 2'2i'.'7~"~ ..... 7676. 7589. 282.98 S 1707.21 E 8639. 8552. t+16.79 S 1939,08 E 9~1'0~, 95"2'~ ~- ............ 541 o-65- S 2 ~4'O ,'~" '~ ................ -'-- 800 VERTICAL_ PROJECTION SOHI~ ~,L ASKA PETROLEUM WELL Y - 7 RADIUS OF CURVATURE I'¢..AGNETiC $)NGLE SHOT SURVEY 5OALE 1": lOC)O' MAY 19~ 1981 2400 '-'- 2600 32,OO 36O0 4400 48OO DEPTHS SHOWN TVD 5200 5600 .6000 6400 68OO 72 O0 7600 ~ 8OOO --~- 8400 . ---~.- 8800 -~ 9200 TVD = ~84' ! TM D = 13075 HORiZOnTAL VIEW SOHIO ALASKA PETROLE.;JM WELL Y - 7 R/~DIUS OF, CURVATURE MAGNETIC SINGLE SHOT SURVEY SCALE 1"= !000' ?,,~ AY I9 ~ 'rVD = 9684 TMD = !0075 Check Form for timely compliance with our regulations. Reports and Materials to be received by:. ~' .... /~ Date Completion Report Wel 1 History samples Required Yes Mud Log Yes ' I Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Logs Run Digitized Log Data Yes / Date Received Remarks SOHIO ALASKA PETROLEUM COMPANY 3111 °'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 ARCO TO: EXXON MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 6/10/81 .# 852 REFERENCE: SOHIO MAGNETIC LIS TAPES The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office'-- 'U~C~C-11 Magnetic .LIS Tape & Listing L/~'*F-4 " " " " 8 ,, ,, ,, ,, #61646 5/16/81 #1 (Sch) ~61612 5/2/81 #5 " #61653 5/21/81 #7 " #61611 4/29/81 #4 " #61645 5/15/81 #3 " #61644 5/14/81 #3 " #61656 5/14/81 #2 " Tract Well ~ Il II i' Il II (11) 33-11-12 Replacement Tape [ Magnetic LIS Tape & Listing #61627 5/8/81 #3 " #61557 4/17/81 #4 (Sch) NLL9200-10350 5/13/81 (Dresser) RECEIVED DATE Anc~orago Carol Krieter Development Geology Well Records HQ 4-5 SOHIO ALASKA PETROLEUM COMPANY June 8, 1981 3111 'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well Y-7 (22-34-11-13) Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of May, 1981. RHR: ja Enclosures cc: Well File ~17 Yours very truly, District Drilling Engineer RECEIVED JUN - 9 1981 ~aska 0ii & Gas Cons. CoJr~mJssJorl Anchorage ALASK ^[,~, STATE OF ALASKA ._ AND GAS CONSERVATION C(~"' JlISSION REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 81-18 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20560 4. Location of Well at surface 1341' SNL, 118' EWL, Sec. 34, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE = 86.76 ' AMSLI ADL 28287 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. ¥-7 (22-34-11-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of. May ,19 81 '~12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at month end: 9906' PBTD Footage drilled: 2921 ' Well Y-7 was suspended May 19, 1981. 13. Casing or liner run and quantities of cement, results of pressur9 tests See well history attached. 14. Coring resume and brief description None 15, Logs run and depth where run DIL/SP/GR @ 9175' DIL/BHCS/GR, FDc/CNL/sP/GR, HDT @ 10076' CBL/VDL/CCL/GR @ 9896' Gyroscopic survey @ 9896' KE~E Y t' 6. DST data, perforating data, shows of H2S, miscellaneous data None JUN - 9 198] ~aska 0ii & Gas Cons. Co~nrnlssion Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,GNED ,, ~-'~, , , %~ T,TLEDistrict Drilling EngineerDATE ~-~-- ~\ NOTE--Report on this form is required for each~alendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th ~ the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1:80 Well Y-7 (22-34-11-13) WEI,L HISTORY Spudded well at 1200 hours, April 22, 1981. Drilled 17 1/2" hole to 2700'. Ran 69 jts. 13 3/8" 72# L-80 Buttress casing to 2685'. Cemented with 3720 cu. ft. Permafrost II cement. Installed and tested BOPE. Cleaned out to 2644', tested casing to 3000 psi, okay. Drilled out to 2714', ran leak-off test to 0.61 psi/ft, gradient. Directionally drilled 12 1/4" hole to 9202'. Ran 239 jts. 9 5/8" 47% L-80. Buttress casing to 9187'. Cemented in two stages: First stage with 1271 cu. ft. Class G cement; second stage through D.V. packer at 2600' with 130 cu. ft. Permafrost C cement preceded by Arctic Pack. Cleaned out to 9070', tested casing to 3000 psi, okay. DirectiOnally drilled 8 1/2" hole to 10075'. Ran open hole logs. Ran 35 jts. 7" 29% L-80 Buttress liner to 10063'. Cemented with 425 cu. ft. Class G cement with 18% salt. Cleaned out to 9906', tested casing to 3000 psi, okay. Changed well over to NaC1. Install~d.~"tubing hanger with one joint 7" tubing. Installed ar~ tested 6" tree. Top 200' of hole displaced to diesel. Released rig at 0001 hours, May 19, 1981. Ran CBL and gyroscopic survey, secured and tested wellhead May 22, 1981. M(I~: ja RECEIVED JUN - 9 1,98] 0ii & Gas Cons. Commission Anchorage SOHIO ALASKA PETROLEUM COMPANY 3111 -c" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 May 19, 1981 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well Y-7 (22-34-11-13) Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our proposal to suspend the well. RHR:ja Enclosures cc: Well File 917 Yours very truly, District Drilling Engineer 4nCl~ora~ Co~i~;~ £ STATE OF ALASKA ~'" ALASKA( ,L AND GAS CONSERVATION C ,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612: Anchorage; Alaska 4. Location of Well At surface: 99502 1341' SNL, 118' 5WL, Sec. 34, TllN, R13E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 86.76' AMSL 6, Lease Designation and Serial No. ADL 28287 7. Permit No. 81-18 8. APl Number 50- 029-20560 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number Y-7 (.22-34-11-13) 1 1. Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice,,Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] ~ Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other Suspend [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other ~$ ~J~Jl~ ~ [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Well Y-7 (22-34-11-13) was suspended May 19, 1981, as follows: A 7" liner was run from 8683' to 10063' MD, cemented with 425 cu.ft. Class G with 18% _ salt, and tested to 3000 psi. Well was displaced with 9.6 ppg. NaC1 with top 200' of hole displaced to diesel. Installed tubing hanger with one joint 7" tubing. Installed and tested 6" tree. Released rig May 19, 1981. RECEIVED MAY 2 1 1981 Alaska 0ti & Oas Cons. CommiSsion Anchorage 14. I hereby ~the best of my knowledge. Signed ' TitleDiStrict Drilling Engineer The space below for Commission use R. H. Reile~ Conditions of Approval, if any: Approved by Form 10403 Rev. 7-1-80 ORIGINAl. SIGNED BY LONNIE C. SMITH Approved" ,~,opy Returned By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 May 8, 1981 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well Y-7 (22-34-11-13) EncloSed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of April, 1981. Yours very truly, RHR:ja Enclosures cc: Well File #17 % District Drilling Engineer I £C 1v£o Alasl~ O# & ~as Cons. ~Chorago C~rni~.loe STATE OF ALASKA ALASK( , _ANDGASCONSERVATION~' MISSION MONTHLY REPOR'I' OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 81-18 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of Well at surface 1341' SNL, 118' EWL, Sec. 34, TllN, R13E, ~ (corrected) 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. KBE = 86.76' AMSLI ADL 28287 8. APl Number 50- 029-20560 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. Y-7 (22-34-11-13) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of April ,19 81 '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at month-end: 7154 ' Footage drilled: 7154 ' Spudded well at 1200 hrs., 4/22/81 13. Casing or liner run and quantities of cement, results of pressure tests Ran 69 jts. 13 3/8" 72# L-80 Buttress casing to 2685'. Cemented with 3720 cu.ft, Permafrost II cement. Tested casing at 2644' to 3000 psi, okay. Performed leak-off test at 2714' to 0.61 psi/ft, gradient. 14. Coring resume and brief description None 15. Logs run and depth where run None 1 6. DST data, perforating data, shows of H2S, miscellaneous data RECEIVED MAY 1 2 1981 A~ 0ii & Gas Cons. CommJsB~Jon 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ':"SIGNED~ TITkEDistrict Drilling EngineeruATE ~-%%- ~% NOTE--Report on this form is required each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton~ Chairman Thru: Lonnie C. Smith / Commissioner ~'" Bobby Foster~..3 Petroleum Inspector April 28, 1981 Witness B.O.P.E. Test on SOHIO'S Y-7, Sec. 34, TllN, R13E, UM Permit #81-18. F.r. iday April 24, !98_1: After witnessing the meter proving and 0~"'~'quality test at~iA!yeska Pump station %.1 I went to SOHIO'S Y-7 to witness the upcoming B.O'~P.E. test. Saturday April. 25, 1981: The lB .O , P .E . test began at 11~30 am and Was COmpleted at. l~30~::.pm, as the attached B.O.P.E. inspection report shows there were no failures. ~n :s~~f~, I witnessed the B.O.P.E. test on SOHIO'S Y-7. BF..mm STATE OF ALASKA ALASKA OIL & GAS O0NSERVATION CCMM%qSION B .O. P .E. Inspection Report I ~rator _ ~0 .~ ~P]'~- 0 Well_ \/.._.~ Dril linq Contractor ~/~ ~ ~'~J~. ~/~. Rig Date ~'~~-- ~ I Representative ~. Permit ~Casing Repre~at ive Location, C-enera~ 0 ~ Wel 1 Sign_ ~ ~ Ce, neral Housekeeping _~ Reserve pit ~_~_ BOPE Stack Annular Preventer, / Test Pressure , .5 oo ACCU~UIA~R SYSTEM Full Charge Pressure ~2~ psig Pressure After Closure / 7PO psig Pump incr. clos. pres. 200 psig -- min/$sec. Full Charge Pressure Attained: ~ min~O sec. N2~7~., _ff_.~o~:?~.,~! 1~,;1~ psig Controls: Master Cji3 Remote O~,_~ B_linds switch cover ~d-~ _ I Kelly and Floor Safety Valves -- Upper Kelly / Test Pressure ~ O Pipe Rams .... Blind Rams Choke Line Valves. Lower Kelly / Bail 'Typ~ / Inside BOP / Test Pres sure_~D~'m~ Test Pressure Test Pressure H.C.R. Valve ........ ~ ..... Kil 1 Line Valves, ] -. Check Valve Choke Manifold~est Pressure No. Valves //_'. No. flanges ~O ~djustable Chokes Hydrauically operated choke / Test Results: Failures 0 Test Time' ~ _ hrs.., Repair or Replacement of failed equipment to be made within. ~- days and Inspector/Ccmmission office notified. Remarks: Distribution orig. - AO&CCC cc - Operator cc - Supervisor Inspector February 20, 1981 Mr. R. H. Reiley District Drilling Engineer Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Rex P~dhoe Bay Unit Y-7 Sohio Alaska Petroleum Company Permit No. 81-18 Sur. Loc.: 118'EWL, 1343'SNL, Sec 34, TllN, R13E, UPM. Bottomhole Loc.~ 2584'E~, 1673'SNL, Sec. 34, T11N, R13E, UPM. Dear Mr. P~iley ~ Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional su~y is require4, if available, a tab containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter survey s. ~ny rivers in Alaska and their drainage systems have been classified as important for We spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter: 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. R. H. Reiley P~adhoe Bay Unit Y-7 -2- February 20, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would, appreciate your notifying this office within 48 hours after the well is spudded. We would also' like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe .is drilled. In ~e event of suspension or abandonment, please give this office adequate advance notification so that we may' have a witness present. Very truly yours, Hoyl H, Hamilton Chairman of E¥ OR~ O~ T~ CO~:~N ~ Alaska Oil & ~s Conser~tion C~:iss-~on Enclosure c¢~ Department of Pish & Game, Habitat Section w/o eno1. Depar~nt of Environmental Conservation w/o/eno1. Department of Labor~ supervisor, Labor Law Compliance Division w/o eric1. SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 February 10, 1981 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99510 Attn: Mr. H. H. Hamilton Gentlemen: WELL Y-7 (22-34-11-13) In accordance with the Prudhoe Bay Field Rules and Sohio's policy for drilling the first well on a new pad and/or new area, a 20" Hydril and diverter system~was used when drilling the surface hole on Y-1 (31-27-11- 13). We did not experience any surface gas during the drilling of the 17 1/2" hole on Well Y-1 and belieVe it unnecessary to continue the use of the 20" Hydril and diverter system on Pad Y. We, therefore, request that Rule 4 (b) of Conservation Order No. 145 be waived for the remainder of Y-Pad wells. Yours very truly, SOHIO ALASKA PETROLEUM District Drilling Engineer CC: Y-Pad/Well File K. W. Kolthoff RECEIVED FEB 1 3 Alaska Oil & Gas Cons, Commission Anchorage SOHIO ALASKA PETROLEUM COMPANY February 6, 1981 3111 'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Con~ission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well Y-7 (22-34-11-13) Enclosed are the following documents, in triplicate, along with our check for $100.00 to cover the permit filing fee. 1. Application for Permit to Drill, 2. Proposed Drilling Program Outline, 3. Surveyor's plat showing well location, 4. Blowout Prevention Equipment diagram, 5. Directional Plan. RHR:ja Enclosures cc: Well File ~17 Yours very truly, DistrictDrilling Engineer Of.. STATE OF ALASKA ~i ALASKA AND GAS CONSERVATION CON( .,ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL[] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of well at surface 9. Unit or lease name 118' EWL, 1343' SNL, Sec. 34, TllN, R13E, UPM Prudhoe Bay Unit At top of proposed producing interval 10. Well number 2319' EWL, 1638' SNL, Sec. 34, TllN, R13E, UPM Y-7 (22-34-11-13) At total depth 1 1. Field and pool 2584' EWL, 1673' SNL, Sec. 34, TllN, R13E, UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Prudhoe Oil Pool Est. KBE = 86' AMSLI ADL 28287 12. Bond information (see ~0 AAC 25.025) Type Blanket Surety and/or number SAFECO INS. 2975387 Amount $200,000.00 13. Distance and direction from nearest town 14, Distance to nearest property or lease line 15. Distance to nearest drilling or completed NW of Dead_horse 10 miles ADL 47471 3937feet well Y-6 NE 110 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. ApProximate spud date 10090'MD 9640'TVD feet 2560 April 5, 1981 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~(3 psig@. Surface KICK OFF POINT 2800 feet. MAXIMUM HOLE ANGLE 21' 2°I (see 20 AAC 25.035 (c) (2) 4390 psig@ 8R(~ft. IF~I~(TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 36" 20x30 Insulat,.~d Cond~ctor 110 surface ] ] O '~. ] ] n, 8 ~3_ ~ya.~_ cop. crete 17 1/~ 13 3/[ 729 L-80 Butt. 2680' surface 2680"I 2680' 3720 cu.ft. Permafros 12 1/4 9 5/8 47# L-80 Butt. 9140' surface 9140'1 8750' 1260 cu.ft. Class G: i I 130 .cu. ft. Permafro. s 8 '1/; 7" 299 L-80 Butt. 1450' 8640' ~, 8280' 10090'11 9640' 270 cu.ft. Class G 22. Describe proposed program: W/18% salt See attached proposed dr illing program outline. · Ala~,~a Oil & 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~-~:~~ ~' TITLE District Drillinq :Engi~e~[~ATE ~--' The space below- ' ~for Commission use CONDITIONS OF APPROVAL Samples required I Mud log required Directional Survey required I APl number l-lYES ~NO/ []YES '~LNO ~'YES []NOI 50- 0 Approval date ..Permit number ~'/ '- / ~ 132/20/81_ · '1 SEE COVER LETTER FOR OTHER REQUIREMENTS ., "~. / _ ,COMMISSIONER DATE ~'~1-,~,.,-,.-.. Om I (301 , APPROVED BY _ _ by order of the Commission ...... .z ..v t II tC Form 10-401 Submit in triplicate Rev. 7-1-80 PROPOSED DRILLING AND CCb~ION PROGRAM WELL Y-7 (22-34-11-13) Dry bucket 36" hole to 80' below ground level and cement 20" x 30" insulated conductor to surface using 8 cu.yds, concrete. Drill 17 1/2" hole to 2700' and cement 13 3/8" 729 L-80 Buttress casing to surface using 3720 cu. ft. Permafrost II cement. Blowout Preventer Program consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer from 13 3/8" casing point to T.D. Maximum possible bottom- hole pressure is 4390 psi at 8800' TVDss (based on original reservoir pressure). Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVD. Directionally drill 12 1/4" hole to 8753'+ TVD. Run 9 5/8" 475 L-80 Buttress casing to 8748' ~TVD and-cement first stage with1260 cu. ft. cement. Cement second stage through D.V. packer collar at 2600'+ with 130 cu.ft. PermafrostC cement. 9 5/8" casing will be hung at surface, the 9 5/8" x 13 3/8''~ annulus will be Arctic Packed. Drill 8 1/2" hole to T.D. at 9638'+ TVD. Cement 7" liner to 500' inside 9 5/8" casing shoe with ~270 cu. ft. Class G cement with 18% salt. Run 4 1/2" 12.6~ A/B Mod Butt.tubing with 6 gas-lift mandrels and a production packer assembly at 8235' + TVD. A subsurface safety valve with dual control lines will be placed at 2075'. Displace tubing to diesel. Install and test Xmas tree. Suspend well for preforating subsequent to rig release. Details of proposed perforations to be submitted on Sundry Notice to follow. 1/27/81 3470' TVD 3800' TVD Y-5 3489' TVD 7° Lead 4000' TVD B.O.P. ~~TACK CONFIGURATION 13 5,?1~ 5000 PSI WP III i I DRILLING ANNULAR PREVENTER PIPE RAMS BLIND RAMS KILL LINE CHECK GATE GATE DRILLING SPOOL PIPE RAMS 4" CHOKE LINE 6ATE HYDR. ASST. GATE 04 O~ O2 O~ O~ O2 03 04 4O ~0 20 30 40 $0 2.0 ¥- 6 (Actual) Proposed i 3383' ~'~ lPropo~ed! 22 30 40 -._ ~_27 3zs~' ¥-2 (Actual) (22- $4 -//-/$.) SUMP ay-7' o =_, (Proposed) _.i~'''Y-I LAT. = 70° 6'05.61" LONG.: 148°49, 2 I. 96" 3 3 ~so' x: s45,575 3 4 Y- 12 Y'- 5,949,065 (ProPosed) 2560' [ 317 O' -~ -----i -~FY' ~ -5 PORTION OF III N, R13E, UM SCALE I"= I/2 MILE T. IIN. J T. ION. CONDUCTOR HOLES CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered to practice land surveying in the State of Alaska and that this plat represents a location survey of the wellpad shown and the wells thereon. This survey was made by me or under my supervision and all dimensions and other details ore correct. Bottom hole locations are furnished by others. Revised Proposed BHL Add Proposed BHLY-7 Add Proposed BHL Y-12 2 / 2 /81 PJR /28/81 PJR lO/9/80 PJR' Date Surveyor Add Proposed BHL Yo 11 9/26/'80 PJR All Bottom Holes ore 8800' sub sea. Revised BHL Y- 1,2,5 66 from Proposed toActuel. 6/25/80LAB NOTE: Plot doted Aug. 30, 1979 changed to 0ct. 2,1979. BHL 1,5 ~ 6 changed. AS- STAKED PAD "Y" Located in NE I/4 R, NW ¥4 PROTRACTED SEC. 3:3 ~ Surveyed for SOHIO PETROLEUM CO. Surveyed by ~:':'~:~iF. M. LINDSEY 8 ASSOC. LAND ~ HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-081 Anchorage Alaska ,; 7 o rrl , CHECK LIST FOR NEW %~LL PERMITS Item (1) Fee (2) Loc. ove Da te Ye s ~-~,/,, ~1. Is the permit fee attached .......................................... 2 Is well to be located in a defined pool . 3. Is a registered survey plat attached ................................ · 4. Is well located proper distance frcm property line ................. ~___~ ~5. Is well located proper distance frcm other wells .... 6. Is sufficient undedicated ................................... acreage available in this .~.~1..,, .......... f/~/'~ 7 Is well to be deviated 8. Is operator the only affected party ................................. 9. Can permit be approved before ten-day wait .......................... L-~ '// 10. Does operator have a bond in force .................................. ~11. Is a conservation order needed ...................................... , ..... / (3) Admin. ~ / (4) Casg 12. Is administrative approval needed ................................... 13. Is conductor string ovided ....................................... 14. Is enough cement used to circulate on conductor and surface ........ 15. Will cement tie in surface and intermediate or production strings ~16. Will cement cover all known productive horizons .................... 17. Will surface casing protect fresh water zones .................... No 18. Will all casing give adequate safety in collapse, tension and burst..~~ 19. Does BOPE have sufficient pressure rating- Test to ~O psig .~ Approval Rec ch%mended: Additional Requirements: Lease&Well NO. ~'7'' ~ ~/,~ Rerr~rks Geology: Engineering: HWK ~ LCS~'_~BEW ~~ / rev: 03/05/80 Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. TAPE YERZF~CATZON LZSTZNG 'bVP 009,H03 VERIFICATION LISTING ** REEL HEADER ** SERVICE NAME~ ISERVIC DATE 181/05/29 ORIGIN : REEL NAME IREEb CONTINUATION # PREVXOUS REEL. COMMENTS IREEb COMMENTS ** TAPE HEADER ** 8ERVI~E NAME ISERVIC DATE 81/05/29 ORIGIN 16165 TAPE. NAME t CONTINUATION ~ 101 PREVIOUS TAPE l COMMENTS ITAPE COMMENTS pAGE . ? · ** FILE HEADER ** FILE. NAME ISERVIC,OO1 SERVICE NAME I VERSION # I: DATE I MAXIMUM LENGTH I 1024 PREVIOUS FILE I MNEM CONTENTS WN I (22 34-1i-13) FN I PRUDHOE'BAY RANGI 13 E TOWNI 1~ N SECTI 34 COUNI NORTH SLOPE STATI ALASKA CTRYI NORTH SLOPE MNEM CONTENTS PRESi NEDIT4F ooo-ooo o~s o~ ooo Ooo Oo, o~.~ ,, .~co.~ ~EO~ , ** RECORD TYPE 047 bVP OO9,HO~ VE~IF~CA?ION L~STING 10,0 VISC: =. 4~,00 PH = ,5 CASING bOGGER = !3,:38 IN, ~ 2685 T'; BIT SIZE = 12,25 FLUID IN THE HO~E = GE~/PObYMER DENS = 9,80 VISC =~ 4i,00 PH = 8,5 FLUID 'bOSS = 6 5 ~G · RH ~ ~EAS TEMP, = 3,~2 ~ 75 F RHC " " = 4,]2 ~ 60 F R~ ~ BHT = $- ~48 F P 0 R 0 S l T Y ~ A T R l X = S A N D S T 0 N E : Dlb RUN ~ 2~ bOGGED. 14-MAY-81 B l T S I ZE · 8,5 FbUID IN THE H0bE ~ GZb/PObYMER DENS a PAGE bVP 00g. N03 VERIFICA?ION bISTING PAGE 3 rbuIP bOSS = 5 0 Mb RMF " " = !,74 @ 62 F AMC " " = 2.29 , 62 r RM 9 BHT = 0.70 ~ 192 r POROSITY MATRIX ** DATA FORMAT RECORD ** ENTRY BbOCKS TYPE SIZE REPR CODE ENTRY 4 ~ 66 73 6~ 9 4 65 , lin 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT APl API APl.. API FZbE SIZE pROCESS SAMPbE REPR ID ORDER # bOG TYPE CbASS MOD NO. bEV~b _ CODE DEPT FT 0 ~ 0 0 ~0 SFbU 003 OH~M 0 v 0 0 0 a IbD 003 OHM~ 0 SP 003 MV 0 GR 004 GAPI 0 CAbI NUC IN 0 DT IS9 US/F 0 RHOB NU~ G/C3 0 NPHI NU PU 0 DRHO NUC G/C3 0 GR NUC GAPI 0 NRAT NUC 0 NCNb NUC 0 rCNb aUC 0 1 31 28 3 52 32 68 2 44 0 31 32 34 93 0 0 4 I DATA DEPT SP RHOB NRAT 100 8 00 srbu 2 50,t NPH I 2,-732 NCNb DEPT SP .10~00,000 SFLU 13,781 GR '999,250 '999.250. 2 27.051 R 0 44~.000 rCNb ,922 IbM 8~.!25 CAbI -999 916- 5:00 ,D ,75B'727 DT ,430 6~.750 LVP 009,H03 VERIFICATION LISTING RHOB 2 641 DEPT 9900,000 SP -el.O00 RHOB 2.348 NRAT 2.199 DEPT 9800.000 SP =86.312 RHOB 2.305 NRAT 2.275 DEPT 9700.00~ SP -80,06 RHOB 2.250 NRAT 2,498 DEPT 9~00,000 SP 73.813 NRAT 1. DBPT 9500,000 RHOB 2. NRAT 2, O0 DEPT 9400.000 SP -70.563 RHOB 2.2~ NRAT 2.2 DEPT 9300.000 RHOB , NRAT 2,258 DEPT 9~00.000 RHOB NRAT 4.906 SP ,141 RHOB 1,790 NRAT 4.852 DEPT 9~00.000 Sp 17.~59 RHOB 1, 97 NRAT 4.414 " oo 09 °° NPH! NCNb SFLU GR NPHZ NCNb SFLU GR NPHZ NCNb srbu GR NPH! NCNb G~ NCN~ SFLU GR NPH! NCNb SFLU GR NPH! NCNb SFLU GR NPH! NCNb 8FLU GR NPHI NCNb SFLU OR NPH! NCNb srbu GR NPHZ NCNb SFLU GR 14 3474 5 26 18 3520 .. 22'60 3054.00 t2 45O4 8 29 22 3456 35 18 3606 22 51 70 t :oog 2.111 98.063 57,666 1242.000 2 112 1251 3 66 014 DRHO :000 FCNb .859 Ib.~ ,969 CALI .066 DRHO .000 FCNL 438 CALl 287 DRHO .000 rCNb .375 .828 ,793 ,000 .'141 IbM ,078 CALI .607 DRHO ,000 FCNL 617 IbM 375 CALI' 896 DRHO .ooo rcNb ,312 IbM ,938 CAL~ ,627 DRHO ,000 FCNL~ O0O3O2 GR 2'637 018 GR 1680,000 8,217 ,180 0,042 GR 1508,O00 IbM i 950 ILD CALI ~:180 DT DRHO '006 GR FCNb 1268.000 IbM 85 CALi 3.613 ,-180 §;039 1446.000 IbM CALI DRHO rCNb DRHO FCNL .023 IbM ,250 CALI ,025 DRHO ,000 rCNb .119 ,750 CAbI ,141- ILD 1495,000 -0,025 GR 243,375 965 ILD ,918 GR -260.000 460 ILD 781 DT 2,375 ILD 8,781 DT PAGE 83,375 2.4.24 79,!88 3'/,219 .027 8~,000 25,250 .855 764,488 25 3.238 66 ,',,~ 68 30.~'~ 0,70' e9,66~ 31,,609 5,750 .906 50,312 I 973 58 594 51 406 55 64 50 · 2:166 bVP 009,H03 VER]:FZCATION bIST]:NG PAGE 5 NRAT 3, NCNb DEP2' 8800,000 SFbU Sp -37,625 OR RHOB -999,250 NPH! NRAT -999,250 NCNb DEP2' 8700:000 SFbU SP -35 344 GR RHOB -999,250 NPH! NRA2' '999,250 NCNb DEPT 8600,000 SFbU . -24,859 GR ~HPOB '999.250 NPH! NRA2' -ggg,250 NCNb DEPT 8500,000 SFbU $p -28,328 GR RHOB '999,250 NPH]: NRAT -999,250 NCNb .o o DEP2' 8400 SFLU SP '35,8 5 GR RHOB -999.250 NPH]: NRA2' -999,250 NCNb DEPT 8300,000 SFbU SP '43,625 GR RHOB -999,250 NPHZ NRA2' -999.250 NCNb DEPT 8200,000 SFbU Sp -56,625 GR RHOB -999.250 NPHZ NRA2' -999,250 NCNb DEPT 8100,000 SFbU Sp -65,125 GR RHOB -999,250 NPH! NRAT -999.250 NCNb DEP2' ~000,000 SFbU 8P -.75,125 OR RHOB 999,250 NPH! NRAT 999,250 NCNb Sp .~88 GR RHOB 9 , 50 NPHI NRA2' 999.250 NCNb ?~00,000 SrbU 85,875 GR 38,770. DRHO. 1495,000 FCNb 97:750 CAb]: '999,250 DRHO '999.250 rCNb 1.586 2bM 91.188 CALi -999,250 DRH -999;250 FCN 1 96 -999 -999 ?88 :ibm ,250 DRHO .250 FCNb~ 1! ' 40 IbM , 88 CAbI' '999, 50 DRHO -999.~50 FCNb- 2 '7'7 -999 '999 ,629 ZbM ,$75: CAb/ ,250 DRHO ,250 FCNb~ .000 . 1,181 .999,250 DT :999;250 GR ,'.,999'250 0 GR~ 0 :271 IbD 25O ;250 OR --999;250 -999 2-50 GR -999 250 2.303 1,337 IbM 1, 86,288 CAbZ '999 '999,250 DRHO : -999~ -999'.250 FCNb -999', '99 -999 -999 -999 110 IbM .250 DRHO .250 FCNi.,~ ,375' CALl ,250 DRHO ,250 FCNL 029 IbM 00 CAbI 50 DRHO 250 rCNb .125 CAb]: ,250 DRNO .250 FCNb 3 143 -9 2 170 250 GR 250 ,926 IbM ,875 CAbI 48,906 . 1,096 ,,,,~999"250 -999.250 1-218 :999,250 ..'.. 999 -250 .!55 -99c~,250 -999.250 9~*006 -9 .250 -999.250 2 25O 999,250 974 250 :030 IbD 0.974 -99 050 DT' -999,250 '999-;250 GR '999.250 .999,250 .250 83 ILD - 9.1!50 DT - 250 ,999,250 -999,250 2,316 -999,250. 2 309 -999:2 0 -999,2~6 RHOB NRAT DE:PT RHOB NRAT RHOB NRAT DE:PT SP RHOB NRAT DE:PT RHOB NRA? DEPT SP RHOB NRAT RHOB NRAT DEE)T SP RHOB NRAT DEE)T RHOB NRAT DE:PT SP RHOB NRAT DEPT SP RHOB NRAT 5P 009.H03 VE:RIFICATION :999,250 NPHI 999.250 NCNb 7700,000 SFLU -77,375 GR -999,250 NPHI -999,250 NCNb 7600,000 SFLU 't10,125 GR '999.250 NE)HI '999.250 NCNb ! 00,000 SFLU 15,'125 GR 999.250 NE)HI -999,250 NCNb 7400,000 SFLU -122,375 GR -999.250 NE)HZ -999.250 NCNb 7300,000 SPLU -122,225 OR -999,250 NE)HI -999.250 NCNb. 7200,000 SFbU ' 9,250 NPH! -999,250 NCNb 7100,000 SFLU -1.22,375 GR :999,250 NPHi 999.250 NCN~ !:000, 000 SFLU 22,3'/5 GR , NCNb 6900.000 8FLU -126,375 GR -9 ,250 NCNL i ; 25 GR , 50 NE)H! "99 ,250 NCNb ~700,000 8FLU I07,875 GR LISTING "'999 '999 2 809 124 875 ¢~:b2 '999 250 DRHO '999 6 '999,250 ~ 927 250 - 250 ,; -99~ - 160 000 .999,25:0 999 '250 2 o2i '999 2 'gg9 '999 '999 935 250 250 250 664 150 25O 273 -9gg -999 .99! "999 50 !! 3 86 -- 999 'ggg 572 250 250 250 25O 4 902 25O bVP 009.H03 VERIFICATION biS?lNG PAGE 7 RHOB NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT RHOB NRAT DEPT RHOB NRAT DEPT 8P RHOB NRAT DEPT SP RHOB NRAT DEPT RHOB NRAT DEPT SP RHOB NRAT DEPT SP. RHOB NRAT DEPT SP RHOB NRAT DEPT =999.250 NPH! -999.250 NCNb $~080,000 SFLU 3,250 GR -999,250 NPH! '999.250 NCNb ... oi:ioo 50 NPHI - 9.~250 NCNb 6.41~0,000 SFLU "99 , 50 NPHI '999.250 NCNb 6~3~00.000 SFLU 6.:~13 GR -999. 50 NPH! ..999.250 NCNb 6200.000 5rbU -5 I GR -9 96');0 NPH! 6~.00,000 8FGU .9~;.500 GR .250 NPHI '999,250 NCNb 60..~0,000 SFbU 9,000 GR '999,250 NPHI -999,250 NCNb 5900,~00 SFbU -55, 50 GR "999,250 NPHI -999.250 NCNb 5800.000 SrbU '99 , 0 NCNb O.iO0 LU o, 999, 50 NPH! 999, $0 NCNb 5~00,000 SFLU 26,969 GR ~.999 50 DRHO 999:~50 FCNb 2,893 IbM ,250 CALl -999,250 rCNb 96[063 CALI 250 DRHO 2,949 IbM 90,563 CAL~ -999.250 DRH -999,250 LrCNb 91,838 IbM ,250 CALl -999,250 DR-MO -999'250 FCNL .5 94 'IbM 7 ,438 CALl '999,250 DR. HO '999.250 FCNL~ 5,133 IbM 70i563 CALl -999 -999 5,4i8 IbM -999. DRHO -999,250 FCNb =999.250 GR 999. 250 "999,2 .~ DT ...999; 250 GR "999. 250 :999 GR 999 3,21! ILD -999,250 DT '999~:250 GE -999.250 '..999,250 OR -999.250 2 -999 250 '99~'125." $050 oRDIXbD , 50 .99~,070 lbD ,250 DT '999~,250 GR - 9 9 9'250 4.3-16 IbM' . 4,~02 lbD 62,3i2 CALI ,~999, 50 DT "999,250 DRHO .1199'9,~50 GR '999.250 FCNL '999' 50 .533 IbM 3 '999, 50 DRHO 999 -999,250 FCNb -999, 633 50 DT 50 OR 25O 2,13! IbM ]J~,750 CALl '9 ,250 '999,250 "999,250 OR '999'250 .586 IbM 8 .563 CALl 3,6t9 '999,250 DT '999.250 2,844 '999,250 -999.250 . 3'14i 999,25 '999'25 3 24O :9 9: 25o 999.250 :3,709 '999;250 -999.250 2.55~ ,999 .250 -999.-250 -999, 00 . 4,043 999;250 .,999~250 3,742 '999,250 '999,250 '2,, '23 '999.~50 "999.250 3,855 '999,250 LVP RHOB NRAT 009,H03 V~RIFICATION -999.250 NPH! -999.250 NCNb DE:PT 5500.000 SFbU SP -31.~;2 OR RHOB -999, 0 NPHI NRAT =999'250 NCNb DEPT SP RHOB NRA? DEPT RHOB NRAT DE:PT SP RHOB NRAT DE:PT RHOB NRAT DE:PT SP RHOB NRA? DE:PT RHOB NRAT DE:PT' SP RHOB NRRT DEPT SP RHOB NRAT P RHOB NRAT DEPT SP 5400,000 SFLU ' . 50 NPH! '999.250 NCNb 5300,000 SrbU -999. 5 NPHI -999,250 NCNb 5200.060~ SrbU =999 50 NPH[ -.999,250 NCNb 5100.000 .5FLU '61"i NPH! so 999. 50 NCNb 999 -50 NCNb 4=800 88 GR 2:200 sr u -9~ .250 NCNb -9 ~'250 NPH! i .o .ooo .406 GR 9929.250 NPHX 999,250 NCNb 4600,000 SrbU '67,t50 GR '999, $0 NPH~ -999,250 NCNb 4500,000 8FLU '28,469 OR LISTING -999. '999. 90'688 .999'250 DRHt 999 · 250 99g 250 DRHO 999,250 FCNL 4, 93 -999 45 '2So 999'2:S0 999,250 3'961. 40 000 999.250 DRHO 999' 250 3' 2: b~ 999'250 DRHO 999'250 FCNL 'egg i ILD D 03 ILD 50 D 50 GR~ GR 120 GR 17 ILD 'g99 ~ '999 " 82:675: :999 250 DRHO 99g -999 'g99 83 '3?5 GR 84 GR PAGE: '999,250 2 834 -9991-250 -999.250 25O 1,880 -999,250 -999.290 -999,250 2,172 ,250 -.' '250 -g-99.250 . 2,830 999 -250 "999.250 - ,250 -9-99,250 4,582 '999"I.A(~ -999 .; 50 5,207 '999,250 bVP 009,H03 YERIFICATfON blSTING PAGE 9 RHOB NRA? :999.250 NPH! 999.250 NCNb 4400.000 SFbU =9 9.250 NPHI -999.250 NCNb 4300,000 8FGU -19.938 GR =999.250 NPH! "999.250 NCNb 4200.~00 SFbU '32, 06 GR -999 150 NPH! -999:50 NCNb .500 GR 99 50. NPH! :~99:150 NCNb i 000 8rbU °8:11 9;9, NPH! 999,250 NCNb .938 GR -999,250 NPH! .999,250 NCNb 3800, O0 SrbU "66.~75 GR -999.250 NPHI -999,250 NCNb 3700,000 Srbu -28.469 GE -999,250 NPHI -999.250 NCNb 3600 000 SrbU -999. 0 NPHI "999,250 NCNb "999,250 NPH! -999,250 NCNb 00,000 SFbU 3~45,000 GR DEPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT DEPT SP RHOB NRAT' DEPT SP RHOB. NRAT DEPT SP RHOB NRA? DEPT SP RHOB NRAT DEPT RHOB NRAT DEPT SP RHOB NRAT DEPT -999 -999 5 38 -999 -999 .8 'g99 -999 6 -999 6 999 8 999 $ '999 "999 41 "999 '999 ? ?! "999 '999 tO 5? ,250 DRHO ,250 rCNb 9999 , 250 199 ,250 OR 512 :281 CAbI ,250 DRHO ,250 FCNb 3.639 lbD -999,2$O O~ 999,250 GR "'999 · 250 ,3i6 IbM , 813 CALI ,2250 , 50 GR D_ ,266 IbM ,344 CAb! ,250 DRHO ,250 rCNb 730 Ibt~ 250 CALI 99.9 -999 D 945 IbM t DRHO 6 676 - 250 DT "" 99-9, -999. ,0 ." ,,ALI '"999 .250 DRHO '999 ,250 'FCNL~ LD 8.219 .6,, .250 FCNL "999,250 ~' 06 M CALl .250 DRHO ,250 rCNb -999 ,164 ,2O7 .563 .250 .250 -'9, FCNL ,,~99 ,938 CALl B,664 '999.250 DT' -999,250 289 -250 ;0 :{.0.094 .,999,250 -999'250 ,250 ",,. 999.250 6.492 -999;250 '999'250 250 250 '999 '999.'.' . 8.656 ...999.250 "'"999,250 6,B48 '999,250 -999.250 8.4114 ,,999'250 LVP 009,.H03 VERIFICATION blSTING RHOB -999..250 NPHI NRAT -999,250 NCNb "999.250 '999.250 DRHO "999,250 GR FCNL -999.250 DEPT 3300.000 SFLU Sp -36,906 GR RHOB -999,250 NPH! NRAT -999.250 NCNb ?,359 IbM .000 CALl 999 FCNL 6,363 ILD 99'250 .'999.250 DEPT 3200.000 Sp -;~,~06 GR RHOB '9 . 50 NPHI NRAT "999.250 NCNb DEPT 3~00.000 &FLU SP .'23,469 GR RHOB 999,250 NPHI NRAT -999.250 NCNb 8, 86 IbM 9 63, 68 CALI -999 ''g'. g~ -999. =~ 8.867 IbM 9 .9~,935 CALl -:999 "250 DRHO :999 -999.250 FCNL ,,,,999 :LD D£PT 3000.000 8rbU SP "46.438 GR RHOB -999..250 NPHZ NRAT -g99.250 NCNb 7,78i ~ZLM 56,813 CALl "999,250 DRHO "999,250 rCNb ,,99~9.238 ZbD '250 DT · ,999.250 GR -999;250 · 2900 000 SFbU DEPT . RHOB .- ,. 50 NPHI NRAT .' 50 NCNb 4.957 IbM 4 LD 68.312 CALl "999 ' DT '999,250 DRHO =999 ' GR "999,250 FCNL "999 DEPT 2800.000 SFLU SP "~3,'750 GR RXOB -99 ,250 NPHZ NRAT '999,250 NCNb 8~,~3 ILM ,~,451 , 3 CALl '99.,250 '999,250 DRHO ~ '9'99' "999.250 FCNL '999. DT DEFT 2Z05,000 SFLU .;;,.ooo ,250 NPHI RHOB NRAT -999,250 NCNb 4,039 'IbM ,250 DRHO -999.250 FCNL 3,730 -999-250 O~ "999 ;250 GR 999.250 DEPT 2664.500 SFLU Sp -49,438 GR RHOB -999,250 NPHI NRAT -999.250 NCNb bM ~000 3,652 , 999 35 844 :999. 999. GR ** FILE TRAILER ** rILE NAME ISERVIC,O01 SERVICE NAME l VERSION # l DATE t MAXIMUM LENGTH I 1024 rILE TYPE l NEXT FILE NAME I PAGE -999,250 7,063 - 9;250 .250 7.590 .-,999,250 999,250 - 250 -999" 250 94,348 .-9 9,250 -999.250 - ,250 ,250 ,576 :Iio° 2§~ ,000 .0 ~,250 .,999,250 10 L¥.P 009,H03 YERIFICATION LfSTING DATE 1Si 5/29 ORIGIN 16165 TAPE NAME I CONTINUATION ~ ~01 NEXT TAPE NAME ~ COMMENTS ~TAPE COMMENTS ~* REEL TRAILER *~ SERVICE ~AM )SERVI~ DATE ,81 05~29 ORIGIN REEL NAME ~REEL ID CONTINUATION ~ )0I NEXT REEL NAME ) COMMENTS )REEL COMMENTS PAGE