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194-065
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~/~/-~' File Number of Well History File PAGES TO DELETE RESCAN Color items- Pages: Grayscale, halftones, pictures, graphs, charts Pages: [] Poor Quality Original - Pages: n Other- Pages: DIGITAL DATA [] OVERSIZED Diskettes, No. Other, No/Type ..ri ri Logs of various kinds Other Complete COMMENTS: Scanned by: Bevedy Dian~athan Lowell Date: Fy TO RE-SCAN Notes: Re-Scanned by; Beverly Dianna Vincent Nathan Lowell Date: ~si Pi� � STATE OF ALASKA AOKA OIL AND GAS CONSERVATION COMAkION AUG 0 7 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other L/ Seal-Tite Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other p Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Na me: BP Exploration(Alaska),Inc • Development❑ Exploratory ❑ 194-065-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99519-6612 50-029-22476-00-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028325 PBU 11-35 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL • 11.Present Well Condition Summary: Total Depth measured 9500 feet Plugs measured None feet true vertical 8975 feet Junk measured 9345 feet Effective Depth measured 9394 feet Packer measured 8664 feet true vertical 8875.85 feet true vertical 8200.84 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 32-112 32-112 1490 470 Surface 3646 10-3/4"45.5#NT-80 31 -3677 31 -3674.56 4560 1730 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None None None Perforation depth Measured depth See Attachment feet SCANNED NOV 0 5 20 13 True Vertical depth See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 30-8766 30-8293.12 Packers and SSSV(type,measured and true vertical depth) 4-1/2"Baker SABL-3 Packer 8664 8200.84 Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 978 31992 2295 1407 1739 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service 151 ' Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas U WDSPI:U GSTOR ❑ WINJ El • WAG ❑ GINJ ❑ SUSP ❑ SPLUC❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-188• Contact Nita Summerhays Email Nit a.Summer L hav_ .BP.com Printed Name Nita S mmerhay Title Petrotechnical Data Technician i w-zo.WAWA V '''''WAY: /��)rJri/.�� _` Phone 564-4035 Date 8/7/2013 1/24� RBDMS AUG - 8 20V% g/i5//3 Form 10-404 Revised 10/2012 v ' % Submit Original Only • S Daily Report of Well Operations ADL0028325 ACTIVITYDATE I SUMMARY Vi ge re men DRIFTED WITH 3.85" GAUGE RING TAG SVLN @ 2092' SLM 6/4/2013 ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** T/I/0=300/300/350 Temp=S/I Circ out( Sealtite Collar Leaks in Tubing) Displace tbg & IA with diesel. Pumped 150 bbls diesel down tbg & up IA taking returns to well#27 Flowline Final WHP's 700/700/500 SV,WV,SSV=closed MV,IA,OA=open DSO 6/6/2013 notified at departure ***WELL SHUT IN ON ARRIVAL***(gel treatment) DRIFTED W/3.77"WRP DRIFT& 3.84" NOGO -TAGGED SSSV @ 2094' SLM SET 4-1/2"WFD WRP @ 659' MD 6/9/2013 ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED*** TWO = 520/370/380. Temp = SI. TBG FL Depress. (assist SLB SL). No AL. Hard line rigged up from IA to OT tank. T& IA FLs @ surface. Used AL gas from 11-27 to pressure the TBG from 520 psi to 900 psi, depressing the TBG FL from surface to 1932' taking returns out the IA to OT tank(29.5 bbls). 6/9/2013 SLB SL in control of valves on departure. 22:00 Hrs. T/I/O = 1920/81/320. Temp = ST. Assist Seal-Tite ( Pump &activate sealant). TP decreased 1081 psi, IAP increased 46 psi and OAP increased 10 psi since 06-17- 2013. Increased TP from 1920 psi to 3037 psi with MEOH ( 14.75 gal). Monitor for 1 hr, 30 min increments. TP decreased 147 psi and IAP increased 5 psi. Job in progress. FWHP's =2890/86/320. 6/18/2013 SV,WV= C. SSV, MV= O. IA& OA= OTG. NOVP. 11:00 hrs. T/I/O = 1390/192/320. Temp = SI. Bleed flow line (assist seal-tite). No AL. TP increased 230 psi, IAP increased 48 psi and OAP unchanged since 06-19-2013. Flow line pressure = 1375 psi. Bleed down flow line pressure to 453 psi in 1 min. Monitor FL for 30 min. Called grease crew to service Wing valve and pit valve. See log for details. Job in progress. Final WHPs = 1435/200/320 6/20/2013 SV, WV= C. SSV, MV= 0. IA, OA= OTG. NOVP. 13:30 Hrs T/I/O = 1260/260/330. Temp = SI. Monitor WHPs (assist seal-tite). No AL. TP decreased 175 psi, IAP increased 68 psi & OAP increased 10 psi since 06-20-2013 bleed. Job in progress. 6/21/2013 SV, WV= C. SSV, MV= O. IA, OA= OTG. NOVP 18:30 Hrs. T/I/0= 1500/250/320. Temp.= SI. WFs flowline pressure on s-riser(Post Seal-tite) day and night monitor No AL. Flowline= 1700 psi. TP increased 65 psi, IAP increased 50 psi, OAP unchanged since 6/20/13. 6/21/2013 SV,WV= C. SSV,MV= O. IA& OA= OTG. NOVP. 1100 hrs T/I/0=1345/250/330. Temp= SI. trouble shoot wing svc tree 100% Shut MV and SSV & LAT valve bled flow line down to 40 PSI. Aply 3000 PSI on the tubing for one hour & monitor flow line pressure ever 15 min. to verify wing holds. ever 15 min.flow line gain 4 PSI and & one hour it gain 17 PSI. and the tubing lost 233 PSI. Then we bled the tree to 0 and open up the LAT valve. LAT Line had 1225 PSI on it and 30 min. the 6/21/2013 tree gain 9 PSI.This was all charted & put in to QC field chart. Job complete T/I/O = 1058/304/320 Temp = SI. Assist Seal-Tite (Pump &activate sealant). No AL. TP decreased 442 psi, increased 54 psi an OAP unchanged since 06-21-2013. 6/23/2013 SV, WV= C. SSV, MV= 0. IA, OA= OTG. NOVP 18:30 Hrs. • Daily Report of Well Operations ADL0028325 T/I/O = 927/338/320. Temp= SI. MIT x TBG FAILED to 3000 psi (Post Seal Tite). Initial TBG FL ©Surface. Initail IA FL @ 660' (17 bbls) . Pressured up the TBG to 3000 psi w/5 gallons of DSL. The TBG lost 552 psi in 15 minutes and 242 psi in the second 15 minutes for a total 30 minute loss of 794 psi. Bled the TBG pressure to 1500 psi (-3 gallons, all fluid). Job complete. FWP's = 1538/338/314. 6/26/2013 SV, WV= C. SSV, MV= O. IA, OA= OTG. NOVP. 1515 hrs. T/I/O = 1200/360/330. Temp = Si. Pump Seal-Tite (Assist Seal- ite . ee og or details. Job in progress. Final WHPs = 2105/130/300. 6/29/2013 SV, WV= C. SSV, MV= O. IA, OA= OTG. NOVP. 19:00. T/I/0 =2448/141/306. Temp = SI. MIT-T PASSED to 3037 psi with Diesel (Post Seal Tite). Initial TBG FL @ surface. Pressured up the TBG to 3037 psi with-4 gal Diesel. The TBG lost 8 psi in 15 minutes and 4 psi in the second 15 minutes for 12 psi in 30 min. Bled the TBG pressure to 1970 psi (- 5 gallons, all fluid). Job complete. Final WHPs= 1970/141/305. 6/30/2013 SV, WV= O. IA, OA= OTG. NOVP. 12:00. FLUIDS PUMPED BBLS 152 DIESEL 152 TOTAL FLUIDS PUMPED GALS 55 FLO-SEAL 55 TOTAL Perforation Attachment ADL0028325 SW Name Operation Date Pelf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 11-35 7/10/2013 BPP 9030 _ 9043 8536.89 8548.98 11-35 7/10/2013 BPP 9043.5 9046.5 8549.44 8552.23 11-35 7/10/2013 BPP 9046.5 9047 8552.23 8552.7 11-35 7/10/2013 BPP 9047 9050 8552.7 8555.49 11-35 7/10/2013 BPP 9100 9116 8602.01 8616.89 11-35 7/10/2013 BPP 9117 9127 8617.82 8627.13 11-35 7/10/2013 BPP 9127 9147 8627.13 8645.74 • 11-35 7/10/2013 BPP 9147 9151 8645.74 8649.46 11-35 7/10/2013 BPP 9156 9163 8654.11 8660.62 11-35 7/10/2013 BPP 9282 9292 8771.38 8780.69 11-35 7/10/2013 BPP 9318 9338 8804.92 8823.58 BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • I Casing / Tubing Attachment ADLOO28325 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 32 - 112 32 - 112 1490 470 PRODUCTION 8451 7-5/8"29.7# NT-95HS 32 - 8483 32 - 8040.19 8180 5120 PRODUCTION 1000 7-5/8"29.7# 13CR80 8483 - 9483 8040.19 - 8959.09 6890 4790 SURFACE 3646 10-3/4"45.5# NT-80 31 - 3677 31 - 3674.56 4560 1730 TUBING 8736 4-1/2" 12.6# 13Cr80 30 - 8766 30 - 8293.12 8430 7500 • • •111th= CM r ES • NOT : ""CHROME CSG&TBG"" ' 'D= F 11 -35 ACTUATOR= BKR C NITIAL KB.ELE 62' BF.BEV= - KoP_ 4512' Rut Angle= 31°@ 7276' • I 211W H4-12-CAI(X)BAL-O SSSV NIP,D 3.815' I Datum M3= 9379' kitun 7VD= 8800'SS 110-3/4"CSG,45.5#,NT-•+t,D=9.953' IH 3677' I, GAS LFT MANDRELS 1ST AU TVD'DEV TYPE" VLV LA1O-I PORT DATE 1 '3186 3184 1 KBMG C BK 05/12/12 Minimum ID =3.726" @ 8764' 2 3�: •. o KBMG EQUAL BK-2 09�3as7 4-1/2" OTIS XN NIPPLE 3 6365 6202 30 KBMG EQUAL BK-2 10+01/97 4 7457 7148 30 KBMG BXIAL BK-2 05/22194 5 7651 30 KBMG EQUAL BK-2 05/22/94 6 8142 7743 30 KBMG EQUAL 13K-2 10101/97, 'PORTED BKP LATCH ON CIRC VALVE 7-5/8'CSG,29.7#,NT-95 I-IS XO TO 13CR-80 I—I 8483' 1— X ' I 8603' _{4-12"OTIS X NP,D=322' I Z1 8664' —7-5/8"X 4-1/2"BKR SABL-3 PKR,D=3.92" I ' 5688' .H4-12'OTIS X NP,D=3.813' I I I 8754' 4-1/2'OTIS XN NP,D=3.725' I 1 4-12'TBG,12.6#,13CR- ,.0152 bpi,D=3.958' I— 8788' I / \ 1 8766' 1--I4-1/2'ACED,D=CO' 8768' —ELMD TT LOGGED 06/11/94 PERFORATION SLIWARY REF LOG: INA/DG'VPBJ ON 05/19/94 ANGLE AT TOP F :20°@ 9030' Note:Refer to Production DB for historical pert data SIZE SPF NTERVAL Opn/Sqz SHOT SQZ 3-3/8" 6 9030-9050 0 12/13/02 2-7/8' 6 9100 9116 0 09/01/02 2-7/8' , 6 9117 9127 0 09/01/02 2-718" 6 9127-9147 0 08/19/01 3-3/8" 4 9147-9151 0 12/12/98 3-3B' 6 9156-9163 0 05/12197 3-3/8' 4 9282- 2 0 07/10/96 3-3/8" 4 9318-9338 0 06/11/94 934$' I—FISH-(2)5/8'X1-1/16"X4'ARM SFF*13S R371) --{ 9394' (9130/199R371) 7-58"CSG,297#,13CR-80,0=r-8.875' 9483' 1444440400044041 H 40000000001 i4i4ii4ii�ii∎i TD — 9500' 4.0.4.0.4.444. DATE REV BY COMMENTS DATE REV BY C OMNBJTS PRJDHOE BAY UNT 06/21/94 ORIGINAL COMPLETION 05/15/12 SET/JMD SET WFD 1M;IP(05/12/12) WELL 11-35 1026/01 F2WTP CORRECTIONS 05/27/12 PJC PEW COERRECT1ON FERMT M': 1940650 02/11/07 RCT/PAG PULL PXN RUG @ 8754' 06/17/13 LEC7JM)'SET WFD WRF'(06/09/13) API No: 50-029-22476-00 03/04/07 SPF/TLH I I N SET TO SECURE(2/2 07/23/13 FET/JMD PULLED ALL PLUGS(07/07-10/13) SEC 28,T11 P1 R15E 540'FSL&247'FE_ 11/17/07 KDCIPJC.RJLL/RESET PXN(11/13107) 05/15/12 SWCIJM)GLV CIO(05/12112) Q BP Exploration(Alaska) • • • w * \1 %%y s THE STATE Adiaska Oil and Gas 1 ,4 Of A` Ccpnseivation m ission a r GOVERNOR SEAN PARNELL 333 West Seventh Avenue ALAS� Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax 907.276.7542 DINED MAY 0 2 2013 Bernhard Stechauner Petroleum Engineer 1 Cf ©6� BP Exploration (Alaska), 1 ( f L t p � ), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 11 -35 Sundry Number: 313 -188 Dear Mr. Stechauner: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. r Commissioner DATED this ) day of May, 2013. Encl. • • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 1 6 2013 APPLICATION FOR SUNDRY APPROVALS AOGCC AAC 25.280 A AOGCC 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Chertge Approved Program ❑ Suspend ❑ Plug Perforations❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ r Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. SEAL -TITE - in 2. Operator Name: ,t 4. Current Well Class: 5. Permit to Drill Number. • BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 194 -065 -0 3. Address: Stratigraphic ❑ Service El • 6. API Number. ✓' P.O. Box 196612, Anchorage, AK 99519 - 6612 50-029 - 22476 -00-00 • 7. If perforating: 8. Well Name and Number. ✓' What Regulation or Conservation Order govems well spacing in this pool? 341 D PBU 11 -35 . Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): ✓ 10. Field /Pool(s): r/' ADL0028325 ' PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9500 • 8975 . 3220 3218 None 9345 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 32 - 112 32 -112 1490 470 Surface 3646 10 -3/4" 45.5# NT -80 31 - 3677 31 - 3675 4560 1730 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None Nam None Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (It): See Attachment See Attachment 4 -1/2" 12.6# 13Cr80 13Cr80 30 - 8766 Packers and SSSV Type: 4 -1/2" Baker SABL -3 Packer Packers and SSSV MD (ft) and TVD (ft): 8664 8200 No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 151 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/1/13 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 0 • GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bemhard Stechauner Email Bemhard.Stechauner(BP.com Printed Name Bernhar echauner Title PE Signature Phone Date ' 907- 564 -4594 4/16/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RBDMS MAY - 2 201 Other: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: D 4 0 4 7' APPROVED BY /j.3) Approved by: � COMMISSIONER THE COMMISSION Date: � 1 1/ 4/231/1 V V,4) O R 11 - 64N 4., 1�_ Approved application is valid for 12 months from the date of a proval. Submit in Duplicate ∎ , �; �s•� 'QF 1��k , %a • • • bp Date: 03/15/13 To: Jerry Bixby /Rob Liddelow, AK, D &C Wireline Operations Team Lead Clark Olsen/Tyler Norene, AK, D &C Well Services Team Lead Jerry Murphy /Mehreen Vazir, AK, Well Integrity Coordinator From: Bernhard Stechauner, DS11 Pad Engineer, 564 -4594 office, 360 -7485 cell Neil Carry, STI, 985 - 875 -1292 office Subject: 11 -35 Repair Tubing Leak using Seal -Tite AFE: APBNRWOS IOR: 150 bopd Step Type Procedure 1 S Pull DGLV at Station #1 3186' MD and set circ sleeve. Set WRP at 3220' MD. 2 F Displace tubing and IA with diesel. Establish liquid level in tubing below 650'. 3 S Set WRP at 635' MD. 4 Spec Pump and activate sealant Proj 6 SP Pull WRPs if repair is successful. Discuss with WIC requirements for pulling TTP and steps required to make and Operable well. Objective: This program is to repair multiple tubing leaks by lube and bleeding Seal -Tite into the tubing and sealing the leaks. If the repair is successful, the WIC will need to obtain an AA in order to use a MIT -T and CMIT -TxIA to establish dual barrier integrity so that a high differential pressure from the IA to the tubing that could potentially unseat the plugs won't occur. Well Stats: Well Status: SI and Not Operable for TxIA Last injection: 27,000 bwpd at 1100 psi on 1/21/2005 Deviation: max 31° @ 7276' MD Min ID: 3.725" @ 8754' XN Nipple Est BHP: —3350 psi @ 8800' TVD (2010 BHP map) SSSV: No Last H2S: NA (injector) Well Events Summary: 11 -35 is a shut -in SWI that has not seen injection since 2005 due to flowline troubles at DS11. The flowlines at DS11 were repaired and returned to service in 11/2011. In May of 2005, soon after the shut -in, the well had a passing MIT -T and MIT -IA. In October of 2009 the well failed an MIT -T and MIT -IA. A Tecwell LDL found collar leaks at 76', 120', 163', 208', 250', 379', and 639'. The LLR for all of these leak points together is only 0.46 gpm at 3000 psi. The well had , another failing MIT -IA but a passing CMIT -TxIA on 11/15/11, confirming that the leak seen in the IA is only to the tubing. Please call Bernhard Stechauner (APE) at 564 -4594 or Neil Carry (Seal -Tite Engineer) at (985) 875 -1292 with any questions or concerns regarding this program. Cc: Well File AK, D &C Well Integrity Engineer • • Discussion: • The IA was completed with 8.65 ppg inhibited seawater. The highest GLM (Sta. 1) will be used to circulate and displace fluids in the IA and tubing • Two WRPs will be used in this program. The top WRP will be directly below the bottom leak and will be used to stack out our sealant and brine pills. The bottom WRP will be set below the circulating gas lift mandrel. Its purpose is to stop most of the Seal -Tite from falling below our circulation point and ending up on the perforations. • Either nitrogen or AL will be used to displace the liquid level of the tubing down beneath the bottom leak point. The gas selected for use is at WSL discretion. Note that the top WRP will be set in gas and will be RIH with pressure on the tubing in order to prevent liquid from rising above the bottom leak point. • The initial displacement of tubing and annulus can be sent to the production system. The second displacement containing the Seal -Tite pills should only be circulated to a tank. Do not send Seal -Tite returns to the production system. Rig up notes and requirements: - Rig up hard line through a choke skid to pump down both the Tbg and IA taking returns down to a neighboring well's flowline or contingency tank. Make sure there is a sample port in the choke skid to confirm return densities. Make sure there is a strap sheet for the contingency tank. The nearest well is 11 -25, a shut -in producer. If returns are sent down the production line, ensure that it is kept freeze protected. - Have a mud scale available for density measurements. - Because the Seal -Tite must be injected into the tubing by the lube and bleed method, a diaphragm pump must be used. Be sure that this equipment is available and operational on the slope before beginning this work. Work with the STI representative to make sure the equipment spec is correct. - The sealant is freezable fluid. The special projects trailer will be needed for maintaining temperature and mixing the sealant pills. - Heaters for the well house and projects trailer. - Air compressor for the pumps. - Bleed trailer. - Flowback tank for Seal -Tite returns Volumes: Note — all volumes /depths below are corrected for RKB /BH elevation difference of 26' (K.B. 60.2' and G.L. 34.3'). As such all depths are denoted "MDBH" (Measured Depth to Bradenhead) Total IA volume — 7 -5/8" x 4 -' /s" to Production Packer @ 8638' MDBH (8754' MD) = 226.3 bbls Tubing Volume To Bottom Leak @ 613' MDBH (639' MD)= 9.3 bbls Tubing Volume to Top WRP @ 659' MD (633' MDBH) = 9.6 bbls Tubing VolumeTo Highest Gas Lift Mandrel @ 3160' MDBH (3186' MD)= 48 bbls Annulus Volume To Highest Gas Lift Mandrel @ 3160' MDBH (3186' MD) = 83.5 bbls Tubing Volume 4'/2" (to PXN plug) at 8728' MDBH (8754' MD)= 132.7 bbls Leak Depths: Tubing Leaks at 76', 120', 163', 208', 250', 379', and 639' MD Tubing Leaks at 50', 94', 137', 182', 224', 353', and 613' MDBH • • Fluid requirements: - 350 bbls Diesel - 1.2 bbls 10.8 ppg NaCI /NaBr Low Temp for sealant mixing (Flo -Seal blended with this brine gives a 10.8 ppg sealant) - 5.2 bbls 10.3 ppg NaCI /NaBr Low Temp for sealant mixing (Flo -Seal blended with this brine gives a 10.4 ppg sealant) - 2.8 bbls 10.6 NaCI /NaBr Low Temp ppg brine - 10 bbls neat McOH Procedure: Slickline: Change Out GLV and Set Bottom WRP 1. Hold PJSM. RU slickline. 2. RIH and mechanically tie -into SSSV nipple at 2119' MD (2093' MDBH). Flag wire as appropriate. • Note that depth control is critical when setting the WRP in Step 11 below to ensure volumes are correct both for squeezing the leak and freeze protecting the tree. 3. Pull DGLVs from Sta# 1. Set circ sleeve in Sta #1. 4. Set WRP at 3210' MD (3184' MDBH), directly below Sta #1 at 3186' MD (3160' MDBH) and tubing collar at 3200' MD (3174' MDBH). 5. Pump with triplex (or FB) to establish both TxIA and IAxT circulation. Fullbore and Projects: Circulate Well Out with Diesel 6. Hold PJSM. RU FB pump to the choke skid. 7. Line up to pump down tubing, taking returns up the IA to nearby flowline of 11 -25. Leave -200 psi of back pressure on the annulus during circulation to make sure the system remains liquid packed. 8. Circulate a total of 150 bbls of diesel down the tubing taking returns up the IA. At 131.5 bbls (one round trip volume), the IA & Tbg should be fully displaced. Ensure returns are clean diesel. Maintain maximum pump rate as per PE manual. 9. Line up to pump nitrogen or AL (WSL discretion) down the tubing taking returns up the IA. Displace diesel down tubing and out of IA until liquid level in tubing is below 700'. This will take approximately 1 mscf of N2 or AL. Displaced liquid volume will be -10.5 bbls. • Note: As the warm nitrogen or AL volume cools in the permafrost, the volume will shrink. Overdisplacement may be necessary. • Note: Confirm liquid level is below 700' by either using SL to tag the liquid level or by strapping the return tank to make sure at least 11 bbls have been circulated back. • Note: Once gas enters the tubing (N2 or AL), it will become underbalanced compared to the annulus. Once the displacement is complete, the tubing ., • • will have approximately 250 psi more than the IA. This pressure must not be bled off or the liquid level will rise. Slickilne: Set Top WRP 10. RU SL. Maintain constant tubing pressure. 11. RIH and confirm liquid level is below 700' MD. Set WRP in N2 column at 659' MD (633' MDBH), directly below bottom leak. 12. If Seal -Tite is not immediately ready to pump, pressure test to 1000# with N2 or AL for at least 30 minutes. RDMO. Fullbore and Projects: Lube and Bleed Sealant and Pills, then Activate Sealant 13. Blend 1.2 bbls of Flo-Seal to 10.9 ppg (Flo -Seal SS concentrate blended with 10.8 ppg brine). 14. Lube and bleed 1.2 bbls of 10.9 ppg Flo-Seal into the tubing. Allow 30 minutes for sealant to fall and settle on top of the WRP. 15. Lube and Bleed in 2.8 bbls of 10.7 ppg NaCI /NaBr Low Temp into tubing. AIIow 30 minutes for brine to fall and settle on top of bottom Seal -Tite pill. 16. Lube and bleed 5.2 bbls 10.5 ppg Flo-Seal into tubing. 17. Lube and bleed 0.5 bbl neat McOH into the tubing to freeze protect the tree. 18. Use neat McOH to pressure the tubing up to 2000 psi to cure the sealant. Monitor pressures every 15 min and repressure every 30 min until the leak rate begins to decrease. Once there are indications that the sealant begun working and pressure is holding steady, bleed the Tbg back to 1000 psi. • Note: Keep close track of annulus pressure and bleed them off so that they never go over 500 psi. The leak off in the tubing will be going into the fixed IA volume. 19. Shut down pump and allow a seal to be obtained at 1000 psi. Let the sealant cure for a minimum of four hours. 20. Increase Tbg pressure to 1500 psi. AIIow to cure for at least two hours. 21. Increase Tbg pressure to 2000 psi. AIIow to cure for at least two hours. 22. IncreaseTbg pressure to 3000 psi. 23. Shut in the Tbg and allow the sealant to cure for 5 days. Monitor pressure daily and bump back up if the pressure falls below 2000 psi. 24. RDMO FB pump. Slickline and DHD: Pull WRPs, change out GLVs, pressure test, and pull TTP • • NOTE: Contact WIC about required testing procedure, to make the well operable, to be done in conjunction with the following slickline work. The following steps are recommendations to be modified as the WIC requests. 25. RU SL. 26. Pull top WRP. NOTE: At this point the IA is underbalanced to the tubing by -100 psi, and this will be the dP across the plug. 27. Circulate 150 bbls diesel down tubing and up IA taking returns to a tank. • Note: Do not send returns to the production system. Only take them to a tank to be disposed of. 28. Pull Circ Sleeve from Sta #1 and set DGLV. 29. Pull bottom WRP. 30. MIT -T to 3000 psi. CMIT -TxIA to 3000 psi. LLR if either Fails. 31. If both MIT -T and CMIT -TxIA pass, pull the PXN TTP from 8754'. If either test fails, leave the well secured. If the repair is successful, notify Well Integrity of the test results and add a note to AnnComm stating: DO NOT MIT -IA due to sealtite TxIA repair - MIT -T & CMIT -TxIA instead - IAP should remain below TP if possible to avoid displacing SealTite repair. 32. RDMO SL & FB pump. III • ON I SAF£IY NOTE& 'CliR3MECSO & TOG" , ;L ,_ _ ., ._... -_ 1 1 -35 ►. 3�.:: :: •, KR ELEV * OW EF. aeu • KCCP • 4517 lax Amiss s 1 A 727W Dakin MD s 93717 2119` f- I4-1/1' C,RMDD BAL-0 sBSV NP D = 3.815• I Dabtm TVD : 8807 SS • 1 1 10 -3/4' CSG, 45.51, NT80, D =9.953' H 3677 GAS LET MANDRELS ST MD TVD CEV TYPE VLV LATCH FORT DATE 1 3186 3184 0 KBKAG BK -2 Minimum ID = 3.725" @ 8754' 2 3988 318 0 KB 13K -2 3 63139 6201 30 148/AG BK -2 44/2" OT IS XN NIPPLE 4 7457 7148 30 KEING BK -2 5 8036 7651 30 K8&IG BK -2 6 8142 7743 30 KBIAG BK -2 1 7-5/8' GSG, 29.71, NT-95 HS XO TO 13CR410 --I ear I—r 8603" FI4 -117 OT1S X IMP, ID s 3.82' I .7:1 CI 868c 7 -SW X 4-1/2' EOM SABL -3 RCR, D = 392' II 8638' H4 -1/2' OTtS x N•P 0 =lair I ' 4 111' 074 s XN PIP, o = 3. 79 _ iii 875e F-I 8754' H3.81" PXN PLUG (11(134)7) 1 4-112' TBG 12.6S,13CR4,0, .0152 b(, D = 3.958' H 8766' 1— 87W I-- I4 -1,7' VYLB D = 4.17' I I 8758'' I--Ia/A:I TT LOGGED OV11/94 I Ft7RFORAT1CN St MIARY I REF LOG: WAXEN/013J ON 06(19/94 ANGLEAT TOPFERF: 20“ 90307' Note: Ref ertD Prod LaMar, DB for netoocaf pod Oafs I SEE SPF NTERVAL OpiSgz DATE 3-3,or 6 9030 - 9050 C 1211 302 I 2- 7.8•' 6 9107 - 9116 C 090102 2 -718' 6 9117 - 9127 C 090 1,0t2 4) 2 - 6 9127 -9147 C 01119101 I 3-318' 4 9147 - 9151 C 12112418 3-38" 6 9156 - 9163 C 0301 HIT 3-3g 4 9282 - 9292 C OM CI96 I 3-324' 4 9318 - 9338 C 061` 1/94 I 934,5' FISH- (2) 5/8'X1- 1/46'X4'AFIIASFRNGS I (930/1997) PBTO 9394' _I 4•10.4.010.1 44444411444 144444444/1 17 -5A1" CSG, 29.71,13CR 80, C=6 875" F u L 9483' 1 + 4 4 4 4 1 4 4 4 4 4 4 4 4 1 4 1 4 4 4 t 1 4 4 4 4 1 44 �! 4 1 TD 9500' ....0.0.0.0.4.0.4 DATE REV BY OOMENTs DATE REV BY COMLENTS PRL 10E BAY 'LOST 05(21/94 ORIGINAL COMPLETION 10/27 /05 DFRAItG WELIJ-EAORREE CORRECTIONS WELL P+ 1-35 10/26001 RNRP CORRECTIONS 02111 /07 RCT IPA G FULL PAN PLUG I@ 8754' PERAT No: R 940650 09/01/02 CWS/W( ADPf3ZF 03/04/07 SFF /TU-I TTP SET TO SECURE (2 /284)7) API Nei: 50-029-22476-00 1€124102 GC.I(AK PEW CORRECTION '1: 17, KDC/PJC PAIL I RESET PXN (11/13/07) SR' 28, T' 1N, R15E, 490.0T FEL 8 2559.72' 12/13/02 C.AO/KK ADFEFF 09/23/05 MOWTLH PXN TTP SET (09 BP Exploration (Alaska) • • o v"sp y LEAK DETECTION - WLD r . wiEti Wr os Main Up P. 0 Lk- r . MM XTU- HTU -CCL- TEMP -VN.D r _ Peo.ono o o oi.q s,. to 07 -Nov -09 Mr 4— 00 T bg =100 psi = C ompany BP E XPLORATION (ALASKA), INC. PepeAtrive Pi+wAetu Stank et. , Well 11 - 35 Po Database Fee d :t►varriorldalatil 1- 35111 -35 3.db 1 Field PRUDHOE BAY Detese1 pathraime oass3 § County NORTH SLOPE State ALASKA Presentation Format: wld_log e N I _ litters ea o Surface location Dateset Creation: Sat Nov 47 12:16:15 2009 by Log Sonde a g x to one Cheated by: Depth In Fact srsied 1 a S C : FE TVVP: 11N FNL 5E r _..._ Elevation 5000 CCL • 6` ■ 0 a Permanent Datum Ma ._.. Elevation 0.0 KB 80 0 Va � .r ,,1 Vy'yr ✓A Y - to p Measured F,o,,, RKB 60.0 FT. Above Perm. Datum D F N 0 Line Speed «1/n rl) -200 0 S API Seam Number 50-029-22476-00 G l NIA D ine - -- `_. Nai�b9 0 ad Tension (lb) 200 0 Run Number One P BT 9390 --..-- .— ._._..�- _- _.— ,._- _- _- _.� -_ PBTDLogger _ ......faTegged -._ 0 Temperature (degF) 2+00; 20 T I,I Logged i "°"a' u :1 ..,..•..,.. i »..-.. Open Bole Sze n N/A Type F1ud Produced Honda • t�.00rded temp to F_) T -_- 1993 — FINAL PRINT Tine Reedy 0600 i 1me L on Hohom _ __ __ 1216 _ .__ .._ E -... _ Safi 12128 __.__ i Location aervt NOIBI Slofy _......... ,.... ' m - By N No 9052 Recorded By . ...._ - 9 ear o i. - -_ - Winterised -- By ...__ 1 Denlem .... R Doe* i � �� RtnNunber� Borehole - ,' Rcc° F rd .._ o a i LB /F tt Prom To . 1 l 117 1290 Surface 8.708 . t -- _. - Fleeced ` t__ , Too bottom - 1 1t k_ 'Cameo to 103/4' ... __.4630 _ Suffice 367T s Plot.eiitp _— TS19' li76 _ Surface 9:3Qq tlltar .. -. — __ -____ Der r 200 Leak S Leak Signature ' 1 4 CC L , - .� -rte r .Line Speed _ I - I . t I - - Head Tension . • M` Leak Sognahire $ 400 ,, i Temperature Ternperetse •` " I .- ► 500 —_ -_ DItterer lel Te� :' , 4 i ir ......" , 600 _ — Leak Signature iv. ,..... iv ._ . .. ... 11 , i • , _ _ , I nn r i • • Perforation Attachment ADL0028325 Well Date Perf Code MD Top MD Base TVD Top TVD Base 11 -35 5/12/12 BPS 9030 9043 8537 8549 11 -35 5/12/12 BPS _ 9044 9047 8549 8552 11 -35 5/12/12 BPS - 9047 9047 8552 8553 11 -35 5/12/12 BPS 9047 9050 8553 8555 11 -35 5/12/12 BPS 9100 9116 8602 8617 11 -35 5/12/12 BPS 9117 9127 8618 8627 11 -35 5/12/12 BPS 9127 9147 8627 8646 11 -35 5/12/12 BPS 9147 9151 8646 8649 11 -35 5/12/12 BPS 9156 9163 8654 8661 11 -35 5/12/12 BPS 9282 9292 8771 8781 11 -35 5/12/12 BPS 9318 9338 8805 8824 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Casing Summary ADL0028325 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 80 20" 91.5# H-40 32 112 32 112 1490 470 H-40 PRODUCTION 8451 7 -5/8" 29.7# NT -95HS 32 8483 32 8040 8180 5120 NT -95HS PRODUCTION 1000 7 -5/8" 29.7# 13CR80 8483 9483 8040 8959 6890 4790 13CR80 SURFACE 3646 10 -3/4" 45.5# NT -80 31 3677 31 3675 4560 1730 NT -80 TUBING 8736 4 -1/2" 12.6# 13Cr80 30 8766 30 8293 8430 7500 13Cr80 • • .., VVELLHEAD = aw III r SV NOTES: ***CHROMECSG & TBG*** I FMC - ACTUAT'OR= -- '13146 1 1 -35 KB. ELEV = 60' BF. ELEV = KOP= - - — 4512 J I 2119 H4-1/2" CANICO BAL-0 SSSV NP, D = 3.815" Mix Angle= - - 31":167i76 bitiirn her; — 9379 INtum 1VD= 8800' SS I 3220 F-14-1/7WFOWFIP (05/12/12) I 10-3/4' CSG 45.5#, NT-80, 13 = 9• 953" H 3677' 411° GAS LFT MkNORELS 1ST MD IVD ('kV TYPE VLV LATCH PORT DATE 1 '3186 3184 1 KBMG CRC BK 05/12/12 Minimum ID = 3.726" @ 8764' 2 3988 3986 0 KBMG EQUAL BK-2 09/30/97 4-1/2" OTIS XN NIPPLE 3 6365 6202 30 KBMG EQUAL BK-2 10/01/97 4 7457 7148 30 KBMG EQUAL BK-2 05/22/94 5 8036 7651 30 KBMG EQUAL BK-2 05/22/94 6 8142 7743 30 ICBM EQUAL BK-2 10/01/97 *PORTED BKP LATCH ON CIRC VALVE I 7-5/8' CSG, 29.7#, NT-95 HS X0 TO 13CR-80 H 8483* I-< I 8603° H4-1/2' OTIS X NIP, D = 3.87 I z ■MA 8664 7-5/8" X 4-117 BKR SABL-3 PKR, 13= 3.92' I II • 8698' 1-14-10 OTIS X MP, 13= 3.813' I I I 8764' H4-1/2" ORS XN NIP, 13 = 3.725' I 8754' H3.81" PXN FLUG (11/13/07) I 1 4-117 TBG,12.6#, 13CR-80, .0152 bpf, 13 = 3.958' H 8766' I- / 8766' H4-1/7 1ALEG, ID = 4.0' I I 8758' H ELMO 1T LOGGED 06/11/94 I PERFORATION SUMMARY REF LOG: WA/DIENTI3J ON 05/19/94 I ANGLE AT TOP PERF: 20° 1 1 , 90313' Note: Refer to Production DB for historical perf data SIZE SW INIITA/AL Opn/Sqz DATE I 3-3/8' 6 9030 - 9050 0 12/13/02 2-7/8' 6 9100 - 9116 0 09M1/02 I 2-7/8" 6 9117 - 9127 0 09/01/02 2-7/8" 6 9127 - 9147 0 08/19/01 3-3/8' 4 9147 - 9151 0 12/12/98 I 3-3/8" 6 9156 - 9163 0 05/12/97 3-3/8" 4 9282 - 9292 0 07/10/96 I 3-3/8" 4 9318 - 9338 0 06/11/94 411111r I 9345' I— FISH- (2) 5/8 SFRIGS (9/30/1997) FBID 9394' 1 *********4 ****40*** ,.........#4 I 7-5/8' CSG, 29.7#, 13CR-80, D = 6.875" H 9483' 100000 *00000 •••••••••• ••••••••••■ •••••••••• ID 95W .0.0.0.0.0.4 DATE REV BY CO/4MM DATE REV BY COMMENTS FRUDHOE BAY MIT 05/21194 ORIGINAL COMPLETION 05/15/12 SET/JNO SET VVFD WRP (05/12/12) MI: '11-35 10/26/01 MCP CORRECTIONS 05/27/12 PJC FERF CORRECTION FAT Pb: '1940650 02/11/07 RCT/PAG PULL PXN RUG rf 8754' API Pb: 50-029-22476-00 03/04/07 SFF/TLH TIP SET TO SECURE (2/28/07) SEC 28, T1 1N, R15E, 490.07' Fa & 2559.72' FNL 11/17/07 KDICIPJC PULL/ RESET PXN (11/13/07) 05/15/12 SWC/JNI) GLV C/O (05/12/12) 11 BP Exploration (Alaska) 4 )l ti it fi �' 1d K �„ y SEAN PARNELL, GOVERNOR C`y ' �d 1 `U ra �.JJ ,4 _ i i P, -- -, 7 ALASKA OIL AND GAS! 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Ross Huebel Petroleum Engineer BP Exploration (Alaska), Inc. PC/�— 0 65— P.O. Box 196612 YY Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 11 -35 Sundry Number: 312 -091 54 si r 4 Dear Mr. Huebel: h�A °�+�, rt Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerel 4 K. Norma om 'ssioner .0' DATED this day of March, 2012. Encl. nn� STATE OF ALASKA RECEIVED ,��3.t2C y A OIL AND GAS CONSERVATION COMMI OI� ! 01 3. 6 /.2 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon Plug for Redrill Perforate New Pool Repair Well ` '7 '`Cha A'�"titi'vet1.P. YP q ❑ 9 ❑ ❑ P ❑ pP dim IC - i Suspend ❑ Plug Perforations ❑ Perforate❑ Pull Tubing ❑ -, ` tom Extension ❑ d Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: SEAL -TITE `-' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 194 -0650 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 _ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22476 -00 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ PBU 11 -35 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028325 PRUDHOE BAY Field / PRUDHOE BAY Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9500 8975 9394 8876 8754 9345 Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" CONDUCTOR 30 110 30 110 Surface 3648' 10 -3/4" 45.5# NT -80 29 3677 29 3675 5210 2480 Production 9455' 7 -5/8" 29.7# NT -95 28 9483 28 8959 8180 5120 Liner Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# 13CR -80 30 110 1 _ _ Packers and SSSV Type: 4 -1/2" CAMCO BAL -0 Packers and SSSV MD and TVD (ft): 2119 2117 4 -1/2" BKR SABL -3 PKR 8664 8201 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program p BOP Sketch ❑ Exploratory ❑ Development ❑ Service El 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/16/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ El GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ross Huebel Printed Name Ross Huebel Title PE Signature 'Ir I e Phone Date ly�' "�. 564 -5779 3/2/2012 Prepared by Nita Summerhays 564 -4035 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 51 7.- 0 t 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1.1 0 Subsequent Form Required: 4 — 7 • 411/ 1 APPROVED BY _ ^' /� Approved by: CO MISSIONER THE COMMISSION Date: v (f FHSDM MAR 0 9 2012 Wiz � Mi' Form 10 -403 Revised 1/20.l O 1 I G I 1 I A M/70_. \% \ 1 V Submit in Duplicate 11 -35 194 -065 . PERF ATTACHMENT Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 11 -35 6/11/94 PER 9,318. 9,338. 8,804.92 8,823.58 11 -35 7/10/96 APF 9,282. 9,292. 8,771.38 8,780.69 11 -35 5/12/97 APF 9,156. 9,163. 8,654.11 8,660.62 11 -35 12/12/98 APF 9,147. 9,151. 8,645.74 8,649.46 11 -35 8/19/01 APF 9,127. 9,147. 8,627.13 8,645.74 11 -35 11/16/01 FIL 9,325. 9,394. 8,811.45 8,875.85 11 -35 9/1/02 APF 9,117. 9,127. 8,617.82 8,627.13 11 -35 9/1/02 APF 9,100. 9,116. 8,602.01 8,616.89 11 -35 12/13/02 APF 9,030. 9,043. 8,536.89 8,548.98 11 -35 12/13/02 APF 9,043.5 9,046.5 8,549.44 8,552.23 • 11 -35 12/13/02 APF 9,046.5 9,047. 8,552.23 8,552.7 11 -35 12/13/02 APF 9,047. 9,050. 8,552.7 8,555.49 11 -35 2/28/07 BPS 8,754. 8,755. 8,282.2 8,283.11 11 -35 11/12/07 BPP 8,754. 8,755. 8,282.2 8,283.11 11 -35 11/13/07 BPS 8,747. 8,755. 8,275.84 8,283.11 AB ABANDONED PER PERF APF ADD PERF RPF REPERF ' BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET 1 FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • WELLHEAD = FMC • SAO NOTES: ** *CHROM E CSG & TBG*** I ACTUATOR = BKR C 1 -3 5 KB.ELEV= 60' KOP = 4512' Max Angle = 31 @ 7276' Datum MD = 9379' 2119' H 4 -1/2" CAMCO BAL -O SSSV NIP, ID = 3.815" I Datum TVD = 8800' SS 10 -3/4" CSG, 45.5 #, NT -80, ID = 9.953" j—I 3677' 1 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3186 3184 0 KBMG BK -2 Minimum ID = 3.725" @ 8754' L 2 3988 398 0 KBMG BK -2 3 6365 6201 30 KBMG BK -2 4 -1/2" OTIS XN NIPPLE 4 7457 7148 30 KBMG BK -2 5 8036 7651 30 KBMG BK -2 6 8142 7743 30 KBMG BK -2 7 -5/8" CSG, 29.7 #, NT -95 HS XO TO 13CR -80 I—I 8483' I--->< ' , I 8603' H4-1/2" OTIS X NIP, ID = 3.82" I 8664' 1 - - 17 -5/8" X 4 -1/2" BKR SABL -3 PKR, ID = 3.92" ' 1 8698' H 4 -1 /2" OTIS X NIP, ID = 3.813" I ,lEil' I 8754' H 4 -1/2" OTIS XN NIP, ID = 3.725" I 8754' H3.81" PXN PLUG (11/13/07) I 14 -1/2" TBG,12.6 #, 13CR -80, .0152 bpf, ID = 3.958" H 8766' I-- / ' 8766' 1-14-1/2" WLEG, ID = 4.0" I I 8758' I I ELMD TT LOGGED 06/11/94 I PERFORATION SUMMARY I REF LOG: WA /DEN/NEU ON 05/19/94 ANGLE AT TOP PERF: 20 @ 9030' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 9030 - 9050 C 12/13/02 I 2 -7/8" 6 9100 - 9116 C 09/01/02 2 -7/8" 6 9117 - 9127 C 09/01/02 2 -7/8" 6 9127 - 9147 C 08/19/01 I 3 -3/8" 4 9147 - 9151 C 12/12/98 3 -3/8" 6 9156 - 9163 C 05/12/97 3 -3/8" 4 9282 - 9292 C 07/10/96 I 3 -3/8" 4 9318 - 9338 C 06/11/94 t 9345' - FISH- (2) 5/8 "X1- 1/16 "X4 "ARM SPRINGS IPBTD I—I 9394' 1 111N1N111 (9/30/1997) ,0********* 1 1 1 1 1 1 1 1 1 7 -5/8" CSG, 29.7 #, 13CR -80, ID = 6.875" J 9483' 1 10.0600 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 f 1 TD I — I 9500' ..1.1 x.1.1.1.1.1.1.4 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/21/94 ORIGINAL COMPLETION 10/27/05 DFR/PAG WELLHEAD/TREECORRECTIONS WELL: x 11 -35 10/26/01 RN/TP CORRECTIONS 02/11/07 RCT /PAG PULL PXN PLUG @ 8754' PERMIT No: x 1940650 09/01/02 CWS /KK ADPERF 03/04/07 SPF/TLH TTP SET TO SECURE (2/28/07) API No: 50- 029 - 22476 -00 10/24/02 GC/KAK PERF CORRECTION 11/17/07 KDC/PJC PULL / RESET PXN (11/13/07) SEC 28, T11 N, R15E, 490.07' FEL & 2559.72' FNL 12/13/02 CAO /KK ADPERF 09/23/05 MOR/TLH PXN TTP SET (09/03/05) BP Exploration (Alaska) • . bp • Date: 02/28/12 0 To: Jerry Bixby /Rob Liddelow, AK, D &C Wireline Operations Team Lead Clark Olsen/Tyler Norene, AK, D &C Well Services Team Lead Jerry Murphy /Mehreen Vazir, AK, Well Integrity Coordinator From: Ross Huebel, DS11 Pad Engineer, 907 - 564 -5779 office, 832 -455 -0275 cell Neil Carry, STI, 985 - 875 -1292 office Subject: 11 -35 Repair Tubing Leak using Seal -Tite Est. Cost: AFE: APBNRWOS IOR: 150 bopd Step Type Procedure 1 S Pull DGLV at Station #1 3186' MD and set circ sleeve. Set WRP at 3220' MD. 2 F Displace tubing and IA with diesel. Establish liquid level in tubing below 650'. 3 S Set WRP at 635' MD. 4 O/D Pump and activate sealant 5 D MIT -T to 2640 psi 6 SP Pull WRPs if repair is successful. Discuss with WIC requirements for pulling TTP and steps required to make and Operable well. Objective: This program is to repair multiple tubing leaks by lube and bleeding Seal -Tite into the tubing and sealing the leaks. If the repair is successful, the WIC will need to obtain an AA in order to use a MIT -T and CMIT -TxIA to establish dual barrier integrity so that a high differential pressure from the IA to the tubing that could potentially unseat the plugs won't occur. Well Stats: Well Status: SI and Not Operable for TxIA Last injection: 27,000 bwpd at 1100 psi on 1/21/2005 Deviation: max 31° @ 7276' MD Min ID: 3.725" @ 8754' XN Nipple Est BHP: -3350 psi @ 8800' TVD (2010 BHP map) SSSV: No Last H2S: NA (injector) Well Events Summary: 11 -35 is a shut -in SWI that has not seen injection since 2005 due to flowline troubles at DS11. The flowlines at DS11 were repaired and returned to service in 11/2011. In May of 2005, soon after the shut -in, the well had a passing MIT -T and MIT -IA. In October of 2009 the well failed an MIT -T and MIT -IA. A Tecwell LDL found collar leaks at 76', 120', 163', 208', 250', 379', and 639'. The LLR for all of these leak points together is only 0.46 gpm at 3000 psi. The well had another failing MIT -IA but a passing CMIT -TxIA on 11/15/11, confirming that the leak seen in the IA is only to the tubing. ,/ Please call Ross Huebel (At) at 564 -5779 or Neil Cary (Seal -Tite Engineer) at (985) 875 -1292 with any questions or concerns regarding this program. Cc: Well File AK, D &C Well Integrity Engineer • V� Discussion: • �` $6 • The IA was completed with 8.65 ppg inhibited seawater. The highest GLM (Sta. �� 1) will be used to circulate and displace fluids in the IA and tubing • Two WRPs will be used in this program. The top WRP will be directly below the bottom leak and will be used to stack out our sealant and brine pills. The bottom WRP will be set below the circulating gas lift mandrel. Its purpose is to stop most of the Seal -Tite from falling below our circulation point and ending up on the perforations. • Nitrogen will be used to displace the liquid level of the tubing down beneath the bottom leak point. Note that the top WRP will be set in gas and will be RIH with pressure on the tubing in order to prevent liquid from rising above the bottom leak point. • The initial displacement of tubing and annulus can be sent to the production system. The second displacement containing the Seal -Tite pills should only be circulated to a tank. Do not send Seal -Tite returns to the production system. Rig up notes and requirements: - Rig up hard line through a choke skid to pump down both the Tbg and IA taking returns down to a neighboring well's flowline or contingency tank. Make sure there is a sample port in the choke skid to confirm return densities. Make sure there is a strap sheet for the contingency tank. The nearest well is 11 -25, a shut -in producer. If returns are sent down the production line, ensure that it is kept freeze protected. - Have a mud scale available for density measurements. - Because the Seal -Tite must be injected into the tubing by the lube and bleed method, a diaphragm pump must be used. Be sure that this equipment is available and operational on the slope before beginning this work. Work with the STI representative to make sure the equipment spec is correct. - The sealant is freezable fluid. The special projects trailer will be needed for maintaining temperature and mixing the sealant pills. - Heaters for the well house and projects trailer. - Air compressor for the pumps. - Bleed trailer. - Flowback tank for Seal -Tite returns Volumes: Note — all volumes /depths below are corrected for RKB /BH elevation difference of 26' (K.B. 60.2' and G.L. 34.3'). As such all depths are denoted "MDBH" (Measured Depth to Bradenhead) Total IA volume — 7 -5/8" x 4 -W to Production Packer @ 8638' MDBH (8754' MD) = 226.3 bbls Tubing Volume To Bottom Leak @ 613' MDBH (639' MD)= 9.3 bbls Tubing VolumeTo Highest Gas Lift Mandrel @ 3160' MDBH (3186' MD)= 48 bbls Annulus Volume To Highest Gas Lift Mandrel @ 3160' MDBH (3186' MD) = 83.5 bbls Tubing Volume 4'/2" (to PXN plug) at 8728' MDBH (8754' MD)= 132.7 bbls Leak Depths: Tubing Leaks at 76', 120', 163', 208', 250', 379', and 639' MD Tubing Leaks at 50', 94', 137', 182', 224', 353', and 613' MDBH Fluid requirements: - 350 bbls Diesel • • - 1 bbls 9.8 ppg NaCI for sealant mixing (Flo -Seal blended with this brine gives a 9.9 ppg sealant) - 5 bbls 9.3 ppg NaCI for sealant mixing (Flo -Seal blended with this brine gives a 9.5 ppg sealant) - 3 bbls 9.75 ppg brine - 10 bbls neat McOH Procedure: Slickline: Change Out GLV and Set Bottom WRP 1. Hold PJSM. RU slickline. 2. RIH w/ memory GR /CCL. Create tie -in log and flag wire as necessary for accurate depth control. • Tie into reference log Nov 7, 2009 PDS LDL. Bottom leak is at 639' MD at a collar. The WRP directly below this is the most critical for depth control. • Suggested flag methods are to do a 5 minute stop at 700' with a corresponding flag and tie into collars. Or tag up on SSSV nipple at 2119' and flag. 3. Pull DGLVs from Sta# 1. Set circ sleeve in Sta #1. 4. Set WRP at 3210' MD (3184' MDBH), directly below Sta #1 at 3186' MD (3160' MDBH) and tubing collar at 3200' MD (3174' MDBH). 5. Pump with triplex (or FB) to establish both TxIA and IAxT circulation. Fullbore and Projects: Circulate Well Out with Diesel 6. Hold PJSM. RU FB pump to the choke skid. 7. Line up to pump down tubing, taking returns up the IA to nearby flowline of 11 -25. Leave -200 psi of back pressure on the annulus during circulation to make sure the system remains liquid packed. 8. Circulate a total of 150 bbls of diesel down the tubing taking returns up the At 131.5 bbls (one round trip volume), the IA & Tbg sTiou d be u y isp aced. Ensure returns are clean diesel. Maintain maximum pump rate as per PE manual. 9. Line up to pump nitrogen down the tubing taking returns up the IA. Displace diesel down tubing and out of IA until liquid level in tubing is below 700'. This will take approximately 1 mscf of N2. Displaced liquid volume will be -10.5 bbls. • Note: As the warm nitrogen volume cools in the permafrost, the volume will shrink. Overdisplacement may be necessary. • Note: Confirm liquid level is below 700' with echometer shot before SL installs second WRP. • Note: Once N2 enters the tubing, it will become underbalanced compared to the annulus. Once the displacement is complete, the tubing will have approximately 250 psi more than the IA. This pressure must not be bled off or the liquid level will rise. • Slickilne: Set Top WRI' 10. RU SL. Maintain constant tubing pressure. Use echometer to confirm liquid level is below 700'. 11. Set WRP in N2 column at 645' MD (619' MDBH), directly below bottom leak. 12. If Seal -Tite is not immediately ready to pump, pressure test to 1000# with N2 for at least 30 minutes. RDMO. Fullbore and Projects: Lube and Bleed Sealant and Pills, then Activate Sealant 13. Blend one bbl of Flo-Seal to 9.9 ppg (Flo -Seal SS concentrate blended with 9.8 ppg brine). 14. Use diaphragm pump to lube and bleed one bbl of 9.9 ppg Flo-Seal into the tubing. Allow 30 minutes for sealant to fall and settle on top of the WRP. 15. Lube and Bleed in 2.8 bbls of 9.75 ppg NaCI into tubing. AIIow 30 minutes for brine to fall and settle on top of bottom Seal -Tite pill. 16. Use diaphragm pump to lube and bleed 4.5 bbls 9.5 ppg Flo-Seal into tubing. • Note that the expected liquid column height is now expected to be at 65' MDBH, which is below the top leak. The top leak is suspected to be the most minor. Flo-Seal has a freeze point of 10F and bringing it up higher could put the well at risk for freezing. 17. Use diaphragm pump to lube and bleed 1 bbl neat McOH into the tubing to freeze protect the tree. 18. Use neat McOH to pressure the tubing up to 2000 psi to cure the sealant. Monitor pressures every 15 min and repressure every 30 min until the leak rate begins to decrease. Once there are indications that the sealant begun working and pressure is holding steady, bleed the IA back to 1000 psi. • Note: Keep close track of annulus pressure and bleed them off so that they never go over 500 psi. The leak off in the tubing will be going into the fixed IA volume. 19. Shut down pump and allow a seal to be obtained at 1000 psi. Let the sealant cure for a minimum of four hours. 20. Increase IA pressure to 1500 psi. AIIow to cure for two hours. 21. Increase IA pressure to 2000 psi. AIIow to cure for two hours. 22. Increase IA pressure to 3000 psi. 23. Shut in the IA and allow the sealant to cure for 5 days. Monitor pressure daily and bump back up if the pressure falls below 2000 psi. 24. RDMO FB pump. • Slickline and Fullbore :hange out GLVs and MIT -T 25. RU SL. 26. Pull top WRP. NOTE: At this point the IA is underbalanced to the tubing by —100 psi, and this will be the dP across the plug. 27. Circulate 150 bbls diesel down tubing and up IA taking returns to a tank. • Note: Do not send returns to the production system. Only take them to a tank to be disposed of. 28. Pull Circ Sleeve from Sta #1 and set DGLV. 29. Pull bottom WRP. 30. RDMO SL & FB pump. 31. Notify WIC of well's status. Likely next step is to conduct an MIT -T and CMIT -TxIA to prove two barriers. • T ' R E M = a t v S A F E T Y NOT E S : — c IM ECSG & T O "' WB_LI-EA D a FMC ACT roR = Blai CI 1 1 - Ka e_ei = 60' BF ELEV = 45'2 211W H4_ ,.,,-2. (A moo aA L-o sssv NP, C b' 1 Dal. T1 I& - 931g 1 Dal.. •ri rVD = 8Y.X.7 SS . II A 1 1 ' e.)- r... 4 5.:3g, NT-80, D - 9.9631 hi 3677' G S LIFE MA NS S r MD IV D De: TY PE V LV LA I (.I-1 FORT DA rE ' 3' 86 3'84 0 KBMG BK-2 Minimum ID = 3.725" @ 8754' 2 Y16. '3986 0 K.BMG BK-2 3 (r.;36 620' 30 KBIX3 BK-2 4-1/2" OTIS XN NIPPLE 4 '4.5/ r 4 8 O KBMG BK-2 5 80* /65 • 30 KB/Ki BK-2 6 8' 42 //4 X'.) KB/X.3 BK-2 I !--5;8-",..... 29' 1 sr , NT•95 HS XO TIL) 13C R-80 H 8483' 1 I 8603' I-14- • .7 OTIS X NP, ID a- 3.6e I " leil 8664' f - bor X 4-'..2 BKR SA BL-3 MR, ID a 397 I II 8688' H4-'1? OTIS x NP, ID = 3.8' 3 ' I I 11 II 8754' H-' OTIS XN NP, ID 8754' H 3.8" PxN 1 4- ' . / . 2 " T L ., '2.6*, 13C R-80, .0' '.:,2 DrA, ID 3.9e H 8766' I-- 8766' H4-' re 'eV LEG, ID = 4 .(j* I L 8758' 11 ELMO T T LOGE: 06' "..94 I 1 YON SU/AWRY ' Ra LOS. WADENt NBJ ON 05/ ' 9 I A NGLE A T TOF'1 20 4 g030' No*. kW er t. f *a: ur.rto" DEl to . , .eloecai D e1 ra ta SIZE SPF /*FIERY A L 4..)D^/S.:2 DAM -j 2-1.03" 6 9' rf.') - I 248" 6 9" / - 9'2/ L. USISJ',02 6 9'21 - 9' 41 ',_• 3- Mi." 4 9' 4/ - 2.4' 298 6 9' 56 - 9'6'3 3- 'At.' 4 9262 - 9292 L. 0 /," 096 I 3.• 4 93'8 - 9S.36 L. OW" .94 41111r 9345' F ISI-1- I2) 5.‘8"X' - ,''' 6' X4"ARM SPREGS I91310' ' 99 t) UM 9394• '9 • till 't VP , IVIP 1 04 00044•04$101 11.44446.414 , ....0•04110.4 1 I L'G, 2.9. Ilt, 13C R ID a 6.8/5' %tax 1111.044.0.11 41.0.00.141 44.11.0.41.1.4 , II #0.11 4 1.$ • I 4 i TD 9500' DAM REV BY COMBATS DA TE REV BY ocovivEnrrs PRUDHOE BAY UNIT 05021P54 ORM NA L COM PL ET ION • 0;2 /,.05 DFRPAG VY ELL1-1EA D/TREE CORRECTORS WBI P • -15 • 0 RIIWIT' CORRECTIONS LIZ " . RCT PAC; MILL MN PLUG , ,caP 8f PEWIT No, 940BW OB. 0' .1)2 CWS KK A DIE** c3:04;or SPE. 11H M'' SET TO s20/) AF No. 50-029-224 /6- 00 0'2402 V.A K PER' OURREC TEN ": ' /FO/ KIX:: RIC PULL ) RESET MN I ' • ;" 3/0/ ) SEC 28, 1' 'N, R'56, 490.0r FEL& 265932' z (2 CA.O.KK A DPERF , Y.1 , 23e05 MORTLH PXN T FP SET i OW 0 3.05) BP Exploration (Alaska ' • • r eel Qt o Q LEAK DETECTION - WLD $ * S te ° ` { Up Main � 1-. V XTU•HTU -CCL- TEMP-UVLD Ar 4 rxa4 ., o1. .. c s .e. �, 07-Nov-09 Pe A i Y Tbg = 100 psi Company BP EXPLORATION (ALASKA), INC *wow. 0..„...0... 5,.n,... Y 11 - 35 �Wep f lalabaee File. d 'mrarrior'r�ata'i11 -35'r 11 -35 < 3.db ' Field PRUDHOE BAY Owaset Pethr+,a me pa County NORTH SLOPE State ALASKA Presentation Format: wid_log 3 8. ,, _ o m -2 Surface Location Ogler Services daaaset Creation: Sat Nov 07 12:15 :15 2009 by Log Sande o � + Charted by f3epiht in f eel *Wed 1 1200 v 1, 490.07' FEL & 2.559,72' FNL i None n_ a z a SEC: 28 T 11N RGE: 15E ............ -. - ... 60 6000 CCL '• Elevation 00 CCL - 646 e o eermareen?Dat MSL Elevat B. BD.0 - - — _ top Measured From RK8 SO 0 F Ab P erm . Datum 00 K Ntn 0 ine Speed I.K' 't i -200 0 l 3 . LL aal s«(a Number 50.026 00 GL p,F N/A Dat ._ at Nov 09 ,. _.. .._._ '�„ I Run Number 0 Head Tension (lb) 200 0 1 PBTDDnller i 9.394' ._._.._._._._.. _._.._._.- .— ._..— ...- •... -..._, PBTOLogger ...... hot Taaaed _- 0 Temperature;degFi 200 20 BoOemLOggetl ( — 875; T oo Lon Mlervei .... Surface .. , ,. , 3 Type . Open Male Sae -1. ._.. NIA _.._. _�..._. Fled Produced )Tu:ds ' Max Recorded Temp. (deg F) 166 2 .. _... y TuneWN'I Read Oe OD FINAL PRINT __ Time Logger on Bottom 12.18 _ - _.... .. _ Equipment Number SLB EL 12128 Location North h ope _.... Smvw^e /neeice No _ 963 Recordee By i S Carpente• K MIer ' 4YAneeeed Bar �a�iea R Dosser. .._...,.....T.,,.�._ __. _ - _...___ Borehole Record 7,,b,ng Record .._. ... __ -_ R un N I B [ _ _ To Sae LB t Ft F re To i 47 260 S u face 8. i tp . , ..:. A. _ / .. IVY Case Record Sae'__– ! 12(3 % Tc orn __. $refute Befog Strwj 10 371' - Sw'a ac _ 3577' Liner 7518' Su (Liner • • 200 t —``—,-,— _ ._ Leak Signature . = vit. — - -: . • Leak Signature r CCL 300 • Line Speed . Head Tension . Leak Signature ' 400 Temperature Temperature 500 .. ' ' .. j ! Dlferenliel Tertl er ttitre --+I ,, �� ". ` �'-- -, Leak Signature I , .. �.. _. , _......, . .... ..... , , 7ftin – m . ... A • • • Fisher, Samantha J (DOA) From: Foerster, Catherine P (DOA) Sent: Thursday, March 08, 2012 11:47 AM To: Fisher, Samantha J (DOA) Subject: Re: PBU 11 -35 Approve Sent from my iPhone On Mar 8, 2012, at 12:52 PM, "Fisher, Samantha J (DOA)" <samantha.fisher @alaska.gov> wrote: > Please approve. > Thank you, > Samantha Fisher, Executive Secretary II > Alaska Oil and Gas Conservation Commission > (907) 793 -1223 > <S45C- 212030809433.pdf> 1 s • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 a Anchorage, Alaska 99519 -6612 (f &s- December 21, 2010 ,! / _ S. k A NE[3 . I q " Mr. Tom Maunder `"``'' Alaska Oil and Gas Conservation Commission JAN fl 3 ?ill 333 West 7 Avenue Anchorage, Alaska 99501 yuo.,t1 n;f l r rg , " ° Sion Subject: Corrosion Inhibitor Treatments of GPB DS 11 °o Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 11 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to•atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator . • 1 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -11 . Date: 12/21/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor / Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na pal 11 -01A 1921120 50029206440100 NA Sealed NA NA 6/25/2010 11 -02 1811280 50029206490000 NA Sealed NA NA 6/25/2010 11 -03A 1911520 50029206660100 NA Sealed NA NA 6/25/2010 11-04A 1940230 50029204800100 NA Sealed NA NA 6/25/2010 11 -05A 1961570 50029206700100 NA _ Sealed NA NA 6/25/2010 11 -06A 2042250 50029206740100 NA Sealed NA NA 6/25/2010 11 -07 1811770 50029206877000 NA Sealed NA NA 6/25/2010 11 -08 1842290 50029212450000 NA Sealed NA NA 6/27/2010 11 -09A 1961280 50029214020100 NA 25 NA 42.50 6/29/2010 11 -10 1851590 50029213940000 NA 5 NA 28.90 6/30/2010 11 -11 1851410 50029213820000 NA Sealed NA NA 6/27/2010 11 -12 1841950 50029212120000 NA Sealed NA NA 9/12/2010 11 -13A 1921100 50029212290100 NA Sealed NA NA 9/12/2010 11 -16 1860780 50029215817000 NA Sealed NA NA 6/27/2010 11 -17A 2020320 50029215980100 NA Sealed NA NA 6/27/2010 11 -18 1861120 50029216070000 NA Sealed NA NA 6/27/2010 11 -22A 1950870 50029220356000 NA 1 NA 9.35 7/1/2010 11 -23A 1940810 50029216100100 NA Sealed NA NA 7/1/2010 11 -24A 1932040 50029216230100 NA Sealed NA NA 6/26/2010 11 -25A 1990820 50029204880200 NA Sealed NA NA 6/26/2010 11 -26 1861340 50029216280000 NA 1.9 NA 5.10 6/28/2010 11 -27 1861480 50029216380000 NA 3.5 NA 11.90 6/28/2010 11 -28A 2000950 50029219580100 NA Sealed NA NA 6/28/2010 11 -29 1940250 50029224660000 NA _ 0.2 NA 1.70 6/28/2010 11 -31A 1961830 50029225090100 NA 1.4 NA 6.80 6/28/2010 11 -32 1941310 50029225120000 NA 6.7 NA 59.50 6/30/2010 11 -33 1940900 50029224900000 NA 0.5 NA 2.55 6/30/2010 11 - 34 1941380 50029225160000 NA 0.5 NA 3.40 11/27/2009 11-35 1940650 50029224760000 NA 0.6 NA d.10 6/30/2010 11 -37 1961740 50029227160000 NA 4 NA 42.50 7/1/2010 11 -38A 1982160 50029227230100 NA 2.1 NA 22.10 6/28/2010 II • • ~~p~~ 0~ p~p~~{p /.E..aa~oo~a~. ADMINISTRATIVE APPROVAL NO. AIO 4E.013 Mr. Steve Rossberg, Wells Manager Attention: Well Integrity Engineer, PRB-20 r .;ti BP Ex loration Alaska Inc. ~ `' ~"`~' ~~-~~ ~~ P.O. Box 196612 '"'Y Anchorage, AK 99519-6612 RE: Cancellation of Administrative Approval AIO 4E.013 (Well PBU 11-35) Dear Mr. Rossberg: Pursuant to BP Exploration (Alaska) Inc. (BPXA)'s request dated March 17, 2010, the Alaska Oil and Gas Conservation Commission (Commission) hereby cancels Administrative Approval AIO 4E.013, which allows continued water injection in Prudhoe Bay Unit ("PBU") well 11-35. This well exhibited tubing by inner annulus communication and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. Although authorized to operate the well, fluids have not been injected since September, 2005. Following surface injection line repairs last year, the well failed a MITIA on October 27, 2009 and was secured. BPXA has determined to not operate PBU 11-35 until repaired. Consequently, Administrative Approval AIO 4E.013 no longer applies to operation of this well. Instead, injection into PBU 11-35 will be governed by provisions of the underlying AIO No. 4E. DONE at Anchorage, Alaska and dated Ap~i126, 2010. The Alaska Oiler '~ A Commission l nount, Jr. Orman. ath . F erster Chair Com 's ' ner Co missioner ~. :~ ~~ ~ E „~ : ati, • BP Explocatlon (Alaska} Inc. Attn: Weil Integrity Coordinator, PRB-20 Post Office Box 198612 Anchorage, Alaska 99519-8812 March 17, 2010 • aPR ~ ~ 20~o by Masks Oil ~ Oas C,as+s. Commissinr Anc~~arage Mr. Daniel Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit well 11-35 (PTD #1940650) Application for Cancellation of Administrative Approval 4E.013 Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests cancellation of Administrative Approval number 4E.013 dated January 30, 2007. The administrative approval was for continued water injection into well 11-35 with slow T x IA communication. The well was originally shut-in .for injection line repairs. In preparation for returning the well to injection, the well failed a MITIA on October 27, 2009. The well is secured with a downhole mechanical plug and is being evaluated for repair options. Therefore it is requested to cancel the Administrative Approval for continued operations. A plot of wellhead pressures has been included for reference. tf you require any additional information, please contact me at 564-5637 or Anna Dube / Torin Roschinger at 659-5102. Sincerely, R. Steven Rossberg '`~ BPXA, Wells Manager • Attachments: TIO Plot Cc: Bixby/Olsen Dube/Roschinger East Area Manager Bob Chivvis Harry Engel 11-35 (PTD #1940650) TIO~ot w~ ~,.~ <040 3,000 2,000 tp00 - ~- Tbq -f-- IA ~ OA OOA ~- OOOA ~~ On AOGCC MITIA Forms: 01-25 (1030), 01-30 (1861110), 11-35 (19406516-02 (18... Page 1 of 1 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, November 02 2009 1026 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: NSU, ADW Well Integrity Engineer Subject: AOGCC MITIA Forms: 01-25 (1822030), 01-30 (1861110), 11-35 (1940650), 16-02 (1801500), P1-16 (1930340), L-105 (2020580) Attachments: MIT PBU 01-25, 01-30 10-29-09.x1s; MIT PBU 11-35 10-27-09.x1s; MIT PBU 16-02 10-25- 09.x1s; MIT GPMA P1-16 10-25-09.x1s; MIT PBU L-105 10-30-09.x1s Hi Tom, Jim, and Phoebe, Here are AOGCC MITIA forms for the following wells: 01-25 (PTD #1822030) 01-30 PTD #1861110) 11-35 (PTD#1940650) 16-02 (PTD#1801500) P1-16 (PTD#1930340) L-105 (PTD#2020580) 4-yr UIC MITIA post RWO MITIA post initial injection Pre-AOGCC failed ~-- MITIA for AA 4E.014 Compliance 4-yr UIC MITIA MITIA and LLR-OA for AA 24.004 Compliance «MIT PBU 01-25, 01-30 10-29-09.x1s» «MIT PBU 11-35 10-27-09.x1s» «MIT PBU 16-02 10-25-09.x1s» «MIT GPMA P1-16 10-25-09.x1s» «MIT-PBU L-105 10-30-09.x1s» Please let us know if you have any questions. Thank you, Anna ~Du6e, ~ ~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~ s ~ ~ . ~~ {~~'~ ,,fib ~~r' "`~ ~, ~~1~~; S fir... 4/26/2010 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; tom.maunder~alaska.gov;bob.fieckenstein~al~ka.gov;doa.aogcc.prudhce.bay~alaska.gov OPERATOR: FIELD /UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: BP F~cploration {Alaska}, Inc. Prudhoe Bay /PBU / DS 11 1027/09 Anna Dube Packer Pretest Initial 15 Min. 30 Min. Well 11-35 T In'. N TVD 8,201' Tubi 440 440 480 510 Interval 4 P.T.D. 1940650 T test P Test 2050 Cali 440 2,500 2,350 2,220 P/F F Notes: Pre-AOGCC MITIA failed OA 340 450 450 450 LLR-IA of 0.5 mat 2500 i Well T In'. TVD Tubi Interval P.T.D. T test Test P/F Notes: OA Well T In . TVD Tubi Interval P.T.D. T test Test P/F Notes: OA Well T In . TVD T Interval P.T.D. T test Test C P/F Notes: OA Well T In'. TVD Tubi Interval P.T.D. T test Test C P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I = Infial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A = Temperature Anornaiy Survey T =Test during Workover W =Water D = DilFererrtiai Temperature Test. O =Other (describe in notes} MIT Report Form BFL 11/27!07 MIT PBU 113510-27-09.x1s .-_I~. PROACTIVE DIAgNOS11C SERVICES ANC. I/IfL~LL LC? T~A~~/T`T:4 To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 [907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ~ _ _ 8P Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ~.,~~~ ~E~ ~ ~ ZnD9 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 P~~--_ Fax: (907) 245-8952 ~ f ~ ~ _ ©~ 1) Leak Detection - WLD 04-Nov 09 1 1-35 2) Signed Print Name: 1 BL / EDE 50-029-22476-00 Date : _ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 w. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL _.i.= ,~~;'a i ~ ;~;fi _ _ __ wEBSITE: ~.-.~ ~_ ~i'i; C'~Doci¢nents and Settings\lliane Witliams',Desktop~Ttan nut_BP.docx Monthly Injection Report for GPB~PMA, Northstar, Milne Point & Endicott for October 204? Page 1 of 2 Re , James B DOA • 99 ( ) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj Sent: Sunday, November 11, 2007 3:15 PM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer; Engel, Harry R; Holt, Ryan P (ASRC) Subject: RE: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for October 2007 Jim, It does appear that the TTP is leaking. The TIOs were 108011090!290 psi on 11110{07 and the flowline is blinded. Our plan forward is as follows: 1. S: Pull and reset TTP 2. F: MITT to 3000 psi 3. D: Bleed IAP Please call with any questions or concerns. Thank you, Andrea Hughes ~~~,~~~ ~1CV ~. 2007 From: Regg, lames B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, November 08, 2007 4:51 PM To: NSU, ADW Well Integrity Engineer Subject: RE: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for October 2007 PBU 11-35 shows IA pressure increasing linearly with well SI. I found a note from Feb 25, 2007 that indicates the well is shut in pending repairs to injection line. Any thoughts on the reason far increasing IA pressure tracking tubing pressure (TTP leaking)? Jim Regg AOGCC 333 W.7th Avenue, Suite 10fl Anchorage; AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Sunday, November 04, 2007 7:58 PM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: GPB, Area Mgr Central (GC1/3/FS3); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, Area Mgr North (Gas Plants/GPMA); GPB, Area Mgr West (GC2/WRD); GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, GC1 OTL; GPB, GCi Wellpad Lead; GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, GC3 OTL; GPB, GC3 Wellpad Lead; GPB, GPMA OTL; GPB, LPC DS Ops Lead; GPB, Ops Supt; Kurz, John;. MPU, Area Manager; MPU, Field Lead Tech; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Wells Ops Coord2; Nstar, Lead Tech; Nstar, OIM/Area Manager; Nstar, Ops Team Leader Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for October 2007 Hello Jim & Tom, 11/13/2007 Monthly Injection Report for GPPMA, Northstar, Milne Point & Endicott for October 2007 Page 2 of 2 Attached is the October 2007 Injecti eport for GPB, GPMA, Northstar, Milne and Endicott injectors operating under a Sundry or Administrative Approval. «AOGCC Inj Report 10-07.zip» Notes on the wells: 04-42: Internal waiver cancelled. Sundry #302-059 cancellation in progress. Decided to cancel approval and repair well by RWO. 13-25: AOGCC witnessed CMIT-TxIA Passed to 2500 psi for AA compliance on 10/28/07. 13-32A: AOGCC witnessed CMIT-TxIA Passed to 2500 psi for AA compliance on 10/28/07. NGI-02: TIO plot confirms that resetting the SSSV mitigated the IA repressurization. Well will be removed from this report. NGI-05: TIO plot confirms that resetting the SSSV mitigated the IA repressurization. Well will be removed from this report. S-11 B: AA cancellation in progress due to failed MITIA. A LDL is planned to evaluate repair options. X-20A: AA cancellation in progress due to CTD+ RWO restored tubing integrity. Well will be removed from this report. 11/13/2007 11-35 (PTD #1940650) High Tubing & lAP Pressure . . }s' \01 !JM; 4£.013 Jim, ~ An AA was recently approved for 11-35 (PTD #1940650) for TxlA communication. The tubing tail plug was pulled in preparation for return to injection. However, the well can not return to injection until repairs are complete on the injection line. With the TIP out of hole, gas has swapped out with the well bore fluids causing high tubing pressure and therefore high IA pressure. Current WHPs are 2450/2450/250. Once on water injection, this gas will be swept from the near well bore reducing wellhead pressures. Until then, a TIP is being reset. This communication is to notify you of the high pressures and of the plan forward. If you have any questions, please don't hesitate to call. Thank you, }f.nna CDu6e œ. f£. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 , .". " ... . . ..-, .-.". SCANNED MAR 2 7 2007 . -'-"'_r·}:."..... I of I 3/5/2007 12:34 PM • • ~ ~ li~ ~~~ ~~ ~,~~ ,, ~-~f 1 ` SARAH PAL/N, GOVERNOR ~5~~ oIIj ~D ~i~s (~t` 333 W. 7th AVENUE, SUITE 100 co1~TSERV~TIOIIT col-II~IISSIOIIT J PHONE 907)279-14339$01-3539 f FAX (907) 276-7542 ADNIINISTRATIVE APPROVAL AIO 4E.013 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 :~1~~ JAN 4 ~ 2008 RE: PBU 11-35 (PTD 1940650) Request for Administrative Approval Dear Mr. Rossberg: In accordance with Rule 9 of Area Injection Order ("AIO") 04E.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. PBU 11-35 exhibits slow T x IA pressure communication when operating. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU 11-35. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, PBU 11-35 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection in PBU 11-35 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and in}ection rates; 3. BPXA shall perform anMIT-IA every 2 years to 1.2 times the maximum anticipated well pressure; 4. BPXA shall limit the well's IA pressure to 2000 psi; 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; • AIO 4E.013 January 30, 2007 Page 2 of 2 • 6. after well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection, and 7. The MIT anniversary date is December 14, 2006. Please note that PBU 11-35's status remains 1 WINJ. 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. DONE at Anchorage, Alaska and dated January 30, 2007. ;ass; Cathy P Foerster Commissioner ,~N RE: PBU 11-35 (PTD 1940650) . . Jim - Here's a test form for the MITIA pn 11-35 from 12-14-06: Thank you - Jack L. Winslow Well Integrity Engineer office - 659-5102 pager - 659-5100, ext. 1154 SCANNED FEB 0 7 2007 -----Original Message----- From: James Regg [~~.:!:_1__!:..()_:j_~_TI1-£~9.9~adJ~in. !?!_~_t:~._:_~_~__:~~~] Sent: Wednesday, January 24, 2007 5:04 PM To: NSU, ADW Well Integrity Engineer Subject: PBU 11-35 (PTD 1940650) Received admin approval for this well; you reference an MITIA done on 12/14/06; we do not have a record of that test (last MIT in our files was 2/24/2005) In the future, it would be helpful if you would include a copy of the MITs that are part of the barrier eval submitted in the AA request. Thank you. Jim Regg AOGCC Content-Description: MIT PBU 11-35 12-14-06.xls MIT PBU 11-35 12-14-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 1/29/2007 11 :23 AM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ( ~ \ r; 1 Mechanical Integrity Test ~tet1 vD Ernail to: Winton Aubert@adrnin.state.ak.us; Bob Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_MaUn~r@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / OS 11 12/14/06 Anna Oube Packer Depth Pretest Initial 15 Min. 30 Min. WellI11-35 I Type Inj. I W TVD I 8,473' Tubing 1,1501 1,1501 1,1501 1,150 lnterval 0 P.T.D.11940650 I Type test 1 P Test psil 3000 Casing 1,0001 3,0001 2,9001 2,8801 P/F P Notes: MIT/A for AA OAJ 5501 5501 5501 5501 Well' I Type Inj. I I TVD I Tubing Interval) P.T.D.' ) Type test 1 J Test psi Casing P/F Notes: OA Weill I Type Inj.' I TVD , Tubing Interval P.T.D.I I Typetestl 1 Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval P.T.D.I I Typetestl I Test psi! Casing P/FI Notes: OA I Weill I Type InU 1 TVD I Tubing Interval! P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1105 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o " Other (describe in notes) MIT PBU 11-3512-14-06.xls /' 11-35 (PTD #1940650) Classified as Problem HJ:Jll ) 'Kd{q q( Z(05 Subject: 11-35 (PTD #1940650) Classified as Problem Well From: "Anders, Joe L" <anders22@BP.com> Date: Tue, 23 Aug 2005 05 :20:45 -0800 To: "Harris, Marvin L (ConocoPhillips)" <Marvin.Harris@BP.com>, "GPB, FS2/COTU. Area Mgr" <GPBFS2TL@BP.com>, "Rossberg,R Steven" <RossbeRS@BP.com>, "NSU, ADWWell Op~rations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>,..','GPB, Wells Opt Eng" <QPBWellsOptEng@BP.com>, "AOGCC Jim Regg (E-mailY.<jim_regg@admin.state.ak.us>. "AþGCC Winton Aubert (E-mail)..<wìnton_aubert@admin.state.ak.us>.··NSU. ADW WL & , Gompletion Supervi~or" <NSUADWWL&CompletionSupervisor@BP.com>, "GPB, FS2 DS Ops L~ad" <GPBFS2DSOpsLead@BP .com~, "OPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "Gj>B, Ops Mgr" ..<::GPBOpsMgr@BP ~com>" Engel~@BP .com C¢:"NSU, ADWWell· Integrity Engineer" <NSUADWW el1lntegrityEngineer@BP~com>,.. "Mielke, RQbert L." <robert.mieIke@BP.com>, "Hughes, Andrea (VECG)" <hugl1a4@BP.com>,"Holt, Ryan P (V)3CO)"<Ryan.Ho1t@BP.com> All, Injection well 11-35 (PTO #1940650) has been identified with IA pressure> 2000 psi and has been classified as a Problem well. TIO's on 08/19/05 were 2450/2450/0, the well is currently shut-in. The well /'" exhibited recent indications of slow TxlA comm and activities to pursue a AA are in progress. However, v the IA pressure has increased over 2000 psi, resulting in this notice and reclassification of the well status. The plan forward is as follows: 1. FB: MITIA 2. WIE: Eval next steps A wellbore schematic is attached. Please call if you have any questions. «11-35.pdf» Thanks, Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.eom ". .' ') fì r\\~¡ "'....,,.', .. ',. '"~_.~-" ('.EP Î:, .L (_uu~ ;,)If'!~N~~t,~., ..) Content-Description: 11-35.pdf 11-35.pdf Content-Type: application/octet-stream Content-Encoding: base64 SCP ~'LAtP t J./iJ 'i P .- .- ~ 'l45Vp~ ; 2>, ßo¡s: 30 (~ OA Opsi Åe~~vl -4v ~'-t+(1 tl, I "f'c.\w I~--"f.¡ r2ffl\} pz; f\XJ 4 c. JK~1q 1lqlo~ 1 of 1 9/2/2005 9:27 AM ) ) TREE == WB..LHEA D = ACfiJ6:tÖ¡:f;" KB. ELE\! == 'ifF...·ELËV..·;... . 'kóÞ;" . ,~~..-L\:.~.~..~ :. Datum MD = Datum TVD = FMC CIW ··..····..··...i3kFfc 60' 11-35 SAFEfY NOlES: CHROME CASING AND TUBING ·...·····45·12' ........~~....~..????..' 9379' 8800' SS - 2119' H4-1/2" CA~O BAL-O SSSV NIP, 10 = 3.815" 110-3/4" CSG, 45.5#, NT-80, 10 = 9.953" 1--4 3677 ~ ~ GAS LlFTMANDR8.S ST MD TVD DE\! lY PE VL V LATCH R) RT D4. lE 1 3186 3184 .05 KBMG BK-2 2 3988 3986 .03 KBMG BK-2 3 6365 6201 30 KBMG BK-2 4 7457 7148 30 KBMG BK-2 5 8036 7651 30 KBMG BK-2 6 8142 7743 30 KBMG BK-2 Minimum 10 = 3.725" @ 8754' 4-1/2" OTIS XN NIPPLE L 17-5/8" CSG, 29.7#, NT-95 HS, 10 = 6.875" 1-1 8483' , / ITOPOF7-5/8" CSG 1-1 8483' I 8603' 1-14-1/2" OTIS X NIP, 10 = 3.82" 1 g ¿S 8664' 1--\7-5/8" x 4-1/2" BAKER SABL-3 PKR, 10= 3.92" ~ 8698' 1-l4-1/2" OTIS X NIP, 10 = 3.813" 1 8754' 1-i4-1/2" OTIS XN NP, 10 = 3.725" 1 14-1/2"TBG,12.6#, 13-CR-80, 0.0152 bpf, 10=3.958" 1-1 8766' l--¡ 8766' 1-i4-1/2" WLEG, 10 = 4.0" 1 8758' 1-1 ELMO IT LOGGED 06/11/94 1 PERFORATION SUrvTv1ARY REF LOG: WAIDI3\I/NEU ON 05/19/94 ANGLE AT TOP PERF: 20 @ 9030' Note: Refer to Production DB for historical perf data SIZE SPF NTERVAL Opn/Sqz DAlE 3-3/8" 6 9030 - 9050 0 12/13/02 2-7/8" 6 9100-9116 0 09/01/02 2-7/8" 6 9117-9127 0 09/01/02 3-3/8" 4 9147-9151 0 12/12/98 3-3/8" 6 9156 - 9163 0 05/12/97 3-3/8" 4 9282 - 9292 0 0711 0/96 3-3/8" 4 9318 - 9338 0 06/11/94 2-7/8" 6 9127 - 9147 0 08/19/01 1 PBlD l-i 9394' ~ 9345' 1-i(2) 5/8"X1-1/16"X4"ARM SPRINGS 09/30/97 1 17-518" CSG, 29.7#, 13-CR-80, 10= 6.875" I~ 9483' 1 TO l-i 9500' l------ ..x l .x .... --- ~ I D4.1E REV BY COMWENTS 05121/94 ORlGINð.L COMA..ETION 01/16/01 SIS-MH CONVERlED TO CANV AS 01/12/01 SIS-MD FINA.L 1 0/26/01 RNITP CORRECllO NS 09/01/02 CWSIKK A DPERF 10/24/02 GClKAK PERF CORRECTION DATE REV BY COMrvENTS 12/13/02 CAO/KK ADPERF PRUDHOEBAY UNIT WELL: 11-35 PERMIT No: 1940650 API No: 50-029-22476-00 SS:: 28, T11 N, R15E, 490.07' ÆL & 2559.72' FNL BP Exploration (Alaska) RE: STATUS: 11-35 (PTD 1940650) ...... ....... ... .......... ...... ..... .... ..)... ...... .. .............. ) ~~;~~~~t~lŒj:~T¡\~US:ll~35(~~I)l949<5?Pl.....·...·...·...·......................... .... ............. ................... .... . ...... ..<.. ...... ........ ............................................ .... . ¥~.~;~;...."NSB,..·.·A.[)\V. .W'.ell....*t.~~titY.·Engiµeer".;.~N§.tJ1~V{W~llP1tegrityEngineer@B.i?·..CQW> :O~1~:'Tlle, 19 Ju1200509:19:~6-0800.· . Hi Jim & Winton, As per the e-mail below, we pulled the plug from well 11-350n06/28/05and put the well back on PWI. It appears from the TIO plot the well still exhibits TxlA communication. We plan to submit an AA for TxlA V communication. Attached is a TIO plot and the wellbore schematic. Please call if you have any questions. «11-35.pdf» «11-35 TIO.ZIP» :J~fl7/zllð) Thanks, Donald Reeves - Filling in for Anna Dube Well Integrity Engineer 907 -659-5102 907-659-5100 #1923 pgr SCANNED AUG 0 9 2005 From: Anders, Joe L Sent: Friday, June 24, 20059:35 AM To: Winton GAubert; Jim_Regg (jim_regg@admin.state.ak.us) Cc: Harris, Marvin L (CONOCO); Rossberg, R Steven; NSU, ADW Well Operations Supervisor; GPB, FS2/COTU Area Mgr; GPB, FS2 DS Ops Lead; Engel, Harry R; Dube, Anna T; NSU, ADW Well Integrity Engineer Subject: STATUS: 11-35 (PTD 1940650) Hi Jim & Winton. Well 11-35 was shut-in 21 January 2005 due to the TIO plot indicating possible TxlA communication. A standing valve was installed and subsequent MIT-T and MIT-IA both passed. Here's a summary of recent events: > 01/08/02: AOGCC witnessed MIT IA Passed to 2600 psi > 10/24/04: lAP BUR = 1140 psi overnight. Sent email to Aubert & Regg > 10/26/04: MITIA Passed to 3000 psi > 11/23/04: Set SV in XN nipple @ 8754' MD > 11/25/04: CMIT-TxIA Passed to 3000 psi, state witnessed by John Crisp > 11/30/04: Pulled SV > 01/21/05: Set SV in XN nipple @ 8754' MD > 02/23/05: MIT-T Passed to 3000 psi 10f2 7/18/2005 12:57 PM RE: STATUS: 11-35 (PTD 1940650) > 02/24/05: AOGCC MIT-T pa)sed to 3000 psi, Scheve declined witnesstng the test > 05/16/05: MITIA Passed to 3000 psi Current plan is to pull the standing valve, return the well to water injection and monitor the IA pressure for indications of TxlA comm. If the TIO plot indicates a return of the communication, we'll submit an Administrative Action request with appropriate well operating safeguards. Attached is a TIO plot and the wellbore schematic. Please call if you have any questions or prefer some other approach. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.eom Content-Description: 11-35.pdf 11-35.pdf Content-Type: application/octet-stream Content-Encoding: base64 11-35 Content-Description: 11-35 TIO.ZIP Content-Type: application/x -zip-compressed Content-Encoding: base64 20f2 7/18/2005 12:57 PM ) TREE = W8..LHEAO = A·CTUÄTOR;;;; KB. ELEV = B"¡=.... ELEV ..;m.... KÒP=··· ..~~./:\~.~. ~..~ Datum MIJ = OatumNO = FMC CIW ······......··áKFfc 60' 4512' ..........~..~...<t#:...!.2!(3' 9379' 8800' SS 110-3/4" CSG, 45.5#, NT-80, 10 = 9.953" 1-1 3677 ~ Minimum ID = 3.725" @ 8754' 4-1/2" OTIS XN NIPPLE 1 7-5/8" CSG, 29.7#, NT-95 HS, 10 = 6.875" 1-1 ITOPOF7-5/8" CSG 1-1 8483' 8483' 14-1/2"TBG,12.6#, 13-CR-80, 0.0152 bpf, 10=3.958" I., PffiFO RATION SUIVMARY REF LOG: WA/OEN/NEU ON 05/19/94 ANGLE AT TOP PERF: 20 @ 9030' f'.t>te: Refer to Production DB for historical perf data SIZE S~ NTffiVAL Opn/Sqz OA 1£ 3-3/8" 6 9030 - 9050 0 12/13/02 2-7/8" 6 9100-9116 0 09/01/02 2-7/8" 6 9117-9127 0 09/01/02 3-3/8" 4 9147-9151 0 12/12/98 3-3/8" 6 9156 - 9163 0 05/12/97 3-3/8" 4 9282 - 9292 0 0711 0/96 3-3/8" 4 9318 - 9338 0 06/11/94 2-7/8" 6 9127 - 9147 0 08/19/01 PBID l-i 9394' 1 7-518" CSG, 29.7#, 13-CR-80, 10 = 6.875" 1-1 9483' 1 TO l-i 9500' [)\ TE REV BY COMWENTS 05121/94 ORlGINl\L COMA..EllON 01/16/01 SIS-MH CONVERl£OTO CANVAS 01/12/01 SIS-MO FINl\L 10/26/01 RNITP CORRECllONS 09/01/02 CWSIKK AŒ'ERF 10/24/02 GO'KAK PffiF CORRECTION 11-35 (I) L , :g I ~ ) SAFErY NOl£S: CHROME CASING AND TUBING 2119' 1--14-1/2" CArvx::;O BAL-O SSSV NIP, 10 = 3.815" ~ GA S LIFT MANDR8..S ST MO TVO DEV TYPE VLV LATCH FORT [)\ 1£ 1 3186 3184 .05 KBMG BK-2 2 3988 3986 .03 KBMG BK-2 3 6365 6201 30 KBMG BK-2 4 7457 7148 30 KBMG BK-2 5 8036 7651 30 KBMG BK-2 6 8142 7743 30 KBMG BK-2 ~ 8766' r- -¡ ., ~ 8603' 1-14-1/2" OTIS X NIP, 10 = 3.82" 1 8664' 1-17-5/8" X 4-1/2" BAKffi SABL-3 PKR, 10= 3.92" 8698' 1-14-1/2" OTIS X NIP, 10 = 3.813" 1 8754' 1-i4-1/2" OTIS XN NP, 10 = 3.725" 1 8766' 8758' H4-1/2" WLEG, 10 = 4.0" 1 l-i EUvÐ 1T LOGGED 06/11/94 1 9345' l-i (2) 5/8 "X 1-1/16"X4"ARM SPRINGS 09/30/97 1 DATE REV BY COMWENTS 12/13/02 O\O/KK AOPffiF PRUOHOEBAY UNIT WELL: 11-35 Pffirvu f\b: 1940650 API f\b: 50-029-22476-00 SEC 28, T11 N. R15~ 490.07' ÆL & 2559.72' FNL BP Exploration (Alaska) 4,000 3,000 - . ... := ~ I ... Q. 2000 _ I,i'.. t,.'1.I\......:~.F' I 1,000 _ f}{'ÞAI t-~ _ o ... 7/1212004 11-36TIOj\pløt ~ .Jì I I //rW' .~ ,"- .. {,.... 9/1212004 .. ........ .. . . 1111212004 PI1- 1 1L ~_rJ1. I 7/1212005 ............._._.~~. 3/1212005 f¡ _...~ 511212005 . .... . Tbg 4-IA ..... OA ~ OOA ____ OOOA - STATUS: 11-35 (PTD 1940650) ) ) Subject: STATUS: 11-35 (PTD 1940650) Fr()m: "Anders, Joe L" <anders22@BP.com> Date: Fri, 24 Jun 2005 09:34:46 -0800 To.: Winton GAubert <winton_aubert@admin.state.ak.us>, jim_regg@admin.state.ak.us CC: "Harris, Marvin L (CONOeO)" <harrml@BP~com>, "Rossberg, R Steven" <RossbeRS@BP.com>, tlNSD, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "GPB, FS2/COTU Area Mgr" <GPBFS2TL@BP.com>, "GPB, FS2DS Ops Lead" <GPBFS2DSOpsLead@BP.com>,"Engel, Harry RW<EngelHR@BP.com>, "Dube, Anna T" <Anna.Dube@BP.com>, "NSD, ADWWell Integrity Engineer" <NSUADWWellIntegrityEngineer@BP .com> Hi Jim & Winton. Well 11-35 was shut-in 21 January 2005 due to the TIO plot indicating possibl~ TxlA communication. A standing valve was installed and subsequent MIT-T and MIT-IA both passed. Here's a summary of recent events: > 01/08/02: AOGCC witnessed MIT IA Passed to 2600 psi > 10/24/04: lAP BUR = 1140 psi overnight. Sent email to Aubert & Regg > 10/26/04: MITIA Passed to 3000 psi > 11/23/04: Set SV in XN nipple @ 8754' MD > 11/25/04: CMIT-TxIA Passed to 3000 psi, state witnessed by John Crisp > 11/30/04: Pulled SV > 01/21/05: Set SV in XN nipple @ 8754' MD > 02/23/05: MIT-T Passed to 3000 psi > 02/24/05: AOGCC MIT-T Passed to 3000 psi, Scheve declined witnessing the test > 05/16/05: MITIA Passed to 3000 psi Current plan is to pull the standing valve, return the well to water injection and monitor the IA pressure for indications of TxlA comm. If the TIO plot indicates a return of the communication, we'll submit an Ad ministrative Action request with appropriate well operating safeguards. Attached is a TIO plot and the wellbore schematic. Please call if you have any questions or prefer some other approach. «11-35 TIO Plot.jpg» «11-35.pdf» Joe Anders, P.E. 0 20r1\- Well Integrity Coordinator, BP Exploration, (Alaska) Inc. SCANNED JUL ~~ (~ - J!J:J Wark: 1-907-659-5102 Mo bile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com Content-Description: 11-35 TIO Plot.jpg 11-35 TIO Plot.jpg Content-Type: image/jpeg Content-Encoding: base64 11-35.pdf Content-Description: 11-35.pdf lof2 7/13/2005 8:42 AM STATUS: 11-35 (PTD 1940650) Content- Type: Content-Encoding: 20f2 ) app lication/ octet -stream base64 7/13/2005 8:42 AM TREE = WB..LHEAD = A CTLiÄtÖR;' . ... K B. ELEV = BF. ELEv = ·ï<oþ··;···...· ....... ,.~~..!\~.Q~...:.. DatumMD= Datu m TVD = FMC CIW . ..... BKR·C 60' ) . .......................................... 4512' .... ..... ................................ .. ...~.~...~..??.!.?~. 9379' 8800' SS 110-3/4" CSG, 45.5#, NT-80, ID = 9.953" 1-1 3677' ~ Minimum 10 = 3.725" @ 8754' 4-1/2" OTIS XN NIPPLE 17-5/8" CSG, 29.7#, Nr-95 KS, 10 = 6.875" 1--1 ITOPOF7-5/8" CSG 1-1 8483' 8483' 14-1/2" TBG, 12.6#, 13-CR-80, 0.0152 bpf, 10 = 3.958" 1-1 PERFORATION SUMv1ARY REF LOO: WA/OEN/N:U ON 05/19/94 AN3LE AT TOP PERF: 20 @ 9030' I\bte: Refer to Production DB for historical perf data SIZE SFf' NTERVAL Opn/Sqz OA lE 3-3/8" 6 9030 - 9050 0 12/13/02 2-7/8" 6 9100-9116 0 09/01/02 2-7/8" 6 9117-9127 0 09/01/02 3-3/8" 4 9147-9151 0 12/12/98 3-3/8" 6 9156 - 9163 0 05112/97 3-3/8" 4 9282 - 9292 0 07/10/96 3-3/8" 4 9318 - 9338 0 06111/94 2-7/8" 6 9127- 9147 0 08119/01 I PBlD l-i 9394' 17-518" CSG, 29.7#, 13-CR-80, 10= 6.875" l-i 9483' 1 TO H 9500' 11-35 - L " I 8: I ~ )FErY NOlES: CHROMECASIf\K3 AND TUBING 2119' 1-f4-1/2" CAWCOBAL-O SSSV NIP, ID= 3.815" ~ GA S LIFT MANffiB..S ST rvD TVO ŒV 1Y PE VL V LA T01 FORT [)!\ lE 1 3186 3184 .05 KBMG BK-2 2 3988 3986 .03 KBMG BK-2 3 6365 6201 30 KBMG BK-2 4 7457 7148 30 KBMG BK-2 5 8036 7651 30 KBMG BK-2 6 8142 7743 30 KBMG BK-2 ~ ~ 8766' .., / 8603' 1-i4-1/2" OTIS X NIP, 10 = 3.82" 1 8664' 1-i7-5/8" X 4-1/2" BAKER SABL-3 PKR, 10= 3.92" 8698' 1-i4-1/2" OTIS X NIP, 10 = 3.813" 1 8754' 1-l4-1/2"OTISXNNP, 10=3.725" 1 8766' 8758' H4-1/2" WLEG, 10 = 4.0" 1 l-i ELrvD TT LOGGED 06111/94 I I :I I I 9345' H (2) 5/8"X1-1/16"X4"ARM SPRINGS 09/30/97 1 PRUOI-OEBAY LNIT VVELL: 11-35 PERMT I\b: 1940650 APII\b: 50-029-22476-00 SEC 28, T11 N. R15E, 490.07' FEL & 2559.72' FNL 8P Exploration (Alaska) DATE REV BY OOMtv'ENTS 12/13/02 C'AOIKK AOPERF [)!\ lE REV BY COMrv£NTS 05121/94 ORlGINA.L COMA..ETlON 01/16101 SIS-M-1 CONVERlEOTOCANVAS 01/12/01 SIS-rvD FINA.L 10/26101 R'JITP CORREC1l0NS 09/01/02 CWSIKK AI:FERF 10/24/02 GO'KAK PffiF CORRECTION 11-35 TIO Plot.jpg (JPEG Image, 923x289 pixels) 4,000 3,000 G) ... E I!!. ""4 v. ß '::F' i 2,000 . , I' . . '-' ... Q. o 612412004 ] of 1 --~~..- ~---_._-~~_._~-~-~-~~~ ---- -~-.._---- ... " .. ""..,...... I 1 012412004 812412004 11-35 TIO Plot --- ---- ------~ -------- ---._---------------_.__._~----~----.._-_.~-- , 1212412004 212412005 412412005 612412005 ..... Tbg . IA ..... OA OOA -- .. OOOA -' 7/13/2005 8:43 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test "Wl--. Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.a(tí'~ OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / Pad 11 02/24/05 Rob Mielke Packer Depth Pretest Initial 15 Min. 30 Min. Well 11-35 Type Inj. S TVD 8,201' Tubing 280 3,000 2,950 2,930 P.T.D.1940650 Type test P Test psi 2,050 Casing 1,860 1,880 1,880 1,880 Notes: MIT-T to evaluate a possible one way tubing leak. The AOGCC representative declined witnessing the test. Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.i.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.i.D. Type test Test psi Casing Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. ,~, ') í\ Iì Ç. .~ .,'" U 1\ 0 n t.: (.0 1j,J ".' f' f';. ~, Nt:. tJ \VI!-\ ¡~ \J ~ -' ~\._~t:'''U''l\ . MIT Report Form Revised: 06/19/02 MIT PBU 11-35 02-24-05.xls ~~.(oÇ \ ~Lt'/O~5' Interval 0 P/F P Interval P/F Interval P/F Interval P/F Interval P/F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) ') ) MEMORANDUM State of Alaska Alaska Oil. and Gas Conservation Commission TO: Jim Regg ~ P.L Supervisor .\ ~1 DATE: Monday, November 29, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 11-35 PRUDHOE BAY UNIT 11-35 I~Lf-()&S- FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: I Jo P.I. Suprv ,-Jg~ 17-1 4- Cornm Well Name: PRUDHOE BAY UNIT 11-35 Insp Num: miUCr041129092340 ReI Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-22476-00-00 Permit Number: 194-065-0 Inspector Name: John Crisp Inspection Date: 11/25/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 11-35 Type Inj. N TVD 8200 IA 1250 3020 2990 2970 P.T. 1940650 TypeTest SPT Test psi 2050 OA 0 0 10 10 Interval OTHER PIF P Tubing 1160 1380 1390 1390 Notes: Diagnostic MIT. High annulus pressures while injecting. I witnessed tubing test to 3000 psi wi IA still pressured up from MIT. Standing valve set below packer. Discussed this MIT wi Supervisor for diagnostic purposes. SCANNED DEC J 4~ 20D4 Monday, November 29,2004 Page 1 of 1 11-35 (PTD 1940650) Possible Tubing Leak .' ') Subject: 11-35 (PTD 1940650) Possible Tubing- Leak From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegntyEngineer@BP.com> Date: Sun, 24 Oct 2004 19:55:52 -0800' . -Rte )PT'DJt114- 06S- .- . . .. ~ '. "," ~ . o. .,. . Hello Jim & Winton. Well 11-35 (PTD 1940650) has a possible tubing leak. TIO's on 10/23/04 were 1500/1590/30. The IA was bled to 0 psi in 25 minutes. Pressure on 10/24/04 is 1500/1170/30, IA pressure increased 1140 psi overnight. The well is currently online, injection rate is 30,000 BWPD of sea water. V" Current plans are to conduct an MITIA. We will notify you of the results. Attached is a wellbore schematic. Please call if you have Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 Email: ~~Q~DWWellIntegr~~yEngineer@bp.com any questions. «11-35.pdf» Content-Description: 11-35.pdf Content-Type: application/octet-stream Content-Encoding: base64 SCANNED NOV 2 9 200~l 1 of 1 11/8/2004 10: 13 AM ) .f> TREE = WElLHEAD = Ä CrÜÄ.'toFf;' KB. ELEV = BF. ELEV = KÒP';; .~~ ~.ng Þ3:...... Datum MD = Datum WD = 4512- ......31. ..~ .???f>..' 9379' 8800' SS FMC CIW ""B'KRê 60' l10-3/4" CSG, 45.5#, NT-80, ID = 9.953" 1-1 3677 Minimum ID = 3.725" @ 8754' 4-1/2" OTIS XN NIPPLE 7-5/8"CSG,29.7#, NT-95 HS,ID=6.875" 1-1 8483' ITOPOF7-5/8" CSG 1-1 8483' 11-35 " ~ L , -') SAFEfY NOlES: CHROME CASING AND TUBING 2119' H4-1/2" CAt£O BAL-O SSSV NIp, ID= 3.815" 1 ~ GAS LIFT MANDRElS DEV 1Y PE VL V LATCH .05 KBMG BK-2 .03 KBMG BK-2 30 KBMG BK-2 30 KBMG BK-2 30 KBMG BK-2 30 KBMG BK-2 FQ RT [)ð. lE ST MO TVD 1 3186 3184 2 3988 3986 3 6365 6201 4 7457 7148 5 8036 7651 6 8142 7743 / I 8603' H4-1/2" OTIS X NIP, ID = 3.82" 1 :?S 'LS 8664' H7-5/8" x 4-1/2" BAKffi SABL-3 PKR, ID= 3.92" ~ 8698' H4-1/2" OTIS X NIP, ID= 3.813" 1 8754' H4-1/2"OTISXNNP, ID=3.725" 1 14-1/2"TBG,12.6#, 13-CR-80, 0.0152 bpf, ID=3.958" 1-1 8766' ~ PffiFORA TION SUMMARY REF LOG: WAIDEN/NEU ON 05/19/94 ANGLEATTOPPERF: 20 @9030' f'..bte: Refer to Production DB for historical perf data SIZE SPF NTffiVAL Opn/Sqz DA lE 3-3/8" 6 9030 - 9050 0 12/13/02 2-7/f!' 6 9100- 9116 0 09/01/02 2-7/8" 6 9117 - 9127 0 09/01/02 3-3/8" 4 9147 - 9151 0 12/12/98 3-3/f!' 6 9156 - 9163 0 05/12/97 3-3/8" 4 9282 - 9292 0 07/10/96 3-3/f!' 4 9318 - 9338 0 06/11/94 2-7/8" 6 9127 - 9147 0 08/19/01 (PBlO 1-1 9394' 1 7-518" CSG, 29.7#, 13-CR-80, ID= 6.875" H 9483' TD 1-1 9500' [)ð. TE REV BY COMtÆNTS 05121/94 ORIGINAL COMR.EOON 01/16/01 SIS-MH CONVERlED TO CANV AS 01/12/01 SIS-M> FINA L 10126/01 RNITP CORRECllONS 09101/02 CWSIKK A DPERF 10124/02 GClKAK PffiF CORRECTION '" . DATE REV BY 12/13/02 CAO/KK ADPffiF COMIVENTS 8766' H4-1/2"WLEG,ID =4.0"1 8758' H ELMO TT LOGGED 06/11/94 I 9345' H (2) 5I8"X1-1I16"X4"ARM SPRINGS 09/30/97 1 PRUDHOE BAY UNIT VVELL: 11-35 PERMT No: 1940650 API No: 50-029-22476-00 SEC 28, T11 N. R15~ 490.07' FEL & 2559.72' FNL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operabon shutdown_ Stimulate _ Plugging _ Perforate _X ADD PERFS Pull tubing_ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 4737' FNL, 244' FEL, Sec. 28, T11N, R15E, UM At top of productive interval 1369' FNL, 467' FEL, Sec. 28, T11N, R15E, UM At effective depth 2620' FNL, 485' FEL, Sec. 28, T11N, R15E, UM At total depth 2560' FNL, 490' FEL, Sec. 28, T11N, R15E, UM 5. Type of Well: Development __ Exploratory__ Stratigraphic__ Service__X (asp's 707290, 5952258) (asp's 707012, 5954205) (asp's 706989, 5954370) (asp's 706980, 5954428) 6. Datum elevation (DF or KB feet) RKB 62 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 11-35 9. Permitnumber/approvalnumber ~ 194-065 10. APInumber 50-029-22476-00 11. Field/Pool Prudhoe Bay OiI Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 112' Surface 3646' Production 9451' 9500 feet Plugs (measured) 8975 feet 9335 feet Junk (measured) 8821 feet Tagged TD @ 9335' (01/17/2003) Size Cemented Measured Depth 20" 260 sx ArcticSet 143' 10-3/4" 1200 sx CS III, 375 sx 3677' Class 'G' 7-5/8" 548 sx Class 'G' 9483' True VerticalDepth 143' 3677' 8951' Perforation depth: measured Open Perfs 9030'-9050', 9100'-9151 ', 9156'-9163', 9282'-9292', 9318'-9338', true vertical Open Perfs 8537'-8556', 8602'-8649', 8654'-8661', 8771'-8781', 8805'-8824' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13-CR-80 TBG @ 8766'. Packers & SSSV (type & measured depth) 7-5/8" x 4-1/2" Baker SABL-3 PKR @ 8664'. 4-1/2" Camco BAL-O SSSV Nipple @ 2119'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Anchorage 14. Prior to well operation 12/01/2002 Subsequent to operation 02/10/2003 Od-Bbl Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 17919 22829 Casing Pressure Tubing Pressure 1821 1673 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service WATER INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Techical Assistant DeWayne R. Schnorr " DMS BFL Form 10-404 Rev 06/15/88 · FE~ 26 Date February 111 2003 Prepared by DeWayne R Schnorr 564-5174 SUBMIT IN DUPLICATE 11-35 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08/17/2O02 09/01/2002 12/07/2002 12/13/2002 01/17/2003 02/10/2003 PERFORATING: DRIFT/TAG PERFORATING: PERFORATING PERFORATING: DRIFT/TAG PERFORATING: PERFORATING IPROF: INJECTION PROFILE TESTEVENT--- INJECTION PRESSURE, BWPD. PSI: 1,673 TYPE: PW VOL: 22,829 EVENT SUMMARY 08/17/02 DRIFT/TAG W/2 7/8" DUMMY GUN, LOCATE TTL @ 8733' SLM+25"=8758' ELM (CORRECTED), TAG BTM @ 9318' SLM+25'= 9343 ' CORRECTED. <<< TURN WELL OVER TO DSO >>> 09/01/02 COMPLETED ADDPERF. PERFORATED FROM 9100'-9116' & 9117'-9127' MD IN ONE RUN, RIH WITH WELL SHUT IN. DID NOT TAG TD. NO PROBLEMS RIH. RE. OPENED WING AFTER JOB, <<< PAD OPERATOR NOTIFIED OF WELL STATUS 12/07/02 DRIFT W/3 3/8" DUMMY GUN TO 9341' CORRECTED DEPTH (NEEDED 9050') SB FULL OF ASPHALTINES. 12/13/02 "PURE" PERF, 9030'-9050' W/3 3/8" HSD, 6 SPF PJ GUNS W/"PURE SHOT PLACEMENT TECHNIQUE" TO ADD PERFS. WELL INJ. PW PRIOR TO RIH. SHUT IN WELL FOR SHOOTING PASSES. NO TAG, PERFORATED 9030'-9050' IN TWO RUNS, LOG TIED INTO CNL DATED 19-MAY-1994. LEFT 16 EA. (1/8" X 0.6" PLUG DEBREES) DOWN HOLE. <<< DSO TO POI >>> 01/17/03 LOG IPROF WHILE INJECTING AT 25000 BWPD / WHP = 1800 PSI / WHT = 145 DEGF. TD TAGGED @ 9335'. FIELD SPLITS: 9030'-9050' - 93%, 9100'-9163' - 2%, 9282'-9292' - 3%, PERFS BELOW 9300' - 2%. <<< WELL LEFT INJECTING >>> DSO NOTIFIED. 02/10/03 TESTEVENT --- INJECTION PRESSURE, PSI: 1,673 TYPE: PW VOL: 22,829 BWPD. FLUIDS PUMPED BBLS 5 DIESEL USED FOR TESTING SURFACE PRESSURE CONTROL EQUIP 5 TOTAL ,SCANNED MAR n ~ ;~Ol~3 Page I 11-35 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ADD PERFS 09/01/2OO2 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 2-7/8" HSD P J, 6 SPF, 60 DEG PHASING, RANDOM ORIENTATION. 9100' - 9127' 12/13/2002 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 3-3/8" HSD P J, 6 SPF, 60 DEG PHASING, RANDOM ORIENTATION. 9030' - 9050' ~GANNED NAR 0 ? 2003 Page 2 TREE = FMC ACTUATOR = BKR C KB. ELEV = 60' BF. ELEV = KOP = 4512' Max An le = 31 ~ ~276_' ......Datum TvDDatum MD~I == ._ 8800'9379'SS [~---t 2119' H4-1/2" CAMCO BAL-O SSSV NIP, ID = 3.815" I GAS LIFT MANDRFI S 110-3/4"CSG, 45.5~,NT-80,1D=9.953''1-1 3677' L~ ii, ST N'I:) TVD BEV TYPE VLV LATCH FORT DATE I II F 1 3186 3184 .05 KBMG BK-2 2 3988 3986 .03 KBMG BK-2 3 6365 6201 30 KBMG BK-2 r, 4 7457 7148 30 KJBMG aK-2 Minimum ID: 3.725" @ 8754' 5 8036 7651 30 KBMG BK-2 4-1/2" OTIS XN NIPPLE 6 8142 7743 30 KBMG BK-2 I 7-5/8" CSG, 29.7#, NT-95 HS, ID: 6.875" H 8483' IToPOFT-6/8''aG H 8483, I i I I----t 8603' [--~4-1/2"OTISXNIP, ID=3.82"I ~ Dx:: I 8664' H7-5/8" X 4-1/z' BAKER SA BL-3 PKR, ID = 3.9Z' 4-1/2" TBG, 12.6#, 13-0R-80, 0.0152 bpf, ID = 3.958" ~--~ 8766' [----7 ----{ 8766' d4-1/2" WLEG, ID = 4.0" I I 8758' HELIvD Tr LOGGED 06/11/94 I PERFORATION SUIVlvlA RY F~F LOG: WA/DEN/NEU ON 051191~, AN~LE AT TOPPEF~: 20 @ 9030' Note: Refer to Production DB for historical perf data SIZE SPF NTERVAL Opn/Sqz DATE 3-3/8" 6 9030- 9050 O 12/13/02 2-7/8" 6 9100- 9116 O 09/01/02 2-7/8" 6 9117- 9127 O 09/01/02 ' 3-3/8" 4 9147- 9151 O 12/12/98 ' 3-3/8" 6 9156- 9163 O 05/12/97 3-3/8" 4 9282- 9292 O 07/10/96 3-3/8" 4 9318 - 9338 O 06/11/94 2-7/8" 6 9127 - 9147 O 08/19/01 ~ 9394'I ~ 9500.I I DATE ~ BY COMrv~NTS DATE REV BY COMIVENfTS PRUDHOE BAY UNIT 05/21/94 ORIGINAL COMFLETION 12/13/02 CAO/KK ADPERF WELL: 11-35 01/16/01 SlS-IVH CONVERTEDTOCANVAS PERIVlTNo: 1940650 01/12/01 SIS-MD FINAL APl No: 50-029-22476-00 10/26/01 RNfTP CORRECTIONS SEC28, T11N, IM5E, 490.07' FEL &2559.72'FNL 09/01/02 CWS/KK ADPERF BP Exploration (Alaska) 10/24/02 GC/KAK PB~F CORRECTION PERFORATION SUIVlVlA RY FiEF LOG: WA/DEN/NEU ON 05/19/94 ANGLE AT TOPPEF~: 20 @ 9030' Note: Refer to Production DB for historical perf data SIZE SPF NTERVAL Opn/Sqz DATE 3-3/8" 6 9030- 9050 O 12/13/02 2-7/8" 6 9100- 9116 O 09/01/02 2-7/8" 6 9117 - 9127 O 09/01/02 3-3/8" 4 9147- 9151 0 12/12/98 3-3/8" 6 9156- 9163 O 05/12/97 3-3/8" 4 9282 - 9292 O 07/10/96 3-3/8" 4 9318 - 9338 O 06/11/94 2-7/8" 6 9127- 9147 O 08/19/01 SCANNED f~AR ¢~ ? 7_003 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor Chair THRU' Tom Maunder P.I. Supervisor FROM' John H. Spaulding Petroleum Inspector NON- CONFIDENTIAL DATE' January 8, 2002 SUBJECT: Mechanical Integrity Tests 4-9, 4-13, 11-35 PBU Prudhoe Bay ' Well! 4-09 P'T'D' ! 1760300 Notes: WellI 4-13 . P.T.D.I 17880310 Notes' Well! 11-35 ! P.T.D. ! 1940650 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type lnj.I "S I T.V.D. i 7928 I ~u~,n~! =oo'o !~000 l=ooo ! 2000' jtnt'ervall i Type testi "P I Test psiI 1982 I Casing t 620 J 2600 [ 2590 'i 2585 .... I ~/F I P Yype,nj.! S' I T.V.D. I 82~0 I Tubi.gl 2000 I 2000 I" 2°°'01 2°°° t'nt~'a'l" Type testI P' I TestpSiI 2053 I CasingI 1050 I .2600I 2600 J 260E)i P/F I P' Type,nj.1 S I T.v.~. i~0~ [Tubing ! 1650 11650 ]'~6s0 I 16s0 I,nterVa,! ,' Type test] P J Test psi] 2050 ! Casing J 1580 i 2600 i 2550, I 255°'1 P/F I -P Well . P.T.D. Notes- Well p.T.D. Notes' TyPe ,nj.1 I' T,V.D. ! i+, in l ! I J' I,~te~va'iI' Type testJ JTest p'sit I Casing J I .... I ' ' i '1 P/F I ' ' TYpe lnj'I l Tubingi ' i' I ! llntervail .... Typetestl JTest. psil tCasingl . ..I. ! "1 ! p/~ !."' i Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N - NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Both 4-09 and 4-13 were post rig workovers, while 11-35 recently was converted from a producer to an injector. All thre wells passed their respective MIT's and are in compliance with area injection orders. M.I.T.'s performed' _3 Number of Failures: 0 Attachments: none Total Time during tests' 1.5 hrs cc' none MIT report form 5/12/00 L.G. MIT PBU FS-2 1-08-02js.xls 3/7/02 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1 .Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ (Prod -> Water Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ InJ conversion) Change approved program _ Pull tubing _ Variance _ Pedorate _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 62 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 196612 Stratigraphic _ Anchorage, AK 99519-6612 service_ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4737' FNL, 244' FEL, Sec. 28, T11N, R15E, UM (asp's 707290, 5952258) 11-35 At top of productive interval 9. Permit number / approval number 1369' FNL, 467' FEL, SEC. 28, T11 N, R15E, UM (asp's 707012, 5954205) 194-065 At effective depth 10. APl number 50-029-22476 At total depth 11. Field / Pool 2560' FNL, 490' FEL, Sec. 28, T11 N, R15E, UM (asp's 706980, 5954428) Prudhoe Bay Oil Pool 12. Present well condition summary Totaldepth: measured 9500 feet Plugs (measured) Tagged PBTD @ 9340' on 9/04/2000. true vertical 8975 feet Effective depth: measured 9340 feet Junk (measured) true vertical 8825 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 112' 20" 260 Sx Arcticset 112' 112' Surface 3646' 1 0-3/4" 1200 Sx CS III & 375 Sx Class G 3677' 3677' Production 9451' 7-5/8" 548 sx Cla,ss G 9483' 8951' Perforation depth: measured 9147' - 9151'; 9156' - 9163'; 9282' - 9292'; 9318' - 9338'. true vertical 8646' - 8649'; 8654' - 8661'; 8771' - 8781'; 8805' - 8824'. Tubing (size, grade, and measured depth 4-1/2", 12.6#, 13CR-80 Tbg @ 8766' MD. Packers & SSSV (type & measured depth) 7-5/8" X 4-1/2" BAKER SABL-3 PACKER @ 8664' MD. 4-1/2" CAMCO BAL-O SSSV @ 2119' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: May 15, 2001 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best ol my knowledge. Queslions? Call Dan Babcock @ 564-5735. Signed ~ Title: DS 11 Surveillance Engineer Date Dan Babcock PreF~ared by Paul Rauf 564-5799 FOR COMMISSION USE ONLY Plug integrity __ BOP Test __ Location clearance __ ~, - v__ v Subsequent form required 10- ! Approved by order of the Commission ,-,,.,. ....... ¢.~n.~,~r',,, , Commissioner Date / Alaska 0il & Gas Cons. Commission Anchoraqe Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE April 9, 2001 bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Tom: Re: Sundry_ Notice for 11-35 Conversion from Producer to Water Injection Service Discussion Well DS 11-35 is currently a producer shut-in for GOR. The conversion of 11-35 to water injection is part of a proposed MI expansion project for Drill Sites 4 and 11. As an injector, DS 11-35 will be one of three guard wells which will act to contain MI and prevent its migration up into the gas cap. Reserve benefits will be realized from both waterflood and MI flood processes. Scope of Work In order to convert to water injection service, DS 11-35 will be tripled with existing injection wells DS 11-02 and DS 11-29. Wellwork associated with this conversion will include dummying off the GLV's, circulating the backside with water and a diesel cap and running an MIT. Current perforations in the Lower Romeo will be left open to increase support in the area. Perforations in the lower Victor will be added and the well put on injection. Diagnostic logs will be run as needed to verify injection conformance If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5735 or E-mail me at babcockdr@bp.com. Sincerely, Dan Babcock BPXA DS 11 Surveillance Engineer Alaska Oil 8: Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4737' FNL, 244' FEL, Sec. 28, T11N, R15E, UM At top of productive interval 2494' FSL, 467' FEL, Sec. 28, T11N, R15E, UM At effective depth 2623' FNL, 484' FEL, Sec. 28, T11N, R15E, UM At total depth 2560' FNL, 490' FEL, Sec. 28, T11N, R15E, UM 5. Type of Well: Development~X Explorato~__ Stratigraphic_ Service__ 6. Datum elevation (DF or KB feet) RKB 62 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 11-35 9. Permit number / approval number 94-65 10. APl number 50-029-22476 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured true vertical 9500 feet 8975 feet Effective depth: measured 9325 feet true vertical 8811 feet Casing Length Size Conductor 1 12' 20" Surface 3646' 10-3/4" Production 9451' 7-5/8" Plugs(measured) Junk (measured) Tagged PBTD @ 9325' MD (12/12/1998) Cemented Measured Depth True vertical Depth 260 sx Arcticset 112' 112' 1200 Sx CS III & 375 Sx Class G 3677' 3677' 548 sx c~ass G 9483' 8951' Perforation depth: measured 9147'-9151'; 9156'-9163'; 9282'-9292'; 9318'-9338'. true vertical 8646' - 8649'; 8654' o 8661'; 8771' - 8781'; 8805' - 8824'. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, 13CR-80 Tbg @ 8766' MD. 7-5/8" X 4-1/2" BAKER SABL-3 PACKER @ 8665' MD. 4-1/2" CAMCO BAL-O SSSV @ 2120' MD. ORIGINAL .RECEIVED V 2 0 199 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 766 Subsequent to operation 659 Represent~ive Daily Averaqe Production orlnjection D~a Gas-Mm W~er-Bbl 8649 3467 12276 2698 Casing Pressure Tubing Pre,ute 1906 1577 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __X Gas _ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~¢,,,,~ ,~. ~ Title Arco Engineering Supervisor Erin Oba Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 11-35 DESCRIPTION OF WORK COMPLETED PERFORATION Date Event Summary 11/11/1998: 12/12/1998: RIH &tagged PBTD @ 9345' MD. MIRU & PT'd equip to 3000 psi. RIH w/per[ guns & tagged PBTD @ 9325' MD. Shot 4' of Add Per[orations @: 9147'- 9151' MD (Zone 2) Reference Log: 6/11/1994. Used 3-3/8" carriers and all shots were 4 SPF, random orientation, & 90° phasing. POOH. ASF. RD. Returned well to production & obtained a valid well test. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS !1. Operations performed: Operation Shutdown_ StimulatL Plugging_ Pefforate_X Puli tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavalion (DF or KB feet): ARCO Alaska, Inc. Development_X 62' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 stratagrapic_ Anchorage, AK 99510-0360 service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 540' NSL, 247' WEL, Sec 28, T11N, R15E, UM. 11-35 At top ol productive interval: 9. Permit number/approval number: 2494' NSL, 467' WEL, Sec 28, T11N, R15E, UM. 94-65 At effective depth: 10. APl number: 50-029-22476 At total depth: 11. Field/Pool: 2718' NSL, 497' WEL, Sec 28, T11N, R1 hE, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 9500 feet Plugs (measured) PBTD Tagged @ 9343' MD (5/10/97) true vedical 8975 feet Effective Depth: measured 9343 feet Junk (measured) true verlical 8829 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 112' 20" 260 Sx Arcticset 112' 112' Surface 3646' 10-3/4" 1200 Sx CS & 3677' 3676' 375 Sx Class G 9451' 7-5/8" 548 Sx Class G0R jG 4N/ L8951' Production Perforation Depth measured 9156 - 9163'; 9282 - 9292'; 9318 - 9338' true vertical 8654- 8661'; 8771 - 8781'; 8805- 8824' !ih J}~.~ ~L; [~, ~'. ~; il.; ,' .'" Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR-80, Tubing @ 8766' MD. ~aS,~,.,.~ ¢il A 6~.s Corls. Cornm~S'; Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 8664' MD; Camco TRCF SSSV @ 2119' MD. ~,l'tCh0t'8.[I0 13. stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) 14. Represenfitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 169 1094 6182 302 Subsequent to operation 3064 6348 5056 363 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Repod of Well Operations _ X Oil _X Gas _ Suspended _ Service _ 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Signed '"~,,X.~ '~- ~ Title: Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT iN DUPLICATE 11-35 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 5/12/97: MIRU & PT equipment. RIH w/perforating gun & shot 7' of add perforations as follows: Added perforations: 9156 - 9163' MD (Z2B) Used a 3-3/8" carrier & shot 6 spf at 60 degree phasing at balanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. STATE OF ALASKA --. ALASKA" AND GAS CONSERVATION COI ~IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: operation shutdown ~ Stimulate ~ Plugging ~ Perforate X~ Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well 6. Datum of elevation(DF or KB) Development X 62 RKB feet ARCO Alaska, Inc. Exploratory 3. Address Stratigraphic 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 Service __ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 540' NSL, 247' WEL, Sec 28, T11 N, R15E, UM. 11-35 At top of productive interval 9. Permit number/approval number 2494' NSL, 467' WEL, Sec 28, T11N, R15E, UM. 94-65 At effective depth 10. APl number 50 - 029-22476 At total depth 11. Field/Pool 2718' NSL, 497' WEL, Sec 28, T11 N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9500 feet Plugs(measured) PBTD Tagged @ 9350' MD (6/26/96). true vertical 8975 feet Effective depth: measured 9350 feet ORIGINAL true vertical 8835 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 112' 20" 260 Sx Arcticset 112' 112' Surface 3646' 10-3/4" 1200 Sx CS III & 375 Sx CIG 3677' 3676' Production 9451' 7-5/8" 548 Sx Cl G 9483' 8951' Perforation depth: measured 9282 - 9292'; 9318 - 9338' true vertical 8771 - 8781'; 8805 - 8824' Tubing (size, grade, and measured depth) 4-1/2", 12.6~, 13 Cr-80 Tbg @ 8766' MD. Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 8664' MD; Camco TRCF SSSV ('~ 2119LMD. 13. Stimulation or cement squeeze summary i'~ L, ~ ~- Intervalstreated(measured) see Attached OCT ~ Treatment description including volumes used and final pressure A];~$](~ Oil & Gas Cor~., 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 169 1482 4044 -- 306 Subsequent to operation 242 318 5382 -- 291 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations __ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~ ~'?- ~ Title Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE~ 11-35 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 7/1 0/96: MIRU & PT equipment. RIH w/perforating gun & shot 10' of add perforations as follows: Added perforations: 9282 - 9292' MD (Z1B) Used a 3-3/8" carrier & shot 4 spf at 60/120 degree phasing at underbalanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. P, ECEIVEf) OCT 2 4 199~ Alaska Oil & (las Cons. Commission Anchorage Page: 'i Date: 0z~/05/96 RUN DATE_.R ECVD 0512'719~ · 1 06/20/9~I. '1 06/20/9a. 'i 07/11/9/.,. i 0'7/11/9/+ 1 o 7 / ,i 'i 1 94 1 07/ 'I 1194 i 0'?/11/9~. '1 I 06/ 18/95 Ar'e dr'y W a s t; h e ¢l'i'tch samples r'equi'r'ed? yes ~A-nd r'ecei'u.,zd2 we'll cored? yes ~~a'lysi's & descr'~'pt'ion r'ecei'ved? Rece ~' ved? yes no yes C~ GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'II'N: Sherrie NO. 9507 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 6/6/95 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk (~L~2-D.S. 11-29i .,'"~ 95192 DUAL BURST TDT-P 051595 1 D.S. 2-19 '"u 95193 DUAL BURST TDT-P 051695 1 D.S. 1-25 AVA PATCH SETrlNG RECORD 052395 I 1 D.S. 4-16 RSTB 052295 I 1 D.S. 5-26 PROD PROFILE 052295 I 1 D.S, 6-8 PROD PROFILE 051895 I 1 D.S. 9-38 DUAL BURST TDT-P 052095 I 1 D.S. 9 -,~r~,.~ TEMP SURVEY 052096 I 1 D.S. 11-35 RSTB 052195 I 1 SIGNED: .... ~~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: ,,m 1 6 '1995 Nasks Oil & Gas Co~s. commission Anchorage GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A3'I'N: Sherrie NO. 9471 Company: 5/23/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Well Job # Log Description Date Field: Prudhoe Bay Floppy BL RF Sepia DIR MWD Disk D.S. 2-31 ti! _ tO_~ TBGCU'CrERRECORD 043095 I 1 D.S. 3-06 '~ (~-~ O M.I. INJEC LOG 0421 95 I 1 D.S. 3-31 ~ ~-~Z_ CNL 050295 I 1 D.S. 7-32 ~-/50 PERFRECORD 042895 I 1 D.S. 9-8 '~-'70 PERFRECORD 042995 I 1 D.S. 9-12 '?-) -" '~ INJECPROFILE 050395 I 1 D.S. 11-16 ST1 ~'~-'7~ PERFRECORD 042995 I 1 D.S, 11-23A c~-'~t PERFRECORD 050195 I 1 D.S, 11-28 ~CJ--~O LEAK DETECTION 042895 I 1 D.S. 11-35 ~_~:~ CNL 050295 I 1 D.S. 11-36 DUAL BUSTTDT-P 050195 1 1 O.S. 11-36 ~-~C~ RST 042195 1 1 D.S. 14-5A ~.-- ~ PERFRECORD 042795 1 1 D.S, 14-22A ~,-/,=~ PERFRECORD 042795 I 1 D.S, 14-28~,- J~-- LEAK DETECTION 042995 1 1 43.S. 14-33 ~'~-/~,._~ CNL 042795 I 1 D.S. 14-43 ~ J~)~ OUALBURSTTDT-P 042795 I 1 O.S. 16-12~1 ;;~-~=~ TBG CUTTER RECORD 043095 I 1 D.S. 18-02A C~5-,~(~ PERFRECORD 050295 I 1 D.S. 15-19 95176 DUAL BURST TDT-P 050495 I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: ivm 1995 Alaska 0il & (~as Cons. Commission Anchorage GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9478 Company: 5/24/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Well Job # Log Description Date Field: Prudhoe Bay Floppy 131_ RF Sepia DIR MWD Disk D.S. 11-35 95174 CNT-D 050595 1 D.S. 2-4 ~(~- ~ '~ STATIC BHP SURVEY 050595 I 1 D.s. 9-3 7~ - &~5 PROD PRO~LE 0 5 0 6 9 5I 1 D.S. 15-11 ~l- 132.. DUAL BURSTTDT-P 050495 I 1 D.S. 15-14 '~1-1~0 CNL 050595 1 1 D.S. 15-19 ~'-~_.~ DUAL BURST TDT-P 050495 I 1 D.S. 15-37(~-'7~ DUAL BURST TDT-P 050495 I 1 D.S. 17-20 ~'~- t'(/~''PROD PROFILE 050695 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DAT~i~ ~P ~, 1995 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA ""-'"' AND GAS CONSERVATION CC'T--IlSSION REPORT SUNDRY WELL OPEr ATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate X Pull tubing ~ Alter casing ~ Repair well~ Other 2. Name of Operator 5. Type of Well 6. Datum of elevation(DF or KB) Development X 62 RKB feet ARCO Alaska, Inc. Exploratory 3. Address Stratigraphic 7. Unit or Properly P.O. Box 100360, Anchorage, AK 99510-0360 service Prudhoe Bay Unit 4. Location of well at surface 8. Well number 540' NSL, 247' WEL, Sec. 28, T11N, R15E, UM 11-35 At top of productive interval · 9. Permit number/approval number ("- il,. /i ~ 94-65 2494' NSL, 467' WEL, Sec. 28, T11N, R15E, UM i'? [ ' 1¢'' "/ '!/l i] 10. APl number At effective depth ; ~ ~ ~ ~ /' 50 - 029-22476 At total depth 11. Field/Pool 2718' NSL, 497' WEL, Sec. 28, T11 N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9500 feet Plugs(measured) PBTD Tagged @ 9258' MD (8/31/94) true vedical 8975 feet Effective depth: measured 9258 feet true vertical 8749 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 112' 20" 260 sx Arcticset 112' 112' Sudace 3646' 10-3/4" 1200 sx CS III & 375 sx G 3677' 3676' Production 9451' 7-5/8" 548 sx G 9483' 8951' RE( EiVED Perforation depth: measured 9318-9338' OCT 1 4 1994 true vertical 8805-8824' Alaska 0il & Gas Cons. Commission Anch0ra.;e Tubing (size, grade, and measured depth) 4-1/2", 12.6~, 13 CR-80, Tbg @ 8766' MD Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 8664' MD; Camco BaI-O SSSV @ 2119' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiJ-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Priorto welloperation 346 / 3657 7 -- 251 / Subsequent to operation 2673 / 4802 3517 -- 294 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations __ Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed . _ Title Engineering Supervisor Date Form 10-404 ;v 06/15/88 SUBMIT IN DUPLICATE 1238/14 KRF cc: KZ, JWP ~ 11-35 DESCRIPTION OF WORK COMPLETED INITIAL PERFORATING, ROPE TREATMENT, & FRACTURE TREATMENT OF ZONE I 6/11/94: Shot Initial Perforations: 9318 - 9338' MD (Z1) Ref. Log: ZDL-CN 5/19/94. 8/15/94: RIH & tagged PBTD at 9376' MD. 8/20/94: Pumped N2 to displace fluids from wellbore to approximately 8700' MD, then RIH & set a 4-1/2" Shear Plug assembly in the XN Nipple located at 8754' MD, in preparation for a ROPE treatment. 8/23/94: A ROPE Treatment & Hydraulic Fracture Treatment were performed as follows: PT equipment to 9100 psi. Pumped 141 Mscf of N2 down the tubing @ 5000 scfm, to rupture the Shear Plug for a ROPE Treatment of the perforations (above). Ruptured the Shear Plug at 7920 psi. RIH & pulled the ruptured Shear Plug assembly, & RU for the Fracture Treatment. Pumped a Fracture Treatment using 20/40 mesh proppant, through the perforations (above). Pumped: a) 250 bbls Pre Pad Gel @ 25 bpm, followed by b) Shutdown. ISIP @ 1870. Resumed pumping Data Frac: c) 124 bbls 30# Crosslinked Pad @ 5 - 20 bpm, followed by d) 153 bbls 20# Linear Flush @ 20 bpm, followed by e) Shutdown. ISIP @ 1840. Resumed pumping Fracture Treatment: f) 65 bbls Crosslinked Pad @ 20 bpm, followed by g) 229 bbls # Crosslinked Slurry w/proppant concentrations @ 1 - 12 ppg, followed by h) 153 bbls Flush, followed by i) Shutdown. Placed a total of 40,100 lbs of proppant into the formation. Rigged down. 8/25/94: RIH w/CT & jetted a fill cleanout from to 9350' MD. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED OCT 'l 4 1994 Oil & Gas Cons. Commission Anch0m :~' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 'WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permil Number 3. Address-~ i i ~ i ~ j~i' ' -- 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o- 029-22476 4. Location of well at surtace 9. Unil or Lease Name '~'* ..... ' ~"'''*'"'"' Prudhoe Bay Unit 540' NSL, 247' WEL, SEC. 28, T1 IN, R15E ~ O0tC~PLE'FION f 't~Tf~ lO. Well Number At Top Producing Interval_{ ~;","-,,,~ n~T~ i ~'¢['Ti:lFte~'~'-,'~- -~ 11-35 2718'NSL, 497' WEL, SEC. 28, T11N, R15E~;-~J 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 62.15' ADL 28325 T2.5/12/94Date Spudded 13.5/18/94Date T.D. Reached 14.6/1Date1/94Comp., Susp. or Aband. 15. Water DepIh,N/A iffeetOffshoreMSL 16.oneNO. of Completions 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD'. 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9500' MD/8975' TVD 9394' MD/8876' TVD YES [] NO [] 2119' feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run GN/GR/DEN/DIFL, MWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 32' 112' 30" 260 sx Arcticset (Approx.) 10-3/4" 45.5t/ NTSOLHE 31' 3677' 13-1/2" 1200 sx CS 111/375 sx "G" 7-5/8" 29. 7# N T95HS 32' 8483' 9- 7/8" 7-5/8" 29. 7# 13CR80 8483' 9483' 9- 7/8" 548 sx Class "G" 24. Perforalions open to Production (MD+TVD of Top and Botlom and 25. TUBING RECORD inlerval, size and number) SIZE DEPTH SET (MDI PACKER SET (MDI Gun Diameter3-3~8" 4 spf 4-1/2", 13CR80 8766' 8664' MD TVD (SS) 9318'-9338' 8742'-8761' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD} AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Dale First Produclion Method of Operalion (Flowing, gas lift, etc.) 6/13/94 Gas Lift Date of Test -Iours Tested TEsTPRODUCTIONpERIOD FOR 31L-BBL 3AS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL DIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence ol oil, gas or water. Submil core chips. RECEIVED JUL_ 1 3 1994 k~aska Oil & Gas 0ohs, Cemmission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE jGEOL~ MARKERS MATION TESTS NAME Include interval lested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Sag River 8880' 8336' Shublik 8880' 8336' Top Sadlerochit 8880' 8336' Base Sadlerochit 9338' 8762' 31. LIST OF ATTACHMENTS 32. I hereby cerlify that the foregoing is true and correct to the best of my knowledge Signed. \ ) Title DrillinoEnoineerSuoervisor Dale '~'{ ~ '~ ['J INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". R E C E IV E D Form 10-407 JUL 994 Alr~ska {Jil & Gas Cons. Commission Anchorage SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/ll-35 500292247600 NORTH SLOPE COMPUTATION DATE: 5/19/94 DATE OF SURVEY: 051894 MWD SURVEY JOB NUMBER: AK-MW-40044 KELLY BUSHING ELEV. = 62.15 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH 'DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 0 .00 -62.15 155 155.00 92.85 248 248.00 185.85 338 338.00 275.85 428 428.00 365.85 0 0 N .00 E .00 .00N .00E 0 6 S 86.90 E .07 .01S .14E 0 6 N 11.00 E .14 .07N .23E 0 12 N 8.10 W .12 .30N .22E 0 6 N 41.30 W .14 .52N .15E 519 519.00 456.85 608 607.98 545.83 698 697.90 635.75 788 787.73 725.58 880 879.46 817.31 0 42 N 67.30 E .81 .79N .61E 1 30 N 67.80 E .90 1.44N 2.19E 2 54 N 75.70 E 1.59 2.45N 5.49E 4 5 N 88.60 E 1.59 3.09N 10.91E 4 41 N 76.60 E 1.19 4,.04N 17.86E 976 975.13 912.98 1071 1069.80 1007.65 1167 1165.54 1103.39 1262 1260.37 1198.22 1357 1355.22 1293.07 4 48 N 81.40 E .43 5.55N 25.66E 4 41 N 85.60 E .38 6.45N 33.47E 3 42 N 84.50 E 1.04 7.05N 40.48E 3 12 N 84.00 E .53 7.62N 46.17E 3 12 N 73.60 E .61 8.64N 51.35E 1452 1450.10 1387.95 1548 1546.01 1483.86 1643 1640.92 1578.77 1738 1735.83 1673.68 1834 1831.75 1769.60 2 30 N 74.90 E .74 9.93N 55.89E 2 24 N 70.80 E .21 ll.14N 59.81E 2 35 N 67.60 E .26 12.61N 63.68E 2 24 N 75.60 E .42 13.93N 67.60E 2 12 N 79.20 E .26 14.77N 71.36E 1928 1925.68 1863.53 2023 2020.62 1958.47 2119 2116.60 2054.45 2214 2211.59 2149.44 2309 2306.58 2244.43 2 30 N 78.90 E .32 15.51N 75.14E 1 17 N 67.30 E 1.32 16.32N 78.17E 0 54 N 41.50 E .65 17.31N 79.67E 1 0 N 50.60 E .19 18,39N 80.81E 0 6 N 81.40 E .96 18.93N 81.53E 2404 2401.58 2339.43 2500 2497.57 2435.42 2595 2592.57 2530.42 2691 2688.57 2626.42 2786 2783.57 2721.42 0 24 S 52.70 W .52 18.74N 81.35E 0 30 S 58.70 W .11 18.32N 80.72E 0 30 S 74.50 W .15 17.99N 79.97E 0 24 S 46.90 W .25 17.65N 79.32E 0 24 S 44.60 W .02 17.19N 78.85E 2882 2879.56 2817.41 2977 2974.56 2912.41 3445 3442.54 3380.39 3747 3744.53 3682.38 3844 3841.53 3779.38 0 24 S 32.00 W .09 16.67N 78.43E 0 30 S 35.70 W .11 16.05N 78.02E 0 30 S 13.00 W .04 12.40N 76.36E 0 30 S 6.00 W .02 9.81N 75.93E 0 18 S 3.70 W .21 9.13N 75.87E 1 VERT. SECT. .00 -.02 .04 .27 .49 .71 1.18 1.81 1.82 1.98 2.59 2.59 2.38 2.30 2.73 3.49 4.25 5.27 6.13 6.54 6.84 7.30 8.11 9.06 9.51 9.34 9.00 8.76 8.5O 8.09 7.62 7.05 3.62 1.09 .42 RECEIVED JUL 1 3 1994 Alaska Oil & Gas Cons. ~rnmls~¢~r~ RllOhora u: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRILLING PBU/ll-35 500292247600 NORTH SLOPE COMPUTATION DATE: 5/19/94 DATE OF SURVEY: 051894 MWD SURVEY JOB NUMBER: AK-MW-40044 KELLY BUSHING ELEV. = 62.15 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH ~DEPTH COURS INCLN DGMN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3941 3938.53 3876.38 4132 4129.52 4067.37 4226 4223.51 4161.36 4322 4319.37 4257.22 4416 4412.87 4350.72 0 18 0 30 1 6 4 48 6 48 S 1.20 E .03 8.63N 75.86E S 13.00 E .11 7.31N 76.06E N 20.20 W 1.70 7.76N 75.84E N 14.40 W 3.86 12.52N 74.52E N 6.90 W 2.27 21.85N 72.87E -.08 -1.40 -.94 3.94 13.40 4512 4508.03 4445.88 4607 4601.74 4539.59 4701 4693.86 4631.71 4796 4786.28 4724.13 4892 4878.95 4816.80 8 18 10 30 12 23 14 18 15 53 N 4.10 W 1.61 34.40N 71.70E N 6.70 W 2.36 49.84N 70.19E N 7.20 W 2.02 68.36N 67.93E N 7.80 W 2.01 90.10N 65.06E N 6.70 W 1.69 114.91N 61.92E 26.01 41.51 60.17 82.10 107.10 4987 4970.01 4907.86 5083 5061.49 4999.34 5178 5151.25 5089.10 5274 5240.76 5178.61 5368 5327.25 5265.10 17 12 18 6 20 6 22 12 23 53 N 6.40 W 1.37 14t.79N 58.83E N 6.70 W .94 170.71N 55.51E N 9.30 W 2.29 201.48N 51.15E N 11.50 W 2.34 235.53N 44.87E N 10.00 W 1.91 271.68N 38.02E 134.16 163.27 194.33 228.88 265.58 5464 5414.39 5352.24 25 42 5559 5499.36 5437.21 27 23 5655 5584.08 5521.93 28 42 5751 5668.08 5605.93 29 12 5846 5750.84 5688.69 29 36 N 8.60 W 1.97 311.41N 31.53E N 7.90 W 1.82 353.43N 25.45E N 8.50 W 1.39 398.11N 19.00E N 7.90 W .60 444.10N 12.38E N 6.90 W .67 490.35N 6.38E 305.79 348.23 393.35 439.80 486.43 5942 5834.23 5772.08 29 47 6037 5916.67 5854.52 29 47 6133 5999.98 5937.83 29 47 6228 6082.37 6020.22 29 53 6323 6164.81 6102.66 29 42 N 7.80 W .51 537.52N .29E N 6.70 W .58 584.35N 5.67W N 5.70 W .52 631.78N 10.82W N 7.10 W .74 678.77N 16.09W N 10.00 W 1.53 725.44N 23.11W 533.98 581.19 628.90 676.18 723.35 6419 6248.24 6186.09 29 36 6514 6330.84 6268.69 29 36 6609 6413.49 6351.34 29 30 6705 6497.12 6434.97 29 17 6800 6579.93 6517.78 29 23 N 8.30 W .88 772.32N 30.66W N 9.00 W .36 818.71N 37.71W N 7.40 W .84 865.08N 44.40W N 8.50 W .60 911.75N 50.91W N 7.60 W .48 957.86N 57.43W 770.78 817.67 864.50 911.61 958.16 6895 6662.77 6600.63 6991 6746.66 6684.51 7087 6830.00 6767.85 7182 6911.72 6849.57 7276 6992.38 6930.23 29 12 29 0 30 30 30 47 31 0 N 7.10 W .33 1003.97N 63.38W N 9.00 W .98 1050.19N 69.92W N 10.20 W 1.68 1097.15N 77.87W N 11.10 W .58 1144.74N 86.82W N 9.70 W .79 1192.22N 95.54W 1004.65 1051.31 1098.87 1147.18 1195.34 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 PRUDHOE BAY DRILLING PBU/ll-35 500292247600 NORTH SLOPE COMPUTATION DATE: 5/19/94 DATE OF SURVEY: 051894 MWD SURVEY JOB NUMBER: AK-MW-40044 KELLY BUSHING ELEV. = 62.15 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 7372 7074.89 7012.74 30 30 N 10.60 W .71 1240.53N 104.18W 7467 7156.82 7094.67 30 17 N 10.40 W .24 1287.80N 112.94W 7563 7239.75 7177.60 30 12 N 8.50 W 1.00 1335.50N 120.88W 7658 7321.94 7259.79 30 0 N 7.50 W .57 1382.68N 127.51W 7754 7405.21 7343.06 29 42 N 6.90 W .44 1430.08N 133.50W VERT. SECT. 1244.32 1292.28 1340.58 1388.20 1435.98 7849 7487.85 7425.70 29 23 N 9.20 W 1.24 1476.47N 140.06W 7944 7570.69 7508.54 29 12 N 7.60 W .85 1522.45N 146.85W 8038 7652.51 7590.36 29 47 N 6.40 W .90 1568.39N 152.49W 8134 7735.73 7673.58 30 0 N 10.60 W 2.19 1615.69N 159.56W 8229 7818.08 7755.93 29 47 N 9.70 W .52 1662.30N 167.91W 1482.81 1529.27 1575.55 1623.35 1670.61 8324 7900.73 7838.58 29 17 N 10.40 W .64 1708.44N '176.08W 8420 7984.65 7922.50 28 47 N 9.20 W .80 1754.37N 184.02W 8516 8069.05 8006.90 28 6 N 9.00 W .74 1799.52N 191.25W 8612 8154.13 8091.98 27 6 N 8.60 W 1.06 1843.47N 198.06W 8706 8238.46 8176.31 25 17 N 10.40 W 2.09 1884.40N 204.89W 1717.37 1763.91 1809.60 1854.04 1895.47 8800 8323.92 8261.77 23 53 N 8.60 W 1.69 1922.98N 211.36W 8896 8412.25 8350.09 22 12 N 8.80 W 1.77 1960.13N 217.04W 8992 8501.32 8439.17 21 36 N 8.60 W .63 1995.53N 222.46W 9085 8587.82 8525.67 21 30 N 9.00 W .19 2029.29N 227.69W 9180 8676.21 8614.05 21 30 N 8.80 W .08 2063.68N 233.07W 1934.54 1972.10 2007.88 2042.01 2076.80 9273 8762.76 8700.61 21 23 N 9.70 W .37 2097.25N 238.54W 9368 8851.33 8789.18 21 0 N 9.30 W .45 2131.13N 244.21W 9431 8910.21 8848.06 20 42 N 6.20 W 1.81 2153.34N 247.24W 9500 8974.75 8912.60 20 42 N 6.20 W .00 2177~59N 249.87W 2110.77 2145.08 2167.49 2191.88 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2191.88 FEET AT NORTH 6 DEG. 32 MIN. WEST AT MD = 9500 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 353.45 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 PRUDHOE BAY DRILLING PBU/ll-35 500292247600 NORTH SLOPE COMPUTATION DATE: 5/19/94 DATE OF SURVEY: 051894 JOB NUMBER: AK-MW-40044 KELLY BUSHING ELEV. = 62.15 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -62.15 .00 N .00 E .00 1000 999.04 936.89 5.85 N 27.65 E .96 2000 1997.62 1935.47 16.12 N 77.69 E 2.38 3000 2997.56 2935.41 15.89 N 77.90 E 2.44 4000 3997.53 3935.38 8.32 N 75.87 E 2.47 .96 1.42 .06 .03 5000 4982.43 4920.28 145.61 N 58.40 E 17.57 6000 5884.56 5822.41 566.09 N 3.52 W 115.44 7000 6754.53 6692.38 1054.50 N 70.60 W ~ 245.47 8000 7619.53 7557.38 1549.63 N 150.38 W 380.47 9000 8508.75 8446.60 1998.44 N 222.90 W 491.25 15.10 97.87 130.04 135.00 110.78 9500 8974.75 8912.60 2177.59 N 249.87 W 525.25 34.00 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 PRUDHOE BAY DRILLING PBU/ll-35 500292247600 NORTH SLOPE COMPUTATION DATE: 5/19/94 DATE OF SURVEY: 051894 JOB NUMBER: AK-MW-40044 KELLY BUSHING ELEV. = 62.15 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -62.15 .00 N .00 E .00 62 62.15 .00 .00 N .00 E .00 162 162.15 100.00 .01 S .15 E .00 262 262.15 200.00 .09 N .24 E .00 362 362.15 300.00 .38 N .21 E .00 .00 .00 .00 .00 462 462.15 400.00 .56 N .12 E .00 562 562.15 500.00 1.00 N 1.12 E .01 662 662.15 600.00 2.00 N 3.73 E .05 762 762.15 700.00 3.04 N 9.08 E .20 862 862.15 800.00 3.71 N 16.48 E .48 .O0 .01 .04 .15 .28 962 962.15 900.00 5.39 N 24.58 E .83 1063 1062.15 1000.00 6.40 N 32.85 E 1.17 1163 1162.15 1100.00 7.02 N 40.26 E 1.45 1263 1262.15 1200.00 7.63 N 46.27 E 1.63 1363 1362.15 1300.00 8.75 N 51.72 E 1.79 .34 .35 .28 .18 .16 1464 1462.15 1400.00 10.07 N 56.40 E 1.91 1564 1562.15 1500.00 11.36 N 60.45 E 2.00 1664 1662.15 1600.00 12.98 N 64.57 E 2.10 1764 1762.15 1700.00 14.20 N 68.67 E 2.19 1864 1862.15 1800.00 14.99 N 72.50 E 2.27 .12 .09 .10 .09 .08 1964 1962.15 1900.00 15.81 N 76.68 E 2.36 2064 2062.15 2000.00 16.69 N 79.02 E 2.39 2164 2162.15 2100.00 17.84 N 80.15 E 2.41 2264 2262.15 2200.00 18.90 N 81.44 E 2.42 2364 2362.15 2300.00 18.91 N 81.57 E 2.42 .09 .03 .01 .01 .00 2464 2462.15 2400.00 18.48 N 80.99 E 2.42 2564 2562.15 2500.00 18.06 N 80.23 E 2.43 2664 2662.15 2600.00 17.78 N 79.46 E 2.43 2764 2762.15 2700.00 17.30 N 78.95 E 2.43 2864 2862.15 2800.00 16.77 N 78.50 E 2.44 .00 .00 .00 .00 .00 2964 2962.15 2900.00 16.14 N 78.08 E 2.44 3064 3062.15 3000.00 15.43 N 77.57 E 2.44 3164 3162.15 3100.00 14.72 N 77.06 E 2.45 3264 3262.15 3200.00 13.93 N 76.72 E 2.45 3364 3362.15 3300.00 13.08 N 76.52 E 2.45 .00 .00 .00 .00 .00 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 PRUDHOE BAY DRILLING PBU/ll-35 500292247600 NORTH SLOPE COMPUTATION DATE: 5/19/94 DATE OF SURVEY: 051894 JOB NUMBER: AK-MW-40044 KELLY BUSHING ELEV. = 62.15 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3464 3462.15 3400,00 12.23 N 76.33 E 2.46 3564 3562.15 3500.00 11.38 N 76.13 E 2.46 3664 3662.15 3600.00 10.52 N 76.01 E 2.47 3764 3762.15 3700.00 9.65 N 75.91 E 2.47 3864 3862.15 3800.00 9.02 N 75.86 E 2.47 .00 .00 .00 .00 .00 3964 3962.15 3900.00 8.50 N 75.86 E 2.47 4064 4062.15 4000.00 7.89 N 75.92 E 2.48 4164 4162.15 4100.00 7.04 N 76.12 E 2.48 4264 4262.15 4200.00 8.97 N 75.47 E 2.51 4364 4362.15 4300.00 16.10 N 73.64 E 2.79 .00 .00 .00 .03 .28 4465 4462.15 4400.00 27.81 N 72.18 E 3.49 4566 4562.15 4500.00 42.55 N 71.05 E 4.59 4668 4662.15 4600.00 61.44 N 68.80 E 6.39 4771 4762.15 4700.00 84.01 N 65.89 E 8.95 4874 4862,15 4800.00 110.16 N 62.48 E 12.38 .70 1.09 1.80 2.57 3.43 4978 4962.15 4900.00 139.37 N 59.10 E 16.62 5083 5062.15 5000.00 170.92 N 55.49 E 21.54 5189 5162.15 5100.00 205.41 N 50.51 E 27.46 5297 5262.15 5200.00 244.08 N 43.13 E 34,95 5406 5362.15 5300.00 286.95 N 35.34 E 44.04 4.24 4.92 5.92 7.49 9.09 5517 5462.15 5400,00 334.38 N 28.10 E 54.96 5630 5562.15 5500.00 386.24 N 20.78 E 67.85 5744 5662.15 5600,00 440.82 N 12.83 E 82.06 5859 5762.15 5700.00 496.72 N 5.60 E 96.85 5974 5862.15 5800.00 553.36 N 1.88 W 112.02 10.92 12.89 14.20 14.80 15.17 6089 5962.15 5900.00 610.23 N 8.65 W 127.26 6204 6062.15 6000.00 667.23 N 14.65 W 142.52 6319 6162.15 6100.00 723.95 N 22.84 W 157.79 6434 6262.15 6200.00 780.14 N 31.80 W 172.85 6550 6362.15 6300.00 836.28 N 40.50 W 187.86 15. 15. 15. 15. 15. 24 26 27 06 01 6664 6462.15 6400.00 892.34 N 48.01 W 202.75 6779 6562.15 6500.00 947.93 N 56.11 W 217.44 6894 6662.15 6600.00 1003.62 N 63.34 W 232.13 7008 6762.15 6700.00 1058.67 N 71.26 W 246.56 7124 6862.15 6800.00 1115.79 N 81.24 W 262.17 14.89 14.70 14.69 14.43 15.61 SPERRY-SUN 'DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/ll-35 500292247600 NORTH SLOPE COMPUTATION DATE: 5/19/94 DATE OF SURVEY: 051894 JOB NUMBER: AK-MW-40044 KELLY BUSHING ELEV. = 62.15 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7240 6962.15 6900.00 1174.31 N 92.47 W 278.58 7357 7062.15 7000.00 1233.16 N 102.80 W 295.07 7473 7162.15 7100.00 1290.86 N 113.50 W 311.02 7588 7262.15 7200.00 1348.39 N 122.81 W 326.77 7704 7362.15 7300.00 1405.68 N 130.53 W 342.27 .16.41 16.49 15.95 15.75 15.50 7819 7462.15 7400.00 1462.17 N 137.75 W 357.35 7934 7562.15 7500.00 1517.72 N 146.22 W 372.06 8049 7662.15 7600.00 1573.88 N 153.10 W , 386.96 8164 7762.15 7700.00 1630.68 N 162.37 W 402.36 8279 7862.15 7800.00 1687.14 N 172.18 W 417.61 15.08 14.71 14.90 15.40 15.26 8394 7962.15 7900.00 1742.16 N 182.04 W 432.18 8508 8062.15 8000.00 1795.88 N 190.68 W 446.02 8621 8162.15 8100.00 1847.53 N 198.68 W 458.86 8732 8262.15 8200.00 1895.42 N 206.91 W 470.06 8841 8362.15 8300.00 1939.70 N 213.89 W 479.65 14.56 13.85 12.84 11.19 9.60 8949 8462.15 8400.00 1980.17 N 220.14 W 487.72 9057 8562.15 8500.00 2019.30 N 226.11 W 495.27 9164 8662.15 8600.00 2058.21 N 232.23 W 502.74 9272 8762.15 8700.00 2097.01 N 238.50 W 510.19 9379 8862.15 8800.00 2135.23 N 244.88 W 517.44 8.06 7.55 7.48 7.45 7.25 9500 8974.75 8912.60 2177.59 N 249.87 W 525.25 7.81 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS BP/AAI SHARED SERVICE DAILY OPERATIONS~I''''~ PAGE: WELL: DS 11-35 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: WO/C RIG: 05/11/94 05:30 05/11/94 10:00 NABORS 28E NABORS 28E 05/11/94 ( TD: 110 PB: 110 1) MIRU MOVE RIG TO 11-35 & RIG UP. MW: 9.3 FSW NOW RIGGING UP RIG FLOOR. 05/12/94 ( 2) TD: 1800' ( 0) 05/13/94 (3) TD: 3702' (1902) 05/14/94 ( 4) TD: 3950' ( 248) 05/15/94 ( 5) TD: 5753' (1803) 05/16/94 (6) TD: 7200'(1447) DRILLING MW: 9.3 VIS:350 NIPPLE UP RISER - FLOW LINE & JETS. TAKE WATER IN MUD PITS. FUNCTION TEST DIVERTER SYSTEM. PICK UP, MAKE UP & ORIENT BHA #1. ENVIRONMENTAL & SAFETY INSPECTION. DRILL F/ 99-1800' RUN 10.75" CASG MW: 9.4 VIS:155 DRILL T/2770. CBU. TRIP T/1800. OK. DRILL T/3702. CIRC HOLE CLEAN. TRIP T/HWDP @ 850'. SLM. HOLE TRIED T/SWAB F/3204 T/2728. TIGHT HOLE F/2535 T/2218. OK TRIPPING IN. CIRC. SWEEP. DROP SURV. TOOH & LD BHA. HOLE OK. RU & RUN 10.75 SURF. CASG. DRILLING MW: 9.1 VIS: 35 RUN 10 3/4" CASING. MAKE UP HANGER, LANDING JOINT & CEMENT HEAD. CIRCULATE & RECIPROCATE 10 3/4" CASING. TEST CMT LINES. RIG UP & PERFORM TOP JOB. RIG DOWN. NIPPLE DOWN DIVERTER. MAKE UP SPEED HEAD, NIPPLE UP BOPE. TEST METAL SEAL ON HEAD. CHANGE OUT ANNULAR PREVENTER PACKING ELEMENT. NIPPLE UP RISER & FLOW LINE JETS. TEST BOPE & INSTALL WEAR BUSHING. MAKE UP BHA #2. TRIP IN HOLE TO 3590'. CIRCULATE BOTTOM UP AND PRESSURE TEST CASING. DRILL CEMENT, FLOAT EQUIP & 10' NEW HOLE. CIRCULATE AND PERFORM LOT. DRILL FROM 3712-3950' BIT TRIP MW: 9.8 VIS: 43 DRILL AND SURVEY F/ 3950-4738' STARTED KICKOFF AT 4200'. SHORT TRIP 11 STANDS TO 10 3/4" SHOE. NO PROBLEMS. DRILL AND SURVEY FROM 4738-5753'. CIRCULATE SWEEP. TRIP OUT OF HOLE. CHANGE OUT MWD & BIT. SWABBED FROM 4730-4460' SERVICE WEAR BUSHING. TRIP IN HOLE WITH BIT #3. DRILLING MW: 9.8 VIS: 42 TRIP IN HOLE WITH BIT #3. PRECUTIONARY REAM 90' TO BOTTOM. DRILLE FROM 5753-6774' SHORT TRIP 11 STANDS TO 5712' NO PROBLEMS. DRILL FROM 6774-7200'. RECEIVED JUL. 1 1994 Alaska Oil & Gas Cons. (;ummission Anchorag~ WELL : DS 11-35 OPERATION: RIG : NABORS 28E PAGE: 05/17/94 ( 7) TD: 8235' (1035) 05/18/94 ( 8) TD: 9225'( 990) 05/19/94 ( 9) TD: 9500'( 275) 05/20/94 (10) TD: 9500'( 0) 05/21/94 (11) TD: 9500' ( 0) 05/22/94 (12) TD: 9500 PB: 8975 DRILLING DRILL FROM 7200-7823'. DRILL FROM 7823-8235'. MW: 9.8 VIS: 44 SHORT TRIP TO 6600' NO PROBLEMS. DRILLING MW: 9.8 VIS: 43 DRILL F/ 8235-8425'. CIRCULATE LO-HI SWEEPS. TRIP OUT OF HOLE FOR BIT. NO PROBLEMS. CHANGE MWD AND BIT. CUT AND SLIP DRILLING LINE. TRIP IN HOLE WITH BIT #4. BENCHMARK SURVEY @3747'. PRECAUTIONARY REAM 90' TO BOTTOM. NO FILL AND NO PROBLEMS. DRILL FROM 8425-9225'. RIH MW: 9.8 VIS: 45 DRILLING AND SURVEYING F/ 9225-9500'. SHORT TRIP TO 7100'. WIPED HOLE F/ 8400-8100' CIRC SWEEP. POH F/ LOGS. SLM, NO CORRECTION. NO HOLE PROBLEMS. R/U WESTERN ATLAS AND RAN TRIPPLE COMBO TOOL F/ 9475-8680'. RIH TO COND FOR 7 5/8" CASING. CIRC MW: 9.8 VIS: 43 FINISH RIH. PRECAUTIONARY REAM 90' TO BOTTOM. NO FILL. CIRC SWEEP. PULLED 15 STDS DP. LDDP AND BHA. PULLED WEAR BUSHING. CHANGED TOP PIPE RAMS TO 7 5/8". TESTED SEALS. R/U AND RAN FS JT, & 23 JTS 7 5/8" 29.7# 13CR80 NSCC CASING. R/U CASING TONGS AND RAN REMAINING 204 JTS 7 5/8" 29.7# NT95HS NSCC CASING. FS @9483', FC @9394' 229 TOTAL JTS + 2 PUP JTS RUN. CIRC AND COND MUD F/ CSG. RECIPROCATE WHILE CIRC. LAND 4 1/2" TUBING MW: 9.8 VIS: 0 CIRC AND COND MUD FOR CEMENTING. TEST CMT LINES. FLUSHED CMT LINES. DROPPED TOP PLUG AND DISPLACED CMT. RECIPROCATED THROUGHOUT JOB WITH FULL RETURNS. BUMPED PLUG @ CALC'D STROKES. HELD PSI F/ CSG TEST. RELEASED PRESSURE, FLOATS HELD OK. FLUSHED STACK. L/D LANDING JT AND CSG EQUIP. INSTALLED 7 5/8" PACKOFF AND TESTED. CHANGE TOP RAMS TO 3 1/2 X 6" AND TESTED SEALS. RIG UP AND RUN 4 1/2" COMPLETION. MADE UP SSSV AND CONTROL LINE. TESTED. M/U HANGER AND CONTROL LINES. TEST LINES. LAND TBG W/ CHECK VALVE IN PLACE. RILDS. RELEASED RIG MW: 9.3 FSW FINISH RILDS. N/D BOPE. M/U CONTROL LINES AND TEST. N/U ADAPTOR FLANGE AND TREE. TEST. R/U LUBRICATOR AND PULL TWO WAY CHECK VALVE. R/U AND SET PACKER. BLEED TBG AND PRESSURE ANNULUS TO 3500 FOR PACKER TEST. SHEARED RP VALVE AND PMP'D 83 BBLS DIESEL IN ANNULUS. INSTALL BPV. U TUBED DIESEL INTO TBG FOR FREEZE PROTECTION. PMP'D 24 BBLS DIESEL INTO 7 5/8 X 10 3/4" ANNULUS. RELEASE RIG @1600 HRS 05/21/94. RECEIVED JUL 1 ~ 1994 Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360,'~;horage, AK June 21, 1994 ARCO Open Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution Transmittal #: 94048 99510,d~ ~b, i , (M-D-Y) Well I Log Date Number * i 5-14A f 7-09-93 t 9-11 //'!/'11-35 i ,/11-35 i 5-19-94 /1'1-35 i 5-19-94 · '15-36 i 0-05-94 ;,/ i-/15-36 i 6-05-94 t/15-36 i 6-05-94 t"15-36 ! 6-05-94 'd5'36 { 6'05'94 %1/15'36 i6'05'94 Tool Type i Run, ScaJe J/ CDN Contractor f 1,2"&5" SCH 6-11-94 ~' Collar i 1,5" Atlas 5-19-94 f Borehole Prof I 1.2"&5" Atlas 5-19-94 Atlas · -"~, uat Ind, GR/SP i 1,2" & 5" / SSTVD ,"Z-Densilocj,CN -/DLL, GR/SP i 1. J Borehole Prof f 1,2" & 5" Atlas 1,2" & 5" Atlas : 2" & 5" Atlas 1,5" Atlas 2" & 5" Atlas 1, 5" Atlas 2" & 5" Atlas 2" & 5" Atlas ,--,Z-Densilo.(:.hCN i 1, ,,'Comp 4-arm dipIo { !/'BHC Acous, GR ! 1, I / SSTVD i 1, * The correct APl # for 5-14A is 50-029-20253-01 Number of Records: John E. DeGrey Distribution: Central Files Phillips ANO-8 Geology BPX Exxon State of Alaska~ Mobil D & M PB Well Files Please ackno~%e~~,)ng and returning a copy of transmittal. By: _ Date: / v ARCO Alaska, Inc. Is a Subsidiary o! AflantlcRIchfleldComparty ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360, ~.,,~.~rhorage, AK June 21, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution Transmittal #: Well i Log Date] Tool Type i Run,I, Number (M-D-Y). ~ t Scale 1-05ST i 6-13-94 i/ Dual Burst j 1, 5" 1-06 I 6-13-94 !/ Dual Burst ! 1, 5" ! 1-11 f 6-14-94 i" Per[ Record Contractor I / Perf Record 1-29 ! i"' Dual Burst 1-30 ! 6-08-94 i -' CNL 3-02 I 6-07-94 !z Tubing Cutter 3-19 i 6-05-94 i'f Per[ Record 4-36 ! 6-11-94 i'" Perf Record 4-41 ! 6-12-94 !,-/Cutter Record Sch Sch .: 1, Sch 1-25 i 6-10-94 ~ 1, 5" Sch ' 6-14-94 i 1, 5" Sch 5" 5" 5" 5" 5" 5" 5" 5-11 [ 6-11-94 I / Dual Burst Sch Sch Sch Sch Sch Sch Sch 9-15 [ 6-13-94 i / InjProf 9-18 i 6-14-94 i / InjProf 9-25 [ 6-i4-94 i / injProf 11-35 i 6-11-94 t / Per[ Record 11-36 ! 6-07-94 ! / Per[ Record 13-31 ! 6-09-94 1 "" Per[ Record 13-35 i 6-09-94 i / Per[ Record 14-03 i 6-15-94 j .~ Prod Log 14-03 ! 6-15-94 !.- Dual Burst 16-23 i . 6-13-94 ?Leak Detection 16-23 ! 6-t0-94 ! '" Alpha Tubing] 17-02 i 6-6-94 i~'' Prod Prof Sch i, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch Sch Sch Sch 1, 5" Sch : Sch [ 1, 1" & 5" 18-02 i 6-12-94 i / Per[ Record [ 1, 5" 18-04 ! 6-12-94 i-- Dual Burst i 1, 5" 18-19 t 6-10-94 l-"LeakDetection j 1,1"&5" Sch : Sch : Sch Sch The correct APl # for 1-05ST is 50-029-20076-00 Number of Records: E. DoGroy Distribution: Central Files ANO-8 Geology Exxon Mobil Phillips BPX State of Alaska- ARCO Alasl(a, Inc. Is a Subsidiary of A1JantlcRIchfleldCompany ARCO Alaska, Date: Inc. June 14, 1994 P.O. Box 100360,k~.~".horage, AK 99510,~~, Transmittal#: 94045 ~ ~' Subject: From/Location: Telephone: To/Location: ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution Well I Number 2-33 3-27 4-07ST { 4-19 4-46 { 6-10 i 6-16 ~ 6-22A 7-4A } 7-7A ~Hb ~ 7-26 7-28 9-13 9-44 9-50 11-291 11-291 A!ask~, 0JJ & Gas Cons. Commission Log Date j Tool Type t Run, (M-D-Y)! 1 Scale 06-02-94 J/ USIT ! 1, 5" 05-22-94 t f CNL i 1, 5" 3-18A 05-19-94 i~ CCL i 1, 5" 05-24-94 !,'BAKER IBP REC ! 1, 5" 1,5" 11-291 11-291 11-35 11-35 11-36 14-3 14-12 I 14-12 14-20 14-34 16-13 17-12 17-19 05-26-94 !-' PERF REC I 06-04-94 {.- INJ PROFILE f 1, 5" 05-25-94 I/ USIT i 1, 5" 06-04-94 i,-Production Profile 06-02-94 i/ CCL 06-03-94 1/ PERF REC 05-22-94 i/Batch Settin9 Rec 06-05-94 .FTubbincj Puncher 05-22-94 1/' CNL 05-21-94 .~ CNL 05-21-94 ivProduction Profile[ 05-20-94 i / Pref Rec 05-21-94 i" CNL 05-24-94 ]/ CCL 1, 1"5" 1,5" 1 5" 1 5" 1 5" 1 5" I 5" I 5" 1 5" 1, 1"5" 05-21-94 !"" Prod Profile i 1, 5" 05-26-94 ]¢" Perf Rec 05-25-94 i," Bride 05-20-94 'oduction Profile 05-20-94 lrProduction Profile 05-31-94 t/ CNL 05-30-94 } -- USIT 05-31-94! ,-" TDT-¢ 05-30-94 i / CBT 05-31-94 t / USIT 05-31'94 }"" CBT 05-23-94 !/ CBT 06-03-94 t f PERF REC 05-28-94 t f GRLOG 05-28-94 ~r~P,roduction Profile 06-01-94 1,-/' PERF REC 06-01-94 ]/ PERF REC 05-24-94 ! -' Baker IBP Rec 06-05-94 1~' Leak Detection 05-26-94 I / PERF REC 18-1 i 06-04-94 ~' Pack Off Gas Lift 18-1 { 06-04-94 l/Tubing Puncher 1, 1"5" Contractor SCH SCH SCH SCH SCH SCH SCH SCH ~ SCH SCH SCH : SCH ' SCH i SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH 1 5" SCH SCH SCH 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH 1, 1" 2" 5" SCH 1, 5" SCH SCH SCH ARCO AIs$1(a, Inc. Is a Sub$1dlar¢ of AflantlcRIchfleldCompany ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: May 24, 1994 Transmittal #: ARCO open hole Magnetic tape(s) John E. DeGrey/ATO-1529 (907) 263-4310 Distribution P.O. Box 100360, ~.~.orage, AK 94041 99510.a~ ~k, Number (M-D-Y) Footage : ." GR . 12637 9120- Atlas 34APH9' .i 03-06-94 !J D,..~J.L/AC/CN/G R :i 11658 11-04A i 03-01-94 i,,"DLL/ZDL/CN/GR i 8410-9341 Atlas 11-35 i 5-19-94 i'/ ZDL/CN i8670-9471 Atlas 11-36 i 05-08-94 VDIFL/ZDL/CN/GR t 9300-9969 Atlas . ~ ~ 1 0380 ! 15-34 i 05-16-941,/DEL/ZDL/CN/GRI 10560-11282 Sch Number of Records: 11 E~ DeGrey Distribution: Bob ©canas Phillips BPX Exxon 'Stats of Alaska' Please acknowledge receipt by signing and returning a copy of transmittal. By: ...-¢ (/~,'~ Date: D '~C~r'l~:" Alaska 0il & Gas Cons. Commission Anchorage ARCO AlaskJ, Inc. Is a Subsidiary of At~an'dcRIchfletdCornpeny ALASKA OIL AND GAS · CONSERVATION COMMISSION May 3, 1994 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Terry Jordan Drilling engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 11-35 ARCO Alaska, Inc. Permit No: 94-65 Sur. Loc. 540'NSL, 247'WEL, Sec. 28, TllN, R15E, UM Btmhole Loc. 2642'NSL, 482'WEL, Sec. 27, TllN, R15E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to drill the above referenced well. The'permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W.~Johnstol Chairman~ BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~% STATE OF ALASKA ALASKA' L~IL AND GAS CONSERVATION COIvlMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] RedrillF] lb. Type of well. Exploratory FI Stratigraphic Testl-I Development Oil[] Re-Entry [] Deepen[] Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 60.2' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 28325 4. Location of well at surface 7. Unit or property Name 11. Type Bond(s,,e 20 AAC 25.o25 540' NSL, 247' WEL, SEC. 28, T11N, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2589' N SI_, 476' WEI., SEC. 28, T11N, R15E 11-35 U-630610 At total depth 9. Approximate spud date Amount 2642' NSL, 482' WEL, SEC. 27, T11N, R15E 5/15/94 $200,000.00 .12. Distance to nearest 13. Distance to nearest well 14. Number of acres in propert~ 5. Proposed depth (MD and TW)) ! property line ADL 28324-482' feet 11-13A-33'@3600'MD feel 2560 9519'MD/8977' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (s~e ~0 ^AC 25.035 (e)(2)} Kickoff depth ,~,~oo feet Maximum hole angle 3~ o IMa, ximum sudace 3330 pslg At total depth (TVD) 880¢/4390 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 32' 32' 112' 112' 260 sx Arcticset (Approx.) 13-1/2" 10-3/4" 45.5# NT8OLHE BTC 3669' 31' 31' 3700' 3700' 1177sxCSIII/375sx "G"/250sxCSII 9-7/8" 7-5/8" 29. 7# ~IT95HS NSCC 8630' 30' 30' 8660' 8170' 9-7/8" 7-5/8" 29.7# 13CR80 NSCC 839' 8660' 8170' 9499' 8960' 632 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate Al)!:{ 2 2 1994 P. ro.duction LinerR' ~,,~'.',-~,~,,~ 0il & 6as Cons. C0mmiss[on Pedoration depth: measured Anchorage true vertical 20: Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements• 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 7~'J-z¢ ~ Title Dr/fling Engineer Supervisor Date ~-~.7_.--¢/t~ Commission Use Only Permit Number IAPI number Approval date See cover letter ~,~¢'_~'j~' J50-c=,2...¢~ 2.2.. 42/'.7 ~' I .,~.., ~,2.._./~',~ for other requirements Conditions of approval Samples required [] Yes ,l~ No Mud Icg required •'Yes J~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ]i~ Yes [] No Required working pressure for BOPE [-12M; FI3M; 1~5M; []1OM; F-]15M; Other: Original Signed By by order of Approved by David W. Johnston Commissioner ~ne commission Date ¢~,.?/.~ ~, Form 10-401 Rev. 12-1-85 Submit in triplicate [Well Name: [DS 11-35 Well Plan Summary [ Type of Well (producer or injector): [ Producer Surface Location: 540FSL 247FEL S28 TllN R15E UM Target Location: 2589FSL 476FEL S28 TllN R15E UM Bottom Hole Location: 2642 FSL 482 FEL S27 Tl lN R15E UM [AFE Number: 14J0263 I [Rig: I Nabors 28E [Estimated Start Date: [ 5/15//94 [ [ Operating days to complete: [ 14 [MD: 19,519 I [TVD: I8,977 ] ]RTE: 160.2 [ Well Design (conventional, slimhole, etc.): [ Slimhole Longstring Formation Markers: Formation Tops TVD (brt) MD (brt) K-15 4870 4872 K-10 7245 7563 K-5 7780 8192 'LCU 8400 8905 SAG RIVER 8400 8905 Truncated, (absent) SHUBLIK 8400 8905 Truncated, (absent) TSAD, ZONE 4B 8400 8905 Top is truncated, (56' TVD remains) ZONE 4/X-RAY 8456 8965 ZONE 3 8525 9039 ZONE 2C 8575 9092 ZONE 2B/TANGO 8625 9145 TARGET ZONE 2A 8730 9257 Upper Romeo ZONE 1B/LROM 8768 9297 Lower Romeo BASE SAD 8836 9369 OOWC, POWC, top HOT TD 8977 9520 TD = 150' md below base SAD I l ! Casing/Tubin: l 'rogram: Wt/Ft Hole Size' Csg/ - Wt~Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 91.5# H-40 Weld 80 32/32 112/112 13 1/2" 10 3/4" 45.5# NT-80LHE BTC 3669 31/31 3700/3700 9 7/8" 7 5/8" 29.7# NT95HS NSCC 8630 30/30 8660/8170 9-7/8" 7-5/8" 29.7# 13Cr80 NSCC 839 8660/8170 9499/8960 N/A 4 1/2" , 12.6~ 13Cr80 FOX 8706 29/29 8735/8248 Well Plan Summary RECEIVED ;',I-:R 2 2 1994 ' '"Gas Cons. C0rnmissi0n Anchorage Page 1 Logging Prol ()pen Hole Logs: ram: GR, .Resistivity, DensitY, Neutron Potential RFT Cased Hole Logs: NONE Mud Program: [Special design considerations [ None. Sm'face Mud Properties: ] - Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 200 30 30 40 9 15 to to to to to to to 9.2 . 300 60 60 80 10 25 Intermediate Mud Properties: [ Density MarSh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss N/A N/A N/A Production Mud Properties: [ Density Marsh Yield 10 sec 10 rnin pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 25 8 3 7 8 4 tO tO tO tO tO tO tO 10.2 50 13 10 15 10 10 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: ] KOP: [ 4400 @ 2.0 deg/100' [ I Maximum Hole Angle: [ 31.0 DEG Close Approach Well: 11-13(A), 33' at 3600' MD, 11-25 (surface) The above listed wells will be secured during the close approach. RECEIVED Well Plan Summary A?[-2 2 2 ]994 Gas Cons. Cornmission Anchora.qe Operations Summary DS 11-35 1. MIRU drilling rig. N/U diverter and function test same. Drill 13-1/2" hole to surface casing point. Run and cement surface casing. Nipple up BOPE and function test same to 5000/250 PSI. PU 9-7/8" BHA and RIH. Test casing to 3000 psi for 30 minutes. Drill 10' of new hole and perform a leak off test. Drill 9-7/8" hole to TD. Perform a wiper trip and wireline Log from 200' above TSAD to base of same, (back-up will be drill pipe conveyed.logs). Perform a conditioning trip after wireline logs. o Run and cement 7-5/8" production casing. Bump the plug with filtered seawater. Test production casing to 3500 psi for 30 minutes. P/U the tubing tail, a 7-5/8" x 4-1/2" production packer, assorted GLM's, and SCSSV, and RIH to desired depth on 4-1/2" Chromium Tubing. 7. Set the production packer and test tubing integrity. 8. N/D BOP's, N/U the production tree and test the same. Freeze-protect the tubing and production annulus with diesel thru the shear valve located in the top GLM station. Freeze-protect the 13-1/2" X 9-7/8" annulus by bullheading dry crude. 10. Release the Rig. Anticipated BHP: Maximum Anticipated BHP: Surface Pressure: Planned Completion Fluid: 3600 psi ~ 8800 sstvd 3600 psi @ 8800 sstvd 2720 psi 8.6 ppg filtered sea water Notes: a. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). c. Based on previous logs on Drill Site 11, no potential productive zones are anticipated above 8456' T~D~[C~t ~ ~,~., ~.D~ff Gas Cons. Commission TWB, April 21, 1994 DS 11-35 Cement Plan Casing Size: Circ. Temp.: Spacer: Lead Cement: Tail Cement: 10-3/4" SURFACE CASING ]0-3/4", 47# 38°F 50 bbls fl'csh water ahead of lead slmqy Coldsct II[ Volume (sacksl: 1177 Add lttves: Retarder Weight: 12.2 ppg Mix Water: 10.5 gps Yield: 1.92 cuft/sx Thickening Time: > 4 h,'s @ 50°F Class G Volume (sacks): 375 Additives: 2% A-7, FP-6L l§bs Weight: 15.8 ppg Mix Water: 5.0 gps Yield: 1.15 cuft/sx Thickening Time: >3-1/2 h]~ @ 50°F Top Job: Coldsct II Additive: Weight: Yield: Cement Volume Summary: (1) Lead slurry to surface w/ 100%excess Retarder 15.6 ppg 0.95 cuft/sx Volume (sacks): 250 Mix Water: 3.7 gps Thickening Time: >2 hrs@ 50°F (2) Tail slurry volume: 375 sx, (to cover at least 500' of casing shoe w/100% cxcess + 80' shcc vol.). (3) 'lop iob volume 250 sx (fixed volmue) 7-5 / 8" LONGSTRING CASING Casing Size: Circ. Temp.: Spacer: 7-5/8", 29.7// 140°F 70 bbls of MCS-4 Spacer weighted 1 pp§ above current mud wei§ht Lead Cement: Class G Additives: Weight: Yield: Fluid Loss: Volume (sacks): 340 A-2: 3°/0, FL-52: 0.4%0, CD-32: 0.5°/0, FP-6L: lghs 11.0 ppg Mix Water: 20.92 gps 3.31 cuft/sx Thickening Time: >5 hrs @ 140°F 150-250 cc Free Water: 0.0 cc Tail Cement: Class G Additives: Weight: Yield: Fluid Loss: Volume (sacks): 292 A-2: 0.1%, FL-52: 0.3%q CD-32: 0.5%, FP-6L: lghs 15.8 ppg Mix Water: 4.85 gps 1.14 cuft/sx Thickening Time: 3.5 - 4.5 hrs ~ 140°F 100-150 cc Free Water: 0.0 CC Cement Volume Summary: (1) Lead Slurry to 500' MD above Top of Cretaceous O'CRET (+/-) 4872' MD) with 30% excess (2) Tail SIm'w to 500' MD al)ore Top of Sadlercchit (TSAD (+/-) 8905' M~ ~tl~ _~r~?,~~ plus 80. of 7_5/8,, 29.7//capacity for float joints h.. TWB, 4/22/94 0 500 Prudhoe i av Dr-ill · Prudhoe Bay Unit Drill Site 11 Well: 11-35 Wpl VERTICAL VIEW SCALE 500 fl.. / DIVISION TVD REP: RKB VERTICAL SECTION REF: WELLHEAD TIE IN :~F BUILD HORIZONTAL VIEW (TRUE NORTH) SCALE 500 ft. / DIVISION SUR~,rlS. Y REF: WELLIIEAI) mALL 3339 I000-- !500-- <-!5 4872 9 zS' 353.52' 4870 39 N <-I0 7563 21 88" 353.52' 7245 1853 N I~;_ t K-5 8i92 31 8fi'352 53' 7780 1593 N 180 !START OF 8522 31 8~' 352 52' 8059 2756 N 233 :GURvE 8 ILSU / ]VISHAK 8905 22.33' 353.52' 8400 3529 N 219 !/ SAG / i SHUBL1K / TO~ iSAD / ZONE 48 ] [/ ZgLU ]ZENE 4A / 8965 20.79' 353.52" 8456 1951N 282 lEND OF CURVE 8997 80 01' ~53.58' 8~85 1962 N 223 i ZONE 3 9039 20.S0' 553.52' 8525 1976 N 225 [Zone 2 / 23 9092 20.33' 252.52' 9575 2994 N ~27 [ZONE 2~ / 9!z5 a0 0C' 251.52' 8S25 2g;a N 229 ;TANGO T:mge% / ZONE 9257 20.02' 353.52' 8730 2C50 N 233 2A / RO~EO ZDNE iB/ 9297 20. CC' 353.52' 8768 2064 N 825 LOWER RO~EO ~DWC / ~DVC / 9369 80.03' 353.52' 8836 2CB8 N 237 TOP HD/T / 2503~ 3053 -- 25~D~ zS0O~ z870 -- 55S5--~ 72~5 7503 ~ASE S,~-8/ KAVIK ~ZDR BO00 9427 20.23' 353.52' BD~O 2238 N 240 q' KAViK SANg 9430 20.2? 353.52' 2893 2139 N 240 W \ \ RECEIVED APR 1g 4 A!~.sha Oil & ~as Corm. Commission AHchorage 9530 1767 .~530 500 O00 ~--530 j PROPOSED BHL J TVD 8977.15 iMD 9519.49 VS 2153.19 N/S 2139.42 E/W 243.11 . Srea~eu By ~qecke~ By ApDrove~ By I i i ! -500 O 500 10O0 VERTICAL SECTION PLANE: 353.52 i i 1500 8300 2500 4/18/94 f l~crge~ 8730 2059 t, 223 W 737030 59543~01 [ CASING POINT DATA l J OD ~D ~nc aZ[ TVD N/$ E/wi I 9 5/8 mn 3700 0.OD' 0.00' 3730 3 N 3 E j ?HALLIBURTO~ 4181104 4~41 p~ E4C~ 210° CLD~T ~ = I ~1'3S~ tl-36 As-b~t~ · I-E~ 11-Bg A~-BL~I_T t 1-04A 11-04A i101 11-01 1101u I1-OIA 111~ 11-0~ 1103 11-03 110~ 11-03A 1104 11-O4 1105 11-05 1106 11-06 110~ 11-07 1107s-~ 11-07A 1108 11-08 llDg 11-Og 1110 11-10 1111 11-11 1118 11-18 1113 11-13 1113o~ 11-13A 1114 11-14 1115 11-15 1116 11-16 1116~-t 11-16A 1117 11-17 lltB Il-lB 118~ 11-8~ lIB3 ii-B3 1124 11-84 11~5 I1-~5 1126 11-86 11~ Il-P1 llaB 11-28 1331 1_3-31 B~Umce D~eu~cn ReF Pi]) ReF ~ ~1~.1c~ 3ag.g7 168.13 50.DO 33.03 108.91 1~7 1~,~ 1~.~ ~,70 1~ 141,~ I~.~ 1~.~ ~.~ ~,61 1~ ~.~ ~ 7~.~ 1169.~ 1~ ~.~ ~ ~.~ 1~,~ 1~ ~,~ 2~,~ 91,~ ~.~ 176.11 2~.~ 2~,~ 1~.~ 1~1 ~,~ E~,~ ~.~ i~.~ 1~ l~.~ i~,~ 181~ 1169.~ 1~ ~.~ i~.~ 1~ g~ 0,~ ~1~4.~ 4~ ~,~ ~/~.~ ~.~ 9.~ 497.10 ~ ~.~ ~.~ g,~ ~ ~1.13 ~.~ ~,~ 6~ 1~.11 ~.~ ~ ~.~ 1~7,~ 145.16 ~.~ 7~ 310~ i~,~ 1~ 11~,~ 11~,~ 1~ ~1,~ ~7~ ~.~ ~.~ 1~,13 ~.~ ~ 314.10 ~.~ ~ ~.~ ! Tarqet Note TVD NS EW C~ld X C~ld Y JTar, ge't 8733 8050 N a'33 V 7070C0 5954303 ]lllmJssloa O 150° CR~FIC/~_ POINT DATA TIE IN ~ / START IF BdlLD ~ a,OO°/tO0 Ct K-iS END OF BUILO K-ID START Dc. ND lnc AZ;. TVD N/S ~ 0 O.CO° 0,00° 0 0 N 0 E 4400 O.OD° 0,00o 44130 0 N 0 E 4878 9.45° 3~.5~° 4870 39 N 4 W ~ 31.E~° 353.52° 5913 ~ N 49 U 7563 31.88° 353.52° 7245 l~ N 1~ V 8193 31.~ 3~.58° 77~ 1~ N 1~ W ~8 3t.~ 3~.~° ~ 1~ N ~ ~ 2.50°1103 Ct LCU / I~SPAK 8905 88.30° 3,53.5a3° ~ 1~ N 219 U ~/~4B ~ ~ / ~5 ~,7~ 3~.52° ~ 1~1 N ~ W X~Y ~ ~ ~VE ~7 ~,~ 3~.~o ~ 1~ N ~ W ~-~ 3 ~ ~.~ 3~,58o ~ 1976 N ~ W Z~,e 2 / ~ ~ ~,~ 3~.520 ~ t~ N ~ ~ ~ ~ / 9145 ~.~ 3~,~o ~ ~1~ N ~ ~ T~ ~ ~41 ~.~ ~.5~° 8715 ~5 N ~ ~ ~/~ ~ lB / ~7 ~.~ ~.~ 87~ ~ N ~ ~ ~/ ] CA3ING FEi!NT DATA OD ~ Inc Az; TVD N/S 1031~ ~ sn 3700 0.00° O.O0° 37C0 0 N 0 E TVD 8977.15 HD ~1g.49 VS 21~.lg N/'S 2139.4E N F_~ 243.11 W 4121/94 WELL PERMIT CHECKLIST dev ~ redrll [] serv [] ON/OFF SHORS . ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ..... ' 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ........ 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERING APPR 14. Conductor string provided ............... .~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CE vol adequate to circulate on conductor & surf csg.. ~ N 17. CMT vol adequate to tie-in long string to surf csg . . .~ N 18. CE will cover all kno~ productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost $ N ~,~ .... 20. Adequate tankage or rese~e pit ............. N 21. If a re-drill, has a 10-403 for abndrmmt been approved. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate . N 25. BOPEs adequate ..................... ~> N 26. BOPE press rating adequate; test to ~ psig.~ N 27. Choke manifold complies w/~I ~-53 (May 84) ...... 28. Work will occur without operation shutdo~ ....... ~ N 29. Is presence of H2S gas probable ............. Y N~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Seismic analysis of shallow gas zones_ .......... Data presented on potential overpressure zones ..... 32. Survey (if off-shore) ........ ./Y N 33. Seabed condition 34. Contact name/phone for weekly progress reports . . . ~/. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: BEW DWJ ~ Comments/Instructions: z HOW~o - A:~FORMS~cheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. RECEIVED IVlAY 2. 4 1995 ::r:' 4.qf ~ "756 ' J 2, .,50 (y e C ,¢:'. C. '? - :, .~ 9.2 b,'.) N 6' ~, !'. C.,.., D -99o 250 C~AT.CNTD - , . ~9'~ C~,~'ro .oqo 250 ~ ':.~ 9. ~ 5 n C ~.. ............ . -99°,250-, CC[~.C~'?r'', . -99q.. 250 GP.DIL -999. 250 ,,999.250 110,916 -999.250 -999.250 203.835 0 ..9 g f~ . :' ':' -.' '_, 5.5 4.469 3015.069 -999.250 -999.250 .rep[:!: sh~..f:te,-~ a~:¢ cj. inned c~rVe$ for each oa$$ in se~?arete fifes. :" 2 ] 7.5 9t51.5 9 !.5~,0 9074,. 5 ?q73. r: %g'7 O. 5 906° · 5 b795.5 :f:qqS. 5 &99.?.~ 'E. c57,r: q c~,~ 7 c {q27.5 ~°27 .0 .... ' Y' :~ S. ~..i :' ? r'b -,:~ 9 q. 2 ;~ :~ C C ._~' ..... Ct, ~'P -99o . ~5p,., C R h T. C "~ 1'~ 0 ,.,, .[ C . C X T () CRAT. C>, TD C ~,~, ~['C . C~ TD ~. 740 3122., 04.3 -999.250 -999.250 000o0o0000 0000000000 O0000000OO 0000000000 O0000OO900 O0000000OO 0000000000 701 .63t C ~'- T C. C",J ;-'~ V 669.442 CRAT.C}iA¥ C~I:C.CN~V' 41.652 3129.155 7,182 2263.523 S t:' :,' V Lr,S7 { C ,:' 3 6 '? 7.0 752.22¢ Ct'?C.PSi 31. b0.066 CFTC.ES1 l~;25.r?(:n CC? PSi 6.368 723.422 7.()78 320.545 C.r:'4 2 . {~ 3 6 '7 7.0 <%,'123 624. 7.45O 310,823 CP42.2 I O~ '7 02-Y,'AY-95 9363. O, 1. 80:,). ,') 3 6 7 '7 . 0 PAGEt 22 ;} 4,961 03O o 005 31.7.122 ARCO ALASKA INC D.S. 11 - 35 PRUDHOE ;.~ ;.~,? .... WESTERN ~ ~ d ~*~l~d--~ ~ J '~ :'" ATLAS ~,,. ,/o/~' ' ' Atlas Wireline Services Tape Subfile 2 is ty~e: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: OWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6204.00 K. RICHARDS RALL/STEIN D.S. 11 - 35 500292247600 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 24-MAY-94 RUN 2 RUN 3 28 liN 15E 540 247 60.20 34.25 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 10.750 3678.0 PRODUCTION STRING 9.875 9500.0 REMARKS: DIFL/ZDL/CN/GR. CIRCULATION STOPPED AT 18:00, 18-MAY-94. CALIPER VERIFIED IN CASING BEFORE & AFTER LOGGING. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING ACTIVE, CASING CORRECTIONS NOT ACTIVE, SALINITY = 0.0 PPK. PER CLIENTS REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CORRECTED FOR BOREHOLE SIZE (CALIPER). THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; all runs merged; no case hole data. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR DIL SDN 2435 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 8670.0 9411.0 8670.0 9471.0 8670.0 9436.0 8670.0 9418.0 BASELINE DEPTH LL8 8607.0 8607.0 8674.5 8675.5 8691.0 8694.5 8695.0 8697.0 8703.5 8704.0 8705.5 8708.5 8709.5 8710.0 8712.0 8715.0 8720.5 8736.0 8738.5 8743.0 8763.5 8779.5 8780.0 8784.5 8786.0 8790.0 8791.0 8798.0 8801.5 8807.0 8810.0 8816.5 8817.0 8821.5 8822.5 8822.5 8834.0 8836.0 8837.0 8837.0 8838.5 8841.5 8845.0 8850.0 8850.5 8850.5 8860.5 ILM 8607.0 8674.5 EQUIVALENT UNSHIFTED DEPTH RHOB NPHI 8607.0 8607.0 8703.5 8737.5 8786.0 8790.0 8790.5 8676.0 8690.5 8694.5 8696.5 8703.5 8694.0 8706.5 8709.5 8706.5 8709.0 8712.5 8716.0 8721.5 8736.5 8763.5 8784.5 8743.0 8780.0 8806.5 8798.0 8801.0 8810.5 8816.5 8822.0 8835.5 8834.0 8841.0 8845.0 8838.5 8850.5 8860.0 8861.0 8864.5 8872.5 8874.5 8878.0 8879.5 8880.0 8880.5 8884.5 8886.0 8886.5 8889.0 8889.5 8904.5 8905.0 8908.5 8913.5 8920.0 8926.5 8927.0 8929.5 8932.0 8932.5 8935.5 8936.0 8939.0 8940.0 8943.0 8954.0 8964.0 8969.0 8973.0 8973.5 8977.5 8978.0 8980.0 8980.5 8982.0 8983.0 8990.0 8999.5 9002.0 9004.5 9017.0 9019.0 9026.0 9026.5 9042.0 9055.5 9090.0 9134.5 9137.5 9154.0 9154.5 9155.0 9160.0 9165.5 9166.5 9171.0 9174 · 0 8890.0 8904.5 8908.5 8920.0 8935.5 8969.0 8977.5 8999.0 9001.5 9004.5 9026.5 9137.5 9154.0 9160.0 9166.0 9171.5 9175.0 8861.5 8865.0 8872.0 8874.0 8877.0 8878.0 8879.5 8880.5 8884.5 8889.0 8904.5 8912.5 8925.5 8926.5 8928.5 8931.0 8932.0 8935.5 8939.0 8940.0 8953.0 8976.5 8977.5 8979.5 8980.5 8982.0 8982.5 8998.5 9004.0 9015.5 9018.5 9025.5 9134.0 9152.5 9159.5 9166.5 8885.5 8888.0 8904.5 8907.5 8919.0 8935.5 8973.0 8976.5 8999.0 9004.0 9025.5 9091.0 9154.0 9171.0 8886.5 8890.0 8920.0 8936.0 8943.5 8964.0 8973.5 8977.5 8990.0 9004.0 9026.0 9042.5 9055.5 9155.5 9171.0 9177.5 9179.5 9182.0 9193.5 9194.0 9196.0 9197.5 9199.0 9201.5 9212.5 9213.0 9223.0 9227.0 9235.0 9238.0 9245.0 9247.5 9255.5 9256.0 9261.5 9262.0 9274.0 9275.0 9281.0 9285.5 9286.5 9288.5 9289.0 9291.0 9294.0 9306.0 9308.5 9314.5 9316.5 9317.0 9324.5 9327.5 9329.5 9331.5 9334.0 9336.5 9338.5 9341.5 9345.0 9347.0 9355.0 9355.5 9359.0 9365.0 9365.5 9374.5 9375.5 9379.0 9384.5 9397.0 9401.0 9406.0 9435.5 9459.5 9463.0 9178.5 9194.5 9196.5 9213.0 9227.0 9255.5 9273.5 9314.5 9317.5 9324.5 9327.5 9330.5 9335.0 9338.5 9342.0 9347.5 9356.5 9406.5 9179.5 9193.5 9196.0 9222.0 9226.0 9234.5 9237.5 9245.0 9247.5 9254.5 9262.0 9272.0 9273.0 9284.5 9285.5 9305.5 9308.5 9313.5 9323.5 9344.5 9355.0 9365.0 9365.5 9378.5 9384.0 9406.0 9435.0 9459.5 9462.5 9181.5 9194.0 9196.5 9212.5 9255.0 9261.5 9280.5 9288.0 9314.0 9317.0 9324.0 9331.5 9336.0 9338.0 9344.0 9346.0 9374.5 9396.5 9194.0 9195.5 9197.0 9199.5 9202.0 9212.5 9226.0 9255.0 9262.0 9274.0 9289.0 9291.5 9293.5 9314.5 9345.0 9347.5 9355.5 9359.5 9376.0 9401.5 9406.5 9488.0 9488.0 9488.0 $ MERGED DATA SOURCE PBU TOOL CODE RUN NO. PASS NO. GR 1 2 DIL 1 2 SDN 1 2 2435 1 2 $ REMARKS: 9488.0 9488.0 MERGE TOP 8670.0 8670.0 8670.0 8670.0 MAIN PASS. MTEM, SP, TEND, & TENS WERE SHIFTED WITH LL8. ILD, RT, & DI WERE SHIFTED WITH ILM. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. MERGE BASE 9411.0 9471.0 9436.0 9418.0 CN WN FN COUN STAT /??MATCH1.OUT /??MATCH2.OUT /??MATCH3.OUT /??MATCH4.OUT $ : ARCO ALASKA INC. : D.S. 11 - 35 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: 1 2 3 4 5 6 7 8 9 10 tl 12 13 14 15 16 17 Name Tool Code Samples Units GR DIL 68 1 GAPI LL8 DIL 68 1 OHMM ILM DIL 68 1 OHMM ILD DIL 68 1 OHMM RT DIL 68 1 OHMM DI DIL 68 1 IN SP DIL 68 1 MV MTEM DIL 68 1 DEGF TEND DIL 68 1 LB TENS DIL 68 1 LB RHOB SDN 68 1 G/C3 DRHO SDN 68 1 G/C3 PEF SDN 68 1 BN/E CALl SDN 68 1 IN NPHI 2435 68 1 PU-S FUCT 2435 68 1 CPS NUCT 2435 68 1 CPS Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 55 965 57 0 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 50 746 76 1 4 22 779 91 0 4 22 779 91 0 4 22 779 91 0 4 22 779 91 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 * DATA RECORD (TYPE# 0) Total Data Records: 126 1014 BYTES * 68 Tape File Start Depth = 9488.000000 Tape File End Depth = 8607.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 31735 datums Tape Subfile: 2 391 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8664.0 DIFL 8664.0 ZDL 8670.0 2435 8670.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS MODL GR CN ZDL KNJT TEMP PCM KNJT DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR KNUCKLE JOINT DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): STOP DEPTH 9418.0 9478.0 9441.0 9424.0 19-MAY-94 FSYS. REV. J001 VER. 1.1 1800 18-MAY-94 128 19-MAY-94 9500.0 9475.0 8670.0 9472.0 2100.0 TOOL NUMBER 3974XA 3967XA 3517XA 1309XA 2435XA 2222EA/2222MA 3921NA 2806XA 3506XA 3921NA 1503XA 9.875 3678.0 .0 LSND 9.80 97.0 9.1 5.9 MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 11 - 35 : PRUDHOE BAY : NORTH SLOPE : ALASKA 152.0 2.780 1.260 2.720 .000 2.420 .000 THERMAL SANDSTONE 2.65 .000 1.5 65.0 152.0 65.0 .0 65.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 2O 21 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHM}4 RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 67 456 14 5 4 27 515 24 6 4 06 213 78 0 4 04 903 06 0 4 04 522 10 6 4 04 903 06 0 4 39 256 18 6 4 53 419 67 0 4 40 467 34 0 4 78 867 34 0 4 78 867 34 0 4 13 331 34 0 4 52 443 33 1 4 09 884 61 1 4 76 731 33 1 4 24 115 90 6 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 * DATA RECORD (TYPE# 0) Total Data Records: 300 974 BYTES * 84 Tape File Start Depth = 9488.000000 Tape File End Depth = 8664.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 72535 datums Tape Subfile: 3 382 records... Minimum record length: Maximum record length: 62 bytes 974 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR DIFL ZDL 2435 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: CHT MIS MODL GR CN ZDL KNJT TEMP PCM KNJT DIFL $ 1 .2500 START DEPTH 8608.0 8663.0 8633.0 8673.5 STOP DEPTH 9416.5 9477.0 9440.5 9419.0 TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR KNUCKLE JOINT DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 19-MAY-94 FSYS. REV. J001 VER. 1.1 1800 18-MAY-94 50 19-MAY-94 9500.0 9475.0 8670.0 9472.0 2100.0 TOOL NUMBER 3974XA 3967XA 3517XA 1309XA 2435XA 2222EA/2222MA 3921NA 2806XA 3506XA 3921NA 1503XA 9.875 3678.0 .0 LSND 9.80 97.0 9.1 5.9 152.0 MTJD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 11 - 35 : PRUDHOE BAY : NORTH SLOPE : ALASKA 2.780 1.260 2.720 .000 2.420 .000 THERMAL SANDSTONE 2.65 .000 1.5 65.0 152.0 65.0 .0 65.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 67 456 14 5 4 27 515 24 6 4 06 213 78 0 4 04 903 06 0 4 04 522 10 6 4 04 903 06 0 4 39 256 18 6 4 53 419 67 0 4 40 467 34 0 4 78 867 34 0 4 78 867 34 0 4 13 331 34 0 4 52 443 33 1 4 09 884 61 1 4 76 731 33 1 4 24 115 90 6 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 84 * DATA RECORD (TYPE# Total Data Records: 0) 974 BYTES * 321 Tape File Start Depth = 9487.000000 Tape File End Depth = 8607.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 109198 datums Tape Subfile: 4 401 records... Minimum record length: Maximum record length: 62 bytes 974 bytes Tape Subfile 5 is type: LIS 94/ 5/24 01 **** REEL TRAILER **** 94/ 5/25 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 25 MAY 94 8:22a Elapsed execution time = 16.09 seconds. SYSTEM RETURN CODE = 0
