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Home My WebLink About201-045MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-20A PRUDHOE BAY UNIT S-20A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/12/2024 S-20A 50-029-21637-01-00 201-045-0 W SPT 8145 2010450 2036 594 595 592 594 140 182 182 184 4YRTST P Austin McLeod 11/12/2023 MITIA 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 S-20A Inspection Date: Tubing OA Packer Depth 44 2306 2272 2260IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM231113192957 BBL Pumped:5.4 BBL Returned:5.2 Friday, January 12, 2024 Page 1 of 1        • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg r DATE: Thursday,November 19,2015 P.I.Supervisor I l(3"l l c SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. S-20A FROM: Chuck Scheve PRUDHOE BAY UNIT S-20A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT S-20A API Well Number 50-029-21637-01-00 Inspector Name: Chuck Scheve Permit Number: 201-045-0 Inspection Date: 11/14/2015 Insp Num: mitCS151115073412 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-20A Type Inj W'TVD 8145 ' Tubing 716 - 717 ' 715 ' 714 - PTD 2010450 - Type Test SPT Test psi 2036 - IA 361 2505 • 2487 - 2480 - Interval 4YRTST P/F P OA 188 264 - 267 266 - Notes: eek• : () T pie ssuveS (404- (z) ►� SCAi4NED SEP 1 6 2016; Thursday,November 19,2015 Page 1 of 1 • . 0 ... ,r....-, • fIr Z-VF,'h'A ++4 + I .......-, r r"--- h ._. . 1..0 Ili ........_* .„. 1:1 I 1:6 , . a a g . III t' i -, q . R Q1/2 • • ...) -43— • •i.n •Pi i• is ....r '271 I 1 •- i • . !-.., .7-,. t... . . TREE e 4-1/16"CW • SA NOTES: H2S READINGS AVERAGE 125 ppm WELLHEAD= 13-3/8" MCEVOY WH ON MI.WELL REQUIRES A SSSV WHEN ON BAKER S-20A Mi. WELL>70°@ 9370' ***COM•4 ITE WRAP kb. ELEV= 70,697 REPAIR SH LEAK-DO NOT MIT-OA OVER 1200 PIS DUE BF. ELEV = 37' TO •Pi.IGNED PRESSURE RATING OF REPAIR& DO KOP= 4150' NOT PUMP METH OR METH BLEND Iwo OA DUE TO Max Angle= 98°@ 10018' J CHEMICAL INCOMPATIBILITY wl ..*XY RESIN*** Datum MD= 10678' Datum TVD= 8800'SS 2194' H 4-1/2"HES X NIPPLE,ID=3.813" 13-3/8"CSG,724,L-80 BTRS, ID= 12.347" H 2677' -A L Minimum ID = 2.37" @ 9378' 3-3/16" X 2-7/8" LNR XO .. L 8599' 1---1_ 4-1/2" HES X NIPFtE, ID=3.813" 8610' — 9-5/8"TM/HBBP-T PKR, ID=3923" CI 0 8729' — 4-1/2" BKR KB LNR TOP PKR, ID=2,562" 3.75"BKR LNR DEPLOYMENT SLV, ID=3 00" H 8734' 1 3-1/2" FL4S X 3-3/16"TGII XO, ID=2 80" H 8775' 8842' — 4-1/2"HES X NIP,ID=3813" 8853' — 4-1/2"HES X NIP,ID=3.813" 4-1/2"TBG, 12.64, L-80 NSCT1-1 8864' 1 8866' H7-3/4"BKR SEAL ASSY (5.69'OF SEALS IN PBR) 0152 bpf, ID= 3 958" 1 21 [2 8866' —19-5/8"X 7"BROWN LNR HGR MILLOUT WINDOW 9160'-9166' TOP OF WHIPSTOCK @ 9155' 9-5/8"CSG,474, L-80 BTRS, ID=8.681 1—f 9133' --A & RA TAG <., 9165' ...7'...-'..'--iii PERFORATION SUMMARY 9378 —13-3/16"TCII X 2-7/8"STL LNR XO,ID=2.37" REF LOG: GO BHCS OF 08/21/86 ANGLE AT TOP PERF:92°@ 10150' Note: Refer to Production DB for historical perf data L. 1 7 . N SIZE SFF INTERVAL Opn/Sqz DATE 0 . it 10700' --ICIBF(07/20/04) 2' 6 10150-10175 0 07/20/04 2" 6 10285-10310 0 07/20/04 0 . 2" 4 10815-10865 C 07/19/01 t * + NI* [ PBTD —1- 10891' r fpl I 4. t ..'•'..." I I • • 1 2-7/8" LNR,6.16#,L-80,STL,.0058 bpf,ID=2.37" —I 10926' 7"TBG,264,L-80 BTRS,0:0383 bpf, ID=6.276" — 9848' 1.1.•..•A DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/25/86 ROCHIN ORIGINAL COMPLETION 02/15/11 M8/JJ ADDED SSSV SAFETY NOTE WELL: 5-20A 11101/95 ML WORKOVER 02/27/11 TQ/PJC SFTY NOTE(COMPOSITE VVRAP) FF_RNIIT Iiiio:.2010450 07120/01 CHIKAK CT D SIDETRACK , 01/18/12 TMN/JMO ADDEDI-'25 SAFETY NOTE AFI No' 50-029-21637-01 07/20/04 JGIVVKAK SET CIBP,A DPERFS SEC 35,T12N, R12E, 1630'SNL&903'EWL _.. 02/16/09 RMC/SV TREE C/O(01/20/09) 09/23/10 PJC SAFETY NOTE UPDATE BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg ^� DATE: Wednesday, November 13, 2019 P.I. Supervisor �C-1 it (( / 1511 r, SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. S -20A FROM: Lou Laubenstein PRUDHOE BAY UNIT S -20A Petroleum Inspector Type Inj Ste: Inspector TVD Reviewed By: Tubing P.I. Supry 854 NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT S -20A API Well Number 50-029-21637-01-00 Inspector Name: Lou Laubenstein Permit Number: 201-045-0 Inspection Date: 11/3/2019 ' Insp Num: ma1.oL191103124822 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well s -20A Type Inj W TVD 1 8145 ' Tubing 854 854 852 851 - PTD 2010450 'I'ypQ 'I'Qst SP7 TQSt psi 2036 IA 37 2398 2376 2367 - BBL Pumped: a.6 'BBL Returned: 4s OA 240 - 332 - 337 _ 336 - Interval 4YRTST p/F P Notes: Good test Wednesday, November 13, 2019 Page I of I • MEMORANDUM State of UM too Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 21, 2011 TO: Jim Regg � ' 1 p f v P.I. Supervisor l� SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -20A FROM: Chuck Scheve PRUDHOE BAY UNIT S -20A Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv- NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT S - 20A API Well Number: 50 029 - 21637 - 01 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS111221071137 Permit Number: 201 - 045 - Inspection Date: 12/20/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S-20,4 Type In'. W TVD 8145 yp ] 469 2520 " 2532 2500 P.T.D 2010450 'TypeTest SPT Test psi 2036 OA 208 291 303 . 289 I n t erva l 4YRTST 1 P Tubing 695 695 " 695 693 . Notes: Si„„MINED F B 1 ZU1 Wednesday, December 21, 2011 Page 1 of 1 AOGCC MITIA Forms for END I- 1530560), BADAMI B1 -14 (1980630), 6F -13 (1950270... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Sunday, October 31, 2010 3:10 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: AOGCC MITIA Forms for END1 -15 (1930560), BADAMI B1 -14 (1980630), MPF -13 (1950270), MPG -13 (1971200), NGI -07A (2061260), NGI -10 (1760690), S -20A (2010450), S -217 (2070950) Attachments: Oct 2010 MIT Forms.zip Jim, Tom and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: END 1- 15/P -25 PTD #1930560 BAD B1 -14 PTD #1980630 MPF -13 PTD #1950270 MPG -13 PTD #1971200 '[ NGI -07A PTD #2061260 PTD #1760690 S -20A _ PTD #2 1045 S -217 PTD #2070950 <<Oct 2010 MIT Forms.zip>> Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 i 11/1/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.regg(Malaska.aov: doa .aogcc.prudhoe.bay @alaska.gov: phoebe.brooks(cDalaska.gov: tom.maunder @alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / S pad DATE: 09/26/10 OPERATOR REP: Gerald Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I S -20A Type In'. I W TVD 1 '8,145' Tubingl 790 H25 790 790 Interval 0 P.T.D. 2010450 Ty pe test P Test si 2036.25 Casin 100 2480 2480 P/F P Notes: MITIA to evaluate potential TAA comm OA 80 140 140 140 Weill I Type In'. I I TVD I Tubing Interval P.T.D.1 I Type test I I Test psi I Casing P/F Notes: OA Well I Type Ini.1 I TVD I Tubing Interval P.T.D.1 I Type testi I Test psi I Casing P/F Notes: OA Weill I Type InJ.J I TVD I Tubing Interval P.T.D.1 I Type test I I Test psi I Casing P/F Notes: OA Well I Type lnj.1 I TVD I Tubing Interval P.T.D.1 I Type testi I Test psi I 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 S -20 09- 26- 10.xis STATE OF ALASKA APR 3 U 2010ALASKA~ AND GAS CONSERVATION COMMISS~ .;__z__:,,6~ ~,__.,___ ~.RF,~,~Q~T OF SUNDRY WELL OPERATIONS 1. Operations .Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q WELLHEAD Performed: Alter Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ REPAIR Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-ent Suspended Well ^ FURMANITE 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 201-0450 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ .API Number: Anchorage, AK 99519-6612 50-029-21637-01-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-028257 ~ PBU S-20A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 10926 feet Plugs (measured) 10700 feet true vertical 9056.1 feet Junk (measured) None feet Effective Depth measured 10700 feet Packer (measured) 8610 8866 true vertical 8882.4 feet (true vertical) 8145 8361 Casing Length Size MD TVD Burst Collapse Structural Conductor 73 20" 91.5# H-40 33 - 106 33 - 106 1490 470 Surface 2654 13-3/8" 72# L-80 32 - 2677 32 - 2675 4930 2670 Production 9102 9-5/8" 47# L-80 31 - 9133 31 - 8593 6870 4760 Liner 46 3-1/2" 9.3# L-80 8732 - 8778 8249 - 8288 10160 10530 Liner 650 3-3/16" 6.2# L-80 8778 - 9428 8288 - 8758 Liner 293 7" 26# L-80 8867 - 9160 8364 - 8616 7240 5410 Liner 1501 2-7/8" 6.16# L-80 9428 - 10929 8758 - 9059 13450 13890 Pertoration depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1 /2" 12.6# LL-80 29 - 8873 29 - 8369 Packers and SSSV (type, measured and true vertical depth) 4-1/2" TIW HBBP-T Packer 8610 8145 4-1/2" Baker KB Too Packer 8866 8361 12. Stimulation or cement squeeze summary: Intervals treated (measured): `~~~1 (A~ ,y! 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: Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Q Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^~ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sund ry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Ph 564-4944 Date 4/29/2010 Form S-20A 201-045 oC~c ATTA!`IJIIACI~IT • Sw Name Operation Date Perf Operation Code ~Meas Depth Top ~ Meas Depth Base Tvd Depth Top Tvd Depth Base S-20A 7/19/01 PER 10,815. 10,865. 8,960.72 9,002.07 S-20A 7/20/04 APF 10,150. 10,175. 8,736.07 8,735.31 S-20A 7/20/04 APF 10,285. 10,310. 8,737.42 8,740.27 S-20A 7/20/04 BPS 10,700. 10,865. 8,882.41 9,002.07 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE S-20A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 2/26/2010 T/I/O=0/0/ .MIT PASSED to 3000 psi. MIT OA to 1200 psi. Pumped down IA 10 ~bbls meth to test. MIT IA lost 20 psi in 1st 15 mins and 0 psi in 2nd 15 mins for a .total loss f 20 psi in 30 minute test. Bled pressure back to 0 psi. Rigged up to =0A and p mped 4 bbls diesel to pressure up for MIT OA at 1200 psi.***Job in [progress, ontinued on next day*"" 2/26/2010~T/I/O = VAC/VAC/0. Temp = SI. No AL (Inj). Assist FB w/cellar watch (MIT-OA ,well w/ SH leak). Trace fluid found @ 7 o'clock position from upper starting head, cleaned to monitor during MIT-OA. No signs of new fluid from flutes or SH jduring pumping. Bled IA & OA to 0 psi. Heater left in wellhouse. Final WHPs = F VAC/0/0. LRS in control on departure. *Job complete* 2/27/2010~"**Job in progress, continued from yesterday.**"Continue with PASSED MIT OA Ito 1200 psi. MIT OA started at 12:51pm yesterday and carries through today. 'MIT OA lost 70 psi in 1st 15 mins and 30 psi in the 2nd 15 mins for a,total loss of j 100 psi in the 30 minute test. Bled pressures down to 0 psi. Hung tags and notified DSO of well status. Swab-closed, Wing-closed, SSV-Open, Master- ;Open, IA and OA open to gauges. FWHP's=vac/0/0. E _ _ _ 2/27/2010`T/I/0= Vac/25/45. Temp= SI. Bleed IA & OA to 0 psi. Install 50 psi N2 cap on OA, assist w/ sand blasting and open bleed for Furmanite (prep-Furmanite ). IA '& OA FL @ surface. Bled IA & OAP to 0 psi in 20 minutes. Increased OAP to 50 psi using N2. Monitored 1 hour, OAP unchanged. CCI sand blasted SH. Bled OAP from 50 psi to 0 psi in 30 sec. Kept open bleed on OA while Furmanite applied E-glass layer of composite wrap. Night crew will continue assisting ;Furmanite. Job incomplete. Final WHPs= Vac/0/0. SV,WV=closed. SSV,MV=open. IA,OA=open to gauge. NOVP. 2/28/2010~T/I/0=vac/0+/0. Temp=S1. Assist Furmanite w/open bleed on OA. Continue :from day shift (1900 hrs). Maintain open bleed on OA. IAP increased 10 psi in i 11 hrs, no change in OAP. **Job incomplete** jSV,WV=Closed SSV,MV=Open IA,OA=OTG NOVP 2/28/2010T/I/0= Vac/12/0. Temp= SI. Assist Furmanite w/ open bleed for Furmanite (pre- furmanite wrap). Continued w/ open bleed on OA, changed out with night crew @ 7:00 am. Kept open bleed on OA for 12 hours, T &IAP unchanged. Night ;crew changed out. Job incomplete. Final WHPs= Vac/12/0. SV,WV=closed. SSV,MV=open. IA,OA=open to gauge. NOVP. 2/28/2010. Severe cold ambient temps caused the temp in the cellar to drop below the required 70* for the repair. A hooch was built around the SH. Two heaters were directed into well cellar and 1 heater trunk into wellhouse. In the AM, Furmanite Techs inspected the wrap and found the resin had not cured after 24 hours. Ambient temps reached -50* overnight. All heaters remained online and iwellhouse temp was 100°+, the cellar was warm and SC pup joint had dropped close to freezing temps. Due to the unknown lowest temp the resin had reached during the night, the decision was made to cancel the repair and to remove as much as possible. Cleaned SH and well cellar. **Job Cancelled ** 3/1/2010 T/I/0=vac/10/0. Temp=S1. Assist Furmanite w/open bleed. Continue from day shift (1900 hrs). Rig down and replaced grating in well house. placed heater ,trunks in cellar, no pressure between swab valve & tree cap left door cracked for 'ventilation. Final WHPs vac/10/0. SV,WV=Closed SSV,MV=Open IA,OA=OTG NOVP 4/13/2010 T/I/0= VAC/10/10. Temp= SI Bleed IA & OA to 0 psi (prep for Furmanite wrap). No AL (Inj). Containment installed in cellar. Projects trailer, bleed tank, two heaters, N2 trailer on location. Took gravel sample from cellar. Installed heater in cellar and Projects trailer. IA FL @ surface. OA FL near surface. Bled IAP to 0 psi in 5 mins (fluid). Bled OAP to 0 psi in 30 mins (gas/fluid). SI, monitored for !30 mins. IAP & OAP increased 5 psi. Bled IAP & OAP several times to 0 psi. ;Unable to maintain 0 psi. Removed grating from cellar. Hung caution tags for ;floor kit on well house doors. Ordered super sucker for tomorrow @ 8 am. ~FWHPs= VAC/5/5. "**Job Incomplete*** jSV, WV= C. SSV, MV= O. IA, OA= OTG. NOVP. 4/14/2010`T/I/O =Vac/0+/18. Temp = SI. Clean SH, bleed IA & OA to 0 psi, install N2 cap, assist sandblasters. (Furmanite prep). OAP increased 13 psi overnight. Super- ;Suck 3 yards of gravel. BLed OAP to 0 psi. 1.25" of fluid in bleed trailer. Increased OAP to 50 psi w/N2 and purged 3 times before leaving a 50 psi N2 cap for sandblasting. CCI sandblasted well. Performed a "man down" drill with Furmanite and CCI. Bled OAP from 50 psi to 0 psi in 1 min, maintaining an open OA bleed for duration (See log for details). Furmanite completed E-glass wrap on well. FW HPs =Vac/0+/0. ~**Job in progress** ?SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. _.. 4/15/2010T/I/O=Vac/0+/Open. Temp=S1. Maintain open bleed on OA (Furmanite wrap). C/O w/day shift. Maintain open bleed on OA. Turned over to day shift. • 4/15/2010 4/16/2010 T/I/O=Vac/0+/0. Temp=S1. Assist Furmanite & maintain open bleed on OA (Furmanite wrap). No AL. Furmanite Techs applied 1st set of carbon layers. Maintained continuous bleed on OA for 12 hours with no fluid or gas returns. Job in progress. Final WHPs=Vac/0+/0. DHD night crew in control of well. T/I/0= VAC/0+/0 Temp= SI Hold bleed on OA (Furmanite). No AL. Furmanite !finished second carbon layer. Maintain open bleed on OA with no gas or liquid returns. Heaters working properly. Night shift in control of bleed. Maintained ;open bleed on OA, no gas or liquid returns to tank. Heaters working properly. !No change in WHP's during bleed. Day shift taking over job. *Job incomplete* Day shift in control of well 4/17/2010?T/I/O=Vac/0+/0. Temp=S1. Hold open OA bleed (Furmanite wrap). **Continued ;from previous days AWGRS** Maintained open OA bleed, bled IAP to 0 psi as 'needed. Furmanite Techs completed final wrap at 0920 hrs; Composite wrap complete. Begin 7 day curing phase. Final WHPs=Vac/0+/0. **Continued on next days AWGRS"* 4/18/2010~T/I/O=Vac/0+/0. Temp=S1. Open bleed OA for Furmanite wrap (WH Repair). No AL. Maintained continuous bleed on OA for 13 hrs, no fluid or gas returns. Bled IAP from 0+ psi to 0 psi in 10 seconds (fluid/gas). Furmanite took protective wrap doff SH & cleaned up cellar. Job in progress. Final WHPs=Vac/0+/0. DHD night crew in control of well. 4/18/2010T/I/O=Vac/0+/0. Temp=Sl. Open bleed OAfor Furmanite wrap (WH repair). **Continued from previous days AWGRS"" Maintained an open OA bleed, bled IAP as necessary. • C~ 4/19/2010; T/I/O=Vac/3/5. Temp=S1. Monitor OAP BUR (WH repair). IA increased 3 psi, OAP increased 5 psi since 1520 pm. Bled IAP & OAP to 0 psi @ 0020 am. Final W HPs=Vac/0/0. ="**Job incomplete*** SSV, WV=Closed. SSV, MV=Open. IA&OA=OTG. NOVP. ~ 4/19/2010T/I/O=Vac/5/0. Temp=S1. Open Bleed on OA for Furmanite wrap (WH repair). Maintained open bleed on OA for 11.5 hrs. No returns to tank. !Turned well over to day crew. C/O w/ night crew. VAC/5/0. Maintained open bleed on OA until 09:20 (am). SI, monitored for BUR. IAP increased 2 psi, OAP increased 4 psi in 6 hrs. Bled IAP & OAP to 0 psi. FWHPs= VAC/0/0 (16:00). ***Job Incomplete**" SV, WV= C. SSV, MV= O. IA, OA= OTG. NOVP. 4/20/2010 4/20/2010 T/I/O =VAC/4/5.5. Temp = SI. WHPs (post-Furmanite). No AL. OAP increased 4.5 psi over 5 hrs. Bled OAP from 5.5 psi to 0 psi in < 1 min (per WIE). Monitored for 15 minutes. OAP increased 4 psi. Bled-OAP from 4 psi to 0 psi in < 1 min. No monitor. (22:00 hrs) Final WHPs =VAC/4/0. *Job complete* SV, WV =Closed. SSV, MV =Open. IA & OA = OTG. NOVP. T/I/0= VAC/2/9. Temp= SI. Monitor WHPs (post Furmanite wrap), bleed OA if needed. OA FL near surface. Bled OAP from 9 psi to 0 psi in less than 1 min. Monitored for 15 min. OAP increased 9 psi. Bled OAP from 9 psi to 0 psi in less than 1 min. Monitored for 4 hrs. OAP increased 9 psi. Hold open bleed for 2 hrs. Monitored for 30 min. OAP increased 1 psi. Final WHPs= VAC/2/1. (16:00) SV, WV= Closed. SSV, MV= Open. IA, OA= OTG. NOVP. _ _ ___ ~. 4/21/2010 T/I/O =VAC/2/10. Temp = SI. WHPs (post-Furmanite). Bled OA from 10 psi to '0 psi in < 1 min. Monitored for 15 mins. OAP increased to 9 psi. Bled OA to 0 ;psi & maintained open bleed on OA for 1 hr (per WIE). Monitored for 1 hr. OAP increased 2.5 psi. Final WHPs =VAC/2/2.5. s*Job complete" jSV, WV =Closed. SSV, MV =Open. IA & OA = OTG. NOVP. • T/I/O=Vac/Vac/7.5. Temp=S1. Monitor WHPs. (Post Furmanite Wrap). Check OA for fluid to surface, OAP bled from 7.5 psi to 0 psi in 10 seconds (all gas no Fluid). Monitor for 10 minutes. OAP increased 7 psi to 7 psi in 10 minutes. Heater down, could not get re-started, swap out heaters. Monitored for 30 minutes post heater install, OAP increased to 7.5 psi. Checked OA for fluid to surface, OAP decreased to 0 psi in 10 seconds (ALL GAS). Final WHPs=VacNac/0. SV & WV =CLOSED. MV &SSV =OPEN. IA & OA = OTG. NOVP. 4/22/2010T/I/O=Vac/0/6. Temp=Sl. WHPs (post Furmanite). OA FL near surface. Bled OAP from 6 psi to 0 psi in < 1 min (all gas). monitored for 15 min. OAP increased 4 psi. Final WHPs=Vac/0/4. Note: checked fuel level in heater. SV,WV=C. SSV,MV=O. IA,OA=OTG. NOVP. 4/22/2010 T/I/O =VAC/4/9. Temp - SI~WHPs (post-Furmanite). OA FL near surface, while checking OA FL OAP decreased to 0 psi. Monitored for OA build up for 10 .min (per WIE). OAP increased 8.5 psi. Monitored again after 50 mins, OAP unchanged (22:00). Checked OAP & OA FL @ 03:45, OAP had increased 1.5 psi to 10 psi. OA FL near surface, while checking OA FL the OAP decreased to 0 psi. Monitored for 5 mins. OAP increased 9 psi. Checked OA FL @ 04:00, OA FL near surface. While checking OA FL, OAP decreased to 0 psi. SV, WV =Closed. SSV, MV =Open. IA & OA = OTG. NOVP. 4/23/2010 T/I/0=vac/3/10. WHPs (post Furmanite), bleed as needed. OA FL near surface. Bled OAP to 0 psi, monitor for 30 mins, OAP increased 10 psi. Bled OAP to 0 psi, monitor for 15 mins, OAP increased 9 psi. Bled OAP to 0 psi. Final WHPs vac/3/0. SV,WV=Closed SSV,MV=Open IA,OA=OTG NOVP 4/23/2010 T/I/0= VAC/3/9. Temp= SI. WHPs (post Furmanite), bleed as needed. OA FL near surface. Bled OAP from 9 psi to 0 psi in 15 seconds. Monitored for 8 hrs. OAP increased 6 psi. Bled OAP from 6 psi to 0 psi in 15 seconds.. Final WHPs= VAC/3/0. (16:00). SV, WV= Closed. WV, MV= Open. IA, OA= OTG. NOVP. 4/24/2010 T/I/O=Vac/3/8. Temp=S1. WHPs (post Fumanite). No monitor. Final W HPs=Vac/3/0. (0100). SV, WV=Closed. SSV, MV=Open. IA&OA=OTG. 4/24/2010 T/1/0= 0/5/10. Temp= SI. WHPs (post Furmanite). decreased to 0 psi. OA FL near surface. (0900) SV, WV= Closed. SSV, MV= Open. IA, OA= OTG 4/24/2010 4/25/2010 Bled OAP to 0 psi in <1 min. ~~ NOVP. While checking for FL OAP NOVP. T/I/O =VAC/5/10. Temp = SI. WHPs (post-Furmanite). No AL. OA FL near surface. While checking OA FL OAP decreased to 0 psi. SV, WV =Closed. SSV, MV =Open. IA & OA = OTG. NOVP. ;T/I/0= VAC/4/13. Temp= SI. WHPs (post Furmanite). While checking for FL .. !OAP decreased to 0 psi. OA FL near surface (0845). Monitored for 10 minutes 'i& OAP increased from 0 psi to 10 psi. Final WHPs=Vac/4/10. jSV, WV= Closed. SSV, MV= Open. IA, OA= OTG. NOVP. .,-..,.... ~~~e~~ __m___.~a 4/25/2010 T/i/O =VAC/4/14. Temp = SI. WHPs (post-Furmanite). No AL (Inj). OA FL near surface. Bled OAP from 14 psi to 0 psi in < 1 min and maintained open bleed for 1 hour (per WIE, see log for details). Monitored for 30 mins. OAP increased 2.5 psi. (00:10) Final WHPs =VAC/4/2.5. "Job complete* SV, WV =Closed. SSV, MV =Open. IA & OA = OTG. NOVP. 4/26/2010~T/I/O=VAC/1/7. Temp=S1. WHPs (post Furmanite). IAP decreased 3 psi, OAP decreased 3 psi (11:50) Heater and surface liner are still in the well house. SV, WV = C. SSV, MV=O. IA, OA = OTG. _ ._.. ~ _.__... e. ___ __. _ __ _ _ . ~ ___. 4/28/2010 T/I/O=Vac/3/14. Temp SI. MIT-OA w/diesel to 1200 psi PASSED (Eval Furmanite). OA FL near surface. Pumped 55 gallons of diesel to pressure up OA to 1200 psi. OAP decreased 30 psi during the 1st 15 mins & 10 psi during the 2nd 15 mins, For a total loss of 40 psi in 30 mins. Bled back OA to 0 psi. No leaking from Furmanite wrap. Removed surface liner & installed cellar grating. 'Final WHPs=Vac/0/0. SV, WV=C. SSV, MV=O. IA, OA=OTG. FLUIDS PUMPED BBLS 52 DIESEL 52 Total TREE = 41/16" CIW WELLHEAD = 13-318" MCEVOY ACTUATOR = BAKER KB. ELEV = 70.69' BF. ELEV = 37' KOF = 4150' Max Angle = Datum MD = 98 @ 10018' 10678' Datum ND = 8800' SS SAFETY S: WELL > 70 deg @ 9370' AND GOES ,s ~2 O~• HORIZONTAL @ 9646'. 2194' I-I 4-1/2" HES X NIPPLE, ID = 3.813" 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" I~ 267T Minimum ID = 2.37"' @ 9378' 3-3/16" X 2-7/$" LNR XO $5gg' -~ 4-1/2" HES X NIPPLE, ID = 3.813" 8610' 9-5/8" TIW HBBP-T PKR, ID = 3.923" $729' 4-1/2" BKR KB LNR TOP PKR, ID = 2.562" 3.75" BKR LNR DEPLOYMENT SLV, ID = 3.00" ~ 8734' 3-112" FL4S X 3-3/16" TCII XO, ID = 2.80" $776' 4-1/2" TBG, 12.6#, L-80 NSCT, I 8864' .0152 bpf, ID = 3.958" 3-5i8" CSG, 47#, L-80 BTRS, ID = 8.681" 9133' PERFORATION SUMMARY REF LOG: GO BRCS OF 08/21/86 ANGLE AT TOP PERF: 92 @ 10150' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10150 - 10175 O 07120(04 2" 6 10285 - 10310 O 07/20/04 2" 4 10815 - 10865 C 07!19/01 I 7" TBG, 26#, L-80 BTRS, 0.0383 bpf, ID = 6.276" (-~ 9$48' 4-1/2" HES X NIP, ID = 3.813" I 4-1/2" HES X NIP, ID = 3.813" 7-3/4" 8KR SEAL ASSY (5.69' OF SEALS IN PBR} 9-5/8" X 7" BROWN LNR HGR MILLOtJT WINDOW 9160' -9166' TOP OF WHIPSTOCK @ 9155' RA TAG @ 9165' ~ ~\ 9378' --{ 3-3/16" TCII X 2-7/8" STL LNR XO, ID = 2.37" PBTD I-I 10891' 2-718" LNR, 6.16#, L-80, STL, .0058 bpf, ID = 2.37" I-I 10926' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/25/86 ROCHIN ORIGINAL COMPLETION 11!01195 ML WORKOVER 07/20/01 CH/KAK CTD SIDETRACK 07/20/04 JGM/KAK SET CIBP; ADPERFS 02/16!09 RMC/SV TREE C!O (01/20/09} PRUDHOE BAY UNIT WELL; S-20A PERMTf No:~`2010450 API No: 50-029-21637-01 SEC 35, T12N, R12E, 1630' SNL & 903' EWL BP Exploration (Alaska) OPERABLE: S-20A (PTD #2010) Starting Head Leak Repaired • Page 1 of 2 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj Sent: Wednesday, April 28, 2010 1:25 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Schwartz, Guy L (DOA) Cc: NSU, ADW Welf Integrity Engineer; Ohms, Danielle H; Janowski, Carrie Subject: OPERABLE: S-20A (PTD #2010450) Starting Head Leak Repaired All, Well S-20A (PTD #2010450) has passed a MITOA post Furmanite wrap of the startinghead proving the leak has been mitigated and integrity restored. The well has been reclassified as Operable and may be returned to injection. Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 4 t.; ~ ~~.;~ r ~~ a~ s ' :h~k~4 /J~~ W'A.Y uz ~'i From: NSU, ADW Well Integrity Engineer Y~"<~ ~'~.U~y c~~~ -\ ~~, ~~~~ Sent: Thursday, May 14, 2009 7:09 PM 1. To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Ohms, Danielle H Subject: NOT OPERABLE: S-20A (PTD #2010450) Starting Head Leak All, Well S-20A (PTD #2010450) has a confirmed starting head leak after fluid was found to be weeping on the upper threads. The well has been reclassified as Not Operable and needs to remain shut-in until it is repaired. The plan forward is as follows. Obj. Mitigate SH leak 1. S: Set TTP for secure 2. D: Repair SH leak 3. F: MIT-OA to 1200 psi Please call with any questions or concerns. 4/29/2010 • • ~~ BP Exploration (Alaska) Inc. ~ Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 ~ Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~~' .:*~~~J ~iliL ~~ C~ 2~'~~ Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report ot Sundry Operations (10-404) &pad ~ Date 6/25/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls it na al S-Ote 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25l2009 5-03 7811900 1325 NA 7325 NA 92.65 5/20/2009 S-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 S-O6 1821650 0 NA 0 NA 0.9 5/26/2009 S-o7A 1920980 0 NA 0 NA 0.9 5/26/2009 S-OaB 2010520 0 NA 0 NA 0.85 5/27/2009 5-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-70A 1911230 0.5 NA 0.5 NA 3.4 5/31I2009 5-718 1990530 025 NA 025 NA 1.7 5/27/2009 S-72A 1851930 025 NA 0.25 NA 1.7 6/1/2009 S-t3 1821350 8 NA 8 NA 55.3 6/1/2009 S-15 1840170 025 NA 025 NA 3 6/2/2009 S-17C 2020070 025 NA 025 NA 2.6 6/t/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 5-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 -20A 2010450 025 NA ~ 025 Nq 1.3 5/79l2009 5-27 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-228 1970510 0.~5 NA 0.75 NA 3 5/19/2009 S-23 1901270 025 NA 025 NA t.7 5/25/2009 5-248 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982740 0.5 NA 0.5 Nq 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 5-288 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29A11 1960120 0 NA 0 NA 0.85 5/27/2009 S30 1900660 0.5 NA 0.5 NA 5.1 5l37/2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 S-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 5-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 5-35 1921480 0 NA 0 NA .BSin 5/31/2009 S36 1921160 0.75 NA 0.75 NA 4.25 5/27/2009 S37 1920990 125 NA 7 25 NA 11.9 5/27/2009 S-38 1921270 025 NA 025 NA 102 5/27/2009 S-47 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5l30/2009 5-43 1970530 0.5 NA 0.5 NA 7.7 5/28/2009 5-44 1970070 025 NA 0.25 NA 1.7 5/28/2009 5-100 2000780 2 NA 2 NA 27.3 5/29/2009 S-101 2001150 1.25 NA 125 NA 11.9 5l29/2009 5-102Lt 2031560 125 NA 125 NA 71.t 5/37/2009 S-103 2001680 1.5 NA 1.5 NA 11.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 S-706 2010120 1625 NA 1625 NA 17a.3 6/2/2009 S-to7 2011130 225 NA 2.25 NA 28.9 5/18/2009 S-108 2011000 3.5 NA 3.5 NA 40 5/30/2009 S-10s 2022450 2 NA 2 NA 21.3 5/30/2009 S-110 2011290 17.75 NA 11.75 NA 98.6 5/30/2009 S-7t7 2050510 2 NA 2 NA 79.6 5/30/2009 S-772 2021350 0 NA 0 NA 0.5 5/30/2009 5-713 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 5-114A 2021980 125 NA 125 NA 10.2 5/30/2009 5-115 2022300 2.5 NA 2.5 NA 272 5/29/2009 S-176 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 5-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-~7s 2032000 5 NA 5 NA 76.5 5/28/2009 S-119 2041620 1 NA t NA 52 5l30/2009 5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 S-127 2060410 4.5 NA 4.5 NA 53.6 5/28l2009 5-122 2050810 3 NA 3 NA 21.3 5l29/2009 5-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 5-124 2061360 1.75 NA 1.75 NA 11.9 5/26/2009 5-125 2070830 225 NA 225 NA 20.4 5/28/2009 S-126 20710970 125 NA 125 NA 15.3 6!1/2009 5-200 1972390 7 25 NA 1.25 NA 14.5 5/28/2009 5-201 2001840 0 NA 0 NA 0.85 6/19/2009 5-213A 2042130 2 NA 2 NA 13.6 5/29/2009 5-215 2021540 2 NA 2 NA 18.7 6/1/2009 5-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 5-217 2070950 025 NA 0.25 NA 1.7 6/1/2009 S-doo 2070740 2 NA 2 NA 9.a 5/28/2009 5-401 2060780 16 NA 16 NA 99.5 6/2/2009 S-50a 0 NA 0 NA 0.85 5/28/2009 RE: UNDER EVALUATION: S-20A (PTD #2010450) Evaluate if IA.repressurization is exhibit... Page 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj Sent: Sunday, November 30, 2008 9:25 PM 2~~ (~"I~I~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Ohms, Danielle H; Hamilton, Gary N; Hibbert, Nancy; Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: S-20A (PTD #2010450) Evaluate if IA repressurization is exhibited on MI injection Attachments: S-20 TIO.ZIP; S-20A.pdf Ali, Weil S-20A (PTD #2010450) was POP'ed on MI Injection on 11/21/08. The well was brought online Under Evaluation to monitor for signs of TxIA communication. The well has been online for 9 days and has exhibited no signs of communication. Please reference the attached TIO plot and wellbore schematic for visual represen as t~~7Vith the well showing no signs of TxIA communication, a passing AOGCC witnessed test on 12{28107 t~ 2 50 psi, and anon-A000C witnessed test to 4000 psi on 09/20/08 we have returned the well to Operable status and can remain on MI Injection. «S-20 TIO.ZIP» «S-20A.pdf» Please feel free to contact me with any questions. Thank you, Taylor Wellman filling in for Anna DubelAndrea Hughes :~~,.1''~~~~ i.)f- r (y ~ ~~Q~ Office: 659-5102 Pager: 659-5100 x 1154 From: NSU, ADW Well Integrity Engineer Sent: Thursday, October 23, 2008 1:23 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB rea Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controlle ,GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Ohms, Danielle H; Hamilto ary N Subject: UNDER EVALUATION: S-20A (PTD #2010450) Evaluate if IA repressuri ion is exhibited on MI injection Hi all, Well S-20A (PTD #2010450) has been reclassifie o that the well can be swapped to MI and evaluated for possible IA repressurization on MI injection. The last time a well was on MI injection in 12/01, some IA repressurization was observed but the well was swapped back to ater. The most recent MITIA passed to 4000 psi on 09/20/08. The well may be swapped to MI injection. The well ha een added to the Monthly AOGCC Injection Report. The plan forward for the well is 1. Fullbore: MITIA to 4000 ps~ PASSED 2. Well Integrity: Reclassi as Under Evaluation to swap to MI for further evaluation -DONE 3. Operations: Swap t I 4. Well Integrity: nitor WHPs and evaluate if further diagnostics are needed. 12/2/2008 • PBU S-20A PTD 201-045 11 /30/2008 12 Month TIO Pressures -. ,y7~"J~~ \J '_ Month TIO Pressures A UNDER EVALUATION: S-20A ~ #2010450) Evaluate if IA repressur'~n is exhibited on... Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, November 28, 2008 7:47 PM ~~~/A IZ,~ZI U To: Regg, James B (DOA) "l Cc: NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: S-20A (PTD #2010450) Evaluate if IA repressurization is exhibited on MI injection Attachments: ATT73429.txt; S-20 WSR.ZIP; S-20 TIO.doc Jim, Enclosed are copies of the Wireline Service Report from the MIT-iA conducted on 09!19/08 and TIO plots in 12 month and 2 month format. 5-20 was brought back online under MI service on 11420/08. If there is any other information that you ) would like to see let me know. / Thank you, ~~ p(~.~ ,(~ Taylor Wellman filling in for Anna DubelAndrea Hughes II Oftice:659-5102 ~ jl+~~~3 P_,uic.~, Pager: 659-5100 x 1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, November 28, 2008 4:00 PM To: NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: S-20A (PTD #2010450) Evaluate if IA repressurization is exhibited on MI injection Please provide results for MIT done on 9!20/2008 since this is the basis for swapping back to MI. Also, I would appreciate seeing a current TIO plot far this well since it has been on Fine for 30+ days (assuming BP swapped it immediately) Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Thursday, October 23, 2008 1:23 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Ohms, Danielle H; Hamilton, Gary N Subject: UNDER EVALUATION: S-20A (PTD #2010450) Evaluate if IA repressurization is exhibited on MI injection Hi all, Well S-20A (PTD #2010450) has been reclassified so that the well can be swapped to MI and evaluated for possible IA repressurization on MI injection. The last time the well was on MI injection in 12/01, some IA repressurization was observed but the well was swapped back to water. The most recent MITIA passed to 4000 psi on 09!20/08. The well may UNDER EVALUATION: S-20A~'D #2010450) Evaluate if IA repressul~ion is exhibited on... Page 2 of 2 be swapped to MI injection. The well has been added to the Monthly AOGCC Injection Report. The plan forward for the well is as follows: 1. Fullbore: MITIA to 4000 psi -PASSED 2. Well Integrity: Reclassify as Under Evaluation to swap to MI for further evaluation -DONE 3. Operations: Swap to MI 4. Well Integrity: Monitor WHPs and evaluate if further diagnostics are needed. A recent TIO plot and wellbore schematic have been included for reference. «S-20A.pdf» «S-20A TIO plot.doc» Please call with any questions. Thank you, Anna ~?u6e, ~P. E. Well Integrity Coord"rnator GPB Wells Group Phone: {907} 659-5'102 Pager: {907) 659-5100 x1154 • WELL SERVICE REPORT ~ 7~t-c~~ WELL S'2OA JOB SCOPE WAG SWAP UNIT LRS 70 DATE 9/19/2008 DAILY WORK MIT-IA; PUMP DAY SUPV SAUVAGEAU COST CODE PLUS PBSPDWL20-C KEY PERSON LRS-BRENNY TOM NIGHT SUPV SPIELER MIN ID 0" DEPTH 0 FT TTL SIZE 0" DAILY SUMMARY T/I/0=750/120/200 Temp =HOT MIT IA PASSED to 4000 psi (Pre-Wag swap) Pressured IA up to 4000 psi with 7.5 bbls diesel. IA lost 60 psi in 1st 15 mins and 20 psi 2nd 15 mins for a total loss of 80 psi in 30 mins. Bled back - 7 bbls. FWHP's=750/100/200 Valves in following positions -and operator notified of positions and result of job upon LRS departure. Wing open, Swab closed, SSV o en, Master o en, IA o en, OA o en -Well on injection LOG ENTRIES Init-> 750 120 200 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 13:00 Start ticket/ PJSM/ RU to IA 13:41 PT SurFace line to 4500 si 13:44 .5 start diesel 40* 750 120 200 Pum in down IA/ Well on injection 13:54 .5 5 750 2650 250 13:59 .5 7.5 750 4000 350 SD/ Start test 14:14 750 3940 350 15 minutes 14:29 750 3920 350 30 minutes/ Passed/ Bleed down ressure 14:32 Bleed down ressure 15:06 RD 15:32 SB for co. man 15:54 Road to E- ad 16:59 End ticket Final-> 750 100 200 JOB COSTS FLUID SUMMARY 7.5 bbls diesel MIT TEST WELL TYPE PWI TEST #1 REQUIRED TEST PRESSURE 4,000 TEST TYPE MIT-IA FLUIDS USED TO TEST DIESEL START TIME: 13:44 PRE TEST PRESSURES INITIAL PRESSURES 15 MINUTE PRESSURES 30 MINUTE PRESSURES PASS OR FAIL _ ____. TUBING _ ~ 750 _~ ~ _ ~ 750 _ 750 750 IA _ 120 4,000 3,940 3,920 PASS OA 200 350 350 350 COMMENTS PBU S-20A PTD 201-045 10/23/2008 TIO Pressures --- --~-,--- wf- ~_~~--- U7.%f,~.Ci the I . ,. ~h 7:9iiC# i 1lif/[:? -~ == ~=f L.N.%7? ~,-. ~~~~~ -- ~-- ~: ~~~ 7~ ti~i-~~r~~~ ~ i ~ ~ ~ iG/17/ta; ~` 7A'if~nYt • • TRFF = 4" CM/ WELLHEAD= ACTUATOR= 13-3/8"MCEVOY ~ AX~SON KB. ELB/ = BF. ELEV = 70.69' 37' KOP = 4150' Max A n le = 98 10018' Datum MD = 10678' Cetum ND= 8800'SS ( 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.34T' H X77' Minimum ~ = 2.37" @ 9378' 3-3/16" X 2-7/8" LNR XO ( 4-1 /2" HES X NIPPLE, D = 3.813" ~ 8599' 8610' H 412" HES X NIPPLE, ID = 3.813" ' 9-58" TMI HBBP-T PKR, D = 3.923" $729' 4-1 /2"BKR KB LNR TOP PKR, D = 2.562" 3.75"BKR LNRDEF'LOYMENTSLV,ID=3.00" 8734' 3-1/2" FL4S X 3-3/16" TCIIXO, ID= 2.80" 8775' 8842' 4-12" FES X N1P, D = 3.813" 8853' 4-12" HES X NIP, D = 3.813" 4-1/2" TBG, 12.6#, L-80 NSCT, $$64' .0152 bpf, ID= 3.958" 8866' 7-3/4"BKRSEAL ASSY (5.69' OF SEALS IN 8866' 9-518" X T' BROWN LNR HGR 9-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" 9133' FERFORATIONSUMMA RY REF LOG: GO BHCS OF 08/21/86 ANGLE AT TOP PERF: 92 @ 10150' Note: Refer to Production DB for historical perf data SIZE SPF INTl3TVAL Opn/Sqz DATE 2" 6 10150 - 10175 O 07!20/04 2" 6 10285 - 10310 O 07/20/04 2" 4 10815 - 10865 C 07/19/01 7" TBG, 26#, L-80 67RS, 0.0383 bpf, ID = 6.276" H 9848' S ~2 0 •, I HORIZONTAOL @ 9646'L > 70 deg @ 9370' A ND GOES MLLOUT W INDOW 9160' -9166' TOP OF WHIPSTOCK @ 9155' RA TAG @ 9165' 9378' 3-3/16" TCI X 2-78" STL LNR XO, ID = 2.3T' I' HaBP(o7/2o/oa> PBTD 10891' 2-7/8" LNR, 6.16#, L-80, STL, .0058 bpf, ID= 2.37" H 10926' DATE REV BY COMviENTS DOTE REV BY COMMENTS 08/25/86 ROCFAN ORIGINALCOMPLEf10N 11/01/95 M L WORKOVER 07/20/01 CWKAK CTDSIDETRACK 07!20/04 JGM/KA SET CBP; ADPERFS FRUDHOE BAY UNff WFiL: S-20A PERMR No: 2010450 API No: 50-029-21637-01 SEC 35, T12N, R12E, 1630' SNL & 903' EWL BP Exploration (Alaska) S-20A PTD #2410450 ~ • Page 1 of 1 Regg, James B (DOA) From: Lau, John, Jack [IaujjO@BP.com] Sent: Saturday, December 29, 2007 7:31 AM ~,~~ ~ ~ ~I ~ ~~'~' to: Winton_Aubert@admin.state.ak.us; Fleckenstein, Robert J (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSU, ADW Well Integrity Engineer; Lau, John, Jack; Engel, Harry R Subject: S-20A PTD #2010450 ~ ~ Attachments: MIT PBU S-20A 12-28-07.x1s; S-20A.pdf All- .. An electronic copy of the MIT form for WAG well S-20A (PTD #2010450) is attached below. The MITIA passed to 2250 ~ psi, losing 20 psi in the first 15 minutes and 0 psi in the second 15 minutes, with a total pressure loss of 20 psi over 30 minutes. A wellbore schematic has been included for your reference. «MIT PBU S-20A 12-28-07.x1s» «S-20A.pdf» Thank you, < Lam W'e1I Integrity Engineer office (,907} X59-~+52~ IZarn~ot~~r• x2378 l~a~or (~)t_)7) ~~:~9-51(){)x:1923 ~~NNE~~ JAN 2 ~ 2008 1/16/2008 • Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay /PBU / S Pad DATE: 12/28/07 OPERATOR REP: Jack Lau AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ I it~~ Mechanical Integrity Test • Packer Dept Pretest Initial 15 Min. 30 Min. Well S-20A Type Inj. W TVD 8145 Tubing 810 810 810 810 Interval 4 P.T.D. 2010450 Type test P Test psi ./2250 Casing 640 2250 2230 2230 P/F P Notes: MIT-IA for quadrennial UIC compliance. OA 260 370 370 370 AOGCC Rep Bob Noble declined to witness °~ 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 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 INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT PBU S-20A 12-28-07.x1s • TREE = 4" CNV WELLHEAD= 13-3/8"MCEVOY ACTUATOR= AX9-SON KB. ELEV = 70.69' BF. ELEV = 37' KOP= 4150' Max A n le = 98 10018' Datum MD = 10678' Datum ND= 8800'SS 133/8" CSG, 72#, L-80 BTRS, ID = 12.347" ~--~ 2677' Minimum ID = 2.37" @ 9378' 3-3/16" X 2-7/8" LNR XO S ~O~ SAFETYNOTES: WELL>70deg@9370'ANDGOES HORIZONTAL@9646'. 2194' 11 41 /7' FMS X NIPPLE, D = 3.813" 8599' ~--~ 8610' 41 /Z" HES X NIPPLE, ID = 3.813" 9-5/8" 11W HBBP-T PKR, D = 3.923" 8729' 4-1 /2" BKR KB LNR TOP PKR, D = 2.562" 3.75" BKR LNR DEPLOYM~NTSLV, ID=3.00" ~ 8734' 31 /2" FL4S X 33/16" TCII XO, ID = 2.80" $775' 4-1 /2" TBG, 12.6#, L-80 NSCT, $$64' .0152 bpf. ID=3.958" 9-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" H 9133' PERFORATION SUMM4 RY REF LOG: GO BHCS OF 08!21186 ANGLE AT TOPPERF:92 @ 10150' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10150 - 10175 O 07!20/04 2" 6 10285 - 10310 O 07/20/04 2" 4 10815 - 10865 C 07/19/01 7" TBG, 26#, L-80 BTRS, 0.0383 bpf, ID=6.276" ~ 9$4$' 8842' ~- { 41 CL" HES XNIP, D = 3.813" f 8853' 41/2" HES X NIP, D = 3.813" 8866' 7-3/4"BKRSEALASSY (5.69' OF SEALS IN A866~ 9-5/8" X T' BROWN LNR HGR MLLOUT WINDOW 9160' -9166' TOP OF WHIPSTOCK @ 9155' RA TAG @ 9165' ^~' 9378' 33/16" TCI X 2-7/8" STL LNR XO. ID= 2.37" )' HCIBP(07/20/04) PBTD 10891' ~ 2-7/8" LNR, 6.16#, L-80, STL, .0058 bpf, ID = 2.37" ~ DATE REV BY COMMENTS DOTE REV BY COMMENTS 08/25/86 ROCHN ORIGINALCOMPLEfION 11/01/95 ML WORKOVER 07/20/01 CWKAK CTDSIDEfRACK 07/20/04 JGM/KA SETCBP;ADPERFS FRUDHOE BAY UNIT WELL: S-20A PERMIT No: 2010450 API No: 50-029-21637-01 SEC 35, T12N, R12~ 1630' SNL & 903' EWL BP Exploration (Alaska) e e ~~, J\.::~. MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \LascrFichc\CvrPgs _ Inserts\Microfil m _ Marker. doc .~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: RepairWeliD PluQ PerforationslK] Stimulate 00 OtherD Abandon 0 Alter CasingD Pull TubingD Perforate New PoolD WaiverD Time ExtensionD Change Approved Program D Operation ShutdownD Perforate IKI Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development D ExploratoryD 201-0450 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D ServiceŒ 50-029-21637-01-00 7. KB Elevation (ft): 9. Well Name and Number: 70.69 S-20A 8. Property Designation: 10. Field/Pool(s): ADL-OO28257 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 10926 feet true vertical 9056.1 feet Plugs (measured) 10700 Effective Depth measured 10700 feet Junk (measured) None true vertical 8882.4 feet Casing Length Size MD TVD Burst Collapse Conductor 73 20" 91.5# H-40 33 - 106 33.0 - 106.0 1490 470 Liner 46 3-112" 9.3# L-80 8732 - 8778 8248.9 - 8288.0 10160 10530 Liner 650 3-3/16" 6.2# L-80 8778 - 9428 8288.0 - 8757.6 LIner 293 7" 26# L-80 8867 - 9160 8364.0 - 8615.7 7240 5410 Liner 1501 2-7/8" 6.16# L-80 9428 - 10929 8757.6 - 9058.8 13450 13890 Production 9102 9-5/8" 47# L-80 31 - 9133 31.0 - 8592.5 6870 4760 Surface 2645 13-3/8" 72# L-80 32 - 2677 32.0 - 2674.8 4930 2670 Perforation deDth: Measured depth: 10150 -10175,10285 -10310 RECEIVED True vertical depth: 8736.07 - 8735.31,8737.42 - 8740.27 Tubing ( size, grade, and measured depth): 4-112" 12.6# L-80 @ 29 - 8873 SEP 1 6 2004 Packers & sssv (type & measured depth): 4-112" Baker KB Liner Top Packer @ 873~laska Oil & Gas Cons. Commission 4-112" TIW HBBP-T Packer @ 8617 Anchorage 12. Stimulation or cement squeeze summary: ! §\EP) i e> . Intervals treated (measured): 10150 -10310 Treatment descriptions including volumes used and final pressure: 25 Bbls NHCL, 50 Bbls 7.5% DAD, 50 Bbls 9%-1% HCL-HF Acid @ 225 psi 13 Reoresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Me! Water-Bbl Casino Pressure Tubing Pressure Prior to well operation: 0 0 -4992 0 812 Subsequent to operation: 0 0 -2327 0 1652 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ] Copies of Logs and Surveys run - 16. Well Status after proposed work: Daily Report of Well Operations - ! OilD GasD WAGD GINJD WINJ[! WDSPLD Prepared by Garry Catron (907) 564-4657. 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 Garry Catron 304-202 Printed Name Garry Catron Title Production Technical Assistant Signature 9f.n C,.dh. Phone 564-4657 Date 9/14/04 . Form 10-404 Revised 4/2004 ORIGINAL .~ ~ S-20A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/19/04 MIRU UNIT 9. RIH WITH MEMORY LOGGING TOOLS IN 2.2" CARRIER WITH 2.25" GAGE NOZZLE. JOB IN PROGRESS. 07/20104 CONTINUED FROM WSR OF 7/19/04. RIH TO 10750. LOG UP FROM 10750 TO 10500 AT 40 FPM. FLAG PIPE AT 10500 (PINK WITH WHITE STARS). LOG UP TO 10000 AND REFLAG PIPE. (WHITE AND ORANGE). POH. VEIRFY DATA. MU AND RIH WITH CIBP. SET AT 10700' GOOD SURFACE INDICATION TOOL SET. POH LD SETTING TOOLS. MUIRIH WITH SOS PERF GUN #1-2" HSD 2006PJ - 6 SPF - 60 DEG - RANDOM ORIENTATION - FIRE GUN -POH - LD GUN#1 ALL SHOTS FIRED. MUIRIH WITH GUN # 2. TIE AND SHOOT 10150-10175 USING 2" GUNS DETAILED ABOVE. POH. OOH. ALL SHOTS FIRED. JOB IN PROGRESS. 07/20104 SET CIBP @ 10700' 07/21/04 CONTINUED FROM WSR OF 7120104. RIH WITH 2" JS NOZZLE. TAG CIBP FOR DEPTH CONTROL. POH LAYING IN SBG. ON SURFACE LET SBG SOAK. RIH JETTING TBG WIRETURNS TO S-03, CIRCULATE BU.PUMP 25 BBLS NHCL - 50 BBLS 7.5% DAD - 50 BBL 9%-1% HCL-HF ACID, OVER FLUSH WITH 120 BBLS NHCL INJECTION TEST 4 BPM AT 1100 PSI RDMO **** NOTIFY PO 1 PCC TO PUT WELL ON INJECTION **** JOB COMPLETE **** FLUIDS PUMPED BBLS 458 1 % KCL 30 Methonal 43 Diesel 223 Schmoo-Be-Gone 50 10% DAD Acid 50 9:1 Mud Acid 145 NH4CL with additives 999 TOTAL Page 1 /--' lREE= 4" CfoN WELLHEAD = 13-318" MCEVOY ACTIJATOR = AXB.SON KB. ELEV - 70.69' BF. ELEV - 37' KOP= 4150' Max Al1Çle = 98 (å¡ 10018' Datum M) = 10678' Datum lV D = 8BOO'SS 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.347' Minimum D = 2.37" @ 9378' 3-3/16" X 2-7/8" LNRXO 3.75" BKR LNR De:>LOYM:NT SLY ,ID = 3.00" 8734' 877f¡ 3-1/2" FL4SX 3-3/16"TCIIXO, ID= 2.80" 4-1/2" TOO, 12.6#, L-80 NSCT, -0152 bpf,ID=3.958" 8864' 9-5/8" COO, 47#, L-BO BTRS,ID = 8.681" ÆRFORA llON Sl.fII1tv'ARY REF LOG: GO BHCS OF 08/21/86 ANGLE AT TOP PERF: 92 @ 10150' Note: Refer to Production œ for historical perf data SIZE SPF INfERV AL Opn/Sqz DATE 2" 6 10150-10175 0 07/20104 2" 6 10285-10310 0 07/20104 2" 4 10815- 10865 C 07119101 7" TBG, 26#, L-80 BlRS, 0.0383 bpf, ID = 6.276" 9848' ~ S-20A SAÆTY NOTES: WB.L > 70 deg @ 9370' AND GOES HORIZONTAL @ 9646'. 2194' 4-1/2" HES X t-IPPLE, D = 3.813" 4-1/2" BKR KB LNRTOPPKR, D = 2.562" 4-1/2" HES X t-IPRE, ID = 3.813" 9-5/8" 1lW HBBP- T PKR, D = 3.923" 8842' 4-1/2" HES X t-IP, D = 3.813" 4-1/2" HESX t-IP, D =3.813" 7-314" BKRSEALASSY (5.69' OF SEALS IN FaR) 9-5'8" X 7' BROWN LNR HGR MLLOUTWINDOW 9160' -9166' TOP OF WHIPSTOCK @ 9155' RA TAG @ 9165' 3-3116" TCI X 2-7/8" STL LNR XO, ID = 2.37' 2- 7/8" LNR, 6.16#, L-BO, STL, .0058 bpf, ID = 2.37" DATE RBI BY COMvlENTS D6.TE REV BY COMM:NTS 08125/86 ROCHN ORIGINAL COM PLEI'ION 11/01/95 ML WORKOVER 07/20101 CIfKAK CTD SlDErRACK 07/20104 JGMlKM SET cap: AœERFS FRUDHOE BAY Uf\IT WB.L: S-20A PERMIT No: 2010450 API No: 50-029-21637-01 Sa:; 35, T12N. R12E. 1630' SNL & 903' EWL BP Exploration (Alaska) bp ... ..\If.'II. -......~ ~.~ ~.- --:...~ ..~ ~...... .j'~~I\" ". f tJ I ~ 0 4.ç- Memorandum To: G ANC Wellwork Program Date: 6/22/2004 PBSPDWL20C 500 BOPD $50,000 From: Phone: Jim Young, PE, GPB Waterflood 564-5754, cell: 440-8007, hm: 248-0133 AFE: lOR: Est. Cost: Subject: S-20A CIBP. PERF. mud-acid stirn OBJECTIVE/COMMENTS: ) 0 t - 0J 7- S-20ai was sidetracked by N3S in July 2001. Currently, zone 2 is perforated but has reached maturity, so it is proposed to isolate, adperf Z4 and establish injectivity. The mud acid stimulation will clean up the perforations, enabling the well to inject water and MI. The flowback unit will not be required for this job, since the well will be put on water injection immediately after the stimulation. S-20a DETAILS: Completion: 4-1/2" tubing and 4-1/2" x 2-7/8" cemented liner, tested to 3000# wi rig Injectivity: Min. 10: Last TO tag: Last Downhole Ops: Latest H2S level: 4000 BWPD, 124 deg. F, 1000 psi WHP (Zone 2) 2.37" at 2-7/8" liner PBTD @ 10,891 CTD MD Caliper 1/15/04 10 ppm 8-14-00 NOTES: Beware of potential H2S in any returns taken at surface! 1. Trap 1500 psi on the 4-1/2" by 9-5/8" inner annulus. 2. MIRU CT. RU return line to adjacent well (S-02)or returns tank. Be aware of the potential for H2S in the returns. 3. Set Cast-iron Bridge Plug at approx. 10700' MD (error on the shallow-side as objective is to cover perforations at 10815' MD 4. RIH w/ memory GRlCCL tag CIBP & flag-pipe. 5. Perforate 50' per adperfform dated 4-04. 6. MU jetting nozzle. Pump minimum rate while RIH and tag PBTD for depth control. 7. Attempt to establish injection rate into the perfs. 8. Circulate 25 bbls ofNH4CI followed by 50 bbls of7.5% HCl followed by 50 bbls of9:1 mud 6/23/2004 acid and NH4CI while reciprocating the coil across perfs. Circulate at maximum rate and take returns until acid reaches the nozzle. After 10 bbls ofHCL acid is washed across the perfs, SI well, pull above the top perfs and displace acid at maximum rate with a maximum WHP of 4000 psi*. 25 bbls 3% NH4CI with 10% U-66 and 0.2% FI03 50 bbls 7.5% HCI 50 bbls 9% - 1% HCI-HF 100 bbls 3% NH4CI with 10% U-66 and 0.2% FI03 overflush (behind pipe) * Go to 4000 psi during the first half of the HCI stage if necessary to establish injection. Once mud acid is at the perfs the maximum treating pressure should be 2000 psi. All fluids should be filtered to 3 microns. Please note the initial and final injectivity in the WSR summary. Please note the rates and pressures in the WSR when each stage hits the perfs. Please run a cable so that the pump truck can record back side WHP on the treating report. Please e-mail the EXCEL treating report (5 minute readings) to the program author. 9. POOH. Bleed lAP. RDMO. ****NOTIFY DSO TO BRING WELL BACK ON INJECTION.**** Treatment Design: "" 125 bbls 3% NH4CI water with 10% U-66 and 0.2% FI03 2100 gal 7.5% HCI 0.5% A261 0.5% A201 20 ppt L58 0.2% FI03 0.5% W54 0.5% W35 2100 gal 9/1 HCI/HF 0.5% A261 0.5% A201 20 ppt L58 0.2% FI03 0.5% W54 0.5% W35 Please note the acid titrations and iron ppm on the WSR. 6/23/2004 2 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Development D Exploratory D / StratigraphicD Service ŒI 9. Well Name and Number: S-20A /' 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY I Effective Depth MD (ft): IEffective Depth TVD (ft): 10892 8955.1 ~m MD WD ."'-""" 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: Suspend 0 RepairWell 0 Pull Tubing 0 BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 70.69 KB 8. Property Designation: ADL-028257 11. Total Depth MD (ft): 10926 Casing I Total Depth TVD (ft): 9056.1 Length Conductor 73 20" 91.5# H-40 Liner 46 3.1/2" 9.3# L.80 Liner 650 3-3/16" 6.2# L.80 Liner 293 7" 26# L-80 Liner 1501 2.7/8" 6.16# L.80 Production 9102 9-5/8" 47# L-80 Surface 2645 13-3/8" 72# L-80 Perforation Depth MD (ft): I Perforation Depth TVD (ft): 10815 - 10865 8960.7 - 9002.1 Packers and SSSV Type: 4-1/2" Baker KB Liner Top Packer 4-1/2" TIW HBBP-T Packer 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 00 BOP Sketch 0 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: June 8, 2004 Date: w -. -. . - ~ . " - . 1:/1/4-- ~ orl Operation Shutdown D Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Perforate!!] WaiverD StimulateD Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Nu!J!ber: 201-0450/ 6. API Number / 50-029-21637-01-00 Annular DisposalD OtherD Plugs (md): None Burst Junk (md): None Collapse top bottom top bottom 33 106 33.0 106.0 8732 8778 8248.9 8288.0 8778 9428 8288.0 8757.6 8867 9160 8364.0 8615.7 7240 5410 9428 10929 8757.6 9058.8 13450 13890 31 9133 31.0 ~592.5 6870 4760 32 2677 32.0 - 2674.8 ~f"\~ 2670 I Tubing Size: I Tubing ~rade: ITu~n~J,ft;~¡;;:IV-;f'\ 4.5 " 12.6 # L-80 I ~9' -rIrI Packers and SSSV MD (ft): MAY 2 d 2 8~ 004 8617 Q¡&Gaseoo 13. Well Class after proposed work: ~ ~ Exploratory 0 DevelopmentD Serviceoo /' 1490 10160 470 10530 15. Well Status after proposed work: Oil 0 GasO PluggedO AJ>andonedO WAG D GINJD WINJŒ /" WDSPLD Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Ji7f\f~1 Contact Jim Young S;"7.).. 0 <f Title Phone Petroleum Engineer 564-5754 5/25/04 Commission Use Only I Sundry Number3óLf ~2IJ 1- Plug Integrity 0 BOP TestO Conditions of approval: Notify Commission so that a representative may witness Location Clearance 0 Other: Subsequent Form Required: 10 .. 404- Orig¡n:]Î Sig1"led 8y Júr.¡¡ K. Norm~n Approved by: Form 10-403 Revised 12/2003 Mechanciallntegrity Test 0 .... Bfl 'JUM 0 2 7004 U / DL BY ORDER OF THE COMMISSION Date: ORIG![~AI SUBMIT IN DUPLICATE r-. r'\ PERFORATING PROCEDURE Well: Date: S-20A 3.22.04 API #: 50-029-21637-01 Prod Engr ,J v:~~~~------- ------ -- - -- ----- - CC or AFC: PBSPDWL20C --- ---- Description: ADD PERF/CTU Detail Code: lOR 250 Type C Attachment: Tie in log with proposed perfs annotated Reference Log Tie in Log Log: MWD GR/CCL Date: 2t4ï¿003 3/9/2ÔÔ3 - - Company: SWS SWS Depths (from-to) r Depths (from-to) 10,285' 10,310' 10,285' 10,310' 10,150' 10,175' / 10,150' 10,175' Gas Jetting Expected? Requested Gun Size: No 2" Charge: Desired Penetration: Office Ph: 564-5754 -- - ----- ----- Home Ph: 248-0133 Cell/Pager: 440-8007 - ------- - WBL Entries Work Desciption /' CT set IBP, memory log, aperf 50', mud-acid stim Well Obiectives and Loaaina Notes: Feet 25 25 SPF 6 spf ~ At what Depth? PJ2006 HMX Max Is Drawdown Necessary/DesiredJUnnecessary During Perforating DBscribB bBlow how to achlB.B drawdown (chøck wi Pad OpBrator to SBB if nøcBssary plptng IS tnstallBd) (B,g N2 Lilt, Hard/tnB Lilt Gas, Gas Lilt, Flow WB/I, Bacldlow Through Dratn or Hard/tnB) Tie in to Jewelry @ MD Minimum ID: 2.37 in Tail Depth: NA ftMD Last Tag: NA ft MD on Well: S-20A _-m--_____----- Date: API#: General Comments: Balance O/B/U O/B/U O/B/U O/B/U O/B/U Depths Referenced to BHCS Gun Dia. ,m---- "m Tie in using: Min ID Type: Casing Size: Est Res. Pres. @ Perforation Summary 50-029-21637-01 ----------------------- Orient. ,._---,---~,- ,-_.',-,.,---,-,-- -- ----~- --- -- Add 0 to the tie-in log to be on depth with the reference log. Orient. Phasing 600 60° Entry Hole Diam: feet Vel'.. .6I04IO1 II H2SLevel: II -- 2Ö ,,¡)n11fï6lOij Zone Z4 Z4 AdlRellperf APERF APERF N/A No, however a flowback may be need to establish injection,_- 2-7/8 in 1Ö,81s"MD is Set CIBP -10700', tag with Mem GR/CCL XO @ 9,378 'MD Prod Engr: PBTD SPF Phasing 00 00 0 - -- --- ...-- 3500 psi Summary Dist Town: Anch Prod Engr P.D. Center Zone AperflReperf - - - ....-.,- - - ----,--- '._m__.. -- -- "......... .- lREE= W8l.HE'AD = AClUATOR= KB. ELEV = BF. ELE.V = KOP= Wax Angle = Datum M) = DatumlVD= 4" aN 13-318" MŒIIOY AXB.SON 70.69' 37' 4150' 98 @ 10018' 10678' 8800' 55 I 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" H 2677' I Minimum D = 2,37" @ 9378' 3-3/16" X 2-7/8" LNRXO I 3.75' BKR LNRDEPLOY~NTSLV,ID =3.00" H I 3-1/2" FL4SX 3-3/16"TCIIXO, ID= 2.80" H 8734' I 877ft I I 4-112" TOO, 12.6#, L-80 NSCT, H .0152 bpf, ID = 3.958" I . 8864' 9-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" H 9133' PffiFORA TION SUMIIAA RY REF LOG: GO BI-CS OF 08/21186 ANGLE AT TOP PERF: 42 deg @ 10815' f\bte: Refer to A"oduction DB for historical perf data SIZE SFF INTERVAL OpnlSqz DATE 2" 4 10815' - 10865' 0 07/19/01 I 7" TBG, 26#, L-80 BlRS, 0.0383 bpf, ID = 6.276" H DA TE REV BY CO~ENTS 08125'86 ROCHN ORIGINAL COMPLETlON 11/01/95 ML WORKOVER 01/09101 SIS-OAA CONVERTED TO CA NIl AS 03113101 SIS-M) FINAL 05'28101 CHnP CORRECllONS 9848' I r'\ 8-2 OA /' SAFETY NOTES: WB.L > 70 deg @ 9370' AND GOES HORIZONTAL @ 9646'. r---J - -----f ~ H 4-112" I-ESX NPPLE, D =3.813" I 2194' - ---I 8599' H 4-1/2" I-ESX NlPRE,ID =3.813" I :8: z---1 8610' H 9-518" llW HBBP- T PKR, D = 3.923" I <g 8 I 8729' H 4-1/2" BKR KB LNRTOPPKR, D =2.562" I '-----" I 8842' H 4-1/2"I-ESXNlP,D=3.813" I I 8853' H 4-1/2" I-ES X NIP, D = 3.813" I I '~ 8866' H7-3I4" BKRSE'ALASSY (5.69' OF SEALS IN FaR) I ~ IZL1 8866' H 9-5'8" X 7" BROWN LNR HGRI I----- MLLOUTWII'ÐOW 9160'-9166' TOP OF WHIPSTOCK @ 9155' RA TAG @ 9165' ~ I 9378' H3-3/16"TCIX2-718"STLLNRXO,ID=2.37" I .,/'" 10891' I /' I 2-7/8"LNR.6.16#,L-80,STL,.0058bpf,ID=2.37" H 10926' I DA TE REV BY COM~NTS 07/20101 Oi/KAK CTD SIDErRACK FRUDHOE BA Y UNT WB.L: S-2OA PERMIT No: 201-045 API No: 50-029-21637-01 1630' SNL & 903' EWL, Sec. 35, T12N, RG12E BP Exploration (Alaska) ( f STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us'~fi OPERATOR: BP Exploration (Alaska) Inc. FIELD I UNIT I PAD: Prudhoe Bay / PBU / S Pad DATE: 12/24/03 OPERATOR REP: Anna Dube AOGCC REP: AOGCC representative not on slope to witness. \ ~I 't'¡l ð3> Packer Depth Pretest Initial 15 Min. 30 Min. Well S-20A Type Inj. F TVD 8,145' Tubing 725 725 725 725 Interval 4 P.T.D. 2010450 Type test P Test psi 2,036 Casing 30 2,500 2,460 2,440 P/F P Notes: 4 Year required test. AOGCC representative not available to witness test. Well Typelni. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Ini. TVD Tubing Interval P.T.D. Type test Test psi CasinQ P/F Notes: Well Type Ini. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: " Well Type Ini. TVD Tubing Interval P.T.D. Type test Test psi CasinQ P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover a = Other (describe in notes) stú~\NNE[),> DEC 3 1 2003 MIT Report Form Revised: 06/19/02 2003-1224_MIT _PBU - S-20A.xls ( Permit to Drill 2010450 DATA SUBMITTAL COMPLIANCE REPORT 7/30/2003 Well Name/No. PRUDHOE BAY UNIT S-20A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-21637-01-00 MD 10926 ~"-' TVD 9056 .~" Completion Dat 7/20/2001 -'-'- Completion Statu WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log N._~o Sample N_go Directional Survey N_go (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Scale Media No Start Stop CH Received Number Comments DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type ~edia Fmt Name ~ D Ind Induction/Resistivity 1 9159 ~ 8567 ~ D GR Gamma Ray 1 9159 rD-"-- .... D ..Directional Survey FINAL [~.-~"' ~ .---Dl~ectional Survey FINAL L---'''''~'' ~ r..G~pensated Neutron 2 FINAL 8567 Log ~ ~..-~. ;1.O2-85 FINAL 8567 10926 Open 12/19/2001 'd13~88 10890 Case 9/12/2001 ~5 10926 Open 12/19/2001 ~-0~88 ch 9/7/2001 10890 ch 9/7/2001 CH 9/14/2001 10890 CH 9/14/2001 ~ 8567-10890 Directional Survey Digital Data Directional Survey 8567-10890 BL, Sepia 8567-10890 digital data Well Cores/Samples Information: Interval Name Start Stop Sent ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? Analysis R P.c.P. iv~.d ? Comments: Received Dataset Number Comments Daily History Received? Formation Tops Permit to Drill 2010450 DATA SUBMITTAL COMPLIANCE REPORT 7~30~2003 Well Name/No. PRUDHOE BAY UNIT S-20A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-21637-01-00 MD 10926 TVD Compliance Reviewed By: 9056 ,pletion Dat 7/20/2001 , Completion Statu WAGIN Current Status WAGIN UIC Y Date: __~_~__~ ~t.O ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging_ Perforate _ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1630' FNL, 902' FWL, Sec. 35, T12N, R12E, UM At top of productive interval Service Well At effective depth 1586' FSL, 960' FWL, Sec. 35, T12N, R12E, UM At total depth 1591' FSL, 945' FWL, Sec. 35, T12N, R12E, UM 5. Type of Well: Development __ Explorato~__ Stratigraphic__ Service__X (asp's 619065, 5979855) (asp's n/a) (asp's 619158, 5977794) (asp's 619143, 5977798) 6. Datum elevation (DF or KB feet) RKB 71 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-20A 9. Permit number / approval number 201-045 10. APl number 50-029-21637-01 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool' 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2642' Intermediate 9100' Liner 294' Sidetrack Liner 2197' 10926 feet Plugs (measured) 9056 feet 10891 feet Junk (measured) 9025 feet Milled Window in 7" @ 9160'- 9166'. TD Tag @ 10891 (08/29/2001) Size Cemented Measured Depth True Vertical Depth 20" x 30" 72 c.f. concrete 13-3/8" 3720 cf AS Ill, 465 cf AS II 2677' 2675' 9-5/8" 1981 c.f. Class 'G' 9133' 8593' 7" 345 c.f. Class 'G' 8866'- 9160' 8363'- 8616' 3-3/16"x2-7/8" 129 c.f. Class 'G' 8729' - 10926' 8247' - 9056' Perforation depth: measured Open Perfs 10815' - 10865' true vertical Open Perfs 8961' - 9002'. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6~, L-80 TBG ~ 8610' MD. Tubing Tail ~ 8864'. 9-5/8" x 4-1/2" TIW HBBP-T PKR ~ 8610'. 4-1/2" BKR KB LNR TOP PKR ~ 8729'. 9-5/8" X 7" BROWN LNR HGR ~ 8866', 4-1/2" HES X Nipple ~ 2194' 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 09/02/01 Subsequent to operation 09/11/01 Representative Daily Averaqe Production orlniection Data OiI-Bbl Gas-Mcf Water-Bbl 0 0 11319 0 18696 0 Casing Pressure Tubing Pressure 2100 28OO 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil _ Gas _ Suspended _ Service WAG Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. . ~~/~f~¢'~'~~~ Title: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · Date September 15, 2001 Prepared by DeWayne R. Schnorr 564-5174,,,. SUBMIT IN DUPLICAT~ S-20A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08/24/2001 08/29/2001 08/30/2001 09/09/2001 08/24/01 08/29/01 ACID: D/T (PRE ACID STIM.) ACID: MUD ACID STIMULATION INJECTION: START WATER INJECTION INJECTION: SWAPPED TO MI GAS INJECTION EVENT SUMMARY DRIFT TBG W/1 1/2" ROLLER STEM W/2" CENT & SB. SLOWED TO A STOP @ 9524' SLM (DEVIATION). HAVE SMALL SAMPLE OF SCHMOO. RDMO. RETURN WELL TO PCC FOR INJECTION. RIH AND TAGGED PBTD, CORRECTED THE DEPTH OF 10891'. TRIED TO ESTABLISH INJECTION RATE INTO THE PERFS AT 10800', BUT WELL LOCKED UP. WASHED THE PERFS WITH NH4CL FOLLOWED BY 6 BBLS HCL ACID, WITH WELL OPEN, DID ONE PASS WITH HCL ACID ACROSS PERFS, SI WELL, PUMPED 94 BBLS HCL ACID INTO THE PERFS. WHP DROPPED FROM 2500 PSI TO 1650 PSI WITH HCL AND CONTINUED TO DROP WHEN THE MUD ACID HIT THE PERFS. 47 BBLS MUD ACID BEHIND PIPE. 200 PSI FINAL WHP AFTER MUD ACID. OVER FLUSHED WITH 150 BBLS NH4CL, WHP BUILT BACK UP TO 1480 PSI. POOH. ****NOTIFIED DSO TO BRING WELL BACK ON INJECTION.**** 08/30/01 START WATER INJECTION 09/09/01 SWAPPED TO MI GAS INJECTION Fluids Pumped 1 PRESSURE TEST LUBRICATOR TO 3000 PSI W/DIESEL. 35 2%KCL WATER 8 50/50 METHANOL/WATER 200 NH4CL 47 MUD ACID (IRON<50 PPM, TITRATE 9.6% HCL--1% HF) 94 HCL (IRON<50 PPM, TITRATE 7.9) 385 TOTAL Page 1 Transmittal Form BAKER HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference: S-20A Prudhoe Bay Unit Contains the following: 1 LDWG format disk 1 listing 1 set films (3 films: GR MD, ResistivitY MD and TVD) 1 set prints (3 prints: GR MD, Resistivity MD'and:TVD). LAC:15928 Sent By: Iuliana Craiciu Received By: ~ O~ -- Date: Dec 17, 2001 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (403) 537-3767 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 RECEIVE DE'O 19 2001 Alaska Oit a ' '- ' ~. ~as GOA~,, { ~c~r~e '..:... '.2' .-7..' .;'. .... · '.; %t.'....:.-':~i;::-."...:..__:'...'i --~E-'."'_"': :.-":' :'.'.2:.'."': ;:. ;!7' ,;~: ..-. ~ .:~.-_:-?~{.:----,,:. '1,.': 127 7 ..... · ....... · ::i::-...--" :.::_. b.... ~_ .;......%-_: ........... ~. :- ..-. ..... ]~ ........ i~. ........ · Li:"~.:~'.:' '"':.'-.. :.:~'. · '..' . :2'. 7-._' '~.:...." ".:,],'::. -?.:-...::_:-.. ....... ,-:~ :-.._-:~t".-'..= .--::----_--. ::_~:-~:.. .......... : .- ........ .:-._-:-... :-.._ ...-:.: .- :::. - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ MUD ACID STIM Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 .. Anchorage, AK 99519-6612 5. Type of Well: Development _ Exploratory._ Stratigraphic__ Service_X 4. Location of well at surface 1630' FNL, 902' FWL, Sec. 35, T12N, R12E, UM At top of productive interval Service Well At effective depth 1586' FSL, 960' FWL, Sec. 35, T12N, R12E, UM At total depth 1591' FSL, 945' FWL, Sec. 35, T12N, R12E, UM (asp's 619065, 5979855) (asp's n/a) (asp's 619158, 5977794) (asp's 619143, 5977798) 12. Present well condition summary Total depth: measured true vertical 10926 feet 9056 feet Plugs (measured) 6. Datum elevation (DF or KB feet) RKB 71 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-20A 9~/approval number 1 o.'")[1:~r"'h-u m be r 50-029-21637-01 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool Milled Window in 7" @ 9160' - 9166'. TD Tag @ 10891 (08/29/2001) Effective depth: measured 10891 feet true vertical 9025 feet Junk (measured) Casing Length Size Conductor 110' 20" x 30" Surface 2642' 13-3/8" Intermediate 9100' 9-5/8" Liner 294' 7" Sidetrack Liner 2197' 3-3/16"x2-7/8" Cemented Measured Depth True Vertical Depth 72 c.f. concrete 3720 cf ASIII, 465 cf ASII 2677' 2675' 1981 c.f. Class 'G' 9133' 8593' 345 c.f. Class 'G' 8866'- 9160' 8363'- 8616' 129 c.f. Class 'G' 8729'- 10926' 8247'- 9056' Perforation depth: measured Open Perfs 10815' - 10865' true vertical Open Perfs 8961' - 9002'. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 TBG @ 8610' MD. Tubing Tail @ 8864'. 9-5/8" x 4-1/2" TIW HBBP-T PKR @ 8610'. 4-1/2" BKR KB LNR TOP PKR @ 8729'. 9-5/8" X 7" BROWN LNR HGR @ 8866', 4-1/2" HES X Nipple @ 2194' 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 08/28/01 Subsequent to operation 08/30/01 OiI-Bbl 0 Representative Daily Average Production or Iniection Data Gas-Mcf Water-Bbl 0 4 0 0 8404 Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _ 16. Status of well classification as: Oil _ Gas __ Suspended __ Service X 17. I hereby certify that the foregoing is truce and correct to the best of my knowledge. ~~~2C,~t.3~ Title: Technical Assistant e ayne .Sc norr__.- Form 10-404 Rev 06/15/88 · ORiGInAL Date Auqust 31,2001 Prepared b~, DeWar, ne R. Schnorr 564-5174 SUBMIT IN DUPLICATE S-20A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08/24/2001 ACID: D/T (PRE ACID STIM.) 08/29/2001 ACID: MUD ACID STIMULATION EVENT SUMMARY 08/24/01 DRIFT TBG W/1 1/2" ROLLER STEM W/2" CENT & SB. SLOWED TO A STOP @ 9524' SLM (DEVIATION). HAVE SMALL SAMPLE OF SCHMOO. RDMO. RETURN WELL TO PCC FOR INJECTION. 08/29/01 RIH AND TAGGED PBTD, CORRECTED THE DEPTH OF 10891'. TRIED TO ESTABLISH INJECTION RATE INTO THE PERFS AT 10800', BUT WELL LOCKED UP. WASHED THE PERFS WITH NH4CL FOLLOWED BY 6 BBLS HCL ACID, WITH WELL OPEN, DID ONE PASS WITH HCL ACID ACROSS PERFS, SI WELL, PUMPED 94 BBLS HCL ACID INTO THE PERFS. WHP DROPPED FROM 2500 PSI TO 1650 PSI WITH HCL AND CONTINUED TO DROP WHEN THE MUD ACID HIT THE PERFS. 47 BBLS MUD ACID BEHIND PIPE. 200 PSI FINAL WHP AFTER MUD ACID. OVER FLUSHED WITH 150 BBLS NH4CL, WHP BUILT BACK UP TO 1480 PSI. POOH. ****NOTIFIED DSO TO BRING WELL BACK ON INJECTION.**** Fluids Pumped I PRESSURE TEST LUBRICATOR TO 3000 PSI W/DIESEL. 35 2%KCL WATER 8 50/50 METHANOL/WATER 200 NH4CL 47 MUD ACID (IRON<50 PPM, TITRATE 9.6% HCL--1% HF) 94 HCL (IRON<50 PPM, TITRATE 7.9) 385 TOTAL Page 1 STATE OF ALASKA~[~' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service I-'1TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-045 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21637-01 :4. Location of well at surface ~: ...................... 1~ 9. Unit or Lease Name 1630' SNL, 903' NWL, SEC. 35, T12N, R12E, UM At top of productive interval Prudhoe Bay Unit 3693' SNL, 962' NWL, SEC. 35, T12N, R12E, UM At total depth . ~iE'~-:~i" 10. Well Number ,, s- 0^i 3688' SNL, 945' NWL, SEC. 35, T12N, R12E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial' No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 70.69' ADL 028257 12. Date Spudded7/14/2001 113' Date T'D' Reached 114' Date c°mp'' susp'' °r Aband'7/16/2001 7/20/2001 I15' Water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 10926 9056 FTI 10892 9026 FTI [] Yes [] NoI (Nipple) 2194' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, CCL, CNL, TEMP, RES 23. CASINGr LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED , 20" Conductor Surface 110' 3 cu yds Concrete 13-3/8" 72# L-80 35' 2677' 17-1/2" 3258 cu ft AS II1~ 465 cu ft AS II 9-5/8" 47# L-80 33' 9133' 12-1/4" 1981 cu ft Class 'G' 7" 26# L-80 8866' 9160' 8-1/2" 345 cu ft Class 'G' 2-7/8. x3-3/16. 6.2# / 6.16# L-80 8729' 10926' 3-3/4" 129 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) ' SiZE ........ DEPTH SET (M,D,) '' ' P'ACKER SET (M'D) " 2 Gun Diameter, 4 spf ......... ~'-i/~", 1'2.6~, L-SO "88'66' '"86'i0' MD TVD MD TVD ...................... 10815'- 10865' 8961'- 9002' '26.' ..... ACID, FRACTURE, CEMENT SQuEEzE, ETc. DEPTH INTERVAL (aD) AMOUNT & KIND OF MATERIAL USED 1650' Freeze Protected with 25 Bbls of Crude 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) August 1, 2001 water & Gas Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD I Flow Tubing 3asing Pressure CALCULATED OIL-BBL GAS'MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Alaska Oil & Gas Cons. Con'~r'nission , Anchora,qe ,, Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Shublik 'B' 9257' 8688' Shublik 'C' 9282' 8703' Top of Sadlerochit 9341' 8729' 45P 9400' 8750' 44P 9505' 9576' 31N 10683' 8873' 25P 10885' 8950' , 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble~~ ~Title Technical Assistant Date (~'c~j. ................ ' ~..1 .......... S-20Ai 201-045 Prepared By Name/Numbec Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 BP EXPLORATION Page' 1 of 5 Operations Summary Report Legal Well Name: 8-20 Common Well Name: S-20A Spud Date: 8/9/1986 Event Name: REENTER+COMPLETE Start: 7/1 1/2001 End: 7/20/2001 Contractor Name: NABORS Rig Release: 7/20/2001 Rig Name: NABORS 38 Rig Number: Date From - To Hours Activity Code NPT Phase Description of OPerationS ......... 7/11/2001 lO:O0 - 23:00 13.00 RIGU P PRE MIRU Nabors 38 from Milne Pt. 1-04 23:00 - 00:00 1.00 RIGU P PRE Start N/U BOPE. Accept rig at 2300 hrs 07-11-2001 7/12/2001 00:00 - 03:00 3.00 RIGU P PRE Continue N/U BOPE. (DS unit ~ on location @ 0130 hrs and spot same) 03:00 - 03:30 0.50 BOPSUF P ABAN Pull BPV and install TWC. Well on vacuum. Close master valve. 03:30 - 05:45 2.25 BOPSUI; P ABAN Change upper pipe rams from 2 7/8" back to 3 1/2". Finish preparations for testing BOP. (Spot ROC) 05:45 - 14:45 9.00 BOPSUF P ABAN Pressure test BOP's. Witnessing wavied by AOGCC rep Chuck Scheve. 14:45 - 16:00 1.25 BOPSUF P ABAN Pull TWC. RU hardline to flowback tanks. 16:00 - 18:00 2.00 RIGU P ABAN Unstab E-line coil; stab rock. 18:00 - 21:55 3.92 BOPSUF P ABAN Make-up CTC and pull test to 30k# PT to 3500 psi. Stab on well and PT inner reel valve and pack-off. 21:55 - 22:45 0.83 PXA P ABAN PJSM discuss P/A procedure and job assignments. 22:45 - 23:45 1.00 PYA P ~ABAN Make-up BHA #1 (71.27') 23:45 - 00:00 0.25 PYA P ABAN RIH. Same time bullhead down annulus with seawater. 7/13/2001 00:00 - 02:10 2.17 PYA P ABAN Finish RIH and bullheading 260 bbls of seawater at a constant rate of 3 bpm and 300 psi down annulus Tagged whipstock at 9181' uncorrected. Correct depth back to 9155'. P/U to 9145'. 02:10 - 02:50 0.67 PYA P ABAN Switch to Nabors pump and line-up to pump down CT. With well shut-in establish injectivity rate 3.2 bpm 2400 CTP, 190 WHP. Open choke circ rates 3.1/2.1 and 1.0/0.8 make final prep work with cementers. 02:50 - 05:30 2.67 PXA P ABAN With well open start w/5 bbl water ahead. PT lines to 4000 psi. Follow with 5 bbl neat then 80 bbls 13.8 ppg 'G' w/20 ppb aggregate then 5 bbls neat. Dipslace with 1.5# Bio (Shut-in well 5 bbls prior to cement exit from CT). WHP increased to 710 psi at 3.0 BPM after 77 bbls into perfs. CIP @ 0400 hrs. Stopped pumping and pulled to safety leaving 14 bbls cement on top of whipstock. Hesitation squeeze 12 bbls cement to 550 psi over 90 min time. 05:30 - 06:05 0.58 PYA P .ABAN Open well and wash down to 9145' twice from 8350'. 06:05 - 08:15 2.17 PXA P ABAN TOH. About 5 bbl of 10 ppg cement seen at surface. Well does not appear to be drinking any. 08:15 - 08:30 0.25 PYA P ABAN Bump up. Est circ and check returns 1.3/1.3. 08:30 - 09:45 1.25 PYA P ABAN LD cementing BHA. PU swirl nozzle and wash stack. 09:45 - 10:15 0.50 STWHIP P WEXIT Set inj on back deck. 10:15 - 11:45 1.50 STWHIP P WEXIT Unstab ROC. Stab E-line coil. 11:45 - 12:30 0.75 STWHIP P WEXIT Back pump slack into coil. Cut 30' of coil. 12:30 - 14:30 2.00 STWHIP P WEXIT Install E-line CTC. 14:30 - 15:00 0.50 STWHIP P WEXIT PT well to 500 psi. Lost 100 psi in 15 minutes. Good to go. 15:00-15:30 0.50 STWHIP P WEXIT PT CTC. Leak. 15:30 ~ 17:15 1.75 STWHIP N SFAL WEXIT Rehead, PT CTC. 17:15 - 19:15 2.00 STWHIP P WEXIT Pump slack forward. MU milling BHA (BHA #2). Surface test OXP. 19:15-21:00 1.75 STVVHIP P WEXIT TIH 21:00 - 22:15 1.25 STWHIP P WEXIT GR log tie-in @ 8950' -11' correction. TCL log from 8995' to 8845'. Bottom of 4 1/2 tbg tail at 8852'. 22:15 - 22:35 0.33 S'I'WHIP P WEXIT TIH tag pinch point on whipstock at 9160'. ~ 22:35 - 00:00 1.42 STWHIP P WEXIT Mill window f/9160' to 9162.5'. 1.5k wob, 2.5 bpm 2850 psi 7/14/2001 00:00 - 02:05 2.08 STWHIP P WEXIT Finish milling window from 9162.5' to 9166'. 02:05 - 02:40 0.58 STWHIP P WEXIT Orient TF 140R and drill new formation from 9166' to 9171'. Printed: 7/23/2001 11:10:45 AM BP EXPLORATION page 2 of'5 Operations Summa Report ,. Legal Well Name: 8-20 Common Well Name: S-20A Spud Date: 8/9/1986 Event Name: REENTER+COMPLETE Start: 7/11/2001 End: 7/20/2001 Contractor Name: NABORS Rig Release: 7/20/2001 Rig Name: N^BORS 38 Rig Number: · · Date FrOm,:'TO Hours Activity Code NPT phase Description of Operations , 7/14/2001 02:05 - 02:40 0.58 STWHIP P VVEXIT 'Only drilled 5' to lesson the build rates for next section. 02:40 - 04:05 1.42 STVVHIP P WEXIT Circulate Bio sweep and dress window area. Prep to swap to FIo-Pro mud system. Shut down pump and RIH from 9135', through window, to TD. Window looks good no hang-ups. (Top of window 9160', bottom 9166'). 04:05 - 06:00 1.92 S-I-WHIP P WEXIT Open circ sub swap out to new FIo-Pro mud while POOH. 06:00 - 06:30 0.50 STWHIP P WEXIT Safety meeting. 06:30 - 07:00 0.50 S'I'WHIP P WEXIT LD milling BHA. Normal wear on both mills. 07:00 - 08:00 1.00 DRILL P PROD1 MU drilling BHA #3. 08:00 - 09:45 1.75 DRILL P PROD1 RIH. 09:45 - 10:30 0.75 DRILL P PROD1 Log tie-in at 8950'. Correct depth (-19'). 10:30 - 10:45 0.25 DRILL P PROD1 Run thru window clean. Tag 9170'. 10:45 - 15:15 4.50 DRILL P PROD1 Drill 30R thru Sag and into Shublik at 20 - 30 FPH, building and turning right. 15:15 - 15:45 0.50! DRILL P PROD1 Popped into Zone 4 at 9320'. ROP 70 - 100 FPH. Drill 2.5/3400 to 9340'. 15:45 - 16:15 0.50 DRILL P PROD1 Wiper to window. 16:15 - 17:15 1.00 DRILL P PROD1 Drill to 9550'. 17:15 - 17:45 0.50 DRILL P PROD1 Wiper to window. 17:45 - 18:15 0.50 DRILL P PROD1 Drill 150 - 200 FPH to 9654'. Drilling so fast having hard time getting expected doglegs nessesary from motor (need 21 deg ) for righthand turn. 18:15 - 19:10 0.92 DRILL P PROD1 Pull up for re-surveys. 19:10 - 21:05 1.92 DRILL P PROD1 TOH for short radius motor. 21:05 - 22:15 1.17 DRILL P PROD1 Change out motors. BHA ~ (77.63') 22:15 - 23:50 1.58 DRILL P PROD1 TIH 23:50 - 00:00 0.17 DRILL P PROD1 Log tie-in. 7/15/2001 00:00 - 00:25 0.42 DRILL P PROD1 Finish log tie-in -21' correction. 00:25 - 01:00 0.58 DRILL P PROD1 TIH 01:00 - 01:50 0.83 DRILL P PROD1 Drill f/9654' to 9753'. 3280 psi (2890 FS) 2.1/2.1 150'-170'/hr 80-90R TF 01:50 - 02:00 0.17 DRILL P PROD1 Check surveys, wiper trip. 02:00 - 02:40 0.67 DRILL P PROD1 Drill f/9753' to 9805'. 02:40 - 03:10 0.50 DRILL P PROD1 Wiper trip to window. 03:10 - 04:30 1.33 DRILL P PROD1 Drill f/9805' to 9925'. Finish turn. 04:30 - 06:45 2.25 DRILL P PROD1 Trip for lateral motor. 06:45 - 08:00 1.25 DRILL P PROD1 LD short radius motor. MU 1.2 deg Extreme lateral motor and DS49 bit. 08:00 - 09:30 1.50 DRILL P PROD1 RIH with BHA #5. 09:30 - 09:45 0.25 DRILL P PROD1 Log tie-in at 8950'. Correct depth (-21'). 09:45 - 10:00 0.25 DRILL P PROD1 RIH and SD in 44N shale at 9780'. Unable to get thru with left hand TF. 10:00 - 10:30 0.50 DRILL N DPRB PROD1 Orient to right side. Still can't get thru at min rate. Take a run at it with full pumps and skipped past. Ream shale. 10:30 - 12:30 2.00 DRILL P PROD1 Drill left turn 2.5/3400 to 10100'. 12:30 - 13:30 1.00. DRILL P PROD1 Wiper to window. The 9780' shale was much kinder to us this time. 13:30- 15:00 1.50 DRILL P PROD1 'Drillto 10270'. 15:00 - 16:15 1.25 DRILL P PROD1 Position TF for right turn and drop. Attempt drilling, stacking. Wiper to window. BHA pulling tight thru 9780' shale (no motor work). Ream slowly. 16:15-17:00 0.75 DRILL P PROD1 Drilling. Start drop down thru Z4. Drillto 10320'. Stack weight. PU and stuck. No motor work. Acts like differential sticking. Printed: 7/23/2001 11:10:45 AM BP EXPLORATION Page3 of 5 Operations Summary Report · Legal Well Name: S-20 Common Well Name: S-20A Spud Date: 8/9/1986 Event Name: REENTER+COMPLETE Start: 7/11/2001 End: 7/20/2001 Contractor Name: NABORS Rig Release: 7/20/2001 Rig Name: NABORS 3S Rig Number: Date From.To HOurs:ActivitY COde NPT Phase DeScriPtion of Operations ,' , 7/15/2001 17:00- 18:00 1.00 DRILL N STUC PROD1 Work pipe to 55k (12k over). No movement. No change in WeB sensor indicating stuck somewhere within 23' of BHA above this point. Order crude. Let relax in neutral with no pumps. Wait on crude. 18:00 - 20:00 2.00 DRILL N STUC PROD1 Pump 20 bbls crude. With 5 bbls out bit, pull, free. Circulate out crude while doing wiper trip to window. 20:00 - 21:25 1.42 DRILL P PROD1 Drilling ahead f/10320' 3740 psi 2.5/2.5 100fph to 10420', 21:25 - 21:55 0.50 DRILL P PROD1 Wiper trip to 10200'. 21:55 - 22:50 0.92 DRILL P PROD1 Drilling ahead f/10420' to 10505'. Swap to new Fie-Pro mud. 22:50 - 00:00 1.17 DRILL P PROD1 Wiper trip to window. 7/16/2001 00:00 - 00:15 0.25 DRILL P PROD1 Continue RIH from wiper trip to window. (checked RA tag on whipstock no correction) 00:15 - 01:00 0.75 DRILL P PROD1 Drill f/10505' to 10573'. Stacking weight. P/U appear differentially stuck. OXP also not responding. 01:00 - 01:45 0.75 DRILL N STUC PROD1 Work pipe. Pump 10 bbl crude and came free. 01:45 - 03:45 2.00 DRILL N DFAL PROD1 TOH unable to re-boot eXP. Made it to 5000' then OXP started working again. Ruled out surface equipment problems. 03:45 - 04:35 0.83 DRILL N DFAL PROD1 RIH. OXP failed agian at 8990'. 04:35- 06:30 1.92 DRILL N DFAL PROD1 :TOH 06:30- 08:15 1.75 DRILL N DFAL PROD1 !CO eXP. Bit 1-1. 08:15- 09:30 1.25 DRILL N DFAL PROD1 i RIH 09:30 - 09:45 0.25 DRILL N DFAL PROD1 Log tie-in at 8950' marker. Correct depth (-19'). 09:45 - 10:00 0.25 DRILL N DFAL PROD1 RIH to TD. Tagged a couple of shales, but squeezed thru ,easy. 10:00 - 14:15 4.25 DRILL P PROD1 : Drill. Nabors pump getting hot. Bring-on DS pump in parallel. Looks like we found Zone 3 transition at about 10720' -- ReP falling off here. Samples showing 80% chert. Drill about 20 - ,30 FPH to 10775' 14:15 - 15:30 1.25 DRILL P PROD1 Wiper to windoW. Shales in good shape. 15:30 - 19:30 4.00 DRILL P PROD1 Drill. Made it thru all of Z3 with DS49. Continue drilling Z2 at 60-80 FPH. Hit a wall at 10884' -- right where 25N is suppossed to come in. Drilled ahead to 10926' TD. 19:30 - 21:30 2.00 DRILL P PROD1 Circulate bottoms-up and pick up to tie-in point. 21:30 - 22:00 0.50 DRILL P PROD1 Log tie-in 0' correction. 22:00 - 00:00 2.00 DRILL P PROD1 Circulate and make several wiper trips. 7/17/2001 00:00 - 04:00 4.00 DRILL P PROD1 TOH. Finish wiper trips and lay-in new Fie-Pro mud in the openhole, Displace rio-pro from 2000' to surface with seawater for ease of running liner. 04:00 - 05:15 1.25 DRILL P PROD1 L/D BHA #6. 05:15 - 06:15 1.00 CASE P LNR1 Set injector on back deck. Unstab E-line coil. 06:15 - 06:45 0,50 CASE P LNR1 Safety meeting at crew change. 06:45 - 07:30 0.75 CASE P LNR1 Stab rock, 07:30 - 08:00 0.50 CASE P LNR1 RU liner running equipment. 08:00 - 08:30 0.50 CASE P LNR1 Safety meeting. 08:30 - 10:15 1.75 CASE P LNR1 MU 2-7/8" liner, 10:15 - 10:30 0.25 CASE P LNR1 BOP drill. 10:30 - 11:15 0.75 CASE P LNR1 Continue MU 2-7/8" liner. 11:15 - 11:45 0.50 CASE P LNR1 Crew change safety meeting. 11:45 - 12:30 0.75 CASE P LNR1 Continue MU 2-7/8" liner. 12:30 - 14:30 2.00 CASE P LNR1 MU 3-3/16" liner 3-1/2" and LRT 14:30 - 15:00 0.50 CASE LNR1 P/U injector make-up lubricator. 15:00 - 15:30 0.50 CASE P LNR1 M/U Baker CTC pull test to 30k#. M/U CT wiper dart catcher. 15:30 - 18:25 2.92 CASE P LNR1 Fill ROC coil with ilo-pro mud and pump around wiper dart. Printed: 7/23/2001 11:10:45 AM BP ExpLORATION Page 4 of 5 Operations Summa Report Legal Well Name: 8-20 Common Well Name: S-20A Spud Date: 8/9/1986 Event Name: REENTER+COMPLETE Start: 7/11/2001 End: 7/20/2001 iContractor Name: NABORS Rig Release: 7/20/2001 Rig Name: NABORS 3S Rig Number: · Date: From,To Hours: ACtivity COde NpTI phase DesCriPtionlofOPerations ::i.: 7/17/2001 15:30 - 18:25 2.92 CASE P LNR1 First dart didn't show up. Pumped around another and retrieved 'both. PT OTC to 3500 psi. 18:25 - 18:45 0.33 CASE .P LNR1 Crew change PJSM running liner. 18:45 - 19:30 0.75 CASE P LNR1 Make-up CTLRT. Fill liner with fie-pro. 19:30 - 21:50 2.33 CASE P LNR1 TIH with 2 7~8" liner. PU at 9100', check wt 38k lbs. continue to RIH with no problems. Tag at 10,948 uncorrected, corrected depth is 10, 926'. PU check weight 49k lbs. 21:50 - 22:35 0.75 CASE P LNR1 Release liner setting tool at 3400 psi. PU and confirm liner release. String weight lost 11 Klbs. Slack off 20K onto liner top. 22:35 - 00:00 1.42 CASE P LNR1 Displace mud in hole with 2% KCI. Pumping 2.5~2.3 BPM. 7/18/2001 00:00 - 00:20 0.33 CASE P LNR1 Finish displace mud in hole with 2% KCI. 00:20 - 00:40 0.33 CASE P LNR1 PJSM prior to cementing liner. 00:40 - 01:30 0.83 CASE P LNR1 Pressure test cementing lines and batch mix 25 barrels of cement while circulating the hole with 2% KCI. Hole was taking fluid at a rate of 0.3 BPM while circulating. 01:30 - 01:40 0.17 CASE P LNR1 Pump 23 barrels of cement, launch plug, and follow with 35 barrels of biozan, followed by 24.4 barrels of 2% KCI. Losses to the hole were approximately 0.3 BPM while pumping the cement at surface. 01:40 - 02:30 0.83 CASE P LNR1 Bump the coil wiper plug into the liner wiper plug. Shear the liner wiper plug and pump an additional 13.5 barrels of 2% KCl. Bump liner wiper plug with 3,200 psi. 02:30 - 02:40 0.17 CASE P LNR1 Bleed pressure off of the coil and test the float equipment. Ok. 02:40 - 05:00 2.33 CASE P LNR1 Pressure up to 1000 psi on the coil and pull the liner setting tool out of the liner. Wash up on liner top w/bio-zan. Circulate hole. POOH with coil. 05:00 - 05:30 0.50 CASE P LNR1 L/D CTLRT. 05:30 - 06:30 1.00 EVAL P LNR1 P/U logging tools and surface test. 06:30 - 06:50 0.33 EVAL P LNR1 PJSM covering p/u 1 1/4" CSH tbg. 06:50 - 11:20 4.50 EVAL P LNR1 P/U BHA #7 (2278.67') 11:20 - 12:10 0.83 EVAL P LNR1 P/U and stab on injector. 12:10 - 13:45 1.58 EVAL P LNR1 TIH w/logging tools. 13:45 - 15:15 1.50 EVAL P LNR1 Begin to log down. Tag PBTD at 10,891' MD. 15:15 - 16:30 1.25 EVAL P LNR1 Begin to log up. 16:30 - 17:45 1.25 EVAL P LNR1 POOH with coil. 17:45 - 20:40 2.92 EVAL P LNR1 Stand back the 1-1/4" hydril and lay down the logging tools. 20:40 - 21:43 1.05 EVAL P LNR1 Pressure test liner lap to 2,000 psi. (Dowell cement analysis showed 12 hour compressive strength of 2457 psi.) Double blocked all lines and isolated the pump. After 30 minutes the pressure dropped to 1,700 psi. Closed Master valve to monitor surface lines. After 10 minutes the pressure in the surface lines had dropped from 1680 psi to 1650 psi. Re-opened the master valve and the pressure immediately dropped to 1600 psi. 21:43 - 22:20 0.62 EVAL P LNR1 Attempt another 30 minute pressure test of the liner lap. Initial pressure 2120 psi, final pressure 1856 psi. Initial IA pressure was 100 psi. After 10 minutes the IA was 100 psi, and the final IA pressure was 100 psi. 22:20 - 00:00 1.67 EVAL P LNR1 Make up Baker KB liner top packer (min. ID of 2.441"). RIH and set on the liner top at 8737.5' ELM. The top of the liner top KB packer is now at 8729.6' ELM. 7/19/2001 00:00 - 03:45 3.75 EVAL P LNR1 RIH with KB liner packer and set on the liner top at 8734.5' CTM (8737.5' ELM). The top of the liner top KB packer is now at 8729.4' CTM (8732.4' ELM). Drop 5~8" packer setting ball Printed: 7/23/2001 11:10:45 AM BP: ~EXPLORATION Page 5 of 5 Operations Summa Report Legal Well Name: 8-20 Common Well Name: S-20A Spud Date: 8/9/1986 Event Name: REENTER+COMPLETE Start: 7/11/2001 End: 7/20/2001 Contractor Name: N^BORS Rig Release: 7/20/2001 Rig Name: N^BORS 38 Rig Number: , Date FrOm' To H°urs ActivitY:code NPT :phase DescriptiOn of:OperatiOns ........ 7/19/2001 .00:00 - 03:45 3.75 EVAL P LNR1 'into the coil. Once ball reached packer setting tool, the string was pressured up to 1400 psi to set the slips and then to 3250 psi to shear out. 03:45 - 04:30 0.75 EVAL P LNR1 Pressure test KB liner top packer to 2000 psi for 30 minutes. Final pressure was 1962 psi. Inner annulus pressure was 100 psi at both the start and end of the test. 04:30 - 06:00 1.50 EVAL P LNR1 POOH with coil and KB packer setting tool. 06:00 - 06:15 0.25 EVAL P LNR1 L/D packer running tools. 06:15 - 06:16 0.02 PERF COMP Called AOGCC and received 24 hr extension on BOP testing by Insp. John Crisp. 06:16 - 06:45 0.48 PERF P COMP PJSM p/u and running perfguns. 06:45 - 07:00 0.25 PERF P COMP P/U 50' of 2" 4SPF Schlumberger TCP guns ( PJ 2006 HMX 6.5gm charge, 0.20" entrance 18.6 penetration.). 07:00 - 10:50 3.83 PERF P COMP TIH w/pen"guns on 1 1/4" CSH tbg. 10:50 - 11:40 0.83 PERF P COMP Tag bottom confirm depth to flag. Correct tag depth to 10891' PBTD. Launch .625" ball. Pick-up to position bottom perf at 10865'. With ball on seat pressure up to 3400 psi and fire guns. Confirmed firing with pressure drop and loss of 1 bbl. Pen" depths: 10815' to 10865'. (At or just above 25N shale) 11:40 - 13:55 2.25 PERF P COMP TOH tagged up with BHA. 13:55 - 14:20 0.42 PERF P COMP Set back injector. 14:20 - 18:00 3.67 PERF P COMP PJSM I/d 1-1/4" CS Hydril tbg. 18:00 - 20:35 2.58 PERF P COMP MU BHA, stab on well, and freeze protect with crude. 20:35 - 22:00 1.42 PERF P COMP Set BP¥ and blow down stack. 22:00 - 00:00 2.00 PERF P COMP Rig down and move ROC from S-20A location, continue to rig down Nabors 38 and CTU #4. 7/20/2001 00:00 - 03:00 3.00 DEMOB P COMP N/D BOP equipment. Install wellhead cap and test to 3500 psi. Rig released at 0300 hrs 7-20,2001 03:00 - 06:00 3.00 DEMOB P COMP PJD move off S-20A. Wait on S-08 wellsite leveling work. Printed: 7/23/2001 11:10:45 AM Well: S-20Ai Rig Accept: 07/11/01 Field: Prudhoe Bay Unit Rig Spud: 07/14/01 APl: 50-029-21637-01 Rig Release: 07/20/01 Permit: 201-045 Drillin~l Rig: Nabors 3S POST-RIG WORK 08/24/01 Drift tubing with roller stem with 2" cent. and SB. Slowed to a stop at 9524' sim (deviation). Have small sample of schmoo. Rig down, move off and return well to Production for injection. 08/29/01 RIH and tagged PBTD, corrected the depth of 10891'. Tried to establish injection rate into the perfs at 10800', but well locked up. Washed the perfs with NH4CL followed by 6 bbls HCL acid. With well open, did one pass with HCL acid across perfs, shut in well. Pumped 94 bbls HCL acid into the perfs. WHP dropped from 2500 psi to 1650 psi with HCL and continued to drop when the mud acid hit the perfs. 47 bbls mud acid behind pipe. 200 psi final WHP after mud acid. Over flushed with 150 bbls NH4CL, WHP built back up to 1480 psi. Pull out of hole. Notified Production to bring well back on injection. 09/09/01 Set 4-1/2" MCX valve at 2175' sim. Turn well over to Production. Obp BP Amoco Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Field: Prudhoe Bay Sl~e: PBS Pad Well: S-20 Wellpu~: S-20A Date: 8/1/2001 Time: 10:27:20 Page: 1 Co-ordinate(NE) Reference: Well: S-20, True North Vertical (TVD) Reference: 36: 20 8/9/1~ 00:00 70.7 Section (VS) Reference: Well (0.00N,0.00E,260.00Azi) Survey Calculation Me~od: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Gee Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2001 Site: PBS Pad TR-12-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5980854.54 ft Latitude: 70 21 23.002 N 617919.92 ft Longitude: 149 2 32.343 W North Reference: True Grid Convergence: 0.90 deg Well: S-20 Slot Name: 20 Well Position: +N/-S-1017.53 ff Northlng: 5979855.00 ft Latitude: 70 21 12.994 N +E/-W 1129.30 ff Easting: 619065.00 ff Longitude: 149 1 59.335 W Position Uncertainty: 0.00 ft Wellpath: S-20A Drilled From: S-20 500292163701 Tie-on Depth: 9150.00 ft Current Datum: 36: 20 8/9/1986 00:00 Height 70.69 ff Above System Datum: Mean Sea Level Magnetic Data: 1/10/2001 Declination: 26.62 deg Field Strength: 57461 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg -0.50 0.00 0.00 260.00 Survey: MWD Start Date: 7/16/2001 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation 9150.00 8607.20 KO P 10926.00 9056.09 TD Survey ~ iMDi,~ i:iinel i Azlm ' TVD,:!'i~ ':"' i;: SSTVD' 'N/S !'; :' i E/W~ ' i~ :~' :MiPN :~ 'i' ,MapE :'/ :: ':i V$.,i' :'::ii' i,'!ft:,,: !' i' = ::deg ::,. ;, : ;i~, :deg/lOOff :ft' 9150.00 30.43 161.65 9181.00 36.50 164.50 9210.00 41.00 167.50 9240.00 47.30 170.00 9270.00 55.00 173.00 9300.00 61.70 174.00 9331.00 66.50 180.60 9360.00 68.50 185.40 9392.00 71.30 192.60 9420.00 74.90 1 94.80 9450.00 76.70 203.00 9482.00 78.60 202.70 9513.00 80.60 208.80 9547.00 82.60 211.40 9583.00 64.70 216.70 9617.00 87.30 222.10 9646.00 90.30 227.80 9676,00 92.20 237.40 8607.20 8536.51 -1949.43 1220.70 5977925.38 620316.42 0.00 -863.64 8633.05 8562.36 -1965.78 1225.64 5977909.11 620321.62 20.21 -865.66 8655.66 8584.97 -1983.39 1230.01 5977891.57 620326.26 16.81 -866.91 8677.18 8606.49 -2003.88 1234.05 5977871.15 620330.64 21.78 -867.34 8695.98 8625.29 -2026.97 1237.47 5977648.12 620334.42 26.82 -866.69 8711.72 8641.03 -2052.33 1240.35 5977822.81 620337.71 22.51 -865.13 8725.27 8654.58 -2080.16 1241.63 5977795.01 620339.43 24.62 -861.55 8736.37 8665.68 -2106.90 1240,22 5977768,25 620338.44 16.77 -855.52 8747.38 8676,69 -2136,55 1235.51 5977738.53 620334.20 22.87 -845.73 8755.52 8664.83 -2162.57 1229.16 5977712.41 620328.27 14.89 -834.96 8762.89 8692.20 -2190.06 1219.74 5977684.78 620319.29 27.17 -820.91 8769.73 8699.04 -2218.86 1207.60 5977655.79 620307.61 6.01 -803.96 8775.33 8704.64 -2246.31 1194.36 5977628.14 620294.80 20.40 -786.15 8780.30 8709.61 -2275.40 1177.49 5977598.79 620278.40 9,58 -764.48 8784.28 8713.59 -2305,03 1157.46 5977568,84 620258.85 , 15,75 -739.61 8786.66 8715,97 -2331,23 1135.94 5977542.31 620237.75 17.59 -713.87 8787.27 8716.58 -2351.74 1115.47 5977521.48 620217,61 22.21 -690.15 8786,61 8715.92 -2369.93 1091.67 5977502.91 620194,10 32.61 -663.55 BP Amoco Lj b,p Baker Hughes INTEQ Survey Report ~T~.O Compaay: BP Amoco Date: 811/2001 Time: 10:27:20 Page: 2 F~d: Prudhoe Bay Co-ordh. a~gNE) Reference: Well: S-20, True North Site: PBS Pad Vertical (TVD) Refereaee: 36: 20 8/911986 00:00 70.7 Well: S-20 Seeaoa (VS) Refemace: Well (0.00N,0.00E,260.00Azi) Weflpat~: S-20A Sam/ey Cakllafloa Method: Minimum Curvature Db: Oracle Survey MD lncl Azim TVD SSTVD NIS E/W MapN MapE DLS VS ff deg (leg ff ' ff ff ff ff ff deg/100ft' ff 9707.00 93.70 247.20 8785.01 8714.32 -2384.31 1064.30 5977488.11 620166.96 31.94 9739.00 94.50 258.10 8782.72 8712.03 -2393.81 1033.88 5977478.12 620136.70 34.07 9771.00 96.10 268.80 8779.75 8709.06 -2397.45 1002.27 5977473.99 620105.16 33.67 9802.00 97.10 278.60 8776.18 8705.49 -2395.46 971.58 5977475.48 620074.44 31.57 9832.00 98.00 288.40 8772.23 8701.54 -2388.53 942.70 5977481.95 620045.46 32.52 9861.00 97.80 298.00 8768.23 8697.54 -2377.23 916.33 5977492.83 620018.91 32.80 9892.00 97.60 308.20 8764.07 8693.38 -2360.48 890.63 5977509.17 619992.95 32.61 9923.00 96.80 318.00 8760.17 8689.48 -2339.49 868.20 5977529.80 619970.20 31.47 9955.00 96.70 314.30 8756.41 8685.72 -2316.57 646.19 5977552.36 619947.83 11.49 9985,00 97.80 310,90 8752.62 8681.93 -2296.43 824.29 5977572.15 619925.61 11.83 10018.00 98,00 307.40 8748.09 8677.40 -2275.80 798.95 5977592.38 619899.94 10,52 10066.00 96.20 300,60 8742.15 8671.46 -2249.18 759.48 5977618.36 619860.06 14.55 -634.10 -602.49 -570.73 -540.85 -513.61 -489.61 -467.21 -448.77 -431.07 -413.00 -391.62 -357.37 10100.00 94.30 297.80 8739.04 8668.35 -2232.67 729.93 5977634.40 619830.25 9.92 10130,00 93.30 294.70 8737.05 8668.36 -2219.43 703.08 5977647.21 619803.21 10.64 10161.00 91.80 291.50 8735.67 8664,98 -2207,28 674.60 5977658.90 619774,54 11.39 10196.00 90,20 287.30 8735,06 8664.37 -2195,68 641.60 5977669.99 619741,36 12.64 10227.00 89.20 284,00 8735,22 8664.53 -2187.30 611.76 5977677.68 619711.39 11.12 10259.00 88.20 282.60 8735.95 8665.26 -2179.94 580.62 5977664.74 619680.14 5.38 10287.00 85.10 282.90 8737.58 8668.89 -2173.78 553.36 5977690.47 619652.79 11.12 10317.00 80.40 283.00 8741.37 8670.68 -2167.11 524.37 5977696.68 619623.70 15.67 10361.00 74.90 287.80 8750.78 8680.09 -2155.72 482.96 5977707.41 619582.11 16.42 10393.00 72.90 285.90 8759.65 8688.96 -2146.81 453.53 5977715.85 619552.55 8.46 10423.00 76.50 283.20 8767.57 8696.88 -2139.54 425.53 5977722.67 619524.44 14.81 10455.00 75.30 286.90 8775.37 8704.68 -2131.49 395,57 5977730.24 619494.35 11.82 10490.00 72.30 284.10 8785.13 8714.44 -2122.50 363.19 5977738.71 619461.84 11.51 10519.00 69.40 284.40 8794.65 8723.96 -2115.76 336.64 5977745.03 619435.19 10.05 10550.00 66,30 282.80 8806.33 8735.64 -2109,01 308.74 5977751.34 619407.18 11.08 10578,00 62.50 280.00 8818.43 8747.74 -2104.01 283.99 5977755.95 619382.37 16.29 10613.00 57.30 278.20 8835.98 8765.29 -2099,21 254.11 5977760.27 619352.41 15.51 10644.00 56.90 275.70 8852.82 8782.13 -2096.06 228,27 5977763.01 619326.53 6.89 10676.00 59.60 279.70 8869.66 8798.97 -2092,40 201.32 5977766.24 619299.53 13.57 10706.00 55.40 282.90 8885.78 8815.09 -2087.46 176.52 5977770.78 619274.65 16.64 10737.00 50.50 264.40 8904.45 8833.76 -2081.63 152.48 5977776.23 619250.53 16.27 10771.00 44.00 279.50 8927.53 8856.84 -2076.42 128.09 5977781.06 619226.06 21.64 10800.00 40.10 279.20 8949.06 8878.37 -2073.26 108.93 5977783.91 619206.86 13.47 10830.00 35.50 280.90 8972.76 8902.07 -2070.07 90.83 5977786.81 619168.71 15.72 10868.00 30.30 283.00 9004.65 8933.96 -2065.82 70.64 5977790.74 619168.45 14.01 -331.14 -307.00 -281.06 -250.58 -222.64 -193.26 -167.49 -140.09 -101.28 -73.85 -47.54 -19.43 10.90 35.88 62.18 85.68 114.28 139.17 165.08 188.65 211.31 234.42 252.74 270.01 289.16 10891.00 26.80 287.90 9024.85 8954.16 -2062.92 60.05 5977793.47 619157.82 18.30 10926.00 26.80 287,90 9056.09 8985.40 -2058,07 45.03 5977798.08 619142,73 0.00 299.08 313.03 REFERENCE IN FORMAT{ON Co~ordina~e (N/E Refe[ence: TVD)) Reference: Well Cenlre: S-20, True Nodh Vedical System: Mea~ Sea Level Sedion (VS Reference: SlOi 2O (000N,00OE) Measured Deptl~ Reference: 36: 2O 8/9/1986 00:00 7069 Calculation Me~hOd: Minimum Cuwature 700 ~00 500 400-300-200-100 0 S20^ Magnetic F~eld 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 1100-1050 1000 950 900 850-800-750-700-650-600-550 ~500 450 400 350 300-250-200 t50-100 50 0 50 100 150 200 250 300 350 400 450 500 550 600 650 700 750 800 850 8/11200~ ~0;~ 09/12/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1435 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD J-17A //~:::~C~'O~ ¢~ 21388 SCMT 08/29101 K-07C L~-/~_ 20034 MCNL 12/10199 S-=0A c~ t')/-~¢-/.~_~ 21348 MCNL 071~ 8/0J X-tSLl (REDO)~o/~O~ ~ 21330 MCNL 06111/01 D.S. ~5~2A (REDO~-~ 20307 MCNL 071~6100 NK-07A (REDO~(~/~(a ~ 21341 ~GR 04126101 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED S£P 1,4 2001 0il & Gas Cons. ,C0mm~ion Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie ! ~KA OIL AND GAS CONSERVA~I~ION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: ?rudhoe Bay Unit S-20Ai BP Exploration (Alaska) Inc. Permit No: 201-045 Sur Loc: 1630' SNL, 903' EWL,' SEC. 35, T12N, R12E, UM Btmhole Loc. 3681' SNL, 904' EWL, SEC. 35, T12N, R12E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above referenced Well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. BloWout prevention equipment (BOPE) must be tested in accordance with 20AAC25 036. Sufficient notice (approximately 24 hours) must be given to allow a representative of the CommiSsion to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this , j'-~4 day of April, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALA~ STATE OF ALASKA .~,r' OIL AND GAS CONSERVATION C(~ .... vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill I~ Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE - 70.70' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028257 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1630' SNL, 903' EWL, SEC. 35, T12N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 3646' SNL, 2142' EWL, SEC. 35, T12N, R12E, UM S-20Ai Number 2S100302630-277 At total depth 9. Approximate spud date 3681' SNL, 904' EWL, SEC. 35, T12N, R12E, UM 04/05/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028258, 904' MDI No Close Approach 2560 10894' MD / 8995' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9150' MD Maximum Hole Angle 99 ° Maximum surface 2350 psig, At total depth (TVD) 8704' / 3400 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8..x3-3/16. 6.16# L-80 ST-L 2194' 8700' 8151' 10894' 8995' 129 cuft Class'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary F'E 13 3 Z 0 0'l Total depth: measured 9848 feet Plugs (measured) true vertical 9205 feet ^laska 0il & Gas Cons. Commission'; Effective depth: measured 9790 feet Junk (measured) Anchorage true vertical 9155 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cu yds concrete 110' 110' Surface 2642' 13-3/8" 3258 cuft AS III, 465 cuft AS II 2677' 2675' Intermediate 9100' 9-5/8" 366 cuft 'G', 1385 cuft 'G', 230 'G' 9133' 8593' Production Liner 982' 7" 345 cuft Class 'G' 8866' - 9848' 8363' - 9205' Perforation depth: measured 9296' - 9365', 9372' - 9434', 9640' - 9650' Straddled Intervals: 9449' - 9457', 9461'- 9471', 9478' - 9488', 9500' - 9510' true vertical 8733' - 8792', 8798' - 8852', 9028' - 9036' Straddled Intervals: 8865' - 8871', 8875' - 8883', 8889' - 8898', 8908' - 8917' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mary Endacoff, 564-4388 Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoino is true and correct to the best of my knowledge ' , ' ' ' _ Signed. M,,; ,, ,.S Endacott .~ ~. ~. L/....~~'/ ~{'"~.g,~,~'~ (~.~"' ' "'~' '" ~/;. Title CT Drilling Engineer Date ~..~?-~? "Permit Number " ' J APl'~umber ...... """ .... ' ................... '""' ................ I""' .... 'ba e" ......... :":""" ...... '" ...... .... .~-O,2-~ 0 ,~;/~'" J 50- 029-21637701 .... J. /7/.S'".~2/ .... J f0rother requirements Conditions of Approval: Samples Required [] Yes ,l~ No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures ,[~'Yes ~;~ No Directional Survey Required ~ Yes [] No Required Working Pressure for DOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K kI~3.5K psi for CTU Other: ORIG,NAL ~.$~tGN'i:::~.~ ~:.:. ~ by orderof ,/_7/ Approved By D Taylor S Commissioner the commission .... earned, ir.ti. Date Form 10-401 Rev. 12-01-85 Submit In Triplicate bp S-20ai Sidetrack Summary of Operations: S-20i is currently injecting 6000bpd, with a target of 9000bpd. The sidetrack, S-20ai, will exit the 7" liner in the Sag R. interval and target Zone 2 and Zone 4. Following initial slug MIST injection in Zone 2, S-20ai will be plugged back to the upper portion of Zone 4B to provide injection support for offsetting Zone 4 producers. Existing perfs will be squeezed by pumping ±20 bbls cement past the whipstock. It will be completed with a cased and perforated 3 3/16" x 2 7/8" liner. Phase 1: Drift, set whipstock on E-Line & with service coil. Planned for Mar 27-28, 2001. squ.,e, eze · Tubing and liner have been drifted to 3.625. · Tubing integrity will be confirmed by executing an MIT. '~ · A Kinley caliper.has been run across the tubing and liner. Phase 2: Mill window, Drill and Complete sidetrack: Planned for Apr. 5, 2001. Drilling coil will be used to mill the window then drill and complete the directional hole as per attached plan. Mud Program: · Phase 1: Seawater · Phase 2: Mill with seawater, drill with FIo-Pro (8.6 - 8.7 ppg) Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · Top of 3 3/16" x 2 7/8" liner to be ±8,700' MD (8151' TVDSS), 2 7/8" will be run from TD to ±9,180' MD (8560'TVDSS). · The tapered liner will be cemented with ±23 bbls cement. · A short shoe will be necessary to allow room for completion. Well Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan. BHL (State Plane): 619,102; 5,977,804. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Max. hole angle is 99 deg. RECEIVED Logging · An MWD Gamma Ray log will be run over all of the open hole section. · A real time Resistivity Log will be run in open hole. FEB 2 3 ZOO1 Hazards · The highest H2S recorded to date on S Pad is 120 ppm on 8-32 on 1/12/00. Alaska Oil & Gas Cons. Commission · Lost circulation risk is moderate at small fracture in Zone 4. Anchorage · Plan to drill through conglomerate Zone 3, may be difficult. Reservoir Pressure Res. press, is estimated to be 3400 psi at 8704'ss. Max. surface pressure with gas (0.12 psi/ft) to surface is 2350 psi. TREE = 4" .DlVV WELLHEAD= 13-3/8" McEV ACTUATOR= AXELSON "J~i'"~'~'''~: ............. 37.0 '"~'~'"~'~'~i~"':: ........................ @ .................. i Datum MD = RKB Datum TV D= SS S-20Ai ( PROPOSED HORIZONTAL SIDETRACK 4-1/2" HES X NIPPLE 3.813" ID no control lines 13-3/8 72# L-80 RECEIVED 4-1/2" 12.6# L-80 IPC BTRS Tbg FEB 2 3 Z001 Alaska Oil & Gas Cons. Commission Anchorage I Proposed Top of 3..3/16" Liner 8700' [' ILeak in Casing I Casing Leak between 8675' - 8866' I ~o, of~"Liner I I 8SSS' I 8599' I-I 8610' 1 ~42'I--I 8866' I--I 4-1/2" HES X NIPPLE 3.813" ID I 9-5/8" TIW HBBP-T 3.92" ID [ 4-1/2" HES X NIPPLE 3.813" ID I 4-1/2" HES X NIPPLE 3.813" ID I 9-5/8" Baker Seal Assembly w / seals 9-5/8" 47# L-80 I I 9133' I 9155' 9t80' ] Mill Window off W/S I 3~3/16" x 2-7/8" XO [ Perfs (9296'-9434') P&A'd w/15.8ppg cement I 7" 26#L-80 I I 9848' 2-7/8" Liner Cemented & Perf'd ] 10900' DATE REV BY COMMB'qTS 01/09/01 pcr Proposed ST Completion PRUDHOE BAY UNIT WELL: S-20Ai PERMIT No: APl No: 50-029-21637-01 Sec. 35, T12N, R12E, FEL, FNL BP Exploration (Alaska) BP Amoco WELLPATH DETAILS Plan#1 S-20A 500292163701 Parent Welipath: S-20 Tie on MD: 9t50.00 Vertical Section Origin: Slot- 20 {0.00,0.00) Vertical Section Angle: 260.00° Rig: Depth Reference: 36: 20 $/9/1986 00:00 70.70ff REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well CeriSe: S-20, True North VRrUc. al (TVD~ Reference: System: Mean Sea L~vel Section (VS~ Reference: Slot - 20 (0.00,0.00) Measured Depth Reference: 36: 20 8/g!1c986 00:00 70.7 Calculation Method: Minimum Curvature fl350- .; ....: .. 840~';~ ....... · 8450~. [ 55o-}] ............. " :.i ~,~$~.i .q ., . ~?o0"',: ........... .'.~ .~: o~oo- ~-~ .: . .: 9050' i ':: ;,;~:, 4 00o -9 : ..-%[; ., LEGEt~D ........ S-0~ .... · S-?O 'T i .'i'.~.':'.y ..: '.';'.T .. .. -. ...: .._; ..... .. ........... · ..: .. ........ : .......... ': ..... ~::-..,.-~ · '-.':-'-'-'.-.'~:~:.:L'~ i-: :': · :-:.. .:.;-:.:-...:...:.: · _ .'i'-i-';'-Y-'.' '.' Yi'-!.'- Azim~.r~h$ tO True Norlh I '¢¢c~palh: ($.79~'~;~1 .~20/~ Magnetic Noflh: 26.62' Magnetm Field M~el: BGGM20~ J [;-;{ 4, ;;::¢:;.:.;. -SL,~J -'/O-; ~JCJ '-'~ ,;t::) - %:; ,' ~;~ "';,L: t: 180 200 300 400 West(-)lEast(+) [lOOft/in] .. .:, . . · ..:. "' · · .. :_ · .:.: : ...... : :::.¥-:::-. :i.::.. · :-;- ;:::--:: .t .......... :' .. : ......... ;. .'.'.".':. : · · ,.:",~' ........ '.' ................ : ..... . ........................... : ...... .."<:":::::::". ................... : ......................... :'"tx ....... 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'FJO Vertical Section at 260.00° [50ft/in] Pict 1/10/2001 4:30 PM bp BP Amoco ( ( Baker Hughes INTEQ Planning Report t~T£Q Company: BP Amoco Field: Prudhoe Bay Site: PBS Pad Well: S-20 Wellpath: Plan#1 S-20A Date: 1/1012001 Time: 16:15:54 Page: 1 Ce-ordinate(NE) Reference: Well: S-20, True North Vertical (TVD) Reference:' System: Mean Sea Level ~ction (VS) Reference: Well (0.00E,0.00N,260.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Ge# Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: PBS Pad TR-12-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0,00 ft Ground Level: 0.00 ft 5980854.54 ft 617919.92 ft Latitude: 70 21 23,002 N Longitude: 149 2 32.343 W North Reference: True Grid Convergence: 0.90 deg Well: S-20 S-20 Well Position: +N/-S-1018.39 ft Northing: 5979854.12 ft +E/-W 1128.22 ft Easting: 619063.94 ft Position Uncertainty: 0,00 ft Slot Name: 20 Latitude: 70 21 12.986 N Longitude: 149 1 59,366 W Wellpath: Plan#1 S-20A Drilled From: S-20 500292163701 Tie-on Depth: 9150.00 ft Current Datum: 36: 20 8/9/1986 00:00 Height 70.70 ft Above System Datum: Mean Sea Level Magnetic Data: 1/10/2001 Declination: 26,62 deg Field Strength: 57461 nT 'Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +NI-S +E/-W Direction ff ft ff deg 0,00 0.00 0.00 260.00 Plan: Plan #1 Date Composed: 1/10/2001 Lamar's Plan #6 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets ; .,.,, .:, ,. i',..,i"'...'.': , ,..'..;MAP :'.',... MAP..'..: '"<-~ Latitude -->, <-- Longitude.--> Name. ..... "' '" Description ' TVD': '' .. +N/-S ' .:" +E/-W" 'Northing.':'.,'. Easting =. ' :'..Deg Min. 'Sec.' . Deg 'Min. Sec.' Annotation · " '" .... "' · :~D''., TVD .. ...:: .... :.. :.:.'..:::..'....'..::,':.::..'..."..:.~....: ..: ' ........ :..'.... :..': . R'.~,''',. 'V:..~?:.:~,-~'' 9100,00 8493,34 Tie-in Point 9150.00 8536.50 Kick-off Point 9160.00 8545.04 1 F E B ?~ :3 ZOO 1 9344.69 8659.64 2 9637.85 8715.83 3 9930.00 8690.24 4 Alaska Oil & Gas Cons. Commission 10244.65 8664.99 5 Anchorage 10894.08 8995.29 TD Plan Section Information 'MD' ' in'cl "Azim '" '.TVD.. :i""+N/-S'.. ".. '~E/-W' ' . '! ,'. DLS .... BUild .: .... Turn ..... ..T'FO.'". Target ....... ' .. .. . . . .. .... . ....... , · .. ............ '.. ..' . ft' deg. .. deg' '.'" '. ',, ft. '. ': .":.'.: 'ff.':'".... '; ft.':" .... degll00ft, deg/100ft.deg/!'00ft .::'.'deg':' . :.. : ..:' 9100.00 30.20 161.90 8493.34 -1925.45 1212.80 0.00 0.00 0.00 0.00 9150.00 30.43 161.65 8536.50 -1949.42 1220.70 0.52 0.46 -0.50 331.14 9160.00 32,18 163,53 8545.04 -1954.38 1222.25 20.00 17.46 18.78 30.00 9344.69 70.00 183.80 8659.64 -2094.03 1230.80 22.00 20.48 10.98 30.00 9637.85 90.00 246.53 8715.83 -2313.53 1069.86 22.00 6.82 21.40 80.00 9930.00 99.00 310.46 8690.24 -2273.84 796.84 22.00 3.08 21.88 80.00 10244.65 90.00 280.18 8664.99 -2141.88 516.68 10.00 -2.86 -9.62 255.00 10894.09 25,06 280.18 8995.30 -2050.16 5.81 10,00 - 10.00 0.00 180.00 ObP ,. BP Amoco i .... ( Baker Hughes INTEQ Planning Report lxNTEQ Company: BP Amoco Field: Prudhoe Bay Site: PBS Pad Welh S-20 Wellpath: Plan#1 S-20A Date: 1110/2001 ~ Time: 16:15:54 Page: 2 Ce-e~Unate(NE)Reference: Well: S-20, True North Vertical (TVD) Reference: System: Mean Sea Level SectiOn (VS) Reference: Well (0.00E,0.00N,260.00Azi) SUrveY Calculation Methed: Minimum Curvature Db: Oracle Survey MD Incl Azim SSTVD NIS E/W MapN MapE DLS VS TFO Tool ff deg deg fl ff ft ft tt deg/100ft ff deg 9100.00 30.20 161.90 8493.34 -1925.45 1212.80 5977948.34 620307.08 0.00 -860.02 0.00 MWD 9125.00 30.31 161.77 8514.93 -1937.42 1216.73 5977936.44 620311.20 0.52 -861.81 331.14 MWD 9150.00 30.43 161.65 8536.50 -1949.42 1220.70 5977924.50 620315.36 0.52 -863.64 331.25 MWD 9160.00 32.18 163.53 8545.04 -1954.38 1222.25 5977919.57 620316.99 20.04 -864.31 29.98 MWD 9175.00 35.07 166.40 8557.53 -1962.40 1224.40 5977911.58 620319.26 22.00 -865.03 30.00 MWD 9200.00 40.02 170.36 8577.35 -1977.32 1227.43 5977896.72 620322.53 22.00 -865.43 27.61 MWD 9225.00 45.07 173.58 8595.76 -1994.05 1229.77 5977880.03 620325.14 22.00 -864.82 24.46 MWD 9250.00 50.20 176.27 8612.61 -2012.44 1231.39 5977861.67 620327.05 22.00 -863.22 22.09 MWD 9275.00 55.38 178.58 8627.72 -2032.32 1232.27 5977841.80 620328.24 22.00 -860.64 20.28 MWD 9300.00 60.60 180.62 8640.97 -2053.51 1232.41 5977820.62 620328.72 22.00 -857.09 18.88 MWD 9325.00 65.85 182.46 8652.22 -2075.82 1231.80 5977798.31 620328.46 22.00 -852.62 17.80 MWD 9344.69 70.00 183.80 8659.64 -2094.03 1230.80 5977780.08 620327.75 21.98 -848.48 16.95 MWD 9350.00 70.21 185.02 8661.45 -2099.01 1230.42 5977775.10 620327.45 22.00 -847.23 80.00 MWD 9375.00 71.29 190.73 8669.70 -2122.37 1227.18 5977751.69 620324.58 22.00 -839.99 79.58 MWD 9400.00 72.55 196.37 8677.46 -2145.47 1221.61 5977728.51 620319.38 22.00 -830.49 77.70 MWD 9425.00 73.96 201.92 8684.67 -2168.07 1213.76 5977705.79 620311.89 22.00 -818.84 75.95 MWD 9450.00 75.51 207.39 8691.26 -2189.98 1203.70 5977683.73 620302.18 22.00 -805.13 74.35 MWD 9475.00 77.18 212.78 8697.16 -2210.99 1191.52 5977662.53 620290.34 22.00 -789.49 72.91 MWD 9500.00 78.97 218.10 8702.33 -2230.90 1177.34 5977642.39 620276.48 22.00 -772.06 71.63 MWD 9525.00 80.84 223.35 8706.71 -2249.55 1161.29 5977623.50 620260.73 22.00 -753.01 70.53 MWD 9550.00 82.80 228.55 8710.27 -2266.74 1143.51 5977606.02 620243.23 22.00 -732.52 69.61 MWD 9575.00 84.80 233.70 8712.98 -2282.34 1124.17 5977590.12 620224.14 22.00 -710.76 68.87 MWD 9600.00 86.85 238.81 8714.80 -2296.18 1103.44 5977575.95 620203.63 22.00 -687.95 68.32 MWD 9625.00 88.93 243.91 8715.72 -2308.15 1081.52 5977563.64 620181.91 22.00 -664.28 67.94 MWD 9637.85 90.00 246.53 8715.83 -2313.53 1069.86 5977558.07 620170.34 22.02 -651.87 67.78 MWD 9650.00 90.46 249.16 8715.78 -2318.11 1058.61 5977553.31 620159.16 22.00 -639.99 80.00 MWD 9675.00 91.41 254.58 8715.37 -2325.89 1034.86 5977545.16 620135.54 22.00 -615.25 80.01 MWD 9700.00 92.35 260.00 8714.55 -2331.38 1010.50 5977539.28 620111.27 22.00 -590.30 80.10 MWD 9725.00 93.27 265.43 8713.32 -2334.55 985.74 5977535.73 620086.57 22.00 -565.37 80.28 MWD 9750.00 94.16 270.87 8711.70 -2335.35 960.81 5977534.52 620061.66 22.00 -540.69 80.54 MWD 9775.00 95.01 276.32 8709.70 -2333.79 935.95 5977535.69 620036.78 22.00 -516.47 80.90 MWD 9800.00 95.81 281.79 8707.34 -2329.87 911.38 5977539.22 620012.15 22.00 -492.96 81.33 MWD 9825.00 96.56 287.27 8704.65 -2323.64 887.33 5977545.06 619988.01 22.00 -470.36 81.85 MWD 9850.00 97.26 292.77 8701.64 -2315.15 864.02 5977553.18 619964.57 22.00 -448.87 82.44 MWD 9875.00 97.88 298.28 8698.34 -2304.48 841.67 5977563.50 619942.05 22.00 -428.71 83.10 MWD 9900.00 98.44 303.81 8694.79 -2291.72 820.47 5977575.91 619920.65 22.00 -410.05 83.83 MWD 9925.00 98.91 309.35 8691.02 -2277.00 800.63 5977590.31 619900.59 22.00 -393.07 84.61 MWD 9930.00 99.00 310.46 8690.24 -2273.84 796.84 5977593.42 619896.74 22.03 -389.89 85.46 MWD 9950.00 98.48 308.51 8687.20 -2261.27 781.58 5977605.74 619881.29 10.00 -377.04 255.00 MWD 9975.00 97.81 306.07 8683.66 -2246.28 761.90 5977620.42 619861.37 10.00 -360.26 254.70 MWD 10000.00 97.13 303.65 8680.41 -2232.11 741.56 5977634.26 619840.81 10.00 -342.69 254.36 MWD 10025.00 96.44 301.23 8677.46 -2218.80 720.61 5977647.23 619819.65 10.00 -324.37 254.04 MWD 10050.00 95.73 298.82 8674.81 -2206.36 699.09 5977659.33 619797.94 10.00 -305.33 253.76 MWD 10075.00 95.02 296.41 8672.46 -2194.83 677.03 5977670.51 619775.70 10.00 -285.62 253.50 MWD 10100.00 94.29 294.01 8670.43 -2184.22 654.49 5977680.76 619753.00 10.00 -265.26 253.28 MWD 10125.00 93.56 291.61 8668.72 -2174.55 631.50 5977690.06 619729.86 10.00 -244.30 253.08 MWD 10150.00 92.82 289.22 8667.33 -2165.84 608.11 5977698.39 619706.34 10.00 -222.78 252.92 MWD 10175.00 92.08 286.83 8666.26 -2158.11 584.36 5977705.74 619682.47 10.00 -200.73 252.78 MWD 10200.00 91.34 284.44 8665.51 -2151.38 560.30 5977712.09 619658.30 10.00 -178.20 252.68 MWD 10225.00 90.59 282.06 8665.09 -2145.65 535.97 5977717.43 619633.89 10.00 -155.24 252.62 MWD 10244.65 90.00 280.18 8664.99 -2141.88 516.68 5977720.90 619614.55 10.00 -136.90 252.58 MWD 10250.00 89.46 280.18 8665.01 -2140.93 511.41 5977721.76 619609.27 10.00 -131.88 180.00 MWD 10275.00 86.96 280.18 8665.79 -2136.52 486.82 5977725.78 619584.61 10.00 ~L~S~~.~ Alaska Oil & Gas Co~s. Com,missior~ Anchoraoe (, BP Amoco (" Baker Hughes INTEQ Planning Report mmm~ Company: BP Amoco Date: 111012001 Time: 16:15:54 Page: 3 Field: Prudhoe Bay Coordinate(NE) Reference: Well: S-20, Tree North Site: PBS Pad Vertical (TVD) ReferenCe: System: Mean Sea Level Well: S-20 Section (VS) Reference: Well (0.00E,0.00N,260.00Azi) Wellpath: Plan#1 S-20A Survey CalcUlation Method: Minimum Curvature Db: Oracle Survey MD lncl Azim SSTVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft It deg/100ft ft deg 10300.00 84.46 280.18 8667.66 -2132.11 462.29 5977729.80 619560.01 10.00 -85.03 180.00 MWD 10325.00 81.96 280.18 8670.61 -2127.73 437.85 5977733.80 619535.51 10.00 -61.73 180.00 MWD 10350.00 79.46 280.18 8674.65 -2123.37 413.57 5977737.77 619511.16 10.00 -38.57 180.00 MWD 10375.00 76.96 280.18 8679.75 -2119.04 389.49 5977741.71 619487.02 10.00 -15.60 180.00 MWD 10400.00 74.46 280.18 8685.92 -2114.76 365.64 5977745.61 619463.11 10.00 7.14 180.00 MWD 10425.00 71.96 280.18 8693.14 -2110.53 342.09 5977749.47 619439.49 10.00 29.60 180.00 MWD 10450.00 69.46 280.18 8701.40 -2106.36 318.86 5977753.27 619416.20 10.00 51.75 180.00 MWD 10475.00 66.96 280.18 8710.67 -2102.26 296.01 5977757.01 619393.30 10.00 73.54 180.00 MWD 10500.00 64.46 280.18 8720.96 -2098.23 273.59 5977760.68 619370.81 10.00 94.92 180.00 MWD 10525.00 61.96 280.18 8732.22 -2094.28 251.62 5977764.27 619348.79 10.00 115.87 180.00 MWD 10550.00 59.46 280.18 8744.45 -2090.43 230.16 5977767.78 619327.27 10.00 136.33 180.00 MWD 10575.00 56.96 280.18 8757.62 -2086.68 209.25 5977771.20 619306.30 10.00 156.28 180.00 MWD 10600.00 54.46 280.18 8771.70 -2083.02 188.92 5977774.53 619285.92 10.00 175.66 180.00 MWD 10625.00 51.96 280.18 8786.67 -2079.49 169.21 5977777.76 619266.16 10.00 194.46 180.00 MWD 10650.00 49.46 280.18 8802.49 -2076.07 150.17 5977780.87 619247.07 10.00 212.62 180.00 MWD 10675.00 46.96 280.18 8819.15 -2072.77 131.82 5977783.87 619228.67 10.00 230.11 180.00 MWD 10700.00 44.46 280.18 8836.61 -2069.61 114.21 5977786.76 619211.01 10.00 246.91 180.00 MWD 10725.00 41.96 280.18 8854.82 -2066.58 97.36 5977789.51 619194.12 10.00 262.98 180.00 MWD 10750,00 39.46 280.18 8873.77 -2063.70 81.31 5977792.14 619178.03 10.00 278.28 180.00 MWD 10775,00 36,96 280.18 8893.41 -2060.97 66.09 5977794.63 619162.77 10.00 292.80 180.00 MWD 10800,00 34,46 280,18 8913.71 -2058.39 51.73 5977796.98 619148.37 10.00 306,49 180.00 MWD 10825.00 31,96 280.18 8934.62 -2055.97 38.25 5977799.19 619134.85 10.00 319,35 180.00 MWD 10850.00 29.46 280.18 8956.11 -2053.71 25.68 5977801.24 619122.25 10.00 331,33 180.00 MWD 10875.00 26.97 260.18 8978.14 -2051.62 14.05 5977803.15 619110.59 9,99 342.42 180.00 MWD 10894.09 25.06 280.18 :",'18'99§.30,ii,~ -2050.16 5.81 5~7~804.48 619,102.33 9.99 350.28 180.00 MWD FER 2, 3 ZOO1 ,Alaska Oil & Gas Cons, Commission Anchorage 2 3/8" CT ---~1 I I I10,000 psi I Pack-Off Lubricatort S-20ai CT Drilling & Completion BOP 7 1/16" Annular 7 1/16" 5000 psi Blind/Shear 7 1116" Pipe/Slip ~ ~ 2 3/8" Pipe/Slips ~ 2 718" 7 1116" Pipe/Slips ~ 2 3/8" SWAB OR MASTER VALVE RECEIVED FEB g 3 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage ,o V~NOO~ ALASKAO I LA O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET ' ' )12901 CKO12901B 100. O0 100. O0 PYMT (:DMMENTS: Peri,it To Drill lee HANDL]NO INST: S/H - Te~-eie Hubl le X4&28 - All'ACHED CHECK I$ IN PAYMENT FOR rr~m DESCRIBED ABOVE. BI[tillS!Il 1 OO. OO 1 OO. OO PAY WELL PERMIT CHECKLIST COMPANY ,./~_~ WELL NAME~-Z.~/~/ PROGRAM: exp dev FIELD & POOL redrll ~ serv ",Z wellboreseg ADMINISTRATION Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available, in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can. be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ann. disposal para req INIT CLASS / '- ~,~', GEOL AREA 1. ~N · ~- . 4. 5. . 6. Y N 7. Y N 8. Y N ' 9. Y N .. 10. Y N ' " 11. Y N 12. Y N ' " 13. Y N 14. Conductor string provided ................... N ') ~ ' 15. Surface casing protects all known USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... ~i~--~" 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. (~ N ¢~.~-~'.-c ~"~.¢ / ¢.,.o t--r.2_~,.:,~_ ~.~- 21. If a re-drill, has a 10-403 for abandonment been approved... ~.~ N 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... 24. Drilling.fluid program schematic & equip list adequate ..... ~ N . 25. BOPEs, do they meet regulation ........... '-". · · 'LY_) N 26. BOPE press rating appropriate; test to '.$~"~ L.)psig. 27. Choke manifold complies w/APl RP,53 (May 84) .' . . . .... ~ N - - - - \ ... ' 28. Work will occur without operation shutdown .......... ~...~L_ ~ ~'~_~.'q.'~,:q. ~,,.S'k \'~'~ '~' ~c~..~,.%~,,- ,~.~'c_~k~,~. ., · _ 29. Is presence of H2S gas probable ................. y GEOLOGY 30. Permit can be issued wlo hydrogen sulfide measures ...... ' Y N ,/ 31. Data presented on potential overpressure zones ....... Y/N/ ,,~ ~ ,,,,,) 32. Seismic analysis of shallow gas zones ........... . . Y//N /'/~/r-/~, D T Contact name/phone weekly progress reports [exploratory on~] Y N for /~R ? D/AT/E?34. 33. Seabed condition survey (if off-shore) ....... . ..... /'Y N ' ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N ENGINEERING: UIC/,~nular COMMISSION: Ys,~ ~._/,~ ~ JM~ Comments/Instructions: O Z O rtl c:\msoffice\wordian\diana\checklist (rev. 11/011/00) Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this .nature is accumulated at the end of the file under APPEN. DIXi No 'special'effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 01/12/17 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 01/12/17 182034 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** RECEIVED DEC 1 2001 Alaska Oil A Gas Cons. Commissio~'~ Anchorage Remark File Version 1.000 Extract File: ldwg.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block 9MI~EM. UNIT Data Type STRT.FT STOP FT STEP F? NULL COMP WELL FLD LOC CNTY STAT SRVC TOOL DATE API CWLS log ASCII Standard -VERSION 1.20 One line per frame Information 9159.0000: Starting Depth 10926.0000: Ending Depth 0.5000: Level Spacing -999.2500: Absent Value COMPANY: BP Exploration, Inc. WELL: S-20A FIELD: Prudhoe Bay Unit LOCATION: 1630' SNL, 903' EWL COUNTY: North Slope STATE: Alaska SERVICE COMPANY: Baker Hughes INTEQ TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray LOG DATE: 16-Jul-01 API NYUMBER: 500292163701 ~Parameter Information Block 35 : Section T12N : Township R12E : Range MSL : Permanent Datum 0 : Elevation Of Perm. Datum RKB : Log Measured from 70.69 : Feet Above Perm. Datum KB : Drilling Measured From 70.69 : Elevation of Kelly Bushing N/A : Elevation of Derrick Floor N/A : Elevation of Ground Level N/A : Casing Depth DIRECTIONAL : Other Services Line 1 9MNEM.UNIT Value Description SECT. TOWN. N RANG. PDAT EPD F LMF FAPD F DMF EKB F EDF F EGL F CASE F OS1 ~Remarks (5 Multiple 10926' MD Ail depths are Measured Depths (MD) unless otherwise noted. All depths are Bit Depths unless otherwise noted. All Gamma Ray data (GRAX) presented is realtime data. Well S-20A was drilled as a sidetrack on well S-20 The sidetrack (TOW) began on MWD Run 92 at 9150' MD (8537' SSTVD). Baker Hughes INTEQ utilized Gamma Ray the Orient Express with Ultra Slim Propagation Resistivity (USMPR) services from 9171' MD (8554' SSTVD) to (8985' SSTVD). (7) The interval from 10896' MD (8959' SSTVD) to 10926' MD (8985' SSTVD) was not logged due to sensor to bit offset. (8) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BPX ( SWS, 18 July, 2001). (9) A Magnetic Declination correction of 26.62 degrees has been applied to the Directional Surveys. (10) Surface Logging System / Software : CTMWD / DRILLBYTE (11) Gamma Ray Detector Type: Scintillator MNEMONICS: GRAX = Gamma Ray MWD-API [MW-D] (MWD-API units) ROPS = Rate of Penetration, feet/hour TVD = Subsea True Vertical Depth (SSTVD), (feet) TCDX = Downhole Temperature [MWD], (deg F) RACLX = Resistivity Compensated 400 kHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) RPCLX = Resistivity Compensated 400 kHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) RACHX = Resistivity Compensated 2 MHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) RPCHX = Resistivity Compensated 2 MHz Phase Difference Resistivity Borehole Corrected [MWD], (ohm-m) SENSOR OFFSETS: RUN GAMMA DIRECTIONAL N/A N/A N/A CURVE SHIFT DATA BASELINE 9163 74 9185 41 9207 07 9233 11 9237 28 9242 70 9254 16 9270 20 9283 11 9311 03 9315.61 9321.24 9334.16 9350.61 9359 78 9382 28 9398 53 9439 99 9442 49 9455 61 9471 03 9474 78, 9569 16, 9578 11, 9584 99, 9626 03, 9639 57, 9654 57, 9695 20, 9712 07, 9717 91, 9724 78, 9740 20, 9764.78 9777.91 9783.74 9809.78 9816.86 9821.24 9844.16 9868.53 9887.07 9893.53 9896.03 9902.70 9911.24 9943.11 9951.66 9980.61 10010.6 MEASURED, 9163.11 9185.61 9207.07 9232.70 9236.45 9243.11 9253 95 9270 20 9283 53 9309 99 9315 20 9320 4'1 9333 32 9349 99 9363 11 9382 28 9398 11 9438.95 9441 86 9454 99 9471 03 9473 32 9566 66 9576 03 9583 11 9623 74 9636.45 9653.53 9696.45 9708.74 9715.82 9722.70 9739.57 9764.78 9776 66 9782 49 9807 49 9814 36 9818 95 9841 03 9867 49 9886 66, 9891 86, 9894 78, 9902 49, 9909 99, 9942 49, 9950 41, 9978 95, 10010.4, DISPLACEMENT -0.625 0.208008 0 -0.416992 -0.833984 0.416016 -0.208008 0 0.416992 -1.04199 -0.416016 -0.833008 -0.833984 -0.625 3.33301 0 -0.416992 -1.04199 -0.625 -0.625 0 -1.45898 -2.5 -2.08301 -1.875 -2.29199 -3.125 -1.04102 1.25 -3.33301 -2.08301 -2.08398 -0.625 0 -1.25 -1.25 -2.29199 -2.5 -2.29199 -3.125 -1.04199 -0.416992 -1.66699 -1.25 -0.208008 -1.25 -0.625 -1.25 -1.66699 -0.208008 10020 10088 10290 10312 10324 10392 10397 10425 10431 10442 10447 10455 10457 10500 10505 10517 10527 10557 10562 10566 10573 10578 10584 10587 10591 10617 10646 10661 10678 10685 10699 10714 10727 10838 10849 10867 EOZ .END 4 9 4 1 2 7 .7 .0 .0 .7 .9 .2 .1 .2 8, 9, 3, 7, 3, 2, 3, 5 2 8 0 8 3 7 0 7 9 7 4 9 7 7 10019.6 10086.9 10287.7 10312.3 10322.7 10390.6 10396.0 10423.9 10428.9 10441 0 10448 1 10454 6 10456 7 10497 5 10504 8 10518 3 10528 3 10555.6 10559.6 10563.3 10571.2 10575.2 10581.9 10585.5 10588.5 10615.7 10643.4 10659.0, 10675.3, 10682.2, 10697.2, 10710.9, 10725.9, 10834.5, 10850.2, 10865.8, -0.833008 -2.08301 -2.70898 0.208008 -1.45801 -2.08301 -1.66602 -1.04102 -2.08301 -1.66699 0.208008 -0.625 -0.416016 -2.70801 -1.04199 0.416992 1.04102 -2.08301 -2.70801 -2.91602 -2.08301 -3.33398 -2.29102 -2.29199 -2.5 -2 08301 -2 91602 -2 70801 -2 70801 -3 54102 -2 70801 -3 75 -1 45801 -4 375 0.416992 -1.875. BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 164 records... Minimum record length: Maximum record length: 10 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MI~EM VALU WDFN mwd.xtf LCC 150 CN BP Exploration. Inc WN S-20A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 18-Jul-01. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM GR GR ROP ROP RACL RACL RACH RACH RPCH RPCH RPCL RPCL TCD TCD GRAXll ROPSll RACLXll RACHXll RPCHXll RPCLXll TCDXll ODEP 0 0 0 0 0 0 0 0 0 0 0 0 0.0 FORMAT RECORD (TYPE% 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size 1 GR MWD 68 1 2 ROP MWD 68 1 3 RACL COMP 68 1 4 RACH COMP 68 1 5 RPCH COMP 68 1 6 RPCL COMP 68 1 7 TCD COMP 68 1 API F/HR Length 28 Total Data Records: 115 Tape File Start Depth = 9159.000000 Tape File End Depth = 10926.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 129 records... Minimum record length: Maximum record length: 38 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration. Inc S-20A Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX GRAX 0 ROPS ROPS ROPS 0 RALX RALX RACLX 0 RAHX RAHX RACHX 0 RPHX RPHX RPCHX 0 RPLX RPLX RPCLX 0 TCDX TCDX TCDX 0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7'Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 2 ROPS MWD 68 1 3 RALX COMP 68 1 4 RAHX COMP 68 1 5 RPHX COMP 68 1 6 RPLX COMP 68 1 7 TCDX COMP 68 1 API F/HR Total Data Records: 115 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 4 4 28 Tape File Start Depth = 9159.000000 Tape File End Depth = 10926.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 129 records... Minimum record length: Maximum record length: 38 bytes 4124 bytes **** TAPE TRAILER **** MWD 01/12/17 182034 01 **** REEL TRAILER **** MWD 01/12/17 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP RPCH RPCL TCD 9159.0000 -999.2500 9159.5000 -999.2500 9200.0000 29.6442 9300.0000 166.7089 9400.0000 8.0239 9500.0000 4.8698 9600.0000 8.6495 9700.0000 8.6723 9800.0000 7.2030 9900.0000 12.4326 10000.0000 7.4919 10100.0000 8.6257 10200.0000 11.7281 -811.4645 -999.2500 36.4440 -999.2500 82.3233 33.7620 66.9948 229.2734 39.0354 7.8274 32.3906 4.9696 32.0300 8.6987 23.9632 8.7506 22.8347 8.0382 40.9419 12.2581 28.7504 7.5343 20.8399 9.2801 38.6789 11.4080 -815.1873 -788.1982 14.4893 164.2347 29.4594 140.0000 27.2450 138.2000 57.6643 140.0000 126.3541 141.8000 184.3328 141.8000 167.2918 150.8000 84.4224 147.8889 87.0675 149.0000 103.5155 152.6000 11.9067 156.2000 114.0979 156.2000 RACL -999.2500 -999.2500 43.6484 384.6528 7.6628 5.4421 8.6436 8.3248 8.8417 10.5524 8.0571 10.3585 10.8828 12.8180 RACH -999.2500 -999.2500 46.8673 6064.5420 7.9407 5.1165 9.2078 9.1537 8.5929 13.2752 7.7772 9.9709 12.0648 12.7365 10300.0000 24.6150 136.2330 9.7720 10.8930 158.0000 10400.0000 28.4518 90.5805 11.9611 11.5627 159.8000 10500.0000 40.8592 106.8414 6.9141 6.9470 159.8000 10600.0000 35.6656 60.5162 6.4418 6.1502 167.0000 10700.0000 111.4220 93.7290 9.0381 9.2085 163.4000 10800.0000 18.3321 75.2776 3.2015 3.3933 165.5575 10900.0000 -999.2500 32.8242 -999.2500 -999.2500 167.0000 10926.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = feet Tape Subfile 3 is type: LIS 9159.000000 10926.000000 0.500000 DEPTH GRAX ROPS RPHX RPLX TCDX 9159.0000 -999.2500 9159.5000 -999.2500 9200.0000 29.7950 9300.0000 159.3180 9400.0000 8.2500 9500.0000 5.1590 9600.0000 9.1280 9700.0000 8.6650 9800.0000 7.1760 9900.0000 12.5010 10000.0000 7.7660 10100.0000 8.7010 10200.0000 11.2560 -999.2500 -999.2500 -999.2500 -999.2500 84.0110 33.8660 105.5800 211.9390 57.6520 7.9360 25.4960 5.2330 34.6060 8.9100 23.6320 8.7440 24.6020 8.0910 40.0430 12.3420 33.1010 7.7180 21.8970 9.2090 43.0280 11.0820 26.2040 10.6210 -999 -999 10300.0000 9.4220 .2500 .2500 -999.2500 -999.2500 29.4010 140.0000 27.7270 138.2000 58.7760 140.0000 138.6860 141.8000 180.3310 141.8000 167.3350 150.8000 84.2890 147.2000 82.9970 149.0000 106.8870 152.6000 75.6950 155.3000 124.3270 156.2000 138.2760 158.0000 10.3655 7.1266 6.2324 10.1351 3.4402 -999.2500 -999.2500 RALX -999.2500 -999.2500 43.3610 309.6880 7.6260 5.6410 8.6030 8.3200 8.9280 10.5800 8.1200 10.1730 10.7630 12.6950 10.2260 11.7281 6.9337 6.3781 9.2294 3.6261 -999.2500 -999.2500 RAHX -999.2500 -999.2500 46.6770 6064.5420 7.9640 5.3680 9.1550 9.1450 8.8210 13.4100 7.9380 9.7670 11.8370 12.5140 11.7220 10400.0000 79.0320 72.5120 12.6860 11.8420 159.8000 10500. 0000 41. 5230 123. 8200 6.4750 6.5700 159.8000 10600.0000 33.5540 77.9290 6.5720 6.4090 167.0000 10700.0000 25.0490 68.7600 8.5720 8.8560 163.4000 10800.0000 19.9570 75.0030 3.4240 3.4520 165.2000 10900.0000 -999.2500 38.4680 -999.2500 -999.2500 167.0000 10926.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9159.000000 Tape File End Depth = 10926.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 6.9320 6.5720 9.7510 3.3970 -999.2500 -999.2500 6.5840 6.6090 9.3140 3.5750 -999.2500 -999.2500 Tape Subfile 4 is type: LIS