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Home My WebLink About177-080MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC NGI-11 PRUDHOE BAY UNIT NGI-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 NGI-11 50-029-20283-00-00 177-080-0 G SPT 7311 1770800 1828 3384 3382 3381 3382 3 4 4 4 4YRTST P Bob Noble 7/4/2022 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT NGI-11 Inspection Date: Tubing OA Packer Depth 171 2218 2137 2117IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220704152342 BBL Pumped:5.1 BBL Returned:4 Thursday, July 21, 2022 Page 1 of 1          3URSHUW\'HVLJQDWLRQ/HDVH1XPEHU 2SHUDWLRQV 3HUIRUPHG 2SHUDWRU1DPH $GGUHVV :HOO&ODVV%HIRUH:RUN3HUPLWWR'ULOO1XPEHU $3,1XPEHU :HOO1DPHDQG1XPEHU /RJV/LVWORJVDQGVXEPLWHOHFWURQLFGDWDSHU$$&)LHOG3RROV $EDQGRQ 6XVSHQG 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 3HUIRUDWH 3OXJ3HUIRUDWLRQV 5HHQWHU6XVS:HOO 2WKHU6WLPXODWH )UDFWXUH6WLPXODWH $OWHU&DVLQJ 3XOO7XELQJ 5HSDLU:HOO 2WKHU &KDQJH$SSURYHG3URJUDP 2SHUDWLRQVVKXWGRZQ 3UHVHQW:HOO&RQGLWLRQ6XPPDU\ &DVLQJ /HQJWK 6L]H 0' 79' %XUVW &ROODSVH ([SORUDWRU\ 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Supervisor FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL 0 State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 09, 2018 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. NGI-11 PRUDHOE BAY UNIT NGI-11 Src: Inspector Reviewed By: P.I. SuprT—&2— Comm Well Name PRUDHOE BAY UNIT NGI-11 API Well Number 50-029-20283-00-00 Inspector Name: Jeff Jones Permit Number: 177-080-0 Inspection Date: 7/3/2018 Insp Num: mitJJ180809112838 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-11Type Inj G " TVD 7311 Tubing 3214 3209 3212 3215 PTD 1770800 Type Test SPT Test psi 1828 IA 6 2496 2386 I 2368 " BBL Pum ed: 6 BBL Returned: 2.7 OA o 0 0 0 InteYVal 4YRTST P/F P Notes: 1 well inspected, no exceptions noted. ' SEtNIMP E'Llf S EP 2 0 2018 Thursday, August 09, 2018 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 25, 2014 TO: Jim ReggC ' el.J�j SUBJECT: Mechanical Integrity Tests P.I. Supervisor 14 (( 11 BP EXPLORATION(ALASKA)INC NGI-11 FROM: Johnnie Hill PRUDHOE BAY UNIT NGI-11 Petroleum Inspector Src: Inspector Reviewed Bye�::� P.1. S u p r v lc r NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-I1 API Well Number 50-029-20283-00-00 Inspector Name: Johnnie Hill Permit Number: 177-080-0 Inspection Date: 7/5/2014 Insp Num: mitJWH140706162046 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -- G 7311po 2soo 2aso 2449 Type Inj TD�ell NGIa1V TD 1770800 Type Test SPT Test psi 1828 OA o z 4 6 T - Interval INITAL p/F P Tubing 3383 - 3381 3379 3379 Notes: 3 bbls meth used SCp►INHED OCT 3 0 2014 Friday, July 25, 2014 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, July 06, 2014 9:54 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Farinez, Javier; Wallace, Chris D (DOA); Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator Subject: OPERABLE: Injector NGI-11 (PTD #1770800) Passing AOGCC witnessed MIT -IA Attachments: image003 jpg; image004.png,- image005 jpg All, Injector NGI-11 (PTD #1770800) had a passing AOGCC witnessed MIT -IA performed on July 5, 2014, demonstrating the presence of competent downhole barriers. At this time the well has been reclassified as Operable and removed from the quarterly AOGCC Not Operable Injectors Report. Please call with any questions. Thank you, Laurie Climer SCANNED BP Alaska - Well Integrity Coordinator GWGiooal e:ls arganuat.on WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Mon June 23, 2014 7:36 AM To: AK, OPS FS1 M; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations it Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Farinez, .er; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity En i eer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; 'jim.regg@alaska.gov'; AK, OPS FF Wel Comp Rep Subject: UNDER EVALUATION: Injector NG - PTD #1770800) MIT -IA Passed Post Rig Workover on NGI-11 (PTD #1770800) recently underwent a rig workover completed o 5/31/2014. The tubing was replaced during the workover and a subsequent MIT -IA passed on 06/07/2014. The passing t confirms two competent barriers in the wellbore. The well is reclassified as Under Evaluation and may be placed on gas inje n. 1 STATE OF ALASKA AL _,KA OIL AND GAS CONSERVATION CC, iSSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JUN 25 2014 1. Operations Performed: x"l ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic ❑ Development ® Service 177-080 3. Address: 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519-6612 50.029-20283-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 028302 PBU NGI-11 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field/ Pool(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary: Total depth: measured 10496' feet Plugs: (measured) None feet true vertical 8610' feet Junk: (measured) Unknown, 10425' feet Effective depth: measured 10425' feet Packer: (measured) 8697', 8850', 8943' feet true vertical 8548' feet Packer: (true vertical) 7117', 7237', 7311' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 95' 20" 95' 95' 1530 520 Surface 2744' 13-3/8" 2744' 2744' 4930 2670 Intermediate 9544' 9-5/8" 9544' 7797' 8150/6870 5080/4760 Production Liner 1296' 7" 9200'- 10496' 7516' - 8610' 8160 7020 Perforation Depth. Measured Depth: 9870' - 10318' feet True Vertical Depth: 8070'- 8454' feet Tubing (size, grade, measured and true vertical depth). 7-5/8", 29.7# x 7", 26# L-80 9008' 7362' x 5-1/2", 17# 7" MCX SSSV 2196', 2196'; Packers and SSSV (type, measured and true vertical depth): 9-5/8" x 7" HES TNT Packer: 8697': 7117` 9-5/8" x 5-1/2" Baker S-3 Packer, 8850', 7237'; 9-5/8" x 5-1/2" Baker S-3 Perm Packer 8943' 7311' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description 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: 0 226234 0 1120 3466 Subsequent to operation: 0 0 0 120 0 14. Attachments: ❑ Copies of Logs and Surveys run 15. Well Class after work: F1Exploratory ElStratigraphic ElDevelopment ® Service ® Daily Report of Well Operations 16. Well Status after work: El Oil El Gas ❑ WDSPL ® Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ WAG ® GINJ ❑ SUSP ❑ SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: Abby Warren, 564-5720 Email: Abigail.Warren@bp.com 314-277 Printed Name: Joe LastufkrA\.Title: Drilling Technologist / Signature: Date: ( /E'26/4- 564-4091 Form 10-404 Revised 10/2012 U U V mgignffty6 4 NGI-11, Well History (Pre -Rig Workover) Date Summary 05/11/14 T/I/O=SSV/250/0+, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS), pre RWO. PPPOT-T: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS, all moved freely (1 "). Single port, unable to pump through void. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. Stung into body seal test void (0+ psi), bled to 0 psi. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). PPPOT-IC: Stung into test void (300 psi), bled to 0 psi. Functioned LDS, all moved freely (1 "). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 05/15/14 PULLED 7" WFD UPPER ER STRADDLE PATCH @ 8817' SLM (-26' oal). 05/16/14 MADE 3 ATTEMPTS TO PULL LOWER ANCHOR OF 7" WFD ER STRADDLE PATCH FROM 8817' SLM. 2.5 HRS TOTAL JARRING. 05/17/14 PULLED 7" WFD LOWER ER STRADDLE PATCH ANCHOR FROM 8817' SLM (-6' oal, all intact) EQUALIZED 3-1/2" XXN-PLUG IN NIP REDUCER @ 8970' SLM / 8996' MD. 05/18/14 T/1/0=1092/184/24 Temp=S/I Assist Slickline MIT -T to 3000 psi ( PASSED) CMIT-TxIA to 4000 psi in progress (RWO EXPENSE) Pumped 5bbls meth followed by 720 bbls of 2% KCL to load TBG. Pumped 125 bbls 50/50 down TBG for Freeze protect. Pumped 15 bbls 50/50 meth water while SL RIH w/ plug.Pumped 2 bbls of 50/50 to reach test pressure. 1st 15 min TBG lost 50 psi. 2nd 15 min TBG lost 23 psi for a total loss of 73 psi. 05/18/14 PULLED 3-1/2" XXN-PLUG FROM NIP REDUCER @ 8972' SLM. PULLED 5-1/2" x 3-1/2" NIPPLE REDUCER FROM 8966' SLM / 8996' MD. LRS LOADED TBG W/ 720 BBL 2% KCL & 120 BBL 60/40 METHANOL (see Irs log). SET 5-1/2" PXN-PLUG @ 8966' SLM / 8996' MD. LRS PERFORMED PASSING 3000 psi MIT -T (see Irs log). 05/19/14 CMIT-TxIA to 4000 psi (PASSED) Pumped 4.7 bbls of 30' 50/50 down TBG to reach test pressure. 1 st 15 min TBG/IA lost 19/18 psi. 2nd 15 min TBG/IA lost 13/13 psi for total loss of 32/31 psi in 30 min. Bled back — 9 bbls. Tags hung, SL in control of well upon departure. IA OA= OTG. DSO notified, F W H P S=500/500/13. 05/19/14 SET 5-1/2" JUNK CATCHER ON P -PRONG @ 8953' SLM. LRS PERFORMED PASSING 4000 psi CMIT- T x IA (see Irs log). 05/21/14 T/1/0= 250/300/25 Temp= SI Assist E -line with Tbg punch (Pre RWO) CMIT-TxIA 1000 psi *`PASSED"". MIT -OA 2000 psi. Pressured up IA with .5 bbls of diesel to mainatain 500 psi differential between Tbg and IA before E -line punched Tbg (see log). Pumped 1.2 bbls of diesel down IA to achieve test pressure of 1000 psi for CMIT-TxIA. TxIA lost 26/26 psi in the 1 st 15 min and 8/8 psi in 2nd 15 min for a total pressure loss of 34/34 psi in 30 min test. Bled TxIA psi. Bled back— 1 bbl. Pumped 2.3 bbls crude down OA to achieve MIT -OA to 2000 psi. Established LLR of .21 gal per min. 05/21/14 INITIAL T/1/0= 150/250/0. RAN IN W/ VX 1.56" TBG PUNCHER AND SHOT TBG PUNCH HOLES @ 8832'- 8833'. GOOD INDICATION OF TBG & IA PRESSURE CHANGE WHEN SHOOTING HOLES. FINAL T/I/0= 100/200/20. WELL LEFT SHUT IN UPON DEPARTURE - NOTIFIED DSO OF WELL STATUS. Page 1 of 2 NGI-11, Well History (Pre -Rig Workover) Date Summary 05/22/14 Assist E -line with Tbg punch (Pre RWO) CMIT-TxIA 1000 psi **PASSED**. MIT -OA 2000 psi **FAILED** Pumped 2.5 bbls ambient crude down OA to achieve 2000 psi. MIT -OA results; 1 st 15 min OA lost 238 psi. 2nd 15 min OA lost 128 psi, total loss of 366 psi over 30 min test. **FAIL** Established LLR of — 0.21 gal/min. Bled back OA to 200 psi and returned 2.5 bbls crude. Valve positions: WV= closed, SV= closed, SSV= closed, MV= open, CV,s= OTG,s. FWHP= 284/376/200. DSO notified of LRS departure. 05/22/14 T/1/0=SSV/280/530. Temp =S1. WHP's (pre rig). IA has an integral installed =inspection not current. Well house removed. Tie-in crew on location to remove flowline & divert line from well for rig. SV, WV, SSV =C. MV =0. IA, OA =OTG. 17:10. 05/23/14 T/1/0=200/310/480. Set 6" "K" BPV #612, N/D tree to dryhole w/temp valve #48. Attempt to bleed I/A & O/A to 0 psi (fail) . Insall 3" Gray VR plug in I/A. CO I/A valve with temp valve #46 & install Piggy Back on I/A w/temp valve #68. Torque & test to spec. Pulled BPV per CM approval. Final WHP's 90/16/20. Drill: Perform gas line parting drill with WSL. Page 2 of 2 Printed 6/2/2014 10 23.1 OAM North America - ALASKA - BP Page 1 of Operation Summary Report Common Well Name: NGI-11 AFE No Event Type: WORKOVER (WO) Start Date: 5/23/2014 End Date: 5/31/2014 X4 -01072-E: (3,050.000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name/No.: DOYON 14 Spud Date/Time: 1/30/1978 12:00:OOAM Rig Release: Rig Contractor. DOYON DRILLING INC. UW: 500292028300 Active datum: ORIG KELLY BUSHING @44.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 11:00 13:00 (hr) 2.00 RIGD (usft) P PRE SKID RIG FLOOR INTO MOVE POSITION. 5/23/2014 -PJSM. -SKID RIG FLOOR. 13:00 - 15:00 15:00 - 21:00 2.00 6.00 MOB MOB P P PRE PRE PJSM AND MOVE RIG OFF OF WELL 15-25B. PJSM AND MOVE RIG DOWN DS 15 ACCESS ROAD, DOWN OXBOW RIG, DOWN 21:00 - 00:00 3.00 MOB N WAIT PRE WESTDOCK ROAD, TO NGI PAD. _ RIG PULLED OVER TO SIDE OF NGI PAD. WAIT ON WELL WORK AND PAD PREP -HAVING DIFFICULTY BLEEDING DOWN IA TO INSTALL DOUBLE PIGGYBACK VALVES ON OFF -RIG SIDE OF WELL. -RIG HANDS WORKING ON MP -2 WORK ORDERS. 00:00 - 06:00 6.00 MOB N WAIT PRE -REMOVE REAR DRIVING CAB FROM RIG. WAIT ON WELL WORK AND PAD 5/24/2014 PREP -HAVING DIFFICULTY BLEEDING DOWN IATO INSTALL DOUBLE PIGGYBACK VALVES ON OFF -RIG SIDE OF WELL. -RIG HANDS WORKING ON MP -2 WORK ORDERS. -REMOVE REAR DRIVING CAB FROM RIG. -HOUSEKEEPING ON RIG. 06:00 - 06:30 0.$0 MOB N WAIT PRE WAIT ON WELL WORK AND PAD PREP. -CONSULT WITH TOWN WITH PLAN 1 FORWARD TO ASSIST WITH RIG. -PLAN FORWARD APPROVED BY TOWN. 'SIMOPS -RIG HANDS WORKING ON MP -2 WORK ORDERS. -HOUSEKEEPING ON RIG. 06:30 - 07:30 1.00 MOB N ' `�VYI'AIT PRE WAIT ON WELL WORK AND PAD PREP. -SHUT DOWN WELL SUPPORT CREW AND RIGGED THEM DOWN FROM WELL. -LUBRICATOR CREW OUT AND REMOVED BACK PRESSURE VALVE FROM TREE. `SIMOPS -RIG HANDS WORKING ON MP -2 WORK ORDERS. -HOUSEKEEPING ON RIG. 07:30 1000 2.50 MOB N WAIT PRE WAIT ON WELL WORK AND PAD PREP. -VALVE CREW OUT AND INSTALLED PIGGYBACK VALVE ON IA. `SIMOPS -RIG HANDS WORKING ON MP -2 WORK ORDERS. _ -HOUSEKEEPING ON RIG. MOB N WAIT 10:00 10:30 0.50 PRE TESTING IA VALVES ON TREE. -WHILE TESTING PIGGYBACK VALVE ON TREE, THE PRIMARY VALVE STARTED LEAKING ON PACKING. -BLED PRESSURE OFF AND SECURE Printed 6/2/2014 10 23.1 OAM Ah Adk Printed 6/2/2014 10:23:10AM North America - ALASKA - BP Page 2 of 12 Operation Summary Report AL Common Well Name: NGI-11 i AFE No Event Type: WORKOVER (WO) Start Date: 5/23/2014 End Date: 5/31/2014 IX4-01072-E: (3,050,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name/No.: DOYON 14 Spud Daterrime: 1/30/1978 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292028300 Active datum: ORIG KELLY BUSHING @44.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) N WAIT PRE 10:30 - 11:30 1.00 MOB INSTALL VR PLUG IN IA SIDE. -HOOK UP TO INSTALL VR PLUG IN IA CASING. -VR PLUG LUBRICATOR DEVELOPED HYDRAULIC LEAK. -SECURED LUBRICATOR AND REMOVED FROM IA VALVE. 11:30 - 12:30 1.00 MOB N WAIT PRE WAIT ON NEW LUBRICATOR TO GET ON SITE. 'HELD PRE -SPUD MEETING NTH "A" DRILL CREW. 12:30 - 14:00 1.50 MOB N WAIT PRE INSTALL VR PLUG AND TEST. -INSTALL NEW LUBRICATOR ON IA VALVE. -INSTALL VR PLUG AND TEST -GOOD TEST. 14:00 - 16:00 2.00 MOB N WAIT PRE 'INSTALL NEW VALVES ON IAAND TEST. -INSTALL NEW MASTER IA VALVE ON TREE. !-TEST MASTER IA VALVE -GOOD TEST. -REMOVE VR PLUG. -INSTALL NEW PIGGYBACK VALVE ON IA. -TESTED PIGGYBACK VALVE ON IA -GOOD TEST. 16:00 - 18:00 2.00 MOB N WAIT PRE - PERFORM GROUNDWORK FOR PAD LEVELING AND DIRT WORK. 18:00 - 19:00 1.00 MOB N WAIT PRE HARDLINE CREWASSEMBLE HARD LINE TO - - j FLOWBACK TANK. -SET RIG MATS AROUND WELLHEAD. 2.00 MOB P PRE MATS. 19:00 - 21:00 JSHARDLEETDRIG INE CREW -TEST HARDLINE TO 250 PSI/4000 PSI -GOOD TEST. -START MOVING RIG FROM FRONT EDGE OF PAD CLOSER TO WELL. -SPOT RIG APPROXIMATELY 15 FT IN FRONT OF THE WELL. —ACCEPT RIG AT 21:00 HRS 05/25/2014 21:00 - 22:00 1.00 CONDHL P PRE RIG UP CIRCULATING LINES. -PJSM. -RIG UP CIRCULATING LINES FROM RIG TO OUTSIDE CHOKE MANIFOLD, TO IAAND TUBING, AND TO FLOWBACK TANK -LINE UP 3 VAC TRUCKS WITH 9.8 PPG BRINE TO RIG PUMP. PRE _ PRESSURE TEST LINES FROM RIG TO CHOKE 2200 00:00 2.00 CONDHL P MANIFOLD AND TREE. -PJSM. -PURGE LINES OF ALL AIR. -PRETEST TO FIND LEAKS. -PRESSURE TEST ALL CIRCULATING LINES TO CHOKE ON CHOKE MANIFOLD TO 250 PSI LOW/4000 PSI HIGH FOR 5 MINUTES EACH. 5/25/200:00 01:00 1.00 CONDHL _ P PRE -HAD TO RESTART TEST DUE TO WORKING AIR OUT OF LINES. PRESSURE TEST LINES FROM RIG TO CHOKE MANIFOLD AND TREE. -PJSM. -PURGE LINES OF ALL AIR. -PRETEST TO FIND LEAKS. -PRESSURE TEST ALL CIRCULATING LINES TO CHOKE ON CHOKE MANIFOLD TO 250 PSI LOW/4000 PSI HIGH FOR 5 MINUTES EACH. -HAD TO RESTART TEST DUE TO WORKING AIR OUT OF LINES. Printed 6/2/2014 10:23:10AM North America - ALASKA - BP Page 3 of 12 Operation Summary Rep Common Well Name: NGI-11 AFE No Event Type: WORKOVER (WO) Start Date: 5/23/2014 End Date: 5/31/2014 X4-01072-E: (3,050,000.00 ) Project: Prudhoe Bay (various) Site: NGI — Rig Name/No.: DOYON 14 Spud DateRme: 1/30/1978 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292028300 Active datum: ORIG KELLY BUSHING @44.00usft (above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 02:00 1.00 CONDHL P PRE REVERSE CIRCULATE 9.8 BRINE INTO WELL. -REVERSE CIRCULATE 9.8 BRINE INTO IA TAKING RETURNS THRU TUBING INTO FLOWBACK TANK. -ICP AT 3.5 BBLS/MIN @ 750 PSI-FCP AT 4.0 BBLS/MIN @ 970 PSI. -PUMP 95 BBLS DOWN IA. P PRE CIRCULATE 9.8 BRINE INTO WELL. 02:00 - 05:00 3.00 CONDHL -CIRCULATE DOWN TUBING TAKING RETURNS THRU IA INTO FLOWBACK TANK -ICP AT 2.0 BBLS/MIN @ 550 PSI. -FCP AT 4.3 BBLS/MIN @ 1400 PSI. -CIRCULATED TOTAL OF 600 BBLS DOWN TUBING. -@ 540 BBLS AWAY, FLUID WT OUT WAS 7.5 PPG. -@ 570 BBLS AWAY, FLUID WT OUT WAS 9.7+ PPG. -@ 595 BBLS AWAY, FLUID WT OUT WAS 9.8 PPG. 'NOTE-MONITORING OA. OA PRESSURE UP TO 1000 PSI-BLED DOWN INTO BLEED TANK TWICE. 1.§6 05:00 - 06:30 CONDHL P PRE FLOWCHECK WELL. -FLOWCHECK WELL FOR 10 MINUTES AFTER ` WELL STABILIZED-WELL STABLE. -START MONITORING IA @ 05:25 FOR UPCOMING IA WORK. -BLOW DOWN LINES FROM RIG TO FLOWBACK TANK. -. -RIG DOWN CIRCULATING LINES FROM RIG TO CIRCULATING MANIFOLD. 06:30 - 13:30 7.00 RIGU N 1(Vi4 PRE SWAP DOUBLE IA VALVES TO OFF RIG SIDE OF WELL (WORK BY DRILL SITE MAINTENANCE) -RIG DOWN PIGGYBACK IA VALVE. -SET VR PLUG IN RIG SIDE OF IA. TEST VR PLUG-TEST FAILED. -TIGHTENED UP VR PLUG IN IA. RETEST VR PLUG-TEST FAILED. -ATTACH COMPANION FLANGE AND NEEDLE VALVE TO MASTER IA VALVE ON RIG SIDE OF [A. -ATTACH VALVE ON NON-RIG SIDE OF IA ON WELL. TEST VALVE-GOOD TEST. -REMOVE VR PLUG FROM NON-RIG SIDE OF IA ON WELL. 'COMPLETED RIG EVACUATION DRILL WITH AAR WITH ALL RIG PERSONNEL ON LOCATION. -ATTACH PIGGY BACK VALVE. TEST VALVE-FACE SEAL FAILURE. SEND FOR ANOTHER VALVE. -RIG UP PLATFORM TO SET BACK PRESSURE VALVE. 13:30 - 15:00 1.50 RIGU N WAIT PRE -RIG UP AND TEST BACK PRESSURE VALVE LUBRICATOR-GOOD TEST. -SET BACK PRESSURE VALVE IN WELL Printed 6/2/2014 10:23:10AM Awk North America - ALASKA - BP qw Page 4 of 12 ) Operation Summary Repo Common Well Name: NGI-11 AFE No Event Type: WORKOVER (WO) Start Date: 5/23/2014 End Date: 5/31/2014 X4 -01072-E: (3,050,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name/No.: DOYON 14 Spud Date/Time: 1/30/1978 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292028300 Active datum: ORIG KELLY BUSHING ®44.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) I (usft) _ 15:00 - 18:00 3.00 RIGU N WAIT PRE SET PIGGYBACK IA VALVE. -ATTACH PIGGYBACK VALVE ON IA ON NON -RIG SIDE OF WELL. -TEST PIGGYBACK VALVE -SHELL TEST GOOD, INTERNAL TEST BAD. -GREASED VALVE AND WORKED SEVERAL TIMES. 3.50 -RETEST VALVE -GOOD TEST. TEST BACK PRESSURE VALVE FROM BELOW. 18 00 21 30 RIGU N WAIT PRE -RIG UP CIRCULATING LINES FROM RIG TO OUTSIDE CHOKE MANIFOLD TO IA VALVE ON TREE. -TESTALL LINES TO MANIFOLD AND TREE. -PRESSURE TEST BACK PRESSURE VALVE ON WELL FROM BELOW TO 250 PSI LOW / 13500 PSI HIGH FOR 5 MINUTES EACH. HUNT FOR LEAKS ON RIG. FOUND NONE. PRESSURE STABILIZED AFTER 20 MI NUTES-GOOD TEST. 21:30 - 23:15 1.75 RIGU N WAIT PRE FLOWCHECK, RIG DOWN LUBRICATOR. -BLEED DOWN WELL TO FLOWBACK TANK AFTER BPV TEST. -TOOK 45 MINUTES TO BLEED DOWN TO NO FLOW. -FLOWCHECK FOR 10 MINUTES -NO FLOW. -BOOM TRUCK FOR BPV LUBRICATOR 1 WOULDN'T START. HAD TO CALL BRYCE EQUIPMENT TO REPAIR. -BLOW DOWN HARD LINE TO FLOWBACK TANK. -HARDLINE CREW CHANGED OUT LEAKING "• SWING ON HARDLINE FROM CHOKE MANIFOLD TO FLOWBACK TANK. PRESSURE TESTED TO 250/4000 PSI FOR 5 MINUTES ` EACH. -HOOK UP IA TO BLEED TANK TO MONITOR FOR BUILDUP. 0.75 RIGU N WAIT 23.15 - 00:00 PRE PREP TO SPOT RIG. -RIG DOWN BACK PRESSURE VALVE LUBRICATOR. -MOVE TREE STAND AWAY FROM TREE. -MOVE PORTABLE HEATER FROM WORK AREA. -MOVE BLEED TANK AND RE -SPOT ON NON -RIG SIDE OF WELL. 5/28/2014 00:00 - 01:00 1.00 RIGU P PRE RIG DOWN TOOLS AND PREP TO SPOT RIG OVER WELL. 01:00 - 02:30 1.50 MOB P PRE SPOT RIG OVER WELL. -PJSM. -MOVE RIG FORWARD OVER WELL -CENTER RIG ONTO WELL. -SHIM RIG AND LEVEL RIG. 02:30 - 03:30 1.00 RIGU P PRE SKID RIG INTO DRILLING POSITION. -PJSM. -SKID RIG FLOOR INTO DRILLING POSITION. 03:30 - 05:00 1.50 RIGU P PRE RIG UP RIG FLOOR. -RIG UP HIGH PRESSURE MUD PUMP LINES TO RIG FLOOR. -RIG UP FLOOR STEAM, AIR, WATER AND PUMP LINES. Printed 6/2/2014 10:23:1OAM r7 North America - ALASKA - BP Page 5 of 12 Operation Summary eport Common Well Name: NGI-11AFE No Event Type: WORKOVER (WO) Start Date: 5/23/2014 End Date: 5/31/2014 X4 -01072-E: (3,050,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name/No.: DOYON 14 Spud Date/Time: 1/30/1978 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292028300 Active datum: ORIG KELLY BUSHING @44.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) PRE NIPPLE DOWN TREE. 05:00 - 07:00 2.00 BOPSUR P -PJSM. -BLEED OFF HANGER VOID. -BREAK OFF DRYHOLE TREE AND ADAPTER FLANGE. -PULL TREE AND ADAPTER FLANGE AND LAY DOWN. PRE -NIPPLE UP BOPE. 07:00 - 10:00 3.00 BOPSUR P -PJSM. -INSPECT AND VERIFY HANGER THREADS. -INSTALL K -DART IN BPV BODY BY HAND (8.5 TURNS TO LEFT TO MAKE UP). -NIPPLE UP BOPE. -MAKE UP AND INSTALL RISER AND ' FLOWLINE. i -INSTALL TURNBUCKLES ON BOP STACK PRE RIG UP TO TEST BOPE. 10:00 - 11:00 1.00 BOPSUR P -PJSM. -MAKE UP CROSSOVERS TO TEST TOP DRIVE, FOSV'S, AND DART VALVE. -FILL BOP STACK WITH WATER. '-CONDUCT SHELL TEST WITH 4" TEST JOINT AND ANNULAR ELEMENT CLOSED -GOOD TEST. PRE KOOMEY DRAW -DOWN TEST. 11:00 - 12:00 1.0� BOPSUR P -PJSM. -CONDUCT KOOMEY DRAWDOWN TEST. -FUNCTIONED AND CHECKED HIGH PRESSURE BY-PASS VALVE. 12:00 20:00 8.00 BOPSUR P _ PRE PRESSURE TEST BOPE. -PJSM. -TEST ALL BOP EQUIPMENT (EXCEPT ANNULAR) TO 250 PSI LOW, 4,000 PSI HIGH FOR 5 MINUTES EACH. -TEST ALL BOP EQUIPMENT WITH 4" AND 7-5/8" TEST JOINTS. -TEST ANNULAR ELEMENT TO 250 PSI LOW AND 3,500 PSI HIGH FOR 5 MINUTES EACH. -ONE FAILURE -INSIDE BOP DART VALVE FAILED -PROCURED REPLACEMENT AND TESTED -GOOD. -ALL TEST DOCUMENTED ON CHART. SEE ATTACHED CHARTS. -TEST WITNESS WAIVED BYAOGCC REP ROBERT NOBLE. 20:00 - 20:30 0.50 DHB P PRE INSTALL DUTCH RISER. -PJSM. -INSTALL DUTCH RISER. -CLOSE ANNULAR ELEMENT ON RISER. 20:30 - 21:30 i -RUN IN LOCK DOWN SCREWS ON RISER. PRE MAKE UP LUBRICATOR AND TOOLS. 1.00 DHB P -PJSM. -BRING UP BACK PRESSURE VALVE LUBRICATOR AND TOOLS TO RIG FLOOR. -MAKE UP ALL TOOLS ONTO LUBRICATOR. 21:30 - 22:00 0.50 DHB P PRE PRESSURE TEST RISER/LUBRICATOR. -PJSM. -PRESSURE TEST LUBRICATOR AND DUTCH RISER SYSTEM TO 250 PSI LOW/4,000 PSI HIGH FOR 5 MINTUES EACH -GOOD TEST. Printed 6/2/2014 10:23:10AM North America - ALASKA - BP Page 6 of 12 Operation Summary Report Common Well Name. NGI-11 AFE No Event Type: WORKOVER (WO) Start Date: 5/23/2014 End Date: 5/31/2014 X4 -01072-E: (3,050,000.00 ) Project Prudhoe Bay (various) Site: NGI Rig Name/No.: DOYON 14 Spud DateTme: 1/30/1978 12:00:OOAM Rig Release: Rig Contractor. DOYON DRILLING INC. UWI: 500292028300 Alive datum: ORIG KELLY BUSHING 0".00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 23:00 1.00 DHB P PRE STAND BACK LUBRICATOR. -BREAK LUBRICATOR AT QUICK TEST SUB. -STAND BACK LUBRICATOR. PJSM. -BLOW DOWN KILL LINE AND CHOKE LINE. 23:00 23:30 0.50 DHB P PRE -SUCK OUT STACK WITH RIG VAC. HOLD RIG EVACUATION DRILLANDAAR WITH 23:30 00:00 0.50 PRE RIG HANDS. PULL DART AND BPV. DHB P -CHECK IA PRESSURE -0 PSI. -PJSM. -RIG UP DRY ROD SECTIONS TO PULL DART. -PULL DART FROM BPV BODY. -MAKE UP LUBRICATOR -TEST QTS. 00:00 01:00 1.00 -PULL BACK PRESSURE VALVE. 5/27/2014 DHB P DECOMP 'LAY DOWN DUTCH RISER AND LUBRICATOR. -PJSM. -LAY DOWN DUTCH RISER AND LUBRICATOR/TOOLS. ,-MOBILIZE MULTI -STRING CUTTER BHAAND STABILIZER TO RIG FLOOR. -BLOW DOWN CHOKE AND KILL LINE, CHOKE MANIFOLD. 01:00 - 01:30 0.50 -- CUT P DECOMP MAKE UP AND RUN IN HOLE WITH MULTI -STRING CUTTER. -PJSM. -MAKE UP MULTI -STRING BHA. -RUN IN HOLE WITH MULTI -STRING BHA WITH 01:30 09:30 8.00 STABILIZER. DECOMP RUN IN HOLE WITH MULTI -STRING BHA ON 4" CUT P DRILL PIPE. -PJSM. RIH WITH BHA ON 4" DRILL PIPE, PICKING UP SINGLES FROM PIPE SHED. 09:30 11 00 1.50 -RIH FROM SURFACE TO 8,845'. DECOMP CUT 7-5/8" x 7" COMPLETION. CUT P j-PJSM WITH BAKER REP. -RIH F/ 8,845' AND TAG X OVER AT 8,870'. -P/U T/ 8,853'. -ESTABLISH PARAMETERS. 'PUW=170K, SOW --140K, RTW --158K, RPM=80 WITH 3-6K TORQ, PUMP RATE=2.8 BPM WITH 350 PSI. -LOCATE COLLAR AT 8,851'. �-CONFIRM CUT DEPTH. 11:00 12:00 1.00 CUT P DECOMP CUT 7-5/8" x 7 COMPLETION. -CUT COMPLETION STRING AT 8,854', PUMP RATE= 4.5 BPM WITH 710 PSI, RPM=80 WITH 4-7 TORQ. -INCREASE PUMP RATE TO 7 BPM WITH 980 PSI, PRESSURE AND TORQ DROPPED OFF. -SHUT DOWN ROTATION, PICKED UP ABOVE CUT AT 8,854'. 'OBSERVED KNIVES TAKE WEIGHT AT CUT. -10 MIN FLOW CHECK. WELL STABLE 12:00 14:00 2.00 CUT P DECOMP CIRCULATE WELL. -CLOSE ANNULAR PREVENTER. -CIRCULATE BOTTOMS UP THRU MGSAT7 BPM WITH 2,130 PSI. -10 MIN FLOW CHECK. WELL STABLE. Printed 6/2/2014 10.23:10AM North America - ALASKA - BP �alllli Page 7 of 12 s.,. r . F Operation Summary Report Common Well Name: NGI-11 AFE No Event Type: WORKOVER (WO) Start Date: 5/23/2014 End Date: 5/31/2014 X4-01072-E: (3,050,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name/No.: DOYON 14 Spud Date/Time: 1/30/1978 12:00 OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292028300 Active datum: ORIG KELLY BUSHING @44.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) -PJSM. 14:00 - 17:30 3.50 CUT _ P DECOMP PULL OUT OF HOLE LAYING DOWN DRILL -LUBRICATE TOP DRIVE. DRAWWORKS AND PIPE TO PIPE SHED. ST -80. 0.50 PULL P -PJSM. 01:30 02:00 DECOMP SAFETY MEETING. -POOH AND UD DP F/8,842' TO/4,093'. P DECOMP HELD KICK WHILE TRIPPING DRILL. 17:30 - 18:00 0.50 CUT -CREW RESPONSE TIME 2:15. 0200 - 02:30 0.50 PULL -HELD AAR WITH CREW. P DECOMP SLIP AND CUT DRILL LINE. 18:00 - 20:00 2.00 CUT -VOID BOP STACK OF FLUID. -PJSM. -SLIP AND CUT 59.5' OF DRILLING LINE. -ENGAGE COMPLETION STRING WITH ITCO -SERVICE AND INSPECT TOP DRIVE, BLOCKS SPEAR, TO NO-GO AT 30'. AND DRAWWORKS P DECOMP PULL OUT OF HOLE WITH MULTI-STRING 20:00 - 22:30 2.50 CUT -SET 5K DOWN. CUTTER, LAYING DOWN DRILL PIPE TO PIPE -PULL 25K OVER TO VERIFY GRAPPLE SHED. -PJSM. 1.00 PULL P -POOH AND UD DP F/4,093' T/ 10' P DECOMP LAY DOWN MULTI-STRING CUTTER. 02:30 - 03:30 22:30 - 00:00 1.50 CUT -PJSM WITH BAKER REPS. -UD MULTI-STRING CUTTER. P DECOMP RIG UP TO PULL 7-5/8" COMPLETION 5/28/2014 00:00 - 01:00 1.00 PULL EQUIPMENT. -PJSM. FLOOR. — -MOBE COMPLETION PULLING AND Printed 6/2/2014 10:23:1OAM HANDLING EQUIPMENT TO RIG FLOOR. 0.50 PULL P -RN TO PULL 7-5/8" COMPLETION. DECOMP RIG SERVICE. 01:00 - 01:30 -PJSM. -LUBRICATE TOP DRIVE. DRAWWORKS AND ST -80. 0.50 PULL P 01:30 02:00 DECOMP SAFETY MEETING. -PJSM WITH CAMERON AND BAKER REPS ON PULLING TUBING HANGER. DECOMP ENGAGE HANGER. 0200 - 02:30 0.50 PULL P -VOID BOP STACK OF FLUID. -ENGAGE COMPLETION STRING WITH ITCO SPEAR, TO NO-GO AT 30'. -SET 5K DOWN. -PULL 25K OVER TO VERIFY GRAPPLE ENGAGED. 1.00 PULL P 02:30 - 03:30 DECOMP PULL HANGER FREE TO RIG FLOOR. -CAMERON, BOLDS AND VERIFIED ALIGNMENT PIN DISENGAGEMENT. -WORK AND PULL HANGER FREE TO RIG FLOOR. 'HANGER PULLED FREE AT 375K. (100K OVER) 03:30 - 05:00 1.50 PULL P DECOMP LAY DOWN SPEAR BHA AND HANGER. -DISENGAGE SPEAR. -UD HANGER AND XO. -P/U AND M/U SAFETY JOINT WITH X -OVER. -RIH AND SPACE OUT WITH SAFETY JOINT ACROSS BOPE. -CLOSE ANNULAR PREVENTER. 2.00 PULL P _ CIRCULATE BOTTOMS UP. 05:00 07:00 DECOMP -LINE UP AND CIRC B/U THRU THE MUD GAS SEPARATOR AT 6 BPM WITH 1,130 PSI. 5.00 PULL P DECOMP 07 00 12:00 POOH WITH 7-5/8" COMPLETION. -POOH, UD 7-5/8" COMPLETION F/ 8,854' T/ 2,450'. Printed 6/2/2014 10:23:1OAM North America - ALASKA - BP Page 8 of 12; Operation Summary Repo Common Well Name: NGI-11 AFE No Event Type: WORKOVER (WO) Start Date: 5/23/2014 End Date: 5/31/2014 X4 -01072-E: (3,050,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name/No.: DOYON 14 Spud Date/Time: 1/30/1978 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292028300 Active datum: ORIG KELLY BUSHING @44.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 13:00 1.00 DHB P DECOMP M/U 9-5/8 HES STORM PACKER. -MOBE STORM PACKER TO RIG FLOOR. -M/U 9-5/8 STORM PACKER. 1.00 DHB P DECOMP-" RIH AND SET 9-5/8" HES STORM PACKER. 1300 1400 -PJSM WITH HES REP. -RIH AND SET STORM PACKER WITH 3 JTS OF 4" DP OUT OF PIPE SHED PER HES REP AT 87'. -STAND BACK STD OF DP AND UD STORM PACKER RUNNING TOOL. 14:00 - 15:00 1.00 DHB P DECOMP TEST 9-5/8" HES STORM PACKER. -PJSM WITH HES REP. -R/U TEST EQUIPMENT. TEST STORM PACKER TO 250 / 3,500 PSI FOR 5 CHARTED MINS EACH. TEST PASS. 15:00 - 18:30 3.50 BOPSUR P DECOMP NIPPLE DOWN BOP STACK -PJSM. -VOID STACK OF FLUID. -BLOW DOWN CHOKE AND KILL LINE, BLEED OFF LINE AND HOLE FILL LINE. _ -R/D BLEED OFF LINE, HOLE FILL LINE, FLOW LINE, RISER AND TURNBUCKLES. -N/D BOPE AND SECURE ON STUMP. - -SIMOPS: DSM, INSTALL VR PLUG IN RESERVE PIT SIDE OF OAAND TEST SAME 250 / 3,500 PSI FOR 5 CHARTED MINS EACH. 18:30 - 00:00 5.50 WHSUR P _ DECOMP REPLACE TUBING SPOOL AND PACK -OFF. -PJSM WITH CAMERON REPS. - -N/D TBG SPOOL. -REMOVE PACK -OFF AND REPLACE WITH GRAY NEW STANDARD PACK -OFF. -N/L1 NEW GREY STANDARD 13-5/8" 5M TBG SPOOL. 5/29/2014 00:00 - 00:30 0.50 WHSUR P DECOMP RIG SERVICE. -LUBRICATE DRAW WORKS, TOP DRIVE, BLOCKS AND ST -80. DECOMP TEST PACKOFF. 00:30 - 04:00 3.50 WHSUR P -TEST PACK -OFF 250 PSI FOR 5 CHARTED MINS AND 3,500 PSI FOR 30 CHARTED MINUTES. TEST PASS. -R/U AND TEST PIGGY BACK VALVE ON IA WORKING SIDE TO 250 / 3,500 PSI FOR 5 CHARTED MINS EACH. TEST PASS. DECOMP NIPPLE UP ROPE. 04:00 - 06:00 2.00 BOPSUR P -PJSM. -N/U ROPE. -R/U BLEED OFF LINE, HOLE FILL LINE, FLOW LINE, RISER AND TURNBUCKLES. 06:00 - 07:30 1.50 BOPSUR P DECOMP TEST BOPE BREAK -PJSM. -R/U AND INSTALL TEST PLUG. -PURGE CHOKE MANIFOLD AND CLOSE BLIND/SHEAR RAMS. -TEST BOPE BREAK TO 250 / 4.000 PSI FOR 5 CHARTED MINS EACH. TEST PASSED. -BLEED OFF PRESSURE, OPEN BLIND/SHEAR RAMS. -BLOW DOWN CHOKE AND KILL LINES. -R/U AND RETRIEVE TEST PLUG. Printed 6/2/2014 10:211OAM North America - ALASKA - BP Page 9 of 12 Printed 6/2/2014 10:23:1OAM Operation Summary Report Common Well Name: NGI-11 AFE No Event Type: WORKOVER (WO) Start Date: 5/23/2014 End Date: 5/31/2014 X4 -01072-E: (3,050,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name/No.: DOYON 14 Spud Date/Time: 1/30/1978 12:00:OOAM Rig Release: Rig Contractor. DOYON DRILLING INC. UWI: 500292028300 Active datum: ORIG KELLY BUSHING @44.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 08:00 0.50 BOPSUR P DECOMP , DERRICK INSPECTION -CONDUCT DERRICK INSPECTION AFTER 12 HOURS OF IDLE TIME DURING FREEZING RAIN CONDITIONS. 08:00 - 08:30 0.50 DHB P DECOMP RETRIEVE 9-5/8" HES STORM PACKER. -PJSM WITH HES REP. -RIH WITH 1 -STD OF OF. -M/U FOSV. -ENGAGE STORM PACKER WITH 21 -TURNS TO THE RIGHT, TO OPEN STORM VALVE. -OPEN FOSV AND VERIFY NO PRESSURE BELOW STORM PACKER. SHUT FOSV. -CLOSE ANNULAR PREVENTER. -RELEASE STORM PACKER. VERIFY NO PRESSURE. -OPENED ANNULAR PREVENTER. -POOH AND L/D FOSV, 3- JTS OF OF, _ RETRIEVAL TOOLAND STORM PACKER. 08:30 12:00 3.50 PULL P DECOMP POOH, LAYING DOWN 7-5/8" x 7" COMPLETION. -PJSM WITH DOYON CASING REP. -M/U X -OVER FOR WELL CONTROL EQUIPMENT. -POOH, L/D COMPLETION F/ 2,450'. 1'RECOVERED: 210 FULL JTS AND 1- CUT JT. 12:00 15:00 3.00 CUT P DECOMP LOAD PIPE SHED WITH 7-5/8" COMPLETION. -DEMOBE OLD 7-5/8" COMPLETION OUT OF PIPE SHED. -LOAD 74 JTS OF 7-5/8" COMPLETION. -ORGANIZE COMPLETION JEWELRY. -SIMOPS: WACHS CUT PUP JT, SEND TO UNIQUE MACHINE FOR INSPECTION. -PJSM WITH CAMERON REP. -CAMERON REP. R/U WACHS CUTTER AND CUT PUP JT. -DRIFT CUT ON PUP JT WITH 6.059" DRIFT, TO VERIFY IF DRESS -OFF RUN IS NECESSARY. `CUT DRIFTED, INDICATING DRESS -OFF RUN IS NOT NECESSARY. 15:00 16:00 1.00 RUNCOM P RUNCMP PREPARE TO RUN 7-5/8" COMPLETION. -VERIFY 7-5/8" JT COUNT AND ASSEMBLY RUNNING ORDER IN PIPE SHED. -VERIFY COMPLETION RUNNING AND HANDLING_ EQUIPMENT. 16:00 00:00 8.00 RUNCOM P RUNCMP RUN IN HOLE WITH 7-5/8" 29.7# L-80 VAMTOP HC COMPLETION. -PJSM WITH HES AND DOYON CASING REP. -PN, M/U AND RIH WITH 7-5/8" COMPLETION T/ 3,564'. 'ALL CONNECTIONS BELOW TNT PACKER, BAKER LOCKED. 'ALL VAMTOP HC CONNECTIONS TORQUE USING TORQUE TURN. Printed 6/2/2014 10:23:1OAM Ah North America - ALASKA - BP Page 10 of 12 Operation Summary Report ` Common Well Name: NGI-11 AFE No Event Type: WORKOVER (WO) Start Date: 5/23/2014 End Date: 5/31/2014 X4 -01072-E: (3,050,000.00 ) Project: Prudhoe Bay (various) Site: NGI Rig Name/No.: DOYON 14 Spud Date/Time: 1/30/1978 12:00 OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292028300 Active datum: ORIG KELLY BUSHING (j ".00usft (above Mean Sea Level) Date From -To Him Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) RUNCMP RUN IN HOLE NTH 7-5/8" 29.7# L-80 VAMTOP 5/30/2014 00:00 - 02:30 2.50 RUNCOM P HC COMPLETION. -P/U, M/U AND RIH WITH 7-5/8" COMPLETION F/ 3,564' T/ 5,395'. -CLEAN AND CLEAR RIG FLOOR OF STACK TONGS AND THREAD PROTECTORS. ALL CONNECTIONS BELOW TNT PACKER, BAKER LOCKED. 'ALL VAMTOP HC CONNECTIONS TORQUE USING TORQUE -N -TURN. RUNCOM P 02:30 - 03:00 0.50 RUNCMP SERVICE RIG. -PJSM. -LUBRICATE TOP DRIVE, DRAWWORKS AND ST -80. RUNCOM P 0300 09:00 8.00 RUNCMP f RUN IN HOLE WITH 7-5/8" 29.7# L-80 VAMTOP HC COMPLETION, -P/U, M/U AND RIH WITH 7-5/8" COMPLETION F/ 5,395' AND NO-GO AT 8,872'. 'ALL CONNECTIONS BELOW TNT PACKER, BAKER LOCKED. `ALL VAMTOP HC CONNECTIONS TORQUE USING TORQUE TURN. RUNCOM P 09 00 1200 3.00 RUNCMP +SPACE OUT AND ATTEMPT TO LAND HANGER. -- -L/D 2- JTS OF 7-5/8". -M/U HANGER ASSEMBLY AND LANDING JT. -ATTEMPT TO LAND HANGER AND TAG HIGH AT 8,857'. -ATTEMPT TO APPLY RIGHT HAND TORQUE TO COMPLETION STRING, WITH POWER TONGS AND RECIPROCATE STRING TO WORK TORQUE DOWN. -ATTEMPT TO LAND HANGER, WITH NO SUCCESS, TAG HIGH AT 8,857. RUNCOM P 1200 13 30 1.50 RUNCMP ATTEMPT TO WORK MULE SHOE INTO TUBING STUB. -PJSM WITH DOYON CASING, CAMERON AND HES REPS. -UD HANGER ASSEMBLY AND LANDING JT. -P/U AND M/U 1- JT OF 7-5/8" TO WORK TORQUE DOWN COMPLETION STRING AND VERIFY THAT THE HANGER WAS NOT HANGING UP IN THE BLIND RAM CAVITY OR BOPE. -RN STACK TONGS. -PJSM WITH DOYON CASING, HES AND CAMERON REPS. -PUT RIGHT HAND TORQUE IN COMPLETION STRING WITH STACK TONGS AND RECIPROCATE COMPLETION STRING TO WORK TORQUE DOWN. -MADE SEVERALATTEMPTS TO WORK COMPLETION STRING PAST 8,857', WITH 5K DOWN. NO SUCCESS. Printed 6/2/2014 10:23:10AM North America - ALASKA - BP Page 11 of 12 Operation Summary Report" Common Well Name: NGI-11 AFE No Event Type: WORKOVER (WO) Start Date: 5/23/2014 End Date: 5/31/2014 X4-01072-E: (3,050,000.00 ) i Project: Prudhoe Bay (various) Site: NGI Rig Name/No.: DOYON 14 Spud Date/Time: 1/30/1978 12:00 00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292028300 Active datum: ORIG KELLY BUSHING @44.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 15:00 1.50 RUNCOM P RUNCMP ATTEMPT TO WORK MULE SHOE INTO 'TUBING STUB. -NOTIFY TOWN AND DISCUSS PLAN FORWARD. -TURN COMPLETION STRING 3/4 TURN TO THE RIGHT WITH RIG TONGS, WHILE RECIPROCATING STRING TO WORK TORQUE DOWN. -PASS MULE SHOE INTO TUBING STUB 2-TIMES, WITH NO TURN APPLIED. -UD 1- JT OF 7-5/8". 15:00 - 17:00 2.00 RUNCOM P RUNCMP LAND COMPLETION HANGER. -M/L1 HANGER ASSEMBLY WITH LANDING JT. -LAND 7-5/8" COMPLETION HANGER AT 8,867'. -CAMERON, RILDS. `NO-GO SHOULDER AT 8,872'. 'PUW = 285K, SOW= 200K IN 9.8 PPG BRINE. 17:00 - 18:00 1.00 RUNCOM P RUNCMP R/U TO FREEZE PROTECT. PJSM WITH LRS CREW ON FREEZE PROTECT WELL. PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE 'QUESTIONS WITH CORRECT RESPONSES. -R/U LRS LINES TO IA. R/U LINES ON RIG FLOOR TO U-TUBE FREEZE PROTECT. LRS PRESSURE TEST LINES TO 250 / 3,500 PSI FOR 5 MINS EACH. TEST PASS. ""SPILL DRILL IN CELLAR"" 18:00 - 21:00 3.00 RUINCOM P RUNCMP FREEZE PROTECT WELLBORE. -PUMP 35 BBLS OF 80" DIESEL DOWN IA AT 1.5 BPM WITH 220 PSI. -U-TUBE FOR 1-HR. -10 MIN FLOW CHECK. WELL STABLE. -LRS VOID LINES OF RESIDUAL DIESEL. -R/D LINES AND REMOVE LANDING JT. 21:00 - 22:00 1.00 DHB P RUNCMP INSTALLTWC. -PJSM WITH DSM. -R/U DUTCH RISER AND DSM LUBRICATOR. -INSTALL TWC. 22:00 - 00:00 2.00 DHB P RUNCMP TEST TWC. -PJSM WITH LRS CREW. -LRS TEST TWC FROM BELOW TO 250 / 3,500 PSI FOR 5 CHARTED MINS EACH. TEST PASS. -SIMOPS: INSTALL FRONT BOOSTERS. 5/31/2014 00:00 - 01:00 1.00 BOPSUR P RUNCMP CLEAR RIG FLOOR. -PJSM. -CLEAN AND CLEAR RIG FLOOR OF COMPLETION RUNNING AND HANDLING EQUIPMENT. Printed 6/2/2014 10:23:10AM Ah Ah North America - ALASKA - BP Page 12 of 12 Operation Summary Report Common Well Name: NGI-11 AFE No Event Type: WORKOVER (WO) Start Date. 5/23/2014 End Date: 5/31/2014 X4 -01072-E: (3,050,000.00) Project: Prudhoe Bay (various) Site: NGI Rig Name/No.: DOYON 14 Spud Date/Time: 1/30/1978 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292028300 Active datum: ORIG KELLY BUSHING @44.00usft (above Mean Sea Level) Date From- To 01:00 - 05:00 Hrs (hr) Task Code NPT NPT Depth Phase Description of Operations _ (usft) BOPSUR P RUNCMP CHANGE LOWER PIPE RAMS IN 4.00 PREPARATION FOR NEXT WELL. -PJSM. I -CHANGE LOWER PIPE RAMS FROM 7-5/8" FIXED RAMS TO 3-1/2" x 6" VBR. 'SIMOPS SLIP AND CUT DRILL LINE. PJSM. -SLIP AND CUT 4750F DRILL LINE. -RESET AND FUNCTION TEST CROWN-O-MATIC. -SERVICE TOP DRIVE, BLOCKS, CROWN AND DRAWWORKS. 1.00 05:00 - 06:00 BOPSUR P RUNCMP NIPPLE DOWN BOPE. -PJSM. -R/D BLEED OFF LINE, HOLE FILL LINE, FLOW LINE, RISER AND TURNBUCKLES -N/D BOPE AND SECURE ON STUMP. 6.00 06:00 - 12:00 WHSUR P WHDTRE NIPPLE UP AND TEST CAMERON 13-5/8" 5M x 7-1/16" 5M ADAPTER FLANGE. -PJSM WITH CAMERON REPS. -N/U ADAPTER FLANGE. -TEST HANGER SEALS AND VOID 250 PSI FOR 5 MIN. 5,000 PSI FOR 30 CHARTED MIN. EACH. TEST PASS. -SIMOPS: R/D RIG FLOOR AND SERVICES LINES IN PREPARATION TO SKID RIG FLOOR TO MOVE POSITION. 3.00 1200 15:00 WHSUR P { WHDTRE NIPPLE UP AND TEST CAMERON 7-1/16" 5M DRY HOLE TREE. -PJSM WITH CAMERON REP. I -INSTALL 7-1/16" DRY HOLE TREE. I -FILL DRY HOLE TREE WITH DIESEL TREATED WITH HEET. -TEST TREE TO 250 / 5,000 PSI FOR 5 CHARTED MINS EACH. TEST PASS. -INSTALL JEWELRY ON TREE. -SECURE TREE AND CELLAR. -RDMO. 'TUBING, IAAND OA PRESSURES = 0 PSI. 'RIG RELEASED AT 15:00 HRS, Printed 6/2/2014 10:23:10AM NGI-11, Well History (Post -Rig Workover) Date Summary 06/02/14 T/1/0= TWC/0/0 RD Temp SV # 55 and installed 6" CIW upper tree. PT'd pass Pull TWC # 423. RDMO. See log for details Final T/1/0= 0/0/0. 06/02/14 T/I/O=TWC/0/0; Remove Piggy back IA valve and remove and replace OA valve with 3-1/8" CIW FL HWO gate valve; Final T/I/O=TWC/0/0; 06/05/14 T/1/0=495/542/0 Temp=Sl Assist Slickline (RWO EXPENSE) Rig up. 06/06/14 SET 5.625" PRN PLUG BODY (keyless) IN RN -NIPPLE @ 8806' MD. SET P -PRONG IN PRN PLUG BODY @ 8806' MD. LRS ATTEMPT TO SET HES TNT PACKER. LRS PERFORMED PASSING MIT -T TO 4000psi (see Irs log). LRS UNABLE TO GET PASSING MIT -IA. PULLED P -PRONG FROM PRN PLUG BODY @ 8806' MD. 06/06/14 Assist Slickline Circ -Out / MIT -T to 4000 psi ***PASSED*** / MIT -IA to 4000 psi ***PASSED*** (RWO EXPENSE) Pumped 5 bbls meth spear, 555 bbls of 120* 1 % Inhibited KCL, 140 bbls 92* DSL down IA taking returns up TBG to tanks. Pumped 5bbls meth, 2 bbls of diesel to freeze protect surface lines. Pumped 7 bbls of diesel down Tbg for MIT. 15 min Tbg lost 22 psi. 30 min Tbg lost 19 for a total of 41 psi in 30 min. Bled back -3 bbis of diesel. 06/07/14 Assist SSL MIT -IA to 4000 psi (RWO EXPENSE) Pumped 4.5 bbls of diesel for MIT. 15 min IA lost 65 psi. 30 min IA lost 12 psi. for a total of 77 psi. Bled back - 4.5 bbls of diesel. Slickline in control of well per LRS departure IA/OA=OTG FWHP's=100/50/0. 06/07/14 SET 5.625" PRN PLUG IN RN -NIPPLE @ 8,806' MD. APPLY 4000psi TO TBG AND SET HALLIBURTON TNT PACKER. PULLED P -PRONG FROM PRN PLUG BODY @ 8,806' MD. LRS PERFORMED PASSING MIT -IA TO 4000psi. PULLED 5.625" PRN PLUG BODY FROM RN -NIPPLE @ 8,806' MD. BAILED VISCOUS MUD FROM 8919' TO 8927' SLM W/ 3.00" & 3.50" X 10' BAILERS (recovered -4 gals of mud). 06/08/14 BAILED VISCOUS MUD & METAL CHIPS FROM 8927' TO 8952' SLM W/ 3.00" x 10' DD BAILER (recovered -15.5 gallons). RAN 5 1/2" BRUSH & 4.38" G.RING BETWEEN BAILER RUNS TO CLEAR RESIDUAL MUD/METAL FROM TBG WALL. NOTE: METAL CHIPS BAILED OUT LOOK LIKE/HAVE CONSISTENCY OF SAND BUT IT IS ALL MAGNETIC. 06/09/14 BAILED VISCOUS MUD/METAL CHIPS FROM 8950' TO 8958' SLM W/ 3.50" x 10' P.BAILER & 2.50" x 5' DD BAILER (recovered -2.5 gallons, metal marks on bailer). 06/10/14 BAILED VISCOUS MUD/METAL CHIPS FROM 8948' TO 8962' SLM W/ 3.50" x 10' PUMP & 2.50" x 10' DD/PUMP BAILERS (recovered -4.5 gallons). RAN 5 1/2" BRUSH & 4.50" G.RING BETWEEN BAILER RUNS TO CLEAR RESIDUAL MUD/METAL CHIPS FROM TBG WALL. 06/11/14 LATCHED JUNK CATCHER @ 8955' SLM, JARRED 7.5 hrs. JUNK CATCHER NOW AT 8950' SLM. 06/12/14 PULLED EMPTY JUNK CATCHER FROM 8,955' SLM. ATTEMPT TO LATCH P -PRONG... SITTING DOWN HIGH AT 8960' (PRONG AT 8965' SLM). BAILED METAL CHIPS FROM 8960' TO 8964' SLM W/ 2.50, 3.00, & 3.50" BAILERS (recovered 9 gallons). Page 1 of 2 NGI-11, Well History (Post -Rig Workover) Date Summary 06/13/14 BAIL 2 GALLONS OF MUD/METAL CHIPS OFF P -PRONG @ 8965' SLM. RAN 3.60" BELL GUIDE, 2- 1/2" JUS AND PULLED P -PRONG FROM 8965' SLM. BAIL 1/2 GAL MUD/METAL CHIPS OFF 5-1/2" PXN-PLUG BODY @ 8,970' SLM. PULLED 5-1/2" PXN PLUG BODY FROM 8970' SLM / 8996' MD. SET 5.963" R -LOCK W/ 7" MCX (SER# BPX-721, 2.50" BEAN) SSSV @ 2196' MD. NOTE: 5.625" GS REQUIRED TO PULL 5.963" R -LOCK (5.625 GS IS AT BP WLB). PERFORM SUCCESSFUL DRAW DOWN TEST. Page 2 of 2 TTfE= 6-318"CNV VAILFEAD =._ 8' ACTUATOR= ......... ............._GRAY BAKRE C 09/25184 N1ES BF. ELIN 400• EST. TOP OF ARCTIC SET2179'2196' 2_950' Max Angle = 52" � 7598' Datwn HU . 10783' Datum TVD = 8800' SS ' CONDUCTOR, ID= 7-5/8" TBG -PC, 29.7#, L-80 VAM TOP HC, .0459 bpf, D = 6.875" 9-518" CSG, 47#, L-80 NT95HSINSCCI BTC -M, D = 8.525" 13-318" CSG, 72#, N-80, ID = 12.347" 17-5/8' TBG -IFC, 29.7#, L-80 VA TOP HC, 0459 bpf, D = 6.875' N G' S— V NOTE: WELL REQUIRES A SSSV :'• — ■ 8' RELD NGL DISPOSAL WELL*** 06/03/14 DLY PJC TREE CIO 09/25184 N1ES 8822' 400• EST. TOP OF ARCTIC SET2179'2196' 8850' 9-518'X 7" BKR S-3 PKR RWO 06/17/14 CJN/JMD PULLJC/FLUG(6/12-13114) w 1K-22 ANCHOR LATCH, ID fi.00" 7' TUBING STUB (FUG TAG 051XX/14) 885d• 7' HES R NIP D = 5.963"w 05/31/14 / 7" MCX (SER # BPX-721, 2.50" BEAN) SSSV J2373' 5-112" TBG, 17#, L-80 TCU, .0232 bpf, D = 4.892" 8867 06!03114 $862' 7" X 5-1/Z" XQ D = 4,880" 2212234$' 7- TBG, 32#, T-95 VT, .0361 bpf, 10 = 6.07" $8&2' 5-1/2' TBG, 17#, L-80 TCU, .0232 bpf, D = 4.892" 8896' 8899' 9-5/8" X 5-1/2' UNIQUE OVERSHOT 5-1/2" TBG STUB (TAGGED 11/06104) 8894 $g27• 5-112" TIW SBRw/BKR 8665' —{7" HES R NtP, D = 5.963" K-22 ANCHOR LATCH, D = 4.750" NALCO RBP DRAG BLOCK( X 1' X 112") $943' 9-5/8" X 5-1/2' BKR S-3 PERM PKR, 8649' 8697' 9-5/8" X 7" FSS TNT PKR D = 5.90' 8733' 7" HES R NI', D = 5.625" Minimum ID = 4.455" @ 8996'- REV BY $$06• r FiES RN NP, D= 5.50" 5-1/2" OTIS XN NIPPLE 03/12178 PKR 141 INITIAL COMPLETION 06/03/14 DLY PJC TREE CIO 09/25184 N1ES 8822' 7" TBG, 26#, L-80 TCI, .0383 bpf,D = 6.27fi' 8825' 08/03192 8850' 9-518'X 7" BKR S-3 PKR RWO 06/17/14 CJN/JMD PULLJC/FLUG(6/12-13114) w 1K-22 ANCHOR LATCH, ID fi.00" 7' TUBING STUB (FUG TAG 051XX/14) 885d• RWO 05/31/14 D-14 8867' 5-1/2"HALF MULESHK)E D=4,990" 5-112" TBG, 17#, L-80 TCU, .0232 bpf, D = 4.892" 8867 06!03114 $862' 7" X 5-1/Z" XQ D = 4,880" DRLG HO COR[T{CTIONS 7- TBG, 32#, T-95 VT, .0361 bpf, 10 = 6.07" $8&2' 5-1/2' TBG, 17#, L-80 TCU, .0232 bpf, D = 4.892" 8896' 8899' 9-5/8" X 5-1/2' UNIQUE OVERSHOT 5-1/2" TBG STUB (TAGGED 11/06104) 8894 $g27• 5-112" TIW SBRw/BKR POSSIBLE FISH BEHIND 5-1/2' STUMP ?7? — K-22 ANCHOR LATCH, D = 4.750" NALCO RBP DRAG BLOCK( X 1' X 112") $943' 9-5/8" X 5-1/2' BKR S-3 PERM PKR, 8949 7" MLLOUT EXTENSION, ID = 6.00" 8979' 5-1/2" PARKER SWS NIP, ID=4.562' $996' S-112" OTIS XN NI? D = d.445" 5-1/2" TBG, 17#, L-80 BTC, .0232 bpf, D = 4.892' 9008' 9008' 5-112" WLEG, D = 4.892 TOP OF 7" LNR 9200' ��—I f3MD TT NOT LOGGED 9200` 9-5/8" X 7" BOT MG HGR w / 6' TRK, D = ? 9-5/8" CSG, 47#, JL -95 /N-80 BTRS, D = 8.681" 1—{ 9544' PERFORATION SUMMARY REF LOG: BHCS ON 02/28/78 ANGLE AT TOP Fes: 33° @ 9879 Note Refer to Production DB for historical perf data SIZE I SFS I INTERVAL I Opn/Sqz I SHOT I SQZ G"l�:✓ILe3��3i7:7i�.��7:7�1 f7�If►7��t•�1 PBTD10425' 7" LNR, 29#, N-80 BTRS, .0371 bpf, ID = 6.184"10496' 9793' —�7" MARKER JOINT 981 7" MARKER JOINT 10425' 1—{ FISH (4" SV PIN / FLAPPER (4/26106) DATE REV BY COMMENTS DATE REV BY S 03/12178 PKR 141 INITIAL COMPLETION 06/03/14 DLY PJC TREE CIO 09/25184 N1ES RWO 06/04114 AWr PJC FINAL ODEAPPROVAL 08/03192 AID 4 RWO 06/17/14 CJN/JMD PULLJC/FLUG(6/12-13114) 11/09/04 N4E5 RWO 05/31/14 D-14 1 RWO 06!03114 PJC DRLG HO COR[T{CTIONS PRUDHOE BAY UNIT WELL: NGI- 11 PERIAT No: 1770800 API Na: 50-029-20283-00 SEC 1, T11 N, R14E, 254' FSL & 890' FWL BP Exploration (Alaska) NGI-11 PEWORATION SUMMARY REF LOG: BHCS ON 02/28/78 ANGLE AT TOP PE21=: 33" @ 9870' Note: Refer to Production DB for historical pert data SIZE SPF INTFRVAL Opn/Sqz SHOT SOZ 3-318" 4 9870-9900 O 05/10/79 RWO 06/17/14 CJN/JMD PULL JC / PLUG (6/12-13/14) 4 9906-9918 O 05/22187 05/31114 3-3/8" 4 9918-9948 O 05/10/79 DRLG HO CORRECTIONS 4 9948-9964 O 05/22/87 3-3/8" 4 9964-9984 O 05/10/79 4 9984-10000 O 05/22/87 3-318" 4 10000 - 10040 O 05/10/79 4 10040 - 10066 O 05/22/87 3-3/8" 4 10066 - 10086 O 05/10/79 4 10086 - 10098 O 05/22/87 3-3/8" 4 10110 - 10130 O 05110!79 3-318" 4 10150- 10160 O 05/10179 3-318" 4 10190- 10200 O 05/10/79 3-3/8" 4 10212 - 10232 O 05/10/79 3-3/8" 4 10264 - 10280 O 05/10/79 3-3/8" 4 10304 - 10318 O 05/10/79 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/12/78 PKR 141 INITIAL COMPLETION 06/03/14 IDLY PJC TREE CIO 09125/84 N1ES RWO 06/04/14 AW/ PJC FNAL ODEAPPROVAL 08/03/92 AUDI 4 RWO 06/17/14 CJN/JMD PULL JC / PLUG (6/12-13/14) 11109/04 WES RWO 05/31114 D-14 RWO 06/03/14 PJC DRLG HO CORRECTIONS PRUDHOE BAY UNIT WELL: NGI-11 PERMIT No:'1770800 API No: 50-029-20283-00 SEC 1, T1 1N, R14E, 254' FSL & 890' FWL BP Exploration (Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Monday, June 23, 2014 7:36 AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 GAS INJ OPERATOR; Farinez, Javier; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA); AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Injector NGI-11 (PTD #1770800) MIT -IA Passed Post Rig Workover MR NGI-11 (PTD #1770800) recently underwent a rig workover completed on 05/31/2014. The tubing was replaced during the workover and a subsequent MIT -IA passed on 06/07/2014. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Under Evaluation and may be placed on gas injection. Plan forward: 1. Operations: Place well on injection 2. Fullbore: Perform AOGCC Witnessed MIT -IA once well is online and thermally stable Please use caution while placing the well on injection due to fluid packed annuli. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator SCONED GWGlobal Wells Organization Office: 907.659.5102 WIC Email: AKDCWeIIlntegrityCoordinator@bp.com From: AK , &C Well Integrity Coordinator Sent: Satur y, March 01, 2014 2:21 PM To: AK, OPS 1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 D s Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operati s Team Lead; AK, D&C Wireline Operations Team Le Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Eng AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specl ts; AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 S INJ OPERATOR; Farinez, Javier; 'chris.wallace@alas ov' Cc: AK, D&C DHD Well Int ity Engineer; AK, D&C Well Integrity Coordinator; AK, C Projects Well Integrity Engineer; 'jim.regg@alaska.gov'; AK, OP Well Ops Comp Rep Subject: NOT OPERABLE: Gas Inje r NGI-11 (PTD #1770800) Tubing x Inner Annulus munication All, Injector NGI-11 (PTD #1770800) has reached the en f the 60 day monitoring period granted by the A GCC to evaluate tubing x inner annulus communication. The inner annul luid level and pressures were monitored durin this time and it has been determined that the well has tubing x inner annu communication. The inner annulus fluid le has dropped and gas has been present in all bleeds that have taken p e during the monitoring period. The well is 4 THE STATE GOVERNOR SEAN PARNELL Dave Bjork Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU NGI-11 Sundry Number: 314-277 Dear Mr. Bjork: Alacka 011 and Gas 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fox: 907.276.7542 Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this S day of May, 2014. Encl. Sincerely, Cathy P. Foerster Chair SCANNEV, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 GE��'L.D m 3 0 20141 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program AOGCG ❑ Suspend ❑ Plug Perforations ❑ Perforate ® Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic ❑Development ®Service - 177-080 3. Address: 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 9 50.029-20283-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU NGI-11 - Will planned perforations require a Spacing Exception? ❑ Yes No 9. Property Designatior 10. Field / Pool(s): ADL 028302 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft) Effective Depth TVD (ft): Plugs (measured): Junk (measured) 1 10496' • 8610' 1 8548' 8996' Unknown, 10425' Casing Length Size MD ND Burst Collapse Structural Conductor 95' 20" 95' 95' 1530 520 Surface 2744' 13-3/8" 2744' 2744' 4930 2670 Intermediate 9544' 9-5/8" 9544' 7797' 8150/6870 5080/4760 Production Liner 1296' 7" 9200'- 10496' 7516' - 8610' 8160 7020 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9870'- 10318' 8070'- 8454' 7-5/8", 29.7# x 7", 26n x 5-1/2", 17# L-80 / 13Cr80 9008' Packers and SSSV Type: 9-5/8" x 7" Baker SAB -3 Packer; Packers and SSSV 8851'/ 7238' 9-5/8" x 5-1/2" Baker S-3 Perm Packer MD (ft) and ND (ft): 8943'/ 7311' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑Exploratory ❑Stratigraphic [I Development ®Service El Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation May 20, 2014 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged ❑ Gas ® GINJ ❑ GSTOR ❑ Abandoned 16. Verbal Approval: Date ❑ WAG ❑ SPLUG ❑ Suspended Commission Representative: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Abby Warren, 564-5720 Printed Name: Dave Bjork Title: Engineering Team Leader Email: Abigail.Warren@bp.com Signature: Phone: 564-5683 Date: 1G Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 1 2.1 -7 Sundry Number: l ,�� Elb Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance RBDMA�W 8 2014 Other: le) <sszd /L/lIT�tt r��`�-<</ �frtr �fQ��l��< J Spacing Exception Required? ❑ Yes ❑ No Subsequent Form Required: l d _ D ZT i 0 APPROVED BY _ Approved By: r ` COMMISSIONER THE COMMISSION Date: Form 10-403 Revised j2012 ApproU ftila&[NdAt months from the date of approval r Submit In Duplicate��s Sundry Request for tubing Swap on an Injector Well: NGI-11 Date: 4/17/2014 Engineer: Abby Warren MASP: 2500 psi ---}---- s Injector Estimated Start date: May 20'h, 2014 History: Well NGI-11 is a high pressure gas injector that was completed in 1978. The well most recently had a RWO in 2004 to repair AnnComm issues. In 2012 the well showed rapid IA pressure buildup when the IA pressure was bled below 1000 psi. During November and December, 2011, the IA was bled down several times to check for pressure buildup. The pressure would build up to 1000 psi in a couple of days. A caliper log was run on Jan. 6, 2012 and indicated good tubing. The well passed aMIT-IA on Jan. 10, 2012 and a PPPOT-T on Dec. 3, 2011. A patch was set in late 2012 from 8,817 fo_ 6,$46 however the IA presure continue to increase until the well was no longer manageable by bleeds. Recent integrity testing to liquids where all successful and a LDL with gas was run in March 2014 with no leaks discovered. Because the current tubing has no premium threads the assumption is that there might be multiple small leaks at the threads making it technically challenge to determine the leak point and pursuing the patching options. The well is currently not operable and this is critical well for the field operations since i t is one of the two wells require for NGL re-injection. Also the well must be operable for the CGF TAR and the NGI system restoration project. Scope of Work: Pull the 7" x 7-5/8" tubing from prerig tubing cut. Run new 7" x 7-5/8" plastic coated tubing stacker packer completion. Pre Rig Prep Work: Task W PPPOT-T&IC, Function LDS S Pull the 7" WFD Patch at 8817 (set 10/26/12). Pull the 3-1/2" XXN plug at 8996', pull the nipple reducer at 8996'. Run a SBHPs. Set a 4.56" PX plug at 8875' F CMIT-TxIA to 4000 psi. S If a passing CMIT-TXIA is achieved, set a junk catcher E Jet cut tubing at 8845' F Circulate wellbore to 9.8 ppg brine, circulate in freeze protect, post cut CMIT-TxIA to 1000 psi. V Set BPV 0 Pull well -house, flow -line, prep pad for the rig. Proposed RWO Procedure: 1. MIRU Doyon 14. ND tree. NU and test BOPE with four preventers configured top down (annular, 3- 1/2" x 6" VBRs, mud cross and 7-5/8" fixed rams). Test the VBRs to 4000 psi and the annular to 3500 -psi. 2. Pull 7" x 7-5/8" L-80 tubing from pre-RWO cut 8845' MD. 3. LD 5000' of tubing, hang remainder of tubing off of stormpacker and test the packer. 4. Perform tubing spool swap, pull stormpacker 5. Continue LD old tubing from cut. 6. Run new premiup threaded 7" and 7-5/8" plastic coated tubing. Packer set at 8620' MD 7. Freeze protect — �— 8. Set BPV. ND BOPE. NU and test tree. RDMO. — �v �� "� ` c h a r Post rig Work V Pull BPV S Set TTP in the RN nipple, Set Pkr, Pull TTP, Pull Junk catcher, Pull PX Plug F A/SL: Circ in Pkr Fluid, Press Set Pkr, MIT's TTS = CMV VVELLFEAD = GRAY ACTUATOR = BAKER OIB. B" SPF BF. ;U2348 KOP = 2959 Maz Angie = 52" @ 75W Datum MD = 10783' Datum TVD = 8800 SS 9-5/8" CSG, 47#, L-80 NT95HS, D = 8.525" NOTE SEE DRLG FILE FOR THREAD LIST 2373' 13-3/8' CSG, 72#, N -8O, ID = 12.347' 2744,• I7-5/8' TBG4PC, 29.7#, L-80, .0459 W ID = 6.919" —j 8816' 7" WFD ER PATCH, D = 3.958" (10/26/12) j17' - 884C N G I-11 SAL �� SPOSALWRr** SSSS. REF LOG: BHCS ON 02/28/78 ANGLE AT TOP PH2F: 33° @ 9879 NDte: Refer to Production DB for historical pert data EST. TOP OF ARCTIC SET CEMENT SPF 75/8" x r XO, D = 6.276• ;U2348 r DBS NO GO NIP, ID = 6.000" SQZ T x 7-5I8' �, D = 6.276• - 95/8' NALCO ES CEMENTER, D = 8.50- ('Minimum ID = 2.75" @ 8995' j 5-1/2" X 3-1/2" NIP REDUCER hJ 15-112' TBG, 17#, L50, ID = 4.892- 8896- 15-112- TBG STUB (TAGGED 11/06/04 .88844 POSSIBLE FISH BEHIND 5-112" STUMP ??? NALCO RBP DRAG BLOCK (6" X 1' X 1/2") 5-1/2" TBG, 17#, L-80 BTC, .0232 bpf, 10 = 4.892 - TOP OF r LNR 9-518" CSG, 47#, JL -95 /N-80 BTRS, D = 8.681 1 9544 1 PERFORATION SUMAARY REF LOG: BHCS ON 02/28/78 ANGLE AT TOP PH2F: 33° @ 9879 NDte: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 3-3/8" 4 9870-9900 O 05/22/87 5 1/2- NESX 7NIP. 3-318" 4 9964-10098 O 05/22/87 3-3/8" 4 10110 - 10130 O 05/10/79 3-3/8" 4 10150 - 10160 O 05/10(/9 3-3/8" 4 10190 - 10200 O 05/10/79 3-318" 4 10212 - 10232 O 05/10/79 3-3/8" 4 10264 - 10280 O 05/10/79 3-3/8" 4 10304 - 10318 O 05/10/79 PBTD I-1 10425- 7' LNR, 29#, N-80 BTRS, .0371 bpi, D = 6.184"I 10496' 8816' 7-5/8' X T X4, D = 6.276' 8828• 7' HES R NIP, D - 5.963' (BEHOW PATCH) DATE REV BY COMuBTTS 03112178 PKR 141 INITIAL COMPLETION 1 • 7-5/8- X 7- XO, D = 6.220• $850• K-22 ANCHOR TBG SEAL NIP, ID= 6.000' SAB -3 PKR, D = 6.000" _8W2- SL� 10131/121 PJC I DRAWING COWFTIONS/ PATCI-tETC 8875• 5 1/2- NESX 7NIP. 8899• I—j9-5/8" X5-1/2- UNIQUE OVERSHOT $927 5-112' TIW SBR ASSY W/BKR K-22 ANCHOR LATCH, ID = 4.750' 9-5/8' X 5-1/2" BKR S-3 PERM PKR, ID = 4.75^ $949' 7• MILLOUT EXTENSION, ID = 6.00" 8979' 5.1/2- PARKER SWS NIP, ID = 4.562' 8895• 5.112- X 3-1/2- NIP REDUCER, ID = 2.75" 889G• 5 1/Z- OTIS XN NP, ID = 4.450' 8996'3-1/2" XXN PLUG (03/28/14) l� 5-1/2' WLEG, ID = 4.89 ELMD TT NOT LOGO 9793' -�7- MARKER JOINT 9$12' 7- MARKH2 JOINT 10425' I-JFISH (4" SV PN / FLAPP3T (4/26/06) PRUDHOE BAY UMT WELL: NCA 11 PERMT ND: 1770800 API No: 50-029-20283.00 SEC 1, T11N, R14E, 254' FSL & 890' FVVL DATE REV BY COWENTS DATE REV BY COMuBTTS 03112178 PKR 141 INITIAL COMPLETION 04/07/14 MAID SET 3.1/2" XXN PLUG (3/28/14) 09/25/84 Ni ES WO 04/30/14 JMD 9-5/8' CSG CORRECTIONS 08/03/92 ALU 4 RWO 11/09/04 WE5 RWO 10131/121 PJC I DRAWING COWFTIONS/ PATCI-tETC BP Exploration (Alaska( 12/20/13 BF/JMD I PATCH DEPTH COF41EMK C 11 TREE= CNV Wf311fAD= GRAY ACTU'kTOR= —BAKB2 OKB. E EV = — 44' BF- H.EV = Opn/Sqz KOP = --_—__2_950' M3_x Angle = __ 52" @ 7598' Datum KU = ----10783 Datum TVD = 8800' SS 9-5/8" CSG, 47#, L-80, ID = 8.525" NOTE: SEE DRLG FILE FOR THREAD LIST 13-3/8" CSG, 72#, N-80, ID = 12.347' 2373' 1 1 2744' 1 7-5/8" TBG -IPC, 29.7#, L-80, VamTopHC, ID = 6.875'1--1 8635' 5-1/2" TBG, 17#, L-80 BTC, .0232 bpf, D = 4-892"�--8821 5-1/2" Haff Wle Shoe86860 I5-1/2" TBG, 17#, L-80, ID = 4.892' It 8896' 5-1/2" TBG STUB (TAGGED 11/06/ ^8894 POSSIBLE FISH BEHIND 5-1/2" STUMP ??? HALCO RBP DRAG BLOCK (6" X 1' X 1/2") 5-1/2" TBG, 17#, L-80 BTC, .0232 bpf, 4,892-1—F— 9OW OW TOP OF 7" LNR 9200- 9-518- CSG, 47#, JL -85 1N-80 BTRS, ID = 8.681" 1—� 9544• PERFORATION SUMuMRY PB7D FEF LOG: BRCS ON 02/28/78 ANGLE AT TOP PERF: 33' Q 9870' Note: Refer to Production DB for historical pert data SIZE SPF NTERVAL Opn/Sqz SHOT SQZ 3-3/8" 4 9870-9900 O 05/22/87 8862' 3-3/8" 4 9964-10098 O 05/22/87 8927' 3-3/8" 4 10110 - 10130 O 05/10!79 $3• 3-3/8" 4 10150 - 10160 O 05/10/79 3-318" 4 10190 - 10200 O 05/10/79 3-3/8" 4 10212 - 10232 O 05/10/79 3-3/8" 4 10264 - 10280 O 05/10/79 3-3/8" 4 10304 - 10318 O 05/10/79 NG I -11 SAL NOTE WELL REQUIRES A SSSV. Proposed RWO *8*HELD NGL DISPOSAL WELL*** % l 22' I( I 400' EST. TOP OF ARCTIC SET CEMENT 10425- 7- LNR, 29#, N-80 BTRS, .0371 bpf, D = 6.184" 10496' 2200' 7" FES 'R' NP, D = 5.963- 2348- 1-195/8• HALCO ES CEMENTER, ID = 8.50• 8635' x-17-518" X 7', ID = 6.276" r— 8691' DATE REV BY COMMENTS 7" HES 'R' NIP, ID = 5.963" 8706' 9-5/8• x 7" HES TNT, ID = 5.90` 09/25/84 N1 ES RWO 8806' 7" HES 'RN' ID = 5.50` 8846' 7• c ut joist $$rj1• 95/8' X 7" BKR SAB -3 PKR, ID = 6.000' 8862' 7- X5-1/2" XO, ID 8875' 45--1/2--H—ES X NIP, D = 4.562" $$�• 9-5/8' X5-1/2" UNIQUIE OVERSHOT 8927' 5-1/2" TIW SBR ASSY W/BKR K-22 ANCHOR LATCH, ID = 4-750' $3• 95/8' X5-1/2' BKR S-3 PERM PKR, ID = 4.75' 8949" 7- MILLOUT EXTENSION, ID = 6.00' 89� 5-1/2' PARKER SWS NIP, ID = 4.W6— 89%' i-1 1/2' OTIS XN NIP, ID = 4.450' 900$• 115-1/2" WLEG, ID = 4.892" 9793' -17' MARKER JOINT 9$12• 7' MARKER JOINT 10425' 1—I FISH (4" SV PIN/ FLAPPER (4/26/06) PRIJDHOE BAY UNIT WELL: NGI-11 PERW No: 1770800 AR No: 50-029-20283-00 SEC 1, T11 N, R1 4E, 254' FSL 8 899 FWL DATE REV BY COMMENTS DATE REV BY COMMENTS 03/12/78 PKR 141 INITIAL COMPLETION 04/07/14 DW/JMD SET 3-1/2" XXN RUG (3128/14) 09/25/84 N1 ES RWO 08/03/92 AUDI 4 RWO 11/09/04 NOES RWO 110/31/121 PJC DRAWNG CORRECTIONS/ PATCH ETC BP Exploration (Alaska) 12/20/13 BF/JMD I PATCH DOTH CORRECTIONS 1 3 1/8' 5000 F 3 1/8' 5000 RIG FLOOR 33.7 ' AGL BOP STACK ELEVATION 150 PSI HYDR. RATED KNIFE GATE VALVE 7G'D VENT UNE 13 5/8'. 5000 PSI, HYDRIL ANNULAR BDP, STUDDED TOP/FLANGED BOTTOM FLANGED TDP 13 5/8•. 5000 PSI, 10' MPL OPERATORS, HYDRIL PIPE RAM 13 5/8-, 5000 PSI, 14' MPL OPERATORS. HYDRIL BUND SHEAR RAL STUDDED BOTTOM BX 160 3 1/8' 5000 PSI NCR VALVE 2' KILL UNE 3 1/8' 5000 PSI GATE VALVE SINGLE 13 5/8'. 5000 PSI, 10' NPL OPERATORS, HYDRIL PIPE RAM STUDDED BOTTDM/FLANGED TOP BX ABO SURFACE DIVERTER CONFIGURATION —21 1/4•. 2000 PSI, NSPHYDRIL 8OP/DNERTER STUDDED TOP/RANGED BOf10M —RANGE/RANGE RX 73 ACCUMULATOR: NL SHAFFER, 180 GAL, 6 STATION TRIPLEX PUMP: 575 VAC, 30 HP AIR PUMP: 1, NL SHAFFER ACCUMULATOR MANIFOLD 18 BOTTLES, 10 GALLONS EACH NITROGEN BACKUP BOTTLES VALVE LEGEND 1 BYPASS 2 KILL 3 CHOKE 4 BOTTOM RAMS 5 BLIND RAMS 6 TOP PIPE RAMS 7 ANNULAR O O O BT PA55 • • • • • • U 1500 3000 • D REMOTE PANEL IN DOGHOUSE AND UTILITY MODULE wayon UPBNE BOP SRpi lsarz ero �� M10IFX.T RIG 14 BOP SYSTEM XE aYAF /IaL 1IE: X CH A srwa AND CONTROL oaIIIK ro MRBf10 WE tl6IN19,F0 BY 11/28/98 RPR RPR LFA srvNE — ar oBc. No NTS JTFI R1.4BOPSYSACONTT 1V)0P:Ps7 1P?1LL1#7G LOC. MATERIAL LIST Item Description A 3-1/16' 10M Remote Operated Hydraulic Choke B 3-1/8" 5M Adjustable Choke 1 2-1/16" 5M Manual Gate Valve 2-14 3-1/8" 5M Manual Gate Valve RIG - 14 Divert Line From BOP's a Divert Line 9 To Mud/Gas Separator 1 LEDGEND 1 White Handle Valves Normally Open Red Handle Valves Normally Closed IF Date: 07-08-10 Rev. 2 40 PROACTIVE DIAgNOSTIC SERVICES, INC. To: AOGCC Makana Bender 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 DATA LOGGED / /2014 M K BENDER APR 18 2014 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2-1 900 Benson Blvd. Anchorage, AK 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 26 -Mar -14 NGI-1 1 BL/ CD 2) LeakPointTm Survey 29 -Mar -14 17-08 8L/ CD Signed Print Name: 50-029-20283-00 50-029-20602-00 Date : \% I 1`q PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGECU MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D.\Archives\MasterTemplateFi les\Templates\Distdbution\TransmittalSheets\BP_Transmit. docx Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Thursday, March 27, 2014 10:48 AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 GAS INJ OPERATOR; Farinez, Javier; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA): AK. OPS FF Well Ops Comp Rep Subject: NOT OPERABLE: Injector NGI-11 (PTD #1770800) Leak Detection Log Complete 21 The leak detection log is complete on injector NGI-11(PTD #1770800). The well is reclassified as Not Operable and must be shut in and locked out. Thank you, Jack Disbrow BP Alaska -Well Integrity Coordinator SCANNED G/� � Global Wells �0 N Organization Office: 907.659.5102 WIC Email: AKDCWeIIlntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, March 26, 2014 1:40 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 GAS INJ OPERATOR; Farinez, Javier; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; 'jim.regg@alaska.gov'; AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Injector NGI-11 (PTD #1770800) Pressurize Tubing With Injection Gas All, Injector NGI-11 (PTD #1770800) is suspected of having tubing x inner annulus communication. In order to determining the location of the communication a leak detection log will be performed. Because the well passes MIT-IAs with fluid, the LDL will be performed with injection gas in the tubing. There is a tubing tail plug set, and the tubing will be pressured up against the plug. Injection into the formation is not allowed. The well is reclassified as Under Evaluation in order to pressurize the tubing with injection gas. Once the leak detection log is complete and it is determined that the data is accurate, the well will be made Not Operable and the wing valve shall be locked out. Thank you, Jack Disbrow (Alternate: Laurie Climer) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.comj Sent: Saturday, March 01, 2014 2:21 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 GAS INJ OPERATOR; Farinez. Javier; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA); AK, OPS FF Well Ops Comp Rep Subject: NOT OPERABLE: Gas Injector NGI-11 (PTD #1770800) Tubing x Inner Annulus Communication Attachments: NGI-11 (PTD #1770800) TIO Plots.docx; NGI-11 (PTD #1770800) Wellbore Schematic.pdf All, Injector NGI-11 (PTD #1770800) has reached the end of the 60 day monitoring period granted by the AOGCC to evaluate tubing x inner annulus communication. The inner annulus fluid level and pressures were monitored during this time and it has been determined that the well has tubing x inner annulus communication. The inner annulus fluid level has dropped and gas has been present in all bleeds that have taken place during the monitoring period. The well is reclassified as Not Operable until the tubing x inner annulus communication is resolved or an administrative approval is approved. Plan forward: Slickline: Secure with tubing tale plug Eline/Slickline: Pull and reset tubing patch A copy of the TIO plot and wellbore schematic are included for reference. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator GGlobal( /►/ Wells Y Y Organization Office: 907.659.5102 WIC Email: AKDCWeIIlntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Tuesday, December 31, 2013 3:16 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 GAS INJ OPERATOR; Farinez, Javier; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; 'jim.regg@alaska.gov' Subject: OPERABLE: Gas Injector NGI-11 (PTD #1770800) MITIA Passed on Tnjector NGI-11 (PTD #1770800) passed a MITIA on 12/09/2013. The passing MITIA proves two competent barriers in the wellbore, however, the fluid level in the inner annulus continues to fluctuate. We have permission from the AOGCC to continue injecting gas for 60 days while monitoring for fluid level fallout and to gather additional information that may assist in identifying a potential leak, or to apply for an Administrative Approval. The well is reclassified as Operable for this monitoring period. Plan forward: 1. DHD: Obtain fluid levels weekly for 60 days. 2. APE / WIC: Evaluate well for repair options A copy of the TIO plot is included for reference. Please call with any questions. Thank you, Jack Disbrow BP Alaska -Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email: AKDCWellinteerityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, November 21, 2013 11:20 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Farinez, Javier; G GPB FS1 Drillsites; 'chris.wallace@alaska.gov'; 'jim.regg@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Gas Injector NGI-11 (PTD #1770800) Low IA Fluid Level All, Injector NGI-11 (PTD #1770800) has been found to have inner annulus fluid level of 900 ft with TBG/IA/OA = 3377/840/40 psi. Due to this depth and the higher IA pressures seen, the well is reclassified as Under Evaluation for further diagnostics. Plan Forward: 1. Fullbore: Load IA, MIT -IA 2. DHD: Pending a passing test, monitor IA fluid level for up to 21 days 3. WIE: Further diagnostics as needed. Copies of the TIO and Injection plots, and wellbore schematic have been included for reference. Please call with any questions. Thank you, Laurie Climer BSP Allajska - Well Integrity Coordinator GW0r(gafllzal:011 WIC Office: 907.659.5102 WIC Email: AKDCWelllnteprityCoordinator@BP.com 4.000 3.000 2.000 1.000 ODD 3.000 2.LYG i 0O6 Injector NGI-11 (PTD #1770800) 3 Month TIO Plot w.11-wG1-11 Injector NGI-11 (PTD #1770800) 1 Year TIO Plot V" HCO-11 zm --W— Tb9 ;— IA —+— OA GOA DOOA 0n —�— Tb9 i- IA —+ OA DOA DOOA Oe TRJT = CiW WEYLHEAD=` GRAY ACTUATOR= BAKER OKB. EL.EV SQZ BF. E -EV _ 4 KOP= 2950' Max Angle = 52" @ 7598' Datum MD = 10783' Datum TVD = 8800' SS 9 5/8' CSG, 47#, L-80. ID = 8 525 2373' NOTE: SEE DRLG FILE FOR THREAD LIST 135/8" CSG, 72#, N-80, ID = 12 347- 2'744• 7-5/8" TBG4F`C 297#, L-80, .0459 bpf, ID = 6.919' 8816- 17' WFD ER PATCH, D = 1958" (10/26/12) 8817' !,Minimum ID = 2.75" @ 8995' 5-1/2" X 3-1/2" NIP REDUCER 5-1/2" TBG, 17#, L-80, ID = 4.892' ]--[1 8896• 5-1/2- TBG STUB (TAGGED 11/06!04 —88 POSSIBLE FISH BEHIND 5-1/7 S711MP 777 NALCO RBP DRAG BLOCK (6" X 1" X 112") 5-1/2" TBG, 17#, L-80 BTC, .0232 bpf, ID = 4.892" '——ww - -- TOP OF 7" L NR 9200' 9-5/8' CSG, 47#, JL -85 /N-80 BTRS, ID = 8.681' I 9544' PERFORATION SL#&MRY REF LOG: BHCS ON 02/28/78 ANGLE AT TOP PERF- 33° @ 9870' Note: Refer to Roduction DB for historical perf data SIZE SPF ENTI3RVAL Opn/Sqz SHOT SQZ 3-3/8" 4 9870-9900 O 05/22/87 2215• 3-3/8" 4 9964-10098 O 05/22/87 9518" HALCO ES CEMENTER, ID = 8.50- 3-3/8" 4 10110 - 10130 O 05/10/79 3-3/8' 4 10150 - 10160 O 05/10f79 3-3/8" 4 10190 - 10200 O 05/10179 3-3/8" 4 10212 - 10232 O 05/10!79 3-3/8" 4 10264 - 10280 O 05/10!79 3-3/8" 4 10304 - 10318 O 05/10f79 PBTD I 7- LNR, 29#, N-80 BTRS, .0371 bpi, ID = 6.184'! 10496' Sm WELL A SSSV_ N G I-11 WIFIELD NGLEDISPOSAL WELLS 22' DATE REV BY 0OMuEt3NTS 400' EST. TOP OF ARCTK; SET CEMENT 2203• 7-5/8" x 7- XO, ID = 6.276" 2215• 7" DBS NO GO NIP, ID = 6.000' 2226' r x 7-5/s• x0, ro = s.27s• 2348' 9518" HALCO ES CEMENTER, ID = 8.50- 8816' 17-5/8" x 7' XO, ID = 6.276- 8828' 7' HES R Nil'. ID = 5.963' (BEHIND PATCH) 883 � 8841' -{is/8' x r AD. ro = s.22o• 8850• K-22 ANCHOR TBG SEAL NIP, ID = 6.000' $$51' 95/8" X 7- BKR SAB -3 PKR, ID = 6.000' 8862' 7' X 5-1 /2• �, ro = 4.880' 8875' 5-1/2" HES X NIP, ID = 4.562' RR 9-5/8- X 5-1/2- UNIQUE OVERSHOT 8927•5-1/2' TIW SBR ASSY W/BKR K-22 ANCHOR LATCH, ID = 4.750" DATE REV BY 0OMuEt3NTS DATE REV BY OOWAE NTS 9 518' X 5 1/2' BKR S-3 PERM PKR, ID = 4.75- -d7- MILLOUT EXTENSION, ID = 6.00' 8979• 5-112- PARKER SWS DMP, ID = 4.562' $995•-�5-1/2" X 3-1/2- NIP REDUCER, ID = 2.75- 89�• 5 112" OTIS XN DNP, ID = 4.4W - i W08- —15-112- W LEG, ID = 4.892- -FRAU TT NOT LOGGED 9793' r MARKER JOINT 981 �—{r MARKER JOINT 10425' j--� FISH (4" SV PN / FLAPPi32 (4/26/06) PRUDHOE BAY LINIT WELL: W-411 (1 PERMIT No: '1770800 AR No: 50-029-20283-00 SEC 1, T11N, R14E, 254' FSL 8 899 FWL DATE REV BY 0OMuEt3NTS DATE REV BY OOWAE NTS 03112!78 PKR 141 INTIAL COMPLETION 10/29/12 SET/JMD SET WFD ER PKR (10/04/12) 09/25/84 N1 ES FM 10/29/12 GJS/JMD PULL XX PLUG, SET 7" PATCH 08/03/92 AW 4 RWO 10/31/12 PJC DRAWING CORRECTIONS/ PATCI 11/09/04 NOES RIND 12/20/13 BF/JND PATCH DEPTH CORRECTIONS 02/11/11 MB/JMD ISSSV SAFETY NOTE BP Exploration (Alaska) 09/24/12 1 MSS/JMDJ NP R®V XXN PLUG (09/20/12 Wallace, Chris D (DOA From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] Sent: Tuesday, December 31, 2013 3:16 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsites; AK, OPS FS1 GAS INJ OPERATOR; Farinez, Javier; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA) Subject: OPERABLE: Gas Injector NGI-11 (PTD #1770800) MITIA Passed Attachments: Injector NGI-11 (PTD #1770800) TIO Plot.docx All, Injector NGI-11 (PTD #1770800) passed a MITIA on 12/09/2013. The passing MITIA proves two competent barriers in the wellbore, however, the fluid level in the inner annulus continues to fluctuate. We have permission from the AOGCC to continue injecting gas for 60 days while monitoring for fluid level fallout and to gather additional information that may assist in identifying a potential leak, or to apply for an Administrative Approval. The well is reclassified as Operable for this monitoring period. Plan forward: 1. DHD: Obtain fluid levels weekly for 60 days. 2. APE/ WIC: Evaluate well for repair options A copy of the TIO plot is included for reference. SCANNED Please call with any questions. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email: AKDCWelllntegritvCoordinator@bp.com From: AK, D&C We rity Coordinator Sent: Thursday, November 013 11:20 PM To: AK, OPS FS1 OSM; AK, OPS FS ility OTL; AK, OPS FE DS Ops Lead; AK, OPS FS1, DS5 Operator; AK, OPS PCC EOC TL; AK, D&C Well Services Operation am Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr, RES GPB West Wells Opt Engr; Farinez, lave G GPB FS1 Drillsites; 'chris.wallace@alaska.gov'; 'jim.regg@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Proje Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Gas Injector NGI-11 (PTD #177G&Q0) Low IA Fluid Level All, Injector NGI-11 (PTD #1770800) TIO Plot 1D*5/13 11V12n3 16'19'13 IUM+i3 11Abi3 IIM'13 '1;16'13 '12313 111=3 IM -13 12.1413 IMIM3 771"'F" -0- 1>g t CIA ooa ort Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, December 31, 2013 6:43 AM To: 'AK, D&C Well Integrity Coordinator' Cc: Daniel, Ryan Subject: RE: Injector NGI-11 (PTD #1770800) Permission to Continue Injection While Monitoring Jack, Thank you for the call yesterday and the follow up email. We approve the requested 60 day continued gas injection for diagnostics and monitoring. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 (907) 793-1250 (phone) (907) 276-7542 (fax) chris.wallace@alaska.sov LU 1-t From: AK, D&C Well Integrity Coordinator[mailto:AKDCWellIntegrityCoordinator@bp.com] Sent: Monday, December 30, 2013 5:04 PM To: Wallace, Chris D (DOA) Cc: Daniel, Ryan Subject: Injector NGI-11 (PTD #1770800) Permission to Continue Injection While Monitoring Chris, Gas injector NGI-11 (PTD #1770800) is currently Under Evaluation to monitor for inner annulus fluid level fall out. The inner annulus fluid level was found to be at 600 feet on 10/26/2013, a subsequent MITIA passed on 12/13/2013. The fluid level in the inner annulus remained at surface until a bleed took place and the fluid level dropped to 360 feet. There have been no over pressure events on the well and the inner annulus pressure fluctuations remain within what can be expected with changes in injection rates and temperature. BP would like permission from the AOGCC to continue injecting gas for 60 days while monitoring for fluid level fallout and evaluating the well for a possible administrative approval. Copies of the TIO plot and most recent MITIA are included for reference. Please call with any questions. Thank you, Jack Disbrow (Alternate: Laurie Climer) BP Alaska - Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator@bp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submitto:iim.regg(a)alaska.c�ov: AOGCC.Inspectors(cbalaska.gov; phoebe.brookscDalaska.gov chris.wallace(a),alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay/ PBU / NGI Pad DATE: 12/13/13 OPERATOR REP: Laurie Climer AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI-11 Type In'. G TVD 7,311' Tubing 3,296 3,294 3,284 3,285 1 1 Interval O P.T.D. 1 1770800 Type test I P Test psi 1827.75 Casing 766 2,203 2,173 2,156 P/F P Notes: MITIA Performed for Diagnostic Purposes OA 0 0 0 0 Well I Type In'. TVD Tubing Interval P.T.D. Type test I Test psi Casing P/F Notes: OA Well I Type In'. I TVD I Tubing Interval P.T.D. I Type test I Test psi Casing P/F Notes: OA Well I Type In'. I TVD I Tubing Interval P.T.D. I Type test I Test psi Casing P/F Notes: OA Well I Type In'. I TVD I Tubing Interval P.T.D. I Type test I Test psi I Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Form 10-426 (Revised 11/2012) MIT PBU NGI-11 12-13-13.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance O = Other (describe in notes) Injector NGI-11 (PTD #1770800) TIO Plot Ma:IIM I0CS'i3 i u,213 "140'13 10'26''13 '.t1p£+3 11.0'13 77;1613 112113 11130'73 im71.3 12!7473 7221:53 122813 --*-- Tb0 t IA �— OA OOA -- OOOA Oo Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] Sent: Thursday, November 21, 2013 11:20 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Farinez, Javier; G GPB FS1 Drillsites; Wallace, Chris D (DOA); Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Gas Injector NGI-11 (PTD #1770800) Low IA Fluid Level Attachments: NGI-11 TIO and Injection Plots 11-21-13.docx; NGI-11 wellbore schematic.pdf All, Injector NGI-11 (PTD #1770800) has been found to have inner annulus fluid level of 900 ft with TBG/IA/OA = 3377/840/40 psi. Due to this depth and the higher IA pressures seen, the well is reclassified as Under Evaluation for further diagnostics. Plan Forward: 1. Fullbore: Load IA, MIT -IA 2. DHD: Pending a passing test, monitor IA fluid level for up to 21 days 3. WIE: Further diagnostics as needed. Copies of the TIO and Injection plots, and wellbore schematic have been included for reference. Please call with any questions. Thank you, SPA Laurie Climer Salon (Alternate: Jack Disbrow) BP Alaska - Well Integrity Coordinator `_r... . ot6anild WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com jo Injector NGI-01 (PTD #1770800) 11/21/13 TIO Plot Injection Plot wM . :1P17 WELLHEAD = GRAY ACTUATOR= BAKER KB. ELEV = 44' BF. ELEV = 9870-9900 KOP = 2959 Ntax Angle = 52` @ 7598' Datum ND = 10783' Datum TVD = 8800' SS 9-518' CSG, 47#, L-80, ID = 8.525" 2373' NOTE: SEE DRLG FILE FOR THREAD UST 13-318' CSG, 72#, N80, ID = 12.34r 2744' TBG4PC, 29.70, L-80_0459 W ID = 6.919' 8816- 7* WFD ER PATCH, ID = 3.958' (10/26/12) 8B1 T - 8841' Minimum ID = 2.75" @ 8995' 15-1/2" X 3-1/2" NIP REDUCER 5-1/2- 78G, 17#, L-80. ID = 4.892 8$96' 5-1/r TBG STUB (TAGGED 11/06/04 —8894 POSSIBLE FISH BEHIND 5-1/2* STUMP ??? HALCO RBP DRAG BLOCK (6• X 1' X 1/r) 5.1/2- TBG, 17#, L-80 BTC, .0232 tipf, ID = 4.892 - TDP OF 7" LNR 9-5/8" CSG, 47#, JL55 /N50 BTRS, ID - 8.681" FXI—A PERFORATION SL MMRY REF LOG: BHCS ON 02/28/78 ANGLE AT TOP PERF: 33' @ 9870' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9870-9900 O 05/22/87 3-3/8" 4 9964- 10098 O 05/22/87 3-3/8" 4 10110 -10130 O 05/10/79 3-3/8" 4 10150 - 10160 O 05/10/79 3-3/8" 4 10190 - 10200 O 05/10/79 3-3/8" 4 10212- 10232 O 05/10/79 3-3/8" 4 10264 - 10280 O 05/10/79 3-3/8" 4 10304- 10318 O 05/10/79 PBTD 7• LNR, 290, N-80 BTRS, .0371 W, D = 6.184- 10425' SAF. S A SSS/. N G I-11 NGL DISPOSAL WELL r HES R NIP, D = 5.963' (BEHIND PATCH) 7"X75l8"XO,ID=6.276" r X 7-5►8• XO, D = 6.276• EST. TOP OF ARCTIC SET CEMENT 75J8' x r �. D = s.220' 75/8'r $34 DB5 NO GO NP, ID = 6.000•98/8' 95/8' X r BKR SAB -3 PKR D - 6.000' 8862' r x 5-1/r x0, D = 4.880• HALCO ES CEMENTER, D = 8.50' 8816' -175/8" X 7' x0, D = 6.276' 8828• r HES R NIP, D = 5.963' (BEHIND PATCH) 8839' r X 7-5►8• XO, D = 6.276• 8841' 75J8' x r �. D = s.220' $850• K-22 ANCHOR TBG SEAL NP, ID F6.5'00 8851 • 95/8' X r BKR SAB -3 PKR D - 6.000' 8862' r x 5-1/r x0, D = 4.880• 88�5-1/r HES X NP, ID = 4.562" 88W -19-5/8• X5-1/2- UNIQUIE OVERSHOT $927' 5.1/2- T1W SBR ASSY W/BKR K-22 ANCHOR LATCH, ID = 4.750' 95/8' X 5-1/2- BKR S-3 PERM PKR, ID = 4.75• $949' r MILLOUT EXTENSION, ID - 6.00' 897 '5112' PARKER SWS NIP, ID = 4.562' I5-1/2- X 3-1/2- NIP REDUCER, ID = 2.75- 5-iY2' OTIS XN NIP, ID = 4.450• -] 9OWJ-15-1/r W LEG, ID = 4.892- ELMD TT NOT LOGGE 9793' _]-jr MARKER JOINT 9812' r MARKER JOINT 10425' 1--J FISH (4' SV PN / FLAPPER (4/26/06) PRUDHOE BAY UNIT WELL NGF11 PERMIT No: 1770800 API No: 50-029-20283-00 SEC 1, T1 IN, R14E, 1095.1' FEL & 609.5' FNL DATE REV BY COMMENTS DATE REV BY COMMENTS 03112!78PKR 141 INITIAL COMPLETION 10/29/12 SET/JMD SET WFD ER PKR (10/04/12) 09/25/94 N1ES RWO 10/29/12 GJS/JMD PULL XX PLUG, SET r PATCH (10 08/03/92 AUDI 4 RWO 10/31/12 PJC DRAWING CORRECTIONS/ PA;fCF 11/09/04 NIES RWO 02/11/11 MB/JMD SSSV SAFETY NOTE BP Exploration (Alaska) 09/24/12 MSS/JMD NP RED/)M PLUG (09/20/12) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWellintegrityCoordinator@bp.com] Sent: Monday, December 03, 2012 8:28 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS1 DS; Farinez, Javier Cc: AK, D&C DHD Well Integrity Engineer Subject: OPERABLE: Gas Injector NGI-11 (PTD #1770800) Tubing Patch Set To Mitigate TxIA Communication op Gas Injector NGI-11 (PTD # 1770800) passed an MIT -IA on 11/09/2012. The well pressures have been monitored since the MIT was performed and the IA pressure has remained stable. At this time the well is reclassified as Operable. The well will continue to be reported on the AOGCC Monthly Injection reports for the next 2 months for further monitoring. Please call if you have any questions. Thank you, Mehreen Vazir SCAHHE�: BPXA Well Integrity Coordinator From: AK, D&C Well Integrity Coordinator Sent: Monday, October 29, 2012 3:37 PM To: Regg, James B (DOA); Chris Wallace (chris.wallaceC&alaska.gov); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS1 DS; Farinez, Javier Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; Walker, Greg (D&C); Clingingsmith, Mike J Subject: UNDER EVALUATION: Gas Injector NGI-11 (PTD #1770800) Tubing Patch Set To Mitigate TxIA Communication on Gas injector NGI-11 (PTD #1770800) has had a tubing patch installed to mitigate a TxIA communication in the wellbore. The well passed a MIT -T to 3500 psi on 09/29/2012 prior to the installation of the patch. The well is reclassified as Under Evaluation. Plan forward: Operations: Return well to gas injection Fullbore: AOGCC witnessed MIT -IA to 2000 psi (per sundry 312-307 requirement) 3. WIE: Monitor TIO pressures for 14-20 days 4. WIC: Leave well on Monthly Injection Report for two months A copy of the new wellbore schematic, and the MIT -T is enclosed for reference. « File: MIT PBU NGI-1109-29-12.xls >> « File: NGI-11.pdf >> Please call if you have any questions or concerns. Thank you, Gerald Murphy (Alternate: Mehreen BP Alaska - Well Integrity Coordinator << OLE Object: Picture (Device Independent Bitmap) >> WIC Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator@BP.com • MEMORANDUM TO: Jim Regg ' J P.I. Supervisor ��, 1 Zb I T✓ FROM: John Crisp Petroleum Inspector 0 State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November 26, 2012 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-11 PRUDHOE BAY UNIT NGI-11 Sre: Inspector Reviewed By: P.I. Suprvj_e40_ NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-I 1 API Well Number 50-029-20283-00-00 Inspector Name: John Crisp .fuf Permit Number: 177-080-0 Inspection Date: 11/8/2012 Insp Num: mit 121112062101 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ell NGI-11Type Inj G TVD 1770800 - SPT TD ' Type Test Test psi 7311 1828 IA959 OA 15 - 2108 12 1902 - 14 — -- Interval OTHER -- p/F _ F Tubing 3382 - 3375 3375 Notes: MITIA post tubin atch. It took 8.5 bbls to test the IA . 1251-tt�(e� c oe- Vii' e,, -Ce, -At- 1�`� Pr�s�e loss SCANNED 1,11 3 /` t i s Monday, November 26, 2012 Page 1 of 1 • MEMORANDUM TO: Jim Regg �"(W(v P.I. Supervisor `` \\ t t FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November 26, 2012 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-11 PRUDHOE BAY UNIT NGI-11 Src: Inspector Reviewed By: r P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-11 API Well Number 50-029-20283-00-00 Inspector Name: John Crisp a� Permit Number: 177-080-0 Inspection Date: 11/8/2012 Insp Num: mit 121112062426 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-11 - Type Inj G - TVD 7311 IA 1902 2107 1987 - 1987 - TD 1770800 ' Type Test SPT Test psi 1828 OA 14 14 15 15 Interval OTHER P/F P Tubing 3375 3378 i 3385 3385 Notes: .6 bbls pumped for retest. Post tubing patch retest. Operator Rep. requested they repressure IA due to failed MIT with pressure loss of over 200 psi after 15 minutes on first test. I told the Rep. I would witness test & my Supervisor would review data & make judgment on pass fail. Pass - per J. Regg. SCANNED A u �, 2 8 Monday, November 26, 2012 Page 1 of 1 N"i L: # G ®V Lob, STATE OF ALASKA NOV 2 0 2012 AWKA OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS O CC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other Jfivb I v1 p u tG Pi Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ ✓ I Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Weil❑ 113/13 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development El Exploratory ❑ — 177 -080 -0 3. Address: P.O. Box 196612 Stratigraphi4j Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20283 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: . ADL0028302 -'• PBU NGI -11 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 10496 feet Plugs measured 8982 feet true vertical 8609.93 feet Junk measured 10425 feet Effective Depth measured 10425 feet Packer measured See Attachment feet true vertical 8547.53 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H -40 26 - 106 26 - 106 1490 470 Surface 2719 13 -3/8" 72# N -80 25 - 2744 25 - 2744 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet SCANNED FEB 2 8 2013 True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (tYP e, measured and true vertical depth) See Attachment See Attachment See Attachment Packer 7" DB -6 SSSV 2215 2215 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: 0 5740 0 0 1409 Subsequent to operation: 0 131477 0 0 2357 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service El Stratigraphic f Daily Report of Well Operations X 16. Well Status after work: Oil U Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ 5 SUSP ❑ SPLUG-❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -307 Contact Garry Catron Email Garrv.Catr t BP.Com Printed Name Garry Catron Title PDC PE Signature a Phone 564 -4424 Date 11/19/2012 . ,., . VLil" i ., -- c) ■ ti13 i ,1) Form 10-404 Revised 10/2012 j Submit Original Only • • Packers and SSV's Attachment ADL0028302 SW Name Type MD TVD Depscription NGI -11 SSSV 2215 2171 7" DB -6 SSSV NGI -11 PACKER 8817 7167.02 4 -1/2" WFD ER Packer NGI -11 PACKER 8841 7185.93 4 -1/2" WFD ER Packer NGI -11 PACKER 8853 7195.41 9 -5/8" Baker SAB -3 Packer NGI -11 PACKER 8947 7269.86 5 -1/2" Baker SABL -3 Packer Casing / Tubing Attachment ADL0028302 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 26 - 106 26 - 106 1490 470 LINER 30 4 -1/2" 12.6# L -80 8817 - 8847 7211.02 - 7234.67 8430 7500 LINER 1293 7" 29# MN -80 9203 - 10496 7518.13 - 8609.93 8160 7020 PRODUCTION 960 9 -5/8" 47# NT95HS 24 - 984 24 - 984 8150 5080 PRODUCTION 1393 9 -5/8" 47# L -80 984 - 2377 984 - 2377 6870 4760 PRODUCTION 7167 9 -5/8" 47# N -80 2377 - 9544 2377 - 7797.04 6870 4760 SURFACE 2719 13 -3/8" 72# N -80 25 - 2744 25 - 2744 4930 2670 • TUBING 2181 7 -5/8" 29.7# L -80 24 - 2205 24 - 2205 6890 4790 TUBING 23 7" 26# L -80 2205 - 2228 2205 - 2228 7240 5410 TUBING 6590 7 -5/8" 29.7# L -80 2228 - 8818 2228 - 7211.81 6890 4790 TUBING 23 7" 26# L -80 8818 - 8841 7211.81 - 7229.93 7240 5410 TUBING 4 7 -5/8" 29.7# L -80 8841 - 8845 7229.93 - 7233.09 6890 4790 TUBING 19 7" 26# L -80 8845 - 8864 7233.09 - 7248.1 7240 5410 TUBING 37 5 -1/2" 17# L -80 8864 - 8901 7248.1 - 7277.37 7740 6280 TUBING 115 5 -1/2" 17# L -80 8896 - 9011 7273.41 - 7364.64 7740 6280 • Perforation Attachment ADL0028302 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base NGI -11 5/10/1979 PER 9870 9900 8070.05 8095.37 NGI -11 5/22/1987 APF 9906 9918 8100.44 8110.57 NGI -11 5/10/1979 PER 9918 9948 8110.57 8135.93 NGI -11 5/22/1987 APF 9948 9964 8135.93 8149.46 NGI -11 5/10/1979 PER 9964 9984 8149.46 8166.41 NGI -11 5/22/1987 APF 9984 10000 8166.41 8180 NGI -11 5/10/1979 PER 10000 10040 8180 8214.07 NGI -11 5/22/1987 APF 10040 10066 8214.07 8236.3 • NGI -11 5/10/1979 PER 10066 10086 8236.3 8253.41 NGI -11 5/22/1987 APF 10086 10098 8253.41 8263.68 NGI -11 5/10/1979 PER 10110 10130 8273.95 8291.08 NGI -11 5/10/1979 PER 10150 10160 8308.23 8316.8 NGI -11 5/10/1979 PER 10190 10200 8342.54 8351.12 NGI -11 5/10/1979 PER 10212 10232 8361.42 8378.6 NGI -11 5/10/1979 PER 10264 10280 8406.26 8420.24 NGI -11 5/10/1979 PER 10304 10318 8441.27 8453.55 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK 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 Daily Report of Well Operations ADL0028302 ACTIVITYDATE f ; : — • r r - • . .. _ V • INITIAL T /I /0 = 600/500/0 PSI RIH W/ MH -22( 7X3 ),AH- 38,ERS,PEKC,CAL- B,FIRING HEAD,CPST,WFD PACKER, OAL = 20', WEIGHT = 420 LBS, MAX OD = 5.85" WEATHERFORD ME SET DEPTH = 8846' TOP OF PACKER (SNAP LATCH ASSY) AT 8840.6' FINAL T /I /0 = 550/500/0 PSI 10/4/2012 ** *WELL S/I ON DEPARTURE * ** ** *WELL S/I UPON ARRIVAL * ** (patch tbg /liner) • DRIFTED W/ 35" x 5.95" PATCH DRIFT TO TOP OF LOWER ANCHOR @ 8,825' SLM SET 7" UPPER WEATHERFORD ER PATCH ASSEMBLY IN LOWER ANCHOR @ 8,838' SLM ( -21' oal, 3.95" min id) 10/25/2012 * * *CONT WSR ON 10/26/12 * ** * * *CONT WSR FROM 10/25/12 * ** (patch tbg /liner) EQ AND PULL 3 1/2" XXN PLUG FROM NIPPLE REDUCER @ 8995' MD/ 8978' SLM DRIFT TO SSSV NIPPLE AND SET A -1 INJ SSSV (BWS -137) (3.5" ORIFICE, MOD FLAPPER HOUSING) @ 2215' MD/ 2196' SLM PERFORM PASSING CLOSURE TEST. BLED 300# OFF. 1450# TO 1150# 10/26/2012 ** *WELL LEFT S /I, DSO NOTIFIED OF STATUS * ** T /1 /0= 3340/810/10. Temp =110 ". WHPs (Eval post -POP). 11/2/2012 SV =C. WV, SSV, MV =0. IA &OA =OTG. NOVP. 1630. T /1 /0 = 3540/1070/0 +. Temp = 136 °. WHPs. (Eval post -POI). On Inj. DSO stated well temp has increased —10° overnight. Tubing pressure increased 200 psi, IAP increased 260 psi & well temp increased 26° since 11 -02 -12 monitor. 11/5/2012 SV = C. WV, SSV, MV = 0. IA & OA = OTG. NOVP. 16:35 • T /I /0= 3400/1000/0 temp =INJ AOGCC State Witness Test (ANN -COMM) pump 8.5 bbls neat meth down IA to reach test pressure. Failed 1st test in the 1st 15 min, repressured with .6 bbls meth. MIT IA passed lost 120 psi 1st 15 min, 0 psi 2nd 15 min. Bled IAP to —1600 psi started getting gas returns. Turned well over to DHD to resume IA bleed. FWHP's= 3385/1600/15 Tags hung well 11/8/2012 on inj, IA, OA =OTG. DSO notified T /1 /0 = 3380/960/10. Temp = 136 ". Bleed IAP to 500 psi (Eval High IAP). On Ind. IA I-L near surface. Bled IAP to BT from 960 psi to 500 psi in 1 hr (fluid to surface). IAP increased 60 psi in 30 min. monitor, bled IAP to 400 psi in 15 min & monitored for 30 min, WHPs unchanged. Job complete. Final WHPs = 3380/400/10. SV = C. WV, SSV, MV = 0. IA, OA = OTG. NOVP. 12:00 hrs. 11/9/2012 Daily Report of Well Operations ADL0028302 T /I /O = 3400/750/10. Temp = 134 °. WHPs ( Eval High IAP ). TP increased 10 psi, IAP increased 350 psi, OAP unchanged overnight. 11/10/2012 SV = C. WV, SSV, MV = 0. IA, OA = OTG. NOVP. 0930. T /I /O= 3300/850/0 +. Temp= 78 °. WHPs (Eval high IAP). On Ind. TP decreased 100 psi, IAP increased 100 psi & OAP decreased from 10 psi to 0+ since 11/10/12. 11/12/2012 SV =C. WV, SSV & MV =0. IA & OA =OTG. NOVP. 1630 hrs. T /1 /0 = 3200/820/0 +. Temp = 62 *. WHPs (Eval high IAP). On inj. IAP decreased 30 psi, no change in OAP since 11/12/12. 11/14/2012 SV =C. WV, SSV, MV =0. IA, OA =OTG. NOVP. 08:41 • T /I /0 = 3350/900/0 +. Temp = 74 *. WHPs (Eval high IAP). IAP increased 80 psi since 11/14/12. IA has integral flange = Inspection current. 11/16/2012 SV =C. WV, SSV, MV =0. IA, OA =OTG. NOVP. 08:20 T /I /O = 3200/810/0 +. T = Ps (1Eva! high ' . as in egra installed = inspection current. IAP decreased 90 psi, no change in OAP overnight. 11/17/2012 SV =C. WV, SSV, MV =0. IA, OA =OTG. NOVP. 10:12 T /I /0 = 3400/900/0 +. Temp = 76 *. WHPs (Eval high IAP). IAP increased 90 psi, no change in OAP overnight. 11/18/2012 SV =C. WV, SSV, MV =0. IA, OA =OTG. NOVP. 10:13 • ' WELLHEAD= GRAY N G I -11 *8*FIELD NGL DISPOSAL WELL*** R SA SSSV. ACTUATOR= BAKER , KB. 44' 1 ` , 22' HT X7 - 5/8" )(0, ID = 6.276' BF. EEV= Kam V. T4 400• - EST. TOP OF ARCTIC SET CEMENT Max Angle = 52° @ 7598' 1 • t; 2203 - 17 - 518" X7' )00, ID = 6.276' Datum MD 10783' 1 4 4 4 Milt.... 2215' - 1T DB NO GO NP, ID = 6.000" 1 DetumTVD= 8800' SS I � � � 4,4 � 4 o . 0 •■ 2226' HT X7-5/8" )OD, ID = 6.276" 9-5/8" CSG, 47 #, 1-80, ID = 8.525" - 2373' ■�4 9 .i 2348' -19-5/8" HALCO ES CEMENTER, D = 8.50' 1 ■ NOTE: SEE DRLG FILE FOR THREAD UST . 113 -3/8' CSG, 72#, N-80, ID = 12.347" H 2744' f7-5/81[29.7#. L-80 ,ID = 6.919" - 8816' , , I 8816' -17 -5/8" X7' )OD, 10 = 6.276" WFD ER PATCH, ID = 3.958" (10 26/12) 8817• - 8844' ; $$28' -IT HES RNIP, p = 5.963' (BEHIND PATCH) > 1 8839' H7' X7 -5/8" X), D = 6.276' - `_"` •{ 8841' - 17-5/8' X7' XO, D = 6.220" Minimum ID = 2.75" @ 8995' . K 22 ANCHOR TBG SEAL NIP, ID = 6.000` 5 -112" X 3 -1/2" NIP REDUCER -___� 8850 J� B P - � $$51' - 9-5/8" X 7' BKR SAB-3 PKR, N3 = 6.000' 1 #s --1 8862' - 7 X 5-1/2' X3, D = 4.880' 1 1 8875' IH5 -1/2' HES X NP, ID = 4.562' 5-1/2" TBG, 17 #, 1-80, ID = 4.892' H 8896• 1- __---i 8899• H9 -5/8" X5 -1/2" UNIOUIE OVERSHOT 5-1/2" TBG STUB (TAGGED 11/06/04) -1 -8894 8927' J 5-1/2' 71W SBR ASSY W /BKR POSSIBLE FISH BEHIND 5-1/2' STUMP -1 ??? I K -22 ANCHOR LATCH, ID = 4.750' HALCO RBP DRAG BLOCK (6' X1" X 1/2') �� J 8943' - 19 -5/8' X 5-1/2' BKR S -3 PERM PKR, ID = 4.75" 1 -----■ 8 iii; -17' MILLOUT EXTENSION, ID = 6.00' 1 1 8979' 15-112' PARKER SWS MP, ID = 4.562" $995 - 1 5 112' X 3 -12" NIP REDUCER, ID = 2.75 8996• 1 -1/2 0115 XN MP, ID = 4.450 1 5-1/2" TBG, 17#, 1-80 BTC, .0232 bpf, ID = 4.892' - 9008• 1 TOP OF 7' LNR -1 9200' - ------------._ 900$' 1-151 /2• MEG, ID = 4.892" 1 MI I -1 ELM) TT NOT LOGGED 9-5/8" CSG, 47 #, JL-85 IN-80 BTRS, ID = 8.681' H 9544• 1- ■ PERFORATION SUMARY 9793' 17' MARKER JOINT 1 RE= LOG: BHCS ON 02/28/78 9812' 1-r MARKER JOINT ANGLE AT TOP PEW: 33° © 9870' 1 Note: Refer to Rod uction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9870 - 9900 0 05/22/87 1 3-3/8" 4 9964 - 10098 0 05/22/87 3-3/8" 4 10110 - 10130 0 05/10/79 3-3/8" 4 10150 - 10160 0 05/10[79 1 3-3/8" 4 10190 - 10200 0 05/10[79 3-3/8" 4 10212 - 10232 0 05/10/79 1 3-3/8' 4 10264 - 10280 0 05/10/79 1 3-3/8" 4 10304 - 10318 0 05/10 [79 1 PBTD 1 10425' [ 10425' -- 1 FISH (4" SV PIN / FLAPPER (426/06) 1 4'1'1''1'1'4 ....... 7' LNR, 29#, N-80 BTRS, .0371 bpf, D = 6.184" H 1049 1,0,0,0,0,0,0,4 I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 1 03/12/78 PKR 141 INITIAL COMPLETION 10/29/12 SET /JMD SET WFD ER PKR (10/04/12) WELL NGI-11 09/25/84 NIES RWO 10/29/12 GJS /JMD PULL )0( PLUG, SET T PATCH (10 PERMIT No: X 1770800 08/03/92 AUDI 4 RWO 10/31/12 PJC DRAWING CORRECTIONS/ PATC- API No: 50-029- 2028300 1 11109/04 N4ES RWO SEC 1, T11N, R14E, 1095.1' FEL & 609.5' FNL 02/11/11 MB /JMD SSSV SAFETY NOTE 02/11/11 ' MSS /JMD NP RED/ )0X• PLUG (09/20/12) BP Exploration (Alaska) • MEMORANDUM TO: Jim Regg �G Il�� P.I. Supervisor t FROM: John Crisp Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, November 15, 2012 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-11 PRUDHOE BAY UNIT NGI-11 Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-11 API Well Number 50-029-20283-00-00 Inspector Name: John Crisp �: Permit Number: 177-080-0 Inspection Date: 11/8/2012 Insp Num: mit 121112062426 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ell NGI-II - Type Inj G- TVD 7238 - IA 1902 2107 - 1987 1987 - TD 1770800 Type Test SPT Test psi 1809 OA la ]a is is Interval OTHER p/F P Tubing 3375 _ 3378 3385 3385 , Notes: .6 bbls pumped for retest. Post tubing patch retest. Operator Rep. requested they repressure IA due to failed MIT with pressure loss of over 200 psi after 15 minutes on first test. I told the Rep. I would witness test & my Supervisor would review data & make judgment on pass fail. Pass - per J. Regg. ✓ SCANNED A111"G 2 8 201 Thursday, November 15, 2012 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Friday, November 09, 2012 5:25 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA) Subject: UNDER EVALUATION: Gas Injector NGI -11 (PTD #1770800) Tubing Patch Set To Mitigate TxIA Communication Attachments: MIT PBU NGI -11 11- 08- 12.xls Hello Jim /Chris, An AOGCC witnessed MIT -IA was performed on NGI -11 (PTD # 1770800) on 11/08/2012 per the post patch sundry requirement. The MIT -IA initially failed but a retest passed. The IA had to be loaded with 8.5 bbls during the first test to fill up the void created from previous injection operations when the TxIA leak was exhibiting. Since the patch was installed this was the first MIT -IA performed. At this time, the IA pressure has been bled down and the plan forward is to monitor the well for 14 -21 days to evaluate for IA repressurization. The MIT -IA form is attached for reference: SCANNED Jul 2 2 L�i�; «MIT PBU NGI -11 11- 08- 12.xls» Please let me know if you have any concerns with our plan forward. Thank you, Mehreen Vazir BPXA Well Integrity Coordinator From: AK, D &C Well Integrity Coordinator Sent: Monday, October 29, 2012 3:37 PM To: Regg, lames B (DOA); Chris Wallace (chris.wallace @alaska.gov); AK, OPS FS1 OSM; AK, OPS FS1 Facility 011; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC 11; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS1 DS; Farinez, Javier Cc: AK, D &C Well Integrity Coordinator; AK, D &C DHD Well Integrity Engineer; Walker, Greg (D &C); Clingingsmith, Mike J Subject: UNDER EVALUATION: Gas Injector NGI -11 (PTD #1770800) Tubing Patch Set To Mitigate TxIA Communication All, Gas injector NGI -11 (PTD #1770800) has had a tubing patch installed to mitigate a TxIA communication in the wellbore. The well passed a MIT -T to 3500 psi on 09/29/2012 prior to the installation of the patch. The well is reclassified as Under Evaluation. Plan forward: 1. Operations: Return well to gas injection 2. Fullbore: AOGCC witnessed MIT -IA to 2000 psi (per sundry 312 -307 requirement) 1 • • 3. WIE: Monitor TIO pressures for 14 -20 days 4. WIC: Leave well on Monthly Injection Report for two months A copy of the new wellbore schematic, and the MIT -T is enclosed for reference. « File: MIT PBU NGI 09 » « File: NGI 11.pdf » Please call if you have any questions or concerns. Thank you, Gerald Murphy BP Alaska - Well Integrity Coordinator « OLE Object: Picture (Device Independent Bitmap) » WIC Office: 907.659.5102 WIC Email: AKDCWeIIInteeritvCoordinator c BP.com From: AK, D &C Well Integrity Coordinator Sent: Sunday, May 27, 2012 6:02 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (D0A)'; AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility 011; AK, RES GPB Central Prod Opt Engr; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Chiwis, Robert; Daniel, Ryan Cc: Walker, Greg (D &C); Olson, Andrew; AK, D &C DHD Well Integrity Engineer Subject: NOT OPERABLE: Injector NGI -11 (PTD #1770800) Tecwel LDL Located Tubing Leak All, A Tecwel LDL has been performed on Gas Injector NGI -11 (PTD #1770800) and a tubing leak was located at the 7- 5/8"x7" crossover at 8841' MD. At this time, possible repair options are being evaluated. The well is secured with a downhole plug and is reclassified as Not Operable until a plan forward is determined and approval is obtained from the AOGCC for continued injection. A wellbore schematic is attached for reference: Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 2 • • Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D&C Well Integrity Coordinator Sent: Monday, January 30, 2012 12:19 PM To: 'Maunder, Thomas E (DOA) ; 'Regg, James B (DOAy; 'Schwartz, Guy L (DOA) ; AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Fadlity OTL; AK, RES GPB Central Prod Opt Engr; AK, RES GPB East Wells Opt Engr; Cismosld, Doug A; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Chivvis, Robert; Daniel, Ryan Cc: King, Whitney; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: OPERABLE: Injector NGI -11 (PTD #1770800) TxIA Evaluate for Administrative Approval All. Gas injector NGI -11 (PTD #1770800) passed an AOGCC witnessed MIT -IA to 4200 psi on 01/07/2012 proving two competent barriers in the welibore. The IA pressure has been erratic since the IA was fluid packed for the MIT as seen in the attached TIO plot. The well is reclassified as Operable and may remain on injection while further work is performed to determine if an Administrative Approval will be required. The well will continue to be reported on the AOGCC Monthly Injection Report. Plan forward: 1. WIC: Continue to monitor TIO for IA stabilization 2. Downhole Diagnostics: Bleed IA pressure once stabilized and monitor repressurization to confirm an active leak prior to performing Leak Detect Log 2. Eline: Tecwel Leak Detect Log 3. APE: If a leak point is located, determine plan for repair 4. WIC: If no plan for repair, apply for Administrative Approval Attached is an updated TIO Plot, Injection Plot and MIT -IA form for reference: « File: NGI -11 TIO 01- 30- 12.doc» « File: MIT PBU NGI -11 01- 07- 12.xls » Please let me know if you have any questions or concerns. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 3 • • Email: AKDCWeIllntegrityCoordinator @BP.com F AK, Well Integrity Coordinator A , D&C a teg ty Coord nator Sent Monday, December 05, 2011 9:22 PM To: 'Maunder, Thomas E (DOA); 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, RES GPB Central Prod Opt Engr; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Chivvis, Robert Cc: Olson, Andrew; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Injector NGI-11 (PTD # 1770800) IA repressurization post bleed All, Injector NGI -11 (PTD #1770800) IAP was bled from 1370 psi to 500 psi on 11/25/2011. Over the next three days the IAP repressurized and stabilized at 1100 psi which corresponded to a period of injection rate fluctuation. On 12/03/2011, the IAP was bled again from 1120 psi to 300 psi to further diagnose the repressurization observed. Over the next two days the IAP has repressurized 700 psi to 1000 psi. The well is being reclassified Under Evaluation and can remain on injection while further diagnostics are conducted. The plan forward is: 1. Downhole Diagnostics: Bleed IAP to 500 psi 2. Well Integrity Coordinator: Monitor IAP over 3 -5 days to confirm stabilization at 1100 psi 3. Fulibore: MIT -IA 4. Well Integrity Coordinator: Evaluate for Administrative Approval A wellbore schematic, TIO Plot and Injection Plot are attached for reference: «File: NGI- 11.pdf» «File: NGI -11 TIO 12- 05- 11.doc» Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIllntegrityCoordinator @BP.com 4 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reckaalaska.gov; doa.aogcc.prudhoe.bayt alaska.00v; phoebe.brooks(rialaska.gov; tom.maunder(V alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / NGI Pad DATE: 09/29/12 OPERATOR REP: Gerald Murphy AOGCC REP: I Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI -11 Type Inj. N TVD 7,238' Tubing 3,463 3,503 3,490 3,478 Interval p P.T.D. 1770800 Type test P Test psi 1809.5 Casing 569 569 569 569 P/F P Notes: MIT -t to 3500 psi pre -patch set OA 0 0 0 0 Pumped 0.45 bbls of MEOH to reach test .si Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing PIF Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D._ Type test Test psi Casing PIF Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA - TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial 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 Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU NGI - 11 09 29 12.xds TREE= CM • SARIpOTE: WELL REQUIRES A SSSV. "'FIELD VVELLHEAD = GRAY NG1-11 NM POSAL WELL "'CHROME 5-112 MG' ACTLIATDR = BAKER • NM= =IN 111 22' H7" X 7-5/8" XO, ID = 6.276' 1 RD — - - - - — - 295-0" f• 0.44 400' HEST. TOP OF ARC71C SET CEMENT 1 Max ;----- 52-"-iii598' I* • • 1,•; 2203' H7-5/8" X 7" XO, 0 = 6.276" Datum 14) = 10783' I • • S ' al = ' M Datum TVD 8800' SS • • 22'16' Hr DB-6 NO GO NIP, ID = 6.000" 1 / • • • 111111 I • eV, 2226' .. 1-17 - X 7-5/8" XO, ID = 6.276" 1 h. 9-5/8" CSG, 47#, L-80, ID = 8.525" -- I 2373' '6' • • 4 . 4 23418' H9-5/8"1-ALCO EB CEMEMER, 0 = 8.50" 1 NOTE SEE DRLG FLE FOR THREAD LIST 113-3/8" CSG, 72#, N-80, D = 12.347" H 2744' 1 Minimum ID = 2.76" @ 8996' 8816" 1--17-5/Er x r X0, ID = 6.276" 1 6-112" X 3-112" NIP REDUCER ' 8828' H7" HES R NIP, ID = 5.963" 1 7" UPPER WFD ER PATCH ASSY, —1 8817' 13 = 3.958" (10/26/12) IN ia 8839' 1-17" X 7-5/W XO, ID = 6.276' 1 8841' 1 X 7" X0, 13 = 6.220' 1 17-5/8" TBG-I, 29.7*, L-80, .0459 bpf, ID = 6.919 8841' W I 8850' K ANCHOR TBG SEAL NP, 0 = 6.000" 17" VVFD ER PKR w /SNAP LATCH ASSY (10/04,12) H 88411' PMII Oilb.. 8851' H9-5/fr X 5 BAKER SAB fl ID = 6.000* 1 Ir TBG, 26#, L-80, .0383 bpf, ID = 6.276" H 8838' a . 1 8862' 1 X 5 XO, 0 = 4.880" 1 L 8875' H5-1/2" NES X NIP, ID = 4.562" 1 8899" H9-5/8" X 5-1/2" UNIQUE OVERSHOT I 15-1/2" TBG, 17# , L-80, ID = 4.892" H 8896' 1 8927' 1 TM( SBR ASSY W/BKR FOSSBLE FISH BEHND 5-1/2" STUMP H ??? K-22 ANCHOR LATCH HALLO RBP DRAG BLOCK (6" X 1" X 1/2) 8943' H9-518" X 5-1/2" BAKER SABL-3 FERN PKR 1 10-■.„1411 10........ 8978' H6-112- PARKER SWS MP, ID= 4.662" 1 8996* H5-1/2" X 3-112" NIP RBXICER,10 = 2.75' 1 1 5-1/2" TBG, 17#, 13CR-80, .0232 bpf, ID = 4.892" H 9008' 8995' H &lir arts pi 181 4.466" 1 'TOP OF 7" LI421-1 9203' 9008 H5-1/2" TUBING TAL VVLEG 1 1 9-5/8' CSG, 47*, N-80, ID = 8.681" 1-1 9544' 1 • 1 HELM) TT NOT LOGGED 1 FERFORATON SUMMARY 1 I LOG: BHCS ON 02/28/78 ANGLE AT TOP PERF: 33° © 9870' 1 Ikbte: Refer to Production DB for historical perf data SEE SW WTER'VAL Opn/Sqz DATE 3-3/8" 4 9870 - 9900 0 05/22/87 1 3-3/8" 4 9964 - 10098 0 06/22/87 3-3/8" 4 10110 - 10130 0 05/10/79 3-3/8" 4 10150 - 10160 0 05/10/79 I 3-3/8" 4 10190 - 10200 0 05/10/79 3-3/8" 4 10212 - 10232 0 05/10/79 3-3/8" 4 10264 - 10280 0 05/10/79 3-3/8" 4 10304 - 10318 0 05/10/79 _ _ 1 10425' H FISH (4' SV P14 I FLAFFER (4/26/06) 1 PBTD 10425' VA ■••••••1 •,•,•,•,*,•,•, 7" LNR, 29#, MN-80, .0371 bpf, I) = 6.184" 10496' DATE REV BY COIAIENIS 1 DATE REV BY COMMENTS FRUDHOE BAY UNIT 03112/78 ORIGINAL COMPLETION 02/11/11 ABIJMO ADDED SSSV SAFETY NOTE VVE3.1.: NG1.11 OW03/112 RWO 09/24/12 IS/J/11) SET MP RED & XXN RUG (09/20/12) FERMI "IT70800 11/09/04 JOINTLH MVO 10/29/12 SET/JM3 SET WFD B2 PKR (10/04/12) API No: 50-029-20283-00 04/29/06 JGIV/PJC FULL FISH (4 8975 (12/21 10/29/12 G.IS/JIVDFULL XX PLUG, SET 7" PATCH (10/26/12) SEC 1, TI 114, R14E, 1095.1' FE. & 609.5' FM. 04/21/06 JCW/PJC FISH E ! 10425 11 [ 09/05/08_ JMO/PJC WELLHEAD CORRECIIONS BP EXploration (Alaska) • MEMORANDUM TO: Jim Re -- t� P.I. Supervisor y 71 Jt Z' FROM: John Crisp Petroleum Inspector E State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November 19, 2012 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-11 PRUDHOE BAY UNIT NGI-11 Src: Inspector Reviewed By: P.I. Supry Zg- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-1 l API Well Number 50-029-20283-00-00 Inspector Name: John Crisp Sd Permit Number: 177-080-0 Inspection Date: 11/8/2012 Insp Num: mit 1 21 1 1 20621 01 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ', NGI-I1 'Type Inj G TVD 7238 IA 959 2108 1902 -- —_� PTD 1770800 Type Test SPT Test psi 1809 OA 15 12 14 interval OTHER P/F P ✓ Tubing 3382 3375 3375 — —� Notes: MITIA post tubing patch. It took 8.5 bbls to test the IA. ,F5qt? luc�C/ I Suwn j 307 SCANNED Aij ` Monday, November 19, 2012 Page I of 1 • rallE A[LAsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1iISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Bethany Freel Interventions Engineer 51 / AuG I BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU NGI -11 Sundry Number: 312 -307 1 _ 7 QO Dear Ms. Freel: 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, KP Cathy . Foerster Chair DATED this I d y of August, 2012. Encl. STATE OF ALASKA * kc ' \ RECgIV,ED ALASKA OIL AND GAS CONSERVATION COMMISSION i'Uti 0 7 2012 APPLICATION FOR SUNDRY APPROVALS �OGCC 20 ARC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ig • Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 177 -080-0 ' 3. Address: Stratigraphic ❑ Service IS 6. API Number: P.O. Box 196612, Anchorage, AK 99519 -6612 50 -029- 20283 -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 El PBU NGI -11 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0028302 • 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): 10496 • 8610 . 10425 8548 8982 10425 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 26 - 106 26 - 106 Surface 2719 13 -3/8" 72# N -80 25 - 2744 25 - 2744 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 1293 7" 29# MN -80 9203 - 10496 7518.13 - 8609.93 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths 7" DB -6 SSSV 2215', 2215' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program n BOP Sketch ❑ Exploratory [l Development ❑ Service n 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ El WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact A03 ,. . 6C4c13 Prepared by Garry Catron 564 -4424 Printed Name 12 _ , ,' r - e - 1 Title ..� 1.. v i Signature � / Phone ■a e �ti../I _"Pr _ • 1 , COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 312 • . Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Subsequent Form Required: /C - 4 G 9- � APPROVED Y Approved by: � OMMISSIONER THE COMMISSION �- Date: e / �i / Z (41 Di 1A5 1 , 4/ Form 10 -403 Revised 1/2010 � � , S'./•*--- u mit in Dupl' ate V „� J AUG 16 2 ��4 // R I G I A L .�`' z tb, Casing Summary ADLOO283O2 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 80 20" 91.5# H -40 26 106 26 106 1490 470 H-40 LINER 1293 7" 29# MN -80 9203 10496 7518 8610 8160 7020 MN -80 PRODUCTION 960 9 -5/8" 47# NT95HS 24 984 24 984 8150 5080 NT95HS PRODUCTION 1393 9 -5/8" 47# L -80 984 2377 2377 7797 6870 4760 L -80 PRODUCTION 7167 9 -5/8" 47# N -80 2377 9544 984 2377 6870 4760 N -80 SURFACE 2719 13 -3/8" 72# N -80 25 2744 25 2744 4930 2670 N -80 • TUBING 2181 7 -5/8" 29.7# L -80 24 2205 7273 7365 6890 4790 L -80 TUBING 23 7" 26# L -80 2205 2228 7230 7233 7240 5410 L -80 TUBING 6590 7 -5/8" 29.7# L -80 2228 8818 7248 7277 6890 4790 L -80 TUBING 23 7" 26# L -80 8818 8841 7212 7230 7240 5410 L -80 TUBING 4 7 -5/8" 29.7# L -80 8841 8845 7233 7248 6890 4790 L -80 TUBING 19 7" 26# L -80 8845 8864 24 2205 7240 5410 L -80 TUBING 37 5 -1/2" 17# L -80 8864 8901 2205 2228 7740 6280 L -80 TUBING 115 5 -1/2" 17# L -80 8896 9011 2228 7212 7740 6280 L -80 • • • Packers and SSSV's Attachment ADL0028302 Well Facility Type MD Top Description TVD Top NGI -11 SSSV 2215 7" DB-6 SSSV 2215 NGI -11 PACKER 8853 9 -5/8" Baker SAB -3 Packer 7239 NGI -11 PACKER 8947 5 -1/2" Baker SABL -3 Packer 7314 • • Perforation Attachment ADL0028302 Well Date Perf Code MD Top MD Base TVD Top TVD Base NGI -11 5/10/79 PER 9870 9900 8070 8095 NGI -11 5/22/87 APF 9906 9918 8100 8111 NGI -11 5/10/79 PER 9918 9948 8111 8136 NGI -11 5/22/87 APF 9948 9964 8136 8149 NGI -11 5/10/79 PER 9964 9984 8149 8166 NGI -11 5/22/87 APF 9984 10000 8166 8180 NGI -11 5/10/79 PER 10000 10040 8180 8214 NGI -11 5/22/87 APF 10040 10066 8214 8236 NGI -11 5/10/79 PER 10066 10086 8236 8253 NGI -11 5/22/87 APF 10086 10098 8253 8264 NGI -11 5/10/79 PER 10110 10130 8274 8291 NGI -11 5/10/79 PER 10150 10160 8308 8317 NGI -11 5/10/79 PER 10190 10200 8343 8351 NGI -11 5/10/79 PER 10212 10232 8361 8379 NGI -11 5/10/79 PER 10264 10280 8406 8420 NGI -11 5/10/79 PER 10304 10318 8441 8454 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 TREE = CIW • WELLHEAD = GRAY N G I -11 SA TE: WELL REQUIRES A SSSV. ***FIELD NGL DISPOSAL WELL *** ** *CHROMES -1/2 TBG*** ACTUATOR = BAKER KB. ELEV = 44' BF. ELEV = fi I 22' H 7" X 7 -5/8" XO, ID = 6.276" I KOP = 2950' / 4 '1 400' 1—I EST. TOP OF ARCTIC SET CEMENT J Max Angle = 52° CO 7598' 1 1 1 1 1 1 1 1 Datum MD = 10783' 111 11 2203' H 7 -5/8" X 7" XO, ID = 6.276" I Datum TV D = 8800' SS 1 1 1 2215' H 7" 08-6 NO GO NIP, ID = 6.000" I • M 1.1! I • • • �� 2226' H 7" X 7 -5/8" X0, ID = 6.276" I • 9 -5/8" CSG, 471, L -80, ID = 8.525" —I 2373' 1 1 2348' H9 -5/8" NALCO ES CEMENTER, ID = 8.50" I NOTE: SEE DRLG FILE FOR THREAD LIST 113 -3/8" CSG, 721, N-80, ID = 12.347' H 2744' I Minimum ID = 4.466" @ 8995' 8816' H7 -5/8" X 7" XO, ID = 6.276" I 6 -1/2" OTIS XN NIPPLE ( 8828' H7 HES RNIP, ID= 5.683" ..... 8839' IH r X 7 -5/8" XO, ID = 6.276" I I7 -5/8" TBG -PC, 29.71, L -80, .0459 bpf, ID = 6.919" H 8841' I 8841' H 7 -5/8" X 7" XO, ID = 6.220" 1 / -0 . 8860' H K -22 ANCHOR TBG SEAL NIP, ID = 6.000" I 8851' H9-5/8" X 5-1/2" BAKER SA B -3 PKR, ID = 6.000" I 17" TBG, 268, L -80, .0383 bpf, ID = 6.276" H 8839' I En I 8862' I-1 X 5-1/2" XO, ID = 4.880" I 8875' N5 -1/2" HES X NIP, ID = 4162" I 15-1/2" TBG, 171, L -80, ID = 4.892" H 8896' I I fill I 8899' H9 -5/8" X 5-1/2" UNIQUE OVERSHOT I I 8927' H5 -1/2" TIN SBR ASSY W /BKR K -22 ANCHOR LATCH I f POSSIBLE FISH BEHIND 5-1/2" STUMP ? ?? NALCO RBP DRAG BLOCK (6" X 1" X 1/2 ") I 8943' H 9 -5,/8" X 5-1/7' BAKER SABL -3 PERM PKR I ►�� I 8978' H S -1/2" PARKIN SW8 MP, ID= 4.662" I I 8995' H 6 -112" OTIS XN NIP, ID= 4.455" I 1 5-1/2" TBG, 171, 13CR -80, .0232 bpf, ID = 4.892" H 9008' I•-- - " — 9008' H5-12" TUBAVG TAIL WLEG I ITOP OF 7" LNR H 9203' 1 H BIM TT NOT LOGGED J 19 -5/8" CSG, 471, N-80, ID = 8.681" H 9544' 1—A PERFORATION SUMMARY I REF LOG: BHCS ON 02/28/78 ANGLE AT TOP PERF: 33° @ 9870' 1 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9870 - 9900 0 05/22/87 3-3/8" 4 9964 - 10098 0 0522/87 3-3/8" 4 10110 - 10130 0 05/10/79 I 3-3/8" 4 10150 - 10160 0 05/10/79 3-3/8" 4 10190 - 10200 0 05/10/19 3-3/8" 4 10212 - 10232 0 05/10119 3-3/8" 4 10264 - 10280 0 05/10/79 3-3/8" 4 10304 - 10318 0 05/10/79 I 10425' H FISH (4" SV PIN / FLAPPER (426/06) 1 PBTD 10425 ,I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 17" LNR, 29#, MN-80, .0371 bpf, ID = 6.184" H 10496' 1,1.1.kkk1, DATE REV BY COMMENTS DATE REV BY CONVENTS FRUDHOE BAY UNIT 03/12178 ORIGINAL COMPLETION 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE WELL: NGI-11 08/03/92 I9NO 05/14/12 CJN/JMD SET XX PLUG (05/12/12) PERMIT No 1770800 11109/04 JDM/TLH RINO 07/26/12 GJF /JMD PULL XX PLUG (07/23/12) API No: 50 -029- 20283 -00 04/29/06 JGWPJC PULL FISH © 8975 (12/21/04) SEC 1, T11 N, R14E, 1095.1' FEL 8 609.5' FNL 04/21/06 JGMPPJC FISH @ 10425 , 09/05/08 JMO/PJC WELLHEAD CORRECTIONS 1 BP Exploration (Alaska) • • bp NGI -11 is an Elevated Risk Well. Please review and follow the extra requirements as prescribed in the Elevated Risk SOP. To: C. Olsen /J. Bixby Date: August 3, 2012 GPB Well Ops Team Leaders From: Bethany Freel AFE: APBWEINR Interventions Engineer / Est. IOR: 1000 bpd Subject NGI -11: 7" 2 trip tubing patch / Est. Cost: Please perform the following procedure: 1 S Pull 7" CA Al ISSSV, Set 5 -1/2" x 3 -1/2" XN nipple reducer in 5 -1/2" XN Nipple, set 3 -1/2" plug in nipple reducer 2 E Set lower patch element @ 8846' MD 3 S Set upper section of patch, pull plug from XN NIP reducer, Set 7" Al ISSSV Well Status Current Status: Not Operable Max Deviation: 52 degrees @ 7598' MD Minimum ID: 4.455" @ 8995' MD 5 -1/2" OTIS XN NIP Last Downhole Op: 07/23/2012 S/L set 7" CA Al ISSSV @ 2215' MD Last TD Tag 04/28/2012 S/L tagged soft bottom © 10,354'SLM/10,375' MD with 3.60" Cent./TEL/2.5" S. Bailer Objective Restore tubing integrity and return to operable status by placing a patch over tubing leak at 8841' MD. The leak was suspected due to TxIA communication and was later confirmed with an E -line LDL. A successfully set patch will enable the well's classification the be changed to operable. In order to allow for plug setting below the patch, a nipple reducer and a plug must be set in the XN nipple prior to setting the patch. After successfully setting the patch, the plug will be P ulled and an Al ISSSV must be installed. Well History NGI -11 was first completed on 03/12/1978 and has been worked over twice, once on 08/03/92 and the latest on 11/09/04. In early 2007 IAP rose and consistently remained around 600 to 800 psi but operation was not affected. In January 2009 an AOGCC MIT -IA passed to 2000 psi but in February 2010 evaluation of high IAP began after consistent IA repressurization around 1000 psi. Investigation continued with various troubleshooting measures including a passing PPPOT- 1 • • T on 12/03/2011 and a 40 arm caliper from 9025' to surface on 01/06/2012 indicating that the tubing appears to be in good condition with no significant wall penetrations or losses. Despite continued IA repressurization, another AOGCC MIT -IA passed to 4200 psi on 01/07/2012. On May 25, 2012 E -line conducted an LDL and located a slow tubing leak at 8841' MD. After the log, slickline replaced the Al ISSSV and the well was temporarily reclassified as under eval for NGL injection. The 7" Eclipse patch to be used in this procedure was originally slated for NGI -01 but after it • was decided that NGI -01 would be worked over, the patch will be used for NGI -11. The patch set up for NGI -01 was designed with special packer elements for a greater temperature range. Since the patch in NGI -11 will not see these temperature ranges, please ensure that standard packers are used, NOT the 90/70/90 elements. Contacts: Bethany Freel, Interventions Engineer Office: Cell: (907) 379 -6493 Josh Allely, Interventions Engineer Office: 564 -5732 Cell: 350 -7362 Javier Farinez, NGI PE Office: 564 -5043 Procedure Slickline 1. Pull CA Al ISSSV from 7" DB -6 NO -GO NIP at 2215' MD / 2. Set 5 -1/2" x 3 -1/2" XN nipple reducer in 5 -1/2" Otis XN NIP at 8995' MD • Please ensure that the seal bore of the 3 -1/2" section of the reducer has a NO -GO shoulder 3. Set plug in nipple reducer at 8995' MD 4. MIT -T to 3500 psi to ensure plug is holding • The MIT -T should not fail due to the tubing leak because of its slow leak rate. 2 - • Tubing volume to the XN Nipple is -411 bbls. Plan fluid transports accordingly. 5. RDMO slickline E -line 6. Set bottom section of 7" Weatherford Eclipse 2 trip patch with the center of the packer element at 8846' MD • Tie -in log: PDS Leak Detection 25- May -2012 • Ensure that the bottom section of the patch is set with the snap latch assembly facing UP to allow the upper section of the patch to latch in. • Please review attached patch schematic and tie -in log for visual confirmation of setting depth • Ensure that standard packer elements are used (NOT the higher temperature range 90/70/90 elements) 2 • • 7. RDMO E/L Slickline 8. Set upper section of 7" Weatherford Eclipse 2 trip patch in snap latch seal assembly. With the bottom section set at 8846 mid element, the top of the snap latch seal assembly will be at 8841' MD • This should result in a setting depth of 8823' MD for the center of the top packing element. 9. Pull plug from nipple reducer at 8995' MD 10. Install 7" Al ISSSV in 7" DB -6 NO -GO Nipple @ 2215' MD , 11. RDMO Tie -in Log: 3 • • , 1 Viacedo 1 fplAPA'%- 46 tiV-e-ti Fle-- LEAK DETECTION - WLD 4 aw S V XTU - HTEN - CCL - TEMP - WLD ii. 25 - May-2012 PRoAcTive trimgmasTic Seuvicas d c Company BP EXPLORATION (ALASKA), INC. --z 63 Well NGI - 1 1 _lc to as < Field PRUDHOE BAY c .0 ,... County NORTH SLOPE State ALASKA c ak-(1) ' Surface Location Other Services 0r CO ai None il x i , _ .c TI . _v 254.23' FSL & 889.73' FWL ..c - "Z aca Z er. Z .1 _ SEC: 1 IVVP: 11N RGE: 14E „._ Elevation Permanent Datum MSL Elevation 0.0 Ka 44.00' E 7 12 = 1 Log Measured From RKB 44_0 FT. Above Perm. Datum ' D.F. N/A 8 3 it 8 M API Serial Number 50-029-20283-00 G.L. NIA Date 25- May: 2012 Run Number ne . - 0 8 T D Dnller 10,426 P B T D Logger Not Tagged , Bottom Logger! Interval 8 646' . - , Top Log Interval Surface . Open Hole Size N/A Tyr, Fluid , , Irlie 03d Gas Max. Racorded, Isrif r) 135 . . - Time Wei 11.00 FINAL PRINT Time Logrr on Bottom 13:50 , Equipment Number SLB EL /2266 . Location , North Slope _ ..._...... _ • T _ Service kworce No , 11634 Recorded gli . 1 T. Thompson D,Sparks Witnessed By I T. Roctinger . Borehole Record Tubing Record Run Number Bit 1 From To _ ,,, Size LB /.Ft _ Fforn .._ _ _ 3.9... One N/A 7 5/8" 29.70 _ 22 8,841' , . r 26.00 8816 8839' 1 • , 17.00 - 8 r 862' 9,006 ` - Caai Record ; Size LB / Ft Tosi . . Bottom Surface String I 13 3/8" 7200 Surface 2744' Prot. Striw 9 5/8 47.00 t Surface 9,544' i _Liner 7" 29.00 I - 9,203' 10,496' . , ' Liner 1 . , i I - 1 . 1 , 4 • • -," Expanded Main Pass - Tbg x IA Leak Active w Tbg = 3,300 psi -- IA = 400 psi -- OA = 0 psi p.,..A..:— u,,,—,„..0.„ir, s...vic.,. Database File: diwarrior\datatrigi-11_1dhngi-11_1d1_3.db Dalaset Pathname: pass4 Presentation Format: wld log Dataset Creation: Fn May 25 13:51:00 2012 by Log Sondex V7.02 SP1 Charted by: Depth in Feet scaled 1 240 4000 CCL -465 120 Temperature (degF) 140 0 Line Speed (ft/min) -200 -3 Differential Temperature (degF) 1 . _. 0 Head Tension (lb) 200 0 WLD-A 250000 0 Temperature (degF) 200 0 WLD-B 250000 _ ...„ .... 0 WLD-C 250000 ' 1 ! - - i --- Head Tenson i Line Speed CC —II' 1-P I 1 i . 141 i I ) ' i . i t ,. . 7 8800 — - -, i Temperature --11. i Temperature --0 ; 1 i 1 Differential Temperature —11•;:, , / - 1 -&-- X-Over i • --- 1 1 -- -_, Tor ei-emer41 - I .t i e- -:* 1 "- Niiii • 1 ..e I i i 1 , Leak Signature WLD-A •:-......„,::::::., . , 1 -0v _-_-... ... . - IN ELEME-r [ a WLD-B Packer , .. 1 . , . III WLD X-Over - ; --• -1; -.- ; . . i- . ,..-...- 1 ; . . 4000 CCL -465 120 Temperature (degF) - 140 0 Line Speed (ft/min) -200 -3 Differential Temperature (degF) i 1, 0 Head Tension (lb) 200 0 WLD-A 250000 5 • • • W { A dept: 8P Alaska Lome � 'EOA Address: Fiald .Prudnoe 1Neatherford Pariah Paten 01:8-0 ,i wnp.ny Man I.ao n AIINY _ ,.... Drilling & Intervention well Nunit erg NGI-11 _Phan* : E07 4644732 - Services Pape of Operation: 2T 7" eR patc iteart C/T to $arbet Taal Deactivliol Teel O/D Toot VD Lagtil { Depth 1 Cannelton ,I Asset No. Top of Packer I 8817 1 Weatherford 5.720 4ilia) 6.30 4.58 rd NU box ER Packer KP 70001 1 If 1 Setting 5.4 Center of Element Depth to TOP of Packer 8823 M 2 Spa Pipe 4.500 1458 15.37 torsi 4.5 8 rd Nu pie Straddle x 4.5 8 rd NU pin Length 21 1 4 4' 1. I 3 Snap latch 5.720 4.0011 I ,64) 4.3 8 rd N[' box . . Seal Assembly bp ?i.■;I4i a 4 Weatherford 5.720 4.000 6.30 ER Packer t HP 70002 t Se oul 5 Center of Element S to TOP or Packer Depth 6846 DRILLING & INTERVENTION SERVICES THRU TIMING PACKER INTERVENTION '1Totai Stradma Lana* of B,H.A.:. 7.N _ (Motara) J 21.t e rr B.H .A Propa b I Oata flea. rote tint an 1233s an: 1 ?s am appanaasIc arm are awe as a tatonea*a 0n8 IELH.A. 10) (Runt a Aaron McDonough 17 Jul12 6 • • • TUBING SUMMARY }-`� RIG Nabors 4es Date 11/4/2004 ( BP + 1 WELL # NGI -11 TUBING 7 5/8" L-80 IPC Vam Top HC -' TBG WT. 29.7 lb /ft. 210 JTS RAN 19.28 4es KB TO BF 8757.39 FT ON RACK 8,757 FT RAN NOTE: CORRECTIONS IN RED BY T. HOLBROOK 11/16/04 ID OD LENGTH TOP BOTTOM 1 9 5/8" x 5 1/2" Unique OS. OA = 9.57 5.630 8.190 3.00 8896.00 8899.00 5 1/2" 17 lb/ft L-80 TCII Pup Jt. 4.850 5.970 9.78 8886.22 8896.00 5 1/2" 17 lb /ft L-80 TCII Pup Jt. 4.892 6.085 9.80 8876.42 8886.22 5 1/2" X- Nipple. Pkg Bore 4.562" w /RHC Plug 4.562 5.930 1.24 8875.18 8876.42 5 112" 17 lb /ft L-80 TCII Pup Jt. 4.892 6.085 9.67 8865.51 8875.18 7" x 5 1/2" XO Sub. 4.880 7.750 3.91 8861.60 8865.51 7" 32 Ib/ft T -95 Vam Top HC Pup Jt. 6.070 7.740 5.84 8855.76 8861.60 9 5/8" x 7" Backer SAB -3 Packer 6.000 8.250 4.63 8851.13 8855.76 K -22 Anchor Tubing Seal Nipple 6.000 8.060 1.09 8850.04 8851.13 7 " 32 lb/ft T -95 Vam Top HC Pup Jt. 6.060 7.540 7.10 8842.94 8850.04 7 5/8" x 7" XO Sub. 6.220 8.250 1.87 8841.07 8842.94 7" x 7 5/8" XO Sub. 6.276 7.625 1.80 8839.27 8841.07 7" 26 lb /ft L-80 TCII Pup Jt. 6.276 7.500 9.79 8829.48 8839.27 7" HES R- Nipple. 5.963" 5.963 7.500 1.59 8827.89 8829.48 7" 26 lb/ft L -80 TCII Pup Jt. 6.276 7.500 9.79 8818.10 8827.89 7 5/8" x 7" XO Sub. 6.276 8.250 1.94 8816.16 8818.10 158 ea 7 5/8" 29.7 lb /ft L-80 IPC VT HC Tbg. 6.919 8.213 6588.36 2227.80 8816.16 7" x 7 5/8" XO Sub. 6.276 7.625 1.81 2225.99 2227.80 7" 26 lb /ft L-80 TCII Pup Jt. 6.276 7.500 9.80 2216.19 2225.99 7" DB-6 Nipple. No-Go = 7.656" x 6.00" ID. 6.000 7.500 1.58 2214.61 2216.19 7" 26 lb /ft L-80 TCII Pup Jt. 6.276 7.500 9.80 2204.81 2214.61 7 5/8" x 7'" XO Sub. 6.276 8.250 1.94 2202.87 2204.81 51 ea 7 5/8" 29.7 lb /ft L-80 IPC VTHC Tbg. 6.919 8.213 2127.54 75.33 2202.87 7 5/8" 29.7 lb /ft L-80 IPC VT HC Pup Jt. 6.919 7.500 7.56 67.77 75.33 1 ea 7 5/8 " 29.7 lb /ft L-80 IPC VTHC Tbg. 6.919 8.213 41.49 26.28 67.77 7 5/8" 29.7 lb /ft L-80 IPC VT HC Pup Jt. 6.919 7.500 3.54 22.74 26.28 7" x 7 5/8" XO Sub. 6.276 7.000 .79 21.95 22.74 Vetco Grey Gen II Tubing Hanger 6.257 1.85 20.10 21.95 20.10 20.10 4 es KB ( +) 19.28 .82 20.10 .82 .82 Top Hanger Thread = 7" BTC .82 .82 .82 .82 PUW = 272 K .82 .82 SOW =171 K .82 .82 .82 .82 .82 .82 .82 .82 7 • 177 (DMZ Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator@bp.com] g( ql Sent: Thursday, August 02, 2012 4:05 PM ll To: Regg, James B (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; G GPB FS1 DS; Farinez, Javier Cc: AK, D &C Well Integrity Coordinator; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Injector NGI -11 (PTD #1770800) Utilization for Short Term NGL Injection During Proration Has Been Completed All, Injector NGI -11 (PTD # 1770800) utilization has been finished, with the disposal of the NGLs from the flow lines. The well is reclassified as Not Operable and will be secured as soon as well work is allowed on the drill site. Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) SCANNED MAY 0 7 2013 Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Wednesday, July 25, 2012 6:06 PM To: 'Regg, James B (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, ••S FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Le. •; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, • GPB East Wells Opt Engr; G GPB FS1 DS; Chivvis, Robert Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingi • smith, Mike 3 Subject: UNDER EVALUATION: Injector NGI -11 (PTD #1770800 ell To Be Utilized for Short Term NGL Injection During Proration All, Injector NGI -11 (PTD # 1770800) has been re- assified as Under Evaluation to allow for NGL injection to clear flow lines during pro- ration at Flow Statio• 1. Please notify the Well Integrity Coordinator at completion of this operation to facilitate the re- securi - g of the well upon completion of the operation. Please call if you have questions or'concerns. 1 Mt 17 00 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] t �� 7 ` �I i Sent: Wednesday, July 25, 2012 6:06 PM To: Regg, James B (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; G GPB FS1 DS; Chivvis, Robert Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J Subject: UNDER EVALUATION: Injector NGI -11 (PTD #1770800) Well To Be Utilized for Short Term NGL Injection During Proration All, Injector NGI - 11 (PTD # 1770800) has been reclassified as Under Evaluation to allow for NGL injection to clear flow lines during pro- ration at Flow Station 1. Please notify the Well Integrity Coordinator at completion of this operation to facilitate the re- securing of the well upon completion of the operation. Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659-5102 SCANNED MAY 0 2 2013 Cell (907) 752 -0755 Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Wednesday, June 20, 2012 9:33 PM To: AK, OPS FS1 DS Ops Lead Cc: Reynolds, Charles (Alaska); Daniel, Ryan; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A Subject: RE: AA on NGI -11 Dave, We have approval internally and from the AOGCC to use NGI -11 for short term injection of NGLs as requested without applying for an AA. We will have Slickline come out and pull the downhole plug and set the SSSV prior to the end of July to prep the well for injection. Please notify the Well Integrity Coordinator when you are ready to start the operation and we will send out notification to make the well Under Eval. Thanks, Mehreen Vazir 1, ?lit't"rufc. {ii'J',ilil 1 • Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com From: Reynolds, Charles (Alaska) Sent: Monday, June 18, 2012 12:57 PM To: AK, D &C Well Integrity Coordinator Cc: AK, OPS FS1 DS Ops Lead; Daniel, Ryan Subject: RE: M on NGI -11 Mehreen, Since we will only be clearing the surface lines of a small volume of NGLs and not performing regular injection service Doug is comfortable making this well "Under Eval" for the time necessary to clear the lines taking the NGLs down NGI -11 instead of rigging up temporary hardline. Charles Reynolds BP Alaska Well Integrity Group Ph: (907) 564 -5480 Cell: (907) 575 -6234 Email: Charles.ReynoldsCa�BP.com From: AK, OPS FS1 DS Ops Lead Sent: Thursday, June 14, 2012 10:18 AM To: Reynolds, Charles (Alaska) Subject: RE: AA on NGI - 11 Charles I talked with Steve Bunch out at CCP and we are looking to inject around 92 bbl of NGL with a 10 bbl Methanol chaser down NGI 11. This will take 2 days and would start sometime between the dates of July 28th and August 10th. Sorry I could not nail it down more accurately. If you need more info let me know Thank you Dave Demaris ALT; Tony Peter FS1 DS LEAD OP email : AK, Ops FS1 DS Ops Lead office: 907 - 659 -5394 cell: 907 - 602 -6940 2 • • From: Reynolds, Charles (Alaska) Sent: Thursday, June 14, 2012 7:23 AM To: AK, D &C Well Integrity Coordinator; Demaris, David C Cc: AK, OPS FS1 DS Ops Lead; Daniel, Ryan Subject: RE: AA on NGI -11 Dave, Do you have an estimated duration of time that NGI -11 will be needed for NGL service and the injected volume? Charles Reynolds BP Alaska Well Integrity Group Ph: (907) 564 -5480 Cell: (907) 575 -6234 Email: Charles. Reynolds c(DBP.com From: AK, D &C Well Integrity Coordinator Sent: Tuesday, June 12, 2012 9:48 AM To: Demaris, David C; AK, D &C Well Integrity Coordinator Cc: AK, OPS FS1 DS Ops Lead; Reynolds, Charles (Alaska); Daniel, Ryan Subject: RE: AA on NGI -11 Dave, In regards to pursuing a patch for NGI -11, town is working on getting a patch ready for this well. There are a few uncertainties about when the timing of prepping then setting the patch will take place. Timing will depend on how long it will take to prep the patch for this well. In addition, if we are able to fabricate and patch this well in time for the CCP TAR, there is no guarantee the patch will restore the operability of this well. The well will be pressure tested once the patch is set and if the MIT -IA fails, the well will remain not operable. The Wells Group is working on getting the patch ready and set in a timely fashion but cannot guarantee that the repair will be completed or hold by the time of the TAR when you will need to inject NGLs. Charles, Can you touch base with Doug when he returns to town next week in regards to pursuing an AA for this well? Thanks, Whitney King filling in for Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 3 • • From: Demaris, David C Sent: Tuesday, June 12, 2012 9:34 AM To: AK, D &C Well Integrity Coordinator Cc: AK, OPS FS1 DS Ops Lead Subject: AA on NGI -11 Wells Group Wells NGI -7 and 11 have a permanent 4" NGL line tied into their flow lines for the purpose of disposing of NGL's from CCP. This July during the TAR, CCP will need to do some welding in their plant on this 4" NGL disposal line. We have been tasked with helping them clean up their system by pumping Methanol, then water and finally N2. We had planned to push the NGL's down hole on NGI -11 and out of harms way, then switch to hot water which will be diverted to a tank via a short run of hardline off the tree cap, and then the line will be purged of all liquids with N2. If NGI -11 cannot be used because of the Tbg x IA Comm, we will have to run 150' of hardline from the tree cap on NGI -11 over to the tree cap on NGI -12 and dispose of the NGL's down well 12. This will also require two tanks. This could be done, but it could also be problematic dealing with NGL's in the hard line. I am proposing an AA on NGI -11 so we can keep it on line and dispose of the NGL's down well 11 so we do not have to rig up to NGI -12. Your consideration would be greatly appreciated Dave Demaris ALT; Tony Peter FS1 DS LEAD OP email : AK, Ops FS1 DS Ops Lead office: 907 - 659 -5394 cell: 907 - 602 -6940 4 V77- o$o • • '2- k 6 29 WELL LOG Mr S TRANSMITTAL PROACTIVE DiAgNOSric SERVICES, INC. To: AOGCC Christine Shartzer 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 attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Shay Phillips LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 AUG 1 6 LU1L and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - WLD 25- May-12 NGI -11 BL / CD 50 -029- 20283 -00 2) Leak Detection - WLD 16- May-12 N -19 BL / CD 50-029- 20922 -00 / ol 2 Signed : � �_ �:/ Date : C � l k Print Name: N tx --- -- 6 ty" PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 Fax: (907)245 -8952 E -MAIL : PDSANCHORAGEAMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution \TransmittalSheets\BP Transmit.doc, PTb 177olgoo Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Sunday, May 27, 2012 6:02 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, RES GPB Central Prod Opt Engr; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Chivvis, Robert; Daniel, Ryan Cc: Walker, Greg (D&C); Olson, Andrew; AK, D&C DHD Well Integrity Engineer Subject: NOT OPERABLE: Injector NGI-11 (PTD #1770800) Tecwel LDL Located Tubing Leak Attachments: NGI-11.pdf W A Tecwel LDL has been performed on Gas Injector NGI-11 (PTD #1770800) and a tubing leak was located at the 7- 5/8"x7" crossover at 8841' MD. At this time, possible repair options are being evaluate a well is secured with a downhole plug and is reclassified as Not Operable until a plan forward is determined and approval is obtained from the AOGCC for continued injection. A wellbore schematic is attached for reference: «NGI-11.pdf>> Thank you, Mehreen Vazir (,,l tlernwc: (icT 00 1,17ir hy) Well Integrity Coordinator SCAN"Er` BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Monday, January 30, 2012 12:19 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, RES GPB Central Prod Opt Engr; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Chiwis, Robert; Daniel, Ryan Cc: King, Whitney; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: OPERABLE: Injector NGI-11 (PTD #1770800) TxIA Evaluate for Administrative Approval All. Gas injector NGI-11 (PTD #1770800) passed an AOGCC witnessed MI A to 4200 psi on 01/07/2012 proving two competent barriers in the wellbore. The IA pressure has been erratic Ince the IA was fluid packed for the MIT as seen in the attached TIO plot. The well is reclassified as Operable and mremain on injection while further work is performed to determine if an Administrative Approval will be required. The w will continue to be reported on the AOGCC Monthly Injection Report. Plan forward: 1. WIC: Continue to monitor TIO for IA stabilization 2. Downhole Diagnostics: Bleed IA pressure once stilized and monitor repressurization to confirm an active leak prior to performing Leak Detect Log Z, TREE = CIW WELLHEf+) = GRAY 7 CTUATOR = BAKER KB. ELEV = 44' --- BF. ELEV = O KOP = - 295_0' Max Angle = 52° -10783 Datum M0 - 3-3/8" Datum TVD = 8800' SS 9-5/8" CSG, 47#, L-80, ID = 8 525" 2373' NOTE: SEE DRLG FILE FOR THREAD LIST 13-3/8" CSG, 72#, N-80, ID = 12.347" 2744' Minimum ID = 4.466" @ 8995' 6.1/2" OTIS XN NIPPLE 17.5/8" TBG -IPC, 29.7#, L-80-0459 bpf, ID = 6.919" 1 7" TBG, 26#, L-80, .0383 bpf, ID = 6.276" 5-1/2" XX PLUG (05/12/12) 15-1/2" TBG, 17#, L-80, ID = 4 892" POSSIBLE FISH BEHIND 5-1 /2"STUMP HALCO RBP DRAG BLOCK (6" X 1" X 112") 1 8841' 1 8839' 8875' 8896' ??? 5-1/2" TBG, 17#, 13CR-80, 0232 bpf, ID = 4.892" 9008' TOP OF 7" LNR —9203- 9-5/8" 203' 9 5/8" CSG 47# N-80, ID = 8,681 9544' PERFORATION SUMMARY REF LOG: BHCS ON 02128/78 ANGLE AT TOP PERF: 33° @ 9870' Note Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9870-9900 O 05/22/87 3-3/8" 4 9964- 10098 O 05/22/87 3-3/8" 4 10110- 10130 0 05/10/79 3-3/8" 4 10150 - 10160 O 05/10!79 3-3/8" 4 10190- 10200 O 05/10179 3-3/8" 4 10212- 10232 0 05110/79 3-3/8" 4 10264- 10280 0 05110!79 3-3/8" 4 10304- 10318 0 05/10/79 PBTD 7" LNR, 29#, MN -80, 0371 bpf, ID = 6.184" 10425' 10496' WELL REQUIRES A N G I -1 1 NGL D SPOSAL WELL— —CHROME 5-1/2 * LD TBG 22' 03112178 ORIGINAL COMPLETION 400� EST TOP OF A RCTIC SET CEMENT 2203' 11109!04 JDMtTLH RWO 2215' 7" DB-fi NO GO NIP, ID = 6.000" 2226' 8851' 2348' 9-5/8" NALCO ES CEMENTER, ID -1 8816' 1-17-5/8" X 7" XO, ID = 6.276" 03112178 ORIGINAL COMPLETION 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE 8839' 7" x 7-5l8" XO, ID = 6.276" 11109!04 JDMtTLH RWO 8850' K-22 ANCHOR TBG SEAL NIP, ID -:-6-00-0---] 8851' 9-518" X 5-1 /2" BAKER SAB -3 PKR, ID = 6.000" 09/05/08 1 JMO/PJC I WELLHEAD CORRECTIONS $875' S-112" NES X NIP, ID = 4.562" 8899' 9-5/8" X 5-1/2" UNIQUE OVERSHOT 8927 5-1/2" TMJ SBR ASSY W/BKR K-22 ANCHOR LATCH 8943' 1--�9-5/8" X 5-1/2" BAKER SABL-3 PERM PKR 8i 978' 1--16-1/2" PARKER SWS NIP, ID=4.662" 8995' 6-112" OTIS XN NIP, ID= 4.466" 9008' -[5-1/2" TUBING TAIL WLEG ELMD TT NOT LOGGED 10425' 1-1 FISH (4" SV PIN/ FLAPPER (4/26/06) DATE REV BY COMMENTS DATE REV BY COMMENTS 03112178 ORIGINAL COMPLETION 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE 08/03/92 RI 05/14/12 CJrYJMID SET XX PLUG (05112/12) 11109!04 JDMtTLH RWO 04/29/06 JGWPJC PULL FISH @ 8975 (12/21 t04) 04/21/06 1 JGWPJC I FISH @ 10425 09/05/08 1 JMO/PJC I WELLHEAD CORRECTIONS PRUDHOE BAY UNIT WELL: NGF11 PERMIT No 1770800 API No: 50-029-20283-00 SEC 1, T11 N, R14E, 1095.1' FEL & 609.5' FNL BP Exploration (Alaska) • • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, February 06, 2012 4:45 PM To: 'AK, D &C Well Integrity Coordinator' Subject: RE: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for January 2012 This is to memorialize my decision regarding reporting requirements for 5 injectors as discussed with you earlier today: (BU NGI -11 (PTD 1770800); BU AGI -08 (PTD 1930330) Weekly reporting may be discontinued based on passing MITs (1/7/12 for NGI -11; 2/5/12 for AGI -08). Intent as I communicated to Ryan Daniel on 1/20/12 was that weekly reporting was interim step while waiting for diagnostics (suspended due to extreme cold temps); TIO pressures should continue to be reported on monthly injection well integrity report for both wells until decision is made regarding need for Administrative Approval. PBU AGI -05 (PTD 1930020) Weekly reporting (see NGI -11) may be discontinued based on stabilization of annuli pressures that began last week of December 2011. This well can also be dropped from the monthly injection well integrity report at this time. PBU WGI -06 (PTD 190030) Existing Admin Approval (AIO 4E.006) should be canceled based on completion of workover. AOGCC will evaluate the need for a new Admin Approval for the shallow setting depth of packer associated with approved repair. PBU W -44 (PTD 1891000) Well may be removed from the monthly report based on passing MITIA (4/12 -11), no leak found with LDL (6/26/11), and stabilized annuli pressures exhibited during past 90 days while on injection.. Jim Regg 9LAWAEPFEB 1 3 2 112 AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 7934236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWeIIIntegrityCoordinator (abp.com] Sent: Sunday, February 05, 2012 10:09 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Sauve, Mark A Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for January 2012 Jim, Phoebe, and Guy, Attached is the January 2012 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. 1 «AOGCC Inj Report 02- 12.zip» Notes on wells: Added to Report: 11 -38A (PTD #1982160) Added per requirement of AA 4E.040 issued January 9, 2012. Taken off Report: MPC -10 (PTD #1850150) Was being evaluated for TxIA communication. IAP stabilized and well returned to Operable status. Please call with any questions or concerns. Thank you, Mehreen Vazir (Alternate. Gerald:t'lurplt}) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 2 . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission g � DATE: Monday, January 09, 2012 a TO: Jim Regg , l i 1d i L P.I. Supervisor �( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI -11 FROM: Matt Herrera PRUDHOE BAY UNIT NGI -11 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT NGI - 11 API Well Number: 50 029 - 20283 - 00 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH120108142159 Permit Number: 177 - 080 - Inspection Date: 1/7/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI-1I - Type Inj. N TVD 7238 - IA 85 4200 , 4159 4147 P.T 1770800 ' TypeTest SPT Test psi 1809 - OA 0 0 0 0 Interval OTHER - p/F P - Tubing 2185 2334 2321 2322 Notes: Well pressure tested to 4200psi. Well secured - StANNED FFR Monday, January 09, 2012 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, February 01, 2012 Jim Regg 2 " - r P.I. Supervisor l - 1 /(z- SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI -11 FROM: Matt Herrera PRUDHOE BAY UNIT NGI -11 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT NGI - 11 API Well Number: 50 029 - 20283 - 00 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH120108142159 Permit Number: 177 - 080 - Inspection Date: 1/7/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI -I I ''Type Inj N ' TVD 7238 " IA 85 4200 - 4159 4147 P.T.D 1770800 'TypeTest SPT � Test psi 1809 OA 0 0 0 0 Interval 4YRTST p/Ii P _ Tubing 2185 2334 2321 2322 Notes: Well pressure tested to 4200psi. Well secured s ' rtf)FEB C 5 '61' Wednesday, February 01, 2012 Page 1 of 1 i • • Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, January 30, 2012 6:47 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) el/ ( ;a) Z' Cc: Daniel, Ryan; Chivvis, Robert Subject: Gas Injector Status Update for AGI -08 (PTD #1930330), NGI -11 (PTD #1770800), and AGI -05 (PTD #1930020) Attachments: AGI -08 TIO 01- 30- 12.doc; NGI -11 TIO 01- 30- 12.doc; AGI -05 TIO 01- 30- 12.doc All, Please see attached updated TIO and Injection plots for the three subject wells. AGI -08 (PTD #1930330): No progress has been made at this time on the MCX reset due to wellwork operations being shut down for weather conditions on the North Slope. As we come back to normal operations, AGI -08 MCX change out will be a top priority job. An IA bleed was performed on 01/21/2012 and the well continues to exhibit slow IA repressurization. «AGI -08 TIO 01- 30- 12.doc» NGI -11 (PTD #1770800): Continue to monitor for thermal stabilization of the IA prior to progressing Leak Detect Log. «NGI -11 TIO 01- 30- 12.doc» AGI -05 (PTD #1930020): IA pressure continues to remain stable at 850 psi. Continue to monitor for IA repressurization. «AGI -05 TIO 01- 30- 12.doc» — w --- Please let me know if you have any questions or concerns. Thank you, ' Mehreen Vazir �EPFEB (� 3 ZU1L t4liernate. Gerald !tI urphva Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Co nator Sent: Sunday, January 22, 2 7:42 PM 1 • • PBU NGI -11 PTD # 1770800 1/30/2012 TIO Plot wales 11 1 1.000 3000 -U- 3e0 -111- IXq -a -M OM - • -_pOM 'r On 7(pr ........ 1 MO. 11 /01/11 11/12/11 1 /19/11 11/26/11 12/03/11 12 /10/11 12717/11 12/24/11 12/31 /11 01,07/12 01/14/12 01 /21/12 01/28/12 Injection Plot waNw -11 3000 210.000 230: 3.300 �' `�~ ♦ ~ v _ .. ', 220000 32� 210100 1100 3900 200/300 2910 19U.0W 2000 2700 18.010 '.. 2/3310 2500 1711,006 2.400 160600 2300 2100 150000 2100 140 000 m _yip 1,930 1LC00 1000 120.000 " - M 1,700 ) - AI /1f 110000 _aw iHL 1500 102D30 - On 1100 1700 90 OM 1200 60000 11C0 70000 1000 930 60030 GOO s¢aw 700 500 mom 400 300 0 CV 2110 1 2000 100 11/4/111 11/12/11 11,19/11 11/26/11 12/03/11 12/10/11 12/171 12%8/11 12/11/11 01/07/12 21/14/12 01/21 /12 01/28/12 '.,. Pr6 1 pg o Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] .se 3b/(.z_ Sent: Monday, January 30, 2012 12:19 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, RES GPB Central Prod Opt Engr; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Chivvis, Robert; Daniel, Ryan Cc: King, Whitney; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: OPERABLE: Injector NGI -11 (PTD #1770800) TxIA Evaluate for Administrative Approval Attachments: NGI -11 TIO 01- 30- 12.doc; MIT PBU NGI -11 01- 07- 12.xls All. Gas injector NGI -11 (PTD #1770800) passed an AOGCC witnessed MIT -IA to 4200 psi on 01/07/2012 proving two competent barriers in the wellbore. The IA pressure has been erratic since the IA was fluid packed for the MIT as seen in the attached TIO plot. The well is reclassified as Operable and may remain on injection while further work is performed to determine if an ddministrative Approval will be required. The well will continue to be reported on the AOGCC Monthly Injection Report. Plan forward: 1. WIC: Continue to monitor TIO for IA stabilization 2. Downhole Diagnostics: Bleed IA pressure once stabilized and monitor repressurization to confirm an active leak prior to performing Leak Detect Log - 2. Eline: Tecwel Leak Detect Log 3. APE: If a leak point is located, determine plan for repair 4. WIC: If no plan for repair, apply for Administrative Approval Attached is an updated TIO Plot, Injection Plot and MIT -IA form for reference: «NGI -11 TIO 01- 30- 12.doc» «MIT PBU NGI -11 01- 07- 12.xls» c Please let me know if you have any questions or concerns. Thank you, Mehreen Vazir aliittiVED FEB 0 3 21.02 (Alternate: Geru/d Ahoy >hv Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Monday, December 05, 2011 9:22 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwa , uy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, RES GPB Central Prod Opt Engr; AK, RES GPB East Wells O ngr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Chiwis, Robert Cc: Olson, Andrew; Arend, Jon (NORTHERN LOTIONS LLC) Inj Subject: UNDER EVALUATION: e NGI -11 (PTD #1770800) IA repressurization post bleed 1 • PBU NGI -11 PTD # 1770800 1/30/2012 TIO Pressures Plot Walk M61 -11 6.000 3.061 rt- TE0 t M 2900- —m— OA 001 '.,. 1604 1500 _a uoo 1120,1 +1112,1 1119,1 1/2611 !2!31,1 12,011 12,1,1 - - 12/24,1 12131,1 O1/07,2 11/14,12 01/2112 01/29/12 Injection Plot W16 M61.11 230 990 3100 ` 3 ` ` v 2111.000 r 3100 200 3100 2191000 3000 201000 2.920 ZOM 190.09/ 2.100 190 2mo 2520 2400 , 50 . 900 2320 2200 9/ 1501 2.199 I40000 —W1F 1.900 130000 pw 1620 '29.000 —M 1200 110110 1530 100 we .■ I40 510[0 1200 1100 00101 1100 100yp '... 1.000 900 60.09/ 1730 w.au ''.... 111 Sao 3 00 320 muro 211 m. 0 100 1116211 11/12/11 111011 111 002/11 1293/1 1212/11 12211,1 12/24/11 12/ 31,1 01207,2 01414/12 012112 01/006/12 '.,. • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaq(c'Dalaska.gov; doa .aogcc.prudhoe.bav @alaska.gov; phoebe.brooksCd).alaska.aov; tom.maunderAalaska.aov OPERATOR: BP Exploration (Alaska), Inc. � ( Q (I li FIELD / UNIT / PAD: Prudhoe Bay / EOA / NGI DATE: 01/07/12 OPERATOR REP: Mehreen Vazir AOGCC REP: Matt Herrera Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI -11 - Type Inj. N - TVD 7,238' Tubing 2185 2334' 2321 2322' Interval 4 P.T.D. 1770800 ' Type test P Test psi 1809.5 Casing 85 4200 4159 4147 P/F P ' Notes: Pumped 5.2 bbls of diesel to reach test pressure. OA 0 0 0 0 Witnessed MIT -IA to evaluate tubing x inner annulus communication. Apply to 4 year test requirement. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P /F_ Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial 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 Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU NGI - 11 01 - 07 - 12 • PI-N 17 7 o Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Sunday, January 22, 2012 7:42 PM 1- 11 i /z. To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Daniel, Ryan; Vazir, Mehreen; Chivvis, Robert Subject: Gas Injector Status Update for AGI -08 (PTD #1930330), NGI -1 (PTD #1770800 and AGI -05 (PTD #1930020) Attachments: AGI -08 (PTD #1930330) well bore schematic.pdf; AGI -08 (PTD 930330) TIO and Injection Plot.doc; NGI -11 TIO and Injection Data.xls; AGI -05 (PTD # 1930020) TIO and Injection Plot.doc Jim and Tom, I wanted to update you on the current status of 3 gas injectors that are either currently classified as Under Evaluation, AGI -08 and NGI -11, or we have been in communication about in the last month, AGI -05. AGI -08 (PTD #1930330) is awaiting the resetting of the MCX SSSV, which has been delayed due to weather conditions on the North Slope. The well is currently on injection, and has been showing slow TxIA communication with a rate of about 20 psi /day. The well has not exceed MOASP. The plan forward will be to change out the safety valve and monitor the IA pressure for continued build up. If continued pressure buildup is observed, a Leak Detect Log would be planned. Our plan forward would be to pursue an AA to allow for continued injection is a leak is not identified. «AGI -08 (PTD #1930330) well bore schematic.pdf» «AGI -08 (PTD # 1930330) TIO and Injection Plot.doc» NGI -11 (PTD #1770800) passed a witnessed (Matt Herrera) MIT -IA to 4200 psi with the well shut -in on 1/7/2012 but has continued to show erratic IA behavior after it was returned to injection, that appears to be thermally related as it reaches stabilization. An Excel plot is included which plots the last 3 months injection rate and temperature with the TIO plot for your review. An IA bleed performed on 1/16/2012 was recorded as all diesel. The plan forward will be to run a Leak Detect Log, then if nothing is identified, pursue an AA for the well. «NGI -11 TIO and Injection Data.xls» AGI -05 (PTD #1930020) is a well that had operated under an AA (4E.003) until it was cancelled in January, 2011 after not exhibiting IA repressurization for over a year. Shortly after the cancellation, the well began exhibiting intermittent slow IA repressurization. The well is currently not exhibiting IA repressurization since late December, as can be seen in the enclosed TIO and Injection plot. A rig workover is being planned for late 2012 to repair the well. Our plan forward is to pursue an AA since the rig workover is planned for late in 2012 to allow for continued injection until the RWO is completed. «AGI -05 (PTD # 1930020) TIO and Injection Plot.doc» All 3 wells will remain on the monthly injection reports. We are planning to continue to send weekly TIO and Injection plots to keep you informed on the status of these wells. Please call if you have any questions or concerns. Thank you, s ; L t� . Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1 NGI -11 TIO and Injection Plot PTD 1770800 4,000 - — 300 3,500 " --/-/----1\ — 250 3,000 , ..&,.. i��. A , tit 7°- • — 200 2,500 i u_ Wellhead Pressure Inner Annulus Pressure 0. 2,000 150 —Outer Annulus Pressure a I " —0--- Flow Line Temperature a o : :. ,,. " „ E — 3(-- Gas Injection (MMCFPD) w 1,500 " F - . " °— 100 1,000 . - ■ -. y 50 • 500 x \ 0 0 I \ N N NI N N 1 NI NI NI N NI N N N N N N \ �0 \ �0 \ �0 \ �0 \ �0 \ ,L0 \ �0 \ �0 \ �0 \ �0 \ � 0 \ � 0 \� 0 0 ,O \ \ 10 10 r1' Monthly Injection Report for GPIiPMA, Northstar, Milne Point & Endicefor Decem... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Tuesday, January 17, 2012 8:52 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Sauve, Mark A Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for December 2011 Attachments: AOGCC Inj Report 01- 12.ZIP Tom, Jim, Phoebe, and Guy, Attached is the December 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 01- 12.ZIP>> Notes on wells: Added to Report: bitAitieP NGI -11 (PTD #1770800) Under evaluation for IA repressurization. MPC -10 (PTD #1850150) Under evaluation for IA repressurization. Taken off Report: 16 -05A (PTD #2010100) Economic evaluation completed and well returned to Not Operable status. NGI -03 (PTD #1750610) Under Evaluation for IA repressurization in October 2011. No repressurization observed post SSSV change out WGI -03 (PTD #1790490) AA 4E.027 for TxIA communication cancelled post RWO. Please call with any questions or concerns. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 1/31/2012 Well NGI -11 Injection Plot TIO Plot Well: NGI -11 o Pressure vs. Rate o PTD: #1770800 0 0 0 v v Tbg IA Under Evaluation for IA o A o OA tir repressurization co o • O "' 12/03/11: Bled IA from 1120 to . a o • • ',7) 300 psi, 1 hr, gas 0 o a a 11/25/11: : Bled IA from 1370 to N = csi 500 psi, 20 min, gas o 0 0 0 0 • ♦ Last 90 days • Last Month o � 0 0 50,000 100,000 150,000 200,000 250,000 300,000 8/2/11 10/23/11 1/13/12 Injection Rate, MCFPD Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 01/01/12 225,271 3,315 01/01/12 3,315 1,100 20 12/31 /11 231,722 3,290 12/31 /11 3,290 1,100 20 12/30/11 229,926 3,355 12/30/11 3,355 1,150 20 12/29/11 232,421 3,319 12/29/11 3,319 1,100 20 12/28/11 224,312 3,319 12/28/11 3,319 1,140 20 12/27/11 229,550 3,337 12/27/11 3,337 1,100 40 12/26/11 236,255 3,334 12/26/11 3,334 1,060 40 12/25/11 237,194 3,313 12/25/11 3,313 1,040 40 12/24/11 233,707 3,270 12/24/11 3,270 1,040 40 12/23/11 231,206 3,280 12/23/11 3,280 1,040 40 12/22/11 218,855 3,308 12/22/11 3,308 1,100 20 • 12/21/11 210,520 3,347 12/21/11 3,347 1,160 20 12/20/11 212,409 3,344 12/20/11 3,344 1,160 20 12/19/11 210,409 3,363 12/19/11 3,363 1,160 20 12/18/11 209,335 3,357 12/18/11 3,357 1,120 20 12/17/11 206,452 3,357 12/17/11 3,357 1,160 20 12/16/11 198,766 3,335 12/16/11 3,335 1,200 20 12/15/11 212,620 3,332 12/15/11 3,332 1,100 20 12/14/11 212,338 3,376 12/14/11 3,376 1,160 20 12/13/11 207,998 3,353 12/13/11 3,353 1,120 20 12/12/11 197,509 3,331 12/12/11 3,331 1,220 20 12/11/11 185,806 3,308 12/11/11 3,308 1,220 20 12/10/11 189,678 3,326 12/10/11 3,326 1,220 20 12/09/11 203,195 3,358 12/09/11 3,358 1,220 20 12/08/11 221,372 3,400 12/08/11 3,400 1,140 20 12/07/11 235,426 3,392 12/07/11 3,392 1,020 20 12/06/11 236,106 3,368 12/06/11 3,368 1,020 20 12/05/11 219,823 3,364 12/05/11 3,364 1,080 20 12/04/11 227,854 3,384 12/03/11 3,359 1,080 20 12/03/11 237,334 3,359 12/02/11 3,360 1,090 20 12/02/11 236,468 3,360 12/01/11 3,364 1,080 20 OPERABLE: Injector NGI -11 (PTD #1770800) IA pressure stabilized Page 1 of�p Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Saturday, November 20, 2010 8:16 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, RES GPB Central Prod Opt Engr; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead Cc: King, Whitney; AK, D &C Well Integrity Coordinator; Chivvis, Robert Subject: OPERABLE: I njector NGI -11 (PTD #1770800) IA pressure stabilized Attachments: NGI -11 TIO Plot 11- 20- 10.doc All, Injector NGI -11 (PTD #1770800) has been monitored for more than two weeks without any signs of IA repressurization. The well has been reclassified as Operable and may continue on injection. A TIO plot has been attached for reference. «NGI -11 TIO Plot 11- 20- 10.doc>> Thank you, Torin Roschin er alt. Jerry Murp b' ( ►Y p Y) Well Integrity Coordinator 9 Y Office (907) 659 -5102 NOV 2 2 20% Harmony Radio x2376 Cell 406 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Thursday, November 04, 2010 2:23 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, RES GPB Central Prod Opt Engr; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Chivvis, Robert Cc: AK, D &C Well Integrity Coordinator; Janowski, Carrie; Winslow, Jack L (ASRC) Subject: UNDER EVALUATION: Injector NGI -11 (PTD #1770800) IA repressurization All, Injector NGI-11 (PTD #1770800) has slow IA repressurization as seen on the attached TIO plot. On 10/30/10, the operator bled the IA pressure from 1400 to 600 psi which built back up to 1050 psi over the next three days. The plan forward is to keep the well on injection and perform a pack -off test on the tubing to diagnose whether the communication is through the wellhead in addition to obtaining a build -up -rate. The well has been reclassified as Under Evaluation on a 28 day clock. A TIO plot, injection plot and wellbore schematic have been included for reference. << File: NGI -11 TIO & Injection Plot 11- 04- 10.doc >> Please call with any questions or concerns. 11/22/2010 WWII OV£l /IL Ol/90/Ll Ol /OM G"WL OV9"I Ol/60/OL 0L20/OL 0trZM OL/BV60 OVII /60 OV10/60 0V8Zl80 0V2/80 �•_...��y. -tom ono i up V00p voo U� VO'� 000 Z �� a� oonc — — 000 r � LL r+m TIO Plot �tbg —a ( \�.� � ..,.to mnanp pemna oenv,o ovrtuno pwnno u+neno oeano ,apvtp tpirono tpnsnp tp�no tp�pno Injection Plot wa N-11 3.ID0 '.111A00 '. 3000 'mom 3.W0 2�0 !LU.000 60,OW 2 ]WO z19L 1A 000 —MI 3 _IN On 1000 tl10 000 dW TL OB/OJn0 08AU10 @YZ,n0 ®/�10 09/OU10 Ol "in.0 00 ^, 0.n.CT 09!1 IONLtp lOr9An0 10/iW,0 t0 a3n0 ,0.030/10 ' AQ- It" MEMOl~ANDUM To: Jim Regg ~ I J P.I. Supervisor ~ ~~I % ~~~`j FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 07, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI- I I PRUDHOE BAY UNIT NGI-1 I Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UNIT NGI-t 1 Insp Num: mitJJ090106103638 Rel Insp Num: API Well Number: 50-029-20283-00-0o Permit Number: 177-080-0 / Inspector Name: Jeff Jones Inspection Date: 1/1/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ NGI-1] ~TYPe Inj. ~ G ~ TVD _ ~ 7238 ~ IA ~ ~ 20 ~ 2000 ~ ~ ~ 1960 ~ ]950 i - ~ P.T. ; rnos00 TypeTest sPT T st psi T l ao9 s ~ OA ~, a ~ o j o ~ ~ - - - o P _ _ Interval 4YRTST P/F -- Tllbtng -_ -- 3250 3250 I - - -- 3250 '~ 3250 ` - --- I - __ __ _ Notes' 10.2 BBLS diesel pumped. 1 well inspected; no exceptions noted. ------- - _ _ - ---- -- --- - - t do'` ~ffj~t t~ tj, ^ip~ ~« ~~ G~~t ~' Wednesday, January 07, 2009 Page I of 1 MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 'K¿f1 2/73/0<;' DATE: Wednesday, January 05, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORA nON (ALASKA) INC NGI-ll PRUDHOE SAY UNIT NGI-11 l77~6C66 FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv -..:-r~2.-- Comm Well Name: PRUDHOE BAY UNIT NGI-II Insp Num: mitLG050102224142 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-20283-00-00 Permit Number: 177-080-0 Inspector Name: Lou Grimaldi Inspection Date: 1/1/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI-ll Type Inj. G TVD 7238 IA 650 2010 1940 1890 1875 P.T. 1770800 TypeTest SPT Test psi 1809.5 OA 30 30 30 30 30 Interval WRKOVR P/F P Tubing 3460 3470 3440 3430 3420 Notes: SCANNEC MÞ.R 11 ZODS Wednesday, January 05, 2005 Page 1 of 1 " STATE OF ALASKA ) ALASKA u1L AND GAS CONSERVATION COI\IIMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ¡ 0 Abandon 1m Repair Well 0 Alter Casing iii Pull Tubing 0 Change Approved Program 0 Operation Shutdown 0 Plug Perforations 0 Stimulate 0 Perforate New Pool 0 Waiver 0 Perforate 0 Re-Enter Suspended Well 0 Other 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: 0 Development 0 Exploratory 0 Stratigraphic 1m Service 5. Permit To Drill Number: 177-080 6. API Number: 50-029-20283-00-00 99519-6612 44' 9. Well Name and Number: PBU NGI-11 8. Property Designation: ADL 028302 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 10496 feet true vertical 8610 feet Plugs (measured) None Effective depth: measured 10425 feet Junk (measured) Possible at 8943' true vertical 8548 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 95' 20" 95' 95' 1530 520 Surface 2744' 13-3/8" 2744' 2744' 5380 2670 Intermediate 9544' 9-5/8" 9544' 7797' 6870 4760 Production Liner 1293' 7" 9203' - 10496' 7518' - 8610' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): 9870' - 10318' 8070' - 8454' SCANNE.D J 0 (] 2005 7-5/8",29.7# x 7",26# Tubing Size (size, grade, and measured depth): x 5-1/2", 17# Packers and SSSV (type and measured depth): (2) 9-5/8" x 5-1/2" Baker 'SABL-3' packer L -80 / 13Cr80 9008' 8943' & 8851' 12. Stimulation or cement squeeze summary: Replace upper portion of 9-5/8" Casing; See attached Summary Intervals treated (measured): 400' - 2348' through 9-5/8" Halco ES Cementer at 2348' Treatment description including volumes used and final pressure: 114 Bbls of Arcticset Cement RBDMS 8FL JAN 0 3 2005 Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casino Pressure Tubino Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 1m Daily Report of Well Operations 1m Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory 0 Development 1m Service 16. Well Status after proposed work: 0 Oil 0 Gas 0 WAG 1m GINJ 0 WINJ 0 WDSPL 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: Contact David Reem, 564-5743 304-355 Printed Name Terrie Hubble Signature -rDJ\J\.U t\o J ~ Form 10-404 Revised 04/2004 Title Technical Assistant Phone 564-4628 Date '1 ;¡tj"Dl.( Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only ) Page 1 of 9 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-11 NG 1-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES I Date From - To Hours I Task Code NPT Phase 10/22/2004 23:00 - 00:00 1.00 RIGD P PRE 10/23/2004 00:00 - 02:00 2.00 RIGD P PRE 02:00 - 12:30 10.50 MOB P PRE 12:30 - 15:00 2.50 MOB P PRE 15:00 - 21 :00 6.00 RIGU P PRE 21 :00 - 23:00 2.00 KILL P DECOMP 23:00 - 00:00 1.00 KILL P DECOMP 10/24/2004 00:00 - 01 :00 1.00 RIGU P DECOMP 01 :00 - 06:00 5.00 KILL P DECOMP 06:00 - 08:30 2.50 KILL P DECOMP 08:30 - 10:30 2.00 KILL P DECOMP 10:30 - 15:00 4.50 KILL P DECOMP 15:00 - 16:00 1.00 WHSUR P DECOMP 16:00 - 19:00 3.00 WHSUR P DECOMP 19:00 - 23:00 4.00 BOPSUP P DECOMP 23:00 - 00:00 1.00 BOPSUR P DECOMP 10/25/2004 00:00 - 02:00 2.00 BOPSUF P DECOMP 02:00 - 03:00 1.00 BOPSUR P DECOMP 03:00 - 04:30 1.50 PULL P DECOMP 04:30 - 05:30 1.00 PULL P DECOMP 05:30 - 10:00 4.50 PULL P DECOMP 10:00 - 18:00 8.00 PULL P DECOMP Start: 10/22/2004 Rig Release: 11/9/2004 Rig Number: Spud Date: 1/30/1978 End: Description of Operations Rig down components to prepare for rig move to NGI-11. Continue to RID rig components. Move rig components from H-15 to NGI-11. PJSM. Spot sub, pipe shed & mud pits. Raise & scope derrick. Reposition rig: Scope down & layover derrick, move modules & raise & scope up derrick. Rig accepted @ 21 :00 hours, 10/23/2004. Rig up lines to wellhead & test. Rig up lines to tiger tank. PJSM. Slip & cut sandline. Finish Slip and Cut sand line. P/U lubricator, pull BPV. Note pressures: TP 690, CP 100, OA 200 psi. Bleed down well and commence circulating hot seawater @ 3 BPM, 150 psi. Returns started wi diesel, changed to seawater with entrained gas. 73 Bbls were recovered in the Tiger Tank during bleed down. Continue circulating surface to surface wI heated seawater at 2 - 4 BPM, 100-130 psi. PJSM. Continue circulating, bring rate up to 4 1/2 bpm 1500 psi. Clean seawater back after pumping total of 650 bbls. Monitor well, II A slightly gassy, tubing @ 50 psi. Rig up O/A to tiger tank & bleed pressure to 0 psi. PJSM. Bring on pump & pump 150 bbls down tubing @ 6 bpm 1750 psi. Tubing still not bleeding down. Resume pumping @ 6 bpm 1750 psi, taking returns thru gas buster to pits. Pump total of 1075 bbls. Gas successfully evacuated from 7" tubing. Monitor well, well is dead, O/A @ 0 psi. PJSM. Pick up lubricator. Set test plug I bpv. UD lubricator. PJSM. NID existing wellhead. PJSM. N/U BOPE and lines. PJSM. Perform complete BOPE test, 250 psi low, 4000 psi high; 3500 psi for annular preventor. Witnessing of test waived by AOGCC rep Chuck Sheve. Continue full BOPE pressure test. P/U lubricator and pull BPV/test plug. R/U 7" handling equipment. P/U and M/U BHA #1: packoff bull nose, 7" packoff, 2 x 7" Itco Casing Spears, Spear Extension, and Stop Sub. Stab into 7" hanger, BOLDS, pull to 215K to break hanger free. Work pipe up to 225K several times, then up to 230K a couple times, and to 240K when 7" string came free. Slowly work hanger to floor; hanging wt 225K. Remove BHA #1 from hanger and breakout and UD same. Breakout and UD hanger. RlU SWS control line spooling unit. POH and UD 7",26#, L-80 tubing. Spool up control line. 59 control line clamps recovered, 1 missing. Rig down spooling unit. Continue to POOH & UD 7" 26# 1-80 NSCC tbg. Recovered 224 jts 7",26#, L-80 tubing and 20.33' of 5-1/2", 17#, l-80 tbg, 59 S8 bands, one lost downhole, and all the SSSV control line. 18:00 - 21 :00 3.00 PULL P DECOMP Changeout 7" rams to 3-1/2" x 6" variable rams and test to 250/4000 psi. Pull test plug, install wear bushing. RID SWS control line spooler. Printed: 11/15/2004 9:53:02 AM ) ) BP EXPLORATION OperationsS Llmm~~Y:I1J~RØr~ Page 2 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-11 NGI-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: Phase I 10/22/2004 11/9/2004 Spud Date: 1/30/1978 End: Date From - To Hours Task I Code NPT Description of Operations 10/25/2004 21 :00 - 23:00 2.00 CLEAN P DECOMP M/U BHA #2: 8-1/2. x 5-3/4" Shoe, Washpipe ext wi 4-7/8" pilot mill inside, 9-5/8. Csg Scrpr, 2 x 7" Boot Baskets, Lubed Bumper Sub, Oil Jars, and 9 x 6-1/4" DCs. 23:00 - 00:00 1.00 CLEAN P DECOMP Begin RIH wi BHA #2 to cleanout to 5-1/2" stump @ 8903' (+1-). 1 0126/2004 00:00 - 07:00 7.00 CLEAN P DECOMP Continue RIH wI BHA #2 to cleanout to 8903'. 07:00 - 08:00 1.00 CLEAN P DECOMP PJSM. Kelly up wi 270 jts in hole. Up wt = 148K, dwon wt = 100K, rotating wt = 120K. 6000 - 7000 ft/lbs rotating torque off bottom. Tag top of tubing stub wi shoe 26' in on kelly @ 8903' dpm. Washl mill down to 8912' wI shoe, (swallowed 8-9'). Saw 50 psi pressure increase pumping @ 6 bpm @ 1550 psi when all the way down. 08:00 - 10:00 2.00 CLEAN P DECOMP PJSM. Circulate Hi Vis sweep around @ 6 bpm I 1550 psi. Bleed O/A from 110 psi down to 0 psi, all gas. 10:00 - 12:00 2.00 CLEAN P DECOMP PJSM. Stand back kelly, monitor well. LID 3 singles, POOH wi cleanout BHA, & SIB 3-1/2. DP. 12:00 - 12:30 0.50 CLEAN P DECOMP Found spot @ 5383' RKB when POH. WorkBHA up and down through tite spot several times. Gain 15K down wt and 35K up wt while working through the spot. No change in up/down wts while doing so. 12:30 - 14:30 2.00 CLEAN P DECOMP POH and SIB DP and DCs. 14:30 - 16:00 1.50 CLEAN P DECOMP B/O and LID BHA #2, clean boot baskets, clear and clean rig floor. 16:00 - 18:00 2.00 CLEAN P DECOMP Rig maintenance and await SWS crew for USIT log. 18:00 - 19:30 1.50 EVAL P DECOMP PJSM. R/U SWS E-Line equipment and USIT logging tool wi max 7.5. diameter on tool assembly. 19:30 - 21 :30 2.00 EV AL P DECOMP RIH to 7500' wi USIT to tie-in wI GR, CCL and correlate for 9-5/8. collars. 21 :30 - 22:00 0.50 EVAL P DECOMP POH and log starting @ 5500', find tite spots @ 5352' (-8.44" diam) and 5360' (-8.34. diam), ELM. 22:00 - 00:00 2.00 EVAL P DECOMP POH and start logging again @ 3500' for top of cement. Determine TOC to be 2440', ELM. 10/27/2004 00:00 - 01 :30 1.50 EVAL P DECOMP POH SWS USIT assy. RID E-Line equipment. Clear rig floor. 01 :30 - 02:30 1.00 T A P DECOMP M/U Halliburton 9-5/8.RBP on 6-1/4. DCs. 02:30 - 07:30 5.00 TA P DECOMP RIH RBP on 89 stds of 3-1/2. DP from derrick. Slow down @ std #53 to look for tite spot. Saw possible minor bobble of 1-2K in the area of the tite spots. Continue on to 8,849'. PUW = 145K. SOW = 93K. 07:30 - 08:30 1.00 TA P DECOMP Set Reterivable Bridge Plug (lower) at 8,849'. Test at 3,000 psi for 5 mins. Good. Note: No sand dumped. 08:30 - 12:00 3.50 T A P DECOMP TOOH with 31/2. Drill Pipe and Running Tool. 12:00 - 14:00 2.00 TA P DECOMP Pick-up RBP #2 and TIH to 3,498'. PUW = 69K. SOW = 62K. 14:00 - 15:00 1.00 TA P DECOMP Set Retrievable Bridge Plug (upper) at 3,498'. Stand back 1 stand of Drill Pipe. Dump 24 sks of 20/40 Sand down Drill Pipe. WO sand to fall to RBP. Pressure test 9-5/8. to 4000 psi. Hold for 15 minutes--good test. 15:00 - 17:00 2.00 T A P DECOMP Swap Well over to 9.8 Iblgal Brine. 17:00 - 19:00 2.00 T A DECOMP TOH with 3 1/2" Drill Pipe and Drill Collars. 19:00 - 20:30 1.50 TA P DECOMP M/U BHA #3: 8-114" Multi-String cutter, XO, Stabilizer, XO, 9 x 6-1/4" DCs. 20:30 - 21 :00 0.50 T A P DECOMP RIH wI BHA #3. Hit down hard, -1285'. P/U slowly and drop back down slowly. Ran full stand in without seeing any obstruction. Decided to POH to examine knives. Printed: 11/15/2004 9:53:02 AM ) ) BP EXPLORATION Operations Summary~.epò(t Páge 30f9 Legal Well Name: NGI-11 Common Well Name: NGI-11 Event Name: WORKOVER Start: 10/22/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/9/2004 Rig Name: NABORS 4ES Rig Number: Date I From - To Hours Task Code NPT Phase 10/27/2004 21 :00 - 22:00 P DECOMP 1.00 T A 22:00 - 00:00 2.00 TA DECOMP P 10/28/2004 00:00 - 01 :00 1.00 PULL P DECOMP 01 :00 - 03:00 2.00 PULL P DECOMP 03:00 - 05:00 2.00 PULL P DECOMP 05:00 - 06:00 1.00 CLEAN P DECOMP 06:00 - 07:00 1.00 CLEAN N SFAL DECOMP 07:00 - 10:30 3.50 CLEAN P DECOMP 10:30 - 12:00 1.50 CLEAN P DECOMP 12:00 - 13:00 1.00 WHSUR P DECOMP 13:00 - 13:30 0.50 CASE P DECOMP 13:30 - 14:30 1.00 CASE P DECOMP 14:30 - 15:00 0.50 CASE P DECOMP 15:00 - 15:30 0.50 CASE P DECOMP 15:30 - 00:00 8.50 CASE P DECOMP 1 0/29/2004 00:00 - 01 :30 1.50 CASE P DECOMP 01 :30 - 03:00 1.50 CASE P DECOMP 03:00 - 04:30 1.50 CASE P DECOMP 04:30 - 08:00 3.50 CASE P DECOMP 08:00 - 10:00 2.00 CASE P DECOMP Spud Date: 1/30/1978 End: Description of Operations POH wI BHA #3 to examine cutter blades. Blades Okay, but tape holding blades in place had allowed one blade to protrude enough to catch pin end of a joint. One blade had some minor damage. Changed out all blades. RIH wi BHA #3 to place cut in middle of full joint above target depth of 2390'. Find Collars @ 2290' and 2331'. Place cutter @2350' and cut @ 80 RPM, 3-4 BPM, 900 psi. Cut through in 15 minutes, but continue for 30 minutes longer. Stop pumping, P/U, and drop back down slowly to verify cut. Good indication of successful cut. POH wI BHA #3, SIB DP, DCs, UD Multi-string cutter. Found handfull of long metal cuttings stuck around one of the cutters. M/U Muleshoe on DC and RIH on DCs and DP to circulate out Arctic Pack. Park @ 2340'. Pressure test lines to 2000 psi. Begin circulation and build to 2000#, pressure held. Bleed off and pressure test lines to 4000#. Resume pumping hot diesel pressuring from 2000# on up in 200# increments. At 2,800 psi Atctic Pack started moving...however a leak developed in a Hammer Union connection on the line going to the Tiger Tank. Shut down to clean-up and report Spill. Clean-up and report Spill. >10 gals of Arctic Pack contaminated melted snow. Continue with ArcticPack Clean-out. Total Fluids pumped: 50 bbls hot diesel, -140 bbls hot 9.8 Brine, 50 bbls hot Diesel, -140 bbls hot 9.8 Brine, 50 bbls hot 9.8 Brine/10% Safe-Surf 0, -170 bbls hot 9.8 Brine. Initial Circulating pressure = 2 bpm/2000 psi. Final 6 bpm/800 psi. Final returns -clean. TOH with 31/2" Drill Pipe and Drill Collars. Lay down Mule Shoe. Pick-up Pulling Tool. BOLDS. Attempted to pull 9 5/8" Pack-oft. No joy. Make-up BHA #4: 9 5/8" Spear. Rig up to pull and handle 9 5/8" Casing. Plant Spear. Pull 9 5/8" Hanger free at 135K. Casing dragging at 155K however Casing is free from cut. Hanger at Floor with normal weight at 118K. Lay down Spear assembly. Lay down Hanger. POOH and single down 9 5/8" Casing (wipe oft remaining arctic Pack from Casing). POOH and single down 95/8" Casing (wipe oft remaining arctic Pack from Casing). UD cut jt. Clear and clean rig floor. Recovered 60 Jts + 18.92' Stub. Discuss wI engineer the presence of 2 consecutive centralizers immediately above the cut jt. Decide to RBIH wI 12-1/4" washover shoe and washpipe to push a possible centralizer below the collar on bottom of cut jt. Wait on tools from Baker Fishing Tool. M/U BHA: 12-1/4 x 11-3/4 x 10-314 Mill Shoe, 2 jts 11-3/4 wash pipe, Bumper sub, Oil Jar, DCs. RIH wi BHA . Stop wi first stand of DCs due to flow of Arctic Pack forced up 3-112" DP from 11-3/4/1 washpipe. Clear and Printed: 11/15/2004 9:53:02 AM ) ') BP EXPLORATION Qp~rØ~ions Summary Report Legal Well Name: NGI-11 Common Well Name: NGI-11 Spud Date: 1/30/1978 Event Name: WORKOVER Start: 1 0/22/2004 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/9/2004 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT I Phase Description of Operations 10/29/2004 08:00 - 10:00 2.00 CASE P DECOMP clean rig floor. POH and UD BHA. 10:00 - 12:30 2.50 CASE P DECOMP M/U BHA #5: 12-1/4.. bit and 13-3/8. scraper. RIH to +1- 2350', P/U and prepare to circ out Arctic Pack. 12:30 - 16:00 3.50 CASE P DECOMP Circulate Arctic Pack to pits--Messy. 16:00 - 18:00 2.00 CASE P DECOMP POH 7 stands and circulate. More mess to pits. 18:00 - 23:00 5.00 CASE P DECOMP POH 7 stands and circulate. POH another 7 stands and circulate. Begin mud pit cleaning operations. 23:00 - 00:00 1.00 CASE P DECOMP POH and UD BHA #6. Clear and clean rig floor. All 3 truck loads of Arctic Pack sent to MI @ Deadhorse to be further cut wi hot water to enable disposing through Pad 3 facilities. 1 0/30/2004 00:00 - 01 :30 1.50 CASE P DECaMP Continue to clean rig floor of Arctic Pack. Wait on float to install in bit sub in BHA #6 to prevent flow back of well bore fluids while RIH wi 11-3/4. Mill Shoe and Wash Pipe 01 :30 - 03:00 1.50 CASE P DECOMP M/U BHA #6: 12-1/4. Mill Shoe, 2 jts 11-3/4. Washpipe, 11-3/4. Washover Boot Basket, XO, Float Sub, XO, Lubricated Bumper Sub, Oil Jar, XO, Bit Sub wi float, 9 x 6-1/4. DCs. 03:00 - 04:00 1.00 CASE P DECOMP RIH wI BHA #6 to W/O 9-5/8. stub @ 2350'. 04:00 - 13:00 9.00 CASE P DECOMP Wash down over 9-5/8. stub. Washed from 2355' to 2368'. Rate 3-5 BPM @ 450 to 600 psi. 13:00 - 14:00 1.00 CASE P DECOMP Pump Hi-Vis sweep 5 BPM, 600 psi. 14:00 - 17:00 3.00 CASE P DECOMP Continue to W/O 9-5/8. from 2368' to 2386', -36' deeper than top of stub. 17:00 - 19:00 2.00 CASE P DECOMP POH, SIB DP. 19:00 - 21 :30 2.50 CASE P DECOMP Breakout and UD BHA #6. Cutters on 12-1/4. Mill Shoe looked to be in good shape. Clear and clean drill floor. 21 :30 - 00:00 2.50 CASE P DECOMP M/U BHA #7: Bit Sub (as pilot), 9 x 6-1/4. DCs, Lower Anchor Sect of Backoff Tool, Power Sect (B/O Tool), Upper Anchor Sect (B/O Tool), XOs, and Pump Out Sub. 10/31/2004 00:00 - 01 :30 1.50 CASE P DECOMP RIH BHA #7 to backoff the 9-5/8. stub @ 2350'. Fill each stand with diesel for power fluid to function Casing Backoff Tool. 01 :30 - 04:00 2.50 CASE P DECOMP Work BHA into stub and position anchors, connect lines from rig pump. Build pressure to tool activation pres of 5000 psi, 4 times, but no joy. Pulled tool up to position top anchor above top of stub. Pressure up to 5000 psi. Tool did not function. Prepare to POH. (Note: add one more hour for change from Daylight Savings Time.) 04:00 - 06:00 2.00 CASE P DECOMP Drop bar to open pump-out sub and circulate out diesel power fluid from Drill Pipe and BHA #7. 06:00 - 06:30 0.50 CASE P DECOMP Lube Rig. 06:30 - 07:30 1.00 CASE P DECOMP TOH with Drill Pipe and Back-Off Assembly. 07:30 - 08:00 0.50 CASE P DECOMP Lay down BHA #7. 08:00 - 09:30 1.50 CASE P DECOMP Rig up SWS. PJSM with All. 09:30 - 12:30 3.00 CASE P DECOMP RIH with String Shot (12-ft x 3 Strands) Position SS (2,336'- 2,348') across 9 5/8. Connection to be "backed off" at 2,342' elmd. Fire SS. Good. POOH. RD. 12:30 - 13:30 1.00 CASE P DECOMP Pick-up and test Back-Off Tool that was pulled from initial run. Tool functioned perfectly, but needed to re-pin Anchors. 13:30 - 15:00 1.50 CASE P DECOMP M/U BHA #8 (same as #7) for 2nd trip and RIH to backoff 9-5/8. stub @ 2350', 4ES RKB. 15:00 - 17:30 2.50 CASE P DECOMP RIH and fill wI diesel every 5 stands. P/U pup jt and spot Backoff Tool assy inside 9-5/8. stub. 17:30 - 19:30 2.00 CASE P DECOMP Pressure up to set bottom anchor @ -2000 psi. Continue to bulid pressure to 5000 psi to set top anchor. See pipe turn -5/8 Printed: 11/15/2004 9:53:02 AM ) ) BPEXPLORATION O.p~r~~.,øn~$Llrnl11ary . Report Pélge 5 of. 9 Legal Well Name: NG 1-11 Common Well Name: NGI-11 Spud Date: 1/30/1978 Event Name: WORKOVER Start: 1 0/22/2004 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/9/2004 Rig Name: NABORS 4ES Rig Number: From - To Hours Task Code NPT Phase Description of Operations 10/31/2004 17:30 - 19:30 2.00 CASE P DECOMP turn. Bleed off pressure, wait 5 mins, build to 5K and tool turns 5/8 turn starting @ 2100 psi. Continue bleed and build until 6 full turns have been achieved at the surface. 19:30 - 21 :00 1.50 CASE P DECOMP P/U and R/U to circ out diesel. Circ out diesel to surface, 3 BPM @ 150 psi. 21 :00 - 22:00 1.00 CASE P DECOMP POH, SIB DP. 22:00 - 23:00 1.00 CASE P DECOMP Breakout and LID BHA #8 (same as #7), 2nd run. 23:00 - 00:00 1.00 CASE P DECOMP M/U BHA #9: 9-5/8" SpearPackoff Assy, 9-5/8" Itco Csg Spr wI 8.681 Gage Ring, Ext Sub, Stop Sub, Bumper Sub, XO, 9 x 6-1/4" DCs. 11/1/2004 00:00 - 01 :00 1.00 CASE P DECOMP RIH wI BHA #9 to tag @ 2350', enter into 9 5/8" Stump, and set up for backoff. 01 :00 - 02:00 1.00 CASE P DECOMP Set Spear and backout pipe 9 full turns at the floor. No reverse torque after last turn. 02:00 - 03:00 1.00 CASE P DECOMP POH, SIB DP. 03:00 - 04:00 1.00 CASE P DECOMP SIB DCs from BHA, breakout and UD remainder of BHA #9. Recovered 3.30' cut jt, 3.85' DV Collar, and 19.80' of 9-5/8" pipe to the pin end. A collar is looking up, and threads on the recovered pin look very good. 04:00 - 06:00 2.00 BOPSUP P DECOMP Service rig and start AOGCC weekly BOPE test. 06:00 - 09:30 3.50 BOPSUR P DECOMP Perform Weekly BOPE Test per BP/AOGCC requirements at 250/3,500 psi. State's right to witness Test waived by J. Chrisp. Note Upper Kelly Valve failed the high pressure test...call for replacement Valve. Will replace Valve during next TIH so Kelly can be picked up. Rig down Test Equipment. Pull Test Plug. Blow down Lines. 09:30 - 10:30 1.00 CASE P DECOMP Rig up Floor to handle next BHA. 10:30 - 13:30 3.00 CASE P DECOMP Make-up BHA #10 as Follows: 12 1/2" Shoe, 11 3/4" WP Ext, TC Boot Basket, XO, Casing Scraper, Bit Sub, Bumper Jar, Oil Jar, XO, 9 ea 61/4" Drill Collars, XO. Note inside of WP Ext...Made up to the TC Boot Basket as follows: 8 1/2" Junk Mill, XO, XO. 13:30 - 14:30 1.00 CASE P DECOMP Start TIH with BHA #10 and 3 1/2" Drill Pipe. Running in slow due to the "funnel effect" of the Washpipe forcing the Drill Pipe to overflow. 14:30 - 16:00 1.50 CASE P DECOMP Stop to pick-up Kelly to replace Upper Kelly Valve that did not pass during BOPE Test. Tested Valve at 250/3,500 psi. Good. 16:00 - 17:30 1.50 CASE P DECOMP TIH, tag stump @ 2377'. 17:30 - 18:00 0.50 CASE P DECOMP Rotate down over stump, pump @ 3 BPM, 200 psi and work down to 2390'. 18:00 - 19:30 1.50 CASE P DECOMP P/U and circulate well until clean returns over shaker screens. Some Arctic Pack came back during CBU. 19:30 - 22:00 2.50 CASE P DECOMP POH, SB DP and DCs. Breakout and UD remainder of BHA #10. 22:00 - 00:00 2.00 CASE P DECOMP Clear and clean rig floor. R/U to run 9-5/8", 47# casing. 11/2/2004 00:00 - 02:00 2.00 CASE P DECOMP Continue to R/U 9-5/8" running equipment. Hold PJSM to cover handling, stabbing, torquing, and landing 9-5/8" casing. M/U Guide Shoe and cementing assy: Baker Guide Shoe, Baker Triple Connection, 21.02' long 9-5/8", 47# Shoe Track Pup, 9-5/8" Halco ES Cementer. All connections made-up wI Bakerlok, except the stabbing pin-end inside the Guide shoe. 02:00 - 06:00 4.00 CASE P DECOMP RIH the 9-5/8" cementing assy on 9-5/8", 47# casing from Pipe Printed: 11/15/2004 9:53:02 AM ) ) Page 6 of9 BP, EXPLORATION QØ~,r,@ti~tlS',Summary' Report Legal Well Name: NGI-11 Common Well Name: NGI-11 Event Name: WORKOVER Start: 10/22/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/9/2004 Rig Name: NABORS 4ES Rig Number: Date I From - To ! Hours Task Code NPT Phase 11/2/2004 02:00 - 06:00 4.00 CASE P DECOMP 06:00 - 08:30 2.50 CASE P DECOMP 08:30 - 09:00 0.50 CASE P DECOMP 09:00 - 10:00 1.00 CASE P DECOMP 10:00 - 12:00 2.00 CASE P DECOMP 12:00- 14:30 2.50 REMCM-P DECOMP 14:30 - 00:00 9.50 REMCM-P DECOMP 11/3/2004 00:00 - 06:00 6.00 REMCM-P DECOMP 06:00 - 08:30 2.50 REMCM-P DECOMP 08:30 - 09:30 1.00 BOPSUR P DECOMP 09:30 - 12:30 3.00 WHSUR P DECOMP Spud Date: 1/30/1978 End: Description of Operations Shed. All connections torqued to 10K ft Ibs. Average turn to make-up Casing = 9 rounds. Install Turbulators on Joints per Program Finished running 9 5/8" Casing in the following order (Bottom to Top) ...28 Jt 95/8" 471b/ft L-80 BTC, 5 Jts 9 5/8" 471b/ft L-80 BTC-M, 1 Jt 9 5/8" 47 Ib/ft L-80 BTC-M Pin x NSCC Box XO, 23 Jts 9 5/8" 471b/ft NT95HS NSCC. Lightly tag 9 5/8" Casing looking uo at 2,277'. Guide Shoe fell over Casing with no problems. Swallow down to 9 5/8" make-up pin inside Guide Shoe. Screw into Collar and work torque. Got a total of 12 turn down hole. Worked torque several times. Final stall torque = 10K. Attempted to pressure Casing to 2,500 psi. However while walking pressure up the ES Cementer sheared open early at 2,000 psi. It was pinned with 5 pins rated to shear at 2,750 psi (?). No charted test however pressure climbed steady and broke back to 0 psi. Rig down Casing handling equipment and clear Floor. Circulate Well while waiting for Cementers and support Vac Trucks. MIRU SWS Cement Equipment and support Equipment. Spot Vac Trucks. Lay Lines. PJSM with All. Dowell and Nabors Spill Champions do final Walk-Thru. Prime up and Pressure Test Lines with Sea Water at 650/4,500 psi. Good. Displace Line x 3 with Diesel (9 bbls). Observed clean diesel to Pit 1. Line up to pump Diesel down hole. Start Diesel at 5 bpm/225 psi. End Diesel with 57 bbls away. Shut in Well. Batch up first tub of Cement at 13:25 hrs (Start WOC). Open Well. Start Cement at 4.0 bpm/600 psi, 15.8lb/gal density. 50 bbls away at 5.8 bbls/725 psi, 15.7 Ib/gal density. 75 bbls away at 5.0 bpm/575 psi, 15.72 density. End Cement at 114 bbls pumped. Final rate 5.0 bpm/600 psi. Shut down. Drop Wiper Plug. Start Sea Water displacement at 5 bpm/250 psi. Wiper Plug away. 60 bbls away at 6.0 bpm/320 psi. 100 bbls away at 6.0 bpm/310 psi. 120 bbls awat at 6.0 bpm/425 psi. 140 away at 6.0 bpm/620 psi. Observe Diesel to Pit! 160 bbls away at 4.0 bpm/700 psi. Clean Diesel returns. 168 bbls away slow rate to 2.0 bpm/680 psi. Start looking for Plug bump. 172.2 bbls total displacement pumped shut down did not see any sign that plug bumped. Shut in Well. Calculated displacement to bump Plug = 172.2 bbls. Micro Motion Meter at shut down = 172.2 bbls. Close in Well. WOC. Plug did not bump...ES Cementer is not closed. Wait On Cement. Clean, Service & paint Rig. Load & tally 7 5/8" casing. Con't to Wait on Cement. Con't to clean paint & service rig. Con't to load & tally 7 5/8" casing. Continue to maintain Rig while WOC. Discuss Lab results with Anch Eng. Pick-up on Casing at 185K. Split BOPE Stack and lift off of Wellhead. Drop Emergency Slips. RU Wachs Cutter and cut 9 5/8" Csg. Lay down Cut-Off Jt = 27.33'. Set back BOP stack. Printed: 11/15/2004 9:53:02 AM ) ) BP .EXPLORATION Qperati()ns.§:p~l'1lary..Report From - To NGI-11 NGI-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Hours I Task Code NPT I Phase Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/3/2004 11/4/2004 12:30 - 19:00 6.50 WHSUR P DECOMP 19:00 - 21 :00 21 :00 - 22:00 2.00 BOPSURP 1.00 BOPSUR P DECOMP DECOMP 22:00 - 23:00 23:00 - 00:00 1.00 BOPSUR P 1.00 CLEAN P DECOMP DECOMP 00:00 - 01 :00 01 :00 ~ 03:30 1.00 CLEAN P 2.50 CLEAN P DECOMP DECOMP 03:30 - 04:30 1.00 CLEAN P DECOMP 04:30 - 05:30 1.00 CLEAN P DECOMP 05:30 - 06:00 0.50 CLEAN P DECOMP 06:00 - 06:30 0.50 CLEAN P DECOMP 06:30 - 07:30 1.00 CLEAN P DECOMP 07:30 - 09:30 2.00 CLEAN P DECOMP 09:30 - 11 :00 1 .50 CLEAN P DECOMP 11 :00 - 12:00 1.00 CLEAN P DECOMP 12:00 - 13:00 1.00 CLEAN P DECOMP 13:00 - 21 :00 8.00 TA P DECOMP 21 :00 - 22:30 1.50 TA N DPRB DECOMP 22:30 - 23:30 1.00 T A N DPRB DECOMP 23:30 - 00:00 0.50 T A N DPRB DECOMP 11/5/2004 00:00 - 01 :30 1.50 TA N DPRB DECOMP 01 :30 - 02:00 0.50 T A N DPRB DECOMP 02:00 - 03:30 1.50 TA P DECOMP 03:30 - 04:30 1.00 TA P DECOMP 04:30 - 06:30 2.00 TA P DECOMP 06:30 - 07:30 1.00 TA P DECOMP 07:30 - 08:30 1.00 T A P DECOMP 08:30 - 10:00 1 .50 T A P DECOMP 10:00 - 14:30 4.50 T A N DPRB DECOMP 14:30 - 15:00 0.50 T A N DPRB DECOMP Start: 10/22/2004 Rig Release: 11/9/2004 Rig Number: Spud Date: 1/30/1978 End: Description of Operations Dress 9 5/8" Casing stub. Install Pack-Off Assembly. Redress 10 of tubing spool for seal assy. M/U tubing spool. Test to 3850 psi, OK. N/U BOPE. Set test Plug. pressure up & perform BOP body test. to 4000 psi, OK. UD test plug. Blow down lines. Install Waer bushing. M/U BHA #11 as follows: Bit, Csg scraper, Bit Sub, Bumper Sub, Oil Jars, X-O, 9 * 6 1/4" DCs, x-a. TL = 305.02'. Finish M/U BHA #11. RIH wi 31/2" DP to 2302'. P/U kelly & break circulation. RIH & tag up on cement @ 2309.50'. Drill cement from 2309.50 to 2351'. Drill ES Cementer from 2351 to 2354'. P/U 56K, S/O 56K, Rot 56K, 3.8 BPM @ 250 psi. 80 RPMs, Torq = 2-3K. WOB 5-10K. Circulate bottoms up. Circ well clean. R/U & pressure test casing to 4000 psi. Good Test. Lost 100 psi in 38 min. Blow down lines & set back kelly. Lub Rig. Continue TIH with 31/2" Drill Pipe. Tag again at 3,449' Pick-up Kelly. Wash and rotate at 3 bpm/300 psi. from 3,449' . 3,490' (top of Upper RBP at 3,498'). Circulate Well until clean at 6.5 bpm/800 psi. Recovered rubber chunks from Wiper Plug, Cement cuttings, and 20140 mesh Sand. Swapped Well over to clean Sea Water. POOH with 31/2" Drill Pipe. Lay down Bit and Scraper. Pick-up Halco Retreiving Tool. TIH to TOS at 3,490'. Wash and work down to upper RBP at 3,498'. Latch RBP. Work to release. Tool would not release. dis-engauge from tool. P/u & revrese circulate back down onto tool. attempt to release tool, would not come free. Pulled up 130K (60k overpull). Blow down lines. POOH wi drill string. UD retreiving tool. Clear & clean rig floor. Load & tally fishing tools. M/U BHA # 12 as follows: Overshot wi 3 3/8" grapple, Bumper Sub, Oil Jars, X-O, 9 * 6 1/4" DCs, XO. TL = 301.67'. Finish M/U BHA #12 & RIH on 31/2" DP to 3498'. P/U kelly. Break circulation. 3 BPM @ 200 psi. Engauge overshot onto RBP. P/U wI RH torq & Jar. RBP came free on 2nd lick w/100K (30K Over). P/U 70K, S/O 64K. Blow down lines. Set back kelly & prep to POOH. POOH wi RBP. UD Overshot & recover RBP. Retainiong ring & spring assy damaged. Clear & clean rig floor. M/U Retreiving tool & RIH to recover lower RBP @ 8849'. Stop to Cut and Slip Drilling Line. Resume operations. Continue to TIH to lower RBP at 8,849'. Circulate and latch RBP. Work to free. RBP free. Able to go down hole past setting depth. TOH with 31/2" Drill Pipe and RBP. RBP dragging at times. Finished TOH...however, no RBP. Discuss next Trip with Anch Eng. Inspect running tool & equipment. Printed: 11/15/2004 9:53:02 AM ) ) Page 8 of 9 BP EXPLORATION, Operations ..Summ;;lrY~.~R()rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/5/2004 11/6/2004 11/7/2004 11/8/2004 NGI-11 NGI-11 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES I I Hours Task Code NPT Phase Date From - To 15:00 - 18:30 18:30 - 19:00 3.50 TA N DPRB DECOMP 0.50 TA N DPRB DECOMP 5.00 T A N DPRB DECOMP 1.00 T A N DPRB DECOMP 3.00 TA N DPRB DECOMP 1.00 T A N DPRB DECOMP 19:00 - 00:00 00:00 - 01 :00 01 :00 - 04:00 04:00 - 05:00 05:00 - 08:30 3.50 T A N DPRB DECOMP 08:30 - 09:30 1.00 TA P DECOMP 09:30 - 10:30 1.00 CASE P DECOMP 10:30 - 12:30 2.00 CASE P DECOMP 12:30 - 14:00 14:00 - 15:00 15:00 - 17:30 1.50 CASE P 1.00 CASE P 2.50 CLEAN P DECOMP DECOMP DECOMP 17:30 - 20:00 20:00 - 22:30 2.50 CLEAN P 2.50 CLEAN P DECOMP DECOMP 22:30 - 00:00 1.50 CLEAN P DECOMP 00:00 - 01 :30 1.50 CLEAN P DECOMP 01 :30 - 08:00 6.50 CLEAN P DECOMP 08:00 - 11 :00 3.00 CLEAN P DECOMP 11 :00 - 13:00 2.00 BOPSUR P RUNCMP 13:00 - 14:00 1.00 RUNCOI\tP RUNCMP 14:00 - 15:30 1.50 RUNCOI\tP RUNCMP 15:30 - 00:00 8.50 RUNCOMP RUNCMP 00:00 - 06:00 6.00 RUNCOI\tP RUNCMP 06:00 - 09:00 3.00 RUNCOMP RUNCMP 09:00 - 10:00 1.00 RUNCOI\tP RUNCMP Start: 1 0/22/2004 Rig Release: 11/9/2004 Rig Number: Spud Date: 1/30/1978 End: Description of Operations RIH wi running tool to recover RBP. Push RBP to 8897'. Work over & latch up on RBP. P/U wl5K over. POOH wi 31/2" DP. Ud retreiving tool....NO RBP. Clear & clean rig floor. M/U Overshot assy. RIH wi Overshot on 31/2" DP. P/u kelly & break circulation. 3 BPM 500 psi. Work down over fish to 8896'. Engauge fish & slO w/5K. P/U had 2-6K overpull. Fish engauged in overshot. P/u & retag to insure good grab. Blow down lines & set back kelly. POOH wI Overshot & 31/2" DP. Recovered lower RBP fish. A large chunk of alloy from the Wiper Plug rode out on top of the RBP. Several smaller pieces were jammed in and behind the slips. Make up BHA # 14 as follows: 81/2" casing Swage, Bumper Sub, Oil Jar, XO, Drill collars, XO. TIH with BHA and 31/2" Drill Pipe. Pass through tight spot encountered earlier in the workover at 5,385' 4es kb. ( Note: Tight Sopt also showed up on the USIT Log) with no problem. Short Trip Swage 3 times across from 5,437' - 5,341' with no problems. TOH with 31/2" Drill Pipe and BHA. Lay down BHA. Clear and Clean Floor. Make-up BHA #15 as follows: 41/2" x 35/8" MiIIlRev Junk Basket Combo, Bit sub, 3 Jts PAC DP, XO, XC, Casing Scraper, Boot Basket, Bumper Sub, Oil Jar, XC, 9 Drill Collars, XO, Pump-Out sub...MiII/JB Combo is pined inside an 8 3/8" x 81/8" Entery guide as follows: Bit Sub, Shear Bushing, OS Top Sub, OS Ent, OS Bowl, OS Guide. RIH wi BHA #15 on 31/2" DP to 8875'. P/U kelly, break circulation & single in. Tag up on tbg stump @ 8906'. Circulate & wash down in tbg. No fill. Wash down to hard tag on plug @ 8977'. P/U 149K, S/O 70K, Rot 123K. 4 BPM @ 850 psi. 60 RPMs. T orq 4-6K. Reverse circulate thru junk basket & Pump 20 Bbls Hi-Vis sweep. Finish reversing sweep around. 4 BPM @ 1800 psi. No losses. No Recovery other than sweep. POOH. Single down 31/2" Drill Pipe. Lay down 6 114" Drill Collars and BHA # 15. Pull Wear Ring. Set Test Plug. Clear and Clean Floor. Change Pipe Rams fro 31/2" x 6" VB to 7 5/8" Pipe rams. Test Pipe RamslDoor Seal at 25014000 psi. Pull Test Plug. Rig up 7 5/8" handling equipment. Rig up Torque Turn equipment. Perform final inspection of Completion Jewelry. PJSM with All. MIU & RIH wI Completion Tailpipe Assy. Baker-Loc all connections below Packer. P/U & RIH wi 75/8" completion string. Torq turn all connections to 14450ft-lbs. RIH wi total of 100 jts. Con't to P/U & RIH wi 75/8" completion string. Torq turn all connections to 14450 ft-Ibs. Continue running 7 5/8" completion Tbg. Pick-up Jt # 211 (Tag Jt). Bring Pump on line at 3 bpm/300 Printed: 11/15/2004 9:53:02 AM ) ) BP EXPLORATION Operations Su.mmilryRØp:ÇJ.tt Page 9 of 9 Legal Well Name: NGI-11 Common Well Name: NGI-11 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date I From - To Hours Task Code Start: Rig Release: Rig Number: N PT I Phase 1 0/22/2004 11/9/2004 Spud Date: 1/30/1978 End: Description of Operations 11/8/2004 09:00 - 10:00 1.00 RUNCOMP RUNCMP psi. Saw "bobble" as Unique OS started over 51/2" Tbg Stump. Pressure increased at 3 bpm/400 psi while UOS swallowed Stump. Swallowed Stump 8'. Stack 10K. Repeat with same results. Shut down Pump. Dry Tags with same results. Pull up to neutral String Weight +2 feet. 10:00 - 10:30 0.50 RUNCOMP RUNCMP Lay down Jt 211 and 210. Add Space Out Pup, Pick-up Jt 210, XO Pup, and Tbg Hanger. 10:30 -12:30 2.00 RUNCOMP RUNCMP Attempt to land Hanger, however the Hanger "hung-up" in Well Head. Pulled Hanger free ( required extra tugging). Re-dress Seals. Land Hanger. RILDS. Lay down Landing Jt. Completion landed as follows: Unique OS, X-Nipple w/RHC Plug installed, SAB-3 Packer, R-Nipple, 158 Jts 7 5/8" 29.71b/ft L-80 IPC VT HC Tbg, DB-6 Nipple, 51 Jts 7 5/8" 29.71b/ft L-80 IPC VT HC Tbg, Space-Out Pup, 1 Jt 7 5/8" 29.71b/ft L-80 IPC VT HC Tbg, XO Pups, Tubing Hanger. 12:30 - 13:30 1.00 RUNCOMP RUNCMP Pick-up Lubricator and install BPV/Dart. Test BPV/Dart. 13:30 - 14:00 0.50 RUNCOMP RUNCMP Rig down Casing Tongs. Clear Floor. 14:00 - 16:00 2.00 BOPSUR P RUNCMP Change out 7 5/8" Pipe Rams and install 2 7/8" x 5" VB Pipe Rams. 16:00 - 20:00 4.00 WHSUR P RUNCMP N/U adapter flange & X-mas tree. Test void & tree to 5K, OK. Pull BPV IDart. 20:00 - 00:00 4.00 WHSUR P RUNCMP R/U & test lines. Displace well bore fluids down annulus wi 350 Bbls of heated seawater. Pumped 3 BPM @ 800 psi. Mix 225 Bbls of inhibited seawater & pump down annulus. 3 BPM @ 800 psi. 11/9/2004 00:00 - 04:00 4.00 WHSUR P RUNCMP R/U lines to tree & test same. R/U Hotoilers & pump 145 Bbls of diesel down annulus. 3 BPM @ 800 psi. Allow diesel to U-tube & equalize. 04:00 - 08:30 4.50 RUNCOMP RUNCMP RID U-tube lines. Drop Ball/Rod & allow to fall to bottom. Pressure up on tubing to 4300 psi & set Packer. SI tubing & chart test for 30 min. bleed off tubing to 1500 psi & SI. Pressure up on annulus to 4000 psi & test for 30 min. Bleed oft tubing & annulus to 0 psi. Charted entire test. 08:30 - 09:30 1.00 WHSUR P RUNCMP Pick-up Lubricator. Install BPV. Lay down Lubricator. Blow down Lines. 09:30 - 10:00 0.50 WHSUR P RUNCMP Secure Cellar. Release Rig. Printed: 11/15/2004 9:53:02 AM ~ ,r )! : 8--1 :: :~, ~ ~ ~ I TREE =.. WELLHEAD = . "" ~".."..",,_. . ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max ~ngle = Oatum MD = -~, ..~- OatumlVD = _? GRAY .. AXÈlSÖN 44' 2950' 52 @ 7598' 10783' 8800' S5 -1 23731 1 9-5/8" CSG, 47#, L-80, 10 = 8.525" NOTE: SEE DRLG FILE FOR THREAD LIST 113-3/8" CSG, 72#, N-80, 10 = 12.347" 1-1 27441 1 ... Minimum ID = 4.455" @ 8995' 5-1/2" OTIS XN NIPPLE 17-5/8" TBG-IPC, 29.7#, L-80, .0459 bpf, ID = 6.919" 1-1 88411 1 17" TBG, 26#, L-80, .0383 bpf, 10 = 6.276" 1-1 15-1/2" TBG, 17#, L-80, 10 = 4.892" 1-1 POSSIBLE FISH BB-iIND 5-1/2" STUMP HALCO RBP ORAG BLOCK (6" X 1" X 1/2") -1 I 15-1/2" TBG, 17#, 13CR-80, .0232 bpf, 10 = 4.892" 1-1 I TOP OF 7" LNR 1-1 90081 1 9203' 1 . 95441 ~ 19-5/8" CSG, 47#, N-80, 10 = 8.681" 1-1 PERFORA TION SUMMARY REF LOG: BHCS ON 02/28/78 ANGLE A T TOP PERF: 33 @ 9870' Note: Refer to Production OB for historical perf data SIZE SPF INTERVAL Opn/Sqz OATE 3-3/8" 4 9870 - 9900 0 05/22/87 3-3/8" 4 9964 - 10098 0 05/22/87 3-3/8" 4 10110 - 10130 0 05/10179 3-3/8" 4 10150 - 10160 0 05/10/79 3-3/8" 4 10190 - 10200 0 05/10/79 3-3/8" 4 10212 - 10232 0 05/10/79 3-3/8" 4 10264 - 10280 0 05/10/79 3-3/8" 4 10304 - 10318 0 05/10/79 NGI-11 ) \ ;. n I I I I PBTD 1-1 104251 1 ,,~ . 17" LNR, 29#, MN-80, .0371 bpf, 10=6.184" 1-1 104961 ~ DA TE REV BY COMMENTS 03/12/78 ORIGINAL COMPLETION 08/03/92 RWO 11/09/04 JDMfTLI- RWO OA TE REV BY COMMENTS . ~ SAÆ,"'1oTE: *** AELD NGL DISPOSAL WELL *** *** CHROME 5.1/2 TBG *** 22' 1-17" X 7-5/8" XO, 10 = 6.276" 1 4001 1-1 EST. TOP OF ARCTIC SET CEMENT 1 22031 1-17-5/8" X 7" XO, 10 = 6.276" 1 2215' 1-17" DB-6 NO GO NIP, ID = 6.000" 1 22261 1-17" X 7-5/8" XO, 10 = 6.276" 1 23481 1-19-5/8" HALCO ES CEMENTER, ID = 8.50" 1 ... 88161 1-17-5/8" X 7" XO, 10 = 6.276" 1 88281 - 7" HES R NIP, ID = 5.963" 88391 -7" X 7-5/8" XO, 10 = 6.276" 88411 1-17-5/8" X 7" XO, 10 = 6.220" 1 88501 1-1 K-22 ANCHOR TBG SEAL NIP, ID = 6.000" 1 88511 1-19-5/8" X 5-1/2" BAKER SAB-3 PKR, 10 = 6.000" 1 88621 - 7" X 5-1/2" XO, 10 = 4.880" 1 88751 .J - 5-1/2" HES X NIP, ID = 4.562" 1 88991 1-19-5/8" X 5-1/2" UNIQUIE OVERSHOT 1 89271 1-15-1/2" TIW SBRASSY W/BKR K-22 ANCHOR LATCH 1 89431 1-19-5/8" X 5-1/2" BAKER SABL-3 PERM PKR 1 89781 - 5-1/2" PARKER SWS NIP, ID = 4.562" 1 89781 - XXN PlUG SET 06/08/04 1 89951 1-15-1/2" OTIS XN NIP, ID = 4.455" 1 90081 1-15-1/2" TUBING TAIL WLEG 1 1-1 ELMD TT NOT LOGGED 1 PRUDHOE BAY UNrr WELL: NGI-11 PERMIT No: 1770800 API No: 50-029-20283-00 SEe 1, T11 N, R14E, 1095.1' FEL & 609.5' FNL BP Exploration (Alas ka) ~ ~ ~1r~1rŒ (û)~ ~~i%~æi% AI1ASIiA OIL AND GAS CONSERVATION COMMISSION / I I I / ¡ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 p.+'~ ,,~ '\) Re: Prudhoe Bay NGI-ll Sundry Number: 304-355 Dear Mr. Reem: 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 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. BY ORDER OF THE COMMISSION DATED this.Ji day of September, 2004 Enc!. ~ IN~I\- '1/l/{20°4- ~~ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 1. Type of Request: 0 Abandon II Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Alter Casing II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 44' 4. Current Well Class: 0 Development 0 Exploratory 0 Stratigraphic 181 Service / 99519-6612 5. Permit To Drill Number 177-080 / 6. API Number: 50- 029-20283-00-00 / 9. Well Name and Number: PBU NGI-11 /' 10. Field 1 Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool PRESENT WElL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 10425 8548 ....... ...... ... ..M[<. ...........TVD... 8. Property Designation: ADL 028302 11. Total Depth MD (ft): Total Depth TVD (ft): 10496 8610 Casino Lenath Size. - , 95' 2744' 9544' 95' 2744' 9544' 95' 2744' 7797' 20" 13-3/8" 9-5/8" Or~' ,r>tõnn I inAr 7" 9203' - 10496' 7518' - 8610' 1293' Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: 9870' - 10318' 8070' - 8454' 7",26# x 5-1/2", 17# Packers and SSSV Type: 9-5/8" x 5-112" Baker 'SABL-3' packer; 7" Otis MRB Nipple Plugs (measured): None Burst Junk (measured): None CoIIaoS$ 1530 5380 6870 520 2670 4760 8160 7020 Tubing Grade: I Tubing MD (ft): L-80 1 13Cr80 9008' Packers and SSSV MD (ft): 8943' 2209' 13. Well Class after proposed work: / 0 Exploratory 0 Development 181 Service (""/ 15. Well Status after proposed work: September 30, 2004 0 Oil 0 Gas 0 Plugged Date: 0 WAG 181 GINJ I 0 WINJ APPROVED BY THE COMMISSION 12. Attachments: 181 Description Summary of Proposal 0 Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I h~reby cert~~at ~he foregoing is true and correct to the best of ~y. knowl~ge. Printed Name David ReelJJ Iì Title Dniling EngIneer SiQnature ~ '" -"V ~ ~ - Phone 564-5743 Commission Use Only 0 BOP Sketch Conditions of approval: Notify Commission so that a representative may witness 0 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: TI'::.t- 'BO\)E 10 4000 (JÇ.{' 5""""0' Fmfj)- 404 . Approved By: I A ~ Form 10-403 Re~06/.Q(ùV" ~ R9f)MS Sf l ~ 2? 11'(\1, COMMISSIONER ORIGfNAL 0 Abandoned 0 WDSPL Contact David Reem, 564-5743 Date c¡ho/D4 Prepared By Name/Number: Terrie Hubble, 564-4628 I Sundry Number: .3ot/-3.=s-S- RECEIVED SEP 2 1 2004 Alaska Oil & Gas Cons. Commission Anchorage / Date ?It; ;ðr¡; / ¡Submit In' Duplicate ~ ~ NGI-ll Workover Scope Objectives: Replace current 7" 26#/ft L-80 IPC NSCC tubing with 7-5/8", 29.7#/ft L-80 . IPC VamTop HC tubing. Replace top -2300' of 9-5/8" casing with 920' of premium r' connection 9-5/8" casing (top of string) and 1380' of 9-5/8" buttress casing. Procedure: 1. NU and test BOPE to 300 psi (low test)/4000 psi (high test). / 2. Pull 7" tubing down to the pre-rig chemical cut just above existing packer. "...-- 3. Run dress-off BHA and scraper to tubing stub. 4. Set 9.625" retrievable bridge-plug -50' above tubing stub. 5. Run USIT log to find top of cement in 9.625" x 13.375" annulus. / 6. Set 9.625" retrievable bridge-plug -50' below cement top determined in step 5. 7. Cut 9.625" casing -50' above cement top determined in step 5. 8. Circulate out Arctic Pack from 9.625" x 13.375" annulus. 9. Pull 9-5/8" casing down to the cut. / 10. Back-off and recover 9-5/8" stub. 11. Run 13-3/8" scraper to remove all Arctic Pack down to the 9-5/8" stub. 12. Run new 9-5/8" casing (top 920' to have premium connections) and screw back ../ into stub. 13. Cement 9-5/8" in place with a target cement top at -500'. 14. WOC. Drill out cementing equipment. PT 9-5/8" casing to 4000 psi. 15. Retrieve bridge-plugs. 16. Run 7-5/8", 29.7#/ft, L-80 IPC VamTop HC tubing completion./ ~ TREE = ? -- WELLHEAD= GRAY AClUATOR= AXB...SON KB. ELEV = 44' BF. ELEV - KOP= 2950' Max Angle = 52 @ 7598' Cetum M) - 10783' Cetum 1VD= 8800' SS 9-518" CSG, 47#, JL-95, ID = 8.681" 13-3/8" CSG, 72#, N-80, ID = 12.347" 2744' Minimum ID = 4.55" @ 8995' 5-1/2" OTIS XN NIPPLE I 7" lBG, 26#, L-80, 0.0383 bpf, D = 6.276" H I TOPOF5-1f2"lBG H 8875' 8875" 5-112" lBG, 17#, 13CR-80, .0232 bpf, ID = 4.892" 9008' NGI-11 TOP OF 7" LNR 9-5/8" CSG, 47#, No80, ID = 8.681" PERFORATION SUMlAARY REF LOG: BHCS ON 02/28/78 A I\GLE AT TOP PERF: 33 @ 9870' tlbte: Refer to Production DB for historical perf data SIZE SPF INfERV AL Opn/Sqz OA.1E 3-3/8" 4 9870-9900 0 05122/87 3-3/8" 4 9964-10098 0 05122/87 3-3/8" 4 10110-10130 0 05l10f79 3-3/8" 4 10150-10160 0 05l10f79 3-3/8" 4 10190-10200 0 05l10f79 3-3/8" 4 10212-10232 0 05l10f79 3-3/8" 4 10264-10280 0 05l10f79 3-3/8" 4 10304-10318 0 05l10f79 10425' 10496' 7' LNR, 29#, M\I-80, 0.0371 bpf, ID = 6.184" . ~ SAFETY NOTE: THIS IS THE RELD NGL DISPOSAL WB..L. CHROMES-1/2TBG. ***SLOW lAX OA COMM. MAX lAP = 2000 PSL MAX OAP = 2000 PSI (03I2S,u3 W AlVER)*** 2209' 8875" 8880' 8927 8943' 8978' 8995" 9008' DATE REVBY COMM8\!lS OA.1E REV BY CO MIA8\! T S 03/12/78 ORiGNAL COMR.ETION 08/03/92 RWO 01/26/01 SIS-MD FINAL 07/19/01 RNfTP CORRECllONS 03/27/03 RWLfTL~ XN NPPLE ID CORRECllON 03/25/03 ..LAiKK WANER SAFETY NOTE 7" OTIS MRB (\IP, ID = 5.963" 7"X5-1/2"XO 5-1/2" PARKERSWS NIP, ID= 4.562" 5-1/2" 1lW SBR ASSY W/BAKER K-22 ANCHOR LATCH 9-518" X 5-112" BAKER SABL-3 PERM A<R 5-1/2" PARKER SWS NIP, ID = 4.562" 5-1/2" OTIS XN NP, ID = 4.455" 5-1/2" lUBING TAIL WLB3 H B...MD TT NOT LOGGED I PRUCHOEBAY !..NIT WELL: NGl-11 ÆRMT I>b: 1770800 APII>b: 50-029-20283-00 SEC1, T11N, R14E, 1095.1' FEL& 609.5' FI'-I... 8P exploration (Alaska) - WELLHEAD = GRAY ACTUATOR- AXELSON KB. ELEV = 44' BF. ELEV = KOP= 2950' Max Angle = 52 @ 7598' Datum MD = 10783' Datum TVD = 8800' SS ~l\JGI-ll Proposed ~ =---- Target Cement Top = 500' I -920' H 9-5/8" CSG 47# NT95HS NSCC, ID = 8.681" I I I -2200' H 7" CAM DB-6 NIP, ID = 6.00" I TREE = ? 2301' 9-5/8" CSG, 47#, JL-95, ID = 8.681" I 113-3/8" CSG, 72#, N-80, ID = 12.347" I 2744' Minimum ID = 4.55" @ 8995' 5-1/2" OTIS XN NIPPLE I 7-5/8" TBG, 29.7#, L-80, Yam Top HC, IPC 5-1/2" TBG, 17#, L-80, TC-II, ID = 4.892" 5-1/2" x 9-5/8" Unique Machine Overshot (Carbon) 5-1/2" TBG, 17#, 13CR.80, .0232 bpf, ID = 4.892" I 9008' I TOPOF 7" LNR I 9-5/8" CSG, 47#, N-80, ID = 8.681" I ÆRFORA TION SUMIV1ARY REF LOG: BHCS ON 02/28/78 ANGLEATTOPÆRF: 33 @ 9870' Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE 3-3/8" 4 9870-9900 0 OS/22/87 3-3/8" 4 9964-10098 0 OS/22/87 3-3/8" 4 10110-10130 0 05/10/79 3-3/8" 4 10150-10160 0 05/10/79 3-3/8" 4 10190-10200 0 05/10/79 3-3/8" 4 10212-10232 0 05/10/79 3-3/8" 4 10264-10280 0 05/10/79 3-3/8" 4 10304-10318 0 05/10/79 I PBTD I 10425' 10496' 7" LNR, 29#, MN-80, 0.0371 bpf, ID = 6.184" I I -8840' H 7" "R" NIPPLE, ID = 5.963" I -8865' I 7" x 9-5/8" Baker SABL-3 T-95 Packer I H -8890' 5-1/2" "X" NIP, ID = 4.562" I 8927' I 5-1/2" TIW SBRASSY W/BAKER K-22 ANCHOR LA TCH 8943' -l 9-5/8" X 5-1/2" BAKER SABL-3 ÆRM A<R I 8978' -l 5-1/2" PARKER SWS NIP, ID = 4.562" 8995' -l 5-1/2" OTIS XN NIP, ID = 4.455" I 9008' -l 5-1/2" TUBING TAIL WLEG I H ELMD TT NOT LOGGED I DATE REVBY COMMENTS DATE REV BY COMMENTS 03/12/78 ORIGINAL COMPLETION 08/03/92 ~O 01/26/01 SIS-MD FINAL 07/19/01 RI\VTP CORRECTIONS 03/27/03 ~UTL- XN NIPPLE ID CORRECTION 03/25/03 JLA/KK WAWER SAFETY NOTE PRUDHOE BA Y UNIT WELL: NGI-11 ÆRMIT No: 1770800 API No: 50-029-20283-00 SEe 1, T11N, R14E, 1095.1' FEL & 609.5' FNL BP Exploration (Alaska) NOI-ll (PTD #1770800) Notice of SI Subject: NGI-ll (PTD#lY70800}Notice ofSI From: "NSU, ADW Well Integrity Engineer" <NSUAD,WW ellIntegrityEngineer@BP.com> Date: Sun, 11 Jan 2004 07:34:13 -0900 To: "AOGCC Winton Aubert (E-nlail)" <\vinton_aubert@adm.in.state.ak.us>, "AOGCC Jim Regg (E-ll1ail)" <jim_regg@admin.state.ak.us> CC: "N'SU, ADW Wen Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Rossberg,:R Steven" <RossbeRS@BP.com> Winton and Jim¡ We SI NGI-11 at 24:00 hrs on 1/10/04 due to the T x IA communication. A brief summary of events over the past couple of days is as follows: 01/06/04: Initial IA FL @ 2682'. DHD bled IA from 1920 psi to 390 psi ¡bled OA from 1380 psi to 440 psi. Final IA FL @ 2337'. 01/07/04: T/I/O = 3550/1400/690. lAP increased 980 psi since yesterday. 01/08/04: Bled IA diesel. Final IAP 01/09/04: was and at 1280 psi. 01/1,0/04: lAP still at 1280 psi. SI well <3;t midnight. from 1960 to 340 psi and loaded with 70 bbls 500 psi. WIC agree to shut in and secure. lAP stabilized Plans forward for this well are as follows: 1. SL: Pull SSSV¡ Set TTP¡ set DSSSV¡ test control and balance lines. 2. WIE: Discuss options to repalr. If you have any questions¡ or would like to discuss in further detail¡ please let me know. Thanks¡ John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100¡ x. 1154 'I"'~r-~,",,' """\~n'-¡ '"¡'""n"'n',n ("ff.",'\'\¡'-'~"", ";!'VI J "","8",,\1. ,'5)~:;?/~\¡~ tjí, t.t1, ,,:oJ N f'!J Jl, ~'J.; '" ccAh 1 of 1 1/12/2004 8:57 AM NGI-11 (PTD #177080) Request to withdraw sundry application dated 9/30/03 'Subject: NGI-11 (PTD #177080) Request to withdraw sundry application dated 9/30/03 Date: Thu, 23 Oct 2003 16:37:50 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer~BP.com> To: "AOGCC Jim Regg (E-mail)" <Jim_Regg~admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <Winton_Aubert@admin.state.ak.us>, "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> Hi Winton, As per your suggestion, this e-mail is to request the withdrawl of the NGI-11 sundry application dated September 30, 2003. The subject sundry was a proposal by BPXA to continue to operate the NGI-11 gas injection well while diagnostics were performed on a possible T x IA communication issue. Since submitting the sundry, the well has stopped exhibiting sustained pressure on the IA and has been re-classified as a normal well. If you have any questions or need any additional information, please don't hesisitate to contact me. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 NGI-I 1 (PTD #1770800) Status Report 'Subject: NGI-11 (PTD #1770800) Status Report Date: Wed, 22 Oct 2003 12:37:42 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegr/tyEngineer@BP.com> To: "AOGCC Jim Regg (E-mail)" <Jim_Regg@admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <Winton_Aubert~admin.state.ak.us> CC: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer~BP.com> Hi Jim and Winton, we pulled the TTP and reset the SSSV in NGI-11 on 10/13/03 and returned the well to injection. Since its return to injection, we have not seen any signs of IA repressurization. As such, we will remove the well from the weekly AOGCC report and treat the well as a normal injector with daily well head pressure monitors. If you have any questions or if you would like to discuss in further detail, please let me know. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 Name: oleO.bmp Type: Bitmap Image (image/bmp) 2003-0929_P BU_NGI- Il_IA_rep ress u re. txt subject: NGI-11 IA Repressurization Oate: Mon, 29 Sep 2003 10:38:38 -0500 From: "NSU, ADW well Integrity Engineer" <NSUADWWel 1 Integ ri tyEngi nee r~BP. com> To' "AOGCC Jim Regg (E-mail)" <]im_Regg~admin.state.ak.us>, "AOGCC wi nton Aubert (E-mai l)" <Wi nton_Aubert@admi n. state, ak. us> cc: "NSU, ADW well Operations supervisor" <NSUADWWel 10perati onsSupe rvi sor~BP, corn>, "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer~BP.com> Hi Winton and Jim, well NGI-11 (PTD# 1770800) IAP increased 1200 psi overnight on 9/28/03. It is currently waivered for IAXOA communication. Brief well Hi story: > 03/24/03: MTT-T to 4300 psi - Pass. MITOA to 4300 psi - Pass. > 09/20/03: MITIA to 3000 psi - Pass > 09/22/03: NFT-IA - Pass > 09/25/03: Pump GX sealant down balance/control lines > 09/27/03: TIO=3550/1980/1650. Bleed IA/OA (post GX sealant). Final WHP's : 3550/600/50. > 09/28/03: TIO=3540/1800/270. IAP increased 1200 psi overnight. Current plan is to leave well on injection, slickline will change 7" sssv and bleed/monitor IA/OA post change out. Please call with any questions. Thanks, John Petty for cubbon/Anders GPB well Integrity coordinator (907) 659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Page 1 gp.bu_gas_pad_i nj_bp_wai ve rs. txt subject: Information concerning BP Internal waivers at N6I and W6I oate: Sun, 12 Jan 2003 22:53:49 -0600 From: "NSU, ADW well Integrity Engineer" <NSUADWWel I Integri tyEngi neer~BP, corn> To: "'TOm Maunder'" <tom_maunder~admi n. state, ak. us> cc: "Jim_Regg (E-mail)" <Jim_Regg~admin.state.ak.us>, "NSU, ADW well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> Tom and Jim, Please see the information that you requested concerning the gas injection well s with BP internal waivers below. N61-07: waivered for production casing leak on 10/23/90. Records indicate on 8/20/90, the IAP was pressured to 2200 psi when it suddenly dropped to 2100 and started falling. A CMIT TxlA conducted 10/08/90 failed to hold 2500 psi. MITIA'S routinely pass to 2000 psi, the most recent was on 06/02. W61-04: waivered for slow IAxOA comm on 4/28/00. MITIA passed 10/02 to 2650 psi. OA re-pressure review conducted 12/02 indicates the IAXOA communication is no longer present. WGI-05: waivered for slow IAXOA comm on 5/12/00. MITIA passed 06/02 tO 2060 psi. OA re-pressure rate not recently quantified. TIO trends indicate IAxOA comm is still present. If you have any questions, or would like to discuss in greater detail, please let me know. Thanks, John cubbon GPB well Integrity coordinator 1-907-659-5102 pgr. 659-5102, x. 1154 original Message- From' Tom Maunder [mai I to' tom_maunder~admi n. state, ak. us] sent: Tuesday, December 24, 2002 9:41 AM To: cubbon, John R Cc: Jim_Regg (E-mail); NSU, AOW Well Integrity Engineer Subject: Re: NGI-11 (PTO #1770800) OA pressurization John, we have received you message with regard to NGI-11. We are frankly surprised that you would propose to evaluate this well for an internal waiver. T seem to remember some discussions with regard to a couple of wGI wells that may have BP'S internal waivers. would you please provide a listing of the gas injection wells (NGI, WGI, AGI, LGI) that may have internal waivers and the reason a waiver is necessary. Although you indicate in your action plan that you plan to perform MITs and then evaluate the well for the internal waiver, we suggest that you also look into repairing the well. Tom Maunder, PE AOGCC "cubbon, ]ohn R" wrote: > Hi Tom and Jim, Page 1 gpbu_gas_pad_i nj_bp_wai ve rs. txt > > The NGI pad operator has notified us that the bleed frequency for the OA at > NGI-11 has increased recently. A brief history of events is as follows: > > > 05/02/00: MITIA Passed to 3000 psi. > > 02/08/02: MIT IA Passed to 3000 psi. Investigate high IAP > > 10/19/02' DSO reported OA had ~u. mped from 1600 to 2100 psi overnight. IA > gauge on wellhead shows 200 psi n~gner than test gauge. > > 10/20/02: PPPOT-T PASSED > > 12/22/02: PPPOT-IC PASSED > > 12/23/02: OAP increased 750 psi in 2 days. > > As you can see from the attached TIO plot, since October 2002 the OA > repressurization rate for this well has increased. The source of the > pressure in the OA does not appear to be communication through the well head > (passing PBPO¥---~C-)~ > Our plan of action is as follows: > 1. MITIA tO 3000 psi with the OA bled down to < 500 psi. > 2. MITOA to 3000 psi. > 3. Evaluate for an internal waiver to allow OAP tO go tO a maximum of 2000 > psi. > > Please let me know if you would like us to procede in a different manner or > if more information is required. > > Thanks, > > John cubbon > GPB well Integrity coordinator > 1-907-659-5102 > pgr. 659-5102, x. 1154 > > <<NGI-11 TIO.jpg>> <<NGI-11.pdf>> <<NGI-II Inj. plot.jpg>> > Name' NGI-11 TIO.jpg NGI-11 TIO.jpg Type' JPEG Image (i mage/j peg) Encoding' base64 Name' NGI-11.pdf NGI-11.pdf Type' Acrobat (application/pdf) Encoding' base64 Name' NGI-II Inj. plot.jpg NGI-II Inj. plot.jpg Type' 3PEG Image (i mage/j peg) Encoding' base64 Page 2 gas_i nj ecto r_temps, txt subject: RE: NGI Injection Temp Date: Mon, 5 May 2003 23:58:49 -0500 From: "NSU, ADW well Integrity Engineer" <NSUADWWel 1 Integ ri tyEngi neer~BP, corn> To' Jim Regg <jim_regg@admin.state.ak.us> cC: "AOG¢C Wi nton Aubert (E-mai l)" <wi nton_Aubert@admi n. state, ak. us> Hi ]im, AS per your request, we recorded the following temperatures from the AGI-NGI-WGI i nj ecti on I i nes 1 eadi ng into the wel I houses. wel 1 AGI-01 AGI-05 AGI-10 i I-01 -07 WGI-01 WGI-04 WGI-05 Temperat~~grees F) 97 ',-_...].154 ........... / 158 .. 163 '~ '"' 159 If you have any questions';.:?please give me a call. Thanks, John cubbon GPB well Integrity coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 ..... original Message-- From: Jim Regg [mailto:jim_regg~admin.state.ak.us] sent: Tuesday, April 29, 2003 3' 56 PM To: NSU, ADW Well Integrity Engineer Subject: NGI Injection Temp I have been looking for temperature data about gas injectors as part of our review of those exhibiting annular pressures. You have provided quite a bit of pressure information for the Prudhoe gas injectors (NGI-AGI-WGI), but I have not seen any temperature info. Could you tell me the typical injection temp for the wells? Thanks. 3im Regg, AOGCC Page 1 BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 bp September 30, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: NGI-11 (PTD 171-080) Application of Corrective Action Plan Dear Mr. Aubert: Attached is an Application for Sundry Approval form 10-403 for the proposed corrective action plan for well NGI-11. This request is for approval to continue gas injection in a well exhibiting inner annulus repressurization. This request also documents our proposed action plan to troubleshoot and rectify repressurization. A description summary of the proposal and wellbore schematic is included for the well. If you require any additional information or clarification, please contact either John Cubbon or Joe Anders at (907) 659-5102. Sincerely, John Petty Well Integrity Engineer Attachments 1) Application for Sundry Approval form 10-403 2) Description Summary of Proposal 3) Wellbore Schematic RECEIVED OCT _OO3 0il & Gas Cons. comm~ssi0n Anchorage ORIGINAL STATE OF ALASKA I' ,., ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 2O AAC 25.28O 1. Type of Request: Abandon E] Suspend r-] Operation Shutdown E] PerforateE] Variance~// AnnuarDisposalr--] Alter Casin.q D Repair Well E] Plu.q Perforations D stimulateE] Time ExtensionJ~ OtherE] Chan.qe Approved Pro.qram [--I Pull Tubin.q E~ Pedorate New Pool E] Re-enter Suspended ~IID_IA/- 2. Operator 4. Current Well Class: 5. iYermit to DriLl Number: · BP Exploration (Alaska), Inc. / ...... Name: Development E] Expl°rat°ryE] / 1 [/-uuu ' 3. Address: P.O. Box 196612 /16. APl Number Anchorage, Ak 99519-6612 Stratigraphic E] Service. / 50-029-20283-00-00 7. KB Elevation (ft): .9. Well Name and Num~,~. / RKB 44.00 ' NGI-11 ./ 8. Property Designation: 10. Field/Pool(s): ADL 028302 Prudhoe/Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY / Total Depth MD (ft): ITotal Depth TVD (ft): IEffective Depth MD (ft): IEffectiv¢epth TVD (ft): IPlugs (measured): IJunk (measured): 10496 I 8610 I 10420 (10/07/1992)I // 8543 I None I None Casing Length Size MD ~' TVD Burst Collapse top botto~op bottom Conductor 95 20" 47'- 142' /' 47'- 142' 40K 520 Surface 2697 13-3/8" 47' - 2744~// 47' - 2744' 80K I 2670 Intermediate 9487 9-5/8" 47' - 95z~' i 47' - 7797' 80K ! 4760 Sidetralk L,ner 1293 7" 9203' ~14~496' 7518' - 8610' 80K i 7020 Perforat'on Depth MD (ft): I Perforation Depth TVD (ft): '~,~/ingy~ze: I Tubing Grade: ! Tubing MD (ft): I [ .-80, 9008 Packers and SSSV Type: \ ~ V' ,,-, '~°'i4c~rs and SSSV MD (ft): 9-5,8"x 5-1/2" BKR SABL-3 PKR, Offs MRB Nipp~ ~d~_} 1~1~ @ 8943', Nipple @ 2209' 12. Attachments: Description Summary of Proposal~J~' ~,~'~:~ Well Class after proposed work: Detailed Operations Program E] BOP Sketch [~ ~N.i~ Exploratory[--] DevelopmentE] Service. 14. Estimated Date for (.3r, tnh,.,r 9r~n~cl ~' \ 15. We;;:tus after proposed work: Commencing Operation: ...... ' '-"'"'/¥ OilF1 Gas[-] Pluggedr"~ Abandoned E] 16. Verbal Approval: Date: 9/2¢003 WAGb GINJB WINJE] WDSPLF"'] Commission Representative: Winton ,~bert i Prepared by DeWayne R. Schnorr564-5174. 17. I hereby certify that the foregoing is tr,/and correct to the best of my knowledge. Contact Joe Anders Printed Name Jo P Title ADW Well Integrity Engineer Signature ~ Phone 907/659-5102 Date 09/30/2003 - / - Commission Use Only ~ [ Sundry Number: Conditions of app;oval: Np Co,.~mmission so that a representative m.~ay witness I _.~D '~ -,~ I~' Plug ,ntegrity r-] ,~P Testl'-I Mechanical Integrity TestE~ Location Clearancer-] ' Other: ~ · EC' ED / O ,T 1 6 2083 Subsequent ~'orm Required: Alasl(a 0ii o ,-, ,. ~ bas Uons. [;0mmissiof~ Anchorage / ~ BY ORDER OF App?ed by: COMMISSIONER THE COMMISSION ~ Date: Form 10-403 Revised 2/2003 ORIGINAL SUBMIT IN DUPLICATE NGI-11 Description Summary of Proposal 09/30/03 Problem: Gas Injector with Inner Annulus Gas Repressurization Well History and Status: Well NGI-11 (PTD 177-080) is a gas injector that exhibits Inner Annulus repressurization. The following is a brief history of well events: Brief Well History: 03/24/03: MIT-T to 4300 psi- Pass. MITOA to 4300 psi - Pass. 09/20/03: MITIA to 3000 psi- Pass 09/22/03: No Flow Test-lA- Pass 09/25/03: Pump GX sealant down balance/control lines 09/27/03: TIO=3550/1980/1650. Bleed IA/OA (post GX sealant). Final WHP's = 3550/600/50. 09/28/03: TIO=3540/1800/270. lAP increased 1200 psi overnight. Balance/control lines remained unchanged 4550/4900. 09/29/03: Notify AOGCC of well status. This sundry request is to formally submit our corrective action plan to diagnose and rectify the Inner Annulus repressurization. Proposed Action Plan: 1. Allow well to continue gas injection - received verbal from Winton Aubert to leave on injection (9/29/03). 2. Shoot initial IA and OA fluid levels. 3. Pull SSSV (monitor IA after pulling). Run 5-1/2"XN plug in tubing tail pipe. Purge lines, set and pressure test DSSSV. 4. Open wing and charge tubing with injection gas to injection pressure (~3500 psi). Close wing to trap pressure on tubing. 5. Bleed IA and OA pressure as Iow as possible to upright tank. 6. Monitor tubing for pressure fall-off and monitor IA for pressure build-up. (Notify commission if communication exists) If communication is not observed during test, we will suspect the SSSV as the reason for prior communication and continue with step 7. 7. Pull TTP. Pull DSSSV. Run new SSSV. Put on injection and monitor. 8. Notify AOGCC of final disposition. TRE -~ ? ~A/ELL HEAO = GRAY ACTUATOR = AXELSON KB. ELL=,/ = 44' BF. ELEV = KOP= 2950' Max Angle = 52 @ 7598' Datum IV[:) = 10783' Datum'fVD= 8800' SS g-5/8" CSG, 47#, JL-g5, ID = 8.681" H 2301' 113-3/8"CSG, 72#, N-80,1D = 12.347" Id 2744' IMinimum ID = 4.55" @ 8995' 5-1/2" OTIS XN NIPPLE I 7" TBG, 2~, L-80, 0.0383 bpf, D =6.276" Id 8875' I TOP OF 5-1/2" TBG H 8875, I NGI-11 SAFETY NOTE: THIS IS THE RELD NGL DISPOSAL WB.L. CHROME5-112 TBG. ***SLOW laX DA COMM. MAX lAP = 2000 PSI. MAX DAP = 2000 PSI (03/25/03 WAIVER)*** 5-1/2"TBG, 17#, 13CR-80, .0232bpf, ID=4.892" H 9008' 9203' ~ ~ I 9544' PERFORATION SUIVlMARY REF LOG: BHCS ON 02/28/78 ANGLE AT TOP PERF: 33 @ 9870' Note: Refer to Production DB for historical )erf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9870-9900 O 05/22/87 3--3/8" 4 9964-10098 O 05/22/87 3-3/8" 4 10110-10130 O 05/10/79 3-3/8" 4 10150-10160 O 05/10/79 3- 3/8" 4 10190.10200 O 05/10/79 3- 3/8" 4 10212-10232 O 05/10/79 3-3/8" 4 10264-10280 O 05/10/79 3-3/8" 4 10304-10318 O 05/10/79 10425' I 10496' ' I 7" LNR, 29#, MN-80, 0.0371 bpf, ID= 6.184" Id 2209' H 7" OTIS MRB I~IP, ID = 5.963" 8875' H 7" X 5-1/2" XO --J 8880'H 5-1/2" PA F~ER SWS NIP, ID = 4.562" ] 8927' 8943' 8978' 8995' 9O08' ANCHOR LATCH 5-1/2" TIW SBR ASSY W/BAKER K-22 9-5/8"X5-1/Z'BAKERSABL-3PERMFKR I H 5-1/2" PA RKER SWS NIP, ID = 4.562" I 5-1/2" OTISXNNP, ID= 4.455" I H 5-1/2" TUBING TAIL WLEG I H FIMDTTNOTLOGGED I DATE REV BY COMMENTS DATE REV BY OOMMENTS 03/12/78' ORIGNAL COMFLETION 08/03/92 RWO 01/26/01 SIS-MD FINAL 07/19/01 RNR'P CORRECTIONS 03/27/03 RWLfTLF XN NPPLE ID CORRECTION 03/25/03 JLA/KK WAIVERSAFETY NOTE PRUDHOE BAY UNIT WELL: NGI-11 PERIVlT No: 1770800 APl NO: 50-029-20283-00 SEC 1,T11N, R14E 1095.1' FEL& 609.5' FN_ BP Exploration (Alaska) [Fwd: NGI- 11 (ewE) # 1770800) OA pressurization] Subject: [Fwd: NGI-11 (PTD #1770800) OA pressurization] Date: Thu, 26 Dec 2002 13:08:44 -0900 From: Jim Regg <jim_regg~admin. state.ak.us> Organization: AOGCC To: Jody Colombie <jody_colombie@admin. state.ak.us> please include this in info I provided to you Tuesday (NGI-11) Subject: RE: NGI-11 (PTD #1770800)OA pressurization Date: Thu, 26 Dec 2002 16:03:19 -0600 From: "Cubbon, John R" <CubbonJR~BP.com> To: "'Tom Maunder'" <tom_maunder~admin. state.ak.us> CC: "Jim_Regg (E-mail)" <Jim_Regg~admin. state.ak.us>, "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer~BP.com> Tom and Jim, I will meet with Joe at crew change on Tuesday (12/31/02) and we will gather and forward the information that you have requested. Wishing you and yours all the best in 2003! John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5102, x. 1154 ..... Original Message ..... From: Tom Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, December 24, 2002 9:41 AM , To: Cubbon, John R Cc: Jim_Regg (E-mail); NSU, ADW Well Integrity Engineer Subject: Re: NGI-11 (PTD #1770800) OA pressurization John, We have received you message with regard to NGI-11. We are frankly surprised that you would propose to evaluate this well for an internal waiver. I seem to remember some discussions with regard to a couple of WGI wells that may have BP's internal waivers. Would you please provide a listing of the gas injection wells (NGI, WGI, AGI, LGI) that may have internal waivers and the reason a waiver is necessary. Although you indicate in your action plan that you plan to perform MITs and then evaluate the well for the internal waiver. We suggest that you also look into repairing the well. Tom Maunder, PE AOGCC "Cubbon, John R" wrote: Hi Tom and Jim, The NGI pad operator has notified us that the bleed fre~ency for the OA 2/30/2002 3:30 PM [Fwd: NGI-11 (PTD #1770800) OA pressurization] at > NGI-11 has increased recently. A brief history of events is as follows: > > > 05/02/00: MITIA Passed to 3000 psi. > > 02/08/02: MIT IA Passed to 3000 psi. Investigate high IAP > > 10/19/02: DSO reported OA had jumped from 1600 to 2100 psi overnight. IA > gauge on wellhead shows 200 psi higher than test gauge. > > 10/20/02: PPPOT- T PASSED > > 12/22/02: PPPOT-IC PASSED > > 12/23/02: OAP increased 750 psi in 2 days. > > As you can see from the attached TIO plot, since October 2002 the OA > repressurization rate for this well has increased. The source of the > pressure in the OA does not appear to be communication through the wellhead > (passing PPPOT-IC). > > Our plan of action is as follows: > > 1. MITIA to 3000 psi with the OA bled down to < 500 psi. > 2. MITOA to 3000 psi. > 3. Evaluate for an internal waiver to allow OAP to go to a maximum of 2000 > psi. > > Please let me know if you would like us to procede in a different manner or > if more information is required. > > Thanks, > > John Cubbon > GPB Well Integrity Coordinator > 1-907-659-5102 > pgr. 659-5102, x. 1154 > > <<NGI-11 TIO.jpg>> <<NGI-11.pdf>> <<NGI-II Inj. plot.jpg>> Name: NGI- 11 TIO. jpg NGI-11 TIO.jpg Type: JPEG Image (image/jpeg) Encoding: base64 Name: NGI- 11. pdf NGI-11.pdf Type: Acrobat (application/pdf) Encoding: base64 Name: NGI-II Inj. plot. jpg NGI-II Inj. plot.jpg Type: JPEG Image (image/jpeg) Encoding: base64 Petroleum Engineer AOGCC inistration - [Fwd: NGI- 11 0aTD # 1770800) OA pressurization] 2/30/2002 3:30 PM Re: NGI-11 (PTD #1770800) OA pressurization Subject: Re: NGI-11 (PTD #1770800) OA pressurization Date: Tue, 24 Dec 2002 09:41:05 -0900 From: Tom Maunder <tom_maunder~admin.state.ak.us> To: "Cubbon, John R" <CubbonJR~BP.com> CC: "Jim_Regg (E-mail)" <Jim_Regg~admin.state.ak.us>, "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer~BP.com> John, We have received you message with regard to NGI-11. We are frankly surprised that you would propose to evaluate this well for an internal waiver. I seem to remember some discussions with regard to a couple of WGI wells that may have BP's internal waivers. Would you please provide a listing of the gas injection wells (NGI, WGI, AGI, LGI) that may have internal waivers and the reason a waiver is necessary. Although you indicate in your action plan that you plan to perform MITs and then evaluate the well for the internal waiver. We suggest that you also look into repairing the well. Tom Maunder, PE AOGCC "Cubbon, John R" wrote: Hi Tom and Jim, The NGI pad operator has notified us that the bleed frequency for the OA at NGI-11 has increased recently. A brief history of events is as follows: > 05/02/00: MITIA Passed to 3000 psi. > 02/08/02: MIT IA Passed to 3000 psi. Investigate high IAP > 10/19/02: DSO reported OA ~had jumped from 1600 to 2100 psi overnight. IA gauge on wellhead shows 200 psi higher than test gauge. > 10/20/02: PPPOT- T PASSED > 12/22/02: PPPOT-IC PASSED > 12/23/02: OAP increased 750 psi in 2 days. As you can see from the attached TIO plot, since October 2002 the OA repressurization rate for this well has increased. The source of the pressure in the OA does not appear to be communication through the wellhead (passing PPPOT-IC). Our plan of action is as follows: 1. MITIA to 3000 psi with the OA bled down to < 500 psi. 2. MITOA to 3000 psi. 3. Evaluate for an internal waiver to allow OAP to go to a maximum of 2000 psi. Please let me know if you would like us to procede in a different manner or if more information is required. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5102, x. 1154 <<NGI-11 TIO. jpg>> <<NGI-11.pdf>> <<NGI-II Inj. plot. jpg>> Name: NGI-11 TIO.jpg 12/24/2002 11:24 AM Re: NGI-11 (PTD #1770800) OA pressurization /~,. NGI-11 TIO.jpg Type: Encoding: JPEG Image base64 (image/jpeg) Name: NGI- 11. pdf Type: Encoding: NGI-11.pdf Acrobat (application/pdf) base64 NGI-II Inj. Name: NGI-II Inj. plot.jpg plot. jpg Type: JPEG Image (image/jpeg) Encoding: base64 Tom Maunder <tom maunder~admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 12/24/2002 11:24 AM NGI- 1'1 (PTD # 1770800) OA pressurization Subject: NGI-11 (PTD #1770800) OA pressurization Date: Tue, 24 Dec 2002 11:58:39 -0600 From: "Cubbon, John R" <CubbonJR~BP.com> To: "Jim_Regg (E-mail)" <Jirn_Regg~admin. state.ak.us>, "Tom Maunder (E-mail)" <tom_maunder~admin. state.ak.us> CC: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer~BP.com> Hi Tom and Jim, The NGI pad operator has notified us that the bleed frequency for the OA at NGI-11 has increased recently. A brief history of events is as follows: > 05/02/00: MITIA Passed to 3000 psi. > 02/08/02: MIT IA Passed to 3000 psi. Investigate high IAP > 10/19/02: DSO reported OA had jumped from 1600 to 2100 psi overnight. IA gauge on wellhead shows 200 psi higher than test gauge. > 10/20/02: PPPOT- T PASSED > 12/22/02: PPPOT-IC PASSED > 12/23/02: OAP increased 750 psi in 2 days. As you can see from the attached TIO plot, since October 2002 the OA repressurization rate for this well has increased. The source of the pressure in the OA does not appear to be communication through the wellhead (passing PPPOT-IC). Our plan of action is as follows: 1. MITIA to 3000 psi with the OA bled down to < 500 psi. 2. MITOA to 3000 psi. 3. Evaluate for an internal waiver to allow OAP to go to a maximum of 2000 psi. Please let me know if you would like us to procede in a different manner or if more information is required. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5102, x. 1154 <<NGI-11 TIO.jpg>> <<NGI-11.pdf>> <<NGI-II Inj. plot.jpg>> [~NGI- 11 TIO.jpe Name: NGI-11 TIO.jpg Type: JPEG Image (image/jpeg) Encoding: base64 Name: NGI-11.pdf Type: Acrobat (application/pdf) Encoding: base64 ~NGI-II Inj. plot.jpg Name: NGI-II Inj. plot.jpg Type: JPEG Image (image/jpeg) Encoding: base64 1 of 2 12/24/2002 l 1:23 AM NGI- 1'1 (PTD # 1770800) OA pressurization 2 of 2 12/24/2002 11:23 AM TR[~: = ? WELL HEAD = G RAY ACTUATOR = AXFI SON (B. F_LEV = 44' BF. ELEV = KOP = 2950' Max Angle = 52 @ 7598' Datum IVD = 10783' Datum W D = 8800' SS I 9'5/8" CSG' 47#' JL-95' ID = 8'681" H 2301' Jl 3-3/8" CSG, 72#, N-80, ID = 12.347' H 2744' Minimum ID = 4.55" @ 8995' I I 5-1/2" OTIS XN NPPLE 7" TBG, 26#, L-80, 0.0383 bi)f, D = 6.276" H I TOP OF~I~"'FBG H 5-1/2" 'I~G, 17#, 13CR-80, 0.0232 bpf, ID =4.892" H I TOP OF 7" LNR H 9-5/8" CSG, 47#, N-80, ID= 8.681" H 9OO$' 9203' ~ 9544' 8875' 8875' PERFORATION S UlVlVIARY REF LOG: BHCS ON 02/28/78 ANGLE AT TOP PERF: 32 @ 9906' Note: Refer to Production DB for historical 3err data SIZE SPF INrERVAL Opn/Sqz DATE 3-3/8" 4 9870-9900 O 05/22/87 3-3/8" 4 9984-10098 O 05/22_/87 3-3/8" 4 10110-10130 O 05/10/79 3-3/8" 4 10150-10160 O 05/10/79 3-3/8" 4 10190-10200 O 05/10/79 3-3/8" 4 10212-10232 O 05/10/79 3-3/8" 4 10264-10280 O 05/10/79 3-3/8" 4 10304-10318 O 05/10/79 10425' I NGI-11 I PBTD H 7" LNR, 29#, IV~l-80, 0.0371 bpf, ID=6.184" H aL i ~k ~209' 8875' 8880' 8927' 8943' 8978' 8995' 9008' SAFETY NOTE: THIS IS THE FIB. D NGL DISPOSAL WELL 7" OTIS MRB NP, ID = 5.963" 7" X5-1/2"XO H 5-1/2 " PARKERSWS NIP, ID= 4.56Z' I -1 5-1/2" TIVV SBR ASSY W/BAKER K-22 I I ANCHOR LATCH H 9-5/8 " X 5-1/Z' BAKER SABL-3 PERM I:KR I H 5-1/2" PARKERSWS NIP, ID= 4.562" I H 5 -1/2" OTIS XN NP, ID = 4.55" H 5-1/2" TUBING TAIL WLEG I DATE REV BY COMME~ITS DATE REV BY OOIVlVII~ITS 03/12/78 ORIGNAL COMFLETION 08/03/92 RWO 10/16/00 SIS-Isl CONVERTEDTO CANVAS 01/26/01 SIS-MD FII'C,L 07/19/01 RN/TP CORRECTIONS PRUDHOE BAY UNIT WELL: NGI-11 PERIVIT NO: 77-080 APl No: 50-029-20283-00 SEC 1 Tll N R14E 1095.1 FEL 609.5 FNL BP Exploration (Alaska) STATE OF ALASKA U J N ALASKA AND GAS CONSERVATION CC- 41SSION REPORT UF SUNDRY WELL OPI-rlATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate 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 254' FSL & 890' FWL, Sec. 1, T11N, R14E, UM At top of productive interval 917' FWL& 1017' FEL, Sec. 2, T11N, R14E, UM At effective depth 800' FNL & 1054' FEL, Sec. 2, T11N, R14E, UM At total depth 800' FNL & 1054' FEL, Sec. 2, T11N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service Gas Cons. 6. Datum of elevation(DF or KB) 44' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number NGI-11 9. Permit number/approval number 77-80/92-236 10. APl number 50 - 029-20283 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10496 feet 8610 feet Plugs(measured) Fill @ 10420' MD (10/7/92 tag) Effective depth: measured 10420 feet true vertical 8543 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 95' 20" 325 sx Arcticset II 95' 95' Surface 2697' 13-3/8" 6200 sx Permafrost II 2744' 2744' Production 9487' 9-5/8" 800 sx Class G 9544' 7797' Liner 1293' 7" 400 sx Class G 9203-10496' 7518-8610' Perforation depth: measured 9870-9900'; 9906-10098'; 10110-10130'; 10150-10160'; 10190-10200'; 10212-10232'; 10264-10280'; 10304-10318' true vertical 8070-8095'; 8100-8264'; 8274-8291 '; 8308-8317'; 8342-8351 '; 8361-8378'; 8406-8420'; 8441-8453'; Tubing (size, grade, and measured depth) 7", 26#, L-80 @ 8875' MD; 5-1/2", 17#, 13-Cr 80 Tbg @ 9008' MD Packers and SSSV (type and measured depth) Baker SABL-3 packer @ 8943' MD; Otis MRB Nipple @ 2209' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 177,000 198,000 ~ -- Tubing Pressure 3567 WHIP 3570 WHIP 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Qlq/l") FII~I~ r,r,- .qW .IWP Date SUBMIT IN DUPLICATE NGI-11 DESCRIPTION OF WORK COMPLETED HYPOCHLORITE BLEACH & MUD ACID TREATMENTS 10/7/92- RIH & tagged asphaltenes on bottom at 10420' MD. 10/8/92- MIRU CT & PT equipment. Loaded wellbore w/Seawater, then RIH w/CT mounted swirl nozzle & reciprocated the bleach treatment across the perforation intervals at: 9870 - 9900' MD (Z4) 9906 - 10098' MD (Z4) 10110 - 10130' MD (Z3) 10150 - 10160' MD (Z2) 10190 - 10200' MD (Z2) 10212 - 10232' MD (Z1) 10264 - 10280' MD (Z2) 10304 - 10318' MD (Z1) Ref. Log: BHCS 2/28/78. Jetted 46 bbls NaHCO3 Buffer solution @ 2.25 bpm, to stir up 'liquid casing' (peanut hulls), followed by 34 bbls 5% Hypochlorite Bleach to disolve 'liquid casing', followed by 35 bbls Seawater displacement @ 2.2 bpm, followed by 15 bbls Seawater at 0.5 bpm for 30 minutes to push bleach & liquid casing downhole. Pumped Seawater down CT backside @ 1 bpm, while injecting 50 bbls Seawater down CT @ 2 bpm, to displace all bleach through the perforations. Switched back to jetting 21 bbls 5% Hypochlorite Bleach @ 2 bpm, followed by 11 bbls NaHCO3 Buffer solution @ 1 bpm, followed by Seawater down CT backside @ 2 bpm, while jetting 55 bbls Seawater through the CT @ 1 bpm, followed by 281 bbls 1% NH4CI freshwater down backside. Removed bleach tankers from location, then moved in acid tankers & opened to CT. Started pumping. 100 bbls 75% Diesel/25% Xylene down CT @ 2.3 bpm, while pumping 1% NH4CI Water down CT backside @ 1 bpm, followed by 263 bbls 7.5% HCI jetted across perfs @ 4 bpm, while pumping 1% NH4CI Water down CT backside @ 1 bpm, followed by 231 bbls 6.5% HCI - 1.5% HF @ 3.75 bpm, while pumping 1% NH4CI Water down CT backside @ 1 bpm, followed by 225 bbls 1% NH4CI Water down CT @ 3.2 bpm, while pumping 1% NH4CI Water down CT backside @ 6 bpm, to displace acid through the perforations. POOH w/CT. Rigged down. Returned well to gas injection & obtained a valid injection rate. RECEIVED NOV - 2 !992 Oil & Gas Cons. r¢omrcissio~' Anchorage STATE OF ALASKA 0 ~ I~ I ~ A ~ ALASKA ...... AND GAS CONSERVATION CC ..... ~ISSION APPLICA', FOR SUNDRY APr-ROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate X Change approved program Pull tubing Variance Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 254' FSL & 890' FWL, Sec. 1, T11N, R14E, UM At top of productive interval 917' FWL & 1017' FEL, Sec. 2, T11N, R14E, UM At effective depth 800' FNL & 1054' FEL, Sec. 2, T11N, R14E, UM At total depth 800' FNL & 1054' FEL, Sec. 2, T11N, R14E, UM RECEIVED S E P 1 1992 Alaska 0ii & Gas Cons. Commission ~chorage 6. Datum of elevation(DF or KB) 44'RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number NGI-11 9. Permit number 77-80 10. APl number 50 - 029-20283 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10496 feet 8610 feet Plugs(measured) Fill @ 10434' MD ( 8/6/92 tag) Effective depth: measured 10434 feet true vertical 8555 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 95' 20" 325 sx Arcticset II 95' 95' Su dace 2697' 13-3/8" 6200 sx Permafrost II 2744' 2744' Production 9487' 9-5/8" 800 sx Class G 9544' 7797' Liner 1293' 7" 400 sx Class G 9203-10496' 7518-8610' Perforation depth: measured 9870-9900'; 9906-10098'; 10110-10130'; 10150-10160'; 10190-10200'; 10212-10232'; 10264-10280'; 10304-10318' true vertical 8070-8095'; 8100-8264'; 8274-8291'; 8308-8317'; 8342-8351'; 8361- 8378'; 8406-8420'; 8441-8453' Tubing (size, grade, and measured depth) 7", 26~, L-80 @ 8875' MD; 5-1/2", 17#, 13-Cr 80 Tbg @ 9008' MD Packers and SSSV (type and measured depth) Baker SABL-3 packer @ 8943' MD; Otis MRB Nipple @ 2209' MD 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation 15. Status of well classification as: September 1992 16. If proposal was verbally approved Oil Gas Suspended Name of approver Date approved Service Injector 17. I hereby certify that the for?~oing is true and correct to the best of my knowledge. Signed ~ Title Sr. Area Operations Engineer Date FOR COMMISSION U~E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance IApproval No.~,~_ ._ . - Mechanical Integrity Test Approved by order of the Commissioner Subsequent form required lO- Origina. I signed Dy Da¥id W. johnston Commissioner Date Form 10-403 Rev 06/15/88 one/4 ~ r%DD n,~. C~%AI I%AID SUBMIT IN TRIPLICATE / NGI- 11 Stimulation ARco Alaska, Inc. proposes to pump a hypochlorite (bleach) treatment to remove the lost circulation material "Liquid Casing" (peanut hulls) on well NGI- 11. To control fluid loss during the recent rig workover a Liquid Casing kill pill was pumped on well NGI-11. The pill was effective at preventing excessive fluid loss during the workover. Following the hypochlorite treatment a mud acid treatment will be pumped to ensure that the injectivity of this well is restored. A brief description of the proposed work for this well is as follows: 1. Load well with 500 Bbls 2% NaC1. 2. RU S/L. Pull SSSV. Drift tubing. 3. RU CTU, pump units, and fluid tanks. 4. Pump bleach treatment consisting of the following volumes: 5% Hypochlorite Buffer Solution 2% NaC1 Fresh Water 60 Bbls 60 Bbls 190 Bbls 5. RD bleach transports and rig up acid transports. 6. Pump acid stimulation down coil tubing, jetting across the perforations. Treatment volumes are as follows: 75% Diesel/25% Xylene 7.5% HC1 6.5%/1.5% HC1/HF Mud Acid 1% NH4C1 100 Bbls 250 Bbls 250 Bbls 600 Bbls 7. RD CTU, rerun SSSV, and return the well to injection. ,RECEIVED S E P 1 199J Alaska Oil & Gas Cons. Commission Anchorage 6 5 4 2 CO I L ED TUB INO UN 1 T BOP EOUIPHEN~' 1. 5000 PS1 ?" WELLHEAD CONNECTOR rL~G£ 2. 5000 PSI 4 1/1~" PiP[ RAMS 3. 5000 PSI 4 -1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 '1/6" SHEAR RAMS; 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX EEEIVED 0il & Gas Cons. Commission Anchorage H]REL]NE BOP EOU]PHENT - III I I I I II I 1. 5000 PSI ?" W[LLHr. AD CONN£CIOR FLANGE 2. 5000 PS1 WIR[LIN[* RAIDS (VARIABLE SI:Z[) 3. 5000 PSI 4 1/6" LUI3RICA'~OR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF STATE OF ALASKA ALAo~A OIL AND GAS CONSERVATION COMMISS~,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pluggingm Pull tubing X Alter casing Repair well Perforate , Other x Fish 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 254' NSL, 890' EWL, SEC. 1, T11N, R14E, UM At top of productive interval 919'SNL, 1017'WEL, SEC. 2, T11N, R14E, UM At effective depth N/A At total depth 611' SNL, 1097' WEL, SEC. 2, T11N, R14E, UM 5. Type of Well: Development.. Exploratory Stratigraphic Service X 6. Datum elevation (DF or KB) KBE --44 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number NGI- 11 9. Permit number/approval number 77-8O/92-189 10. APl number 50-029-20283 11. Field/Pool __Pru_.dho_e B_..av~ ~iql~O~L~ool 12. Present well condition summary Total depth: measured 10496 feet Plugs (measured) true vertical 8610 feet S F. P - 9 199 Effective depth: measured 10425 feet Junk (measured) true vertical 8549 feet Alaska 0il & Gas Cons. bomm,SS-O~ Anchorage Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 95' 20" 325 sx Arcticset II 95' 95' Surface 2744' 13-3/8" 6200 sx Permafrost II 2744' 2744' Intermediate Production 9544' 9-5/8" 800 sx Class "G" 9544' 7797' Liner 1293' 7" 400 sx Class "G" 10496' 8610' Perforation depth: measured 9870'-9900', 9906'-10098', 10110'-10130', 10150'-10160', 10190'-10200', 10212'-10232', 10264'- 10280', 10304'- 10318' true vertical 8070'-8095', 8100'-8264', 8274'-8291 ',8308'-8317', 8342'-8351 ', 8361 '-8378', 8406'-8420', 8441 '-8453' Tubing (size, grade, and measured depth) 7", 26#, L-80 to 8875'MD; 5-1/2", 17#, CR-80 8875'-9008'MD Packers and SSSV (type and measured depth) 9-5/8" Baker SABL-3 packer @ 8943'MD; 7" Otis "MRB" Nipple w/Dummy @ 2210' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation · Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil Gas Suspended Service Gas Injector 17. I hereby certify that the foregoing is tr,,ue and correct to the best of my knowledge. Signed i/~'~L,.~" ~"~.~--"/ ~-~'~ TitleDrii/in~EnginoorSupervisor Form 10-4d4 Rev (~)/15/88 ~] ~1 ~ SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: NGI-11 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50-029-20283 PERMIT: APPROVAL: ACCEPT: 07/25/92 06:07 SPUD: RELEASE: 08/04/92 01:08 OPERATION: DRLG RIG: NONE WO/C RIG: AUDI 4 07/26/92 (1) TD: 0 PB:10453 07/27/92 (2) TD: 0 PB:10453 N/U BOPE. MW: 8.5 Seawater RIG ACCEPTED @ 18:00 HRS, 7/25/92. R/U LINES TO TREE. R/U LUB. PUMP DN ANNULUS. CIRC DN TBG. MONITOR WELL. SET BPV. N/D TREE. N/U BOPE. L/D 7" TBG. MW: 8.5 Seawater N/U BOPE. TEST BOPE. PULL TBG FREE. CIRC. POOH. L/D 7" TBG. 07/28/92 (3) TD: 0 PB:10453 CIRC. MW: 8.5 Seawater POOH. L/D TBG. TEST BOPE. RIH W/ BHA 31. TAG FISH @ 8947'. JAR ON FISH. FISH FREE. CBU. 07/29/92 ( 4) TD: 0 PB:10453 RIH W/ BHA #3. MW: 8.5 Seawater POOH. L/D PBR. RIH W/ BHA #2. TAG FISH @ 8950'. WASH & MILL TO 8965'. POOH. L/D BHA #2. RIH W/ BHA #3 07/30/92 (5) TD: 0 PB:10453 07/31/92 (6) TD: 0 PB:10453 08/01/92 ( 7) TD: 0 PB:10453 08/02/92 (8) TD: 0 PB:10453 POOH W/ PKR. MW: 8.5 Seawater RIH W/ BHA #3. LATCH ONTO FISH. ROTATE K-ANCHOE FREE. POOH. L/D FISH, BHA. RIH W/ BHA #4. TAG PKR @ 8971'. MILL ON PKR F/ 8971'-8974'. PKR FREE. CBU. POOH W/ PKR. POOH W/ BHA #5. MW: 8.5 Seawater POOH. L/D PKR. RIH W/ TEST PKR. SET @ 2360' TEST CSG. RIH TO 2500' TEST CSG. POOH. L/D TEST PKR. RIH W/ BHA #5. TAG FILL @ 10051'. WASH F/ 10051'-10123' TAG FISH @ 10123'. JAR FREE. POOH 8 STDS. HOLE SWABBING. CBU. CIRC THRU CHOKE. POOH. DRILL OUT FILL. MW: 8.5 Seawater POOH. L/D FISH. RIH W/ BHA #6. WASH ON JUNK F/ 10051'-10165'. WELL FLOWING. SHUT IN WELL. CIRC THRU CHOKE. DRILL JUNK F/ 10165'-10329'. WELL FLOWING. SHUT ION WELL. CIRC THRU CHOKE. DRLG JUNK F/ 10329'-10398' M/U BHA #8. MW: 8.5 Seawater DRLG F/ 10398'-10425'. CBU. POOH. L/D BHA. RIH W/ BHA #7. CBU @ 10425'. POOH. L/D BHA. M/U BHA #8. WELL : NGI-11 OPERATION: RIG : AUDI 4 PAGE: 2 08/03/92 (9) TD: 0 PB:10453 08/04/92 (10) TD: 0 PB:10453 08/05/92 (11) TD: 0 PB:10453 TEST BOPE. MW: 8.5 Seawater RIH W/ BHA #8. SET TEST PKR @ 9249'. TEST CSG, LNR LAP. OK. PULL PKR TO ABOVE LNR TOP. DISP WELL W/ SEAWATER. POOH. LD/ DP. TEST BOPE. N/D BOPE. MW: 8.5 Seawater LD/ TEST PLUG. RIH W/ 7" TBG, BAKER 'SABL-3' PKR. M/U TBG HGR. LAND TBG. PUMP 50 BBLS DIESEL DN ANNULUS. SET PKR W/ 4000 PSI @ 8943'. TEST ANNULUS. SET BPV. N/D BOPE. RIG RELEASED. MW: 8.5 Seawater N/ BOPE. N/U TREE. TEST TREE. SECURE WELL. RIG RELEASED @ 13:00 HRS, 8/4/92. NOTE: RIG WAS NOT RELEASED AS WAS STATED IN YESTERDAY'S MORNING SUMMARY. RECEIVED MORNING REPORT FOR 8/4/92 LATE. TODAY'S MORNING SUMMARY IS CURRENT. NOTE: OTIS 'MRB' SSSV @ 2210'. BAKER 'SABL-3' PKR @ 8943'. TT @ 9008'. SIGNATURE: (drilling superintendent) DATE: RECEIVED S E P - 9 ' 992 Alaska 0il & Gas Cons. Anchorage /3 ARCO ~l~_sk_~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-31-92 REFERENCE: 1-13 ?1-13~° 2-31 q/- 3~' 3-35 11-7 1-1~T ARCO CASED HOLE FINALS 7-12-92 CCL/Perf Run 1, 7-18-92 CCL/Perf Run 1, 7-6-92 Prod/Press/Spin/Temp/Trap Run 1, 7-6-92 CCL/Perf Run 1, 7-13-92 C~L/Perf Run 1, 7-12-92 CCL/Perf Run 1, 7-13-92 CCL/Perf Run 1, 7-11-92 CCL/Tubing Cutter Run 1, 5-30-92 MAI Acoustic Filtered Waveforms Run 2, 5-30-92 BHC MAI Comp Slowness Curves Run 2, 7-11-92 PFC/GR Run 1, 7-13-92 Collar/Perf Run 1, 7-12-92 PFC/GR. Run 1, 7-12-92 CCL/Perf RI~n 1, 7-19-92 CCL/Tubing Cutter Run 1, 5" Atlas 5" Atlas ~' Sch 5" Atlas ~' Atlas 5" Atlas ~' Atlas 5" Atlas ~' Atlas 2~' & i~' Atlas I~' Atlas 5" Atlas ~' Atlas 5" Atlas i~' Atlas Please sign and return the attached copy as receipt of data. RECEIVED BY .... Have A Nice Day! Sonya Wallace - ATOo1529 # CENTRAL FILES # CHEVRON D&M : · # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO R£C£1V£D AUG 1 0 1992 Alaska 01~ & GaS cons. commission Anchorage 0 R I G IN A ALAo~A OIL AND GAS CONSERVATION C;OMMISS~N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well __ Plugging Time extension __ Stimulate __ Change approved program __ Pull tubing x Variance __ Perforate __ Other x Fish 2. Name of Operator ARCO Alaska, Inc. 3. Address P. Oo Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 254'NSL, 890'EWL, SEC. 1, T11N, R14E, UM At top of productive interval 919'SNL, 1017' WEL, SEC. 2, T11N, R14E, UM At effective depth N/A At total depth 611' SNL, 1097' WEL, SEC. 2, T11N, R14E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service X RECEIVED d u L 1 6 1992 Alaska Oil & Gas Cons. Oommissio~ Anchorage 10496 feet Plugs (measured) 8610 feet 6. Datum elevation (DF or KB) KBE ,,44 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number NGI- 11 9. Permit number 77-8O 10. APl number 50- 029-2O283 11. Field/Pool Prudhoe Bay Field/Oil Pool Effective depth: measured true vertical 10433 feet Junk (measured) 8563 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 95' 20" 325 sx Arcticset II 95' 95' 2744' 13-3/8" 6200 sx Permafrost II 2744' 2744' 9544' 9-5/8" 800 sx Class "G" 9544' 7797' 1293' 7" 400 sx Class "G" 10496' 8610' measured 9870'-9900', 9906'-10098', 10110'-10130', 10150'-10160°, 10190'-10200', 10212'-10232', 10264'-10280', 10304'-10318' true vertical 8070'-8095', 8100'-8264', 8274'-8291 ',8308'-8317°, 8342'-8351 ', 8361 '-8378', 8406'-8420', 8441 '-8453' Tubing (size, grade, and measured depth) 7", 29tt, L-80 to 8944'MD;5-1/2", 1711, L-80 8944;8972'MD; 4-1/2", 12.611, N-80 8986;9024 'MD Packers and SSSV (type and measured depth) 9-5/8" Baker SAB packer @ 8973'MD; 7" Camco Bal-O SSSV @ 2215'MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation 7/18/92 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Gas Injector Suspended 17. I here_by certify that theforegoing is true and correct to the best of my knowledge. Sign~_~_~_~_.~~~___-~ /~ 7)~,'/~,~_. 7z!_/~1 ¢ &,' Title Drilling Engineer Supervisor ~ FOR COMMISSION USE ONLY C~ditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance__ Mechanical Integrity Test~ Subsequent form required 10- ~.O~ Original Signed By Approved by order of the Commission David W. ,Johnston I AD,oval No. _/:,~v r /kpprovlea '~op¥ ?~-;,'7 RetUrned Commissioner Date ¢7 '- J ~- ~ ~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE NGI-11WORKOVER OPERATIONS SUMMARY OBJECTIVES:NGI-11 The main objective is to restore tubing integrity. Secondary objective is to clean out the fish and fill covering the bottom third of the perfs. The scope of work is as follows: Kill well and pull the existing 7" tubing/jewelry. Mill out old packer. Fish the old 4.5" tubing tail and cleanout fill to 10453' PBTD. Run new 7" PC tubing with minimum tubing tail ( less than 30', min. 4.5").. PRE RIG OPERATIONS: . 2. 3. 4. 5. . , 10. 11. Pick up the HANDOVER FORM. Grease all tree and wellhead valves. Test 9-5/8" packoff. RU SLICKLINE AND PULL THE SSSV Bull head kill the well. Cut the tubing in the top third of the 5.5" pup joint immediately below the PBR CaCI completion fluid from the well. Set a backpressure valve in the Gray Gen III tubing hanger. Notify Wireline Supervisor Kennedy/Lach of the intent to move over the well. Pick up Handover form. Remove wellhouse and~ flowlines. Level pad and dig out the cellar. Review rig specific Spilt'Prevention Control and Countermeasure (SPCC) Plan and PBU Seawater and Oil Spill Contingency Plan. Get with Drillsite Operator and review any special provisions under the Drillsite or Flow Station specific SPCC plans in terms of drainage on and around the drillsite. Have wellhead hand ensure gauges on the wellhead system are functional in order to read annulus pressure as well as tubing pressure. Have wellhead hand check Iockdown screws. Circulate the RIG . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. OPERATIONS MIRU. ND/NU/Test BOPE. Pull BPV.. Alaska Oit & Gas Cons. Com~'~ss~' AnCl'~orage Circulate well w/8.5 ppg seawater. Spot Temblok pill if required. Pull hanger to floor. LD tubing, PBR and stub. RIH with shoe and spear with disconnect. Mill and recover the packer tailpipe assembly. RIH and fish out cutoff tailpipe. Cleanout to PBTD. Displace wellbore w/clean inhibited seawater. POOH LDDP. Run 7" completion ass'y Freeze protect and set the packer. Test tubing/casing. ND/NU. Test tree. Secure well. Release rig. /~-~o Alaska Inc,- Prudhoe Ba'-'-':-ield ~Weli NGI-1 1 APl#: 5G029-20283-00 Well. Type: Injector Spud Date: 01-30-78 Completion Date: 09-24-84 New I-'1 Workover i~1 i.:.....,,Original RKB: 44' Hanger Type: Gray Hanger: 18" '.)Top of Sadlerochit: 9866' Maximum Hole Angle: 51-o Angle Through Sad.' 32-o ...... Annulus Fluid: Diesel/10.2# NaCI/CaCI Reference Log: BHCS 02-28-78 Ail Depths are RKB MD to Top of Equipment. Jewelry 1 2215' 1 2 8944' 3 8951' FO @ 2346' 4 8973' 5 8984' FO @ 2475' 6 9024' 9CX34' 7" Camco Bal-o SSSV Nipple ID=5.937" Crossover 7" x 5-1/2" Baker PBR Assembly Baker SAB Packer Crossover 5-1/2" x 4-1/2" Tubing Tail 4-1/2" ELM Tubing Tail: 05-22-87 Fish: 76' of 4 1/2" tubing, Camco DB-6 nipple, Baker SOS, PBTD 10098' (05-22-87) Minimum ID: 4-1/2" Tubing Tail ID=3.958" L 3 4 5 6 10 7 PBTD= 1D453' TD = 10496' 8 9 9 10 11 Casing and Tubing Size Weiaht Grade ~ Bottom ,I;)escri_Dtion - 13-3/8" 72# N-80 0 2744' Casing 9-5/8" 47# JL-95 0 2301' Casing 9-5/8" 47# N-80 2301' 9544' Casing 7" 29# MN-80 9203' 10496' Liner 7" 29# L-80 13 8944' Tubing 5-1/2" 17.# L-80 8944' 8972' Tubing 4-1/2" 12.6# N-80 8986' 9024' Tubing Tail Perforation Data (ELM Depths) Interval Zone FT SPF Date 9870-99[Z] 4 12 4 05-02-79 99[]6-9918 4 12 4 0G22-87 9818-9848 4/3 33 4 05-02-79 9848-9964 3 16 4 05-22-87 9964-9984 3 23 4 05-02-79 9984-1DE:X:)0 3 16 4 05-22-87 IO:Z:D-I~ 3/2 43 4 05-02-79 1D34G lC:X366 2 25 4 05-22-87 10366-1~ 2 23 4 05~32-79 10386-10098 2 12 4 05-22-87 10110-10130 2 23 4 05-02-79 10150-10160 2 10' 4 05-02-79 10190-10203 2 10 4 05-02-79 10212-10232 2 23 4 05-02-79 10264-10280 lB 16 4 05-02-79 10304-10318 lB 14 4 0502-79 Datum 8400'SS= 10307' MD 8500'SS = 10421' MD t ECEIV D JUL 1 6 1992 .Oil.& (]as Cons. Com~nission Comments Aperf Aperf Aperf Aperf Aperf Revision Date: 03-23-92 by ENH Reason: SSSV Correction. Previous Revision: 04-20-88 Well NGI-11 BOP STACK CONFIGURATION ATTACHMENT II 13 5/8", 5000 PSi WP TRIPLE RAM STACK WORKO VER RISER ANNULAR PREVENTER ! PI PE RAMS I I PI PE RAMS i 2" KILL LINE MANUAL HYDRAULIC GATE GATE DRILLING SPOOL "l 4" CHOKE LINE HYDRAULIC 'MANUAL GATE I BLIND RAMS Alaska Oil & Ess Cons. ~ ~n~missio~ Anchora~e~ ARCO Alaska, Inc. Prudhoe Bay ~_,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 4, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 9950] Re: DS NGI-11 Approval No. 8-104 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JMV/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS NGI-11)W1-3 STATE OF ALASKA ALASK,. ,.)IL AND GAS CONSERVATION COMM .51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown C Stimulate ~,~ Plugging L_-! Perforate -' Pull tubing Alter Casing -q Other ~ 2. Name of Operator ARCO Alaska, [nc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of wellatsurface 254' FSL & 890' FWL, Sec. 1, TllN, R14E, UM Attop of productiveinterval 917' FWL & 1017' FEL, Sec. 2, TllN, R14E, UM Ateffective depth 800' FNL & 1054' FEL, Sec. 2, TllN, R14E, UM Attotaldepth 800' FNL & 1054' FEL, Sec. 2, TllN, R14E, UM 5. Datum elevation (DF or KB) 47' RKB Feet 6. Unit or Property name Prudhoe Bay Uni. t 7. Well number NG[-11 (41-2-11-14) 8. Approvalnumber 8-104 9. APInumber 50-- 029-20285 10. Pool Sadlerochit · Present well condition summary Total depth: measured true vertical 10496 feet 8610 feet Effective depth: measured 10453 true vertical 8572 Casing Length Size Conductor 95 ' 20" Surface 2697 ' 13-3/8" Production 9487 ' 9-5/8" Liner 1293 ' 7" feet feet Plugs (measured) Junk (measured) Cemented Measured depth 325 sx Arcticset II 95' 6200 sx Permafrost II 2744' 800 sx Class G 9544' 400 sx Class G 9203-10496' True Vertical depth 95' 2744' 7797' 7518-8610' Perforation depth: measured true vertical 9870-9900'; 9906-10098'; 10110-10130'; 10150-10160'; 10190-1020 10212-10232'; 10264-10280'; 10304-10318' 8070-8095'; 8100-8264'; 8274-8291'; 8308-8317'; 8342-8351'; 8361-8378'; 8406-8420'; 8441-8453' Tubing (size, grade and measured depth) 7" 29# MN-80 to 8777' , , 5~" 17# N-80 @ 8777-8959' MD 2 , , Packers and SSSV (type and measured depth) 4½", 12.6#, L-80, 8959-9099' MD Baker SAB packer @ 8973' FE)/Camco SSS¥ @ 2215' lv~ 12. Stimulation or cement squeeze summary Intervals treated (measured) Attached Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average ~.e~e~,~¢e~...~ Injection Data OiI-Bbl Ml~~f Water-Bbl Casing Pressure Tubing Pressure -- 168 .... 3900 196 .... 3900 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run i7~ 15. I hereby oertify that the foregoing is true and correct to the best of my knowledge '~¢¢¢¢~f~ Title 2~6~5 6" 58~~'~~' Signed ~ Form 10-404 Rev. 12-1-85 NEL%S2/62 3. ~, Vitucc-i, - 3 0'; ~~ Date ~/.~ Submit in D[~plicate ~ NGI 11 12% HCI-3% HF MATRIX ACID STIMULATION ARCO Alaska Inc. performed the following mud acid matrix acid stimulation on Well NGI 11 on 3/19/88' 1. MI and RU pump trucks, transports, and N2 unit. 2. Stimulated the well as follows: A. 50 bbls of 50/50 methanol/water B. 175 bbls of hot water C. 1000 gals of xylene nitrified w/1000 SCF N2/bbl D. 4000 gals of 12% HCI w/additives E. 3000 gals of 12% HCI-3% HF w/additives F. 3000 gals of 2% NH4Cl water G 300 bbls of foam consisting of 100 bbls of 2% NH4CI water gelled w/HEC polymer and 2500 SCF N2/bbl water H. 1000 gals of xylene nitrified w/1000 SCF N2/bbl I. 3000 gals of 12% HCI w/additives J. 6000 gals of 12% HCI-3% HF w/additives K. 200 bbls of 50/50 methanol/water 3. RD and released equipment. Returned well to injection immediately. 4. Tested well for new injection capacity. --- STATE OF ALASKA -- ALAS,-,,-, OIL AND GAS CONSERVATION CPM .... SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown C Stimulate ,~ Plugging -~ Perforate - Pull tubing . Alter Casing .~ Other ~ 2. Name of Operator ARCO Alaska~. Inc. 3. Address P.O. Box 100360, AnchOrage, AK 99510 4. Location of well at surface 254' FSL & 890' FWL, Sec. 1, TllN, R14E, UM At top of productive interval 917' FWL & 1017' FEL, Sec. 2, TllN, R14E, UM At effective depth 800' FNL & 1054' FEL, Sec. 2, TllN, Ri4E, UM At total depth 800' FNL & 1054' FEL, Sec. 2, TllN, Ri4E, UM 5. Datum elevation (DF or KB) 47' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-11 (41-2-11-14) 8. Approval number 8-104 9. APl number 50-- 029-2028~'$ 10. Pool Sadlerochit 11. Present welt condition summary Total depth: measured true vertical Effective depth: measured true vertical 10496 feet Plugs (measured) 8610 feet 10453 feet 8572 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 95' 20" 325 sx Arcticset II 95' 95' Surface 2697' 13-3/8" 6200 sx Permafrost II 2744' 2744' Production 9487' 9-5/8" 800 sx Class G 9544' 7797' Liner 1293' 7" 400 sx Class G 9203-10496' 7518-8610' Junk(measured) Perforation depth: measured 9870-9900'; 9906-10098'; 10110-10130'; 10150-10160'; 10190-1020 10212-10232'; 10264-10280'; 10304-10318' true vertical 8070-8095'; 8100-8264'; 8274-8291'; 8308-8317'; 8342-8351'; 8361-8378'; 8406-8420'; 8441-8453' Tubing (size, grade and measured depth) · 7", 29#, MN-80 to 8777' 5½" 17# N-80 @ 8777-8959' MD Packers and SSSV (type and measured depth) 4½", 12.6#, L-80, 89~'~909r9'~ ~ ," ~ .i., ? ~ 1vID., Baker SAB packer @ 8973' MD/Camco SSSV @ 2215' MD .... ~'-'~ ,¢ ':_,' .' i 12. Stimulation or cement squeeze summary Intervals treated (measured) Attached Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average ~ Injection Data OiI-Bbl ~~,¢ Water-Bbl Casing Pressure -- 168 .... 196 Tubing Pressure 3900 3900 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title ~2/6/~5_6 58~~ //'~' Form 10-404 Rev. 12-1-85 WDLLS2/62 ~T. I,{. V'itucci, 3 Submit in Duplicate NGI 11 12% HCI-3% HF MATRIX ACID STIMULATION ARCO Alaska Inc. performed the following mud acid matrix acid stimulation on Well NGI 11 on 3/19/88' 1. MI and RU pump trucks, transports, and N2 unit. 2. Stimulated the well as follows: A. 50 bbls of 50/50 methanol/water B. 175 bbls of hot water C. 1000 gals of xylene nitrified w/1000 SCF N2/bbl D. 4000 gals of 12% HCI w/additives F_ 3000 gals of 12% HCI-3% HF w/additives F. 3000 gals of 2% NH4CI water G 300 bbls of foam consisting of 100 bbls of 2% NH4CI water gelled w/HEC polymer and 2500 SCF N2/bbl water H. 1000 gals .of xylene nitrified w/1000 SCF N2/bbl I. 3000 gals of 12% HCI w/additives J. 6000 gals of 12% HCI-3% HF w/additives K. 200 bbls of 50/50 methanol/water 3. RD and released equipment. Returned well to injection immediately. 4. Tested well for new injection capacity. ARCO Alaska, Inc. Prudhoe Bay =r~gineering Post Office E~o× 100360 Anchorage, A~aska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: NGI-11 Permit No. 77-80 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JMV/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(NGI-11)W1-3 to be RECEI /EO ~las~ 0ii & Gas Cons. c0mmi~a Anchorage . : WELLS2/60 ARCO Alaska, Ibc. is a Subsidiary of Atlan',icRichfieldCompany AR3B 6132-C ...... STATE OF ALASKA ALA,.~ .A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate Pull tubing [] Amend order [] Perforate ~ Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 254' FSL & 890' FWL, Sec. 1, TllN, R14E, UM At top of productive interval 917' FWL & 1017' FEL, Sec. 2, TllN, R14E, UM At effective depth 800' FNL & 1054' FEL, Sec. 2, TllN, R14E, UM At total depth 800' FNL & 1054' FEL, Sec. 2, TllN, R14E, UM 47' RKB 6. Unit or Property name feet Prudhoe Ba~ Unit 7. Well number NGI-11 (41-2-11-14) 8. Permit number 77-80 9. APl number 50-- 029-2028~ 10. Pool Sadlerochit 11. Present well condition summary Total depth: measured true vertical 10496 feet 8610 feet Effective depth: measured 10453 true vertical 8572 Casing Length Size Conductor 95 ' 20" Surface 2697 ' 13-3/8" Production 9487 ' 9-5/8" Liner 1293 ' 7" feet feet Plugs (measured) Junk(measured) Cemented Measured depth True Vertical depth 325 sx Arcticset II 95' 6200 sx Permafrost II 2744' 800 sx Class G 9544' 400 sx Class G 9203-10496' 95' 2744' 7797' 7518-8610' Perforation depth: measured 10212-10232'; 10264-10280'; 10304-10318' true vertical 8070-8095'; 8100-8264'; 8274-8291'; 8308-8317'; 8361-8378'; 8406-8420'; 8441-8453' ~bing(size, grade and measured depth) 7", 29#, MN-80 to 8777' 5½", 17#, N-80 @ 8777-8959' MD Packers andSSSV(typeand measured depth) 4~", 12.6#, L-80, 8959-9099' MD Baker SAB packer @ 8973' MD/Camco SSSV @ 2215' MD 12.Attachments 9870-9900'; 9906-10098'; 10110-10130'; 10150-]0160'; 10190-1020( Description summary of proposal [] Detailed operations program s34 - 3 'l;V ED BOP sketch A~Achorage 13. Estimated date for commencing operation February 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereb~/~ertify ~7/~the~foreg..oing is true and correct to the best of my knowledge Signed .¢~/,~~~ Title Operations Engineering Manager Commission Use Only Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI ~'~ '~ Approved Copy ,:;,,~leee* ORIGINAL SIGNED BY ~- ~' ~ --¢ ~ ~ by order of c. Comm , o, r the oomm s o. Form 10-403 Rev 12-1-85 WELLS2/62 J. M. Vitucci Submit in triplicate NGI 11 12% HCI-3% HF MATRIX ACID STIMULATION ARCO Alaska Inc. proposes to perform the following mud acid matrix acid stimulation on Well NGI 11' 1. MI and RU pump trucks, transports, and N2 unit. 2. Stimulate the well as follows: A. 50 bbls of 50/50 methanol/water B. 200 bbls of hot water (140-150°F) C. 1000 gals of xylene nitrified w/1000 SCF N2/bbl D. 4000 gals of 12% HCI w/additives E. 3000 gals of 12% HCI-3% HF w/additives F. 3000 gals of 2% NH4CI water G 300 bbls of foam consisting of 100 bbls of 2% NH4CI water gelled w/HEC polymer and 2500 SCF N2/bbl water H. 1000 gals of xylene nitrified w/1000 SCF N2/bbl I. 3000 gals of 12% HCI w/additives J. 6000 gals of 12% HCI-3% HF w/additives K. 200 bbls of 50/50 methanol/water 3. RD and release equipment. Return well to injection immediately. 4. Test well for new injection capacity. Cons. Anchorage 99~ t ('-' DATE' ?-I-RR RFFERENCE' ARCO CA~ED Hnl.F FINAl.. '",, i-? ""'4.-t7 ""-' 7-1 ~ "'-N .F, T-~ "-, KI; T -'~ ~N G T - A -'-. ~ NI~:,I-t ? -'~ NGT-t 4 ~ wr; I-2 F'I .FEn2E .? R'EC..E I rED HnV:F.. n N 6-22-R7 COl. A-2¢-R7 Iq. fi I. 6-20-q7 CRI.. R-t ~-R7 r:. RI. R-i 4-R? ROI.. R-24-R7 tZf]I. .5-4-R7 P, FII.. 5-~--g7 CRI... ~,- ,-) .. ..,-.,.-.R7 ~,-.9. -R7 r. nl. ~-2~-~'7 c0~. 5-?4-8? c01. %-o4-~7 c01.. .... ,,% I AP ,/F'F--'RFFiRAT T [71N [ AR (PARKFR) IAI:;' I. ~R'/F'FRFRRTT RN 1., ~R'/F'EERFORAT ~ I. ~R'/F'FRFF]R'AT T ~N I AR'/PERF'~RATTRN I A~'/PFRFORATTON I...~ R/F'ERF[1R'~T T ON I. AR/F'ERFRR'AT T fin I..AN'/F'ERFE1RATT I. AR/PFRFF1RATTON I AR/F'F]R'FRITAT];FIN I AR'/PFRF'RITATT ON R Jig 17 IN Fi' IN 17 IN R IN R IN R' IN R IH R IN ~1' .IN R IN 17 IN 17 IN 5-25-R7 RRI..I.. AI-7/F'F. Iq'FF!I-TATT. Ri'J RI.IN t . 5-25-87 /1 CO~.AR/F'pF,'FOE'ATTFIN R'!lKI t , E~IJ ~./~~~ ~C f..~ \ / ~ U~ ~ -~'--~?'~ ' I [.,E ~ '~ F' E7 F- f} Y BENNETT ATf]- t . ..,' ..:.. I A F' F'I7 0 V -.F..I) 'lb ]' .CTR' T RI .IT T P F;'F S 2 F F,.' n R'F.C.% F R' D R' E.% X' tr F;,' D R I:'.% $,' F I-7 ~ CENTRAl_ F]'I.E2 ~ CHEVRON P ~ H · ~: EXTENXTON FXF't.,NRATTRN MAR'ATHON ~' MO~TL_ ~ F't411. I... T. F'~ F'R WFI..I FTI.. F? F,.' & P -,,-'"' ZAP[: '"/,.: .CTATF F!F AI..A,?KA STATE OF ALASKA AL, ,,SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate I-q Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, ]:nc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 254' FSL & 890' FWL of Sec. 1, T11N, R14E, UM At top of productive interval 917' FWL & 1017' FEL of Sec. 2, T11N, R14E, UN At effective depth 800' FNL & 1054' FEL of Sec. 2, T11N, R14E, UN At total depth 611' FNL & 1097' FEL of Sec. 2, T11N, R14E, UN 5. Datum elevation (DF or KB) 44' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well ~_b~ (41-2-11-14) 8. Approval number 7-225 9. APl number 5O-- 029-20285 10. Pool Sadlerochit 11. Present well condition summary Total depth: measured true vertical 10496 feet 8610 feet Effective depth: measured 10098 true vertical 8264 Casing Length Size Conductor 77' 20" Surface 2726' 13-3/8" Production 9526' 9-5/8" Liner 1293' 7" Plugs (measured) feet Junk (measured) feet None 10098' - Fill & Fish Cemented Measured depth 325 sx Arcticset II 95' 6200 sx Permafrost II 2744' 800 sx Class G 9544' 400 sx Class G True Vertical depth 95' 2744' 7797' 9203'-10496' 7518'-8610 Perforation depth: measured 9870-9900', 9906-10098', 10110-10130', 10150-10160', 10190-1020 10212-10232', 10264-10280', 10304-10318' true vertical 8070-8095', 8100-8264', 8274-8291 ', 8308-8317', 8342-8351' 8361-8378', 8406-8420', 8441-8453' Tubing (size, grade and measured depth) 7", 29#, MN-80, ABM 8rd to 8777'MD 5½", 17#, N-80 ABM 8rd @ 8777'-8959'MD 4½", tailpipe, 8959'-9099'MD Packers and SSSV (type and measured depth) 9-5/8" x 5½" Baker SAB Packer @ 8971'MD/Camco SSSV @ 2222'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 5/19/87 -- 151423 .... Prior to well operation Subsequent to operation 5/28/87 -- 155554 .... Tubing Pressure 3745 3763 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ,~.:. 2.~-'- ~/...~.?~ Signed q~_ ¢~>~/'~2~ J TitleOperations Engineering Manager Date Form 10-404 Rev. 12-1-85 Submit in Dupli.cate~)¢"- NGI-11 ADD PERFS Daily Report of Well Operations 5/22/87 PT BOP/lub to 4500 psi. OK. Pull SSSV. PT lub/Rams to 400 psi. OK. RIH w/ 3-3/8" Dummy Gun, 1-1/4" DD Bailer and TTL. Tag bottom @ 10116' WLMD. POOH - Sample is hard asphaltenes w/some fill. PT hard line to 4000 PSI. OK. Pump in diesel/xylene wash - spot xylene across perfs. PT BOPs to 4500 PSI, l ub/rams to 4000 PSI. OK. RIH w/ Gun #4, 26', 3-3/8", 4 SPF, 120° phasing. Shoot 10040-10066' POH - All shots fi~ed. PT lub/rams to 4000 PSI. OK. RIH w/Gun #5, 22' (6' + 16'), 3-3/8", 4 SPF @ 120° phasing. Lost drum brakes @ 10' out of lubricator. POH - repaired brakes. 5123/.87 RIH w/ Gun #5. Shoot 9984-10000' (16'). Shoot 9912-9918' (6'). POH - all shots fi red. PT lub/rams to 4000 PSI. OK. RIH w/Gun #6, 22' (6 + 16'), 3-3/8", 4 SPF @ 120° phasing. Shoot 9948-9964 (16'). Shoot 9906-9912 (6'). POH - all shots fi red. PT lub/rams to 4000 PSI. OK. RIH w/modified Gun #3, 12', 3-3/8", 4 SPF @ 120° phasing. Shoot 10086-10098. POH - all shots fired. PT lub/rams to 4500 PSI. OK. RIH w/SSSV & set @ 2201. Pressure up to 4400. OK. POH. STATE OF ALASKA ALAS~,,~, OIL AND GAS CONSERVATION COMN,. ~,.qlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other 2. Name of Operator ARCO Alaska: Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 254' FSL & 890' FWL of Sec. 1, T11N, R14E, UM At top of productive interval 917' FWL & 1017' FEL of Sec. 2, T11N, R14E, UM At effective depth 635' FNL & 1091' FEL of Sec. 2, T11N, R14E, UM At total depth 611' FNL & 1097' FEL of Sec. 2~ T11N~ R14E~ UM 11. Present well condition summary Total depth: measured true vertical 10496 feet 8610 feet 5. Datum elevation (DF or KB) 44' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-11 (41-2-11-14) 8. Permit number 77-RQ 9. APl number 50-- 029-20285 10. Pool Sad]erochit Effective depth: measured 10443 true vertical 8563 Casing Length Size Co-du:ctor 77' 20" Surfan~ 2726' 13-3/8" Production 9526' 9-5/8" Liner · 1293' 7" Plugs (measured) 10443' - Cement feet feet Junk (measured) None Cemented Measured depth True Vertical depth 325 sx Arcticset II 6200 sx Permafrost II 800 sx Class G 95' 95' 2744' 2744' 9544' 7797' 400 sx Class G 9203'-10496' 7518'-8610 Perforation depth: measured 9870-9900', 9918-9948', 9964-9984', 10000-10040', 10066-10086' 10110-10130', 10150-10160', 10190-10200', 10212-10232', 10264-10280', 10304-10318' truevertica~ 8070-8095', 8110-8136', 8149-8166', 8180-8214', 8236-8253', 8274-8291', 8308-8317', 8342-8351', 8361-8378', 8406-8420', 8441-8453' Tubing (size, grade and measured depth) 7", 29#, MN-80, ABM 8rd to 8777'MD 5½", 17#, N-80 ABM 8rd @ 8777'-8959'HD az,, tai]pipe 8959'-9099'MD Packers and SSSV (type and measured depth) -~2 , , 12.Attachments Description summary of proposal ~ Detailed operations program El BOP sketch 13. Estimated date for commencing operation May, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I ~ereb~,d~ertify that th~foreg2ing is true and correct to the best of my knowledge Sign6d ~ ~ ~~'/~~~._.~ Title Operations Engineerinq Manaqer Date Conditions of approval Approved by Commission Use Only Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner ] ApprovalNo. by order of the commission Date Form 10-403 Rev 12-1-85 MR0 (265-6810) Submit in triplicate NGI-11 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations within the Sadlerochit interval in Well NGI-11. The proposed perforation intervals are as follows: Existing Perforations 9870-9900 (30') 9918-9948 (30') 9964-9984 (20') 10000-10040 (40') 10066-10086 (20') 10110-10130 (20') 10150-10160 (10') 10190-10200 (10') 10212-10232 (20') 10264-10280 (16') 10304-10318 (14') TOTAL = 230' Proposed Perforations 9906-9918 (12') 9984-10000 (16') 10040-10056 (16') 10086-10100 (14') 10130-10140 (10') 10232-10242 (10') 10288-10298 (10') TOTAL = 88' Reference CNL of 3/9/78 A 5000 PSI WP wireline lubricator, tested to working pressure, will be utilized for this work. All perforations will be made with hollow carrier-type guns at 4 shots per foot. All perforations will be made with an appropriate fluid, the perforating performed, and gas injection resumed with the wellbore load fluid being displaced into the wellbore formation. No flaring is anticipated. WELL: SURFACE LOCATION: BOTTOM HOLE LOCATION: ORIGINAL RKB': TOP OF SAOLEROCHIT: ALL DEPTHS ARE RKB MD NGI ~11 ...... SPUD DATE: 1/30/78 254'N & 890'~ of SE cr. Sec. l, TllN, Ri4E, UM 61!'S & !097'W of NE cr. Sec. 2, T]IN, R14E, UM 44' RKB TO Gray HANGER 18' ' MD 9865 AVERAGE HOLE ANGLE: 45° MAXIMUM ANGLE: 51.5° @ 74i2' ANGLE AT TD: 28.50 Depths are to TOP of equipment ANNULUS FLUID: L 95~ 20", 94#, N-40 Vetco (I9.i24" ID) w/ 325 sx 2222' Camco SSSV Landing Nipple (4.562" ID) 2301' Bot:om of 9-5/8", 47#, JL-95 BTC (8.681" ID) . 2346' 9-5/8" FO 2475' 9-5/8" FO ~ 274&' 13-3/8", 72#, N-80 BTC (!2.347" ID) w/ 6200 sx 10.8 CaCl2/Oiesel 8446' 9-5/8", ¢7#, N-80 BTC (8.681" ID) 8777' Bottom of 7'l, 29#, MN-80 ABM 8rd (6.184" ID) 8812' Camco Sliding Sleeve (4.437" ID) 8887' Camco DB-5 Landing Nipple (4.313" ID) 892I' Baker SBR Assembly 8959' Bottom of 5½", 17~, N-80 ABM 8rd (4.892" ID) 8971' 9-5/8~' x 5½" Baker SAB Packer 90~1' Camco D8-6 Landing Nipple (3.813" ID, 3.7" No-Go) 9099' Bottom of 4½" Tailpipe (3.958" ID) .. 9203' Top of Liner, BOT MC Hanger 9544' 9-5/8", 47#, S-95 BTC (8.681" iD) w/ 800 sx 9870' - 9900' 9918' - 9948' 9964' - 9984' 10000' - i0040' 10066' - 10086' 10110' - t0130' 10150' - 10160' 10190' - 10200' 10212' - 10232' 10264' - 10280' i0304' - 10318' 10443' !0496' 10496' PBTD 7", 29#, H-80 BTC (6.184" ID) TD WORKOVER-STIMULATION 7/19/79 - Water washed well w/ ~66 bbls. 8/12/79 - Wa~er washed well w/ 391 bbls. 9/12/79 - Water washed well w/ 750 bols. 7/22/83 - Water washed well w/ 500 bbls. w/ ~00 sx 1/84 i i ii i · iii i~ ii i i 3 2 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF H I REL I NE BOP EQU I PHENT .... ": STATE OF ALASKA ..~ ALASK..;_:ILAND GAS CONSERVATION ~ MMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well RECOMPLET I ON ~ OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE~ GAS INJECTION ..? ,, :2. Name of OperatOr 7. Permit Number ARCO Alaska, Inc. 77-80 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20283 ,, 4. Location of well at surface 9. Unit or Lease Name 254' FSL, 890' FWL, Sec.1, T11N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. WelI Number 919' FNL, 1017' FEL, Seco2, T11N, R14E, UM NGI-11 At Total Depth 11. Field and Pool 611' FNL, 1097' FEL, Seco2, T11N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 44' RKBJ ADL 28302 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 01/30/78 03/05/78 03/12/78(perf'd 5/9/79)I N/A feet MSLI 1 17'.'Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10496'MD,8610'TVD 10433'MD, 8563'TVD YES [~ NO [] 2215 feet MDI 1900' (Approx) 22. Type Electric or Other Logs Run GR/CNL/CCL, lES 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 Surf 95' 30" 325 sx Arctic Set II cm' 13-3/8" 72.0# N-80 Surf 2744' 17-1/2" 6200 sx PF II cmt 9-5/8" 47.0# N-80 & Surf 9544' 12-1/4" 800 sx Class "G" J & L-95 7" 29.0# L-80 9203' 10496' 8-1/2" 400 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ,,, 9870' - 9900' 10,190' - 10,200' 7" 8945' 8973' 9918' - 9948' 10,212' - 10,232' 5-1/2" 8973' 9964' - 9984' 10,264' - 10,280' 26. ACID, FRACTURE, CEMENT S~UEEZE, ETC. 10,000 - 10,040' 10,304' - 10,318' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10,066' - 10,086' N/A 10,110' - 10,130' 10,150' - 10,160' w/4 spf, 90° phasing 27. N/A PRODUCTION TEST Date First prOduction I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Teste~l PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE sIZE IGAS-OIL RATIO' TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE Jl~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SUbmit core chips. None RECEIVED Alaska Oil & Gas Co;Is. Con-lmissior; Ancho,~,~ge Form 10-407 JMM/WC26 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. ': "i GEOt'OGi:C'MARKERS ' " · FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sad]erochit 9865' 8066' N/A Base Sadlerochit 10,413' 8537' .. 31. LIST OF ATTACHMENTS Wnrkov~-r .~t ~mmn ry 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ --~.~~'~~~~-~ o Area Dri 1 ling E ngr. Signed 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' Flowin9, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Oil and Gas Company Will History- Initial Report- Dally IM: Prepl~l Ind lubmit the "lnillM I~' o~1 the fi/It Wldneldly Iftef · wMI ia iI~ddld or wo~w~r opiretlone em Itltted. O~ily wow Prtor to al~dcllng IlloUld he ~u~ on the form giving Inclultv~ dltN only. Olat~ct Field Alaska North Slope Borough ADL ~28302 Recompletion Prudhoe Bay Auth. or W.O. no. AFE 303194 Alaska Well Nabors 1-ES AP1 50-029-20283 Operator ARCO Alaska, Inc. Spudded or W.O. begun [Date I Workover Date and depth aa of 8:00 a.m, 9/17/84 9/18/84 9/19/84 9/20/84 9/21/84 9/22/84 thru 9/24/84 The above is correct For form preparation Ind distribution, aee Procedurel MlnUlJ. Section 10, Drilling, Pagea ~ and 87. Complete record for elch dly reported J ARCO w.I, Hour IPrlor ItatUl if a W.O. 9/17/84 0330 Hrs. Accept r.i~ @ 0330 hfs, 9/17/84. Pull BPV. 7" @ 9200'-10,496' 10,443' PBTD, Tst XO flange on top of Hydrl Circ well, set BPV, ND tree, NU &tst BOPE to 250/5000 psi. Att to pull SBR w/o success. Prep to cut 5½" in pup Jt bet 7" x 5-1/2" XO & sliding slv. 7" @ 9200'-10,496' 10,443' PBTD, LD 7" tbg 10.2 NaC1/CaC1 Fin tst'g BOPE & lub. RIH w/tbg cutter to 8890', shoot tbg @ 8804', POH, RD DA. Pull 7" hgr, POH & LD 7" tbg. 7" @ 9200'-10,496' 10,443' PBTD, MU fsh'g tls 10.2 NaC1/CaCI~ Chg rams to 3½" &tst to 250/5000 psi. PU wshpipe, RIH, tag up @ 8980'; no fill, CBU, POH w/wshpipe & LD. PU millover shoe/OS. 7" @ 9200'-10,496' 10,443' PBTD, Jar on fsh 10.2 NaC1/CaC12 RIH w/fsh'g tls, tag fsh @ 8822', mill over 5½" tbg, engage OS, att to rel K anchor @ PBR, POH; no rec'y. RIH w/grapple, wsh over fsh, POH; no rec'y. RIH w/grapple, engage fsh & Jar. 7" @ 9200'-10,496' 10,094' PBTD, RD DA 10.2 NaC1/CaC19 Fin jar on fsh] POH, no rec'y. RIH w/fsh'g assy w/double grapple, engage fsh, POOH, rec'd fsh. RIH w/K-Anchor, wsh thru pkr into 4½" tbS tail, tst DP & plug in tailpipe to 2000 psi; OK. POOH & LD K-Anchor. Chg rams to 7" &tst to 5000 psi. RIH w/223 jts, 7", 8RD tbg & lnd w/SSSV @ 2215', PBR @ 8951', SAB Pkr @ 8973'. ND BOPE NU &tst tree to 5000 psi. Pull BPV. RU DA, RIH w/tbg cutter, cut tbg @ 9024', POH. Joete [ Title 10/09/84 RECEIVED k <}V 2 71 1 4 Anchorage Su~e=$~ce~de~c AR3B,.459-1-D Number stl daily well history forms conlecutlvely aa they L,e prepared for each well. ARCO Oil and Gas Company ,~, Daily Well History-Final Report Instructions: Prepare and submit the "Final Repel't" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Rel~ort" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Rll~ert" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish /State Alaska North Slope Borough J Alaska Field Lease or Unit Well no. Prudhoe Bay ADL #28302 NGI-ll WO Auth. or W.O. no. J T t · AFE 303194 I Recompletion Nabors 1-ES API 50-029-20283 Operator A.R.Co. W.I. ITotal number of wells (active or inactive) on this Icost center prior to plugging and [ ARCO Alaska, Inc, 21,66% labandonment of this well I Spudded or W.O. begun Date IHour I Prlor status if a W,O. Workover 9/17/84 ! 0330 Ers. I Date and depth Complete record for each day reporled as of 8:00 a.m. 9/25/84 7" @ 9200'-10,496' 10,094' PBTD, RI{ 10.2 NaC1 w/±625' diesel cap in tbg & ann Set BPV. RR @ 1030 hfs, 9/24/84. Old TD I New TD PS Depth 10,094 ' Released rig I Date JKind of r g 1030 Hrs. 9/24/84 J Rotary Classifications (oil, gas. etc.) Oil Producing method Type completion (single, dual, etc.) Single Official reservoir name(s) Sadlerochit Flowing Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gal per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR correctedGravity Allowable Effective date , ~'",~ .~_~ 10/09/84 For form preparati .... d distribution, see Procedures Manual, Sectiop 10, Drilling, Pages 86 and 87. AR3B-459-3-C as they are prepared for each well. ARCO Alaska, In Post Office :lox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 23, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: NGI - 11 Dear Mr. Chatterton: Enclosed is Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU2/L31 Enclosures If ARCO Alaska, Inc. is s Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LLx~3 OTHER [] 2. NameofOperator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 254' FSL, 890' FWL, Sec.l, T11N, R14E, UM 7. Permit No. 77-80 8. APl Number 50- 029-20283 9. Unit or Lease Name Prudhoe Bay Uni'r 10. Well Number NGI #11 (41-07-11-1z;) 11. Field and Pool Prudhoe Bay Fi eld 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 44' I ADL 28302 I 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEOUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). Accepted rig @ 0330 hrs, 09/17/84. Set BPV. ND tree. NU BOPE & tstd to 5000 psi - ok. Pulled 7" tubing and hanger. Recovered PBR & "K" anchor. Tstd DP and plug in 4-1/2" tailpipe to 2000 psi - ok. Ran 7" tubing. Pumped 40 bbls diesel down tubing and then equalized w/ann 625'± diesel cap on each side. Set BPV. ND BOPE. NU tree and tested to 5000 psi - ok. RIH and cut tubing @ 9024'. RIH and checked PBTD ~ 10,094'. (SSSV ~ 2215', pkr ~ 8973'.) Set BPV. Secured well and RR @ 1030 hrs, 09/24/84. 14. I hereby certify that t~l~ foregoing is true and correct to the best of my knowledge. Area Drilling Engineer Title Signed __ · . . ~ The space below for Commission use Conditions of Approval, if any: Approved by Form 10~,03 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 GRU2/SN19 and "Subsequent Reports" in Duplicate ARCO Alaska, In Post Office ~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 31, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: NGI #11 Dear Mr. Chatterton: Enclosed pull the Since we earliest question is a Sundry Notice for the subject well. We propose to tubing and repair the well as necessary. expect to start this work on September 10, 1984, your approval will be appreciated. If you have any s, please call me at 263-4610. Si ncerely, hian ...,.x, . .... Are~ Drilling Engineer TLF/JG/tw GRU1/L23 Enclosures ,~RCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Alaska Oil & Gas Cons, Oemmission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] -2. Narne of Operator ARCO Alaska, inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 254' FSL, 890' FWL, Seco1, T11N, R14E, UN 7. Permit No. 77-80 8. APl Number 50- 029-20283 9. Unit or Lease Name Prudhoe Bay liner 10. Well Number 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 44' I ADL 28302 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well ~. Change Plans [] Repairs Made Pull Tubing ~. Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) N61 ~11 (4!-02-!!-!4) 11.FieldandPool Prudhoe Bay Field Prudhoe Bay 0il Pool SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to pull and replace the tubing string and seal assembly in gas injection well NGI #11. The procedure will be as follows: 1. Tubing and annulus circulated with kill weight brine. 2. Tubing and seal assembly pulled. 3. 9-5/8" casing tested and repaired as necessary. 4. New tubing and seal assembly run. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. E ~:~ ~" ~ ~i ,:.'. I ~ Estimated Start: September 10, 1984 :~q,.~..?:~ . .. ~/, ..... g~z~sequ~nt V~ or ~t~ Alaska Oit & GElS t;~:..~. Ocmmissi0n 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Area Dri 11 ing Engineer The-sj~;ce:6'elow for Commis~io'i~ use Cond4'uons of Approval, ff any: ~pproved C~p~ Approved by. COMMISSIONER Form 10-403 GRUi/5N56 R~.v 7-1-80 By Order of the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 1, 1984 Reference: ARCO Cased Hole Finals D.S. 1-9~'~/~ 4-20-84 D.S. 1-10~u,;J 5-4-84 r,~ 4-20-84 ,~ '- D.S. 1-21~.~/ 5-4-84 X~~ D.S. 4-13~/ 4,LimB_4_ / TDT CH CNL TDT CN/MSN/GR CET Log TDT > TDT .~~~--.S. ~18 . 4-28-8~ Run 1 / D.S. 7-26 -~/4-27-84 PLS Run 1 ~ D.S. 9-19~-~ 5-11-84 Collar/Perf Lo9 Run 1 ~ D.S_~. 11-5..~/ 3,29-84 $~!inner/Basket Flw Mtr.. Run 2 ~4 ,~~~ 12-16 ~4 .. T~~ Run 2 ~~ , D.S. 12'17~ 5-20-84 Spinner Run 1 ~~. ~;. D.S. 12-18~4-22-84 TDT Run 2 ~ ~~~D.S. 12-2~75-2-84 ACBL/VDL/Signature/GR Run 1 D.S. 13-1 4-12-84 Spinner Run 1 ~ D.S. 14-2/~ 5-3-84 CN/MSN/GR Run 3 ~~ ~~D.S. 14- .' · _~~ Run 1 Run 1 4-30-84 TDT ~ ~5~i~Y3 Run 1 D.S. 16-8~, 5-10-84 CET Run 1 D.S. 16-9/J 5-13-84' Collar/Perf Run 1 NGI ~11 ~/ 4-17-84 5" Sch Run 5 5" GO Run 2 5" Sch Run 2 5" DA Run 1 5" Sch Run 3 5" Sch Run 1 5" Sch 5" Sch 5" DA 5" DA 5" GO 5" Camco 5" Sch 5" Otis 5" Sch 5" DA 5" Camco 5" DA 5" GO 5" Sch 5" Sch 5" Sch 5" GO CET Run 1 5" Sch EPL Run 1 2" Sch Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. #221 ~hevron D&M Have A Nice Day! DISTRIBUTION · & ¢~s Oons Mob i l · Anchorage Mobil E S P Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Phillips Prudhoe Bay Well Files R & D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 17, 1984 Reference: ARCO Cased Hole Finals D.S. 1-24~ 4-18-84 CFS/Spinner D.S. 6-23 // 4-23-84 CH CNL D.S. 12-28j~ 4-24-84 CH CNL D.S. 13-15 ~ 4-13-84 PLS D.S. 13-9S~(Monitor Well) 11-11-83 DIFL/GR (CH) D.S. 13-98''~' 11-12-83 Carbon/Oxygen Log D.S. 13-98-j 2-12-84 Carbon/Oxygen/GR D.,S. 15-1~~ 4-15-84 CFS/Dift Temp Log nGI ~11/ 4-22-84 Collar/Perf Log Run '~ 5" GO Run 1 5" GO Run 1 5" GO Run 1 5" DA Run 2 5" DA Run 3 5" DA Run 4 5" DA Run 1 5" GO Run 1 2" GO ~gn and return the attached copy Have A Nice Day: as receipt of data. Kelly McFarland ATO-1429F Trans. ~ 183 DISTRIBUTION Chevron D&M Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Mob i 1. Mobil E & P Phillips Prudhoe B/~e 1 carolyn Smith Sohio State of Alaska ARCO Oil and Ga'~*':ompany Al:~s kt~ I~ : :-" ,,": ' ': C'? ~:] ' -' ,."' ....;',C:O ..,i :,. -: :] :- ----..-' . ,, :'~ !-- -,....- -,~.- ~'~rch 24, 1980 Reference' ARCO Pressure Surveys ~~ 2/19/80 Bottomhole Pressure Survey Dresser Atlas NGI~,14 2/12/80 Bottomhole Pressure Survey Dresser Atlas ?,~ease sign and return the attached copy as receipt ~ of data. K. J. Sahlstrom North Engineering TRANSMITTAL # 200 · DISTRIBL~ION North Geology R & D Drilling Eng. Manager D6M Geology State of Alaska Mobil '" ".",,:: ,~ Getty Phillips Sohio Marathon Q~e~on ';~RCO Oil and Gar'~"3mpany North Alaska. Jistricl Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 13, 1980 Mr. Hoyl e Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak 99510 Subject' NGI #11, Permit No. 77-80 Dear Sir' Enclosed please find a Sundry Notice detailing work done on the above-mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer Enclosure ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-403' REV. 1-1(%73 Submit "intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. O,L I--I GAS [--] WELL1 I WELL OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield ComPany 3. ADDRESS OF OPERATOR P.0. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 254'N & 890'E of SW cr Sec 01, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 44' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20283 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudh0e Bay Unit 9. WELL NO. NGI #11 (41-02-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 02, TllN, R14E, UM 12. PERMIT NO. 77-80 3orr, or Other Data NOTICE OF INTENTION TO= TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: r---1 WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENTH ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Dr,.r) Reperforate (NOTEz Report results of multiple completion on Well ComplY:Ion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ~letalls, and give pertinent dates, including estimated date of starting any proposed work. Rigged up to reperf well @ 2300 hrs 2/15/80. Pulled SSSV. Ran gage rng to btm @ 10,336' Perf'd intervals form 10,280'-10,264', 10,232'-10,212' 10,200'-10,190', 10,160'-10,150', 10,130'-10,110' 10 086'-10,066' 10 040'-10,000' 998~'-9964' 9948'-9918' and 9900' 9870' w/4 spf. Ran HP press tool. Ran & set SSSV. Installed & tstd tree cap to 5000 psi. Released well @ 0200 hrs 2/21/80. SIGNED..?-;- ~, _ . TITLE District Drillina Engineer DATE 3/1 4./Rll (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side ARCO Oil and Gr'~ompany North Alas,~ _ Disirict Post Office Bo;,< :360 Anchorage, Alaska 99510 'Telephone 907 277 5637 February 12, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservati on Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 Subject- NGI #11, Permit No. 77-80 Dear Sir' Enclosed please find a Sundry Notice detailing work done on the above-mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'cs Enclosure ARCO Oil and Gas Company is a Division of AtlanlicRichfieldCompany Form 10-403 REV. 1-10-73 Submit '1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL ~ OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 5. APl NUMERICAL CODE 50-029-20283 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360 Anchorage, Alaska 99510 NGI #11 (41-02-11-14) 4. LOCATION OF WELL At surface 254'N & 890'E of SW cr Sec 01, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 44' RKB Check Appropriate Box To Indicate Nature of Notice, Re 14. 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 02, TllN, R14E, UM 12. PERMIT NO. 77-80 )ort, or Other Data NOTICE OF INTENTION TO.' FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) - , ~, ,u, (x~ REPAIRING WELL ~ ALTERING CASING ~_~ ABANDONM ENT~____~ (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ¢letalls, and give pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Company proposes to reperforate previously perforated intervals in the Sadlerochit zone as listed below. The total footage of perforated zone will not be altered by this operation. A 5000 psi wireline BOP lubricator will be utilized with all wireline work. Perforations will be at 4 shots per foot on 90 degree phasing. Expected starting date is February 15, 1980. MD Interval 1021 2-10232 20 10190-10200 10 10150-10160 l0 10110-10130 20 10066-10086 20 10000-10040 40 9918-9948 30 9964-9984 20 9870-9900 30 Length SIGNED ./' .J~. · TITLE District DrillinQ Eneineer DATE. (This space for State offlc~se) CONDITIONS OFi~PROVAL, IF A~Y:"~ GA~R OF See Instructions On Reverse Side 2/1P/~n Approved Copy Returned December 21, 1979 Reference' ' EnClosed are Pressure Surveys for the follo~ving ARCO wel is" D.S, 3-7 11/8/79 Schlumberger ~i}~g_ I~#~.1.~..3. ,~, _ , . . 10/23- 24/79 Schlumberger Please sign and retu~ the attached copy as receipt e~ data. K, J, Sahlstrom North Pmgineering TtbMNS)~I]TAL f' 528 DI STRI BU:ION tN×on I, 1ob i 1 Getty Phi 11 Sohio H:n'~,. t-hon Choy:on December 18, 1979 Reference' Rnclosed are Cased Hole Logs for the following ARCO wells' D.S. 3-6 11/10/79 TDT Rrm 2 D.S. 3-7 11/7/79 " Rrm 2 2 & 5" (same log) D.S.. 6-6 11/17/79 TDT Run ]. 5" ~,.~$_~...1~2_r 5 11/23/79 Compensated Neutron 5" ~ of data. K. J. Sahlstrom North Engineering TIb~qS}INTAL # 527 North Geology Dr i } ] ins Hng. 5!anage r Geology State of Alaska Mobil Getty Phil li})s Sohio O~e\rr'on Post O[iJce Box 380 Anchor,.",~'~, Alaska 99510 Telephc 9,37 277 September 20, 1979 Reference' Enclosed are Cased Hole Logsfor the following ARCO wells'. D.S. 1-4''~'''' ~'~%~l-L~' 4/21/79 Collar Log 5" 6/12/79 CNL Run'4 5" ~j~,, 5/6-7/79 Perforating Depth Control Run 1 ~--qYTS~ 1-8~ 6/2/79 Spinner 5" D.S. 3-5 ~/ ref 5/28/79 Spinner D.S. 5-5 ~ 6/19/79 Spinner 5" D.S. 5-6¢' 6/25/79 " 5" D.S. 7-7~/' 7/1/79 " 5" Please sign and retmm the attached copy as re.ceipt of data. Very truly yours, K. J. Sahlstrom North Engineering TRANS'_'~ITFAL # 353 ].)I STRIB[TI'ION North Geology Drilling Eng. Hanager Geology,, State of Alaska k'4xog Mol) ii. Ce'try Sohio Chevron ARCO Oil and G~ .... ~ompany Alaska Re9,_,l Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 30, 1979 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: N~-~l~Permit No. 77-80 -D~l-'7, Permit No 77-60 Dear Sir: Enclosed please find our Sundry Notice of Subsequent Report and Completion Report detailing the work done on the above-mentioned wel 1 s. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'cs Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-403 REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to ¢leepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. Ow~LLLF~WELLGAS ~l OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360 Anchora.qe~ Alaska 4. LOCATION OF WELL At su trace 99510 254'N & 890'E of SW cr Sec 01, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 44" RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20283 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #11 (41-02-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudh0e 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 02, TllN, R14E, UM 12. PERMIT NO. 77 -80 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Perfora te . (NOTE; Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertlrtent ~let&lls, and give pertinent dates, Including estimated date of starting any proposed work. Began rigging up. to perf @ 0600 hrs 5/2/79. Tstd BOP. Pulled dummy valve. Perf'd intervals 10,304-10,318', 9870-9900', 9918-9948', 9964-9984', 10,000-10,040', 10,066- 10,086', 10,110-10,130', 10,150-10,160', 10,190-10,200', 10,212-10,232', & 10,264- 10,280' w/4 shots per ft. All perf'd depths referenced to CNL/GR/CCL log dated 3/9/78. Pumped diesel after perforating. Ran & tstd SSSV. Cleaned up well to burn pit. Ran Amerada press bombs. Installed & tstd tree cap. Released well to Production Department @ 1900 hrs 5/9/79. Verbal approval was received from Russ Douglas on 5/4/79. 16. I hereby certify that the foregoing is true and correct .. TITLE Bigtriot Rrillinn Fnninppr DATE 5/29/79 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side F'(~r m P---7 i SUBMIT IN DUPLICATE* STATE OF ALASKA , : <Sec other lm · . structions on reverse side/ OIL AND GAS CONSERVATION COMMITTEE I I WELL COMPLETION OR RECOMPLETION REPORT AND LOG* -- ' ~ ' '~ ~'[]]" ' []] Gas Iniecti ' la. TYPE OF WELL: Oil, uAs on W ELL W ELL DR ¥ Other ~ b. TYPE OF COMPLETION: : .~Ew []] wo~,~ [] DaP- [--q PL~ ~ DI~. [--1 Perforated w ELL OVER EX BACK RESVR. Other 2. NAbIE OF OPERATOR Atlantic Richfield.CqmpanY. ADDRESS OF OPERATOR P.O. Box 360; Anchoraqe, AK 99510 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 254'N & 890'E of SW cr Sec 01, TllN, R14E, OM At top prod. interval reported below 919'S & 1017'W of NE cr Sec 02, TllN, R14E, OM At total depth 611'S & 1097'W of NE cr Sec 02, TllN, R14E, UM 5. API N~CAL CODE 50-029-20283 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 ~. IF INDIA.N, ALLO'CrEE OR TRIBE NANLE 8. UNIT,FA-R.M OR LF, ASE NAME Prudhoe Bay Unit _NGI #1l ?(41-02-11-14) I0. FIELD AND POOL. OI~,~II-~DGAT Prudhoe Bay F~eld- Pr~dhoe Oil Pool, 11. SEC., T., 1%., M., (BOS['I'OM HOI_~t~ OBJECTIVE) Sec 02, TllN, R14E, UM 12. PERMIT NO, 77-80 13' DA'TE SPUDDED }14' IDATE T'D'''~EA~CHED 115' I)'ATE CO'IVI'P'SUSP O~ A'BAND'l/30/78 3/5/78 [3/1 2/78(perf'd 5/9/79~11~:' I~II~EVATIONS (DF' RKB' RT' GR' ~L'IX~)*I17' FJ'lqV' CASINGHEAD44' RKB .. I-~OW 1V/.A.NY* ROTA OOLS CABLE TOOLS 10,496'MD 8610'TVD 110,443'MD 8563'TVD Single 1 22. PRODUCING INTERVAL(S), OF THIS COMPLETIOn--TOP, BOTTOM, NA1ViE (MD AND TV])), ,23. ~VAS DIRECTIONAL ! SURVEY MADE Top Sadlerochit ~ 9865'MD 8066'TVD Base Sadlerochit 10413'MD 8537'TVD i Yes 24. TYPE ELECTRIC AND OTHER LoGS RUN GR/CNL/CCL, IES _ ! 25. CASING RECORD (Report all strings set in well) C;~SING SIZE 20" 13-3/8" 9-5/8" XYEIGHT, LB/FT~ 94# We~ d. ed 72# Butt 47# Butt H-40 N-80 N-80& DEPTH SET (M_D) 95' 2744' 95,44' ', j&L_9.~ i 26. LINER i~E C O t~D _ 7" 9203' · 10.496' I 400 sx OPF_Rq TO PROD O~' (interv~, size and number) 10,304-10,318C<~]0,066-]0,086' q0,264-10,280 ~9870-9900' ~ 10,110-10,130' w/4 shots : 9918- 9948 ' '~ ]0,]50-]0',160' pe~ ft. 9964-9984' 10,1 90-1 0,200' , ~ 1~000-1 0~040' ~10~212-10,232' ~' ~. ~ODUCTION DATE FIRST P~ODUC~ON [ ~ODUCTION METI{OD (Flowh~g, gas lifL pumped--size and type N/a v,Tz oF T~ST. HOURS T'ES~ ~ [~tOXE SiZE ]PROD'N FOE OI~BEL. GA~CF. 1 ,I -- &l. DISPOSITION O~'GaS (Sol'd, used )dr tuel, vented, etc.) 32. LIST OF ATTACHMENTS HOLE SIZE [ CEaMLNTING RECOILD i AMOUNT PULLED 30" [325 sx Arcticset II cmt ' 17-1/2"16200 sx PF II cmt 12-1./4" ~ 800 sx Class G cmt . ii 27. TUBING RECOF~D SCnE, EN (NID) [ SIZE DEPTH SET (IV, D) ~ PACKER SET (MD) I 7" 9099' i ~--~]; 1 i 29. ACID, Si!OT, F.~A~.~'~RE, CF.,~,~T/:NT SQUr'mZE ETC. D~i INT~V~ (MD) [ AMOUNT ;~D K1ND OF M~'I'EFRAL US~ I N/A ~ \VELL STATUS (Producing or ~nut-ln) [ WATEIt--I]BL. [ GAS-OIL R~tTIO WATER,---BBL. [ OIL GRAVITY-API (CORR.) I TEST WITNESSED BY 33. I hereby certify that the :forego{ng and attached information is complete and correct as determined from all-available records SIGNED ~' .~' '~~ TITLE District Drill in§ Engineer DATE :: *(See Instructions and Spaces [or AdditiOnal Data on Reverse Side) 5/29/79 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end leg on all types of lanJs and leases in Alaska. Item: 16: Indicate which eJevation is used as reference (where not otherwise shown) for depth measure- ments given in ether spaces on this form and in any attach?:~e?:ts Items 20, ~and 22:: If this well is completed for separate f')rcd~ction fror~'~ more th3n or'~e interval zone (multiple completior~), so state ~n iten~ 20, and in ite,~ 22 show thc' p~cJvc~".~l interva'l, or ~te~vals, top(s), bottom(s) and name (s) (if any) for only the interv~l ref~orted in ~ter'r~ 30. Svbmit a separate report (page) on this form, adequately identified, for each addilional ir~te~val to be seperately produce:'], show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~J. (See inslruction for items 20 and 22 above). 34. SUMM'~I~'Y ()b' Io()itM'^TIoN TEST:.-; IN('[.U[)IN¢; INTI.;ItVkI_, 'I'F.S'FEI"), I'HE~'-~qUI[E I)ATA A.ND .FL~C. OVERiF~k; (>F' OIL GAS 35 G~G I(' MARK~ WATEI~ AND MUD lop Sadloroch~t 9865~ 8066~ Base Sadleroch~t 10,413' 8537' .. i ..... I ill t None File ~y 7, 1979 Russell A. Douglass Petroleum E~gineer Perforate PBU NGI#11 Received a call from Arco 05/04/79 AM. They planned to perforate NGI #11 either the fourth or fifth. I gave verbal approval to perforate and report operations on a subsequent P-3. They intend to perforate the following intervals: 9,870-9,900, 9,918- 9,948, 9,964-9,984, 10,000-10,040, 10,066-10,086, 10,110-10,130, 10,150- 10,160, 10,190-10,200, 10,212-10,232, 10,264-10,280, and 10,304-10,318. Ail depths aremeasured. RAD:emi .w~c,~?jBUT~5.D TO: · s'~-~,- -' OF OIL & G~ DiVIsiON To' Fyom: North Alaska. District Engineering 'T RA N S bi I T T A I, Transmitted t~erewith are the following for the subject well' Run No. Scale Xerox .__ff__ BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamyna Ray Log Caliper/CCL Cement Bond Log/VDL ' Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis- Interval Core No. Core Description (SWC) - Interval Core Description (CQnv.) - Core No, Directional Survey -' Gyro Single S-~-6-t b~ltishot Drill Stem Test - Test No, __ / _ Dual Induction Laterolog ' Formation Density Log Fmmation Density Log/Gamma Ray Gamma Ray/~ Laterolog Location Plat Microlatero Microlog ~4ndlog- Intmnzal Sample Log. (A.R. C~.)"- interva-1 S)mergetic Log T\,rD-DIL TVD-Porosity Log . Sepia .BL Line _ / Receipt Acknowledged For' Date: Please retm~ receipt to: By: Abt~tic Richfield Company North Alaska Engineering P. O. Box 360 Anchorage, Alaska 99510 Nor th Alas]m I)i s tric l' E~t'., i ncc't-.in.~ T },' A N S ?.I I T 'J'A .;:s,,it-ted }~crmcith are the follo~..4ng for the ,subject well' Scale' · . Acid or Fracture %'catment Log ' ........ B!IP Buildup & Flo~v Profile Survey ....... }:orchole Geometry Log Carbon Oxygen Log '-- Casing Collar Log Cement Bond Log .~' Compensated Neutron Log - Cased Hole - Core Analysis - Interval Core No. ........ Core Description (~xIC) - Interval ..... Core Description (Cony.) - Core No. . - Single Shot - Nultishot ' .. · lingineering Production' Log .... Fluid'Analysis .Fluid Density Gamma' Ray .. ].,ocat. ion Plat. Monthly Well Test Data ...... Nud Log .....Perforating Raco;d . ..... State Resayvoi~ ~ressura Report Surveillance Reports Temperature Log . ........ Transient Pressure'Surveys --: .... 'IYD Logs - ~el Induction I,aterolog ...... - Compensated Formation Density Log - Compen s a t ed Neu t ton- Fmqnat i on Density l,og . - Bore]~o].e Compensated Sonic Log - Porosity I.og :~s;e Ret.t~rn ReceS.pt To' Ms. R. A~ Loguc Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 995] 0 )[el"ox Sep-.:ia 'BL Line Anct~ora~.. From' J. A'. Rochon/}~. A. Logue i'ran':-md ti'cd hcre~<ith are the f.-ollowing £or the subject well' No. · Scale Xerox Sepia 'BL I,ine Acid or Fracture Treatment Log - Bt-tP Buildup & Flow Profile Survey Borehole Geometry Log Carbon Oxygen Log ~ Collar Log Cement Bond Log ...... Compensated Neutron Log - Cased'Hole Core Analysis - Interval Core No. ........... Core Description (~\'IC) - Interval .......... Corc Description (Cony.) - Core No. Directional Survgy- Gyro - Single' Shot - ~'Mltishot ..... ']ingineering Production' Log Fluid Analysis . Fluid Density . Ganm~a Ray Location Plat Monthly Well Test Data Mud Log Perforating Record State Reservoir Pressure Report Surveillance Reports Temperature Log Transient Pressure Surveys TVD Logs - Duel Induction Laterolog - Compensated Formation Density l,og - Compensated Neutron-Fmm~ation Density Log - Borehole Compensated Sonic Log - Porosity Log / Return Receipt To Ms. R. A Logue At/antic Richfield Compan7 P. O. Box 560 Anchorage, Alaska 99510 : SUBMIT IN DU,~' .~..TE* STATE OF ALASKA .,,-,_+ .... st rti('t ions on 5.API NLrtvI~ll2CAL CODE reverse OIL AND GAS CONSERVATION COSMITTEE - ..... WELL PLETION OR RECOMPLETiON REPORT AND LOG* ..~. ~w~ o~ wm~:: o., ~ '~,~ ~ ~ ~ O~h~ Gas Injection WELL WELL ~ DRY b. TYPE OF COMPLE~ON: WELI. OVER EN ~ BACK ~ESVR. 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P 0 Box 360; Anchorage, AK 99510 ' ' Prudhoe Da{ Field 4. LOC~.rm~ O~' WrLb '(Re~ort tocation cteariu aha in accoraance with a,V State requirement,)* . . Prudhoe~_0i At surface 11. SEC., T., ~., M., (BOTTOM 254'N & 890'E of SW cr Sec. 01, TllN, R14E, UM At top prod. Interval reported below 919'S & 1017'W of NE cr Sec. 02, T11N, R14E, UM ~t total dep~ 611'S & 1097'W of NE cr Sec 02, T11N, R14E, UM ' 77-80 .. Is, TOTAL DE, H, N~ & TVD~9. PLUG, B~CK MD & ~D~. ~ ~rLT~E CO~L., 21. -- INTERVALS DRILl. ED BY / I ~OW~Y* ROTARY TOOLg ~~ CABI,E TOOLS 10,496'MD 8610'TV~ 10,443'MD 8563'TV~ Sinqle All ~. P~ODUCING !N2RVAL(S), OF ~.IS CO~p~TIo~--T&P, BOSOM, NAME (MD AND~)* ~,23, %VAS DIRECTIONAL , SUNVEY MADE Top SadlepochSt 9865'~D 8066'TVD Base Sadlepoch~t 10413'MD 8537'TVD {-~;-''?"} ~ Yes 50-029-2O283 6. LE. ASE D~IGNATION A2XlDSER~L NO.~ ADL 28302 fi-, ~. IF INDiA-N. ALLOTTEE OI{ TRIBE ~ ~!] 8. UNIT,FAIIlVi OH LE~kS]~; NAME Prudhoe Bay Unit ,. w=~,. ~o. /~ 'N-GI ~11 (41-02-11-14) Sec. 02, TllN, R14E, UM C~SLNC; SIZE -20" 13-3/8" ' 9-5/8" TYPE ELECTRIC AND OTHEI~ LOGS RUN GR/CNL/CCL, IES CASING RECOAD (~uport all strings set in weld [94# Welaed! H-401 95' 30" t32S s'X Arcticset II cmt 172# Butt I N-80[ 2744" 47# Butt ',[. N-80~ 9544" . 0:AL-951 m , , i 26. LINE~ [ [ BOTTO}'/' (5<ID) [SACt{S CES'IENT* SIZt~ TOP ~'.' PE~FORA2'iONS OP~ TO PRODU~O~ (interval, size and number) N/A 111 i11 30. DATE FINST PI-~ODUCTION i ii PI~ODUCTION 17-1/2"[6200 sx PF II cmt 12-1,/4" t' 8~0 s'k Class G cut I ii II Ill $Ci-;EEN /~CD~ SIZE DEPTH SET ", 90~)' &2,'~OU NT PULLED SET i 897]' , ,,1 _ 29. ACID, SN©T, FRA:;1 UPi~, CE.,IKNT SQU£i:]fZ~, ETC. DF_aTI'li INTE~iV_a~L (MD) ] AM.~UN ~' AND 1.2I(:.D ~l;' RiA.'i~iLiA~ USED [~. : ' ..... ..: ; L' l .... P~ODUCTION MTLIIiOD (Flowii*g, gas lifL pdrnping--size and t 14 £' am ~ or ~,~j~l~ ~, ~' . . . IV, IL~LI., ::;TAfUS (Producing N/A CI!OXE SIZB I PP. OD'N PLO%', TUBING ~qO PRESSURE [CALC~T~ OI~BBL. 2I. ~mPosm'~ox or ~as (8aid, u, ed /or /uei, vented, etc.)~ OIL---BBL. G AS--NZCF. I I GA S--]2,ICF. 1 32, LIST OF ATTACHMENTS _. Drilling History, Multishot Directional Survey. SIGNED TITLE District Drlg Engine_er D,Vn.: .... 3/28/78___ · ii I i Ill ] *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in ether spaces on this form and in any attachn'~ents. Items 20, and 22:: If this welt is completed for separate, prc, duction from more than one interval zone (multiple completion), so state ,n item 20, and ira item 22 show the prcJuc,r~,g interval, or ~ntervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. ,Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce.J, show- ing the acklitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced, (See instruction for items 20 and 22 above). , , 34. SUiMMAI~.Y OF FOi'{MATION 'FT~'I'S IN('LLII)IN(; INTEI{VAL TE,'~TE~. t'HE~$URE I)ATA ~ ~COVEI'{I~ OF OIL GAS, 35. G~GIC MARK~ WAT~I~ AND MUD afl. C'OHE DATA. A'I'I'ACII BRIEF D~CRIPI~ONS OF LIT'IIOLOGY, POROSITY, FIIAC~RF~, APP~NT DIPS ,, DRILLING HISTORY NGI #11 (41-02-11-14) API 50-029-20283, ADL 28302, Permit No. 77-80 Spudded well @ 1900 hrs 1/30/78. Drld 17-1/2" hole to 2760'. RU & ran 13-3/8" csg w/shoe @ 2744', FC @ 2660'. Cmtd w/6200 sx PF II cmt. Did top job w/50 sx PF I cmt. Tstd BOP. Drld FC & 10' new hole. Tstd form to 12.5 ppg equiv. Drld 12-1/4" hole to 9580'. RU & ran 9-5/8" csg w/shoe @ 9544', lower FO @ 2475', upper FO @ 2346'. Cmtd w/800 sx Class G cmt. Sqz 300 sx Arcticset cmt thru lower FO. Tstd FO. Did Arctic Pack job thru upper FO. Drld 8-1/2" hole to 10,394'. Dropped multishot. Several attempts to run logs failed. RIH w/IES tool. Logged from 10,315'-10,040'. Ran GR/CCL from 10,394'-10,180'. Ran ~idewall core gun, shot from 9986'-9721'. Drld to 10,496'. RU & ran 7" liner from 9203'-10,496' Cmtd w/400 sx Class G cmt. Drld out cmt in top of liner. Tstd csg. RIH w~WSO tools & ran tst. Tst OK. Displ mud w/wtr. Displ wtr w/10.8 CaC1 . Ran GR/CNL/CCL from 10,433'-7200' Ran gauge ring & junk bskt. RU & ran27'' tbg w/tailpipe @ 9099', pkr @ 897~', SBR @ 8920', sliding sleeve @ 8812', flapper valve @ 2222'. Displ CaC12 w/diesel. Dropped ball & set pkr. Ran CCL/dummy gun. Ran & set dummy valve. Installed & tstd tree. RU for long term tbg tst. Released rig @ 2100 hrs 3/12/78. i • ~~~~ .., ~.. ____„ ~. ~, ~~ ~ ~ s ~,. ' , %/ ~~ ~, ;,,~- ~~,~r " . ..... ~, r WELL NAME ~~ ~ 1 ~ ~-~-~ ::.~ ~ . NUMBER ~i ~ 1-~" ~ ~ ~. ~... ;_ ,...~ ,.. . ~~ l p:, ~icr, ~;.. . SURVEY TYPE MUL~'I, ~~~~ ~. . SURVEYOR /( ~ ' - l COMPLETION REPORT MARCH 7~ 1978 ATLANTIC RICHFIELD CO. N G I 11 MAGNETIC MULTISHOT 5URVEY K E ELEV• 44 FT. RAOIU5 OF CURVATURE h1ETHOD OF COP~1pUTATIUN DECLINATION 31 DEGREES EAST COMPUTEb FOR SDC RY F• N. LINDSEY AND ASSOCIATES RECORD OF SURVEY ALL CALCULATIONS PERFORMED f3Y I E3 h1 ELECTRONIC COMPUTER M~AS• DRIFT DEPTJ-f ANGLE D M 0 0 0 27oa n o 2857 4 0 2956 9 15 3043 12 30 3136 15 30 3230 19 45 3324 23 30 3416 26 30 3510 2.8 0 3602 31 15 3695 33 0 3797 37 30 3880 39 30 3973 41 30 406l~ 42 45 4159 43 45 4253 44 0 4346 44 30 4439 44 45 4532 45 0 4625 44 45 4719 45 0 4812 45 15 4905 45 30 TRUE VERTICAL DEPTH 0.00 2700.00 2856.87 2949.21 3040.53 3130.76 3220.33 3307.69 3391.07 3474.63 3554.59 3633.35 3709.46 3781.24 3851.96 3920.93 3998.67 4056.43 4123.Ok .4189.23 4255.14 4321.04 4387.66 4453.27 4518.60 SUE DRIFT 5EA DIREC DEG• -44.00 N 2.OOW 2656.00 N 2.OU~,d 2812.87 N 2.00W 2905.21 N22.OOW 2996.53 fJ41.OOW 3086.76 N43.pOW 3176x33 N34.OOW 3263.69 N34.OOW 3347.07 N33.OUW 3430.63 N32.004d 3510.59 P~31.OOW 3589.35 N31.OOIr1 3664.46 N31.OOW 3737.24 N30.OOW 3807.96 N30.OOW 3876.93 N31.OOW 3944.6? N31.OOW 4012.43 N29.OOW 4079.04 N29r00W 4145.23 N31.OOW 4211.14 N30.00l1 4277 s 04 N30.001-! 4343.66 N30.OUW 4409.27 N30.OOW 4474.60 N30.OOW TOTAL COORDINATES C L O S U R E S DISTANCE ANGLE o.oo s- o.oo w o.oo • • 0.00 5s47 N Or19 W 5.47 15.`91 N 2.40 W 16.09 30.80 N` 11.53 W 32.89 47.51 N 26.58 W 54.45 69.76 N 44.28' w 82.63 98.48- N 63.;65 U,~ 117.25 130.89 N 85.10 W 156.13 167.19 hJ 108.23 W 199.17 205.96 N 131.99 ~;! 244.63 248.35 h! 157.46 W 294.06 293.85 N 184.80 t~! 347.13 343.73 N 214.18 ~V 405.00 396.04 N 244.37 k' 465.37 449.78 N 276.03 lV 527.73 504.40 !d 308.85 t"! 591.45 560.92 hJ 341.43 W 656,58 617.58 N 372.89 W 721x42 674.15 N 405x55 W 786.74 730.69 hl 438.85 W 852.35 787.52 N 471.66 W 917.96 844.95 N 504.82 W 9F34.28 902.03 hl 537.78 W 1050.17 959.35 N 570.87 W 1116.36 D M S DOG LEG SEVERITY SECTL~ DEG/100FT DISTAh~~ S O G C ln' 0.000 0.00 S O O O W 0.000 0.0Q N 1 59 59 W 2.5413 5.Ob N 8 36 41 W 5.672 15.49 N 20 31 44 W 3.623 32.82 N 29 13 34 W 3.229 54.24 N 32 24 14 W 4.652 81.80 N 32 52 31 W 3.989 115.94 N 33 1 51 W 3.268 154.31 N 32 54 58 W 1.613 196.91 N 32 39 10 W 3.545 242.02 N 32 22 30 W 1.882 .291.13 iV 32 9 53 W 4.891 343.P` N 31 55 3b W 2.194 401.x. N 31 40 36 W 2.151 461.49 N 31 32 15 W 1.432 5?3.50 N 31 28 47 W 1.075 586.79 N 31 19 58 W 1.061 .651.61 N 31 7 23 W 0.538 71.6.28 N 31 1 47 W 1.099 781.28 N 30 59 2G W O.bU1 846.51 N 30 55 6 W 0.269 .911.80 N 30 51 23 W 0.266 977.79 N 30 48 10 W 0+269 10~~3.3`l N 30 45 18 W 0.269 2109.23 ARCO NvI-11 MAGNETIC MULTISHOT SURVEY MARCH 7~ 1978 RECORD OF 5URVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS• bRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C L O S U R E S DOG LEG SEVERITY DEPTH ANGLE D M DEPTH SEA DIREC DISTANCE ANG LE DEG/100FT SECTION DISTANCE DEGs D M 5 4998 5092 45 45 45 45 4583.64 4539.64 N29.50W 1017.06 N 603.86 W 1182.82 N 30 41 55 W 0.385 1175.40 5184 46 0 4649x23 4713.29 4605.23 4669.29 N29.OOW N29.OOW 1075x81 1133 57 N N 636.76 66 W 1250.13 N 30 37 14 W Or381 1242./ 5277 46 0 4777.89 4733.69 N29.OOW . 1192.08 N 8.77 701.21 V1 W 1316.15 1383.02 N N 30 30 32 27 21 53 W W 0.272 1308.~~ 537U 46 0 4842.49 4798.49 N29r00W 1250.59 N 733.64 W 1449.90 N 30 23 50 W 0.000 0.000 1374x97 1441 64 5463 5556 47 47 0 15 4906x51 4969 79 4862.51 4 N28r00W 1309.:88 N 765.83 ~J 1517.32 N 30 18 46 W 1x219 . 1588x91 5649 k8 0 . 5031.79 925.79 49.87.79 N28r00W N26r00W 1370.'05 1430.'61 N N 797.82 828.68 W W 1585.42 1653 28 N N 30 12 49 W 0.269 1576.92 5742 47 45 5094.84 5050.84 N24r00W 1493.':79 N 858.14 W . 1722.73 N 30 29 4 52 53 34 W W 1.451 1.196 1644.81 1714 52 5836 48 0 5157.89 5113.89 N25.50W 1557.10 N 887x33 W 1792.18 N 29 40 37 W 0.921 x 1784 23 5929 6020 48 48 15 0 5219.97 5280.71 5175.97 5236.71 N24r5UW N24.50W 161.9.8.6 1681 5 2 N N 91E~59 4; W 1$61.21 N 29 30 11 W Or65b x. 1853.47 6114 48 15 5343.45 5299.46 N24.OOW . . 1745.33' N 94 69 973.44 Vf W 1928.72 1998.44 N N 29 29 19 9 39 0 W W 0.276 1921.23 6206 49 15 5404.12 53bU•12 N23r50V! 1808.64 N 1001,30 W 2067x32 N 28 58 10 W 0.398 1 131 1991x22 bZ98 49 15 5464x17 5420.17 N24x00W 1872.44 N 1029x36 W 2136.73 N 28 47 58 W . 0x412 2060.39 2130 08 6390 6484 50 49 O 45 5523.77 5584.35 5479.77 5540.35 N21.50W N21.OOW 1937.07 2004 06 N 1056.47 W 2206.44 N 28 3b 28 W 1.791 x 220G.14 6576 49 30 5643.94 5599.94 N20.OOW . 2069.70 N N 1082x52 1107.06 W W 2277.74 2347.18 N N 28 28 22 8 34 30 W W U.408 2271.91 6668 50 15 5703.23 5659.23 N21x50W 2135x49 N 113.1.98 W 2416.96 N 27 55 38 W 0.-685 1x262 2341xP° 2412 6761 6855 50 51 15 15 5762.70 5822.18 571Hr70 5778.18 N19+OOW N20 00W 2202.56 2271 18 N 1156.73 W 2487x83 N 2? 42 2b W 2.067 • 2483.38 6948 51 0 5880.54 5836.54 r N19x00W . 2339.43 N N 1181.03 1205.20 W W 2559.90 2631.62 N N 27 27 28 15 29 21 W W 1,245 2555x92 7041 51 15 5938s91 5894x91 N20r50W 2407.57 N 1229.66 W 2703x42 N 27 3 20 W 0.703 1 017 262Rx07 7 7133 7226 51 51 0 15 5996.65 0 5952.65 N18r5UW 2475.08 N 1253x57 W 2774x43 N 26 51 40 W x 1.341 2 00.24 771 7 61 73?_0 51 0 55.02 6 6114.02 6011x02 6070.02 N18r50W N19r00W 2543.74 2613 04 N N :1276.54 0 W 2845x08 N 2b 38 57 W 0x269 . . 2843e65 7412 51 30 6171.61 6127.61 N19r00W . 2680.88 N 13 6•C7 13?_3.42 W W 2918.59 2989.74 N N 26 26 27 lb 6 24 W W 0.417 2916.49- 7505 51 0 6229.82 6185.82 N19.OOW 2749x46 N 1347.04 ;d 3061.70 N 26 6 5 W 0.543 0 538 2987.93 7598 51 30 6298.03 6?.44.03 N19.OOW 281Hr03 N 1370.65 W 3133x69 N 25 56 15 W . 0 538 3Ub0,15 . 3132.37 ARCO NGI-11 MAGNETIC MULTISHOT SURVEY MARCH 7~ 1978 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS. DR IFT VERTICAL SU9 DRIFT TOTAL COORDINATE5 C L O S U R E S ~ DEPTH ANGLE DEPTH SEA DIREC DISTANCE ANG LE SE ERITY DEG/10OFT D M DEG. D M S 7692 7785 49 44 30 6347.81 6303.81 N21.OOW 2886.18 N 1395.46 W 3205.83 N 25 48 12 W 2.458 7878 41 45 30 6411.07 6478.94 6367.07 6434.94 N23.OOW N24•OUW ?_949.35 3007 65 N 1420.98 W 3273.82 N 25 43 28 W 5.218 7971 39 30 6549.66 6505.66 N26.OOW . 3062.38 N N 1446.32 1471.85 W W 3337.34 3397 72 N N 25 25 40 4 55 W 3.526 8066 8161 39 39 0 6623.22 6579.22 N27.OOW 3116.17 N 1498.67 W . 3457.82 N 25 0 41 11 3 W W 2.320 0 571 8256 38 0 15 6697x05 6771.27 6653.05 6727.27 N2b•OOW N26 OOW 3169+68 N 1525x34 W 3517x60 N 25 41 53 W . O.bb2 8351 39 15 6845.36 6801.36 . N25.OOw 3222.97 3276x64 N N 1551.34 1576.94 W W 3576.90 3636 36 N N 25 42 11 W p.76q 8445 8539 38 38 30 30 6918.54 6874.54 N25.OOW 3330•I1 N 1601x87 W . 3695+35 N 25 25 41 41 59 19 W W 1.134 0.798 A634 37 45 6992.10 7066.84 6948x10 7022.84 N25•fUW N24 5OW 3383.15 hi` 1626.60- ` W 3753.87 N 25 40 40 W 0.000 8729 38 15 7141.70 7097.70 . N24.OOW 3436.41 3489.74 N N 1651.15 1675x18 W W 3812.51 387U 98 N N 25 39 49 W 0.814 8824 38 0 7216.43 7172x43 N24.OOW 3543.32 N 1699.03 W • 3929.61 N 25 25 38 37 32 4 W W 0.564 8919 901? 37 3 30 7291.55 7247.55 N24r5OW 3596.34 N 1722.92 W 3987.75 N 25 35 52 W 0.263 0 561 9106 7 37 30 0 7366.12 7440.15 7322x12 7396.15 N23.5OW N24 UO1 1 3648.62 7 N 1746.19 W 40.44.95 N 25 34 31 W . 0.648 9199 36 15 ?514.79 7470x79 ~ . N21.fOW 3 00.14 3751.40 h! N 1768.87 1790.09 W W 4101x22 4156 61 N N 25 33 3 1 W 0.572 9292 93 35 30 7590.14 7546.14 N19.5OW 3802.53 N 1808.96 W . 4210.88 M 25 ?_5 0 26 34 29 W W 1.387 0 973 85 9478 35 34 15 30 7665.97 7742.27 7621x97 7698x27 N19.OOW N18 OOW 3853.36 N 1826.•71 W 4264.41 N 25 21 49 W . 0.323 .. 9509 34 0 7767.89 7723.89 . hl18.5GW 39G3.78 3920x35 N h! 1843.58 1849.04 41 W 4317.21 4334 53 N 25 15 45 W 0.877 9675 33 30 7905.92 7861.92 N17.5OVd 4008.06 N 1877.54 W . 4426.03 N N 25 25 15 6 3 1 k' W 1.690 9769 32 30 7984.75 7940.75 N16.OOW 4O5T•O8 N 1892.30 W 4476x69 N 25 0 18 VJ 0x353 9863 9957 32 32 30 15 8064.03 8143042 8020.63 8099.42 N16.OOW N1 OUW 4105.63 4 N 1906.22 W 4526x58 N 24 54 I8 td 1.159 oxOOO 100,151 31 15 8223.35 8179.35 5. N14.OOW 154.14 4202.02 N N 1919.67 1932 05 W W 4576.24 4 4 N 24 48 7 W 0.403 1f~145 31 0 8303.82 8259.82 N13.5OW 4249.22 N . 1943.60 W 62 .81 4672.63 N N 24 24 41 34 33 45 W W 1.102 " 14239 30 45 8384.50 8340.50 N14.5OW 4296.02 N 1955.27 W 4720.06 rd 24 28 19 Vv 0. s O1 10271 29 0 8412.25 8368.25 N15.OOW 4311.44 N 1959.33 V~' 4735.77 N 24 26 21 W 0.385 5+481 SECTION DISTANCE 3204.70 3272.' 3336.a~ 3396.72 3456.78 3516.52 3575.80 3635.24 3694.23 3752.75 3811.39 3869.88 3928.53 3986.69 4043.91 4100.20 4155.65 421O.c~ 426'3~c_ 4316.55 4333.90 4425.•57. 4476.33 4526.31 4576.05 4524rT~.~ 4672.5.6 4720.03° 4735.75. ARCO NGI-11 MAGNETIC MULTISHOT SURVEY h1ARCH 7~ 1978 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE DOG LEG ~•1EAS• pRIFT VERTICAL SUB pRIFT TOTAL COORDINATES C L 0 5 U R E 5 SEVERITY SECTION DEPTH ANGLE pEPTH SEA DIREC DISTANCE ANGLE DEG/100FT DI5TANCE b M DEG• D M S 10301 28 45 843$•52 8394.52 N15.OOW 4325.43 N 19b3.08 bJ 4750.06 N 24 24 38 W 0.833 4750.04 103ti3 ?.8 30 8510.49 846b•49 N15.OOW 4363x38 N 1973.25 W 4788.82 N 24 20 2 W 0.305 4788x' 10394 28 30 8520.16 8476.16 N15.OOW 4368.45 N .1974.61 W 4794.00 N 24 19 25 W 0.000 4793.~~y 10496 28 30 8609.80 8565.80 N15.OOW ;4415.46 N--X987.20 W -'4842.03 N 24 13 49 W 0.000 4E42.03 BOTTOM HOLE CLOSURE 4842.03 FEET AT N 24 13 49 W ARCO NGI-11 MAGNETIC MULTISNOT SURVEY INTERPOLATED TRUE VERTICAL DEPTH5~ COORDINATES AND CLOSURES FOi; GIVEN DEPTHS CODE- MEA5UREp VERTICAL NAME DEPTH DEPTH TOTAL COORDINATES C L O S U R E DISTANCE ANGLE D M s MARCH 7~ 1978 SUES SEA ~CO NGi-11 MAGNETIC MULTISHOT SURVEY ~ASURED DEPTH AND OTHER DATA FOR EVERY EVEN i00 FEET OF SUB SEA DEPTH, MARCH 7, 1978 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 144 144. 100 0 0 244 244. 200 0 0 344 344. 300 0 0 444 444. 400 0 0 544 544. 500 0 0 644 644. 600 0 0 744 744, 700 0 0 844 844. 800 0 0 944 944. 900 0 0 1044 1044. 1000 0 ,i!0 1144 1144. 1100 0 0 1244 1244, 1200 0 0 1344 1344. 130'0 0 0 1444 1444, 1400 0 0 1544 1544e 1500 0 0 1644 1644, 1600 0 0 1744 1744. 1700 0 0 1844 1844. 1800 0 0 1944 1944. 1900 0 0 2044 2044, 2000 0 0 2144 2144. 2100 0 0 2244 2244, 2200 0 0 2344 2344, 2300 0 0 2444 2444. '2400 0 0 25~4 2544, 2500 0 0 2644 2644. 2600 0 0 2744 2744. 2700 0 0 2844 2844, 2800 0 0 2945 2944, 2900 0 0 3047 3044. 3000 2 2 3150 314~. 3100 5 3 3255 3244. 3200 11 6 3364 3344, 3300 19 8 3475 3444, 3400 31 12 3590 3544. 3500 45 14 0.00 S 0,00 S 0.00 S 0,00 S 0,00 S 0,00 S 0.00 $ 0.00 $ 0.00 S 0,00 S 0.00 S 0.00 5 0.00 S 0.00 5 0,00 S 0,00 S 0.00 S 0.00 S 0,00 5 0,00 S 0.00 S 0,00 S 0.00 $ 0,00 S 0.00 S 0.00 5 0,43 N 4e60 N 15.12 N 31.38 N 50.29 N 76.94 N 112.08 N 153.42 N 200.51 N 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0,00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0,00 W 0.00 W 0.01 W 0.16 W 2.14 W 12.04 W 29.11 W 49.12 W 72.75 W 99e55 W 128.7C W CO NGI-I! MAGNETIC MULTISHOT SURVEY ASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, NARCH 7, 1978 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 3708 3644, 3600 63 18 3832 3744, 3700 88 25 3962 3844, 3800 118 30 4097 3944, 3900 153 35 4236 404~e 4000 191 38 4375 4144, 4100 231 40 4516 4244, 4200 272 41 4657 4344e 4300 313 41 5084 4644, 4600 440 43 5228 4744, 4700 484 44 5372 4844e 4800 528 44 5518 49~4e 4900 574 .46 5666 5044, 5000 622 48 5815 5144, 5100 671 49 5965 5244, 5200 721 50 6115 5344e 5300 770 6267 5444, 5400 823 53 6421 5544, 5500 877 54 6576 5644, 5600 932 55 6731 5744e 5700 987 55 6890 5844, 5800 1046 59 7049 5944e 5900 1105 59 7208 604fl, 6000 1164 59 7367 6144, 6100 1223 59 7527 6244, 6200 1283 60 7686 6344. 6300 1342 59 7831 6444, 6400 1387 45 7963 6544, 6500 1419 32 8093 6644e 6600 I449 30 8221 6744e 6700 1477 28 8349 6844. 6800 1505 28 8477 6944, 6900 1533 28 8605 7044, 7000 1561 28 254,47 N 317,65 N 389,74 N 467,88 N 550,35 N 635,32 .N 720,91N 807,04 N 893j93 N 981.65 N 1070.94 N 1161,25 N 1251,85 N 1345,43 N 1442.64 N 1543.08 N 1644,41N 1745.88 N 1851.08 N 1959,22 N 2069,70 N 2180,91 N 2296,71 N 2413.~3 N 2530.59 N 2647.64 N 2765,63 N 2881,99 N 2978.52 N 3057,79 N 3131.18 N 3203,~4 N 3275,50 N 3348,17 N 3420,31 N 161,13 W 198,96 W 240e74 W 286,91 W 335,58 W 382,85 W 482,93 W 533,10 W 583,6~ W 633.72 W 684,12 W 734,34 W 784,73 W 8~4,50 W 880,49 W 927e52 W 973,68 W 1019,60 W 1064.97 W 1107,06 W 1148e80 W 1190e23 W 1231e79 W 1271e61 W 1311,98 W 1352,61 W 1393,85 W 1433.50 W 1469.62 W 1506,27 W 15~1,81W 1576,40 W 1610.29 W 1643e66 W !CO NGI-i! MAGNETIC MULTISHOT SURVEY !ASURED DEPTH AND OTHER DATA FOR EVERY EVEN I00 FEET OF SUB SEA DEPTH. MARCH ?~ 1978 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 8732 7144, 7100 1588 27 8859 7244. 7200 1615 27 8985 7344, 7300 1541 26 9111 7444e 7400 1667 26 9235 7544, 7500 1691 24 9F58 7644, 7600 1714 23 9480 7744. 7700 1736 22 9601 7844e 7800 1757 21 9720 7944, 7900 1776 19 9839 8044e 8000 1795 19 9958 8144, 8100 1814 19 10075 8244, 8200 1831 17 10192 8344. 8300 1848 17 10307 8444, 8400 1863 15 10421 8544, 8500 1877 14 3491,39 N 1675,91 W 3562.92 N 1707,76 W 3633,15 N 1739,04 W 3702,79 N~ 1770,04 W 3771.25 N 3904.86 N 3968,99 N 4031.69 N 4093,24 N 4154,49 N 4214.10 N 4272e66 N 4328,22 N 4380,89 N 1797.56 W 1821,41 W 1843.93 W 1864,59 W 1884,66 W 1902.66 W 1919,76 W 1935.04 W 1949,12 W 1963,83 W 1977.94 W :CO NG !- 11 'ERPOLATED VALUES FOR EVEN 1000 MAGNETIC MULTISHOT SURVEY FEET OF MEASURED DEPTH, MARCH 1978 TRUE MEASURED VERTICAL DEPTH DEPTH SUB SEA TOTAL COORDINATES 1000 1000, 2000 2000, 3000 2ggS, --~ ~+000 3S 72, 5000 4555, 6000 5267, 7000 5913, 8000 6572, 9000 7355, 10000 8179, 956, 1955, 2954, 3828, 5223, 5869, 7311, 8135, 0,00 S 0,00 0,00 S 0,00 23,72 N 6,40 411e56 N ~ 253,39 1018 e32 N ~ 604e55 1668,18 N ~/" 938,10 2377e61 N~? 1218,55 3078,91 N~/ 1479,96 3641,54 N '.," 1742,6~ 4176e18 N 1925e48 400- 1600- 2000- 2400- 2800' 3200 VERTICAL SECTION SCALE I"=1000' ATLANTIC RICHFIELD COMPANY N.G.I. II RADIUS OF CURVATURE MAGNETIC MULTI-SHOT 44( 48~ I ALL DEPTHS SHOWN I I ARE TVD. 64( 804 TVD = 8,610' TMD = 10,496' HORIZONTAL VIEW SCALE I"= I000' ATLANTIC RICHFIELD COMPANY N. G.I. II RADIUS OF CURVATURE MAGNETIC MULTI-SHOT TVD= 8,6 I0' TMD = 10,496 ' 8400. 7600' 7200' 68 O0 6400 6000 560; 5200' ~ 4800' 4400 ALL DEPTHS SHOWN ARE TVD. $600 320(: Atlt, n~icRichfieldCompany · · North American Producing Division North Alask; ~trict Post Office Box 360 Anchora,7, e, Alaska 99510 Telephone S07 277 5537 March 7, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 4-11 Permit No. 78-6 P6~o. 77-80 Dear Sir' Enclosed please find the Honthly Report of Drilling Operations for the above-mentioned wells. Very truly yours, Frank M. Brown District Drill ing Engineer /am Enclosures SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Form N~. P-4 REV. 3-1-70 MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20283 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL ~'~ GAS ~] Gas Injection WELL WELL OTHER 99510 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.0. Box 360; Anchorage, AK 4. LOCATION OF WELL 254'N & 890'E of SW cr Sec. 01, TllN, R14E, UM 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #11 (xx-02-11-14) lO. ~ ~IPO~ffR Prudhoe 0il Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 02, T11N, R14E, UM 12. PERMIT NO. 77-80 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for the month of February, 1978 Spudded well @ 1900 hrs 1/30/78. Drld 17-1/2" hole to 2760'. RU & ran 13-3/8" csg w/shoe @ 2739', FC @ 2655' Cmtd w/6200 sx PF II cmt. Did top job w/50 sx PF I cmt. Tstd BOP. Drld FC & 10' new h~le. Tstd form to 12.5 ppg equiv. Drld 12-1/4" hole to 9580'. RU & ran 9-5/8" csg w/shoe @ 9543', lower FO @ 2475', upper FO @ 2346'. Cmtd w/800 sx Class G cmt. ~-~,,~_A~cticset.~.m~:.~hr~. lo~er_.F0. Tstd FO. Did Arctic Pack job thru upper FO. Drld 8-1/2 hole t~-~i-~)~,~4', DroPped multishot. As of February 28, attempted to run logs but couldn't get to bottom. 14. I hereby certi~at the~e and correct SIGNED,~~ TITLEDistrict Drlg EngineerDATE 3/6/78 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. O. K. Gilbre~h, Jr.~~ Director Chief Petroleu~ Eng/neer February 17, 1978 Witness BOP Test, ANDO }~II 911 Sec. 2, TllN, R14E, Permit No o 77-80 ~ Feb_ruary 3~ ~_1~:78_ - I ileft my P~use at 7: 30 AM for flight to ~x~%0e -~ ~Y Wie~ ~ at 8:30 AM by ~=co charter. I arri~ in ~ at 10:30 AM. I was picked up by Shorty Allen,. operator for Arco, and taken to NGI No. 11. 13 3/8" casing was run and cemen~ had just been done, but had to have a top job. Nippling up BOP's started at midnight. I witnessed a SSSV test c~ DS 2-11 that failed. Satur..da~., Fe~~ ~ ~ 4~ 1978 - Nippl/ng up BOP's still in progress. ~-c- 7_:- 5, 1~78 - Nippling up of BOPs on 5~I-11 still in ~ss, ~~~-~ at 10:00 AM. ]~e reasc~ BOPs were so long in nipp!~ng up was the tempera~ was -42° and a 35 mile an hour w/nd. E~ryttdng was froze up. ~ne annular preventer was tested first and held 3000 psi OK, after flanges tPmt leaked were retightened cn stack. Thare were 10 valves in cellar c~ stack that ~are replaced, that would not hold test. Also the lower pipe rams were replaced that would not test. The lower kelly entire test. Test ~ took 28 hours. valves c~ stack in cellar tested to 5000 psi. The upper and ~cwer pipe r~s and blin~ rams tested to 5000 psi. The su~ and 6 valves and 14 flanges tested to 5000 psi on manifold. The upper and lower kelly tested to 5000 psi. There were 222 failures during tests that w~re repa/red. Most ~ due %o very cold temperatures. I also had the operator shut all puups down on the a~tor .and shut all c~ntrol~ at cnce on the BOPs, h~]ril, upper and lc~:r pipe rams and blind rams. Accumulator closed all cc~pcne~ts in 40 seconds with 1100 psi left c~ master gauge. Accunulator precharge bottles were about 100 psi iow. Operator gave orders to charge a~tor bottles to 1000 psi. The pit was open but well benned, the location looked in fair shape, but was valve cn the floor OK. ~ manual choke operated freely. There was a well sign up with all data OK. Nitxogen bac~ bottles had 1800, 1800, 1850, 1850 each, NsI %~ 2- Febanary 17, 1978 tests ~ c~leted ~ cc~pc~n~ ~ satisfactory except for vales .on ~fold tt~t ~ not test. Arco is to call our office ~ ~s wmm repaized ~ testea. Atilt -;"- - ' -."" . .- Ala~ Oil and Gas .COnservation Commi~b' ' . · ' ~ _ - '.' - - ~ "' 'Field InSpettion Report ~ ' '~ Permit No.~7-~' ' Well/Platfmo Sec ~ T~RX~,, ~I' ' Operatom ~ ~ ~- . 'Represented by~~ ~~ Name &Numb, r~/~ ~ '.-- Satisfactory Type Inspection Yes No Item ~'Location,General (20 ( ) 1. Well Sign (~) ( ) 2. General Housekeeping O0 ( ) 3. Reserve Pit-(~)open( )filled ~<~) '( ) 4. Rig !~ ( ) Safety Valve Tests ( ) ( ) 5. Surface-No. Wells ( ) ( ) 6. Subsurface-No. Wells (j~) ( ) () Well Test Data- (v) ( ) ( ) ( ) 7. We ll'"Nos. , , , ~..~):; ( ) ( ) ( ) 8. Hrs. obser-'---?-~ , -~ - (X) ( ) ( )( ) 9. BS&W , , ,-- () ( ) ( ) 10. Gr. Bbls. , , , (~() ( ) ( ) Final A~a'ndonment ~ ()~) ( ) ( ) ( ) 11. P&A Marker (9() ( ) ( ) ( ) 12. Water well-( )capped( )plugged (~() ( ) Satis'factory Type Inspection Yes No Item (~<) BOPE Tests (~) ( ) 1~5. (~ ( ) 1 ~r~. fluid-( )wtr.-~-~ )mud ,(~)~ oil ( ) 17] Master Hyd. Control Sys.~ psig ('~') 18. N btls~]z~_,~ - - sig ( ) 19. R2emote Controls ~~'~i~ · ( ) 20. Drillinq spool-~_! "outlets 21. Kill Li~e-(9() Check valve 22. Choke Fl owli'ne ( ) HCR valve 23. Choke Manifold_No. val~s~fl&s//~ 24. Chokes-~')P~emote~[)Pos. (~dj ] 25. Test Plug-(~()Wellhd( )cs..o( )none 26. Annular Preventer ' d~_d_~_O_psi~ 27. Blind Rams ~_~_~_pSl9 28. Pipe Rams~'~9~ psig 29. Kelly & Kelly-cock_~z~O psi§ ( ) ( ) 13. Clean-up I~ ( ) 30. Lower Kelly valve4~~sig ( ) ( ) 14. Pad"leveled ~ ( ) 31 Safety Floor valv6~BV (X)Dart Total inspection observation~time~/days Total number leaks and/or eouip, failures Remarks ~/~/) ~-~A~, ~/= ~ '~ ~ ~/~E .~/~ld~~d~ ~ ~~T ' ' " AflanticRiichfieldCompany North Amc~''~ n Producing Division North Aiask,~ ,~'~istrict Post Office Box 360 Anchorage, Alaska 995'10 Telephone 907 277 5637 February 1, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: ~(xx-02-11-14) ~ No. 77-80 D.S. 1-15 (xx-8-10-15) Permit No. 78-7 W. Sak River St. #7 Permit No. 77-1 Dear Sir: Enclosed please find the Monthly Report for the above-mentioned wells. Very truly yours, ~l~ank M. Brown District Drilling Engineer /am Enclosures of Drilling Operations Form No. P-4 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. OIL F--1 GAS [--I Gas Injection WELL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360; Anchorage, Alaska 4. LOCATION OF WELL 254'N & 890'E of SW cr Sec. 01, TllN, R14E, UM 5. APl NUMERICAL CODE 50-029-20283 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #11 (xx-02-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 02, TllN, R14E, UM Pool 12. PE. RMIT NO. 77-80 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for the month of January, 1978 Spudded well @ 1900 hrs 1/30/78. As of January 31, drld 17-1/2" hole to 689'. 14.SIGNEDI he,eby ~at~~~s t,ue and correct TITLE District Drill ing EngineefATE 2/1/78 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. ,~RichfieldCompany North Amer*~ Producing Division North A~ask .... ~is~rict Post Office Box 360 Ar~chorage, A~aske 99510 Telephone 907 277 5637 December 30, 1977 Mr. Hoyle H~ Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: NGI #11 (XX-02-11-14) NGI #12 (XX-01-11-14) Permit No. 77-80 Permit No. 77-81 Dear Sir: Enclosed please find three (3) copies of a certified location plat for the subject wells. Sincerely, F. M. Brown District Drilling Engineer FMB/mln S E C T,/¢N ,., - BUILT WELL NO t LAT. 70°19'36.129" Y 5 ~71 4000 LONG. 148°28'50016'' X ¢)87 350.54 865' 890' 9~5 94_._0' section line 965' 989 1014' SECTION 12 1039 ., ~089 1114 LEGEND EXISTING WELL OR CONDUCTOR PIPE NOTE' WELL NO.I TOP PAD ELEV. ,= 18.4 FT. ABOVE MLLW CERTIFICATE OF SURVEYOR t HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE L AND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLA:-[ REPRESENTS A LOCATION SURVEY MADE BYi'ME OR UNDER MY SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE _CCLRRECT. DEC 18, 1977_ ELLII* OCT 4, 1975 ~/ , : . ,- ,:.. DATE SURVEYOR '-. , WE/._L NO. 2 .LAT 70© 1'3'37.284" Y 5 971 516 90 LONG. 148©28'-~9.762'' X 687 522 06 WELL NO. 3 LAT 70© 19'38.441" Y 5 971 633 76 LONG. 148° 28'51.493" X 087 ::'94.09 WELL_ NO. 4 LAT 700 19'39.596" ¥ 5 971 750.62 LONG 148° 28'52 223'' X 687 266.18 WELL l'vO. 5 LAT 70019'40.749" Y 5 971 867.11 LONG. 148°28'52.947'' X G87 2,58.47 WELl_ NO. 6 LAT 70©,'9' 41 908" / 5 971 984.28; LONG. 148©28'53.682'' X 487 210.34 WELL. N,. 7 LAT 70c /9',43.052" Y 5 972 099.94 LONG. 148°28 54.412" X 687 !8'2.47 WELL NO. 8 LAT. 70°:9'442i0'' Y '; -~72 2'7.07 LONG .'48°Y8'55.126'' X 687 . 55.06 WELL NO. 9 LAT 70© !9'45.370" Y 5 972. 3%4.31 LONG. i48°28'55850'' X ;;87 IL'7.31 WELL N(). I0 LAT. 70° ~9'46.5/9" ; '5 ~72 ~T~7 ....... ~~.675" Y 5 972 567.37 LONG. 148°28'~.319" X 687 071 WELL NO, 12 LAT. 70° 19'48.830" Y 5 972 684.11 LONG. 148°28'58.044'' X 687 043.43 --: REVISION NO.- 1 .ARCO~ AFL 292265 HVL #30-/VI5-7..~ ATLANTIC RICHFIELD CO. AS -BUILT I THUR 12 NORTH i:I IJECTION SITE LOCATED IN PROTRACTED SECTIONS I &I2~TIIN~ RI4E~ U.M. PREPARED [~Y H£WlTT ~ LOUNSBURY I~ ASSOC. /'23 W 6TH. AVE., ANCHORAGE, ALASKA DATE OCT 9, 1975 SCALE /": 300' LOOSE CHKD. BY___C?_.__D_ ........... FIELD BK. LEAF -, P~~ ~ Unit NGI-~ (xx-02-11-t4) Atlantic Richfield (k~y ~t ~. 77-80 P. O. ~ 360 Anchorage, Alas~ 99510 Sir: Enclosed is ~ app~ application for perm_it to drill ~/~e abcv~ r~ feren~ed ~1 at a location ~ ~g~tion 02, Towns.hip liN, ~ 14E, U.M. A ~irectio~l ~ riM--rs ~ Alaska and their drainage systen%~ ~ k~.n classified as im~ for ~ s~ng ~ migration of anadrc~ous fish. Operations ~ th~e ~ ~ subj~ to ~ 16..50.870 and the regula~ prc~ated ~u~ (Title 5, Alaska ;~]ministrati%~ Code.). Prior to ~ing ~ ~ ~ ~ cc~acted 'by ~ ~itat ~inator's office, Depa_~o~nt of Fish ~ ~. Pollutic~ of any waters of th~ State ~ prohibit, by AS 46, Chapter 03, ~+~/cle 7 ap~ ~he regulations .~gated there%ruder (Title 18, Alaska Adm/nistrati~ ~, Chapter 70) and by ~ Federal Water Pollution (k~I ~, ~ ~. Prior to ~ing cperations you ~a¥ be con~ by a representative of ~ De~t of f~v~tal Cc~serva~ion. _~r~t ~ .AS 38.40~ ~ ~ ~ State Imases, the Alaska De~t of ~ is ~ r~tif~ ~ ~ issuance of this permit to drill. ~fied so that a representati~a of ~ Division may be t=ese~t to witness testir~ of blowout preventer eq~ -~~t before surf~ casing_ shoe is drilled. F. M. B~ P.B. L~nit NGI-11 -2- December 22, 1977 In tl~ ~ of su~~icm or ~t please give this office adequate ~ notific=~cic~ so that w~ may have a witness present. O. K. Gilbre~h, Jr. AI~ Oil and Gas CoD~~~ ~ttee De~t of Fish ar~ ~, Itabitat Section w/o encl. Department of En~tal Cc~servatic~ w/o encl. Department of ~, ~sor, Labor Law O~liance Division w/o eric!. AHa~ficRichfie~dCom, pan¥ -' North Americ~-~ Producing_ Division: North A~ask~ ~trict Post Office ~o~ 360 Anchorage, Alaska 995~0 Telephone 907 277 5~37 December 15, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: NGI #11 (xx-02-11-14) Dear Sir: Enclosed herewith is our Application for Permit to Drill NGI #11 and $100.00 filing fee. The required survey plat will be sent as soon as it is available. Very truly yours, F. M. Brown District Drilling Engineer /am Enclosures Form 10-401 REV. 1-1-71 STATE OF ALASKA SUBMIT IN TRI .... JATE (Other instructions on reverse side) : OIL AND GAS CONSERVATION COMMITTEE .. PERMIT TO DRILL OR DEEPEN , iY. la. TYPE OF WORK ..... DRILL ~] DEEPEN r-] b. TYPE OF WELL OIL GAS WELL ~ WELL IX] OTHER Gas Injection SINGLE ZONE ['~ 2. NAME OF OPERATOR ATLANTIC RICHFIELD COMPANY MULTIPLE I---I ZONE ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL Atsurface 254'N & 890'E of SW cr Sec. 01,. TllN, R14E, UM A~ D[ODOSCd_DLO~. zon~. @ '8300'ss) 1000'S & 1250'W of NE er. Sec. 02, TllN, R14E,UM 13. DISTANCE IN bIILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approximately 8 miles NE of Deadhorse API No, 50-029-20283 6. LEASE DESIGNATION AND SERIAL NO. ADL-28302 ' 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay ~( 9. WELL NO. NGI-11 (xx-02-11-14) 10. FJ4~LD A~ND POOI_--DR WIKOCAT.~. ~ruanoe ~ay ~'~e±a Prudho. e Oil Pool. I 1. SEC., T., R., M.. (BOTTOM HOLE OBJECTIVE) Sec. 02, TllN, R14E, 12. 14. BOND INFORMATION: TYPE Statewidesutetya,d/orNo. Federal Insurance. Company #8011-38-40 IS. DISTANCE FROM PROPOSED * LOCATION TO NEAREST 1000 ' PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 18.DISTANCE FROM PROPOSED LOCATION 3'0 NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2300 ' : 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 44' RKB, 18' Pad Elevation (Gravel) No. OF ACRES IN LEASE 2560. . ' PRopoSED DE~H 8544' ~ TVD $100,000 Amount' 17. NO,ACRES ASSIGNED " TO TtIIS WELL 160 20. ROTARY OR CABLE TOOLS :. Rotary 22. APPROX. DATE WORK WILL START 1-7-78 23. : PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SE~ING DE~H Quantity or cement 32" ..... '2'0'''~ ' 94 lb.. H-40 . 10l;~ _+'MD 300 sx Permafrost, II"t'6' surface '" 17-1/2". 13-3/8" 72'1b. MN-80 2700''+ MD_ ~irc. to sUrface-approx. 5500 sx ' 12-1/4'" '925/.8.''' 47 lb. 80&95. "9386' ~MD 700' ~ cmt column on 1St stage' ('~ .. 700 sx) plus 300' +~ column .on.2n stage (approx. 300 sx) 8-f/2" 7".'!inet ...2'9 lb. MN-80 .!040.~'. ....... ~MD 1316' ± cmt Column-approx'. 500~ sm / Atlantic Richfield Company proposes to directionally drill this well to 10405.' +MD, ~44' + TVD to produce the. Sadlerochit. zone. Logs will be run across selected~ntervals. A 1~~>~00 psi Hydril and 13-5/8" 5000 psi pipe and blind rams will be used on the 13~/8" casing. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 7" 29# N-80 LT&C tubing, packer, and necessary provisions for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. A non-freezing liquid will be left in all uncemented annuli within the permafrost interval. Selected intervals within the Sadlerochit interval will be perforated,(cont.) ~ ABo~ SPACE DESC~BE PROPOSED PROGRAM: If propo~l is to deepen give data on present productive zone and proposed new productive zone. If pro~ is to drill or dee~n ~ecfionMly, ~ve pertinent data on sub~ce locations and measured and ~ue verti~ depthg Give blowout prevent~ pro.am. ' 24. I hereby ce~i~ that the Foregoing is ~he and Co~t SIGNED,/ '~"'~'~' ~ ~,'~'&~"-'/ DATE fi )prox (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE CHIPS REQUIRED [ MUD LOG [] YES ~ No [] YES [~ No DIRECTIONAL SURVEY REQUIRED ['~ YES [] NO 77-80 PERNIIT NO. OTHER REQUIREMENTS: A.P.1. NUMERICAL CODE 50-029-20283 APPROVALDATE December 22, 1977 ApPOvEDBY ~~, ~~,~~7~~- · . TITLE Chairman ~ *See Instruction On Reverse Side DATE December 22~ ]977 CHECK LIST FOR NEW WELL PERMITS Company Yes No Remarks 1.Is the permit fee attached ..................... 2. Is well to be located in a defined pool 3. Is a registered survey plat attached ................ a Is well locau~d proper distance from property line ........... ~::.: 5. Is well located proper distance from other wells ....... 6. Is sufficient undedicated acreage available in this pool 7. Is well to be deviated ..................... 8. Is operator the only affected party ................... 9. Can permit be approved before ten-day wait ........ lO. Does opera, tor have a bond in force ll. Is a conservation order needed ............... 12. Is administrative approval needed 13. Is conductor string provided ........... ~14. Is enough cement used to circulate on conductor and surface . ._~ 15. Will cement tie .in surface and intermediate or production strings 16. Will cement cover all known productive horizons .......... 17. Will surface casing protect fresh water zones .......... 18. Will all casing give adequate safety in collapse, tension & burst 19 Does BOPE have sufficient pressure ratina - Test to ~6~ psig 20. Has DHEIi approved Plan of Operation ...... Additional Requirements' .y Approval Recommended' Geology' Enaineerinfl' TRM ~ UAL tIHH ~4~'. JCM ~ Revised 11/17/76