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200-081
Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 01/12/2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 4Q 2022. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through the end of 4Q 2022. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. 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 have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Engineer Hilcorp North Slope, LLC By Samantha Carlisle at 3:53 pm, Jan 12, 2023 Digitally signed by Oliver Sternicki (4525) DN: cn=Oliver Sternicki (4525), ou=Users Date: 2023.01.12 14:52:49 -09'00' Oliver Sternicki (4525) 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU D-13A Squeeze Perforations, Attempt to Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-081 50-029-20449-01-00 12290 Conductor Surface Liner Liner 9057 2652 10436 1220 2345 11250 13-3/8" 9-5/8" 7" 2-7/8" 8935 26 - 2684 25 - 10461 9933 - 11153 9949 - 12294 26 - 2684 25 - 8347 7989 - 8865 8000 - 9059 11232, 12238 2670 4760 7020 13890 11250 5380 6870 8160 13450 11290 - 12249 4-1/2" 12.6# 13cr80, L80 22 - 9995 8958 - 9039 Structural 80 20" x 30" 26 - 106 26 - 106 5-1/2" Baker S3 Packer - 9626, 7768 4-1/2" TIW Packer - 9909, 7971 9626, 9798, 9862, 9909 7768, 7891, 7937, 7971 Stan Golis Sr. Area Operations Manager Kirsty Glasheen Kirsty.Glasheen@hilcorp.com 907.564.5258 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028285 22 - 8033 Perforations from 10605 - 10636 MD 10-bbls 13.4--ppg FineCem, 15.5-bbls 15.3-ppg Class G Cement. Final squeeze pressure = 1954-psi 557 Well Not Online 54729 54 850 350 1027 0 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S3 Packer - 9798, 7891 4-1/2" TIW Packer - 9862, 7937 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations No SSSV Installed ect to the best of my kn January 10, 2023 By Meredith Guhl at 1:39 pm, Jan 10, 2023 RBDMS JSB 011223 DSR-1/10/23 Plug Perforations Sundry Number Squeeze Perforations, Attempt to Mill CIBP PBU D-13A PRUDHOE BAY, PRUDHOE OIL WCB 10-26-2023 N/A 200-081 ACTIVITY DATE SUMMARY 12/7/2022 CTU#9 1.75" Coil 0.145 WT Job scope: Cmt Sqz perfs/liner , mill CIBP MIRU CTU#9. Load/kill well with 1%KCL w/SL. ***Job in Progress*** 12/8/2022 CTU#9 1.75" 0.145 WT Job Scope: Cmt Sqz perfs/liner, mill CIBP Finish well kill. Pump diesel FP and RIH. Tag CIBP at 11,236' ctmd. Correct to plug depth. PUH to 11,230' corrected and flag the coil. PUH above the liner top 9900'. Finish pumping diesel down the backside of the coil for underbalance. Pump 10 bbls of FineCem followed by 15.5 bbls of 15.3 Class g cement. Bullheaded 12 bbls out the coil down the liner into the perf, laid in 13.5 bbls. ~8 bbls of cement behind pipe. Performed 2000 psi squeeze. Bled pressure down to 500 psi and contaminated to the CIBP at 11,250. Chase OOH washing jewelry. Recovered 5/8' ball. Swapped out BHA to BOT motor w/Venturi burnshoe. Pressure tested squeeze to 1500 psi. Bleed down and RIH. ***Job in Progress*** 12/9/2022 CTU#9 1.75" 0.145 WT Job Scope: Cmt Sqz perf/liner, mill CIBP RIH with BOT motor w/Venturi burnshoe. Set down 10,777' ctmd, Was able mil through. Sat down at 11,125' ctmd. Millied through with ease down to the CIBP at 11,235' ctmd (11250 MD). Milling the plug and had a couple of stalls. Third stall was detained. Jarred 50 times while pumping many ways and rates to free the bit with no success. Freeze protect the coil and well. Pump 1/2" ball and disconnect. CT free, POOH. Cut off tools and 120' pipe. MU BOT fishing BHA and RIH to fish motor/venturi. ***Job in Progress*** 12/10/2022 CTU#9 1.75" 0.145 WT Job Scope: Cmt Sqz perf/liner, mill CIBP RIH w/ BOT fishing BHA to fish motor/venturi. Tag at 10777'. Try to work thru at different speeds, pumping and not pumping, but unable to get thru. POOH. Discuss with OE for plan forward. Decide to try and mill/cleanup tight spots at 9956' and 10777', then resume fishing and plug milling. MU 1-11/16'' milling BHA w/ YJ 2.22" crayola mill. RIH and tagged obstruction at 10,775' ctmd. Milled obstruction down and backreamed up through. Dry drifted to the fish. POOH. ***Job in Progress*** 12/11/2022 CTU#9 1.75" 0.145 WT Job Scope: Cmt Sqz perf/liner, mill CIBP RIH w/ BOT fishing BHA to fish motor/venturi. Return line freezes up, wrap and put heaters on and thaw. Lines free, RIH and latch fish. PU and try jarring. No jar action seen, decide to pump off and circ in Safelube for weight transfer. Discuss with OE and decide to POOH and swap jars. Freeze protect CT, Freeze protect well. Perform pipe maint, MU BOT fishing tools RIH. Latch fish 11226 ctmd and begin jarring. Jar 18 times then try to pump off. Unable to circulate down coil. Try surging coil, wrap reel and try heating. ***Job in Progress*** Daily Report of Well Operations PBU D-13A RIH with BOT motor w/Venturi burnshoe. Set down 10,777'ctmd, Was able mil through. Sat down at 11,125' ctmd. Millied through with ease down to the CIBP atgg 11,235' ctmd (11250 MD). Milling the plug and had a couple of stalls. Bullheaded 12 bbls out theyg coil down the liner into the perf, laid in 13.5 bbls. ~8 bbls of cement behind pipe. Performed 2000 psi squeeze. Tag CIBP at 11,236' ctmd. CTU#9 1.75" Coil 0.145 WT Job scope: Cmt Sqz perfs/liner , mill CIBP Daily Report of Well Operations PBU D-13A 12/12/2022 CTU#9 1.75" 0.145 WT Job Scope: Cmt Sqz perf/liner, mill CIBP Continue heating reel/reel iron. Pressure up coil then dump to try to move fluid. Rig up MM bypass and pressure up to 5300 psi and get circulation. Pump 60/40 and try to release off fish. Swap to KCL for higher rate, but unable to release off. Drop 5/8" ball and release at disconnect. POOH. Top the well off with 23 bbls of 60/40 methanol. Freeze protected. Perform weekly BOP test. Fish left in hole, Fish #1 on bottom - Disconnect, Motor and Venturi burn shoe. Fish #2 Hydaulic G Spear, circ sub and disconnect latched into the lower disconnect. Will be one fish all together when recovered. ***Job Incomplete*** The cement squeeze of the only open perfs was performed. But, the milling of the CIBP did not take place, as a milling assy was left in-hole as a fish. -WCB STATE OF ALASKA [ill-EC " ALASKA OIL AND GAS CONSERVATION COM N REPORT OF SUNDRY WELL OPERA S '} p 1. Operations Performed MAY 1 5 201U Abandon 0 Plug Perforations RI Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑' Suspend 0 Perforate RI Other Stimulate ❑ Alter Casing 0 Change Apprtir r tCg Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set CIBP' 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 200-081 3. Address: P.O.Box 196612 Anchorage, Development a Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20449-01-00', I 7. Property Designation(Lease Number): ADL 028285 8. Well Name and Number: PBU D-13A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12290 feet Plugs measured 111250 feet true vertical 9057 feet Junk measured 12238 feet Effective Depth: measured 11250 feet Packer measured 9626,9798,9862,9909 feet true vertical 8934 feet Packer true vertical 7768,7891,7937,7971 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"x 30" 26-106 26-106 0 0 Surface 2652 13-3/8"72#L-80 26-2678 26-2678 5380 2670 Intermediate 10438 9-5/8" 27-10465 27-8350 6870 4760 Liner 1226 7" 9935-11161 7990-8872 8160 7020 Liner 2345 2-7/8" 9949-12294 8000-9059 13450 13890 Perforation Depth: Measured depth: 10605-12249 feet True vertical depth: 8445-9039 feet JUN 1 121E I U SCANNED Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#x 5-1/2"17#,13Cr80/L-80 25-9995 25-8033 Packers and SSSV(type,measured and Baker S-3 Packers x 2 9626,9798 7768,7891 true vertical depth) TIW Packers x 2 9862.9909 7937.7971 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 546 40980 100 0 922 Subsequent to operation: 271 20199 0 0 729 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory 0 Development ® Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Alatalo,Travis Contact Name: Alatalo,Travis Authorized Title: Production Engineer Contact Email: Travis.Alatalotbp.com Authorized Signature: C/•-2��jr� r.,e--"----4---;"--... -='---� Date: 5-1 t 1-k./(6 Contact Phone: +1 9075645351 � Form 10-404 Revised 04/2017 /1 eV 4./18 RBDMS PMAY 2 9 2018 Submit Original Only 4°' f 1 • 'at iNIT • 44. AV la. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) May 10, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Plug Perforations (Set CIBP) and Perforate for Well PBU D-13A, PTD #200-081. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • Daily Report of Well Operations PBU D-13A ACTIVITYDATE SUMMARY ***WELL S/I ON ARRIVAL"**(profile mod) DRIFTED LINER W/30'x 1.75"BAILER DRIFT TO 11,267'SLM. LRS LOADED TBG W/240 BBLS OF CRUDE.(see Irs log) RAN SLB SCMT LOG FROM 11,265'SLM TO 9850'SLM. (good data) LRS PUMPED 103 BBLS OF CRUDE DOWN TBG FOR LOG.(see Irs log) SET 4 1/2"X-CATCHER SUB IN X-NIPPLE AT 9593' MD. 3/30/2018 ***CONT ON 3-31-18 WSR*** ***CONT FROM 3-30-18 WSR*** PULLED DMY-GLVS FROM STAs#3 AT 3724' MD AT 7331'MD. SET RK-DOME GLV(SN:A1ZG-0128R) IN STA#3 AT 3724' MD. SET RK-OGLV(SN: J17A-0055T) IN STA#2 AT 7331' MD. DRIFT LINER W/34'x 2.16" DMY GUNS&2.31"CENT TO 11,271'SLM SAT DOWN ON PATCH .(no issues) 3/31/2018 ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** ***WELL SHUT-IN ON ARRIVAL***(SLB E-LINE PERFORATING, CIBP) INITIAL T/I/0=2250/420/NA RIH W/31'X 2.0"PJ HSD, 6SPF, 60° PHASE, MAX OD=2.21 (MAX SWELL IN GAS) ISSUES GETTING PAST LINER TOP AT 9949', POOH ADD 2.28"CENTRALIZER W/BULLNOSE TO BOTTOM OF BHA RIH W/31'X 2.0" PJ/2.28"CENT/BULLNOSE(PERF INFO SAME AS ABOVE) CCL STOP DEPTH= 10601.75' CCL TO TOP SHOT=3.25' PERFORATED INTERVAL=10605'-10636' TOOLSTRING STUCK IN PLACE AFTER FIRING GUN, PULL UP TO MAX SAFE PULL—2300 LBS(NORMAL TENSION-1400 LBS), NO LUCK LRS PUMP CRUDE AT VARIOUS RATES FROM 1-5 BPM, NO LUCK FIRE ERS, APPEARED TO FAIL RELEASE COMMAND BUT TOOL CAME FREE WHILE HOLDING 2600#SURFACE TENSION PROCEED TO POOH. 4/3/2018 ***JOB CONTINUED ON 4-APR-2018*** ***JOB CONTINUED FROM 3-APR-2018*** TOOLS RELEASED FROM ERS AT 1116'WHILE POOH. TOOL RELEASE CONFIRMED, RIG DOWN. ***TOOLS LEFT IN HOLE: ERS(1.375" FN)/WEIGHT/UPCT/31 X 2.00" POWERJET HSD(FIRED)/X0- SR/2.28"CENT/BULLNOSE. OAL LIH =46.7', OAW=300 LBS, MAX OD=2.28"*** 4/4/2018 ***WELL LEFT SHUT IN ON DEPARTURE*** ***WSR Continued from 04-03-18*** Assist E-Line (PROFILE MODIFICATION) No fluids pumped, 4/4/2018 Standby for E-line to POOH, E-Line in control of well @ departure, FWHP= 100/320 ***WELL FOUND S/I ON ARRIVAL SWCP 4518***(profile mod) RAN 3.60" BELL GUIDE, 2.50" BELL GUIDE&2"JUC S/D ON TBG STUB @ 9732' SLM WORK TOOLS PAST, S/D @ 9840'SLM&UNABLE TO PASS. RAN 3.35" BELL GUIDE(mule shoe)&2"JUC NO ISSUES&TAG DEP SLV @ 9932'SLM (9949' MD). PULL E-LINE TOOL STRING FROM 11,217'SLM. (11,229'MD)**(recoverd entire tool sting)** 4/26/2018 ***CONTINUE WSR TO 4/27/18*** ***CONTINUE WSR FROM 4/26/18 SWCP 4518**"(profile mod) ) DRIFT W/2.135"CENT, 5' 1-1/2", 2.25"CENT&2.0" LIB TAG PATCH @ 11,267'SLM GOOD IMPRESSION OF TOP OF PATCH. SET BAKER CIBP(max od=2.22", lih =2.42')@ 11,238'SLM+ 12'CORRECTION = 11250' MD. ***WELL LEFT S/I PAD OP NOTIFIED ON DEPARTURE*** 4/27/2018 ***TOP OF PATCH MAYBE DAMAGED*** Fluids Summary Bbls Type 4 Diesel 3 60/40 Methanol 543 Crude I ' - D l 3A . WELL} AD- FMC S NOTES:WELL ANGLE>TIP @ 11408' "CHROMETBG'"" ACTUATOR= BAKER C OKB ELEV- 71 61' 13-3/8"SURFACE CSG CUT 1 14 •.$ I 40, . 1974' -I9-5/8"HES ES CEMENTER BF.ELEV= 47.91' OFF&NEW 9-5/8" itil KOP= 3200' WELLHEAD INSTALLED .'+ 1991' -I9-518"BKR ECP,D=8.70" - Max Angie= 94°@ 11559' ��g A IP; ii 2012' -14-1/2"HES X NP,D=3.813" Datum MD= 11161' GAS LIFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 9-5/8"BOW6d CSG -1 2013' 3 3724 3699 23 MMG DOME RK 16 03/31/18 PATCH,47#,L-80 BTC 2 7331 6201 49 MMG SO RK 20 03/31/18 D=8.681" 1 9512 7687 44 MMG DMY RK 0 06/12/09 13-3/8"CSG,72#,L-80 BTRS,D=12.347" --I 2684' 9693' -I4-112"HES X NP,D=3.813" Minimum ID = 1.30" @ 11305' ____.„,.....-.124' -�4-1r2"XO 5-112",D=3.910" ANCHOR LATCH IN 2-7/8" WFD .14 c 9626' -19-518"X 5-1/2"BKR S-3 PIR,13=4.760" WIDEPACK PATCH 9632' -I5-1/2"X04-1/2",D=3.880" 9664' H4-1/2"HES X NP,D=3.813" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, -I 9736' _0152 bpf,D=3.958" Or 9741' -I UNIQUE OVERSHOT 4-112"TBG STUB(06/09/09) - 9742' 9788' -14-1/2"HES XNIP,D=3.813" '4 ►M" 9798' -19-5/8-X 4-1/2"BKR S-3 PKR,D=3.875"(2001) 9832' H4-112^FEs X IW,D=3.813" 4-1/2"TBG, 12.6#,13CR80 NSCT, H 9852' 9820' -[TOP OF 4-1/2"TBG STUB(11/30/00) I .0152 bpf,13=3.958" Il 9861' -I4-1/2"HES X NIP,D=3.813" �1_ 9869' H CUSTOM UNIQUE OVERSHOT(2001) '. EL- 9862' H 9-5/8"X 4-1/2"T1W PKR,ID=3.875"(1996) , ' 9899' --I4-1/2"HES X NP,ID=3.813" 4-1/2"TBG, 12.6#,L-80, .0152 bpf,D=3.958" -I 9910' 9906' -TOP OF 4-1/2"TBG STUB(11/26/96) z ��^-I 9917' -1 UNIQUE CUSTOM OVERSHOT(1996) ►.1 TOP OF 7"LNR -I 9933' rl IN 9909' H 9-5/8"TW(PKR(1989) 4-112"TBG,12.6#,L-80,.0152 bpf,D=3.958" H 9994' I 9949' H DEPLOY MENT SLEEVE(2-7/8"LNR) 9961' -14-112"OTIS X NP,D=3.813^(BEHIND PIPE) 9-5/8"CSG,47#L-80,BTRS,D=8.681" -I 10460' ill 9982' -I4-1/2"OTIS XN NP,D=3.725"(BEHIND PIPE) TOP OF WHPSTOCK - 11160' , 9996' H 4-1/2"OTIS TBG TAIL,D=3.820"(BBIIND PIPE) i,; PERFORATION SUMMARY •'__--- i- BMD TT LOG ON XX/xwXX REF LOG:PDS DIJGR ON 06/28/00 11250' -I 2-7/8"BKR GBP(04/27/18) ANGLE AT TOP PERE:47°@ 10605' 11279'-11309' 2-718"WFD WIDEPACK PATCH, Note:Refer to Production DB for historical perf data 1D=1.30"(11/19/17) SIZE SPE INTERVAL Opn/Sqz SHOT SOZ /��,` 2" 6 10605-10636 0 04/03/18 ', 12238' -FISH:2-7/8"HES CEP 2" 6 11290-11300 C 04/20/10 y 0 MILLED&PUSHED TO BTM 2" 6 11414-11440 C 02/06/05 t':' ''''''''/:;;;',..��.�� �It1����1 ` (11!02!12) 2" 6 11550-11652 C 07/01/00 •••••••' 2" 6 11750-12050 C 07/01/00 ��.�.�.���.�.�� 2" 4 12100-12190 C 07/01/00 ������1��+����1 ` �� 1� , 2" 4 12225-12249 0 07/01/00 0).....4+ atill kip 14.1.444 .14414114111•11 Ai**, 7"LNR 29#,L-80,D=6.184" -I 11678' �r Orr 2-7/8"LNR,6.16#,L-80 STL,_0058 bpf,D=2.441" H 12294' DATE REV BY COMMENTS DATE REV BY OORTENTS PRUDHOE BAY UNIT 06/10/80 BS36 ORIGINAL COMPLETION 01/26/15 JM) CORRECTIONS PER TALLIES WPI L• D-13A 04/17189 NIES RWO 11/14/17 NXW/JNC SET 2-7/8"WFD LOWER PATCH PKR PERIAT No:'2000810 12/05/96POYON1f RWO 11/21/17 BIYJM)SET 2-7/8"WIDEPACK PATCH API No: 50-029-20449-01 06/30/00 NORDIC1 CTD SIDETRACK(I3-13A) 04/02/18 GJB/JMD GLV 00(03/31/18) SEC 23,T11N,R13E,2460'FSL&1067'FEL 01/16/01 N4ES RWO 04/09/18 JUJM) ADPERFS&SET FISH(04/03/18) 06/12/09 N4ES RWO 05/01/18 HPD/J1,43 PULL®FISH&SET CBP BP Exploration(Alaska) • • CO 01 O :- s O ~ N O m ' c- 0 > N o ` 3 CV co N an co a 03fl 0 H7.: Y O v CO _ s.) a a a• ci c c o m C _O fl �a c xk Q t u c Q 6 m d J ▪ N O W Q co to C co co co 1 O W N F_ O 1 .0 .Q . co fC L -6 i-, L v, F . J .7 lL lL tL ur v- O _c vn LL,_, O C (p U N 1` Vt F-- in 1� e- M oc 00 z g E v O O C • u + cio O 'all (6 41 in N U ❑ ❑ ❑ ❑ ❑ ❑ ❑ Ct' N 1-1 Cq >- W W W W W W W C.1 `� F- LL LL LL LL LL LL LL u N O 4J 0 > a _0 > L Q a d d d d d d d a) 0 O ,- O z Z z z Z Z Z N s v O v LL LL LL LL LL LL LL K -Q C > C.': (6 >+ �+ C _" +' N O ..e- - p; 47.ul (13o %... c a:. > U N 0 Zi O v F- T.y (a F- < v a a Oc n. E v (n 2 w g u O Cl N m c 2 2 ° N C.1 y U U N > o 00 CO Emma' m uvvi o0 Q Vet d U v O c °% o >; = U co C N Y ❑'. CO CO N (� l7 > q -O cw r '3 oa dv C v p v L (p .0 i Z O N (i Z L E y U (0 O W r.p > > >, >. >, N > Z N t V a 0 ,J O O O J O L ro m e z m a£i CL) CD d n Q Q Q m d In An 2 2 2 2 E E E Q O 0 ..41/ j il. _C O. } uO illP ZW Q d Q Q Q LI g CO CO CO d CO CO ZWcC W 00 OO O O O O O O W D D ' v — Z N LL d' LL' d' IN +0 o 2 at),-.45, d o LL LL d 0 Ug! CD 0 tlA (C >— CV M M M M N VI X (n — Q �$ CO ■■■ ■i cc 0 0 0 0 0 O a) �� O O N O O O p O V C3> > f6 ,.,.:. H 0000000 C cox w vi LO 0 0 0 0 0 0 0 OCD Q N O 6 OD (O 6 6 7H E N N •fD r 0 t, ra N CO O CO N CO O 0 O N N N (‘..1 N N N N L _D O N N N N N N N 4! a Q) 0 0 0 0 0 0 0 •L 0 0 0 0 0 0 O 0 a) r-Ia* LT, m al C w ' - co v en i-Z a' E a1u .> Y L W Y 0 �. C O U v Q N s La 1 3 d 0 '.1.j- ai 'rill + d rn d d c d d r E 4, v- QI Z .-' &I m Z N U) <- N O O +' E 0 H V1 T. N J N P E m d 1,1 = a d O N J o 0 Y 6 wZ ❑ ,� Z G7 (o '= v H C O L. in -No .E OJ (o 0CID a `6Qc.._1 a` a • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed DEC 0 4 z017 Abandon ❑ Plug Perforations I1 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing 0 Chart cird;•Z-• fig - ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Stra•dle'atc over Perf I1 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 200-081 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20449-01-00 7. Property Designation(Lease Number): ADL 0028285 8. Well Name and Number: PBU D-13A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 12290 feet Plugs measured feet I true vertical 9057 feet Junk measured 12238 feet DEC 0 4 01y Effective Depth: measured 12251 feet Packer measured See Attachment feet true vertical 9040 feet Packer true vertical See Attachment feet 4CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 26-106 26-106 Surface 2652 13-3/8"72#L-80 26-2678 26-2678 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11290-11300 feet 11414-11440 feet 11550-11650 feet 11750-12050 feet 12100-12190 feet 12225-12249 feet True vertical depth: 8958-8964 feet feet 9010-9017 feet 9019-9014 feet 9015-9012 feet 9009-9016 feet 9028-9039 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: scANNED D E i. 2 8 2017, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 631 44604 82 1160 957 Subsequent to operation: 608 45728 72 1540 960 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development II Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I I Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Haffener,Jordan Contact Name: Haffener,Jordan Authorized Title: Production Engineer Contact Email: Jordan.Haffener@bp.com Authorized Signature: . zae � _7 Date: PZf�/Zei7 Contact Phone: +1 9075645383 Form 10-404 Revised 04/201 . r7-t- /z/ //7--le/gni RBD S LL- LEI 0 2017 Submit Original Only • • ilk440 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary November 30, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Straddle Patch over the upper set of Perforations for Well D-13A, PTD # 200-081. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • Packers and SSV's Attachment PBU D-13A SW Name Type MD TVD Depscription D-13A PACKER 1996.52 1996.51 9-5/8" BOT External CSG PKR D-13A PACKER 2610.04 2609.95 9-5/8" DV Packer D-13A TBG PACKER 9628.7 7770.24 5-1/2" Baker S-3 Packer D-13A TBG PACKER 9800.43 7893.02 4-1/2" Baker S-3 Hydro Set Packer D-13A TBG PACKER 9861.25 7936.79 4-1/2" TIW HBBP-T Packer D-13A TBG PACKER 9909.3 7971.57 4-1/2" TIW Packer • • 0 0 0 0 0) 000000 R r O CO N co O CO O O Oco O O In N Ln O N V V r- r- CO N- ti N- U N 00009000000 i COI- CO CO V- 0000C'7 C`7 CY) CO CO �- MV N-- V' `:1"m V CO CO 00 CO I- co CO co CO co co O N CA O) Ln co N- N CO 00IO N- CC) O N- IC) M N- CO CO O CO CO O N- N- CO CA 0) O N N CO CO 0) f- N- N- N- N CO F- CO O O 0) 1.0 ,- NN CO Cfl N 0) O Cn O N- LO CO [ N N N O 0) O N N- N CO 0) 0) N N- 00 N` N- N- N- co co IN- in V N O 10 CO CO (fl O N CO r CO — CA CO O V NCO CO N O C)) CA N CA C7) O C)) CA CA V p • Q Q▪ M co Lo 0) N.- C V 6) r O O N- CY) V I0 N CO V Cn0) I N N N O O) O) N CO CO N- co O) Q N CA C)) a) a) a) CA a) • M O O O H a o0O O � CDCp0200 O L _ J CO M U co M 00 CO co *k • d CO N *k J 10 *k 4, % CO CO ▪N N X �$ �' CO * CO co • • • • (� _ O N N N U N M 0\0 00 N LO cC) t� \O N N (NJ NCO N N CA CA LC) I"- CO 1.0 N • C) 0) -4- N O O O N Ln C 00 co O) N co co COO) N O 00 J N CO N o) W W Ct — — C H 0 0 .- UUww () DLL 22 tY zzzzzz Z W W W W CO CO CO CO CO 00 UU) ZZJJHHHHHf- 40 IP im II M 0 J CO - CO J_ Q N c `; 2 Z E; 0 " = a' I- 0 C 06 3 2 0 0 O p ` Q LL rTO U V) N + co O W >Z a) (1 J - O p O rn (I) F Ct 0 j Oa. 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Q C (Ni C N V) W w J rn x c_‘-- o , _ o a Y • w w F- O II J N w U Z J O - am U) m Q w 0 > a o O Q U .N m a • O O m > W w O2 z Z w v' Q zp - 6p ;F, ce - v w LL _".h 5 N 1 (/) Q E O cfl Om N J to !?- p LU CO ' (/) nI d O � < x w O c)-o c a) 0 2 z v a p LL II 0 E Q -, in X F- Z O LL E I- J - U Z d 0 O ~ II W 0 _ m O O w 0 = M N N 2 0 2O E O - Q m = J Q * w v O 0 Q pa_ ° m pu) in o u) fr LLZ 4_ c� cn v- W Z z 0 0Qa .c a fri— a > v c II ON „, •- , , p2 O M * U U w w a) - cF- aF- � 2 v) * eh -°° 0 > jz°J° ° OF- * m -1 in p -) m aai � O 20 � 2 0 � II oZ OZ - C) 0 (~/) Q0N- O a N- < (N._ N 0 F- m W II II Q a. 1N la W M0H1JpwO QUU LLN Q EF- F- m QN IT) *OQE Z coo > 2 coo • www- II pzU >- F- > Ce m eez z ,� a. - 7Lu _ Lu , 720 Roil J NZ oil FOpN 0Q - 200 �' zU U o p IlZM � II a Il Z II �'� Z � — � U = 00UNwZZ > Q-2- 0 O � p LL F- � pa � ▪CU 0 � in co Z E ,•,) Q2 J F- o w cn � 1- O ZN N F- OF- ^a. a) Z LL pW O0Z � >> JDV) d II ppw 2 2 w � O � L � ~ cn� > LL JZ O O � ci Nz > Q Jm � 2 � g w 0H F- U Lac\ ° 0 J 5. wI- II LnH - UQwao0 - W a LJ_ �) J - Off$ L- L>LI ZO 0 mWWOZ il ONOONJZ20 -� � EpW cNo OJT E v J � > WU OC/) (nU ~ ‘- zF- pUOF- U WF- 0H C6 OW ' ami a' ° �- ° WOF s- m F- c Q O � Wz � UVT > z N > II O z II a II > U w w O E 5. 2> O c = w O H D a O * O ZL? E ,- E _14:( w CC ov * F- CU E S H cn * Q _1 =1E : c LL d (>/) L>i * (;) CYW H (W/) co a 0 * w Q r` r- r- r- r- r- O o 0 0 0 0 0 CV N N CN I- CON O N N CO 5 rn N H o U Q • • Zr) r-- << I / 1- I E z I, G cc L1.12 O � a < a z z 0 Lu z a O_ z ■ coF / 0 00 _O ± § \ 5 C ƒ CN \ E ® O / e a .g I �� g / E \ O a R \ \ � \ / � > \ < 0 / \ H ° Q \ q % k8k / \ / 7 = © / 0 2 R 0 2 6 m $ ® ._ < a > \ p / \ \ � o_ % \ I ± u w # < O m < 2 - < E R p 1 3 d / 0 E - i w Z a G 2 » / ± t O_ I J / / � � U_ c.5 5 0 UJ - j I » � O \ < 0 2 2 2 ± I .Ca < g ƒ O < / \ CC) E \ \ / \ E / \ An co _ ® % CO 7 7 ^ O O / -J u E 7 \ _ R @ / » - - O \ \ \ Cl / H ® I _I -al L & 4 ± ± WEO0c - w \ \a 2R \ \ m \ OO D \ / t < ± 2 = 6 D - : s 2 E I ± E t « m g t b e O w w \ \ oo / / WELWE.. CM/ • D-1 3A S 4-112"CHROMEES:WELL ANGLE>70'@ 11408' 1 LFEAD= FMC ACTUATOR= BAKER C OKB.ELEV= 71.61' 13-3/8"SURFACE CSG CUT I 111 1' 1! ••� 1974' -j9-5/8"HES ES CEt�tTBt BF.ELEV= 47.9 OFF 8 NBN 9-518" KOP= 3200' WELLHEAD INSTALLED MA 1991' 9-5/8'BKR ECP,D=8.70" Max Angle= 94"@11559' 44f Datum MD= 11161' •• I., 2012' -4-1/2*HES XNP,D=3813' J Datum TVD= 8800'SS GAS LFT MANDRELS ST MD DVD DEV TYPE VLV LATCH PORT DATE 9-5/8"BOWENNCSG - 2013' 3 3724 3699 23 MAG DOME RK 16 11/18/17 PATCH,47#,L-80 BTC 2 7331 6201 49 MAG SO RK 20 11/18/17 ID=8.681" 1 9512 7687 44 MMG DMY RK 0 06/12/09 13-3/8'CSG,72#,L-80 BTRS,D=12.347" H 2684' 9693' -I4-1/2'HES X NP,D=3.813" Minimum ID = 1.30" @ 11305' --' X24' -14-1/2"xo51/r,D=3s1o" ANCHOR LATCH IN 2-7/8" WFD Z2 9626' —I9-5/8"x 5-112"BKR S-3 PKR,D=4.760" WIDEPACK PATCH 9632' H5-1/2"xo4-1/2',D=3.880" 9664' -14-1/2"HES X NP,I3=3.813" 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, H 9736' .0152 bpf,1)=3.958" /,.. 9741' --LONGUE OVERSHOT 4-1/2'TBG STUB(06/09/09) - 9742' 1 1' 9788' --14-1/2"HES X NP,D=3.813' 9798' -9-5/8'X 4_1/2"BKR S-3 PKR.D=3.875"(2001) 9832' -14-112'HES X NP,D=3.813" 4-1/2"TBG, 12.6#,13CR80 NSCT, - 9852' \_______---1 9820' -I TOP OF 4-112'TBG STUB(11/30100) .0152 bpf,D=3.958" ' ' 9$61' --14-1/2"HES X NP,D=3.813" 1 -------L 9869' --I CUSTOM UNQUE OVERSHOT(2001) Z 1 9862' I--19-5/8"X 4-1/2"T1W PKR,D=3.875"(1996) I I 9899' -14-112"HES X NP,03=3.813" bit---\-4 9906' F-TOP OF 4-1/2"TBG STUB(11/26/96) 4-1/2'TBG, 12.6#,L-80,.0152 bpf,D=3.958" -I 9910' ,g 9917 -{ CUSTOM OVERSHOT(1996) TOP OF 7"LN2 9933' f 9909' H9-5/8"TAN PKR(1989) L. , I 9949' H DEPLOY KENT SLEEVE(2-7/8"LNR) 4-1/2"TBG,12.6#,L-80,.0152 bpf,13=3.958' --I 9994' L 9961' H4-1/2"ORS X NP,D=3.813'(BeiM)PIPE) I9-5/8"CSG,47#L-80,SIRS,D=8.681" 1H 10460' 998T 4-1/2 OT1S XN NP,D=3.725" BEHIND PIPE) TOP OF WHPSTOCK --111160' "- 9996' -14-1/2"OTIS TBG TAL,D=3.820"(BEHIND PIPE — �� PERFORATION SUMMARY I 10001' -{ELMD TT LOG ON XX/XX/)0X REF LOG:PDS DIJGR ON 06/28/00 ANGLE AT TOP PEW:73'@ 11414' 11279' -11309' -2-7/8"WFD WIDEPACK PATCH, Nate:Refer to Production DB for historical pert data D=1.30"(11/19/17) SIZE SPF NTERVAL Opn/Sqz SHOT SOZ ��` 2" 6 11290 11300 C 04/20/10 w, A. 12238' -FISH:2-718"HES CBP 2" 6 11414-11440 0 02/06/0502/06/05 °. MILLED&RJSI�TO BTM tp �111111' (11102/12)11tt•t4 1 2" 6 11550 11652 0 07/01/00 11111111 0 1111111' 2" 6 11750-12050 0 07/01/00 .11111111111114 2' 4 12100-12190 0 07/01/00 1114.4•4 2" 4 12225-12249 0 07/01/00 •11111111111111 �� 12254' •1111111 .11111111111111 7'L142,29#,L-80,D=6.184' -1_11678' it!' IV 2-7/8"LM,6.16#,L-80 STL, 0058 bpf,D=2.441" -I 12294' DATE REV BY COMMENTS DATE REV BY COMMENTS F UJHOEBAY UNIT 06/10/80 BS36 ORIGINAL COMPLETION 01/26/15 JM) CORRECTIONS PER TALLIES WELL: D-13A 04/17/89 NIES RWO 11/14/17 NXW/JMC SET 2-7/8"WFD LOWER PATCH FKR PERF 1T No: 2000810 12/05/96 DOYON1€RWO 11/21/17 EPLYJMD SET 2-7/8"WIDEPACK PATCH AR No: 50-029-20449-01 06/30/00 NORDIC1 CTD SIDETRACK(D-13A) 11/27/17 JPK/JMD GLV CIO(11/18/17) SEC 23,T11N,R13E,2460'FSL&1067'FE 01/16/01 N4ES RWO 06/12/09 N4ES RWO BP Exploration(Alaska) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. (~:?'~- ~/ Well History File Identifier Organization (done) [] Two-Sided RESCAN DIGIT~,L-"OATA OVERSIZED (Scannable) E] r- )r items: ~'"'~ Di.~kDiskettes, No. ( [] Maps: " Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds ¢ [] Other TOTAL PAGES: NOTES: ORGANIZED BY: BEVERLY BREI~ SHERYL MARIA LOWELL Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN ~~~sHERYL MARIA LOWELL Scanned (done) PAGES: SCANNED BY: (at the time of scanning) BEVERLY BREN VINCENT~~MARIA LOWELL DATE: /SI RESCANNEDBY; BEVERLY BREN(~~~i~HERYLi ' MARIA LOWELL General Notes or Comments about this file: PAGES: Quality Checked (done) Rev1 NOTScanned.wpd RE(;tIV W STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMMION NOV 2 7 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon Ll Repair Well LJ Plug Perforations Li Perforate LJ Other L] Mill CIBP Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development is Exploratory ❑ - 200 -081 -0 3. Address: P.O. Box 196612 StratigraphiC Service ❑ 6. API Number: _ Anchorage, AK 99519 -6612 50- 029 - 20449 -01 -00 7. Property Designation (Lease Number): _ 8. Well Name and Number: ADL0028285 PBU D -13A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 12290 feet Plugs measured None feet true vertical 9056.76 feet Junk measured 12238 feet Effective Depth measured 9805 feet Packer measured See Attachment feet true vertical 7896.3 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H -40 24 - 104 24 - 104 1490 470 Surface 2660 13 -3/8" 72# L -80 24 - 2684 24 - 2683.9 4930 2670 Intermediate None None None None None None Production 9926 9 -5/8" 47# L -80 23 - 9949 23 - 8000.27 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11290 - 11300 feet 11414 - 11440 feet 11550 - 11650 feet 11750 - 12050 feet 12100 - 12190 feet 12225 - 12249 feet True Vertical depth 8958.11 - 8963.55 feet 9010.4 - 9017.1 feet 9018.67 - 9014.12 feet 9014.65 - 9011.67 feet 9008.71 - 9016.11 feet 9028.29 - 9038.67 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: SCANNED MAR 112013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 215 19468 0 0 726 Subsequent to operation: 0 0 0 x -,.. 0.. .� 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorL❑ Development © - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil _, U Gas ❑ WDSPLLJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCI 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email Garrv Printed Name Garry Catron Title PDC PE Signature N 4LAA-A'y C;t■Phone 564 -4424 Date 11/27/2012 , .�,- -. a - i ,. e / 24 (L • /Z--- 1 L Form 10 -404 Revised 10/2012 / ,2i,(k Submit Original Only Packers and SSV's Attachment ADL0028285 SW Name Type MD TVD Depscription D -13A PACKER 9626 7696.71 5 -1/2" Baker S -3 Packer D -13A PACKER 9798 7819.67 4 -1/2" Baker S -3 Hydro Set Packer D -13A PACKER 9862 7865.72 4 -1/2" TIW Packer D -13A PACKER 9909 7899.75 4 -1/2" TIW Packer • • it Casing / Tubing Attachment ADL0028285 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 24 - 104 24 - 104 1490 470 LINER 1217 7" 29# L -80 9933 - 11150 7988.72 - 8862.86 8160 7020 LINER 2345 2 -7/8" 6.16# L -80 9949 - 12294 8000.27 - 9058.53 13450 13890 PRODUCTION 9926 9 -5/8" 47# L -80 23 - 9949 23 - 8000.27 6870 4760 SURFACE 2660 13 -3/8" 72# L -80 24 - 2684 24 - 2683.9 4930 2670 TUBING 9840 4 -1/2" 12.6# 13Cr80 21 - 9861 21 - 7936.6 8430 7500 TUBING 58 4 -1/2" 12.6# L -80 9859 - 9917 7935.16 - 7977.15 8430 7500 • TUBING 84 4 -1/2" 12.6# L -80 9911 - 9995 7972.8 - 8033.34 8430 7500 • 1 • Daily Report of Well Operations ADL0028285 ACTIVITYDATE -' - SUMMARY CTU #8 w/ 1.75" CT: Job Scope: Mill CIBP. MIRU CT unit. MU and RIH with milling BHA w/ 2.31" 3 bladed junk mill. Tag top of CIBP at 11 346' ctmd. Mill plug and push to bottom at 11/2/2012 12,238' ctmd. RDMO. Freeze protect well with 40 bbls 60/40 meth. ** *Job Complete * ** CTU #8 w/ 1.75" CT: Job Scope: Mill CIBP. MIRU CT unit. MU and RIH with milling BHA w/ 2.31" 3 bladed junk mill. Tag top of CIBP at 11,346' ctmd. Mill plug and push to bottom at 11/2/2012 12,238' ctmd. RDMO. ** *Job In Progress * ** • • TREE = CM/ VlELLHEAD= FMC • , -13 4 SATES: WELL ANGLE> 70°. 11408' ** -1 F ROMETBM** ACTUATOR = BAKER C KB ELEV = 71.61' 13-3/8" SURFACE CSG CUT ( 114 1 ' fit` 1974' H 9-5/8" HES ES C E BVrER 1 BF ELEV = 47.91' OFF & NM 9 b8" • 4 v 1 A 1 W = KC - 3200' WRLL-EAD INSTALLED 1991' H9 -5/8" BKR ECP, D = 8.70" Max Angle = 94° ■ 11559' , Ili t, • / Datum M3= 11161' 2012' - 14 -1/2" HES X NP, D = 3.813" Datum ND = 8800' SS GAS LIFT MANDRELS ST MD 1VD DEV TYPE VLV LATCH PORT DATE 9-5/8" BOWED CSG -I 2013' 3 3724 3699 23 NR03 DOME RK 16 06/16/09 PATCH, 47 #, L -80 BTC 2 7331 6201 49 MMG SO RK 20 06/16/09 D = 8.681" 1 9512 7687 44 MMG DM'( RK 0 06/12/09 113-3/8' CSG, 72 #, L -80 MRS, 13= 12.347" IH 2684' I 1 9593' H4-1/2" FES X NP, D = 3.813" 9624' I-- 14 - 1/2" XO 5 -1/2", D = 3.910" Minimum ID = 2.37" a@ 9949' 0 9626' H 9 -5/8" x 5-1/2" BKR S-3 FKR, D= 4.760" 2 -7/8" LINER TOP ... 9632' -I -1/2" X04 -1/2", D= 3.880" ( 9654' -14 -112" FES X NP, D = 3.813" 4-1/2" TBG, 12.6#,13CR =80 VAM TOP, H 9736' I 0152 bpf, D = 3.958' I 9741' -I UNQUE OVERSHOT 14-1/2" TBG STUB (06/09/09) H 9742' . ( 9788' - I4 -1/2" I-ES X NP, D =3.813" ► ∎i I 9798' H9 -5/8" X 4-1/2" BKR S-3 FKR, D = 3.875" (2001) 9832' H4-1/2" FE5 X NP, ID= 3.813" 4-1/2" TBG, 12.6 #,13CR80 MCI, - 9852' ' 9820' -TOP OF 4-12' TBG STUB (11/30/00) .0152 bpf, D= 3.958" 9851' H4 -1/2" IES X NP D = 3.813" I 9859' H CUSTOM tN'IQUE OVERSHOT (2001) I Qi 9862' - 19 -5/8" X 4-12" 11W ACR, D= 3.875" (1996) IN 9899' H4 -112" I-ES X NP, D = 3.813" II 9906' I ITOPOF 4-1/2" TBG STUB (11/26/96) I (4-12" TBG, 12.6#, L -80, .0152 bpf, Et= 3.958" H 9910' _ 9917' -I UNIQUE CUSTOM OVERSHOT (1996) QI (TOP OF 7" LN2 -1 9933' I ( 9909' H 9 -518" TIN PKR (1989) I 9949' (H DEPLOYMENT SLEEVE (2- 718" LNR) I 1412" TBG, 12.6#, L -80, .0152 bpf, ID= 3.958" H 9994' I 9961' H4 -1/2" OTIS X NF; ID= 3.813" ( WIND PIPE (9 -5/8" CSG, 4 7 # L -80, BTRS, D = 8.681" -1 10460' ( 9982' - 1412" OTIS XN I V ? D = 3.725" ( BEHIND PIPE) I I TOP OF WHPSTOCK (H 11150' I 9995• - 412" OTIS TBG TAL, D = 3.820" ( BERND PIPE PERFORATION SUMMARY 10001' H Emu TT LOG ON XX/XX/XX REF LOG: ADS DLIGR ON 06/28/00 ANGLE AT TOP FERF: 55° © 11290' ""-'- Note: Refer to Production 08 for historical pert data 12238' FISH: 2 -7/8" FES CUP SIZE SPF NTERVAL Opn/Sgz DATE ` MLLED & PUSHED TO BIM 2" 6 11290 - 11300 0 ??? ",,,,_____k (11/02/12) 2" 6 11414 -11440 0 02/06105 tttttttt 2" 6 11550 - 11652 0 06/30/00 1111114' 11111111 ` 2" 6 11750 - 12050 0 06/30/00 11111111 ♦ 111111 ••••••• 2" 4 12100 - 12190 0 06/30/00 11111111 ♦111111 , I PBTD (- ( 12254• 2" 4 12225 - 12249 0 06/30/00 11111114 1 •i • • • 4 i:•' ` 17" LM , 29#, L -80, D = 6.184" (H 11576' * 2 -7/8" LN2, 6.16#, L -80 STL, .0058 bpf, D = 2.441" (H 12294' DATE REV BY CONSENTS DATE REV BY C)t.4U1TS PRA OE BAY UNIT 06/1080 ORIGINAL COMPLETION 06/17/09 TFA/SV GLV (70 WELL: D-13A 04/1789 RWO 06/24/09 HB/JMD DWG DRAFT CORRECTIONS (07/10/05 PERMIT No: " 12/05/96 RWO 06/27/09 MCZTTLH JCJSLUGGITS/PLUG PULLED AR No: 50- 029 - 20449 -01 06/30/00 CTD SIDETRACK (D -13A) 05/01 /10 JGF /PJC OBR PERFS (04/XX/10) SEC 23, T11N, R13E, 2460' FSL & 1067' FEL 01116/01 RWO 11/06/12 RM-VJMD MLLE) CUP (11/02/12) 06/12/09 N4ES RWO BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 March 06, 2011,Fr k °4 7 Mr. Tom Maunder 1 Alaska Oil and Gas Conservation Commission Y 3 'a A 4 1100 333 West 7 Avenue Anchorage, Alaska 99501 tihska Oil & Cs Cons. Cu ob ssiion Subject: Corrosion Inhibitor Treatments of GPB D Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D 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, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator i BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Seala Top-off Report of Sundry Operations (10 -404) Date: 03 /04/11 Corrosion . Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbls ft na gal D -01A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 D -05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 D -10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 D -11B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 0-12 1800150 50029204430000 NA 1.3 . NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 • D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 0-17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -19B 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 D -20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 D -21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 D -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 D -24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 D -27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 D -29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D-31A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 0-33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 Schtumh~rger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2938 ATTN: Beth Well Job # 06/08/10 NO. 5538 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Sufte 100 Anchorage, AK 99501 Log Description - - Date BL Color CD E-05B V-220 E-09C D-13A 09-44A 09-44AP81 17-12A BD86-00015 BCUE-00019 AXED-00062 BBUO-00008 10AKA0043 10AKA0043 09AKA0079 MEM PROD PROFILE MEM INJECTION PROFI E MCNL - RST OH MW WD EDR OH MWD/LWD EDIT - OH MWD/LWD EDIT ~ .05/20/10 05/16/10 11!20/09 03/09/10 03/09/10 03/06/10 03/10/10 1 1 1 1 1 2 2 1 1 1 1 1 1 1 PLEASE ACKNOWLEDGE REC EIPT RV RIGNIN (: Bran race rcrmun nrue rno.. ~...., T... BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~Nri~~rP~~S~c; STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS APR ~ 8 2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations (,r timulate^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ ~YWaiver^ Time Extension ^ ~~ Change Approved Program ^ Operat. Shutdown^ Perforate ^ // ti~~~te-ent Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^~ Exploratory ^ 200-0810 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-20449-01-00 8. Property Designation (Lease Number) : 9. Well Name and Numbe~ ADLO-028285 PBU D-13A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12290 feet Plugs (measured) 11350' 4/20/10 feet true vertical 9056.76 feet Junk (measured) None feet Effective Depth measured 12251 feet Packer (measured) 9626 9798 9862 9909 true vertical 9040 feet (true vertical) 7768 7891 7937 7971 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2684 13-3/8" 72# L-80 SURFACE - 2684 SURFACE - 2684 4930 2670 Intermediate 10461 9-5/8" 47# L-80 SURFACE - 10461 SURFACE - 8347 6870 4760 Production Liner 1220 7" 29# L-80 9933 - 11153 7989 - 8865 8160 7020 Liner 2345 2-7/8" 6.16# L-80 9949 - 12294 8000 - 9059 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 21 - 9861 21 - 7937 4-1/2" 12.6# L-80 9859 - 9995 7935 - 8033 Packers and SSSV (type, measured and true vertical depth) 9-5/8"X5-1/2" BKR S-3 PKR 9626 7768 9-5/8"X4-1/2" BKR S-3 PKR ...,_,-. __.. - 9798 7891 9-5/8"X4-1/2" TIW PKR 9862 7937 9-5/8"X4-1/2" TIW PKR 9909 8033 12. Stimulation or cement squeeze summary: Intervals treated (measured): } ~ ~k y ~ V E `~ 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: 307 16436 0 2178 Subsequent to operation: 758 41090 0 1021 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ SPLUG ^ 17. I hereby certity that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature Phone 564-4944 Date 4/28/2010 RBDMS APR 2 8 20'~ yz~~° yz~/o D-13A 200-081 DGR~ ATTA('_NMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base D-13A 7/1/00 PER 11,550. 11,650. 9,018.67 9,014.12 D-13A 7/1/00 PER 11,750. 12,050. 9,014.65 9,011.67 D-13A 7/1100 PER 12,100. 12,190. 9,008.71 9,016.11 D-13A 7/1/00 PER 12,225. 12,249. 9,028.29 9,038.67 D-13A 2/6/05 APF 11,414. 11,440. 9,010.4 9,017.1 D-13A 5/1/09 BPS 9,832. 9,835. 7,915.7 7,917.86 D-13A 5/2/09 SPS 9,805. 9,832. 7,896.3 7,915.7 D-13A 6/26/09 BPP 9,832. 9,835. 7,915.7 7,917.86 D-13A 4/20/10 APF o/ 11,290. 11,300. 8,958.11 8,963.55 D-13A 4/20/10 BPS 11,350. 12,249. 8,987.43 9,038.67 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 • C~ D-13A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 'r'ACTIVITYDATE SUMMARY 4/20/2010"""WELL SHUT IN UPON ARRIVAL*** INITIAL T/IA = 2330/1300. E RUN 1: RIH TO DEVIATION AND LOG JEWELRY FROM 10450' TO 9390'. TIED INTO RST-SIGMA LOG DATED 9-MAR-2010. RUN 2: SET HALLIBURTON 2-7/8" CIBP AT 11350' -TIED WTO JEWELRY LOG 'FROM RUN 1. RUN 3: PERFORATE 11290'-11300' WITH 2.00" POWER JET 2006 HMX ;LOADED 6 SPF/60 DEG PHASED. TIED INTO RST LOG DATED 9-MAR-2010. ""*CONTINUED ON 21-APR-2010"*" 4/21 /2010 ***JOB CONTINUED FROM 20-APR-2010**" RIG DOWN E-LINE. PAD OPERATOR NOTIFIED OF FINAL VALVE POSITIONS: MASTER:OPEN, WING/SSV/SWAB:CLOSED, IA:OTG. FINAL T/IA: 2300/1300. """JOB COMPLETED, WELL LEFT SHUT-IN**" FLUIDS PUMPED BBLS 1 60/40 METH 1 DIESEL 2 Total TREE _, CM/ WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 71.61' BF. ELEV = 47.91' 13-318" SURFACE CSG CUT KOP = 3200' OFF & NEW 9-5/8" Max Angle = 94° @ 11559' WEI-LHEAD INSTALLED Datum MD = 11161' Datum TVD = 8800' SS 9-518" BOWEN CSG 2013' PATCH, 47#, L-80 BTC ID = 8.681" 13-318" CSG, 72#, L-80 BTRS, ID = 12.347" 2684' Minimum ID = 2.37" @ 9949' 2-7/$" LINER TOP 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, I- j 8736, .0152 bpf, ID = 3.958" 4-112" TBG STUB (06109/09) 9742' 4-1/2" TBG, 12.6#, 13CR80 NSCT, .0152 bpf, ID = 3.958" 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.95$" ~ 9910' TOP OF 7" LNR 9933' (4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" (-i g994' 9-5/8" CSG, 47# L-80, BTRS, ID = 8.681" 10460' TOP OF WHIPSTOCK 11150' PERFORATION SUMMARY REF LOG: PDS DIL/GR ON 06128!00 ANGLE AT TOP PERF: 73° @ 11414' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11414 - 11440 O 02/06/05 2" 4 11550 - 11652 O 06/30/00 2" 4 11750 - 12050 O 06/30(00 2" 4 12100 - 12190 O 06!30(00 2" 4 12225 - 12249 O 06!30/00 7" LNR, 29#, L-80, ID = 6.184" I-I 11576' D ~~ ~~ S 4F 2Y C METBGANGLE>70°@ 11408' 1974' 9-5i8" HES ES CEMENTER 1991' 9-518" BKR ECP, ID = 8.70" 2012' 4-112" HES X NIP, ID = 3.813" ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3724 3699 23 MMG DOME RK 16 06/16/09 2 7331 6201 49 MMG SO RK 20 06/16/09 1 9512 7687 44 MMG DMY RK 0 06/12/09 9593' -j 4-1 /2" HES X NIP, ID = 3.813" 9624' 4-1/2" XO 5-1/2", ID = 3.910" 9626' 9-5/8" X 5-112" BKR S-3 PKR, ID = 4.760" 9632' 5-1 /2" XO 4-1 /2", ID = 3.880"1 8654' 4-112" HES X NIP, ID = 3.813" 9741' UNK~UEOVERSHOT 9788' 4-112" HES X NIP, ID = 3.813" 9798' 9-5/8" X 4-1 /2" BKR S-3 PKR, ID = 3.875" (2001 } 9$32' 4-1/2" HES X NIP, ID = 3.813" g$20' TOP OF4-1/2" TBG STUB (11/30100) 9851' 4-1/2" HES X NIP, ID = 3.813" 9$59' CUSTOM UNIQUE OVERSHOT (2001) 9862' 9-5/8" X 4-1/2" TM/ PKR, ID = 3.875" (1996) g$gg' 4-1/2" HES X NIP, ID = 3.813"~ 9906' TOP OF 4-1/2" TBG STUB (11/26196) 9917' UNIQUE CUSTOM OVERSHOT (1996) 9909' 9-5/8" TMJ PKR (1989} 9949' DEPLOYMENTSLEEVE(2-718"LNR) 9961 4-1/2" OTIS X NIP, ID = 3.813" (BEHIND PIPE) gggg' I-14-112" OTIS XN NIP, ID = 3.725" (BEHIND PI 9995' J-j4-1/2" OTIS TBG TAIL, ID = 3.820" (BEHIND PIPET 10001' ELMD TT LOG DATE NOT AVAILABLE ~I~,P~,1~,3Sb PBTDI-I 12254' 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" I-I 12294' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 06110/80 ORIGINAL COMPLETION 06!17109 TFA/SV GLV C/O WELL: D-13A 04h7t89 RWO 06/24/09 HB/JMD DRLG DRAFT CORRECTIONS (0 711 /09) PERMfT No:2000810 12/05/96 RWO 06/27/09 MCZ/TLH JC/SLUGGffS/PLUG PULLED API No: 50-029-20449-01 06130100 CTD SIDETRACK (D-13A) SEC 23, T11 N, R13E, 2460' FSL & 1067 FEL 01/16101 RWO 08/12!09 N4ES RWO BP Exploration (Alaska) STATE OF ALASKA A OIL AND GAS CONSERVATION CO SION REP T OF SUNDRY WELL OPE~TIONS .~C~J~~' ~/D~9 1. Operations Performed: ^ Abandon ~ Repair Well , ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ~ Alter Casing ~ ~ Pull Tubing - ^ PerForate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time E~ension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~~ Development ^ Exploratory 200-081 ~ 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20449-07-00 - 7. KB Elevation (ft): ~~ 6~, 9. Well Name and Number: PBU D-13A " 8. Property Designation: 10. Field / Pool(s): ADL 028285 & 028305 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 12294' ~ feet true vertical 9059' ~ feet Plugs (measured) None Effective depth: measured 12251' feet Junk (measured) None true vertical 9040' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' SurFace 2684' 13-3/8" 2684' 2684' 4930 2670 Intermediate 10461' 9-5/8" 10461' 8347' 6870 4760 Production Liner 1220' 7" 9933' - 11153' 7989' - 8865' 8160 7020 Liner 2345' 2-7/8" 9949' - 12294' 8000' - 9059' 13450 13890 '~`"A~~~`~~~' ~~~ '~ ~ 2~ '~ Perforation Depth MD (ft): 11414' - 12249' ` - Perforation Depth TVD (ft): 9010' - 9039' 4-1/2", 12.6# 13Cr80 / L-80 9995' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): ~2~ 9"5/8" x 4-1/2" Baker S-3' packers; 9626', 9798'; and (2) 9-5/8" x 4-1/2" TIW paclters; and 9862', 9909' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut & pull tubing from 9741'. Cut, pull & dress 9-5/8" casing to 2021'. Mill out collapsed 13-3/8" casing at wellhead to fluted hanger. Run 9-5/8" tieback to 2013'. Cement w/ 145 Bbls Class 'G'. Run 4-1/2" 12.6#, 13Cr80 com letion to 9741'. 13. Re resentative Dail Avera e Production or In~ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram -~ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Hank Baca, 564-5444 309-156 Printed Name Terrie Hubble Title Drilling Technologist ~, J~~y _n Prepared By Name/Number: Signature Phone 564-4628 Date~~ ~~ M ~+ 0 Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 Submit Original Only ~~~~ Ik~~ JUI. ~ ~ 1009 ~1~'y ~ ~ D-13A, Well History (Pre Rig Workover) Date Summary 4/24/2009 T/I/0=0/400/0 CMIT TxIA PASSED to 3500 psi. (FiWO Prep) Pumped into the IA with 13 bbls crude to reach test pressure for CMIT TxIA. T/IA lost 100/50 psi in the 1 st 15 mins and 40/10 psi in the 2nd 15 mins for a total pressure loss of 140/60 psi in 30 min test. Durinq load and test fluid was cominq up into flutes. Vac truck vacced out flutes every 10 seconds. Vac truck put on constant vac. Bled pressures back to normal. Bled back 10 bbls. Pad Op notified of tree valve positions as follows: SV, WV, SSV = closed. Master open. IA and OA open to gauges. Also notified of job results. Final WHP's = 40/340/0. No visible fluids in conductor flutes at time of departure, 4/27/2009 T/I/O=SSV/300/50, Temp=Si. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (2000 psi), bled to 0 psi. Functioned LDS (ET style), all moved freely (.75"). Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test. lost 0 psi in 30 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (100 psi), bled to 0 psi. Functioned LDS (standard style), one pin stuck (flagged), all the rest moved freely (3"). Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 0 psi in 30 min (PASS). Bled void to 0 psi. 4/29/2009 T/I/0=50/320/0. Temp=Sl. Bleed WHP's to 0 psi. (Pre-RWO). IA FL C~ 39' (2.1 bbl). Bled TP from 50 psi to 0 psi in 15 minutes, all fluid. Bled IAP from 320 psi to 130 psi in 3 hours, Fluid to surface. Monitor during rig down for shift change. TP increased to 37 psi in 3 hours. IAP increased 10 psi to 140 psi in 30 minutes. Final WHP's=37/140/0. SV, WV & SSV = CLOSED. MV = OPEN. IA & OA = OTG. NOVP. 4/30/2009 T/I/0=52/150/0. Temp=Sl. Bleed WHP's to 0 psi. (Pre-RWO). Cellar has sprav in liner, was dry last niqht but now has 18.5" of water in it. TBG FL Q Surface. IA FL C~3 30' (1.6 bbl). Bled IAP from 150 psi to 20 psi in 6 hours, Fluid to surface. Bled TP from 52 psi to 0 psi in 30 minutes. Monitor for 30 minutes during rig down. TP increased 3 psi during monitor. IAP increased 15 psi to 35 psi in 30 minutes. Final WHP's = 3/35/0. SV, WV & SSV = CLOSED. MV = OPEN. IA & OA = OTG. NOVP. 5/1/2009 Attempted to free up stuck LDS. RU 1 HP BT onto IC test void 0 psi in void. Broke flats off pin, attempted to break pin free with pipe wrench unable to move pin. Called WIC informed of situation, will drill I nS_ ' 5/1/2009 T/1/0 = 57/35/0+. Temp = SI. Assist Cameron with open bleed. LDS sheared off. Cameron left location, will need to return to drill out LDS. rellar ic f~~ll of fl~id (snowmPlt frmm ~ad rlraining intn=Pllarl,. TP increased 54 psi overnight. TBG FL C«~ surface. IA FL near surface. Bled IAP from 35 psi to 0+ psi in 1 hr 30 min. Bled TBG from 57 psi to 0 psi in 5 min. SI and monitor for 30 min. TP increased 19 psi, IAP increased 7 psi. FWHPs = 19/7/0+. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 5/1/2009 WELL S/I ON ARRIVAL. DUMP BAILED 2- 50# BAGS OF SLUGGITS ON TOP OF 4-1/2" PX PLUG Q 9,832~MD. CURRENTLY IH C~ 9,791' SLM SETTING 4-1/2" JUNK CATCHER. 5/2/2009 WELL SHUT-IN ON ARRIVAL, SSV OPEN, INITIAL T/I/O = 350/50/50. CUT TBG AT 9748', SURFACE AND VISUAL CONFIRMATION OF CUTTER FIRING. FINAL T/I/O = 350/50/50 PSI. NOTIFIED DSO OF ALL VALVE POSITIONS. JOB COMPLETE. 5/2/2009 SET 4-1/2" JUNK CATCHER (114" oal, 3.76" max od, 2.992" id) Q 9,791' SLM. NOTE: JUNK CATCHER USED AS JET CUTTER DRIFT (target 9300') PER WELLS GROUP. WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS. Page 1 of 2 . • D-13A, Well History (Pre Rig Workover) Date Summary 5/4/2009 T/I/0= 200/80/40, temp= S/I. Circ OuU CMIT Tx IA PASS ( RWO prep). Vac truck sucked 34 bbls fluid out of cellar on arrival. Circ out .Pumped 10 bbls 40° methanol, 1065 bbfs 110° seawater and i40 bbls diesel down tubing taking returns up IA through the jumper line to D-14's flowline. Vac truck on constant vac, leaking approximently .5 bbl every 10 minutes during initial pumping. U-Tube Tx IA to freeze protect. CMIT Tx IA 1000 psi. Pumped 2.2 bbis diesel down tubing to reach test pressure 1000/1000, 3.4 bbls total- 3 rd test T/IA lost 40/40 psi in 1st 15 min's. 0/0 psi in 2nd 15 min's. for a total loss of 40/40 psi in 30 min test. Freeze protect D-14 flowline. Pumped 7 bbls neat meth, 100 bbis crude to freeze protect Swab, Wing, closed; SSV, Master, IA, OA, valves open. All valves on jumper line closed on departure. FWHP's= 0/0/0 5/5/2009 T/I/O = VACNAC/0. Temp = SI. W HPs, IA & OA FLs (pre-LDS Drillout). No AL. IA FL near surface, OA FL near surface. SV, WV = Shut. SSV, MV = Open. IA & OA = OTG. NOVP. 5/5/2009 Arrived on location inspect equipment. PJSM, assisted in installing bleed hoses. Installed HPBT on 9- 5/8" casing hanger void. Void had 0 psi. Removed gland nut from broken lock down pin and cut broke pin off w/ wellhead. Function test WACHS drill base plate. Load tools and return to well service to inspect all tolling and prep for LDS drillout. 5/5/2009 T/I/O=VacNac/0. Temp-Sl. Assist WH Tech w/LDS drillout (pre-RWO). No AL. IA & OA FL's near surface. Purged IA w/N2, then maintained open bleeds on IA & OA during LDS repair procedure. Final T/I/O=Vac/0/0. SV, W = . , _ . , _ . . 5/6/2009 T/I/0= ONAC/0. Temp= SI. Assist W H tech w/ LDS drillout. No AL. IA FL C~ near surface. OA FL C~ near surface. Maintained open bleed on IA & OA while assisting Cameron. Cameron replace broken LDS w/ blank, and performed PPPOT. PPPOT passed. SI, monitored for 30 mins. W HPs unchanged. FWHPs= ONAC/0. SV, WV, MV = C. SSV = O. IA, OA = OTG. NOVP. 5/6/2009 T/I/0= 0/0/0 Arrived on location. Had prejob safety meeting. Stabbed into test void and verified 0 p.s.i. Maintained open bleed. Removed gland nut and installed WACHS drill. Drilled out remainin~c lockdown screw on 9 5/8 casing hanger. Cleaned threads and installed blank lockdown screw. Pressure tested to 3,800 p.s.i. for 30 min. PPPOT-IC (PASSED). JOB COMPLETE. 5/6/2009 T/I/0= ONAC/0. Temp= SI. Assist VAC truck w/ removing cellar fluids. 4" fluid in cellar. Removed 3 bbls fluid, fluid is reentering cellar. MV closed, notified DSO. SV, WV, MV = C. SSV - O. IA, AO = OTG. NOVP. Rig up crew has control of valves. 5/8/2009 T/I/0=0/0/0 Set 6" CIW BPV #403, 1-2' Ext Used, Tag ~ 106"; Pre-Rig, Nabors 4ES. Page 2 of 2 ~ • BP AMOCO Page 1; of 9 ' Uperations Summary Report 'Legal Well Name: D-13 Common Well Name: D-13 Spud Date: Event Name: WORKOVER Start: 5/5/2009 End: Contractor Name: NABORS ALASKA DRILLING i Rig Release: 6/12/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Descrip#ion of Operations 5/31/2009 23;30 - 00:00 0.50 MOB P PRE RDMO J-20 and MIRU on D-13. 6/1/2009 00:00 - 03:00 3.00 MOB P PRE Move from J-20 to D-13. 03:00 - 04:30 1.50 MOB P PRE Spot sub, pits, and pipe shed. Raise and scope derrick. 04:30 - 07:00 2.50 MOB P PRE Rig up tiger tank and well cellar. Prepare to take 8.5-ppg seawater to pits for killing well. 07:00 - 08:30 1.50 KILL P DECOMP **ACCEPT RIG AT 0700 HRS`* Take on 8.5-ppg seawater to pits and rig up circulating lines to tree and tiger tank. 08:30 - 09:00 0.50 KILL P DECOMP Ri u and ressure check DSM lubricator to 500- si and then ull BPV. 09:00 - 09:30 0.50 KILL P DECOMP PJSM for killing well. 09:30 - 12:00 2.50 KILL P DECOMP SITP = 0- si SICP = 0- si OAP = 0- si. Circulate out diesel freeze protect and ensure well is dead. Monitored OA pressure while circulating. Pump 671-bbls of 8.5-ppg seawater at 5.5-BPM and 680-psi. 12:00 - 13:00 1.00 WHSUR DECOMP FMC wellhead tech. d rod set 6" "J" lu TWC 7 turns). P/T TWC from below to 1000-psi for 10-charted minutes. from above. 12:00 - 14:00 2.00 WHSUR P DECOMP ND tree. Inspect top hanger threads - O.K. Made up 7" NSCC XO into hanger 8 turns. Found control line plugs in hanger bubbling (probable cause of TWCleaking). Also removed needle valves from DHCV ports and plugged same off. 14:00 - 16:00 2.00 BOPSU P DECOMP NU BOP. 16:00 - 00:00 8.00 BOPSU P DECOMP Swap out 13-5/8" 5M GX Hydril annular preventer for 13-5/8" 5M GK Hydril annular preventer. 6/2/2009 00:00 - 05:00 5.00 BOPSU P DECOMP Con't to N/U GK annular preventer on existing stack. Lower GK on stack & M/U bolts w/ Sweeny wrench. P/U & set back stack Install Test Spool. Set stack on Test Spool & N/U same. N/U Choke & Kill Lines. R/U riser. 05:00 - 06:00 1.00 BOPSU P DECOMP R/U test equip. Function test equip. Pretest new annular. Odered out 236-bbl. open top tank from well support foreman. 06:00 - 13:30 7.50 BOPSU P DECOMP Test BOPE per BP/AOGCC requirements: 250-psi Lo/3500-psi Hi. Tested 3-1/2" x 6" VBR's with 3-1 2" and 4-1/2" test jts. Tested annular preventer with 3-1/2" test jt. Tested choke manifold, kill and choke HCR's, blind rams, test spool, floor safety valve, DP dart valve and uper and low kelly valves. Performed Koomey test per requirements. Rig down test equipment. 13:30 - 14:00 0.50 PULL P DECOMP MU 3-1/2" DP landing jt. with closed TIW valve and 3-1/2" DP x 7" NSCC XO. Screw into tubing hanger 8 turns. FMC wellhead tech. BOLDS. 14:00 - 14:30 0.50 PULL P DECOMP Unland tubinq hanger with 105K upweight. Hoisted tubing hanger to floor. Broke out and layed down tubing hanger, 2' and 4' 4-1/2" 12.6#, 13Cr80 VAM pups. 14:30 - 17:00 2.50 PULL P DECOMP Hook uq cement line with TIW valve and headpin to tubinq. Circulated bottoms u. 6 b m at 290 psi. 17:00 - 18:00 1.00 PULL P DECOMP UD 4-1/2", 12.6#, 13Cr80, Vam compietion. 18:00 - 18:30 0.50 PULL P DECOMP Crew change, service rig, inspect derrick, set and test PVT's. 18:30 - 00:00 5.50 PULL P DECOMP UD 4-1/2", 12.6#, 13Cr80, Vam completion. Tubing is in good condition. 6/3/2009 00:00 - 02:00 2.00 PULL P DECOMP UD 4-1/2", 12.6#, 13Cr80, Vam completion. Tubing is in good condition. Laid down 249 joints of tubing and 12.40' cut joint of tu ing. oo cut, cut was belled out to 4.84" OD. All tubing Printed: 6/22/2009 2:10:21 PM ~ ~ Operations ~umr~ Legal Well Name: D-13 Common Well Name: D-13 Spud Date: Event Name: WORKOVER Start: 5/5/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/12/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Haurs Task Code NPT Phase Description of Operations 6/3/2009 00:00 - 02:00 2.00 PULL P DECOMP and completion jewelry failed NORM testing and will be hauled to NORM ard. "~ 02:00 - 03:00 1.00 PULL P DECOMP Rig down tubing handling equipment. R/U handling equipment for drill pipe. 03:00 - 03:30 0.50 PULL P DECOMP Clear and clean rig floor. 03:30 - 04:00 0.50 PULL P DECOMP M/U 9-5/8" Casin scra er assembl with 8-1/2" bit. 04:00 - 06:00 2.00 PULL P DECOMP RIH with Casing scraper assembly picking up 3-1/2" 15.5# IF drill pipe. 06:00 - 06:30 0.50 PULL P DECOMP Crew change. PTSM. Service rig, check PVT's, daily derrick inspection & enviro walkaround. 06:30 - 08:00 1.50 PULL P DECOMP RIH w/9-5/8" scra er to 3 000'. 08:00 - 09:00 1.00 PULL P DECOMP Rig up to circulate bottoms up. Circulated bottoms up at - - si. Rig down circulating lines. 09:00 - 10:30 1.50 PULL P DECOMP POH UD 9-5/8" scraper and 8-1/2" bit BHA. 10:30 - 11:00 0.50 PULL P DECOMP Clear and clean rig floor. 11:00 - 12:00 1.00 EVAL P DECOMP Prepare to run USIT log. MIRU SWS E-line. 12:00 - 14:30 2.50 EVAL P DECOMP RIH w/USIT lo in tools. Lo 3,000' to surface in cement corrosion mode. Identif TOC at 2,068'. Uphole casing collars are at 2,030' and 1,992'. Agree cut depth at 2,011' with RWO Engineer. 14:30 - 15:30 1.00 EVAL P DECOMP RDMO SWS E-line eqpt. and tools. Release SWS e-line at 16:00-hrs. 15:30 - 16:00 0.50 DHB P DECOMP PJSM - Review RBP running procedure. PUMU 9-5/8" Halco RBP and running tool. 16:00 - 18:00 2.00 DHB P DECOMP RIH with 9-5/8" Halco RBP on 3-1/2" DP from derrick. Set RBP COE at 2,111'. Stay latched to RBP with running tool for pressure test. Pressure test RBP to 3,500-psi for 10-charted miinutes. Release running tool from RBP. 18:00 - 18:30 0.50 DHB P DECOMP Crew Change, service rig, inspect derrick, set and test PVT's. 18:30 - 21:30 3.00 DHB P DECOMP Release from 9-5/8" RBP and stand back 1 stand ot drillpipe. Dump 2,200# of 20/40 river sand down drilipipe and let settle. Flush drillpipe. P/U stand of drillpipe and tag top of sand at 21:30 - 23:00 1.50 CLEAN P 23:00 - 00:00 1.00 CLEAN P 6/4/2009 00:00 - 01:00 1.00 CLEAN P 01:00 - 02:30 1.50 CLEAN P 02:30 - 03:30 1.00 CLEAN P 03:30 - 04:30 ~ 1.00 ~ CLEAN ~ P 04:30 - 06:00 I 1.50I CLEAN ~ P 06:00 - 07:30 I 1.501 CLEAN I P DECOMP I Disolace well from seawater to 9.8 ppa brine. 5 bpm at 140 psi DECOMP ~ POOH standing back 3-1/2" drillpipe and laying down HES running tool. DECOMP M/U Baker Multi String Cutter DECOMP RIH with casing cutter on 3-1/2" driilpipe from derrick. DECOMP M/U Kelly and establish parameters, P/U 43K, S/O 43K, Rotating Weight 43K, 45 RPM at 1,200 Wlbs torque. 6 bpm with 900 psi. Locate casing collars. Tagged - 7 deep at 1,999' and 2,039'. Space out to cut 9-5/8" casing at 2,019'. DECOMP Cut 9-5/8" casin at 2 019'. 60 rpm wit 3 s o torque, 5-1/2 bpm with 780 psi. Cut through casing rotary torqued up and stalled out. Had returns to cellar from 9-5/8" x 13-3/8" annulus throu h fluted han er on the 13-3/8" casin . DECOMP Line up and pump 130 bbls of 120 degree diesel onto the 9-5/8" x 13-3/8" annulus with Little Red 1.5 bpm with 900 psi, returns coming up in the cellar through the fluted hanqer. Arctic Pack returns are thick with some dead crude. DECOMP Circulate diesel DP x O/A at 2.0-bpm at 500-psi taking 90% returns into cellar and 10% into open top tank. S/D pumping, RDMO LRS. Pumped 13-bbls. Safe-Surf-O to clear diesel from Printed: 6/22/2009 2:10:21 PM . • ' BP AM(~~O Page 3 of 9 Operations Summary Repart Legal Well Name: D-13 Common Well Name: D-13 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES Date From - To Hours Task Code NPT 6/4/2009 06:00 - 07:30 1.50 CLEAN P 07:30 - 08:30 1.00 CLEAN P 08:30 - 09:30 1.00 CLEAN P 09:30 - 10:30 1.00 CLEAN P 10:30 - 11;30 1.00 CLEAN P 11:30 - 12:30 1.00 CLEAN P 12:30 - 15:00 2.50 CLEAN P 15:00 - 16:00 1.00 CLEAN P 16:00 - 18:00 I 2.00 ~ CLEAN I P 18:00 - 18:30 0.50 CLEAN P 18:30 - 00:00 5.50 CLEAN P Spud Date: Start: 5/5/2009 End: I Rig Release: 6/12/2009 Rig Number: P'hase Deseription of Operations DECOMP DP. DECOMP Let diesel soak in O/A for 1 hour. DECOMP Pump remaining 27-Bbis. Safe-Surf-O and f51-Bbls. 9.8-ppg brine at 5.5-bpm at -1500-psi taking 90% of return volume into cellar and 10% of returns into o~en too tank. Returns cleaned up at -120-Bbls. 9.8-ppg brine pumped. DECOMP Rig down circulating lines, break out TIW valve and prepare to POH w/Baker Multi-String casing cutter BHA. DECOMP Safety standdown. Discuss Nabors "Safety Culture" with day rig crew. DECOMP POH UD Baker Mult-String casing cutter BHA. DECOMP Rig up floor with 9-5/8" casing handling tools and make up 9-5/8" ITCO spear w/packoff. DECOMP Engage 9-5/8" casing with spear. Back out lower lockdown screws. Unland 9-5/8" casing with 115K upweight. Hoist mandrel casing hanger and packoff to floor. Release and lay down spear. Break out and lay down mandrel hanger and packoff. DECOMP Hook up circulating lines, close annular preventer on 9-5/8" casing and pump 75-bbls. 9.8-ppg brine at 6.0-bpm at 250-psi takin returns to cellar and o en to tank. receovered substantial amount of arctic pack. Shut down pumping and open annular preventer. Work pipe for 10 minutes. Close annular preventer and reestablish circulation at 6.0-bpm at 250-psi and pump 50-bbls. and recover small amount of arctic pack. Break out and lay down ciculating lines and equipment. DECOMP Crew Change, service rig, inspect derrick, set and test PVT's. DECOMP UD 9-5/8", 47#, L-80, BTC casing. Casing was in good condition. Casing connections broke out rom t. s to 45K 6/5/2009 I 00:00 - 03:00 I 3.001 CLEAN I P 03:00 - 04:30 1.50 CLEAN P 04:30 - 06:00 1.50 CLEAN P 06:00 - 06:30 I 0.501 CLEAN I P 06:30 - 09:00 2.50 CLEAN P 09:00 - 10:00 1.00 CLEAN P DECOMP UD 9-5/8", 47#, L-80, BTC casing. Casing was in good condition. Recovered 52 joints and a 18.89' cut joint. There were no stop rings or centrilizers on pipe. Casing appeared DECOMP Clean Arctic Pack off equipment and clean rig floor. DECOMP Rig down casing handling equipment and rig up floor to P/U BHA. DECOMP PTSM - Crew change. Service rig, check PVT's, daily derrick inspection and enviro walkaround. DECOMP Rig up floor with 3-1/2" DP handling tools and continue cleaning residual arctic pack from floor and tools. DECOMP 13-3/8" casinq collar hanging on top of fluted casing hanger is inwards in flutes. PUMU 13-3/8" scraper and at' irouqh wellhead and top of 13-3/8" casinq. Casii would not pass throuqh casinp collar and on into 10:00 - 12:00 2.00 CLEAN P DECOMP PUMU 12-1/4" string mill BHA. 12:00 - 13:00 1.00 CLEAN P DECOMP Ta ti ht s ot at 27' with strinq mill. Establish parameters: P/U wt. = 25K, S/O wt. = 25K, 51-RPM. Intermittently circulating with charge pump taking returns to well cellar and open top tank. Mill out collapsed 13-3/8" casinq at wellhead. 13:00 - 14:30 1.50 CLEAN P DECOMP POH UD 12-1/4" string mill BHA. 14:30 - 15:30 1.00 CLEAN P DECOMP Clear and clean rig floor. Prinied: 6/22/2009 2:10:21 PM • ~ Legal Well Name: D-13 Common Well Name: D-13 Spud Date: Event Name: WORKOVER Start: 5/5/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/12/2009 Rig Name: NABORS 4ES Rig Number: ~ ~ ~ E ~ ~ , I 6/5/2009 I 15:30 - 16:30 I 1.00 I CLEAN I P 16:30 - 18:00 18:00 - 18:30 18:30 - 20:00 20:00 - 21:30 6/6/2009 21:30 - 00:00 00:00 - 00:30 00:30 - 01:30 01:30 - 03:00 03:00 - 04:00 04:00 - 06:00 1.50 CLEAN P 0.50 CLEAN P 1.50 CLEAN P 1.50 CLEAN P 2.50 C~EAN P 0.50 CLEAN P 1.00 CLEAN P 1.50 CLEAN P 1.00 CLEAN P 2.00 WHSUR P 06:00 - 06:30 0.50 WHSUR P 06:30 - 08:30 2.00 WHSUR P 08:30 - 10:30 2.00 CASE P 10:30 - 11:00 0.50 CASE P 11:00 - 12:00 1.00 CASE P 12:00 - 13:00 1.00 CASE P DECOMP PUMU BHA #4 as follows: 12-1/8" Dress-off Shoe, 11-3/4" W.P. Ext. 11-3/4" Boot Basket, 6-5/8" Double Pin Sub, 13-3/8" Scraper, Bit Sub, Float Sub, 6-1/4" LBS, XO, 6-1/4" Drill Collars '6,X0=218.10' DECOMP RIH w/BHA #4. Stop every fifth stand RIH and CBU. DECOMP Crew change, service rig, inspect derrick, set and test PVT's. DECOMP RIH w/BHA #4. Stop every fifth stand RIH and CBU. DECOMP M/U Kelly and establish paramenters. P/U 55K, S/O 53K, Rot wt 54K, 40 rpm with 2,600 fUlbs of torque, 4 bpm with 200 psi. Ta to of stub at 2,020', dress stub to 2,021', Cleaned out over stub to 2,029'. 70 rpm with 3,000 - 3,300 fUlbs of torque, 4 bpm with 240 psi, 2-5K WOM. Able to slide of stub without rotating or pumping. DECOMP Circulate 40 bbl Safe Surf pill at 4.5 bpm with 310 psi. Heavy Arctic Pack returns to surface. DECOMP Circulate 40 bbl Safe Surf pill at 4.5 bpm with 310 psi. Heavy Arctic Pack returns to surface. DECOMP POOH with 9-5/8" Dress Off Assembly, standing back 3-1/2" Drill pipe in derrick. DECOMP UD Dress Off Assembly, good indication on top dressing mill that casing stub was dressed. DECOMP Clear and clean rig floor. DECOMP Flush BOP stack, crib up welihead, N/D BOP stack. Barriers for nippling down BOP stack are tested PX plug at 9,832' and tested 9-5/8" RBP at 2,105' DECOMP PTSM - Crew change. Service rig, check PVT's, daily derrick inspection and enviro walkaround. DECOMP Finish ND and set back BOP stack. Remove tubing spool/casing head, 13-3/8" pup and top 13-3/8" casing collar in one piece from well cellar (13-3/8" casing parted at bottom of 13-3/8" casin collar landed on fluted han er . Wash and vac out well cellar with fluid from rig pits. TIEB1 Rig up floor with 9-5/8" integral joint casing running and handling tools. TIEB1 PJSM - review running integral joint casing and develop HACL with Nabors Casing crew and rig crew. Identified a few items with regards to the rig up on the floor that would be changed. TIE61 Changed rig up of floor per HACL. TIE61 PUMU 9-5/8" Bowen casinq patch, Baker 9-5/8" ECP, HES 9-5/8" ES cementer and 9-5/8" 47#, L-80 Hydril 523 x BTC BxP XO jt. Baker-Lok'd top and bottom connections of ES cementer. 13:00 - 18:00 5.00 CASE P TIEB1 Commence RIH ickin u 9-5/8" 47#, L-80 H dril 523 casin 1 x 1 from pipe shed.. Makeup Hydril 523 connections using torque turn equipment to 19,000 ft-Ibs. and using "Jet Lube Seal Guard" thread compound. Filled pipe on every fifth joint ran in hole. RIH w/ one centralizer and top and bottom stop rings perjoint. 5yts. RIH at 14:00-hrs. 12-jts. RIH at 15:00-hrs. 18-jts. R1H at 16:00-hrs. 18:00 - 18:30 0.50 CASE P TIEB1 Crew change, rig service, derrick inspection, set and test PVT's. 18:30 - 21:00 2.50 CASE P TIE61 Commence RIH picking up 9-5/8" 47#, L-80 Hydril 523 casing 1 x 1 from pipe shed.. Makeup Hydril 523 connections using Printed: 6/22/2009 2:10:21 PM • • ' B P AMC}~O Page 5 of 9' Qperations ~ummary R~port Legal Well Name: D-13 Common Well Name: D-13 Spud Date: Event Name: WORKOVER Start: 5/5/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/12/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/6/2009 18:30 - 21:00 2.50 CASE P TIEB1 torque turn equipment to 19,000 ft-Ibs. and using "Jet Lube 21:00 - 23:30 2.50 CASE P 23:30 - 00:00 0.50 CASE P I6/7/2009 I 00:00 - 00:30 I 0.50I CASE I P 00:30 - 02:30 2.00 CASE P 02:30 - 03:30 1.00 CASE P 03:30 - 04:30 I 1.001 CASE I P 04:30 - 06:00 1.50 CASE P 06:00 - 07:00 1.00 CASE P 07:00 - 09:00 2.00 CASE P 09:00 - 09:30 0.50 CASE P 09:30 - 12:30 3.00 CEMT P Seal Guard" thread compound. Filled pipe on every fifth joint ran in hole. RIH w/ one centralizer and top and bottom stop rings per joint. Run Hydril 563 x Hydril 523 XO joint, Run Hydril 563. Taqqed at 2,018', placed Casinp collar at Top cap on nductor. P/U 96K, S/O 97K. TIEB1 R/U to release Bowen 9-5/8" casinq patch off of casinq stub. TIE61 Release Bowen 9-5/8" casinq patch off of casinq stub by turninq tieback strinq to the riqht and easinq up on the tieback strin . TIEB1 Release Bowen 9-5/8" casing patch off of casing stub by turning tieback string to the right and easing up on the tieback string. TIEB1 POOH UD 9-5/8" Hydril pups, XO Joint and Joint #48. TIEB1 ~Run XO Joint, 19.75' and 9.75' Hydril 563 pups and Hydril 563 lan in 'oint. P/U 96K, S/O 97K. Saw patch slide overcasing stub. P/U and pull test to 250K. Good test. TIEB1 Test 9-5/8" Casin and Patch to 1 000 si for 10 charted minutes, good test. Walk pressure up to fill and set Baker ECP, ECP sheared at 1,650 si and bled to 1 350 si. Pressure u to 1,600 psi, took 5 strokes, pressure up to 2,000 psi for 10 minutes on the chart, good test. Bleed off pressure. Pressure up and shear open HES ES cementer, Sheared open at 2,900 si. TIEB1 Circulate around 130 dearee 9.8 poa brine until returns are 80 de rees. Takin returns to the cellar. TIEB1 Circulate around 130 degree 9.8 ppg.brine until returns are 80 degrees. Taking returns to the cellar. 07:00-hrs. Gave AOGCC 24 hr. notice of weekly BOPE test due on 6/8/2009. TIEB1 MIRU Schlumberger cementers (verified presense of high pressure pop-off in pump truck). Spot vac trucks. TIEB1 PJSM - Review cement pumping plan, identify hazards, assign tasks to individuals and assign task leaders. TIEB1 Cement 9-5(8" 47#, L-80 Hydril 523J563 casing as per program. Flood lines with 5-Bbls. fresh water. Pressure test lines 800-psi Lo/4500-psi Hi. Initial pressure test failed. Replaced 2" Halliburton plug valve and and 2" 5000-psi hose on rig floor. Attempted retest failed. Schlumberger troubleshoot pressure leaks in pump truck - took 1.5-hrs. to resolve leak issue. Initiated pressure test - 800-psi Lo/4500-psi. Good Test. Batch mix tub of cement and commence pumping 145-Bbls. 15.8-ppg Class "G" with Gas-Blok at 2-6 bpm at -250-psi. and taking returns into weil cellar er lan. Note: Cement field blend matches blend required in well plan. At 145-Bbls. cement away, shut down pumping and dropped HES wiper plug. Displaced cement with 5-Bbls. fresh water and 145-Bbls. 9.8-ppg brine. Bumped plug at 150-Bbls. displacement. Increased pressure to 2000-psi and held for 3-minutes. Bled off pressure and checked floats - O.K. Cement in place at 12:15-hrs. Cement yield = 1.16 ft3/sk. Recovered very little residual arctic pack during cement dis lacement. Will wait for cement to attain 500-psi compressive strength (13.0-hrs.) before cutting casing and Printed: 6/22/2009 2:10:21 PM • • BP AMOCO Page 6 of 9 Operations Summary Report Legal Well Name: D-13 Common Well Name: D-13 Spud Date: Event Name: WORKOVER Start: 5/5/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/12/2009 Rig Name: NABORS 4ES Rig Number: Date Frorn - To Hours Task Code NPT P'hase Description of Qperations 6/7/2009 09:30 - 12:30 3.00 CEMT P TIE61 installing Cameron slip-lock wellhead. 12:30 - 15:00 2.50 CEMT P TIE61 RDMO Schlumberger cementers and vac truck support. Cleared well cellar of all cement and arctic pack. Installed steel wedqe centralizers to centralize 9-5/8" casina in 13-3/fl" casin at surface. 15:00 - 21:00 6.00 CEMT P TIEB1 Wait on cement to attain 500-psi compressive strength. 21:00 - 22:00 1.00 CEMT P TIEB1 Hold weekly safety meeting with crew. Discussed BP HSE Basics, HSE stats from BP and Nabors. 22:00 - 00:00 2.00 CEMT P TIEB1 Wait on cement to attain 500-psi compressive strength. 6/8/2009 00:00 - 01:00 1.00 CEMT P TIEB1 Wait on cement to attain 500-psi compressive strength. 01:00 - 04:00 3.00 WHSUR P TIEB1 R/U Wach's cutter and cut 9-5/8" Casin in cellar. Space out to place side outlet center line at 12" above ground level as per procedure. Prep cut and casing to accept wellhead. Install Cameron Slip Lock Casing Head Assembly. Torque CAHN seal flange to 850 fUlbs, and test seal to 3,800 psi for 30 minutes.Torque Slip Lock Bolts to 1,200 fUlbs. 04:00 - 06:00 2.00 BOPSU P TIEB1 N/U BOPE. Gave AOGCC 2-hrs. notice of impending weekly BOPE test. State's right to witness test waived by Chuck Sheve and Lou Grimaldi. 06:00 - 08:30 2.50 BOPSU P TIEB1 Finish NU BOPE and rigging up test equipment. 08:30 - 16:00 7.50 BOPSU P TIEB1 Pressure test BOPE per BP/AOGCC requirements: 250-psi Lo/3500-psi Hi. Tested 3-1/2" x 6" VBR's with 3-1/2" and 4-1/2" test jts. Tested annular preventer with 3-1/2" test jt. Tested choke manifold, kill and choke HCR's, blind rams, test spool, floor safety valve, DP dart valve and uper and low kelly valves. Performed Koomey test per requirements. Rig down test equipment. 16:00 - 17:00 1.00 BOPSU P TIEB1 Weekly HSE meeting - Reviewed "Alaska HSE Basics" with all crew and had roundtable discussion. 17:00 - 18:00 1.00 BOPSU P TIEB1 Pull test plug and set wear ring with I.D. of 9.125" 18:00 - 18:30 0.50 DRILL P TIEB1 Crew change, rig service, derrick inspection, set and test PVT's 18:30 - 19:30 1.00 DRILL P TIEB1 M/U BHA #5, Drill Out Assembl , BHA is 8-1/2" bit, 7" boot basket, 7" boot basket, bit sub, 6-1/4" LBS, XO, (6) 6-1/4" DC's, XO, Circ Sub. Total BHA length = 205.93' 19:30 - 20:30 1.00 DRILL P TIEB1 RIH with BHA #5 on 3-1/2" drill pipe from derrick to 1,953'. 20:30 - 00:00 3.50 DRILL P TIEB1 M/U Kelly and establish parameters. P/U 53K, S/O 52K, Rot Wt 53K, 60 rpm with 1,800 fUlbs of torque, 4 bpm with 100 psi. Wash and rotate down through stringers. Tagged up on plug at 1 981'. Drill plup ,ES cementer and cement, Wash down to 2,050'. Dry drill on top of sand plug from 2,051' to 2,061'. 6/9/2009 00:00 - 01:00 1.00 DRILL P TIEB1 Pump 30 bbl Hi-Vis sweep aroun a- pm wi psi. Increase in cement and rubber returns when sweep was back to surface. 01:00 - 02:00 1.00 DRILL P TIEB1 POOH with Drill Out Assembly standing back 3-1/2" drill pipe in derrick. 02:00 - 03:00 1.00 DRILL P TIEB1 Standback 6-1/4" DC's, break out and UD Drill Out Assembly. Empty Junk Baskets, recovered 2 gallons of cement and pot metal. 03:00 - 04:00 1.00 CASE P TIEB1 Pressure test 9-5/8" Casing to 3,500 si for 30 charted ~ minutes. Good Test. 04:00 - 05:00 1.00 FISH P TIEB1 M/U BHA #6 RCJB Assembl . BHA is 7-7/8" RCJB, 7" Boot Basket, 7" Boot Basket, 9-5/8" Casing Scraper, XO, (6) 6-1/4" DC's, XO, Circ Sub. Total BHA ~ength = 215.33' Printed: 6/22/2009 2:10:21 PM • . ' BP , Operations ~ Legal Well Name: D-13 Common Well Name: D-13 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date From - To Hours Task Code NPT F 6/9/2009 05:00 - 06:00 1.00 FISH P TI 06:00 - 06:30 0.50 FISH P TI Spud Date: Start: 5/5/2009 End: Rig Release: 6/12/2009 Rig Number: ~se Description of Operatiorr~ 1 RIH with RCJB Assembly on 3-1/2" drill pipe from derrick. PTSM - Crew change. 1 Ta sand at 2061'. Establish circulation at 5.0-bpm at 1920-psi through RCJB. Wash down to 2081' and pump 30-Bbl. sweep around at 5.0-bpm at 1900-psi. Recovered sand and aluminum debris across shaker. 1 Service rig. Check PVT's, daily derrick inspection and enviro walkaround. 1 POH w/BHA #6. 1 Break out and lay down BHA #6. Recovered all major pieces of aluminum ring in ES cementer in junk baskets. Recovered -2 gallons of sand, aluminum debris and rubber on boot baskets. 1 Clear and clean rig floor. 1 PJSM - Review retrieving RBP procedure. 1 RIH w/9-5/8" RBP retrievinq tool on 3-1/2" DP from derrick to 2,090' 1 Reverse sand off to of RBP from 2 090' to 2 105'. 5 bpm with 560 psi. 1 Clean Pit and fill with clean seawater. Mix Arctic Set Class G cement and fill 13-3/8" X 9-5/8" Annulus. . 1 Displace 9.8 ppg brine from hole with clean 8.5 ppg seawater. 5 bpm with 500 psi. 1 Release HES 9-5/8" RPB, let sealing elements relax. Verify plug released by slacking off past setting depth. 1 POOH with RBP standing back 3-1/2" drill pipe in derrick. 1 Break out and UD RBP and running tool. Sealing elements and slip section were intact. AN Clear and clean rig floor. AN Crew change, rig service, derrick inspection, set and test PVT's. AN M/U BHA #7, Dress-Off Assembly. BHA = Dress-Off Shoe, W P E~ension, WP Extension, XO, ( Dress-Off Mill), XO, Csg Scraper, XO, LBS, XO, (6) DC's, XO, Clrculation Sub. Total BHA Length = 225.76' AN RIH with Dress-Off BHA on 3-1/2" drill pipe from derrick to 3,213'. AN RIH with Dress-off BHA picking up 3-1/2" drill pipe from pipe shed. AN RIH with Dress-off BHA picking up 3-1/2" drill pipe from pipe shed to 9,741' AN M/U Kelly and establish parameters, P/U 152K, S/O 112K, Rot Wt 130K, 3 bpm with 370 psi, 55 rpm with 4,000 fUlbs rotary torque. Wash over tubing stub and dress tubing stub from 9,741' to , -4K, 60 rpm with 6,000 - 8,000 ft fUlbs of rotary torque, 3 bpm with 370 psi. Top of stub at 9,742' and bottom of shoe swallowed tubin to 9,758'. Worked over stub without rotating or pumping without problems. AN Pump 25 bbl Hi-Vis sweep around at 5-1/2 bpm with 1,350 psi. AN Crew change. Service Rig. Inspect Derrick. Check PVT Alarms. AN Cut and Slip Drilling Line. Adjust Draw Works Brakes. AN Trip out with 3 1/~" Drill Pipe and BHA #7 EB EB 06:30 - 07:30 1.00 FISH P TIEB 07:30 - 08:30 1.00 FISH P TIEB 08:30 - 09:00 0.50 FISH P TIEB 09:00 - 09:30 0.50 FISH P TIEB 09:30 - 10:00 0.50 DHB P TIEB 10:00 - 11:00 1.00 DHB P TIEB 11:00 - 12:00 1.00 DHB P TIEB 12:00 - 13:00 1.00 CASE P TIEB 13:00 - 14:00 1.00 CASE P TIEB 14:00 - 15:00 1.00 DHB P TIEB 15:00 - 16:00 1.00 DHB P TIEB 16:00 - 17:00 1.00 DHB P TIEB 17:00 - 18:00 1.00 CLEAN P CLE 18:00 - 18:30 0.50 CLEAN P CLE 18:30 - 20:00 1.50 CLEAN P CLE 20:00 - 21:00 1.00 CLEAN P CLE 21:00 - 00:00 3.00 CLEAN P CLE 6/10/2009 00:00 - 02:30 2.50 CLEAN P CLE 02:30 - 03:00 0.50 CLEAN P CLE 03:00 - 06:00 3.00 CLEAN P CLE 06:00 - 06:30 0.50 CLEAN P CLE 06:30 - 08:00 1.50 CLEAN P CLE 08:00 - 12:30 4.50 CLEAN P CLE Printed: 6/22/2009 2:10:21 PM • • BP AMOG~ ,Page 8 af 9 Operations Summary R~p~ort Legal Well Name: D-13 Common Well Name: D-13 Spud Date: Event Name: WORKOVER Start: 5/5/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/12/2009 Rig Name: NABORS 4ES Rig Number: ' Date Fr~m - To Hours Task Code NPT Phase Description of Operations 6/10/2009 12:30 - 14:00 1.50 CLEAN P CLEAN Lay down 6 1/4" Drill Collars. Lay down BHA #7. Observe normal expected wear on Shoe and Dress-Off Mill. 14:00 - 15:00 1.00 CLEAN P CLEAN Clear and clean rig floor. 15:00 - 16:00 1.00 CLEAN P CLEAN M/U BHA #8, Spear Assembly. BHA= ITCO Spear, Stop Sub, XO, Shear Assembly, Washpipe Extension, Bushing, Cutlip Guide Shoe, (4) Jts of 2-7/8" PAC DP, XO, Circulation Sub. Total BHA Length = 140.24' 16:00 - 18:00 2.00 CLEAN P CLEAN RIH with BHA #8 on 3-1/2" drill pipe from derrick. 18:00 - 18:30 0.50 CLEAN P CLEAN Crew change, service rig, derrick inspection, set and test PVT's. 18:30 - 20:30 2.00 CLEAN P CLEAN RIH with BHA #8 on 3-1/2" drill pipe from derrick to 9,580' 20:30 - 21:00 0.50 CLEAN P C~EAN P/U drill pipe and see top of tubing stub at 9,742', set down 25K and shear guide assembly. Tag Junk Catcher at 9,806', set down 15K. Saw 10K overpull when picking up off bottom. P/U 138K, S/O 103K. 21:00 - 00:00 3.00 C~EAN P CLEAN POOH with Spear Assembly, laying down 3-1/2" drill pipe. 6/11/2009 00:00 - 04:00 4.00 CLEAN P CLEAN POOH with Spear Assembly, laying down 3-1/2" drill pipe. 04:00 - 05:00 1.00 CLEAN P CLEAN Break out and UD Spear Assembly. Did not recover Junk Catcher. 05:00 - 07:00 2.00 CLEAN P CLEAN Pull Wear Bushing, Clear and clean rig floor. 07:00 - 09:00 2.00 RUNCO P RUNCMP Load Pipe shed with Jewelry and perform final inspection. Double check running order. Rig up Torque Turn equipment. 09:00 - 10:00 1.00 RUNCO P RUNCMP Crew change. Service Rig. Inspect Derrick. Check PVT Alarms. 10:00 - 12:00 2.00 RUNCO P RUNCMP PJSM. Plck-up and run in with Completion Jewelry as follows: 9 5/8" x 4 1/2" Unique Overshot, 1 full Joint of 4 1/2" 12.6 Ib/ft 13Cr-80 Vam Top Tbg, X-Nipple w/RHC-M seat installed, Baker 9 5/8" x 4 1/2" S-3 Packer, X-Nipple Assembly, 1 full Joint of 4 1/2" 12.6 Ib/ft 13Cr-80 Vam Top Tbg. All connections below the Packer have been Baker-Lok'd. 12:00 - 00:00 12.00 RUNCO P RUNCMP Continue to run the 4 1/2" Completion as designed. The 15 joints of 4 1/2" JFEBEAR Tbg on bottom was made up to 5,400 Wlbs torque. The remainder o the omp etion was 4 am Top Tbg and it was made up to 4,440 s torque. e u e Seal Guard pipe dope was used on the thread connection. Ran 222 joints of tubing, P/U joint #223 and tagged up on Tubing stub, saw both sets of brass screw shear, stacked out at 36' in. UD Joint # 223 and Joint #222. P/U 5.80' Space out pup and run joint #222. Will be spaced out 4.94' from being bottomed out, 10 ' of swallow on overshot. 6/12/2009 00:00 - 00:30 0.50 RUNCO RUNCMP Crew change, rig service, set and Test PVT's. 00:30 - 01:30 1.00 RUNCO RUNCMP M/U Cameron SA-SRL tubing hanger and land tubing string, P/U 109K and S/O 90K. Run in lock down screws and torque to 450 ft/Ibs. 01:30 - 03:00 1.50 RUNCO RUNCMP Wait on trucks, Trucks were waiting in line at seawater plant. 03:00 - 06:00 3.00 RUNCO P RUNCMP Reverse in 160 bbls of 140 degree seawater, followed by 550 bbls of 140 degree inhibited seawater, 3 bpm at 330 psi. 06:00 - 07:00 1.00 RUNCO P RUNCMP Finished circulating wellbore with hot Sea Water w/Corrison Inhibitor (Nalco EC1124A mixed at 25 gal/100 bbls). 07:00 - 09:00 2.00 RUNCO P RUNCMP Dro Packer settin Ball/Rod. Pressure up on Tubing to set Packer. Pressure test Tubing at 3,500 psi x 30 minutes. Good ~ test. Bleed pressure from Tubing down to 1,500 psi and shut in. Pressure ua on 9 5/8" x 4 1/2" Annulus to test Casinq and Printed: 6/22/2009 2:10:21 PM ~ • BP AMOCO Page 9 ofi 9 Op~rations Summary Report Legal Well Name: D-13 Common Well Name: D-13 Spud Date: Event Name: WORKOVER Start: 5/5/2009 End: Contractor Name: NABORS ALASKA DRI LLING I Rig Release: 6/12/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Haurs Task Code NPT Phase ' Description of Operations 6/12/2009 07:00 - 09:00 2.00 RUNCO P RUNCMP Packer to 3,500 psi x 30 minutes. Good test. Drop pressure from Tubing and observe DCR-Valve shear at 1,400 psi. All tests recorded on chart. Pump both directions through DCR-Valve. 09:00 - 09:30 0.50 WHSUR P RUNCMP Set and test TWCV. Test at 3,500 si from above and at 1,000 psi from below. Good tests. Record on chart. 09:30 - 12:00 2.50 BOPSU P RUNCMP Nipple down BOPE and set back on stump. 12:00 - 12:30 0.50 WHSUR P RUNCMP Crew change. Inspect work area and equipment needed. 12:30 - 15:00 2.50 WHSUR P RUNCMP Nipple up adaptor flange and test to 5,000 psi. Nipple up Production Tree and test to 5,000 psi with diesel. 15:00 - 16:00 1.00 WHSUR P RUNCMP R/U DSM lubricator and test to 500 psi, pull 4" type H TWC. 16:00 - 18:30 2.50 WHSUR P RUNCMP ump 150 bbls of diesel down IA, 4 bpm with 850 psi. 18:30 - 19:30 1.00 WHSUR P RUNCMP U-Tube diesel freeze protect between tubin and IA. 19:30 - 20:30 1.00 -WHSUR P RUNCMP e an test 4' Type H BPV. Test from below to 1,000 si for 10 charted minutes. Good test. 20:30 - 22:00 1.50 WHSUR P RUNCMP Secure well and cellar. Rig released at 22:00 hours on Printed: 6/22/2009 2:10:21 PM ~ • D-13A, Well History (Post Rig Workover) Date Summary 6/15/2009 WELL S/I ON ARRIVAL. PULLED BALL & ROD C«3 9643' SLM. PULLED STA# 3 DCR SHEAR VLV C~ .. 3721' SLM / 3724' MD. '~ ~ ' . 6/15/2009 T/I/0=0/0/0. Vac/0/0. Pull 4-1l16" CIW H BPV thru tree, post 4es. 1-2' ext used, tagged C~ 96". No problems. 6/16/2009 PULLED STA# 2 DGLV Q 7335' SLM / 7331' MD. SET GENERIC GLV'S IN STA'S 3& 2. PULLED EMPTY 4-1/2" RHC PLUG BODY Q 9648' SLM / 9654' MD. UNABLE TO LATCH UP TO 4-1/2" JUNK CATCHER C~3 9788' MD. CURFiENTLY BAILING MUD/SAND & DEBRIS ON TOP OF J-CATCHER C~ 9781' SLM. 6/17/2009 CONTINUE TO BAIL FILL ON TOP OF 4-1/2" JUNK CATCHER C~ 9788' MD. RAN 3.50" ~IB TO 9782' SLM, IMPRESSION OF FILL OR RUBBER. NO F-NECK. RAN 2.60" STAR BIT TO 9,781' SLM. JARRED DOWN FOR 30 MIN, NO MARKS ON BHA COME BACK. RAN 3.5" P-BAILER TO 9782' SLM, WORK BAILER FOR 30 MIN. NOTHING RECOVERED. LAID DOWN LUBRICATOR DUE TO HIGH W INDS. 6/18/2009 WELL S/I ON ARRIVAL. RAN 2.63" 3-PRONG WIRE GRAB TO 9,784' SLM, NO RECOVERY. RAN CENTER SPEAR TO 9,784' SLM, NO RUBBER TRASH RECOVERED. BAIL W/ 5' x 3.25" P-BAILER W/ FINGER BASKET C«3 9,784' SLM (- 1 CUP OF COMPACT MUD). RAN 3.25" P-BAILER W/ FINGER BASKET BTM TO 9784' SLM, RECOVER SMALL AMOUNT OF HARD MUD. 6/19/2009 RAN MULTIPLE BAILER RUNS TO 9784' SLM, ONLY FEW CUPS RECOVERED OF SAND LIKE SUBSTANCE. RAN W IRE GRAB & CENTER SPEAR TO POSSIBLY FISH RUBBER W/ NO RECOVERY. RAN 2.0" STAR BIT TO 9784' SLM, JARRED DOWN HARD TO ATTEMPT TO BREAK UP FILL. RAN 1.5" DD-BAILER TO 9784' SLM RECOVERED -1/2 CUP OF HARD FILL JAMMED INSIDE MULE SHOE BTM. 6/20/2009 RUN 3.50" CENT & 5' x 1.75" D-DOWN BAILER..S/D Q 9,784' SLM (NO RECOVERY). RUN 2.50" HYDROSTATIC BAILER..S/D C~ 9,784' SLM (NO RECOVERY). RUN KJ, 3.50" CENT, 2' 1-7/8" STEM & 1.25" CHISEL IN ATTEMPT TO BREAK UP FILL & DEBRIS. RUN 5' x 3.00" P-BAILER W/ MULE SHOE FLAPPER TO 9,784' SLM. ( 1/4 CUP OF SAND RECOVERED) METAL MARKS ON SHOE. RUN 4.5 GR TO 9,784' SLM. UNABLE TO LATCH. RUN 2.60 STAR BIT TO 9,784' SLM, NO MARKS ON BIT. RUN 5' x 2.25 PUMP BAILER W ITH MOD. FLAPPER BOTTOM TO 9,784' SLM. (SMALL SAMPLE RECOVERED). WELL LEFT S/I, DSO NOTIFIED. 6/23/2009 MU/RIH w/ BOT jars and 3 1/8" venturi w/ 3.625" mule shoe. Dr~a C~ 9736'. Flag CT. Venturi to 9739. Did not appear to make anv hole. Same depth as tbq stub. PO Fi to check Venturi. Venturi has about 16 oz of a very gooey substance w/metal shavings in it. RIH w/ BOT jars and 3 1/8" venturi w/ 2.75" snorkel shoe. 6/24/2009 Continue RIH w/ 3.13 Venturi w/2.75" Snorkel Shoe. Got by tubing stub at 9739. Sat down at 9793. Could not qet anv deeper w/Venturi. POOH. Small amount of drilling mud. MU & RIH BHA # 3 w 4" GS. Tagqed up at 9797', Jetted down to 9807'. Latched up, pulled. Jarred up 2 licks at 16 k over, Pulled free on third pull. POOH, at surface, No fish. RBIH with GS. Tagged up C~? 9797', washed down to 9805', latched fish and jarred free w/16k overpull. POOH & LD Junk Catcher. 6/25/2009 Remove Baker MHA. Cut 120' coil. MU 3.50" OD x 10' Venturi tool string. RIH. Tagged top of Sluggits at 9804', washed down x8 passes C~ 1.5 bpm, made 10' of hole, POOH. Recovered -- 1 gallon of sluggets. Venturri baskets were damaqed. Tattie tale in lower extension were still intact. Change out with new basket in venturi, RIH w/3.50" Venturi. Taq top of sluqqetts at 9808', Washed down to 9822', set wt down, make no more hole. Verify depth 2 more times. POOH chase OOH at 80%. Recover - 1/2 gal sluggetts and brass shear stock. MU & RIH 3 1/2 JDC Hyd release overshot, Tag up on tubing stub C~ 9740'. Could not work tools past stub. POOH. LD Baker fishing tool string. Cut 120' pipe rom coi . U 3.5" max OD Baker Fishing tool string w/ Hyd Centralizer. RIH. Page 1 of 2 ! • D-13A, Well History (Post Rig Workover) Date Summary 6/26/2009 RIH w/BHA #6 - 3.5" Max OD Baker Hyd OS fishing tool string. Taqqed Pron with Hvd OS w/1.75" ra le at 9812', ulled 2k overpull, POOH. No prong in Hydraulic overshot. LD Hyd OS. Run back in hole w/BHA #6 Hyd OS. Jet down down on Prong, Latch an ecover Prona. LD hyd overshot and MU &RIH 4..5" GS. Tag up 9813', Jet down to 9822' Sk down. Latch in pulled 13 k over, appeared to move. RBIH, tag up 9813', jet down to 9821. Latch up, begin Jarring. Jarred plug free after 4 licks C 15k overpull. POOH. LD PX pluq. Freeze protect well w/Diesel. RDMO CTU. Job complete. 7/1/2009 T/I/0 = SSV/VAC/NO OA. Temp =S1. WHPs (Eval OAP). Surface casing has been cut off & patched to surface. No OA valve on tree. SV, WV, SSV - Closed. MV = Open. IA, OA = OTG. NOVP. Page 2 of 2 I JELLHEAD = FMC ~ , ,CTUATOR - BAKER C _... B. ElEI/ = 71.61' F. ELEV = 47.91' '~3-3J$" SURFACECSG CUT ' OP - _ 3200' OFF & N 9-518" o ~ WELLHFAD INSTALL 1ax Angie = 94 @ 11559 ~atum MD = 11161' iatum TV D= 8800' SS 9-5/8" BOWEN CSG 2013~ PATCH, 47#, L-80 BTC ID = 8.681" I 3-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" 2684' Minimum ID = 2.37" @ 9949' 2-7/8" LINER TOP 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, 9736~ .0152 bpf, ID = 3.958" 4-1/2" TBG STUB (06/09/09) 9742~ 4-1/2" TBG, 12.6#, 13CR80 NSCT, I 9852' .0152 bpf, ID = 3.958" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 9910~ TOP OF 7" LNR 9933~ ~-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 9994' 9-5/8" CSG, 47# L-80, BTRS, ID = 8.681" 10460~ ~ TOP OF WHIPSTOCK 11150' PERFORATION SUMMARY REF LOG: PDS DIL/GR ON 06/28/00 ANGLE AT TOP PERF: 73° @ 11414' Note: Refer to Production DB for historical perf data SIZE SPF IMERVAL Opn/Sqz DATE 2" 6 11414 - 11440 O 02/06/05 2" 4 11550 - 11652 O 06/30/00 2" 4 11750 - 12050 O 06/30/00 2" 4 12100 - 12190 O 06/30/00 2" 4 12225 - 12249 O 06/30/00 7" LNR, 29#, L-80, ID = 6.184" ~~ 11576~ V_~' ~~ JHFtI T IVUI t5: WtLL HNtiLt~ /U-(~ 774Utf' I *"*4-1~HROM E TBG'** 1974' 9-5/8" HES ES CEMENTER 1991' 9-5/8" BKR ECP, ID = 8.70" 2~12~ 4-1/2" HES X NIP, ID = 3.813" GAS LIFf MANDREIS ST MD ND DEV TYPE VLV LATCH PORT DATE 3 3724 3699 23 MMG DOME RK 16 06/16/09 2 7331 6201 49 MMG SO RK 20 06/16/09 1 9512 7687 44 MMG DMY RK 0 06/12/09 9593' 9624' 9626' 9632' 9654' 9741' 9788' 9798' 4-1/2" HES X NIP, ID = 3.813" ~ 4-1/2" XO 5-1/2", ID = 3.910" 9-5/8" X 5-1/2" BKR S-3 PKR, ID = 4.760" 5-1/2" XO 4-1/2", ID = 3.880"1 4-1/2" HES X NIP, ID = 3.813" UNIQUE OV ERSHOT 4-1/2" HES X NIP, ID = 3.813" 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" (2001) 9832' 4-1/2" HES X NIP, ID = 3.813" 9820~ TOP OF 4-1/2" TBG STUB (11/30/00) 9851 ~ 4-1 /2" HES X NIP, ID = 3.813" 9859~ CUSTOM UNIQUE OV ERSHOT (2001) 9862~ 9-5/8" X 4-1/2" TNV PKR, ID = 3.875" (1996) 9899~ 4-1/2" HES X NIP, ID = 3.813" 9906~ TOPOF4-1/2" TBG STUB (11/26/96) 9917' UNIQUE CUSTOM OVERSHOT (1996) 9909' 9-5/8" TNV PKR (1989) 9949~ DEPLOYMENT SLEEVE (2-7/8" LNR) 9961~ 4-1/2" OTIS X NIP, ID = 3.813" (BEHIND PIP~ 9982' 4-1/2" OTIS XN NIP, ID = 3.725" (BEHIND PIP~ 9995' -I4-1/2" OTIS TBG TAIL, ID = 3.820" (BEHIND '~~(}Q'~' ELMDTTLOGDATENOTAVAILABLE PBTD ~--~ 12254' 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" ~-~ 12294~ DATE REV BY COMMENTS DATE REV BY COMMENTS 06/10/80 ORIGINAL COMPLETION 06/17/09 TFA/SV GLV C/O 04/17/89 RWO 06/24/09 ?/JMD DRLG DRAFT CORRECTIONS 12/05/96 RWO 06/27/09 MCZ/TLH JC/SLUGGfTS/PLUG PULLm 06/30/00 CTD SIDETRACK (D-13A) 01/16/01 RWO 06/12/09 N4ES RWO PRUDHOE BAY UNff WELL: D-13A PERMfT No: 2000810 API No: 50-029-20449-01 SEC 23, T11 N, R13E, 2460' FSL & 1067' FEL BP Exploration (Alaska) 07/06/09 S~hlur~~er~er ~,,t ~}~y~y NO. 5297 z:~~~ '"~:~1~~.~ sl tJ t .. S!'JU~ ~laska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 40o Alaska Oil & Gas Cons Comm ~anchorage, AK 99503-2838 Attn: ChYistine Mehnk2n ~A771V: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~Ilell Job # Log Description Date BL Color CD • ~ L ~ Z-06 AYTO-00035 GLS/PRODUCTION PROF(LE 05/12/09 1 1 07-336 84C4-00003 SCMT 05l30l09 1 1 17-14 AVY5-00049 PRODUC ION PRO ILE ~~- 05/31/09 1 1 12-01 AYTU-00039 PRODUCTION PROFILE O6/01/09 1 1 04-43 AXWS-00011 IBP/CROSS FLOW CHECK - '} O6/02/09 1 1 D-13A B04C-00059 USIT ~- 06/03/09 1 1 Z-912 B2WY-00011 MEM PROD PROFILE 06/03/09 1 1 06-05 B04C-00061 USIT O6/04/09 1 1 12-18 AWH-00014 PRODUCTION PROFILE ~~ a(~5~ 06104/09 1 1 A-35 AY3J-00026 USIT V "~ a(p ~ 06/04/09 1 1 12-22 AXWS-00013 PROD PROF/GLS O6/05/09 1 1 12-16/! AXWS-00014 PRODUCTION PROFILE - 06/05/09 1 1 18-298 B04C-00062 PSP XY-CALIPER LOG _ O6/06/09 1 1 C-12A AXWS-00015 SCMT ... ~ 06/06/09 1 1 B-27A AXBD-00028 MEM PROD PROFILE 06/11/09 1 1 L2-93A AWJI-00036 MEM CNL & INJ PROFILE 06/17/09 1 1 L2-13A AWJI-00036 MEM PROD PROFILE f ~ 06/17/09 1 1 07-21 B14B-00064 LDL 06/20/09 1 1 17-O1A AYQQ-00030 SBHP SURVEY 06/11/09 1 1 01-25 AP3Q-00041 LDL O6/15/09 1 1 L-202 B2WY-00010 MEPA PROD PROFILE ~- ~,/ 06/02/09 1 1 L-103 AXBD-00027 MEM INJ PROFILE 06/04/09 1 1 GNI-03 AWJI-00034 MEM PRESS & TEMP SURVEY ~'~-.- 06/15/09 1 1 G-316 AWJI-00027 MCNL _03 04/30/09 1 1 15-29BPB1 O9AKA0143 OH MWD/LWD EDIT - `~f ~^ 05/11/09 2 1 bl GACG Af~VwIn~11I1 Cnnr nr nr~nt ~v n~~~~~ ~~i. .......~~..~.""~ ~.'~ ~~"" ~_ ~"' __ ""_ "___ ~_ "___.. . .... ............ .-..... ..~.....r...... v~.~ vvr ~ cr~vn ~ v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ` ~ ~ _ _~ , ,„,_. ._.,. ~' • ,~, __ °- _ / Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 • • fL'tl ~ , , ,' -, ,; r : ` 1 ~ ~ f r ~` SARAH PALIN, GOVERNOR ~~i d l'~ ~-7~L~. Oii~ L~1SL ~ ~ r 333 W. 7th AVENUE, SUITE 100 CO1~TS~RQATIOrT COD'II-'IISSIOI~T 1! pHONOE~ 907A279-14339501-3539 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. - ~ ~ _ ~ ~"`~~' ~~.;:'~4i.N1~~~ ~'~i'~': _ ~ ~~ PO Box 196612 Anchorage AK 99519-6612 e ~~~ ~~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-13A Sundry Number: 309-156 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. / ~ Chair DATED this ~'? day of May, 2009 Encl. ~ ~h,o~ . r0 5- S~~ STATE OF ALASKA ALP OIL AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25280 ~' SAS 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ~~ .Ofa~9 ®Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 200-081 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20449-01-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU D-13A - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): , ADL 028285 & 028305 71.61' - Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12294' - 9059' - 12251' 9040' 9832' None Ca in Len th Siz MD TVD B r Ila Structural r 1 2 "x 11 11 urfa 2 84' 13-3/8" 2 4' 26 4 3 2670 In rm i 104 1' 9-5/8" 10461' 8347' 6870 47 Pr n Liner 1220' 7" ' - 11153' 79 ' - 865' 8160 702 Liner 2 5' 2-7/8" 949' - 12294' 8000' - 0 134 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 11414' -12249' 9010' - 9039' 4-1/2", 12.6# L-80 9995' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker'S-3' packer; Packers and SSSV MD (ft): 9798 ; and (2) 9-5l8" x 4-1/2" TIW packer; and 9862', 9909' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ F-xploratory ®Development ^ Senvice ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: May 15, 2009 _~ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Name avid Reem Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date ~/z3 ~~, Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: _ ~~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~° Other: 300 ~g~ ~'~`'~~5~ t~'~~t~S~ P~\~\+'1~1hC~n~1~~ A~~ ~ ~~~~ ~~aska Oil & Gas ions. Clilrllni~~i~,n Subsequent Form Required: \~~ AItChOfa'~Q8 APPROVED BY / ~J A roved B : COMMISSIONER THE COMMISSION Date b // Form 10-403 Revised Oi;/2006 / S ~. ~ ; ~ ~ ~~ 7aos Submit In Duplicate ~~~~ ~-~~~- U by cr,,~,~ D-13A Rig Workover (Replace surface casing) • Scope of Work: Pull 4.5" 13Cr-80 completion. Run USIT log to find TOC, cut and pull 9.625" casing as deep as possible. Tie back 9.625" casing and cement to surface. Cut split 13-3/8" surface casing out of the way. Install 9-5/8" wellhead. Run 4.5"13Cr-80 completion. Engineer: Hank Baca MASP: 2368 psi Well Type: Producer Estimated Start Date:. May 15th, 2009 F 1 CMIT-TxIA to 3500 si for 30 minutes. Surface casin leak, no need for MIT-OA. S 2 Drift tubing to 9300' for jet cutter. Dump sluggits on top of PX plug C~ 9832'. Set junk catcher on to of slu its. E 3 Jet cut tubing at 9238'. Reference tubing tally dated 1/15/01, cut desired to be 10' down first full 'oint above acker. F 4 Circulate well with seawater, diesel FP ca as needed. Bleed WHPs to 0 si. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. V 6 Set a BPV in the tubin han er. O 7 Remove the well house & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 250 psi low/3500 psi high. Circulate out freeze protection and circulate seawater. 2. Pull and LD tubing string to the cut. 3. Dress 4.5" tubing stub 4. RU wireline and run USIT from cut to surface. 5. Run 9 e/a" RBP and set 100' below TOC determined from USIT. PT RBP to 1000 psi to prove plug is set. Dump ~50 ft of sand on RBP. 6. Mechanically cut 9 s/$" casing in 1St full joint above top of cement. Pull casing thru stack. Dress-off 9- 5/a" stub in preparation of casing overshot. Note: VBR's will not be changed to 9-5/S" pipe rams as the well has 2 tested barriers (RBP & packer/PX plug) to the reservoir.. 7. Run in with 9 5/e", 47#, L-80 casing and tie-in to dressed stub. 8. Cement new 9 s/8" casing to surface. 9. ND BOPs & cut the split 13-3/8" casing out the way. 10. Install new 9.625" wellhead. NU BOPs and test to 250 psi low/3500 psi high. 11. Drill out 9.625" 12. Cleanout above 9-5/a" RBP. Test 9.625" tieback to 3500 psi for 30 minutes. Pull 9-S/e" RBP. 13. Run 4-'h" 13Cr-80 stacked packer completion 14. Displace the IA to packer fluid and set the packer. 15. Test tubing and IA to 3500 psi. Freeze protect to 2,200' MD. 16. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. TREE = 6" MCEV OY WELLHEAD = FMC ACTUATOR = AXELSON KB. E1EV = 71.61' BF. ELEV = 47.91' KOP - 3200' Max Angle = 94 @ 11559' Datum MD = 11161' Datum TVD = 8800' SS D -13A SAFETY NOTES: 70° @ 11408' AND 90° @ 11501'. **"4- HROM E T BG*"* 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" 2684' ~4-1/2" PX PLUG (12/25/07) ~ 9832' 4-1/2" TBG, 12.6#, 13CIZ80 NSCT, .0152 bpf, iD = 3.958" 9852' Minimum ID = 2.37" @ 9949' 2-7/8" LINER TOP 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9910' . TOP OF 7" LNR ~-~ 9933' ~ ~4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~~ 9994' 9-5/8" CSG, 47# L-80, BTRS, ID = 8.681" H 10460' TOP OF WHIPSTOCK 11150' PERFORATION SUMMARY REF LOG: PDS DIUGR ON 06/28/00 ANGLEATTOPPERF: 72 @ 11414' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11414 - 11440 C 02/06/05 2" 4 11550 - 11652 C 06/30/00 2" 4 11750 - 12050 C 06/30/00 2" 4 12100 - 12190 C 06/30/00 2" 4 12225 - 12249 C 06/30/00 PBTD 11532' 7" LNR, 29#, L-80, ID = 6.184" 11576' 2173' -~4-112" HES X PROFILE, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TY VLV LATCH PORT DATE 3 3474 3464 0 MMG DMY RK 10/19/03 2 7026 5998 42 MMG DMY RK 10/19/03 1 9255 7501 47 MMG DMY RK 97$$' 4-1/2" HES X NIP, ID = 3.813" 9798' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" (2 9$32' 4-1/2" HES X NIP, ID = 3.813" 9820' TOP OF4-1/2" TBG STUB (11/30/00) 9851' 4-1/2" HES X NIP, ID = 3.813" 9859' CUSTOM UNIQUE OV ERSHOT (2001) 9862' 9-5/8" X 4-1/2" TNV PKR, ID = 3.875" (1996) 9899' 4-1/2" HES X NIP, ID = 3.813" 9906' TOP OF4-1/2" TBG STUB (11/26/96) 9917' UNIQUE CUSTOM OVERSHOT (1996) 9909' 9-5/8" TIW PKR(1989) 9949' ~ DEPLOY MENT SLEEVE (2-7/8" LNR) 9981' 4-1 /2" OTIS X NIP, ID = 3.813" (BEHIND PIPE) 9982' 4-112" OTiS XN NIP, ID = 3.725" (BEHIND PIPE) 9995' 4-1/2" OTIS TBG TAIL, ID = 3.820" (BEHIND PIPE) 10001' ~ B-MD TT LOG DATE NOT AVAILABLE ~ PBTD H 12254' ~ 2-7/8" LNR, 6.16#, L-80 STL, .00579 bpf, ID = 2.37" 12294' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/10/80 ORIGINAL COMPLETION 02/06/05 MDGPJC ADPERFS 04/17/89 RWO 10/14/05 SRB/TLH REDRAW & CORRECTIONS 12/05/96 RWO 08/29/06 RDW/TLH WANER SFTY NOTE DELETED 06/30/00 CTD SIDETRACK(D-13A) 12/26/07 SWC/TLH 4-1/2" PX PLUG SET 01/16/01 RWO 10/19/03 MH/TLP GLV C/O PRUDHOE BAY UNff WELL: D-13A PERMff No: 2000810 API No: 50-029-20449-01 SEC 23, T11 N, R13E, 2460' SNL ~ 1067' WEL BP Exploration (Alaska) WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 71.61' BF. ELEV = 47.91' KOP = 3_200' Max Angle = 94 @ 11559' Datum MD = 11161' Datum TV D = 8800' SS V ~ 1 JH SAF TES: 70° @ 11408' AND 90° @ 11501'. '**4-~HROM E TBG'""' PROPOSE 13-3/8" surface casing - 2000` 4-1/2" HES X NIP, ID = 3.813" cut off and new 9-5/8" wellhead installed '°`' _- 9-5/8" 47#, L-80 from old TOC to surf 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" 2684' ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3725 2 7330 1 9671 9-5/8" x 4.5" Baker S-3 packer @ -9600` ~ ~ 97ss' 4-1/2" HES X NIP, ID = 3.813" 9798' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" (2001 4-1/2" 12.6#/ft, 13Cr-80 tubing & Unique overshot " 9832' --I4-1/2" HES X NIP, ID = 3.813 4-1/2" TBG, 12.6#, 13CR80 NSCT, .0152 bpf, ID= 3.958" 9852' 9820 TOP OF4-1/2" TBG STUB (11/30/00) Minimum ID = 2.37" @ 9949' 9851' ~4-1/2" HES X NIP, ID = 3.813" 9859' CUSTOM UNIQUE OVERSHOT (2001) 2-7/8" LIN ER TOP " (1996) 9862' 9-5/8" X 4-1/2" Tlw PKR, ID = 3.875 g8gg' 4-1/2" HES X NIP, ID = 3.813" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9910' 9906' TOP OF 4-1/2" TBG STUB (11/26/96) 9917' UNIQUE CUSTOM OVERSHOT (1996) 9909' 9-5/8" TIW PKR (1989) TOP OF 7" LNR 9933' 9949' DEFLOYMENTSLEEVE(2-7/8"LNR) 9961' 4-1/2" OTIS X NIP, ID = 3.813" (BEHIND PIPE) 9982' 4-1/2" OTIS XN NIP, ID = 3.725" (BEHIND PIPE) 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9994' 9995' 4-1/2" OTIS TBG TAIL, ID = 3.820" (BEHIND PIP 10001' ELMD TT LOG DATE NOT AVAILABLE 9-5/8" CSG, 47# L-80, BTRS, ID = 8.681" 10460' TOP OF WHIPSTOCK 11150' PERFORATION SUMMARY REF LOG: PDS DIUGR ON 06/28/00 ANGLE AT TOP PERF: 72 @ 11414' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2" 6 11414 - 11440 C 02/06/05 2" 4 11550 - 11652 C 06/30/00 2" 4 11750 - 12050 C 06/30/00 2" 4 12100 - 12190 C 06/30!00 2" 4 12225 - 12249 C 06/30/00 PBTD -{ 11532' ~ 7" LNR, 29#, L-80, ID = 6.184" 11576' PBTD 2-7/8" LNR, 6.16#, L-80 STL, .00579 bpf, ID = DATE REV BY COMMENTS DATE REV BY COMMENTS 06/10/80 ORIGINAL COMPLETION 02/06/05 MDGPJC ADPERFS 04/17/89 RWO 10/14!05 SRBlTLH REDRAW & CORRECTIONS 12/05/96 RWO 08/29/06 RDW/TLH WANERSFTY NOTE DELETED 06130/00 CTDSIDETRACK(D-13A) 12/26/07 SWGTLH 4-1/2" PX PLUG SET 01/16/01 RWO '0/19/03 MH/TLP GLV C;O I 12254' I I 12294' I PRUDHOE BAY UNIT WELL: D-13A PERMfr No: 2000810 API No: 50-029-20449-01 SEC 23, T11 N, R13E, 2460' SNL & 1067' WEL BP Exploration (Alaska) ) STATE OF ALASKA ) RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION 5 REPORT OF SUNDRY WELL OPERATION~PR 1,2 200 --.Alaska Uil & Gas Cons. COlllmi:i:iiul' Stimulate D Anch6ti'ööD WaiverO Time ExtensionO Re-enter Suspended WellO 1. Operations Periormed: Abandon D Alter Casing 0 Change Approved Program 0 2. Operator Name: 3. Address: Repair WellO Pull Tubing D Operation Shutdown D PluQ Periorations 0 Periorate New Pool 0 Periorate [K] 4. Current Well Class: Development 00 Exploratory 0 5. Permit to Drill Number: 200-0810 6. API Numbe 50-029-20449-01-00 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 71.61 8. Property Designation: ADL-0028285 11. Present Well Condition Summary: Stratigraphic 0 Service D 9. Well Name and Number: D-13A 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Total Depth measured 12294 feet true vertical 9058.5 feet Effective Depth measured 12254 feet true vertical 9040.9 feet Casing Conductor Liner Liner Production Surface Length 80 1217 2345 9926 2660 Perioration depth: Plugs (measured) Junk (measured) None None Size 20" 91.5# H-40 7" 29# L-80 2-7/8" 6.16# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 MD TVD Burst Collapse 24 104 24.0 104.0 1490 470 9933 - 11150 7988.7 - 8862.9 8160 7020 9949 - 12294 8000.3 - 9058.5 13450 13890 23 - 9949 23.0 - 8000.3 6870 4760 24 - 2684 24.0 - 2683.9 4930 2670 Measured depth: 11414 - 11440, 11550 - 11650, 11750 - 12050, 12100 - 12190, 12225 - 12249 True vertical depth: 9010.4 - 9017.1,9018.67 - 9014.12,9014.65 - 9011.67,9008.71 - 9016.11, 902f3.2,~ - 9038.67 .sC/-iNNE[) ÞPR 1. 8200!.i Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 4-1/2" 12.6# L-80 4-1/2" 12.6# L-80 @ 21 @ 9859 @ 9911 9861 9917 9995 Packers & SSSV (type & measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Averaqe Production or Injection Data Gas-Met Water-Bbl Casing Pressure 28.1 0 800 23.6 0 300 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ 4-1/2" Baker S-3 Hydro Set Packer 4-1/2" TIW Packer @ @ 9800 9897 RBDMS BFl APR I 4 2005 Oil-Bbl 1116 932 Tubing Pressure 1485 1758 ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA Development Œ] Service D Title Production Technical Assistant Signature ..J:j~ ~..v\. Form 10-404 Revised 4/2004 On \("'\ . h) " \ .~ ~.> Th \' '-é [\ r.I.. h7{le t 564-4657 ,\ ~ ,j I, V r\ '~,.. 4/1/05 Date -) ) D-13A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 02/06/05 CTU #5, ADD PERF; CONT' FROM WSR 2/05/05... CONTINUE RU DS CTU #5. LOAD WELL WITH FILTERED 1 % KCL. RIH WITH PDS MEMORY GR/CCL WITH 2.211 CARRIER AND 2.2511 JSN (BHA #1). LOG INTERVAL 11500' UP TO 11100' CTMD. FLAG PIPE AT 11400' CTMD. POOH. CORRECTION (-2') TIED IN TO MCNL 06/23/03. MU AND RIH WITH SWS 2.011 POWERJET (BHA #2). PERFORATE 26' FROM 11414' TO 11440' AT 6 SPF. POOH. NOTIFY PCC AND PAD OPERATOR TO POP WELL. FLOWLINE IS NOT FREEZE PROTECTED. *** JOB COMPLETE *** FLUIDS PUMPED BBLS 127 60/40 Methonal 135 1 % KCL 262 TOTAL Page 1 I....'.·T" .^ TREE = 6" MCEVOY WELLHEA D = FMC """"""",.,."""",,,,,,,,,,.,.,.,.,.,.,.,.,.,..,M",..,.,.,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,.,.,..,,,,,,,,,,,",,,,,,,,",,,,.,.,.,,,,,,,,,,, A CTUA TOR = AXELSON kB.äE\¡';;' , . . 71.6'1' W""'WWM·,W,...,·,·.·"".....,.,."·"""",w,...,.,.,.,.,,.,.,.,......'......,.....,,,,.,..iVY\W,w,,·,,,.,.,.,.,,,.,,I'MW,"',,,.,.".".,,.,., BF. ELEV = 47.91' KOP = 3200' """"''''''IW'''H''''''''''''''''''''''''IW'''H'''''''''_''''''''''''''''''''''''''''''''''',·/YW'''''''''''''''''HHHN''''''re ~~x,A.ngle= ~~@11~~,~,' DatumMD= 11161' DatumTVD = . "SãÖÖìss ) 113-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" l-i 2684' Minimum ID = 2.37" @ 9949' 2-7/8" LINER TOP TOP OF 4-1/2" TBG STUB l-i 9911' I TOP OF 7" LNR l-i 9933' TOP OF 2- 7/8" LNR l-i 9949' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 9995' 19-5/8" CSG, 47# L-80, BTRS, ID = 8.681" l-i 9949' I TOP OF WHIPSTOCK l-i 11150' PERFORA TION SUMMA RY REF LOG: PDS DIL/GR ON 06/28/00 ANGLE AT TOP PERF: 72 @ 11414' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 11414 - 11440 0 02/06/05 2" 4 11550 - 11652 0 06/30/00 2" 4 11750 - 12050 0 06/30/00 2" 4 12100 - 12190 0 06/30/00 2" 4 12225 - 12249 0 06/30/00 I 7"LNR,29#,L-80,.0371bpf,ID=6.184" l-i 11576' I ~ D-13A I I L I ~ ~ I I Z---1 ~ : , -." ')FETY NOTES: 700 @ 11408' AND 900 @ 11501'. "'''SURFACECSG LEAK. OPERATING LIMITS: M AX lAP = 2000 PSI, MAX OAP = 500 PSI (10/20/03 WAIVER)*** 2173' l-i 4-1/2" HES X PROFILE, ID = 3.813" I GAS LIFT MANDRELS DEV TY PE V LV LATCH PORT DA TE o MMG DMY RK 10/19/03 42 MMG DMY RK 10/19/03 47 MMG DMY RK ST MD TVD 3 3474 3464 2 7026 5998 1 9255 7501 9788' l-i 4-1/2" HES X NIP, ID = 3.813" I 9798' l-i 9-5/8" X 4-1/2" BAKER S-3 PKR, ID = 3.875" 9832' l-i 4-1/2" HES X NIP, ID = 3.813" I 9859' l-i CUSTOM UNIQUE OV ERSHOT z z---i 9897' l-i 9-5/8" TIW PKR w / X I , ~ I 9899' l-i 4-1/2" HES X NIP, ID = 3.813" I 9917' l-i CUSTOM OVERSHOT ASSY I J~W . I 9949' l-i DEPLOYMENT SLEEVE I I 9961' l-i 4-1/2" OTIS X NIP, ID = 3.813" I I 9982' l-i 4-1/2" OTIS XN NIP, ID = 3.725" I I 9995' l-i 4-1/2" OTIS TBG TAIL, ID = 3.820" I r 10001 ' l-i ELMD TT LOG NOT A V AILABLE I I PBTD l-i 12254' 2-7/8" LNR, 6.16#, L-80 STL, .00579 bpf, ID = 2.37" l-i 12294' I DA TE REV BY COMMENTS 02/06/05 MDClPJC ADPERFS DATE 06/10/80 01/17/01 06/30/00 03/03/02 10/19/03 11/17/03 REV BY COMMENTS ORIGINAL COMPLETION RIG WORKOV ER CTD SIDETRACK (D-13A) RN/TP CORRECTIONS MH/TLP GL V C/O TJP/PAG WAIVER SAFETY NOTE PRUDHOE BA Y UNIT WELL: D-13A PERMIT No: 2000810 API No: 50-029-20449-01 SEC 23, T11 N. R13E, 2460' SNL & 1067' WEL BP Exploration (Alaska) F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE PBU D-04 & D-13 ') ?rb pJi) Subject: PBU D-04 & D-13 From: John Crisp <john_crisp@admin.state.ak.us> Date: Fri, 29 Oct 2004 03 :33 :22 -0800 . Tô,~ 'Jim Regg <jim ~regg@admin.state.;ak.us~:. : ~1-I(o 2OO-õ~ f Hi Jim, I stopped @ PBU D Pad to check the status of the D Pad problem wells on my way to witness BOP test on 7ES on Z Pad. D-04 is shut in wi SSV closed & freeze protect sign on flow line. The cellar on D-04 is frozen & I could see no oil in cellar. D-13 is producing wi 1500 psi. tubing pressure. IA has 500 psi & if gauge is correct the OA is @ 0 psi. Small amount of oil or freeze protect coming from conductor. D-13 has waiver posted. SCANNED NO\! n 2, 2004 1 of 1 10/29/20047:59 AM 08~27~03 Schlumberger NO. 2952 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 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 Prints CD L1-15 ~-~;~ c~:-~,-~ ~.~ RST-GRAVEL PACK 08~20~03 1 GNI-03 /(~ '~ '- I ~ c~ SHUT-IN TEMP SURVEY 08118/03 1 NK-62 ~ ~~ PROD PROFILE/DEFT 05/30103 1 4-08/P.27-- ~ ~ ~~ INJECTION PROFILE 08/20/03 2-6~Q-17 ~[~-I ~ LDL 08117/03 2-3~SN-03 ~q ~ ~ I ~ ~ LDL 081~8103 ~-sz~.-2= ~ - ~l ~ 2~2s~ .ST~.GMn 0S~0Z~0= ~ ~ ~ ~.~ 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 ~' "~ }. ..... ~,'; ....... ~ ...... Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Date Delivered: 07/22/03 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2916 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 1130 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Color Well Job # Log Description Date Blueline Prints CD Z-39 r--~ ~J'~- PROD LOG W/DEFT 07/19/03 1 D.S. 2-14 '~'~)'-L"~ ~,~-x¥ RST G~VEL PACK 07/17/03 1 ~ ~ ~ ~-~ LDL 07/16103 ~ N-11B '~' ~ SBHP SURVEY 07116103 1 D.S. 15-08B ~ ~ ~- ~ RET G~VEL PACK 07/14103 1 D-03A ~-~, ~ ~ MEM PROD PROFILE 06119103 1 K-317B ~[ ~T~'(~ PROD PROFILE W/DEFT 06/09103 ~ D.S. 5-04A ~ ~0~~ MEM PROD PROFILE 06/14103 ~ D-13A ~~1 MEM PROD PROFILE 06/23/03 1 D.S. 5-02A ~ -~ L~ ~' MEM PROD PROFILE 06/10103 1 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: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ,. · Permitto Drill 2000810 MD 12294 TVD DATA SUBMITTAL COMPLIANCE REPORT 9~6~2002 Well Name/No. PRUDHOE BAY UNIT D-13A Operator BP EXPLORATION (ALASKA) INC 9059 Completion Dat 6/30/2000 j Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-20449-01-00 UIC N REQUIRED INFORMATION Mud Log N._g_o Sample N._9o Directional Survey ~,,~o~'~,/ ~ , DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fret (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval OH / Dataset Start Stop CH Received Numbe ,r~ Comments 10574 12287 Open 7/6/2000 09<~73~ 10574-12287 9913 LIS Verification TVD GR MD ROP/GR USIT/Cement IL 9573 SRVY RPT 2/5 2/5 5 2/5 FINAL FINAL FINAL FINAL FINAL 11145 12258 Case 2/22/2001 2/22/2001 2/22/2001 11200 12290 CH 2/23/2001 11200 12290 CH 2/23/2001 0 9800 CH 2/26/2001 10574 12287 OH 7/6/2000 OH 7/6/2000 11100 12290 OH 8/23/2000 Q99~- 11145-12258 991~/LIS Verification Digital Data LIS Verification Paper Copy 11200-12290 BL, Sepia 112007.12290 B~Lj__Sepia 0.9800 Color Print-""~ 10574~ ~-~';~ 9~DS IL SPERRY 11100-12290 Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMAT~[0N Well Cored? Y/~_N//) Chips Received? ---..Y-/-N-----~ Analysis ----Y'd'-N-- R~.n~.iv~.d? Daily History Received? ~)N Formation Tops Comments: Permitto Drill 2000810 DATA SUBMITTAL COMPLIANCE REPORT 9/6/2002 Well Name/No. PRUDHOE BAY UNIT D-13A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20449-01-00 MD 12294 'l-VD 9059 Completion Dar 6/30/2000 Completion Statu 1~OIL Current Status 1-OIL UIC N Compliance Reviewed By: .............................. Date: STATE OF ALASKA ALASKA .,.,~L AND GAS CONSERVATION Ct. ,MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Drill-Prep Work 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2820' SNL, 1067' WEL, SEC. 23, T11N, R13E, UM At top of productive interval 3505' SNL, 4363' EWL, SEC. 24, T11N, R13E, UM At effective depth 3661' SNL, 5254' EWL, SEC. 24, T11N, R13E, UM At total depth 3642' SNL, 8' EWL, SEC. 19, T11N, R14E, UM 5. Type .¢J.f well: Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) KBE = 71.61' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number D-13A 9. Permit Number / Approval No. 200-081 10. APl Number 50- 029-20449-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 12294 feet true vertical 9059 feet Effective depth: measured 12251 feet true vertical 9040 feet Casing Length Size Structural Conductor 110" 20"x 30" Surface 2660' 13-3/8" Intermediate 10437' 9-5/8" Production Liner 1220' 7" Sidetrack Liner 2345' 2-7/8" Plugs (measured) Junk (measured) KOP (top of window) 11153'. 7" Liner abandoned from 11153' to 11580'. Cemented MD TVD 126 c.f. Arctic Set 134' 3855 c.f. Permafrost II 2684' 1472 c.f. Class 'G', 130 cuft PF 'C' 10461' 425 c.f. Class 'G' 101 c.f. Class 'G' 9933'-11153" 9949'-12294' 134' 2684' 8347' 7989'-8865' 8000'-9059' Perforation depth: measured Open Perfs 11550'- 11650', 11750'- 12050', 12100' - 12122', 12225' - 12249' true vertical Open Perfs 9019' - 9014', 9015' - 9012', 9009' - 9016', 9028' - 9039' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 tubing to 9897' with 4-1/2" tailpipe to 9995'. Packers and SSSV (type and measured depth) 9-5/8" TIW HB-BP-T PKR @ 9862', 9-5/8" Packer w/"X" (TIW) @ 9897'. 4-1/2" HES HXO SSSVLN @ 2233'. 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Scott L~Vo,e ~'~r'~ ~¢//~ Title Technical Assistant Prepared By Name/Number: Date (~ /,j.Z'""'/~) / DeWayne SctCnorr ~'64-51 "74 Form 10-404 Rev. 06/15/88 Submit In Duplicate D-13A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/06/2001 01/11/2001 DRILL-PREP WORK: RUN JUNK BASKET W/8.30 GUAGE RING DRILL-PREP WORK SUMMARY 01/06/01 RAN JUNK BASKET W/8.30 GUAGE RING TAGGED @ 9787' SLM. RECOVERED 3 BANDS AND WHAT LOOKS LIKE LCM 01/11/01 RAN 3.625" CENTRALIZER & 3 3/8" DUMMY GUN. SAT DOWN ON TUBING CUT @ 9821' WLM. RAN 3.25" SWAGE. SATDOWN @ 9821' & WORKED DOWNTO 9844' WLM. RAN 3.62" DECENTRALIZER & 3.70" LIB. SAT DOWN ON TUBING CUT @ 9821' WLM. LIB INDICATES TUBING OUT OF ROUND. RAN 3.77" SWAGE. WORKED FROM 9825' WLM TO 9839' WLM. RAN 2.74" SWAGE. SAT DOWN @ 9844' WLM. RDMO. Fluids Pumped BBLS. Description No Fluids Pumped 0 TOTAL Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 894 Company: State of Alaska Alaska Oil & Gas Conservation Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: 1/22/01 Color Well Job # Log Description Date Color Sepia Prints CD D-13A 21028 USIT 010109 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E, Benson Bivd, Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Receive~ ~.~_.~f.~~ To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs · D-13A, AK-MW-00079 February 15, 2001 D-13A: ~ 2" x 5" MD Gamma Ray Logs · 50-029-20449-01 2" x 5" TVD Gamma Ray Logs · 50-029-20449-01 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY TRANSMITTAL LETTER TO THE ATrENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 OF THE Date'.~q, -,~ ~- t3/ WELL LOG TRANS~TT~ To~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7~ Avenue, Suite 100 Anchorage, Alaska MWD Formation Evaluation Logs D-13A, February 15, 2001 AK-MW-00079 1 LDWG formatted Disc with verification listing. API#: 50-029-20449-01 PLEASE ACIG~OWLEDGE RECEIPT BY SIG~G AND RETURt~G A COPY OF THE TRANSMI'Iq'AL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Sign~ Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Feb 06 16:01:45 2001 Reel Header Service name ............. LISTPE Date ..................... 01/02/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/02/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER CNS MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB N-UMBER: LOGGING ENGINEER: OPEP~ATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 2 AK-MW-00079 B. JAHN D. MASKELL / D-13A 500292044901 BP Exploration, Alaska Sperry Sun 06-FEB-01 23 lin 13E 2820 1067 71. 61 DERRICK FLOOR: .00 GROUND LEVEL: .00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 11150.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS A_RE SUB-SEA TRUE VERTICAL DEPTHS (TVDSS). 3. MWD RUN 1 MADE NO FOOTAGE AlqD IS NOT PRESENTED. 4. MWD RUN 2 IS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 5. DIGITAL DATA ONLY IS DEPTH SHIFTED TO THE PDC GR LOG (PDS 06/28/00) . LOG AND HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 6. MWD RUN 2 REPRESENTS WELL D-13A WITH API# 50-029-20449-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12290'MD, 8985'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. TVDSS = TRUE VERTICAL DEPTH, SUBSEA. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 11145.0 12258.0 ROP 11168.0 12289.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH -- GR 11143.0 11162 5 11179 5 11187 0 11208 5 11234 0 11251 0 11302 5 11304 5 11306 5 11308 0 11309 5 11356 5 11447 0 11451 5 11472 0 11489 0 11496 5 11500 0 11503 5 11505 5 11536 0 11643 0 11649 5 11900 5 12063 0 12076 5 12081 0 12083 5 12088 0 12119 5 12170 5 12213 5 12241 0 12255 5 12290 0 BIT RUN NO 2 MERGE TOP 11143.5 BASELINE DEPTH 11144 5 11164 11181 11189 11210 11235 11252 11303 11305 11307 11309 11310 11356 11445 11449 11470 11489 11496 11507 11510 11511 11542 11649 11656 11903 12066 12081 12084 12086 12089 12121 12172 12216 12241 12255 12289 $ 0 5 0 0 5 0 5 5 0 0 5 0 5 5 5 0 0 0 0 5 5 0 0 0 0 5 5 0 0 0 0 5 0 0 5 MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down MERGE BASE 12290.0 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 11145 12289.5 11717.3 2290 ROP MWD FT/H 0.54 2181.94 136.919 2244 GR MWD API 13.31 267.48 27.3293 2227 First Reading 11145 11168 11145 Last Reading 12289.5 12289.5 12258 First Reading For Entire File .......... 11145 Last Reading For Entire File ........... 12289.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11143.5 ROP 11166.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ STOP DEPTH 12258.5 12290.0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 27-JUN- 00 Insite 0.0 Real-Time 12290.0 49.6 94.5 TOOL NUMBER FLO PRO 8.70 .0 8.5 24000 6.2 .000 .000 .000 .000 .0 167.0 .0 .0 Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 11143.5 12290 11716.8 2294 ROP MWD020 FT/H 0.54 2181.94 136.645 2248 GR MWD020 API 13.31 267.48 27.1928 2231 First Last Reading Reading 11143.5 12290 11166.5 12290 11143.5 12258.5 First Reading For Entire File .......... 11143.5 Last Reading For Entire File ........... 12290 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/02/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/02/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/02/06 Origin ................... STS Reel Name ................ UNBZWOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,oSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Pedorate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 71.61' AMSL [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2820' SNL, 1067' WEL, SEC. 23, T11N, R13E, UM D-13A ~'~.: (~ :::' ~" !~; ~: - 9. Permit Number/ Approval No. At top of productive interval ~ ~;. ¢ ." .' - ' 200-081 3505' SNL, 4363' EWL, SEC. 24, T11N, R13E, UM 10. APl Number At effective depth ? ? ~" ~.:' ~ .' n '-, 50-029-20449-01 3661' SNL, 5254' EWL, SEC. 24, T11 N, R13E, UM 11. Field and Pool At total depth ,-,1~o,,,~ Oii ¢:; ,:..: :-..,:¢ ~;::::; ~3. ,...r;~,.;,,:. ::.;~..; , .... ~,,, .. .-. Prudhoe Bay Field / Prudhoe Bay 3642' SNL, 8' EWL, SEC. 19, T11 N, R14E, UM ;:.nchor~.'~ !::: Pool 12. Present well condition summary Total depth: measured 12294 feet Plugs (measured) true vertical 9059 feet Effective depth: measured 12251 feet Junk (measured) true vertical 9040 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 14 cu yds Arctic Set 110' 110' Surface 2660' 13-3/8" 3855 cu ft Permafrost II 2684' 2684' Intermediate 10437' 9-5/8" 1472 cu ft Class 'G', 130 cu ft PF 'C' 10461' 8347' Production Liner 1645' 7" 425 cu ft Class 'G' 9933' - 11578' 7989' - 9218' Perforation depth: measured Open: 11311' - 11350' Sqzd: 11214'- 11224', 11240'- 11270', 11281'- 11311', 11311'- 11350' true vertical Open: 8994' - 9026' Sqzd: 8915' - 8923', 8936' - 8960', 8969' - 8994' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13Cr80 to 9859'; 4-1/2", 12.6#, L-80 to 9995' Packers and SSSV (type and measured depth) Baker 'S-3' packer at 9798'; 9-5/8", TIW 'HB-BP-T' packer at 9862'; 9-5/8" packer at 9897'; 4-1/2" SSSV LN at 2173' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the fore. going is t~ect to the best of my knowledge Signed Terde Hubb,e -'""fj~,~'/' ~ Title Technical Assistant Date Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 ORIGINAL Submit In Duplicat,e.e Anchorage Legal Well Name: D-13A Common Well Name: D-13A Spud Date: Event Name: WORKOVER Sta~: 1/5/2001 End: Contractor Name: DOWELL SCHLUMBERGER Rig Release: Group: RIG Rig Name: NORDIC 1 Rig Number: ~ate Fro~:~~~ ~rs: ~ha~ ~: ption of O perations 11512001 00:00 - 06:00 6.00 MOB DEGOMP move rig from EOA 15-41 to WOA D-13A 06:00 - 11:00 5.00 RIGU DEGOMP Spot sub & rig up Raise derrick etc. 11:00 - 12:00 1.00 WHSUR DECOMP rig lubricator & pull BPV 12:00 - 16:00 4.00 KILL DECOMP bleed psi to tank & displace freeze protection diesel to tank with sea h20 16:00- 17:00 1.00~WHSUR DECOMP Set ~c & test same 17:00 - 19:30 2.50 ! WHSUR DECOMP nipple down tree 19:30 - 22:00 2.50 BOPSUF DECOMP Nipple up bop 22:00 - 00:00 2.00 BOPSUF DECOMP test bop to 205-1ow & 3500 high (test waived by Chuck Sheve with ACCO) 11612001 00:00 - 02:00 2.00 BOPSUR DEOOMP test bop;s to 250 Iow & 3500 high. Waived by chuck sheve with aogc. 02:00 - 03:00 1.00 BOPSU~ DEGOMP Rig lubricator & pull ~c. 03:00 - 15:30 12.50 PULL DECOMP pull hanger & lay dn & lay dn 232 jts.4.5" tbg. + 1-cut jr. 20.03' & lost 6-bands from control line from a total of 56- run on previous workover. 19:30 - 00:00 4.50 EVAL COMP Make up HES R~S PKR & 9-5/8" Scraper & Unique overshot & rih on 3.5" drillpipe in singles from shed. 1~/2001 00:00 - 02:00 2.00 EVAL COMP Pick up 3.5" drill pipe to 4900' 02:00 - 03:00 1.00 EVAL COMP Reverse circ. 03:00 - 04:00 1.00 EVAL COMP cut drlg. line 04:00 - 10:30 6.50 EVAL COMP continue to pick up drill pipe to 9816' tag. stump & circ. down over several times was unable to 100 % Identi~ any friction pressure increase, although all measurements were right on. & reverse circ. until well bore cln. 10:30 - 11:30 1.00 EVAL COMP Set R~S packer & test ~g. to 3000 psi. for 30- min. 11:30 - 18:00 6.50 EVAL COMP Lay down 3.5" drill pipe to 2000' 18:00 - 00:00 6.00 EVAL ~HR COMP Phase 3 weather, circ. to prevent seawater from freezing & wait on weather to improve so as to be able to get Schlumberger in & rig up to run USlT Icg. 11812001 00:00 - 23:00 23.00 EVAL ~HR COMP wow & circ. well bore 23:00 - 00:00 1.00 EVAL COMP pooh laying dn 3.5" dp. 11912001 00:00 - 01:30 1.50 EVAL COMP CONTINUE TO ~Y DOWN DRILL PIPE.. 01:30 - 13:00 11.50 EVAL COMP RIG SWS & RUN USIT LOG FROM TBG. STUB. ~ 9817' TO SURFACE & FOUND CSG. TO HAVE GOOD INTEGRI~ EXCEPT ONE ABNORMALITY ABOUT 2700 FOOT AT A COLOR THAT PRESENTED ITSELF AS A COL~SPSE FROM OUTER OD THAT LEFT A i.d. OF 8.55" AT THE WORST. tHIS WILL BE ANALSlZED BY SWS & FURTHER INFO WILL BE GIVEN. 13:00 - 17:00 4.00 CLEAN COMP SWS MADE 2 RUNS IN WELL BORE WITH 8.5" G~JB TO TBG. STUB & REC. 1-BAND ON RUN ~1 & SOME OTHER DEBRI. RUN ~2 WAS CLEAN. RIG DOWN 17:00 - 19:30 2.50 RIGU COMP RIG UP TBG. TONGS & EQUIPMENT FOR CHROME TBG. ~19:30 - 00:00 4.50 RUNCO~ COMP MAKE UP PACKER & UNIQUE OVERSHOT & RICH WITH SAME. .I. 85-JTS. 111012001 00:00 - 12:30 12.50 RUNCO~ COMP cont. to rih with 4.5" completion, to 9817' 14:00 - 15:30 1.50 COMP Make up hanger & prepare rig to circ corrosion inhibitor in IA. 15:30 - 19:00 3.50 RUNCO~ COMP circ. 509 bbl. clean seah20 treated with corroion inhibitor 19:00 - 20:30 1.50 RUNGO~ COMP land hanger & rilds 20:30 - 00:00 3.50 RUNGO~I~THR COMP Rig HES & rih with 3-3/8" spent gun to 9820' (WLM) unable to enter into tbg. stub found impression on bottom as if debri on one side only about 3/4" in width as if spring off of SWS tool laying over top. pooh & change tool. 1/1112001 06:30 - 15:00 8.50 PULL JUNK COMP Pull Hanger to Sudace & lay dn& lay dn tbg. string.at 1500 Hrs. had 1 Printed: 1/26/2001 4:24:42 PM Frr-~ I $'-P?OO'Lage2of3 ! _. -'" - - -- . - BP AMOCO '- - operations SUmmary Report Oil Anchorage Legal Well Name: D-13A Common Well Name: D-13A Spud Date: Event Name: WORKOVER Start: 1/5/2001 End' Contractor Name: DOWELL SCHLUMBERGER Rig Release: Group: RIG Rig Name: NORDIC 1 Rig Number: - Date ."From-To 'Hours Task 'Suni I Phase Description ..... I Code' I of Operations 111112001 06:30- 15:00 8.50 PULL JUNK COMP 68-Jts. laid down. 15:00 - 00:00 9.00 PULL DEGOMP Operation shut down for crews to Attend TL Meeting. 111212001 00:00 - 03:00 3.00 PULL DEOOMP Employees attend safety meeting. 03:00 - 09:30 6.50 PULL DEOOMP Continue to pooh with 4.5" CR tbg. to 2200' 09:30 - 10:30 1.00 PULL DECOMP Circ. hot sea water to prevent wellbore from freezing in permafrost section. 10:30 - 17:00 6.50 PULL DECOMP continue to pooh & inspect packer for damage & stand back in derrick for re-run 17:00 - 19:30 2.50 CLEAN COMP Make up FTA # 1 Washover shoe +I-JT. 8-1/8" washpipe+bumper sub +jars. +2-boot basket. 19:30 - 00:00 4.50 CLEAN COMP Pick up 3.5" drill pipe from shed. Purpose of this trip with wash pipe is to ensure that outside cutter is able to get under collar of pup jr. just above existing tiw packer to make cut this will leave a 7' stub. 1/13/2001 00:00 - 07:30 7.50: CLEAN DEOOMP continue to rih with FTA # 1 1-Jt. 8-1/8" wash pipe with shoe. & wash over tbg. stub to top of tiw packer. 9861' 07:30 - 13:00 5.50 CLEAN DECOMP POOH with FTA # 1 & lay dn same. 13:00 - 20:00 7.00 CASE DECOMP MU FTA # 2 (8-1/8" O.D. cutter. & rih with same to & locate over cut tbg. stub & slack off to packer & pu to collar & pull lk & cut 4.5" tbg. @ 9855' 20:00 - 00:00 4.00 CASE DECOMP pooh with FTA# 2 & cut tbg. 1/14/2001 00:00 - 01:30 1.50 CASE DECOMP Lay down FTA # 2 Baker outside tbg. cutter & rec. 35.92' of 4.5" tbg. & found to be filled with a substance that was later Identified as sluggit & scale and thrash on top. 01:30 - 05:00 3.50 BOPSUR COMP Pressure test bop's to 3500 psi. (test waived by John Crisp with AOGC) 05:00 - 08:30 3.50 CLEAN COMP Rih open ended with 3.5" drillpipe to 9800' 08:30 - 15:30 7.00 CLEAN COMP pooh laying down same. 3.5" drill pipe 15:30 - 19:00 3.50 RIGU COMP Clean rig floor & rig up tbg. running equipment. 19:00 - 00:00 5.00 RUNCO~! COMP Run in hole with baker "S-3" packer on 4.5" 12.6# vam tbg.75-jts, in hole. 1/15/2001 00:00 - 11:30 11.50 RUNCOI~I COMP 'rih with completion to 9855' tbg. top. 11:30 - 13:30 2.00 RUNCO~I COMP MU hose & circ down over tbg. stub & space out same with tbg. hanger & pup jt. 13:30 - 16:30 3.00 RUNCOEI COMP reverse circ corrosion inhibitor in annulus. 16:30 - 17:00 0.50 RUNCOkl COMP land tbg. hanger & rilds 23:30 - 00:00 0.50 RUNCOrl COMP Pressure test lines to 4000 psi. & psi. tbg. to 4000 psi. for 30-min (OK) & Bleed Tbg. to 1500 psi. & test annulus to 3000 psi. & Recognize No communication with tbg. 111712001 00:00 - 01:30 1.50 RUNCO~ I COMP Pressure test lines to 4000 psi. & psi. tbg. to 4000 psi. for 30-min (OK) & Bleed Tbg. to 1500 psi. & test annulus to 3000 psi. & Recognize No communication with tbg. t 10:00 - 10:30 0.50 WHSUR COMP Install TWO valve and Test to 3,000 psi. 10:30 - 12:30 2.00 WHSUR COMP Nipple down BOP 12:30 - 14:30 2.00 WHSUR COMP Nipple Up tree 14:30 - 15:00 0.50 WHSUR COMP Test tree and hanger void to 5,000 PSI 15:00 - 16:00 1.00 WHSUR COMP Rig Up Lubricator and pull TWC valve 16:00 - 19:00 3.00 WHSUR COMP Rigged up Little Red and pumped 155 bbls down the IA to at 3 bpm. shut down and U Tubed into tubing to freeze protect well 19:00 - 19:30 0.50 WHSUR COMP Set BPV 19:30 - 21:00 1.50 WHSUR COMP Rig down lines and Blow down . Secure tree and Cellar area. Printed: 1/26/2001 4:24:42 PM ' - ' BP AMOCO F ~_F ~ ~ ~_~ ~ 0 0 i Page, 3 of 3 · Operations summ ry R ' a eport ~,~q Commissi0r, And ~o~ age Legal Well Name: D-13A Common Well Name; D-13A 8pud Date: Event Name: WORKOVER Sta~: 1/5/2001 End: Contractor Name; DOWELL SCHLUMBERGER Rig Release; Group: 8LIC Rig Name; NORDIC 1 Rig Number; .Date-~ From -T°.' Hours -Task l~e Phase Description of Operations I .:--, .... ' 1/6/2001 15;30 - 19;30 4.00 CLEAN DECOMP Rig Hes & rih with 8." G~JB 1/11/2001 00;00 - 06;30 6.50 RUNCO~THR COMP run 3.25" Swedge & work down hole from tbg. top to 9844' pushing junk. run 3.70" LIB to 9821 & 6et Impression of tbg. cut on ve~ outer edge that had a pattern that tbg. top was flat on gauge as tbg stbg was not pefietly round. Run 3.77" swedge and a~empt to swedge & was unableRun 2.74" Swedge to 9844' & was unable to make fo~ard progress. Diagnosis is that we have Junk in I.D. Of lbg. ~ tbg. top appears to be sliglty fiat and pushed in. Decision to pull tbg. ~ re-cut tbg. in sub on top of packer and this will repair top ~ remove tbg. stub that has Debri in it. Note Debri that is known to not be able to recover is bow spring off of USIT log 14" ~1/4" angle sides X 1" W. 1/15/2001 17:00 - 23:30 6.50 OLEAN COMP rih with 3.80 dri~ a sample bailer to 9806' (wire) no recove~l & drift would not go through X-nipples Run ~2 2.5" pump bailer wilh 3.80' swedge to 9871' went through nipples ok & recovered small amount of debri. Run ~ 3 run plug & set ~ 9832' (WLM) ~ set good. & rig down wire line 1/17/2001 01;30 - 09;30 8.00 CLEAN ' COMP Rig Up wireline unit and run ~ 1 RIH w/equalizing prong, ~2 RIH w/ pulling tool, ~3 RIH 10' Pump Bailer, ~ RIH Pump Bailer. 09:30 - 10:00 0.50 CLaN COMP Rig Down Hallibu~on Slick Line Unit i ! Printed: 1/26/2001 4:24:42 PM STATE OF ALASKA ALASK/-.. ~_ AND GAS CONSERVATION COMI~ SION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-081 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ~. ..... ..~._. 50-029-20449-01 4. Location of well at surface ?~?.~--7~i-~¥~,i-"i u.,,,,,~~ 9. Unit or Lease Name 2820' SNL, 1067' WEL, SEC. 23, T11N, R13E, UM !,.:, ;-~ ~ Prudhoe Bay Unit At top of productive interval 3505' SNL, 4363, EWL, SEC. 24, T11N, R13E, UM ............ . ..... ' ~' ~ 10. Well Number At total depth 3642' SNL, 8' EWL, SEC. 24, T11N, R13E, UM ! .... _..~._._ ...... ! D-13A 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 71.61' AMSL ADL 028285 12294 9059 12251 9040 FT [] Yes [] No (Nipple) 2233' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, ReP, Memory Induction 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" X 30" Insulated Conductor Surface 110' 36" 14 cu )/ds Arcticset concrete 13-3/8" 72# L-80 Surface 2684' 17-1/2" 3855 cuft Permafrost II 9-5/8" 47# L-80 Surface 10461' 12-1/4" 1472 cu ft Class 'G', 130 cu ft PF 'C' 7" 29# L-80 9933' 11153' 8-1/2" 425 cu ft Class 'G' 2-7/8" 6.16# L-80 9949' 12294' 3-3/4" 101 cuft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SiZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 9995' 9862' & 9897' MD TVD MD TVD 11550' - 11652' 9019' - 9014' 11750' - 12050' 9015' - 9012' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12100' - 12190' 9009' - 9016' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12225' - 12249' 9028' - 9039' 2000' Freeze Protect with 25 Bbls of MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 8, 2000 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of litholog~~~~'~¢~j'~.~.rent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 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. 25N 11179' 8885' 25P _ 11189' 8893' 24N .11233' 8923' 24P 11237' 8926' 22N 11297' 8962' 22P 11303' 8965' 21N 12202' 9020' 21P 12215' 9024' ,, 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 TechnicalAssistant Date ~)~),',~.~-~ D-13A 200-081 Prepared By Name/Number: 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 -;-,.,'~- -~'-2-'%_ ~'" ~ ': ,~' ~' ~ ~'~ ITEM 28: If no cores taken, indicate 'none'. : ~. Form 10-407 Rev. 07-01-80 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-13 D-13 Spud Date: REENTER+COMPLETE Start: 6/25/2000 End: 6/30/2000 DOWELL SCHLUMBERGER Rig Release: 6/30/2000 Group: RIG NORDIC 1 Rig Number: Date : From.To Hours ;AcbwtyiCodei phaSe Description of Operations 6/25/2000 6~26~2000 00:00 - 02:00 02:00 - 06:00 06:00 - 08:00 08:00 - 12:00 12:00 - 12:30 12:30 - 15:45 15:45 - 16:45 16:45 - 17:30 17:30 - 18:30 2.00 RIGU 4.OO RIGU 2.00 RIGU 4.OO RIGU 0.50 RIGU 3.25 RIGU 1.00 RIGU 0.75 KILL PROD1 PROD1 TREE PROD1 PROD1 PROD1 PROD1 PRODI PROD1 1.00 KILL PROD1 18:30 - 19:30 1.00 KILL PROD1 19:30 - 20:00 20:00 - 20:30 20:30 - 22:30 22:30 - 23:59 00:00 - 00:15 00:15 - 01:30 0.50 KILL 0.50 KILL 2.00 KILL 1.48 KILL PROD1 PROD1 PROD1 PROD1 0.25 KILL PROD1 1.25 KILL PROD1 01:30 - 02:15 0.75 KILL PROD1 02:15 - 02:45 02:45 - 03:00 03:00 - 03:45 03:45 - 04:00 04:00 - 05:00 05:00 - 07:00 07:00 - 08:00 08:00 - 09:00 09:00 - 11:30 11:30- 14:00 14:00- 15:00 15:00 - 17:00 0.50 KILL PROD1 0.25 KILL PROD1 0.75 KILL 0.25 KILL PROD1 PROD1 1.00 DRILL FILL PROD1 2.00 DRILL FILL PROD1 1.00 DRILL FILL PROD1 1.00 DRILL FILL PROD1 2.50 DRILL FILL PROD1 2.50 STWHIP FILL PROD1 1.00 STWHIP PROD1 2.00 STWHIP FILL PROD1 MIRU. Accept rig 02:00 hrs. Spot equipment. NU BOP's. Install non-return valve in kill line. Attempt BOP test. Tree valves leaking. Grease & work. Pressure test BOPE. Witness waived by Jeff Jones. Safety meeting -- RU injector. Pull injector from stabbing box. Install gooseneck. Stab pipe. Change packoff. Open well. WHP = 340 psi. Bullhead kill well with 200 bbls SW at 5 BPM; 2350 psi WHP; 750 psi lAP. Bullhead 205 bbls FIo-Pro mud. Final conditions: 7.0 BPM; 1950 psi WHP; 950 psi lAP. No P-response when FIo-Pro hit formation. Bleed pressure and monitor well. Slight blow, no liquid. Bleed IA to LDF (230 psi).Continued slight blow. SI tubing and pressure built up to 30 psi in 10 min. Still appears to be some gas entrained in mud in wellbore. Pump dart and fill coil with FIo-Pro. Coil vol from dart = 53.5 bbl. MU nozzle and Dowell drilling package. Stab injector. RIH to circ and cond mud and get residual gas out of hole. POH and circ btms up. Mud returns look clean coming from gas buster. 3.2 bpm 2380 psi. POH circulating thru gas buster. Observe well. Slight intermittent flow. Bleed down lAP from 450 psi to 250 psi down flowline. SI well and monitor WHP - built from 5 to 75 psi in 30 min. Bleed off pressure. RIH to upper GLM while wo PESOS to bleed IA to 200 psi (got liquid back) to see if there is communication from IA to tubing. Grease crew called to service wing and lateral valves o possible leak from flowline causing PBU on wellhead. CBU thru MM 2.8 bpm @ 2020 psi. lAP incr from 200-300 psi in approx 20 min after bleeding and now has gas on top. 15 min flowcheck. Well appears dead and stable. Suspect that wing & lateral valves were leaking before grease crew serviced them. lAP now stable at 300 psi. POH to pick up drilling assembly. 15 min flowcheck, well is stable - no flow, no gas. Stand back injector. Hold PJSM. - MU drilling BHA #1. RIH. Tag 11173' CTM. PU orient TF to highside. Try drilling. Stalls at 11,173' CTM. PUH and log tie-in at 11,000'. Correct depth (-8'). Gas entrained in mud. Bleed IA from 600 psi to LDF. Mud losses at 10 BPH. RIH. Tagged and bounced thru 11,160' (bottom of window?). Tag 11,162.5'. Try drilling with TF 0 deg. Multiple stalls. Attempt with different TF's. Same tag. Lowside TF tag at 11,153'. If this is top of whipstock, then bit is hanging-up at btm of window at 11162'. IA back above 500 psi. Gas back in mud. Bleed IA. POOH for window dressing BHA. LD Drilling BHA. MU window dressing BHA (straight motor, string mill, used diamond mill). RIH. Tie in to flag (-14'). RIH and tag TD a 11161'. Safety stand down -- Nell and Cory. Dress window and drill formation to 11,170'. Three stalls here. Continue drilling formation to 11172'. Ream across window -- no motor Printed: 8/10/2000 11:13:40 AM iBP AMOCO OperationS Summary Report Page 2 of 4 Start: 6/25/2000 Rig Release: 6/30/2000 Rig Number: Spud Date: End' 6/30/2000 Group: RIG Legal Well Name: D-13 Common Well Name: D-13 Event Name: REENTER+COMPLETE Contractor Name: DOWELL SCHLUMBERGER Rig Name: NORDIC 1 i:~: Date : i From, To: 'Hours iAcbwtyI Code : Phase i Description of Operations 16/26/2000 15:00 - 17:00 2.00 STWHIP FILL PROD1 work. Dry tags clean. 6/27/2000 17:00 - 18:45 1.75 STWHIP FILL PROD1 18:45- 19:00 0.25 DRILL PROD1 19:00 - 19:30 0.50 DRILL FILL PROD1 19:30-20:00 0.50 DRILL PROD1 20:00 - 22:00 2.00 DRILL PROD1 22:00- 22:15 0.25 DRILL PROD1 22:15 - 22:45 0.50 DRILL PROD1 22:45 - 23:15 0.50 DRILL PROD1 23:15 - 23:30 23:30 - 23:59 00:00 - 02:00 02:00 - 02:15 02:15 - 02:30 02:30 - 02:45 02:45 - 03:00 03:00 - 03:15 03:15 - 03:45 03:45 - 04:00 04:00 - 04:45 04:45 - 05:15 05:15 - 05:30 05:30 - 05:45 05:45 - 07:00 07:00 - 07:30 07:30 - 07:45 07:45 - 08:30 08:30 - 08:45 08:45- 10:00 10:00- 11:00 11:00 - 13:00 13:00- 14:00 14:00 - 16:45 16:45 - 17:45 17:45 - 19:00 0.25 DRILL PROD1 0.48 DRILL PROD1 2.00 DRILL PROD1 0.25 DRILL 0.25 DRILL 0.25 DRILL 0.25 DRILL 0.25 DRILL 0.50 DRILL 0.25 DRILL 0.75 DRILL 0.50 DRILL 0.25 DRILL 0.25 DRILL 1.25 DRILL 0.50 DRILL 0.25 DRILL 0.75 DRILL 0.25 DRILL 1.25 DRILL 1.00 DRILL 2.00 DRILL 1.00 DRILL 2.75 DRILL 1.00 DRILL 1.25 DRILL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 POOH. PJSM. Re-dress power tongs and LD milling BHA MU drilling BHA #3 wi HYC DS49 bit RIH w/BHA #3. Shallow test Sperry-Sun MWD at 400'. Correct to flag at 11000' (-23'). Tie in to GR marker & correct depth (+10') Orient and go down thru window dry - OK. Bring up pump and tag bottom at 11173'. Drill ahead - get 1 click & drill to 11200'. 2.7/2.7 3100psi 5L. Drill to 11215'. Orient around to 39L. Drill to 11217' & get 1 click to 28L. Drill to 11226'. Get 1 click to 39L. Drill to 11240'. 2.7/2.7 bpm. 2780 psi. 45L. Drill to 11284'. Get clicks to right. 2.6/2.6 bpm. 2690 psi. 51R. Drill to 11355'. ROP 100-120 fph. Short trip up to window & back to bottom. Hole cond good. Drill to 11382'. not holding good orientation with fast drilling. Orient around to 46R & tag btm. 2.6/2.6 bpm. 2900 psi. 29R. Drill to 11388'. Get 1 click. 62R. ROP 120-140 fph. Drill to 11421' - need more build. Orient around to 50R 2.7/2.7 bpm. 2600 psi. 40R. Drill to 11449'. Need to build & land well. Orient around for build only - 17R. 2.7/2.7 bpm. 2790 psi. Drill ahead. ROP 100 fph. Land at 8951' TVD but geology may be 10-12' high. Short trip to window & back to bottom. Hole OK. Drill to 11525' and got stuck. Drilled off and started stacking. PU and were stuck. Cut circ rate and relax pipe after pulling to 65klbs. Pull to 75 klbs and came free - OK. Pull up hole and resume full circ & go back to bottom. Drill to 11650'. Wiper trip to window. Orient for left turn. Drill Orient to hold inclination Drill 100 FPH. Dropping angle even with high left TF (soft sand). No biggy, but need to stay clear of the 21N. Wiper trip to window. Drill, holding desired inclination, to 12030'. Wiper trip to window. Drill. Hard spot 12050'. Cont drilling - 2.7/2.7 bpm. 3030 psi. 163L. Orient to start dropping at 12125'. Some difficulty sliding - adding 1 drum Lubetex. Drill ahead to 12220'. Continued difficulty sliding. Wiper trip to window to clean up hole and try to improve sliding - didn't note improvement with Lubetex addition. RIH to bottom. Continue drilling oriented down looking for HOT in samples. Sliding better after short trip. Est HOT 12220-12230'. Drill to 12278'. Printed: 8/10/2000 11:13:40 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-13 D-13 Spud Date: REENTER+COMPLETE Start: 6~25~2000 End: 6~30~2000 DOWELL SCHLUMBERGER Rig Release: 6/30/2000 Group: RIG NORDIC 1 Rig Number: :::iDate :i From,:To i H°urs i:ActiVityjCode! Phase i Description of Operations 6~27~2000 19:00 - 20:00 1.00 DRILL PROD1 20:00 - 21:00 6~28~2000 612912000 21:00 - 22:00 122:00 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 01:30 01:30 - 04:00 04:00 - 04:15 04:15 - 05:00 05:00 - 07:00 07:00 - 08:45 08:45 - 10:45 10:45- 11:15 11:15- 11:30 11:30- 15:00 15:00- 15:45 15:45 - 17:45 17:45 - 18:30 18:30 - 21:15 21:15- 21:30 21:30 - 22:00 22:00 - 22:20 22:20 - 22:55 22:55 - 00:00 00:00 - 01:15 01:15 - 01:45 01:45 - 02:00 02:00 - 02:30 02:30 - 05:00 05:00 - 10:15 10:15- 11:30 11:30- 13:15 13:15 - 13:30 13:30 - 14:30 1.00 DRILL PROD1 1.00 DRILL PROD1 1.00 DRILL PROD1 1.00 DRILL PROD1 0.50 DRILL PROD1 1.00, DRILL PROD1 2.50 DRILL PROD1 0.25 EVAL PROD1 0.75 EVAL PROD1 2.00i EVAL PROD1 1.75: EVAL PROD1 2.00 EVAL PROD1 0.50: CASE PROD1 0.25 CASE PROD1 3.50 CASE PROD1 0.75 CASE PROD1 2.00: CASE PROD1 0.75 CASE PROD1 2.75 CEMT PROD1 0.25 CEMT 0.50 CEMT 0.33 CEMT 0.58 CEMT 1.08 CEMT 1.25 CEMT O.5O CEMT 0.25 CEMT 0.50 CEMT 2.50 CEMT 5.25 CEMT 1.25 CEMT 1.75 CEMT 0.25 CEMT 1.00 CEMT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Continued difficulty sliding. Pull up hole to clean up shales. Geologist looking at samples to confirm top HOT. Try to drill - no go. Wiper trip to window to try and clean up hole enough to make hole to 12300'. Top HOT at 12230' & want to try and perf right to top HOT. Tied-in with GR. Added 17 ft to CTD. RIH to TD. Tagged TD at 12,289 FT. Stacking wt. Added 2 drums Lubetex. Very slow drilling Drilling, ream bottom 100 ft of hole. Slow rop. Call TD at 12,290' Ream back to window. POOH. Lay out BHA. Bit worn out [6-4-WT-A-X-I-PR] Safety Meeting regarding logging BHA. M/U PDS Memory Induction / GR logging tools. RIH with PDS Memory Induction / GR logging tools to 10900'. Set start depth & log down at 30 fpm - tag bottom at 12300' uncorrected. POH logging at 30 fpm up to 10500'. POH with logging tool. Stand back injector. LD tools. Final corrected TD from DIL/GR log was 12294 ft BKB. RU to run 2 7/8" liner. Hold PJSM and hazard analysis. Run 78 jts 2 7/8" 6.5# L-80 STL liner. Fill at 10 and 38 jts in. Install deployment sleeve and CTLRT. MU Baker CT conn and stab injector. RIH with liner - 100 fpm in tubing. Get up weight 43 klbs at window. Run in to OH at 50 fpm and tag bottom at 12302' & correct to log TD at 12294' (Corr'n -8'). Reciprocate pipe 2X - pickup clean at 48 klbs. Load 5/8" ball and pump down to release from liner. Pump down at 2.0 bpi 1980 psi. Ball on seat at 51.0 bbl away. Shear out ball seat and release from liner w/3900 psi. PU to confirm released from liner - OK. Displace well to 2% KCL water, recover FIoPro. 2.4 BM, 2400#, clean rig pits. Safety Meeting regarding cementing liner. Batch cement. Cement at 15.8 PPG wt at 21:55 hrs. Press test cement line. Pump 18.0 bbls, 15.8 ppg G CMT with Latex. Install dart, vac hard line, displace dart with rig pump at 3 BPM at 2500 psi. Dart on liner wiper plug at 53.8 bbls [54.1 calc], sheared LWP at 3400 psi, displace cmt at 3.0 bpi at 3400 psi, full returns, Bumped plug at 66.9 bbls [67.1 calc], held 1500 psi test, Bleed to zero, Floats held OK. Press CT to 1000 psi and sting out of liner top, OK. Full cement returns during job. Circ. at liner top, 3.2 bpi, POOH with Baker CTLRT. Flag CT at 8300 ft EOP. POOH. POOH with CTLRT. Lay out Baker liner running tools. Safety Meeting regarding running CSH workstring RIH with CSH workstring in singles. 78 its total. RIH with cleanout BHA on CT. Pump 0.5 bpi at 200 psi. Park nozzle at 9500 ft. DS UCA sample had 0 compressive strength at 05:00 hrs. WOC. Went over 200 psi comp str at 10:15 hrs. RIH into 2 7/8" liner. Tag TD at 12258' uncorrected. Correct to 12250 (-8'). POH laying in 10 bb1150 k LSRV perf pill in liner Safety meeting for pulling CSH workstring POH & stand back CSH workstring. Printed: 8/10/2000 11 ;13:40 AM Bp AMOCO OperationS SUmmary Report : Page 4 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-13 D-13 REENTER+COM PLETE DOWELL SCHLUMBERGER NORDIC 1 Start: 6/25/2000 Rig Release: 6/30/2000 Rig Number: Spud Date: End: 6/30/2000 Group: RIG Date : :':iFrom ,T° i Hours iActvity'COde Phase i : Description of Operations 6/29/2000 14:30- 15:45 1.25 CEMT PROD1 6~30~2000 15:45 - 16:30 0.75 CEMT PROD1 16:30 - 16:45 0.25 PERF PROD1 16:45- 19:15 2.50 KILL TREE PROD1 19:15- 23:15 4.00 KILL TREE PROD1 23:15 - 23:30 0.25 PERF 23:30 - 00:00 0.50 PERF 00:00 - 01:15 1.25 PERF 01:15-02:30 1.25 PERF 02:30 - 02:35 0.08 PERF 02:35 - 04:40 2.08 PERF 04:40 - 05:30 0.83 PERF 05:30- 07:30 2.00 PERF 07:30 - 08:30 1.00 PERF 08:30 - 08:45 0.25 PERF 08:45 - 11:30 2,75 PERF 11:30 - 12:15 0.75 CHEM 12:15- 13:00 0.75 CHEM 13:00 - 16:00 3.00 RIGD PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 pROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Open IA to flowline to bleed off pressure to LP header. IA is liquid packed. Attempt to test liner and lap to 2000 psi for 30 min. lAP tracks up with tbg. Bleed off and bleed IA to LP. SI IA Pressure tbg to 1500 psi. IA tracks up to 1665 psi. 10 min: Tbg -- 1450. IA = 1630 psi. Bring tbg up to 2000 psi. IA tracks up to 2180 psi immediately. At 15 min: Tbg = 1950 psi. IA = 2140 psi. At 23 min: Tbg -- 1940 psi. IA -- 2125 psi. Liner and cement good. Bleed off tubing, lAP tracks down with tubing. Tbg = 0 psi. IA = 250 psi. PJSM & hazard analysis for running perf guns. Attempt to bleed off WHP thru choke. Grease wing and lateral valves. Lateral valve would not hold pressure. Wing holding pressure. Bleed WHP to zero and lAP to 125 psi. Well dead. Double block flowline at skid and bleed press. Flowline press built up from 350 - 550 psi. Trace line and determine communication valve between D-12 and D-13a flowlines was leaking. Shut in D-12 and bleed D-13a flowline pressure to 75 psi. Flowline pressure now steady. D-12 to remain shut in until D-13a well work is completed. Safety Meeting and Hazard analysis for running perf guns. RIH with 34, SWS, 2" Powerjet guns at 4 SPF RIH with SWS, 2" powerjet perf guns, 4 SPF, 60 deg. phasing. RIH with 27 stds of CSH workstring. Kick while trip drill, stab TIW valve. Well secured in 28 sec. RIH with perf BHA on CT. BHA = 2419.4 ft. Tag BPTD of 12,251 ft BKB at 12,261' CTD. Correct to 12,251 ft BKB [-10']. Pump 15 bbls, 150,000 cp new FIoPro. Drop 5/8" steel ball. Displace with KCL water. Position bottom shot at 12,249 ft. Pump 2.2 BPM at 2000 psi. Ball on seat at 55 bbls. Firing head sheared at 3100 psi. POOH with perforating BHA. Fill well across top. Stand back injector. Stand back 1 1/4" CSH workstring. PJSM prior to LD perforating guns. Lay down perforating guns. All shots fired. MU nozzle and checks. RIH to 2000' to freeze protect well with MEOH. POH laying in MEOH at 2:1. Close swab valve. Clean pits. ND and secure BOPE for rig move. Install and test Xmas tree cap. Release rig at 16:00 hours on 06/30/2000. Total time on well was 5 days 14 hours. Printed: 8/10/2000 11:13:40 AM North Slope Alaska Alaska State Plane 4 PBU WOAD Pad D-13A Surveyed: 27 June, 2000 ORIGINAL SURVEY REPORT 21 August, 2000 Your Ref: API-500292044901 Surface Coordinates: 5958181.00 N, 654111.00 E (70° ~7' 33.5779" N, Kelly Bushing: 7f.6fft above Mean Sea Level ~48° 45'08.0862"W) {]RILl. Ifil] Survey Ref: svy9899 North Slope Alaska Sperry-Sun Drilling Services Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth (~) (~) (~) 11100.00 37.120 115.110 8751.22 8822.83 11150.00 36.510 115.845 8791.25 8862.86 11185.40 42.630 109.175 8818.53 8890.14 11238.20 49.570 99.175 8855.17 8926.78 11264.80 52.700 93.905 8871.87 8943.48 11314.60 59.850 91.265 8899.50 8971.11 11358.20 66.530 96.005 8919.16 8990.77 11408.00 71.720 106.905 8936.95 9008.56 11425.60 74.440 109.015 8942.07 9013.68 11453.80 81.560 112.705 8947.93 9019.54 11475.80 87.100 113.585 8950.11 9021.72 11500.60 92.200 114.995 8950.26 9021,87 11530.00 94.310 124.135 8948.59 9020.20 11559.40 94.480 133.095 8946.33 9017.94 11597.80 94.310 141.185 8943.38 9014.99 11653.80 87.100 150.675 8942.69 9014.30 11715.40 91.240 132.925 8943.59 9015.20 11753.60 90.520 126.155 8943.00 9014.61 11786.20 87.010 118.685 8943.71 9015.32 11814.80 86.420 111.525 8945.35 9016.96 11854.40 89.030 102.515 8946.92 9018.53 11885.80 93.250 98.115 8946.30 9017.91 11923.40 91.410 89.325 8944.77 9016.38 11954.00 91.580 82.825 8943.97 9015.58 11999.60 92.720 72.625 8942.25 9013.86 Survey Report for D-13A Your Ref: API-500292044901 Surveyed: 27 June, 2000 Local Coordinates Global Coordinates Nothings Eastings Nothings Eastings (~) 664.10 S 5387.42 E 5957627.49 N 659510.90 E 676.99 S 5414.47 E 5957615.16 N 659538.21 E 685.53 S 5435.30 E 5957607.04 N 659559.21 E 694.63 S 5472.12 E 5957598.70 N 659596.21E 696.96 S 5492,68 E 5957596.79 N 659616.81E 698.79 S 5534.03 E 5957595.81 N 659658.19 E 701.30 S 5572.82 E 5957594.09 N 659697.03 E 710.60 $ 5618.31 E 5957585.73 N 659742.69 E 715.79 S 5634.32 E 5957580.87 N 659758.81 E 725.62 S 5660.07 E 5957571.57 N 659784.76 E 734.22 S 5680.19 E 5957563.38 N 659805.05 E 744.42 S 5702.79 E 5957553.65 N 659827.85 E 758.88 S 5728.29 E 5957539.71 N 659853.65 E 777.16 S 5751.17 E 5957521.91 N 659876.90 E 805.20 S 5777.20 E 5957494.41N 659903.49 E 851.50 S 5808.50 E 5957448.76 N 659935.74 E 899.70 S 5846.44 E 5957401.35 N 659974.65 E 924.00 S 5875.88 E 5957377.66 N 660004.58 E 941.46 S 5903.36 E 5957360,76 N 660032.42 E 953.57 S 5929.20 E 5957349.19 N 660058.51E 965.13 S 5967.00 E 5957338.40 N 660096.53 E 970.75 S 5997.87 E 5957333.41 N 660127.51 E 973.18 S 6035.32 E 5957331.75 N 660165.00 E 971.09 S 6065.82 E 5957334.47 N 660195.46 E 961.42 S 6110.29 E 5957345.05 N 660239.71 E Dogleg Rate (°l~OOft) 1.505 21.026 18.919 19.396 15.017 18.130 22.941 19.245 28.303 25.494 21.335 31.855 30.392 21.010 21.273 29.579 17.820 25.310 25.079 23.669 19.412 23.864 21.242 22.492 Alaska State Plane 4 PBU_WOA D Pad Ve~ical Section (fi) 5416.74 5445.72 5467.78 5505.65 5526.29 5567.25 5605.83 5652.25 5668.95 5696.08 5717.46 5741.56 5769.31 5795.20 5826,00 5865.39 5911.65 5945.11 5975.37 6003.01 6O42.3O 6073.68 6110.93 6140.50 6182.38 Comment Tie-on Survey Window Point MWD Magnetic Continued... 21 August, 2000 - 6:55 - 2 - DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for D-13A Your Reft AP1-500292044901 Surveyed: 27 June, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 12047.20 92.280 63.135 8940.17 9011.78 943.53 S 6154.29 E 12084.20 94.130 55.755 8938.10 9009.71 924.77 S 6186.08 E 12121.00 91.850 56.455 8936.18 9007.79 904.27 S 6216.59 E 12159.40 82.440 56.455 8938.09 9009.70 883.11 S 6248.51 E 12192.20 72.690 57.515 8945.14 9016.75 865.67 S 6275.34 E 12236.60 63.810 61.555 8961.59 9033.20 844.75 S 6310.81 E 12290.00 63.810 61.555 8985.15 9056.76 821.92 S 6352.95 E Global Coordinates Nothings Eastings (~) (~) 5957363.83 N 660283.34 E 5957383.25 N 660314.74 E 5957404.36 N 660344.82 E 5957426.18 N 660376.31E 5957444.16 N 660402.76 E 5957465.81 N 660437.81 E 5957489.49 N 660479.46 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Dogleg Rate (°/100ft) 19.939 20.532 6.480 24.505 29,892 21.707 0.000 Alaska State Plane 4 PBU_WOA D Pad Vertical Section Comment (fi) 6222.28 6250.01 6276.16 6303.58 6326.68 6357.63 6394.76 Pr~ected Su~ey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 100.7500 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12290.00ft., The Bottom Hole Displacement is 6405.90ft., in the Direction of 97.372° (True). Continued... 21 August, 2000 - 6:55 - 3 - DrillQuest ~.05.04e Sperry-Sun Drilling Services Survey Report for D-13A Your Ref: API-500292044901 Surveyed: 27 June, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA D Pad Comments Measured Depth {ft) 111o0.00 11150.00 12290.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8822.83 664.10 S 5387.42 E 8862.86 676.99 S 5414.47 E 9056.76 821.92 S 6352.95 E Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 11150.00 8862.86 To Measured Vertical Depth Depth (ft) (ft) 11150.00 8862.86 12290.00 9056.76 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro MWD Magnetic August, 2000.6:55 - 4 - DrillQuest 1.05.04e TRANSMITTAL _ To: State of Alaska AOGCC Lori Taylor 300t Porcupine St. Anchorage, Alaska 99501 RE · Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of ' Robert Richey POS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 BP Exploration (Alaska), Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99508 LoG .DIGITAL _MYLAR/ BLUE LINE REPORT WELL DATE 'TYPE OR SEPIA PRINT(S) OR OD-ROM FILM BLUELINE D-13a Open Hole I I 1 Res. Eval. CH I I 1 .. Mech. CH Caliper Survey I Rpt or nr~ %lEr~ I BL m I~ELE V 06 Print Name: L.) Nas._ka Oil & Gas Cons. Commission Anchorage ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK 99734 Phone:(907)659-2307 Fax:(907)659-2314 E-mail: Ixlsprudhoe~NA800.nct Wcbsit¢: wv.,-,:,,, mcmorv!ogzcZOLt~. ALASKA OIL AND GAS CONSERVATION COPlPlISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit D- 13A BP Exploration (Alaska) Inc. Permit No: 200-081 Sur Loc: 2820'SNL, 1067'WEL, Sec. 23, T1 IN, R13E, UM Btmhole Loc. 3665'SNL, 5240'EWL, Sec. 24, T1 IN, R13E, UM Dear Mr. Stagg: 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 20 AAC 25 035. 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. Sincerely, Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~"~'~ day of June, 2000 dlf/Enclosures cc; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . --- STATE OF ALASKA - - ~. "' ALASK,~ iL AND GAS CONSERVATION COMI. _,SION '- ' PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Ddll [] Reddll lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 71.61' AMSL Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028285 4. Location of well at surface ,/' ~" ../' 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2820' SNL, 1067' WEL, SEC. 23, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 3401' SNL, 4114' EWL, SEC. 24, T11N, R13E, UM D-13A Number 2S100302630-277 At total depth 9. Approximate spud date 3665' SNL, 5240' EWL, SEC. 24, T11N, R13E, UM 06/08/00 Amount $200,000.00 12. Distance to nearest property line !13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028305, 38' MDI No Close Approach 2560 12216' MD / 8960' TVD 16. To be completed for deviated wells 117. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11179' Maximum Hole Angle 92 o Maximum surface 2194 psig, At total depth (TVD) 8800' / 3250 psig . ._ 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casinq Weiqht Grade Couplinq Lenqth MD TVD MD TVD (include staqe data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 3898' 9930' 7915' 12216' 8960 67 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. - ............ ' Present well condition summary . Total depth: measured 11580 feet Plugs (measured) r,'., ~,,, ~ 4 2000 true vertical 9220 feet /': Effective depth: measured 11532 feet Junk (measured) .P..~[~! Oil & true vertical 9179 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 14 cu yds Arctic Set 110' 110' Surface 2660' 13-3/8" 3855 cuft Permafrost II 2684' 2684' Intermediate 10437' 9-5/8" 1472 cu ft Class 'G', 130 cuft PF 'C' 10461' 8347' Production Liner 1645' 7" 425 cuft Class 'G' 9933' - 11578' 7989' - 9218' ORIGINAL Perforation depth: measured Open: 11311' - 11350' Sqzd: 11214'- 11224', 11240'- 11270', 11281'- 11311', 11311'- 11350' true vertical Open: 8994'- 9026' Sqzd: 8915' - 8923', 8936'- 8960', 8969' - 8994' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foreg~n~is true and correct to the best of my knowledge Signed Ted Stagg ,,,,,,,~~ Title CT Drilling Engineer Date _~//oo Permit Number JAPINumber v,/ J A. Dproval Date J See cover,otter ~ -- ~-~ ~ J 50- 029-20449-01 ~:~ ~ _-~-- ~ for other requirements Conditions of Approval: Samples Required [] Yes ,~No Mud Log Required [] Yes .[~ No Hydrogen Sulfide Measures J~'Yes [] No Directional Survey Required .l~l'Yes [] No Required Working Pressure for BOPE r-i 2K; [] 3K; [] 4K; ~ 5K; [] 10K; [] 15K Other: ~~ ~ by order of Approved By OI~[GIN,~ ~,-. ~¢ Commissioner the commission Date ~.-"2'" -.~'"~~ Form 10-401 Rev. 12-01-85 D Taylor Seamou~ Submit In Triplicate BPX D-13a Sidetrack Summary of Operations: D-13 is being sidetracked to target lower Zone 2 reserves. This sidetrack will be conducted in two phases. Phase 1: Set whipstock, cement perfs, mill window: Planned for June 1-4, 2000· · A Tubing Integrity Test will be performed. · A whipstock drift was run on 5/18/00. · A Kinleycaliper was run on 5/22/00. · E-Line will be used to set the whipstock at approx. 11,170' MD. · Service coil will be used to cement perfs and mill the window. Phase 2: Drill and Complete sidetrack: Planned for June 8, 2000. Drilling coil will be used to drill and complete the directional hole as per attached plan. Mud Program: · Phase 1: Seawater · Phase 2: FIo-Pro (8.6 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 9,930' MD and cemented with approx. 12 bbls. cement to bring cement 200 ft above the window. The liner will be pressure tested to 2200 psi and perforated with coiled tubing conveyed guns. Well · · · Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray Icg will be run over all of the open hole section. Both Resistivity and CNL logs will be run. Hazards No faults or lost circulation are expected. Res. pressure is normal. Reservoir Pressure Res. pressure is approx. 3250 @ 8800ss. Max. surface pressure with gas (0.12 psi/ft) to surface is 2194 psi. TREE: 6" MCEVOY WELLHEAD: FMC ACTUATOR: AXELSON D..-13a Pro 13-3/8", 72#/ft, L-80, BTRS 12,684' I KOP: 2800' MAX ANGLE: 52o/5900' 4-1/2", 12.6#/ft, L-80, BTRS TUBING TUBING ID: 3.958" CAPACITY: .01522 BBL/FT FOC I 9862'195/8" x 4.5" TIW HB-BP-T PKR I 9911' I TOP OF 4.5" TBG STUB TOP OF 19,933,I 7" LINER 9-5/8", 47#/ft, 110,461' L-80, BTRS Top of Whipstock approx. 11,170'. 2 7/8" liner cemented to approx. 200 ft above the window. Cement to be downsqueezed past the whipstock PERFORATION SUMMARY REF LOG' SWS- BHCS- 6-5-80 SIZE SPF INTERVAL CF~EN/SQZ'D 3 1/8" 4 11,214 - 11,224' SQZD/3-28-89 " 4 11,240 - 11,270 ..... " 4 11,281 - 11,311 ..... " 4 11,311 - 11,350' Sqz/Reperf PBTD 111,532'1 7", 29#/ft, L-80, BTRS Completi . n KB ELEV = 71.61' BF ELEV = 47.91' 4.5" HES HXO SSSV NIPPLE ( 3.813" ID ) 2233' GAS LIFT MANDRELS: 4.5" X 1.5" HES TB W/RA LATCH ( 3.857" ID ) NO. MD(BKB) TVD(SS) ANG. 2 4384' 4178' 42 1 8322' 6766' 47 HESX-NIPPLE (3.813" ID) I 9851' 4.5" HES X-NIPPLE (3.813" ID) (HIGH PRESSURE SERVICE) ! -- CUSTOM OVERSHOT ASSY I 9917' 9-5/8" PACKER w/"X" I9897' ( TIW )(3.813"1D) 4 1/2 ", 12.6 #/f, L-80 TAILPIPE 4 1/2 .... X"NIPPLE I (OTIS) (3.813" ID) 9961' 4 1/2" "XN" NIPPLE I (OTIS) (3.725" ID) , 9982' 4 1/2" TBG TAIL I 9995' ( OTIS SOS )(3.820"1D) (ELMD) D-13 I I I 1,500 500 -5OO ,500 5,000 5,500 6,000 6,500 7,{ X distance from Sfc Loc -2,500 IWell Name D-13 I 6,365 ft CLOSURE Distance Az 96 de~l NEW HOLE E/W (X) N/S (Y) Kick Off 5,443! -573 TD 6,325 -713 State Plane 660,436 5,957,468 Surface Loc 654,111 5,958,181 DLS deg/100 Tool Face Len~lth Curve 1 6 0 ~0 Curve 2 20 -13 278 Curve 4 22 -90 400 Curve 5 22 180 26 Curve 6 22 140 125 1,039 Drawn: 5/23/2000 14:54 Plan Name: Case 105 D-13 Vertical Section 8650 8700 875O 88OO 885O 89OO 895O 9OOO 9O5O Path Distance(Feet) 0 500 1,000 1,500 2,000 I I I Angle@K.O.= 36 deg MD:11179 ~*~8,952~ Marker Depths (~Ori~l Wellbore TZ3 TZ2C 8,952 8,930 8,690 Ift TVD 8,7so1 8,952 Irt TVD 8,930 Ift TVD Kick Off 8,815 ft TVD 11,179 ft MD Deprtr (~KO 5,488 ft MD KO Pt 11,1791 MD New Hole 1037I I Total MD 12,216I TVD TD 8,9601 Curve 1 iCurve ~ DLS d%1/100 6 2O Tool Face -13 22 -90 22 180 22 140 Len~lth 3O 278 400 26 125 1,o39 Drawn: Plan Name: 5/23/2000 14:54 Case 105 2 3/8" CT --~ Lubricat°r t I D-13a CT Drilling & Completion BOP LLI 1 2II 3S" 22.5" 18" 7 1/16" / Annular I 7 1/16" Pipe/Slip ~ 2 3/8" ..... , .... I 1 [ 1/16" X 5,000 psi ~ I Slips ~ = 2 7/8" 7 1/16" Pipe ~ ~ 2 3/8" ~ ~.' ~ ~'~- il ~',~' ~ 2000 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 50400 C¼050400 I00. O0 100. O0 HANDLZNO INST' S/H TERRIE X 462[ FIRST NATIONAL:EIANK .OF ASHLAND :AN:APF~IATE. OF i. NATIONAL CITY BANK C£EVELAND. OHIO :: .: . i:.:i:-56.389 · 412 No. H1684:95 ,.:.. CONSOLIDATED COMMERCIAL 'ACOOUNT ':: · 001&B4~75 · AY 1'*************************************** US DOLLAR .. . -!;;~'i::: ii:.! ;::i? ii:-i::;f ':::i:i'::-;!':-? DATE :.i::';::i:: :i:i:'.::';'i' : :' ..AMOUNT ANCHORAGE AK 99501 ,' l, r=[; t, cl 5,' ':0 t, l, ilo iii; cl 5'.' 00[; h t, I, /- STATE OF ALASKA ALASKA ~JIL AND GAS CONSERVATION COMrv~,dSlON APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Alter Casing [] Repair Well [] Change Approved Program [] Operation Shutdown 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2820' SNL, 1067' WEL, SEC. 23, T11N, R13E, UM At top of productive interval 3401' SNL, 4114' EWL, SEC. 24, T11N, R13E, UM At effective depth 3594' SNL, 4537' EWL, SEC. 24, T11N, R13E, UM At total depth 1672' SNL, 4560' EWL, SEC. 24, T11N, R13E, UM [] Plugging [] Time Extension [] Perforate [] Pull Tubing [] Vadance [] Other [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service ..... -'_ 4 6. Datum Elevation (DF or KB) KBE = 71.61' AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number D-13 9. Permit Number 180-021 10. APl Number 50- 029-20449-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Casing Present well condition summary Total depth: measured 11580 feet Plugs (measured) true vertical 9220 feet ORIGINAL Effective depth: measured 11532 feet Junk (measured) true vertical 9179 feet Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 14 cu yds Arctic Set 110' 110' Surface 2660' 13-3/8" 3855 cu ft Permafrost II 2684' 2684' Intermediate 10437' 9-5/8" 1472 cu ft Class 'G', 130 cu ft PF 'C' 10461' 8347' Production Liner 1645' 7' 425 cu ft Class 'G' 9933' - 11578' 7989'- 9218' Perforation depth: measured Open: 11311'- 11350' Sqzd: 11214'- 11224', 11240'- 11270', 11281'- 11311', 11311'- 11350' true vertical Open: 8994'- 9026' Sqzd: 8915' - 8923', 8936' - 8960', 8969' - 8994' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, to 9995' Packers and SSSV (type and measured depth) 4-1/2" HES 'HXO' SVLN at 2233'; 9-5/8" HB-BP-T TIW packer at 9862'; 9-5/8" TIW packer at 9897' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation June 1, 2000 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Ted Stagg, 564-4694 15. [] Detailed Operations Program [] BOP Sketch Status of well classifications as: [] Oil [] Gas r-I Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17.'1 hereby certify that the fore~]oi~g is true and correct to the best of my knowledge Signed Ted Stagg~~~-'~/~ Title CT D d I ling Engineer Date IConditions of Approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance .... Mechanical Integrity Test Subsequent form required 10- IAl:,proved ~ order of the Commission Form 10-403 Rev. 06/15/88 Commissioner Date~ '~---~ ~ ~ Submit In Triplicate WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~, ADMINISTRATION WELL NAME ~/_~-/'~.~/~ PROGRAM: exp ~ AP~,~ DATE. ENGINEERING INIT CLASS ~--1/' DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... GEOLOGY 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 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 ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ¼~r~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... ,, dev l/redrll v/ serv wellboreseg~ ann. disposal para req ~ GEOL AREA ~ UNIT# ("~.,//~ ~::,'""C~.) ON/OFF SHORE N Y N N~__ , 31. 32. -~,,~ DATE, 33. ~-, Z '-/. D/.,..) 34. Data presented on potential overpressure zones ........ ,n ~ N Seismic analysis of shallow gas zones .......... ~ Y N Seabed condition survey (if off-shore) ......... .,../~/.. Y N Contact name/phone for weekly progress reports [,~151oratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N 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 GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Commentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 02/17/00)
