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Home My WebLink About209-0447. 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 H-13A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-044 50-029-20559-01-00 10390 Conductor Surface Intermediate Liner Liner 8899 71 2657 8871 654 1978 9310 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 8848 39 - 110 38 - 2695 36 - 8907 8412 - 9066 8412 - 10390 39 - 110 38 - 2695 36 - 8510 8049 - 8659 8049 - 8899 9397 2670 4760 7020 10530 9310 4930 6870 8160 10160 9194 - 10320 5-1/2" 17# x 4-1/2" 12.6# L80 34 - 8466 8767 - 8905 Structural 5-1/2" TIW Packer 8335 7978 Torin Roschinger Operations Manager Brenden Swensen brenden.swensen@hilcorp.com 907.748.8581 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 0028284 34 - 8099 N/A N/A 345 Well Not Online 37640 72 1750 1300 1134 300 N/A 13b. Pools active after work:Prudhoe Oil No SSSV Installed 8335, 7978 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 By Grace Christianson at 11:04 am, Jun 12, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.06.11 20:24:29 - 08'00' Torin Roschinger (4662) JJL 6/13/25 RBDMS JSB 061825 DSR-6/18/25 ACTIVITY DATE SUMMARY 3/30/2025 ***WELL S/I ON ARRIVAL*** RAN 4.61" G-RING, TAGGED DB LOCK @ 2001' MD PULLED 5-1/2" DB LOCK w/ DREAM CATCHER(recovered 3 lugs from lock that fell into lock & 7 small rocks, 5 tabs from collet in lock missing) RAN KJ, 2.29" x 25" SWAGE, S/D @ 8395' SLM, UNABLE TO WORK TOOLS DEEPER RAN 2.29" x 25" SWAGE. S/D @ 8395' SLM, UNABLE TO WORK TOOLS DEEPER (removed kj in toolstring & bha) RAN 2.25" WRP DRIFT, 2.29" x 25" SWAGE (oal=7' 9"), S/D @ 8395' SLM, UNABLE TO WORK TOOLS DEEPER RAN 11' x 2" DUMMY GUNS, 4' 2.25 WRP DRIFT, S/D @ 8395' SLM, UNABLE TO WORK TOOLS DEEPER SET 5-1/2" DB LOCK w/ DREAMCATCHER IN SSSV NIP @ 2001' MD *** WELL LEFT S/I ON DEPARTURE *** 6/5/2025 ***WELL S/I ON ARRIVAL*** R/U SLICKLINE. ***CONTINUED ON 6-6-25*** 6/6/2025 ***CONTINUED FROM 6-5-25*** PULLED DREAMCATCHER FROM 2001' MD. RAN 10' x 2" DUMMY GUNS (2.10" RINGS), 2.26" WRP DRIFT, 1.5" BOWSPRING CENT, AND BULLNOSE; UNABLE TO WORK PAST 8367' SLM. RAN 10' x 2" DUMMY GUNS (2.10" RINGS), 2.20" CENT, AND 1.5" BOWSPRING CENT W/ BULLNOSE; DRIFTED TO DEVIATION @ 9341' SLM. RAN 10' x 2" DUMMY GUNS (2.10" RINGS), 2.24" & 2.20" CENTS, AND 1.5" BOWSPRING CENT W/ BULLNOSE; DRIFTED TO DEVIATION @ 9,341' SLM. ***WELL LEFT S/I ON DEPARTURE*** 6/7/2025 ***WELL SI ON ARRIVAL*** (PLUG AND PERF) MIRU AKEL PT 250/3000PSI FUNCTION WLVS LOG CORRELATED TO SLB MCNL DATED 29-NOV-09 (-2 SHIFT TO REFERENCE LOG) SET NS MAGNA RANGE CIBP WITH BOWSPRING CENT BOTTOM NOSE. PLUG SET MID ELEMENT: 9312' (9310' REFERENCE LOG) CCL STOP: 9301.8' CCL-ME: 10.2', TAG AFTER SET UNABLE TO FALL PAST 8415' ELM WITH GUN. POOH TO TRY NEW CONFIGURATION TOMORROW. NIGHT CAP TESTED ON WLVS LEFT ON TREE. WELL LEFT SI ONDEPARTURE. ***JOB CONTINUED ON 08-JUNE-2025*** Daily Report of Well Operations PBU H-13A Daily Report of Well Operations PBU H-13A 6/8/2025 ***JOB CONTINUED FROM 07-JUNE-20205*** (2" PERF) PT 250/3000PSI LOG CORRELATED TO SLB MCNL DATED 29-NOV-09 (-2 SHIFT TO REFERENCE LOG) PERFORATE 9205-9209' (9203-9207' REFERENCE LOG) 4' 2" 60PHASE 6SPF. CCL STOP: 9197.4' CCL-TS: 7.6', CONFIRM SHOTS FIRED PERFORATE 9196-9205' (9194-9203' REFERENCE LOG) 9' 2" 60PHASE 6SPF. CCL STOP: 9186.7' CCL-TS: 9.3', CONFIRM SHOTS FIRED RDMO ELINE ***WELL SHUT IN ON DEPARTURE*** JOB COMPLETE Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/05/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241217 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 8/17/2024 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 9/26/2024 YELLOWJACKET PERF-GPT BCU 24 50133206390000 214112 8/19/2024 YELLOWJACKET PERF BCU 25 50133206440000 214132 9/27/2024 YELLOWJACKET PLUG-PERF BLOSSOM 1 50133206480000 215015 9/30/2024 YELLOWJACKET GPT-PLUG-PERF HV B-17 50231200490000 215189 9/23/2024 YELLOWJACKET GPT KU 24-7 50133203520100 205099 10/3/2024 YELLOWJACKET PERF KU 13-06A 50133207160000 223112 12/5/2024 AK E-LINE Plug Setting KU 22-6X 50133205800000 208135 12/8/2024 AK E-LINE Perf KU 23-07A 50133207300000 224126 12/7/2024 AK E-LINE CBL MPU L-17 50029225390000 194169 10/5/2024 YELLOWJACKET PERF MPU R-103 50029237990000 224114 10/14/2024 YELLOWJACKET CBL MPU C-23 50029226430000 196016 11/29/2024 AK E-LINE Plug/cement MPU D-01 50029206640000 181144 11/26/2024 AK E-LINE Perf PBU 13-24B 50029207390200 224087 9/26/2024 YELLOWJACKET CBL PBU 06-07A 50029202990100 224043 9/29/2024 BAKER MRPM PBU 06-18B 50029207670200 223071 10/1/2024 BAKER MRPM PBU 07-32B 50029225250200 204128 10/28/2024 BAKER SPN PBU 14-32B 50029209990200 224073 10/12/2024 BAKER MRPM PBU H-13A 50029205590100 209044 10/23/2024 BAKER SPN PBU L2-20 50029213760000 185134 10/7/2024 BAKER SPN PBU L3-22A 50029216630100 219051 10/9/2024 BAKER PEARL 10 50133207110000 223028 9/25/2024 YELLOWJACKET GPT-PERF PEARL 11 50133207120000 223032 8/29/2024 YELLOWJACKET GPT-PLUG-PERF SRU 241-33 50133206630000 217047 8/23/2024 YELLOWJACKET PERF Please include current contact information if different from above. T39863 T39864 T39865 T39868 T39869 T39870 T39871 T39872 T39873 T39875 T39874 T39867 T39866 T39876 T39877 T39880 T39878 T39879 T39881 T39882 T39883 T39884 T39885 T39886 T39887 PBU H-13A 50029205590100 209044 10/23/2024 BAKER SPN Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.18 08:35:44 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, September 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC H-13A PRUDHOE BAY UNIT H-13A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/25/2024 H-13A 50-029-20559-01-00 209-044-0 N SPT 7978 2090440 2500 1590 2734 2705 2692 0 0 0 0 OTHER P Brian Bixby 7/31/2024 CMIT-T x IA as per Sundry 324-234 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT H-13A Inspection Date: Tubing OA Packer Depth 1570 2755 2691 2662IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240731140911 BBL Pumped:3.3 BBL Returned:3.2 Wednesday, September 25, 2024 Page 1 of 1 9 9 9 9 9 9 9 99 99 9 9 9 9 2LOSURGXFHU James B. Regg Digitally signed by James B. Regg Date: 2024.09.25 15:45:53 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, September 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC H-13A PRUDHOE BAY UNIT H-13A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/25/2024 H-13A 50-029-20559-01-00 209-044-0 N SPT 7978 2090440 2500 601 2750 2662 2632 0 0 0 0 OTHER P Brian Bixby 7/31/2024 MIT-T as per Sundry # 324-234. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT H-13A Inspection Date: Tubing OA Packer Depth 534 653 671 671IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240731140631 BBL Pumped:3.4 BBL Returned:3.3 Wednesday, September 25, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 9 MIT-T Sundry # 324-234 James B. Regg Digitally signed by James B. Regg Date: 2024.09.25 15:41:09 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, August 30, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC H-13A PRUDHOE BAY UNIT H-13A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2024 H-13A 50-029-20559-01-00 209-044-0 N SPT 7978 2090440 2500 629 0 OTHER F Kam StJohn 7/26/2024 MIT-T per Sundry 324-234. Started Pumping and at about 5 bbls away noticed pressure was not increasing; increased rate to 1 bbl/min and pressure came up to 1330 psi. When shut down pressure dropped off steadily. Well was pretested (non witness) the day before to 2750 psi (4 bbls in, 3 bbls out) and passed. Believe wireline plug not holding. Troubleshooting next with wireline. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT H-13A Inspection Date: Tubing OA Packer Depth 351 1330IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240728120720 BBL Pumped:20 BBL Returned: Friday, August 30, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 2LO3URGXFHU,$UHPHGLDOFHPHQW MIT-T per Sundry 324-234 James B. Regg Digitally signed by James B. Regg Date: 2024.08.30 15:41:13 -08'00' 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 H-13A IA Cement Repair Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-044 50-029-20559-01-00 10390 Conductor Surface Intermediate Liner Liner 8899 71 2657 8871 654 1978 10353 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 8902 39 - 110 38 - 2695 36 - 8907 8412 - 9066 8412 - 10390 39 - 110 38 - 2695 36 - 8510 8049 - 8659 8049 - 8899 8386 2670 4760 7020 10530 None 4930 6870 8160 10160 9370 - 10320 5-1/2" 17# x 4-1/2" 12.6# L80 34 - 8466 8883 - 8905 Structural 5-1/2" TIW Packer 8335 7978 Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 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 0028284 34 - 8099 IA from 5960' - 8335'MD Pump 104-bbls 15.8-ppg Class G Cement. Final Treating pressure = 2700-psi 393 526 18897 42528 816 32 1080 1800 1880 1170 324-234 13b. Pools active after work:Prudhoe Oil No SSSV Installed 8335, 7978 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 By Grace Christianson at 12:42 pm, Aug 21, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.08.21 11:04:10 - 08'00' Torin Roschinger (4662) WCB 11-6-2024 DSR-8/21/24 RBDMS JSB 082824 ACTIVITY DATE SUMMARY 4/11/2024 ***WELL S/I ON ARRIVAL*** (SET 4.5" PLUG) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH RIH W/CH/ 2.75''-CCL/BAKER #10 SETTING TOOL/4.5" PLUG TO SET PLUG AT 8345' MD, CCL TO MID ELEMENT 8.4' CCL STOP DEPTH 8336.6' CCL LOG CORRELATE TO CASING TALLY DATED 5-15-1981 GOOD INDICATION OF SET, ELINE COMPLETE, WELL SI, DSO NOTIFIED *** WELL SI ON DEPARTURE *** 5/5/2024 T/I/O = SSV/660/0. Temp = SI. IA FL (Fullbore). No AL, no flowline. IA FL @ 1500' (65.7 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:45 5/21/2024 T/I/O = 891/154/2 Circ well to diesel pre-cement retainer (Cement squeeze) Pumped 600 bbls of diesel down tubing taking returns from IA to H-13 flowline behind wellhouse. Take sample on outlet of choke and have good diesel at surface. Shut in and oumped 4.6 bbls to pressure T/IA to 1500 psi. T/IA lost 23/20 psi in 5 mins. ***Job Continued to 05-22-2024*** 5/22/2024 Freeze protect flowline- Pumped 9 bbls 60/40 and 82 bbls Crude into FL for FP. Pressured FL to 1000 psi. Final WHPs' 150/143/13. Pad op notified upon LRS departure. 5/23/2024 ***WELL SI ON ARRIVAL*** ***JOB POSTPONED*** BEGIN RIG UP HAD ISSUES WITH PCE. DECISION MADE TO RD, TRAVEL TO TAKE BACK TO SHOP. *** JOB CONTINUED ON 5-24-24 *** 5/24/2024 *** JOB CONTINUED FROM 23-MAY-24 *** PT 250 LOW AND 2500 PSI HIGH RIH. 1-7/16" FH/3-1/8" CCL/ BAKER 20/ CEMENT RETAINER. MAX OD: 4.37" OAL: 15' WEIGHT: 300# SAT DOWN AT 8325' AND DID NOT TRY TO WORK THROUGH. WAS STILL ENOUGH SPACE TO PULL INTO SETDEPTH. CCL - MID ELEMENT: 9.8' CCL STOP DEPTH: 8305.2' MID ELEMENT DEPTH: 8315' LOG CORRELATED TO TUBING TALLY DATED 5-15-1981. *** JOB COMPLETE*** 7/10/2024 TFS U4 (Assist coil) Travel to location. Standby for coil *Job continues to 7-11-24* Daily Report of Well Operations PBU H-13A Daily Report of Well Operations PBU H-13A 7/11/2024 LRS #1 1.75" Coil Tubing .156" WT. Job Scope = Cement IA, Mill Plugs and Cement Road from DS05 to H Pad. MIRU. MU & RIH w/ YJ BHA knuckle, centralizer, knuckle, & HES Centalizer & 5-1/2 Stinger. MIRU HES Cmt. Tagged GLM #8 @ 6600' CTM. Could NOT work past dry or pumping. POOH. Remove Btm knuckle and add spacer pups. RIH. Tag Cement Retainer @ 8270' CTM. PT CT by Tbg Annulus to 1000 psi - good. Verify Circ down CT up IA. Pump 10 bbl surfactant pill followed by cement. ***job continued 7/12/24*** 7/11/2024 *Job continues from 7-10-24* TFS U4 (Assist Coil) Pumped 40 bbls of diesel to assist coil as directed *Job continues to 7-12-24* 7/12/2024 *Job continues from 7-12-24* TFS U4 (Assist Coil) Pumped 895 bbls of KCL and 15 bbls of Powervis to assist coil as needed *Job continues to 7-13-24* 7/12/2024 LRS #1 1.75" Coil Tubing .156" WT. Job Scope = Cement IA, Mill Plugs and Cement ***Job continued from 7/11/24*** Pumped 104 bbls o 15.8 ppg class g cement down the coil and up the IA Estimated cement top in the IA 5954'. Laid in 1 bbl on top of the retainer. POOH. Pumped 5 bbl gel pill folloed with a flush of the coil.Stand by for cement to thicken. MU YJ 4.27" Reverse Clutch Junk Milling BHA. RIH. Stacking wgt @ 8194' CTM. Start Milling Cmt .Milling Cement Retainer @ 8270' CTM / 8315' MD, milled down to 8287 CTMD, the tubing cut. Chased out to surface to downsize mill. MU YJ milling assembly and 3.8" 5 blade rev clutch mill with string reamer. RIH. ***Job continued on 7/13/24*** 7/13/2024 LRS #1 1.75" Coil Tubing .156" WT. Job Scope = Cement IA, Mill Plugs and Cement ***Job continued from 7/12/24*** Continue in hole with YJ milling assembly and string reamer with 3.8" mill. Tag 9289 CTMD. Begin milling. 9300 milled through CBP and list returns. POOH. MU YJ milling assembly w 3.71" venturi burn shoe. RIH and Tag CBP @ 8307' CTM. Start Milling. Push CBP to 8373' CTM. PUH to 8200' CTM. RIH & tagged 11' deeper @ 8384' CTM. PUH to 8200'. RIH @ 8393' CTM without tag or motor wor. PUH to 8200' CTM. RIH dry tag @ 8386 CTM'. RIH pumping @ 8387' CTM see motor work but slight increase in wgt. RIH dry tag again @ 8386' CTM. POOH. BD YJ Venturi/Burnshoe - Recovered Core CBP and cup full of composite pieces, element chunks, & two slip segments. Bullhead 190 bbls Diesel. RDMO ***Job Complete*** 7/13/2024 *Job continues from 7-13-24* TFS U4 (Assist Coil) Pumped 10 bbls of powervis followed by 281 bbls of KCL down the coil. Pumped 3 bbls of 60/40 followed by 190 bbls of DSL down the backside to assist coil as directed. LRS coil left in control of well upon departure 7/23/2024 ***WELL S/I ON ARRIVAL*** DRIFT FOR CBL TO 8,200' MD PERFORM CBL WITH HES MEMORY (GOOD DATA) RAN 5-1/2" BLB, 4.52" GAUGE RING S/D @ 8,216' SLM (60' CORRECTION) SET DDIC SLIP STOP @ 8,185' MD (8,125' SLM) ***CONTINUE 7/24/24*** DRIFT FOR CBL TO 8,200' MD PERFORM CBL WITH HES MEMORY (GOOD DATA) CBL shows TOC at 5960' MD, as is shown on the WBS, below. The proposed IA TOC in Sundry 324-234 was "~6000' MD". So, actual TOC is 40' higher than planned. -WCB Daily Report of Well Operations PBU H-13A 7/24/2024 ***CONTINUE FROM 7/23/24*** SET 4-1/2" G-FISH NECK, DDIC PLUG BODY @ 8,125' SLM / 8,185' MD SET 5-1/2" TOP DDIC SLIP STOP @ 8,120' SLM SET P-PRONG @ 8,125' SLM / 8,185' MD LRS PRESSURED TBG UP TO 2,500 psi, AFTER 2 MINUTES DROPS OFF TO INITIAL PRESSURE PULLED PRONG PULLED UPPER SLIP STOP PULLED DDIC PLUG BODY (missing element) PULLED LOWER SLIP STOP (3/4 of the element recovered) TAGGED ST #2 @ 8,015' SLM (+49' correction), TATTLE TELL PIN WAS UNTOUCHED, BOTTOM OF RUNNING TOOL WAS A LITTLE MANGLED TAGGED ST #3 @ 7,677' SLM (+50' corection), IMPRESSION OF LATCH RAN KJ, 5-1/2" BLB, 4.52" GAUGE RING, BRUSH FROM 8,200' SLM, TO 8,070' SLM (LRS PUMPED 20 BBLS) SET 5-1/2" EVO @ 8,140' SLM / 8,190' MD (6' LIH) ***CONTINUE 4/25/24*** 7/24/2024 T/I/O=452/0/0 (CEMENT SQUEEZE) Assist SL. Pressured up TBGto 2500 psi took 10 bbls DSL then Pressure fell off. LLR 1.3 bpm pumped 4 bbls. Pumped 20 bbls dsl down TBG for B&F. ***Job Continued 7/25/24*** 7/25/2024 ***CONTINUE FROM 7/24/24*** LRS PERFORMS MIT-T TO 2500 PSI GOOD TEST LRS PERFORMED CMIT TXIA TO 2500 PSI GOOD TEST BLEED TUBING & IA DOWN (STOP @ 350 PSI) ***WELL LEFT S/I*** 7/25/2024 ***Job Continued from 7-24-24*** ( CEMENT SQUEEZE ) Assist SL. MIT-T (PASSED) Pumped 4.3 bbls DSL to reach max applied pressure 2750 psi. 15 min Loss 150 Psi. 30 min Loss 36 Psi. Bleed back 3.6 bbls to starting Pressure. Combo TxIA ( PASSED ) Pumped 9.24 bbls DSL to reach max applied pressure 2750 psi. 15 min Loss T-71 Psi IA-109 Psi. 30 min Loss T-28 Psi IA-48 Psi. Bled back 6.8 bbls to strting Pressure. FWHP=375/356/0 7/26/2024 T/I/O = 629/351/0 (ANN-COMM) **AOGCC MIT-T** (Cam Saint-John) **FAILED** Couldnt catch pressure (Target pressure 2500psi) pump all Diesel on location 19.5 bbls to reach 1325 psi start test. 15 min loss of 143 psi 30 min loss of 246 psi total. Valve Positions = SV,WV,SSV = Closed MV = O IA,OA = OTG FWHPS = 612/398/0 7/26/2024 CMIT-TxIA and MIT-T (CEMENT SQUEEZE (OA/IA DWNSQZ)) CMIT-TxIA to 2500 psi ***FAIL*** Target = 2500 psi Max Applied= 2750 psi Pump 12.8 bbls crude down Tbg/IA on 3 Failing CMIT-TxIA tests(SEE LOG). On the 3rd test took Tbg/IA to 2703/2759 psi. Tbg/IA lost 7/49 psi in 1st 15 mins and 7/38 psi in 2nd 15 mins for a total loss of 14/87 psi in 30 min test.FAILED. Bleed IA down for MIT-T ***Job Cont to 7-27-24 WSR*** CMIT-TxIA and MIT-T (CEMENT SQUEEZE (OA/IA DWNSQZ)) CMIT-TxIA to 2500 psi ***FAIL*** **AOGCC MIT-T** (Cam Saint-John) **FAILED** LRS PERFORMS MIT-T TO 2500 PSI GOOD TEST LRS PERFORMED CMIT TXIA TO 2500 PSI GOOD TEST Daily Report of Well Operations PBU H-13A 7/27/2024 ***Job Cont from 7-26-24 WSR** MIT-T (CEMENT SQUEEZE (OA/IA DWNSQZ)) MIT-T to 2728 ***FAIL*** Target=2500 psi Max Applied=2750 psi Took Tbg to 2753 psi w/ .4 bbls crude. Tbg lost 21 psi in the 1st 15 mins and 4 psi in 2nd 15 mins for a total loss of 25 psi in 30 min test. FAIL because IA came up 22 psi in 30 min test. Bled Tbg to 400 psi and got back ~4 bbls. Took IA to 2105 psi w/ 3.6 bbls crude. IA lost 115 psi in 1st 15 mins and 34 psi in 2nd 15 mins for a total loss of 149 psi in 30 min test. FAIL due to Tbg coming up 107 psi during test. Bled IA to 400 psi and got back ~3 bbls. Pad Op notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG **FPA Tags hung on MV and IA 7/28/2024 T/I/O = 500/380/VAC. Temp = SI. MIT-T PASSED CMIT-TxIA INCONCLUSIVE. No AL. Flowline disconnected. T & IA FL near surface. Bled TP to BT to 360 psi (FTS). MIT-T PASSED to 2622 psi w/ diesel. Max applied = 2750 psi. Target = 2500 psi. Pumped 3.1 bbls of diesel to pressue tbg from 360 psi to 2728 psi. 15 min loss = 74 psi. 30 min loss = 32 psi. Total test loss 106 psi. CMIT-TxIA (INCONCLUSIVE) to 2727 psi w/ diesel. Max applied = 2750 psi. Target = 2500 psi. Pumped 3.5 bbls of diesel to pressure T & IA from 1465 psi to 2727 psi. 15 min loss TBG/IA = 18/54. 30 min loss TBG/IA = 13/40. 45 min loss TBG/IA = 9/32. Total lossl TBG/IA = 40/126 psi in 45 min. Bled TBG/IA from 2687/2601 psi to 245/0 IN 2 hrs (10.1 bbls Fluid/energized fluid). No change in OA during CMIT-TxIA. Final WHPs = 245/0/VAC SV, WV, SSV = C. MV = O. IA, OA = OTG. 19:00 7/29/2024 T/I/O=259/14/0 CMIT TxIA to 2750 max applied ( Post Cement Squeeze ) 1st attempt held for 1 hr failed. Repressured w/0.8 bbl diesel. 2nd attempt held for 1 hr failed. Bled T/IA to ~500 psi. Bled back 6.5 bbls. Pumped 6.8 bbls diesel for 3rd attempt for 1 hour failed. Bled to 200 psi and got back 7.7 bbls. On 4th test pumped 8.5 bbls DSL to take T/IA to 2731/2751 psi. T/IA lost 67/84 psi in 1st 15 mins and 25/37 psi in 2nd 15 mins for a total loss of 92/121 psi in 30 min test. Bled T/IA to 200/200 psi and got back ~8 bbls. Pad op notified of well status per LRS departure. **FPA Tags hung on MV and IA 7/30/2024 T/I/O = 221/225/0 COMBO MIT-TxIA Max:2750 psi Target:2500 psi First Test: **FAILED** Pumped 7.2 bbls of 50*F DSL down TBG and IA to reach max psi of T- 2758 psi / IA- 2764 psi. After first 15 min TBG lost 66 psi @ 2692 & IA lost 65 psi @ 2699. After second 15 min TBG lost 36 psi @ 2656 psi & IA lost 36 psi @ 2663 psi. After third 15 min TBG lost 28 psi @ 2628 psi & IA lost 28 psi @ 2635 psi. Bleed back to 500 psi. Bled back 6.1 bbls. Second Test: **PASSED** Pumped 6.2 bbls of 50*F DSL down TBG & IA to reach max psi of T-2771psi / IA-2778psi. After first 15 min TBG lost 55 psi @ 2716 psi & IA lost 55 psi @ 2723 psi. After second 15 min TBG lost 26 psi @ 2690 psi & IA lost 27 psi @ 2696 psi. Bled TBG & IA to 500 psi. Bled back 6.1 bbls. FWHP = 499/505/0 CMIT-TxIA (INCONCLUSIVE) MIT-T to 2728 ***FAIL*** MIT-T PASSED CMIT-TxIA INCONCLUSIVE. No AL. Flowline disconnected. T & IA FL near surface. Bled TP to BT to 360 psi (FTS). MIT-T PASSED to 2622 psi w/ diesel COMBO MIT-TxIA Max:2750 psi Target:2500 psi First Test: **FAILED** Second Test: **PASSED** Daily Report of Well Operations PBU H-13A 7/31/2024 T/I/O= 601/534/0 AOGCC MIT T PASSED to 2500 psi ( MA=2750 psi ) CMIT TxIA PASSED to 2500 psi ( MA=2750 psi ) ( Witnessed by Brian Bixby ) Pump 3.4 bbls diesel down tbg to 2750 psi. TP lost 88psi 1st 15 min & 30 psi 2nd 15 min. Pumped add'l 3.3 bbls diesel down Tbg & IA to 2734/2755 psi. T/IA lost 29/64 psi 1st 15 min & 13/29 psi 2nd 15 min Bled back 6.5 bbls FWHP's=500/495/0 8/1/2024 ***WELL S/I ON ARRIVAL*** SET CATCHER ON EVO-TRIEVE PLUG @ 8,140' SLM PULLED RK-DGLV FROM STA# 11 @ 4,938' MD. PULLED RK-DGLV FROM STA# 12 @ 3006' MD. SET RK-LGLV IN STA# 12 @ 3006' MD. SET RK-OGLV IN STA# 11 @ 4938' MD. ***CONTINUED ON 8-2-24*** 8/2/2024 ***CONTINUED FROM 8-1-24*** PULLED WHIDDON CATCHER FROM 8133' SLM. PULLED 5 1/2" EVO-TRIEVE PLUG FROM 8140' SLM. SET DREAM CATCHER IN SSSV NIPPLE @ 2,001' MD ***WELL LEFT S/I ON DEPARTURE*** AOGCC MIT T PASSED to 2500 psi ( MA=2750 psi ) CMIT TxIA ( PASSED to 2500 psi ( MA=2750 psi ) ( Witnessed by Brian Bixby ) AOGCC witnessed passing MIT-T and CMIT-TxIA, both to 2500 psi, are COA on Sundry 324-234. -WCB Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 8/7/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240807 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 2-72 50029237810000 224016 6/27/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 7/18/2024 HALLIBURTON RBT END 2-72 50029237810000 224016 7/18/2024 HALLIBURTON TEMP END 2-74 50029237850000 224024 7/20/2024 HALLIBURTON MFC MPU B-24 50029226420000 196009 7/16/2024 HALLIBURTON MFC MPU E-19A 50029227460100 224010 6/22/2024 HALLIBURTON COILFLAG NS-10 50029229850000 200182 7/18/2024 HALLIBURTON MFC NS-10 50029229850000 200182 7/18/2024 HALLIBURTON TEMP NS-32 50029231790000 203158 7/16/2024 HALLIBURTON MFC NS-32 50029231790000 203158 7/15/2024 HALLIBURTON TEMP PBU H-13A 50029205590100 209044 7/23/2024 HALLIBURTON RBT PBU L-246 50029237650000 223078 7/23/2024 HALLIBURTON IPROF PBU R-26B 50029215470100 210025 7/5/2024 HALLIBURTON RBT PBU R-36 50029225220000 194144 6/21/2024 HALLIBURTON RBT PBU V-216 50029232160000 204130 7/11/2024 HALLIBURTON IPROF PBU V-217 50029233340000 206162 7/11/2024 HALLIBURTON IPROF Please include current contact information if different from above. T39365 T39365 T39365 T39366 T39367 T39368 T39369 T39369 T39370 T39370 T39371 T39372 T39373 T39374 T39375 T39376 PBU H-13A 50029205590100 209044 7/23/2024 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.07 13:19:30 -08'00' 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU H-13A IA Cement Repair Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-044 50-029-20559-01-00 341J ADL 0028284 10390 Conductor Surface Intermediate Liner Liner 8899 71 2657 8871 654 1978 8345 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 7987 39 - 110 38 - 2695 36 - 8907 8412 - 9066 8412 - 10390 2320 39 - 110 38 - 2695 36 - 8510 8049 - 8659 8049 - 8899 None 2670 4760 7020 10530 8345 4930 6870 8160 10160 9370 - 10320 5-1/2" 17# x 4-1/2" 12.6# L80 34 - 84668883 - 8905 Structural 5-1/2" TIW Packer No SSSV Installed 8335, 7978 Date: Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 PRUDHOE BAY 5/1/2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.04.19 13:26:30 -08'00' Torin Roschinger (4662) By Grace Christianson at 1:55 pm, Apr 19, 2024 324-234 SFD 4/20/2024 2320 *AOGCC to witness MIT-T and CMIT- T x IA to 2500 psi. * Biennial MIT-T and MIT-IA to 2500 psi. * CBL to AOGCC upon completion. MGR22APR24 10-404 DSR-4/23/24*&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.25 10:30:41 -08'00'04/25/24 RBDMS JSB 042524 IA Cement Repair PBU H-13 PTD:209-044 Well Name:PBU H-13A API Number:50-029-20559-01 Current Status:Not-Operable, TxIA Rig:CT, SL, EL Estimated Start Date:5/3/2024 Estimated Duration:7days Reg.Approval Req’std?10-403 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker First Call Engineer:Aras Worthington Contact:907-440-7692 Current Bottom Hole Pressure:3,200 psi @ 8,800’ TVD (7.0 ppge, based on offsets) Max. Anticipated Surface Pressure:2,320 psi (Based on 0.1 psi/ft gas gradient) Last SI WHP:2,410 psi (3/7/2018) Min ID:2.30” @ 8,417’ MD (Aluminum bushing in CT LT) Max Angle:100 Deg @ 9,793’ MD Brief Well Summary: H-13A is a zone 3 Ivishak GDWFI producer completed in 2009 via CTD. The 5-1/2” tubing showed 75% wall penetration @ 8,326’ MD and was later found to be partially collapsed near this depth in 2019 with a loss of integrity to the IA. CT has successfully milled through the obstruction/parted tubing above the packer, however due to being off-depth CT also milled the tubing tail off leaving a “blunderbuss” WLEG (see caliper snapshots below). SL calipered the entire tubing and verified the above and were able to pull the partially milled-PX prong and the X-plug body. A non-rig workover intervention would return H-13A to production at similar rates to when it went offline in January 2018. Objective: Execute an IA cement job to repair the TxIA and return the well to production. The proposed TOC the IA is ~6,000’ MD which is ~3100’ TVD below the SC shoe and ~1850’ deeper than the estimated top of the UG4 marker @ ~4,151’ MD (depths given per AOGCC CO 736 rules). Integrity Work Completed: o SL set DDIC (retrievable plug) @ 6,176’ MD and achieved a passing MITT to 2535 psi, and a CMIT-TxIA to 2680 psi 12/30/2023 – this verifies that the well will pass MITs with a TOC in the IA of ~6000’ MD. o CT milled through the tubing obstruction/collapse on 2/16/2024 but also inadvertently milled off the tubing tail. o Passing CMIT-TxIA to 2500 psi on 3/6/2024 – this verifies the packer/casing integrity post-milling. o SL calipered the milled section and tubing tail on 3/15/2024 o SL pulled the PX prong and plug body 4/10/24 o EL set a 4-1/2” CBP @ 8,345’ MD to secure the well and prep for the IA cement job on 4/11/24 Post-job Evaluation o MIT-T and CMIT-TxIA o CBL to confirm the Top of Cement (TOC) Long-Term Integrity Monitoring o Biennial MIT-T and CMIT-TxIA o Monitor and Record WHPs daily IA Cement Repair PBU H-13 PTD:209-044 WBL Steps: 1 F PT CBP, CIRCULATE TxIA TO DIESEL 2 E SET CEMENT RETAINER 3 C IA CEMENT JOB, MILL CEMENT AND PLUGS 4 S SET PLUG, MITT & CMIT-TXIA (AOGCC WTNESSED), MEM CBL, PULL PLUG 5 F A/SL; MITT & CMIT-TxIA (AOGCC WTNESSED) 6 WIE ADD BIENNIAL MITT, CMIT-TxIA Procedural steps: Fullbore 1. PT of Tubing x IA to test CBP to 1,500 psi. Five-minute test, no more than 10% pressure loss. Establish LLR if fails. 2. Circulate TxIA with 560 bbls diesel pumping down tubing with returns from the IA. Max tubing pressure 2500 psi. Pump down tubing with returns from the IA to establish LLR from Tubing to IA through the collapsed section of tubing before setting cement retainer. E-Line 3. Set 5-1/2” HES Fasdril SVB cement retainer in the middle of the first full joint of tubing above the packer @ ~8,315’ MD.* *Depth references attached tubing tally of 03/07/2003. Coiled Tubing (1-3/4”) 4. MU HES SVB Fasdril retainer stinger. 5. Displace CT to diesel. Sting into cement retainer. 6. Pressure test the Tbg x CT backside to 1000 psi for five minutes to verify cement retainer is holding and that stinger is engaged. 7. Pump down CT, establish returns up the IA and pump the following schedule: ¾10 bbls surfactant ¾105 bbls 15.8 ppg Class G cement ¾CT volume of FW 8. Un-sting from retainer and lay last 1-bbl of cement on top of the retainer. 9. Reverse cement down to retainer to remove as much cement as possible from the 5-1/2” tubing. 10. POOH. 11. MU motor and 4.40” mill (Note SS @ 8,276’ MD has a 4.437” ID) . 12. WOC until 500 psi compressive strength. Mill out cement retainer and cement down to collapsed section @ 8,332’md. 13. POOH and MU 3.84” Crayola mill, 3.81” String reamer, and 3.80” centralizer (same assembly that was used to mill through the collapsed section the first time). Mill through collapsed section to ~8,340’ MD. POOH. 14. MU 3.80” mill. Mill out cement below the collapsed section and the CBP @ 8,351’ MD. Circulate bottoms-up + 50% with gel sweeps before milling out CBP to remove as much debris/cement from the well as possible before losing the bottom by milling out the CBP. 15. Push CBP remnants down to 8,390’ MD and POOH. This should push the CBP remnants out of the milled-out tubing tail. POOH. 16. Circulate the well to diesel (190 bbls in the 5-1/2” tubing) to assist in well POP. IA Cement Repair PBU H-13 PTD:209-044 Slickline/Fullbore 17. Set 5-1/2” DBP plug in the sliding sleeve @ 8,276’ MD. 18. Log Memory CBL from 8,276’ MD to ~2500’ MD to identify TOC and send log to Aras Worthington for submittal and review by AOGCC. 19. Conduct AOGCC witnessed MIT-T and CMIT-TxIA to 2500 psi. Ensure 24-hour notice provided for AOGCC. 20. Pull DBP plug from sliding sleeve @ 8,276’ MD. Well Diagnostics & WIE 21. Update AKIMS and add biennial MIT-T & CMIT-TxIA. Cement Calculations ¾9-5/8” x 5-1/2” volume from 8,335’ – 6000’ MD: 0.0438 bpf * 2,335’ =102 BBLS Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Tubing tally 4. Caliper Snapshots 5. Sundry Change Form IA Cement Repair PBU H-13 PTD:209-044 Current Wellbore Schematic IA Cement Repair PBU H-13 PTD:209-044 Proposed Wellbore Schematic TOC in IA @ ~6000’ MD IA Cement Repair PBU H-13 PTD:209-044 Tubing Tally IA Cement Repair PBU H-13 PTD:209-044 2018 Caliper (left) vs. 2019 Caliper (right) IA Cement Repair PBU H-13 PTD:209-044 Caliper snapshots of tubing collapse (before milling out with CT) IA Cement Repair PBU H-13 PTD:209-044 IA Cement Repair PBU H-13 PTD:209-044 Caliper snapshots tubing-tail (milled off and belled-out with CT) IA Cement Repair PBU H-13 PTD:209-044 Hi l c o r p N o r t h S l o p e , L L C Hi l c o r p N o r t h S l o p e , L L C Ch a n g e s t o A p p r o v e d W o r k O v e r S u n d r y P r o c e d u r e Da t e : A p r i l 1 2 , 2 0 2 4 Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l H - 1 3 A Su n d r y # : An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a t e d t o t h e AO G C C b y t h e w o r k o v e r ( W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a n g e . St e p Pa g e Da t e P r o c e d u r e C h a n g e HNS Pr e p a r e d By ( I n i t i a ls ) HN S Ap p r o v e d By ( I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : As s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : Fi r s t C a l l O p e r a t i o n s E n g i n e e r D a t e CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20220307 1532 APPROVAL SUNDRY REV1 PTD209-044, Sundry 321-442, H-13A Revision 1 APPROVED Date:Monday, March 7, 2022 3:33:06 PM Attachments:Sundry 321-442 APPROVED REVISION 1 H-13A RWO 10-403 rev1 210917.pdf John, Hilcorp is approved to proceed on Sundry 321-442 revision 1 as described in the attachment. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: John Condio - (C) <John.Condio@hilcorp.com> Sent: Friday, March 4, 2022 4:13 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: RE: [EXTERNAL] PTD209-044, Sundry 321-442, H-13A Revision 1 APPROVED Mel, I would like to make a change to the PBU H-13A RWO program to precut the tubing with Eline prior to the RWO. There is a low probability of the tubing pulling free from the seals and an opportunity to save a likely Eline rig up during workover operations. The approved sundry, attached, already had a contingent step for a tubing cut on-rig. I would like to simply move that step of the procedure to the pre RWO steps. I did not plan to resubmit for a Sundry Revision, unless you deem it necessary. If you are in agreement with this, please respond with your approval and I will include that response with my changes our program here at Hilcorp. Respectfully, John Condio Well Integrity Engineer (Seconded) Hilcorp Energy Company (907) 564-4696 (office) (602) 373-0659 (mobile) From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Friday, September 24, 2021 9:45 AM To: John Condio - (C) <John.Condio@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: [EXTERNAL] PTD209-044, Sundry 321-442, H-13A Revision 1 APPROVED John, The attached revision (Revision #1) to Sundry 321-442 is APPROVED. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Abbie Barker, AOGCC Inspectors From: John Condio - (C) <John.Condio@hilcorp.com> Sent: Monday, September 20, 2021 11:38 AM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Cc: Abbie Barker <Abbie.Barker@hilcorp.com> Subject: FW: [EXTERNAL] Sundry PBU H-13A Mel, I revised the H-13A RWO 10-403 Procedure. Hilcorp plans to use the new Cameron BOP stack, changes are in red and indicated on the Sundry change form. Please email your approval or if you have any questions. Thank you. John Condio Well Integrity Engineer (Seconded) Hilcorp Energy Company (907) 564-4696 (office) (602) 373-0659 (mobile) From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Friday, September 3, 2021 8:38 AM To: John Condio - (C) <John.Condio@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Cc: Brodie Wages <David.Wages@hilcorp.com> Subject: FW: [EXTERNAL] Sundry PBU H-13A Gents, Please see attached approved Change to Approved RWO Program 10-403 for H-13A. Thank you, Abbie From: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov> Sent: Friday, September 3, 2021 8:21 AM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Josh Allely - (C) <josh.allely@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Julie Wellman - (C) <julie.wellman@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Subject: [EXTERNAL] Sundry PBU H-13A Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. RWO: Tubing Swap Well: H‐13A PTD: 209044 API: 50‐029‐20559‐01 Well Name: H‐13A API Number: 50‐029‐20559‐01 Current Status: Not Operable, TxIA Rig: Thunder Bird 1 Estimated Start Date: October 25, 2021 Estimated Duration: 4 days Reg.Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Abbie Barker Permit to Drill Number: 209044 First Call Engr: John Condio 602.373.0659 (M) Second Call Engr: Brodie Dave Wages 713.380.9836 (M) AFE Number: 215‐01688.16.11 Current Bottom Hole Pressure: 3200 psi @ 8800’ TVD (estimated based offsets) Max. Anticipated Surface Pressure: 2320 psi (Based on 0.1 psi/ft gas gradient) Last SI WHP: 0 psi (taken 5/11/2021) Equivalent Brine Weight: 7.3 ppg (estimate + 0.3 ppg SF) Min ID: 3.02” @ 8322’ MD (Partial tubing collapse, PDS caliper 3/8/19) Objective: Restore tubing integrity and return well to production from the Ivishak. Pull existing 5‐1/2” L80 tubing to repair collapsed tubing at ~8322’ and replace with 4‐1/2” L80 tubing. Achieve passing MIT‐IA & MIT‐T Brief Well Summary: H‐13A is a zone 3 Ivishak GDWFI producer that was completed in 2009 by CST. The 5‐1/2” tubing showed 75% wall penetration at 8326’ on a caliper survey and was later found to be partially collapsed near this depth with a loss of integrity to the IA. The workover will return H‐13A to production at similar rates to when it went offline in January 2018. Surface Infrastructure: H‐13A has access to GC2 HP via the 42H header, and GC2 or GC1 LP via the 41H header. If the piggyback well, H‐27B, is shut‐in H‐13A has access to the GC1 annex via the 47H header. Pre‐Rig Prep Work: DHD 1) CMIT‐T x IA to 3000 psi 2) OA Integrity Test to 1200 psi 3) Function all LDS 4) PPPOT‐T & PPPOT‐IC Full Bore: 5) Circulate well from tubing to IA with 1% KCL and diesel FP to 2000’ a. PX plug at 8399’ set on 3/12/18 b. Was able to establish LLR from IA to tubing (assumed thru collapse/tubing failure) at 0.5 bpm at 1650 psi on 3/12/18 Slickline (contingent step): 6) Open sliding sleeve at 8276’ if unable to circulate in previous step Valve Shop: 7) Bleed WHP’s to 0 psi RWO: Tubing Swap Well: H‐13A PTD: 209044 API: 50‐029‐20559‐01 8) Set and test TWC 9) Nipple down tree & tubing head adapter. Inspect lift threads. a. Tubing barriers: tubing tail plug and TWC b. Casing barriers: Production packer and tubing hanger 10) Nipple up BOPE; Annular, 4-1/2” x 7” VBRs, Blinds and flow cross. Proposed Workover Procedure: 11) MIRU Thunder Bird #1 a. Well has TTP at 8399’MD set 3/13/18 b. Tubing has partial collapse above packer/seal assembly at 8322’ MD 12) Test BOPE to 250psi Low/3000psi High, annular to 250psi Low/2500psi High (hold each ram/valve and test for 5‐min). Record accumulator pre‐charge pressures and chart tests. a. Perform Test per Thunder Bird #1 BOP Test Procedure. b. Notify AOGCC 24 hrs. in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test the 4‐1/2” x 7” VBR’s with 4‐1/2’’ & 5‐1/2” test joints. e. Submit to AOGCC completed 10‐424 form within 5 days of BOPE test. 13) Verify well is dead 14) Pull TWC 15) MU landing joint or spear 16) BOLDS and pull hanger to the floor a. PU weights are expected to be ~125K b. 5‐1/2” 17# L80 yield: 397K# 17) If 5‐1/2” tubing is free, circulate bottoms up 18) Pull & laydown 5‐1/2” completion Contingency if tubing does not pull free: 19) RU Eline and cut 5‐1/2” tubing at ~8305’, above collapse 20) Change VBR’s to 2‐7/8” x 5” VBR’s, test with 2‐7/8” & 4‐1/2” test joints, notify AOGCC 24 hours, submit to AOGCC completed 10‐424 form within 5 days of test. 21) RIH with fishing BHA on 2‐7/8” workstring, fish remaining 5‐1/2” tubing and seal assembly 22) POOH and laydown fish 23) Run new completion Contingency if fish does not pull free or if tubing parted near collapse: 24) RIH with bit or packer mill (TBD) on 2‐7/8” workstring 25) Mill through collapse and partially into SBR to set up for WLEG or production overshot 26) Make clean‐out run with casing scraper 27) Run new completion Run New 4‐1/2” Completion 28) Run 4‐1/2” L80 tubing with stacker packer per proposed schematic/tally 29) Land Hanger and reverse in corrosion inhibited 8.4 ppg 1% KCL or equivalent 30) Drop ball and rod and set packer with 3500psi pump pressure. 31) Perform MIT‐T to 3000psi and MIT‐IA to 3000psi charted for 30 minutes 32) Shear valve in top GLM and circulate FP fluid 33) Set TWC 34) Rig down Thunderbird #1 RWO: Tubing Swap Well: H‐13A PTD: 209044 API: 50‐029‐20559‐01 Post Workover Procedure: Valve Shop 35) ND BOPE 36) NU tree and tubing head adapter. 37) Test both tree and tubing hanger void to 500psi low/5000psi high Slickline 38) Pull TWC 39) Pull ball and rod, pull RHC body 40) Set GLV’s per GL engineer 41) Pull 4‐1/2” PX plug at 8399’ Attachments: 1. As‐built Schematic 2. Proposed Schematic 3. BOP Schematic VBR 4. Sundry Revision Change Form RWO: Tubing Swap Well: H‐13A PTD: 209044 API: 50‐029‐20559‐01 As‐built Schematic RWO: Tubing Swap Well: H‐13A PTD: 209044 API: 50‐029‐20559‐01 Proposed Schematic RWO: Tubing Swap Well: H‐13A PTD: 209044 API: 50‐029‐20559‐01 BOP Schematic VBR RWO: Tubing Swap Well: H‐13A PTD: 209044 API: 50‐029‐20559‐01 Changes to Approved Sundry Procedure Date: 9/17/21 Subject: H-13A RWO Sundry #: 321-442 Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) 10,12 ,20 2, 3, 6 9/17/21 REVISED BOPE TEST TO REFLECT NEW CAMERON BOPE WITH U-SHAPED RAM VBR SIZES. UPDATED ATTACHMENT 2 BOPE SCHEMATIC Approval: Operations Manager Date Prepared: Operations Engineer Date 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 H-13A Cut Tubing Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-044 50-029-20559-01-00 10390 Conductor Surface Intermediate Liner Liner 8899 71 2657 8871 654 1978 8399 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 8037 39 - 110 38 - 2695 36 - 8907 8412 - 9066 8412 - 10390 39 - 110 38 - 2695 36 - 8510 8049 - 8659 8049 - 8899 None 2670 4760 7020 10530 8399 4930 6870 8160 10160 9370 - 10320 5-1/2" 17# x 4-1/2" 12.6# L80 34 - 8466 8883 - 8905 Structural 5-1/2" TIW Packer 8335, 7978 8335 7978 Torin Roschinger Operations Manager Josh Stephens josh.stephens@hilcorp.com 907-777-8420 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 0028284 34 - 8099 N/A N/A 393 Well Not Online 18897 816 0 0 1880 0 321-240, 321-442 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 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 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.07.31 14:37:17 -08'00' Torin Roschinger (4662) By Grace Christianson at 11:31 am, Aug 04, 2023 DSR-8/7/23WCB 4-8-2024 RBDMS JSB 080823 ACTIVITY DATE SUMMARY 8/30/2021 Pre RWO inspection: T/I/O = SI/400/0, PPPOT-IC (FAIL) & PPPOT-T (PASS) PPPOT-IC: Stung into IC test void, 600 psi. Bled void to 0 psi. Monitor for 10 min. 0+ psi. Pump through void, good returns. Pressure void to 3500 psi, unable to stabilize pressure, bleed IC-PO pressure to 0. Re-torque IC-PO LDS to 600 ft/lbs. Attempt to pressure test, unable to stabilize psi, bleed IC-PO test void to 0 psi. Suspect secondary Y seal needs re-energized. PPPOT-T: Sting into tubing hanger test void, 0+ psi. Bled void to 0 psi. Monitor for 10 min. 0 psi. Functioned tubing hanger LDS, 3 LDS stuck, ** LDS FREED UP ALL FUNCTION SMOOTHLY**. Re-torque all LDS and gland nuts to 550 ft/lbs. Pressured void to 5000 psi for 30 min test. Lost 125 psi in 1st 15 min. Lost 75 psi in 2nd 15 min for a 30 min total of 200 psi (PASS). Bled void to 0 psi. 8/31/2021 Pre RWO inspection (cont.): T/I/O = SI/400/0, PPPOT-IC (PASS) PPPOT-IC: Stung into IC-PO test port (0 psi). Verify 0 psi in IC-PO packing void. RU packing gun to packing injection port, pump plastic into void to re-energize Y seal to 5000 psi. Pump through test void, good returns. Pressured up IC-PO test void to 3500 psi for 30 min test, lost 75 psi in first15 min, lost 25 psi in second 15 min for 100 psi loss total in 30 minutes (PASS). Bled IC-PO test void to 0 psi. Worked on 3 stuck tubing hanger LDS. Freed up 1 more LDS, functioned out and back in smoothly. Re-torqued LDS and GN to 550 ft/lbs. Remaining 2 stuck LDS are flagged. ** LDS FREED UP ALL FUNCTION SMOOTHLY** Filled tubing hanger test void with Kroil and pressured up to 4500 psi. Leave pressure on test void to help Kroil penetrate LDS thread profile. 9/25/2021 T/I/O = LOTO/450/2. Temp = SI. OA Integrity Test to 1200 psi PASSED (Pre Rig). No AL, flowline, or wellhouse. Temporary scaffloding installed. OA FL @ 70' (4 bbls). Used 5.7 bbls amb Diesel to pressure OA to 1200 psi. OAP decreased 76 psi during the 5 min test. No sign of leaks anywhere on the surface kit. Bled OAP to 0 psi (1.2 bbls). Hung tags. Final WHPs = LOTO/450/0+. SV, WV = C. SSV = LOTO closed. MV = O. IA, OA = OTG. 09:40 9/30/2021 T/I/O = 400/450/80. Temp = SI. TBG & IA FLs (Pre Slickline). No AL or flowline. Rig scaffold installed. TBG FL @ surface. IA FL @ near surface ( ~80', 4 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:00 10/1/2021 ***WELL S/I ON ARRIVAL***(pre-rwo) ATTEMPT TO OPEN 5-1/2" SLIDING SLV @ 8276' MD.(unable to work past) ATTEMPT TO SET 5-1/2" X-CATCHER IN SLIDING SLV @ 8276' MD. SET 5-1/2" DB-CATCHER SUB IN SLIDING SLV @ 8276' MD. PULLED RK-DGLV FROM ST#2 @ 8064' MD. *******ST#2 POCKET LEFT OPEN********* PULLED 5-1/2" DB-CATCHER SUB FROM SLIDING SLV @ 8276' MD. ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** Daily Report of Well Operations PBU H-13A @ SET 5-1/2" DB-CATCHER SUB IN SLIDING SLV @ 8276' MD. () ATTEMPT TO OPEN 5-1/2" SLIDING SLV @ 8276' MD.(unable to work past) Daily Report of Well Operations PBU H-13A 10/4/2021 Circ Out (RWO EXPENSE) CMIT-TxIA to 2890 psi ***PASS*** Pumped 11.5 bbls DSL down Tbg to take Tbg/IA to 3033/2997 psi for CMIT-TxIA. Tbg/IA lost 76/78 psi in 1st 15 mins and 27/29 psi in 2nd 15 mins for a total loss of 103/107 psi in 30 min test. PASS. Pumped 2 bbls 60/40 meth, 596 bbls 1% KCL, 134 bbls 130* DSL down Tbg taking returns from IA to open top tank. U-Tubed FP into IA for 1 hour. Freeze protected harline w/ 5 bbls 60/40 meth. Pad Op notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG 10/4/2021 ***COST PLACEHOLDER*** 3 - DGLV's and Latches, 1 - Shear vlv for completion Invoice # HC10202106 4/5/2022 ***WELL S/I ON ARRIVAL*** JOB SCOPE: WELLTEC TBG CUT. STANDBY FOR WELLTEC. WELLTEC NEEDED FOR CONOCO RIG CUT. ***CONTINUE JOB ON 4/6/22*** 4/6/2022 ***JOB CONTINE FROM 4/5/2022*** JOB SCOPE: WELLTEC TBG CUT. RUN W/WELLTEC 3 5/8'' MECHANICAL CUTTER TAG TOP OF TUBING COLLAPSE @ 8332' CUT 5 1/2'' TBG AT 8327' 5' ABOVE OF TBG COLLAPSE, CCL TO CUTTER HEAD 19.5' CCL STOP DEPTH 8307.5' PRE CUT T/IA/OA 0/0/0psi POST CUT T/IA/OA 0/0/0 psi TOOK ~ 5 MIN TO CUT IN LOW PRESSURE MODE IMMEDIATE STALLS AFTER CUTTING INDICATIING TBG CUT IN COMPRESSION AT SURFACE TATTLE TAIL SHOWED BLADES WENT OUT TO 5.7'' ***JOB COMPLETE*** 4/8/2022 T/I/O = 0/0/0. Temp = SI. CMIT-TxIA PASSED to 3149/3166 psi w/Diesel (pre rig). Max applied = 3200 psi, target = 3000 psi. No AL. TBG and IA FL @ near surface. Used 10.8 bbls diesel to pressure TBG/IA from 0/0 psi To 3191/3198 psi. TBG/IA lost 31/21 psi in 1st 15 min, and 11/11 psi in 2nd 15 min for a total loss of 42/32 psi in 30 min. Bled TBG/IA from 3149/3166 psi to 0/0 psi in 25 min (7.8 bbls). No change in OAP during CMIT. Final WHPs = 0/0/0 SV, WV, MV = C. IA, OA = OTG. 14:00 3/31/2023 T/I/O = SSV/0/0. Temp = SI. PPPOT-IC *FAIL* & PPPOT-T *PASS* (Pre-RWO). No AL. Flowline is disconnected. PPPOT-IC: Stung into IC test void, 0+ psi. Monitor for 10 min. 0+ psi. Pressured void to 3500 psi, unable to stabilize pressure, bled IC-PO pressure to 0 psi. Re- torqued IC LDS to 450 ft-lbs. Pressured void to 3500 psi for 30 min test. Lost 150 psi in 1st 15 min. Lost 200 psi in 2nd 15 min for a FAIL. Bleed void to 0 psi. PPPOT-T: Stung into tubing hanger test void, 750 psi. Bled void to 0 psi. Monitor for 10 min. 0 psi. Functioned tubing hanger LDS, functioned smoothly except 4 LDS stuck @ 02:30, 04:30, 11:30, 12:00 (flagged stuck LDS). Re-torqued all LDS to 450 ft- lbs and glan nuts to 550 ft-lbs. Pressured void to 5000 psi for 30 min test. Lost 400 psi in 1st 15 min. Lost 50 psi in 2nd 15 min for a PASS. Bled void to 0 psi. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:30 RUN W/WELLTEC 3 5/8'' MECHANICAL CUTTER TAG TOP OF TUBING COLLAPSE @ 8332'@ CUT 5 1/2'' TBG AT 8327' 5' ABOVE OF TBG COLLAPSE CMIT-TxIA.gg Tbg/IA lost 76/78 psi in 1st 15 mins and 27/29 psi in 2nd 15 mins for a total loss ofg 103/107 psi in 30 min test. PASS. Daily Report of Well Operations PBU H-13A 4/3/2023 T/I/O=closed SSV, 0/0 IC packoff lock down screws varried out measurements ~1/4", loosen gland nuts, back out all ICPO LDS, run in tag PO, all within ~1/8", torque 500 ft/lbs, tighten gland nuts, test ICPO 500 psi/5 min, 3500 psi/30 min, good tests, 0 psi loss, bleed off test psi., RDMO 4/8/2023 Function (4) flagged TBG HGR LDS. All free. 7/28/2023 T/I/O = SSV/0/0. Temp = SI. WHPs (OE request). No AL. Flowline dissconnected, scaffolding removed. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:40 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:209-044 6.API Number:50-029-20559-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028284 Property Designation (Lease Number):10. 8. PBU H-13A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well 55 Operations shutdown Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 10390 Effective Depth MD: L80 11. Commission Representative: 15. Suspended Contact Name: Contact Email: Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8899 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 8335, 7978 No SSSV Installed Date: Liner 1978 3-1/2" x 3-3/16" x 2-7/8"8412 - 10390 8049 - 8899 10160 10530 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 38 - 2695 38 - 2695 14. Estimated Date for Commencing Operations: BOP Sketch 39 - 110 Structural 6870 Proposal Summary 13. Well Class after proposed work: 5-1/2" TIW Packer 9370 - 10320 8883 - 8905 5-1/2" 17# x 4-1/2" 12.6#34 - 8466 Production 8399 8037 8399 None 39 - 110 13-3/8" 9-5/8" Contact Phone: Date: 4760 71 20"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 55 55 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2657 4930 Intermediate 8871 36 - 8907 36 - 8510 654 7" 8412 - 9066 8049 - 8659 8160 7020 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2370 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. Update to Sundry # 321-240 October 25, 2021 John Condio john.condio@hilcorp.com 907-564-4696 By Samantha Carlisle at 9:37 am, Sep 02, 2021 321-442 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.09.02 04:47:10 -08'00' Stan Golis (880) DSR-9/2/21DLB 09/02/2021 X BOPE test to 3500 psi. Annular to 2500 psi. MGR02SEP2021 10-404 dts 9/2/2021 9/3/2021Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.09.03 07:40:32 -08'00' RBDMS HEW 9/3/2021 RWO: Tubing Swap Well:H-13A PTD:209-044 API: 50-029-20559-01 Well Name:H-13A API Number:50-029-20559-01 Current Status:Not Operable, TxIA Rig:Thunder Bird 1 Estimated Start Date:October 25, 2021 Estimated Duration:4days Reg.Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:209-044 First Call Engr:John Condio 602.373.0659 (M) Second Call Engr:Brodie Dave Wages 713.380.9836 (M) AFE Number:215-01688.16.11 Current Bottom Hole Pressure: 3200 psi @ 8800’ TVD (estimated based offsets) Max. Anticipated Surface Pressure: 2320 psi (Based on 0.1 psi/ft gas gradient) Last SI WHP: 0 psi (taken 5/11/2021) Equivalent Brine Weight: 7.3 ppg (estimate + 0.3 ppg SF) Min ID: 3.02” @ 8322’ MD (Partial tubing collapse, PDS caliper 3/8/19) Objective: Restore tubing integrity and return well to production from the Ivishak. Pull existing 5-1/2” L80 tubing to repair collapsed tubing at ~8322’ and replace with 4-1/2” L80 tubing. Achieve passing MIT-IA & MIT-T Brief Well Summary: H-13A is a zone 3 Ivishak GDWFI producer that was completed in 2009 by CST. The 5-1/2” tubing showed 75% wall penetration at 8326’ on a caliper survey and was later found to be partially collapsed near this depth with a loss of integrity to the IA. The workover will return H-13A to production at similar rates to when it went offline in January 2018. Surface Infrastructure: H-13A has access to GC2 HP via the 42H header, and GC2 or GC1 LP via the 41H header. If the piggyback well, H-27B, is shut-in H-13A has access to the GC1 annex via the 47H header. Pre-Rig Prep Work: DHD 1) CMIT-T x IA to 3000 psi 2) OA Integrity Test to 1200 psi 3) Function all LDS 4) PPPOT-T & PPPOT-IC Full Bore: 5) Circulate well from tubing to IA with 1% KCL and diesel FP to 2000’ a. PX plug at 8399’ set on 3/12/18 b.Was able to establish LLR from IA to tubing (assumed thru collapse/tubing failure) at 0.5 bpm at 1650 psi on 3/12/18 Slickline (contingent step): 6)Open sliding sleeve at 8276’ if unable to circulate in previous step Valve Shop: 7) Bleed WHP’s to 0 psi -00 DLB RWO: Tubing Swap Well:H-13A PTD:209-044 API: 50-029-20559-01 8) Set and test TWC 9) Nipple down tree & tubing head adapter. Inspect lift threads. a. Tubing barriers: tubing tail plug and TWC b. Casing barriers: Production packer and tubing hanger 10)Nipple up BOPE;Annular, 2-7/8” x 5-1/2” VBRs, Blinds and flow cross. Proposed Workover Procedure: 11) MIRU Thunder Bird #1 a. Well has TTP at 8399’MD set 3/13/18 b. Tubing has partial collapse above packer/seal assembly at 8322’ MD 12) Test BOPE to 250psi Low/3000psi High, annular to 250psi Low/2500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per Thunder Bird #1 BOP Test Procedure. b. Notify AOGCC 24 hrs. in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test the 2-7/8” x 5-1/2” VBR’s with 2-7/8”, 4-1/2’’ & 5-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13) Verify well is dead 14) Pull TWC 15) MU landing joint or spear 16) BOLDS and pull hanger to the floor a. PU weights are expected to be ~125K b. 5-1/2” 17# L80 yield: 397K# 17) If 5-1/2” tubing is free, circulate bottoms up 18) Pull & laydown 5-1/2” completion Contingency if tubing does not pull free: 19) RU Eline and cut 5-1/2” tubing at ~8305’, above collapse 20) RIH with fishing BHA on 2-7/8” workstring, fish remaining 5-1/2” tubing and seal assembly 21) POOH and laydown fish 22) Run new completion Contingency if fish does not pull free or if tubing parted near collapse: 23) RIH with bit or packer mill (TBD) on 2-7/8” workstring 24) Mill through collapse and partially into SBR to set up for WLEG or production overshot 25) Make clean-out run with casing scraper 26) Run new completion Run New 4-1/2” Completion 27) Run 4-1/2” L80 tubing with stacker packer per proposed schematic/tally 28) Land Hanger and reverse in corrosion inhibited 8.4 ppg 1% KCL or equivalent 29) Drop ball and rod and set packer with 3500psi pump pressure. 30) Perform MIT-T to 3000psi and MIT-IA to 3000psi charted for 30 minutes 31) Shear valve in top GLM and circulate FP fluid 32) Set TWC 33) Rig down Thunderbird #1 RWO: Tubing Swap Well:H-13A PTD:209-044 API: 50-029-20559-01 Post Workover Procedure: Valve Shop 34) ND BOPE 35) NU tree and tubing head adapter. 36) Test both tree and tubing hanger void to 500psi low/5000psi high Slickline 37) Pull TWC 38) Pull ball and rod, pull RHC body 39) Set GLV’s per GL engineer 40) Pull 4-1/2” PX plug at 8399’ Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic VBR 4. Sundry Revision Change Form RWO: Tubing Swap Well:H-13A PTD:209-044 API: 50-029-20559-01 As-built Schematic RWO: Tubing Swap Well:H-13A PTD:209-044 API: 50-029-20559-01 Proposed Schematic RWO: Tubing Swap Well:H-13A PTD:209-044 API: 50-029-20559-01 BOP Schematic VBR RWO: Tubing Swap Well:H-13A PTD:209-044 API: 50-029-20559-01 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Operator Name:2. Exploratory Development Service Permit to Drill Number:209-044 6.API Number:50-029-20559-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028284 Property Designation (Lease Number):10. 8. PBU H-13A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil WINJ Exploratory DevelopmentStratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 10390 Effective Depth MD: L80 11. Commission Representative: 15. Suspended Contact Name: Brodie Wages Contact Email: David.Wages@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes NoSpacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8899 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 8335, 7978 No SSSV Installed Date: Liner 1978 3-1/2" x 3-3/16" x 2-7/8"8412 - 10390 8049 - 8899 10160 10530 Well Status after proposed work: 16.Verbal Approval: Change Approved Program 38 - 2695 38 - 2695 14. Estimated Date for Commencing Operations: BOP Sketch 39 - 110 Structural 6870 Proposal Summary 13. Well Class after proposed work: 5-1/2" TIW Packer 9370 - 10320 8883 - 8905 5-1/2" 17# x 4-1/2" 12.6#34 - 8466 Production 8399 8037 8399 None 39 - 110 13-3/8" 9-5/8" Contact Phone:907.564.5006 Date: 4760 71 20"Conductor 2670 GINJ Post Initial Injection MIT Req'd? Yes No Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2657 4930 Intermediate 8871 36 - 8907 36 - 8510 654 7" 8412 - 9066 8049 - 8659 8160 7020 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. NoYes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2370 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.05.13 15:45:44 -08'00' Stan Golis (880) 5/27/21 By Meredith Guhl at 4:06 pm, May 13, 2021 321-240 SFD 5/13/2021 DSR-5/13/21MGR17MAY21 BOPE test to 3500 psi. Annular to 2500 psi. 10-404 dts 5/20/2021 JLC 5/20/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.20 13:47:03 -08'00' RBDMS HEW 6/2/2021 H-13 Integrity RWO Well: H-13A PTD: 209-044 Well Name:H-13A API Number: 500292055901 Current Status:Offline, Not Operable Estimated Start:June 2021 Operations Engineer:Brodie Wages (907) 564-5006 (O) (713) 380-9836 (M) Reservoir Engineer:Laurie Derrick (907) 564 5279 (O) (720) 308-3386 (M) Geologist:Ashlyn Murphy (907) 564-4889 (O) (832) 417-1640 (M) Current Bottom Hole Pressure:3209psi @ 8800’ TVD 7.4ppg | 2006 SBHP + Safety Max. Anticipated Surface Pressure:2329psi 0.1 psi/ft gas to surface Last SI WHP:0 psi Taken 5/11/2021 Min ID:3.02” tubing collapse @ 8322’ (3/19 caliper) Max Angle:100 deg @ 9794’ MD Objective:Restore tubing integrity and return the well to production from the Ivishak. Pull the existing tubing string to repair the collapse at 8322’md and restore the wellbore to full ID to enable retrieval of the PX plug. Brief Well History: H-13A was completed in June 2009. It was originally perforated in Zone 2C in the toe. The toe perfs produced approximately 1000 bfpd at 94% water cut. In early 2010 perforations were added in Zone 3 and the well started producing 1000 bopd, 1500 bwpd and 13 mmscfd formation gas. Minimal interventions have occurred through well life. In 2014, the tree failed and the well was secured for the tree changeout. During the slickline steps to set a plug it was noted that the tubing had some ovality at ~8326’md. In early 2018, the well started to exhibit signs of TxIA communication. A tailplug was set to perform integrity diagnostics and the tubing was apparently collapsed during the pressure test causing the plug to be stuck and the tubing to have rapid pressure communication with the IA. The 5.5” tubing is the original string from H-13, which was set in 1982. Surface Infrastructure: H-13A has access to GC2 HP via the 42H header, and GC2 or GC1 LP via the 41H header. If the piggyback well, H-27B, is shut-in H-13A has access to the GC1 annex via the 47H header. Notes Regarding Wellbore Condition: > 03/08/19: Caliper: 143 jts=0-20%, 67 jts=20-40%, 22 jts=40-85%, Max Pen=100% @ 8321' MD > 03/04/19: Re-energize Y seal, PPPOT-IC Passed > 02/28/19: CMIT-TxIA Passed to 3196 psi, PPPOT-T Passed, PPPOT-IC Failed > 03/14/18: PPPOT-T Passed > 03/12/18: Tubing failed during MIT-T > 03/12/18: Set TTP @ 8399' MD, MIT-T Failed to 2520 psi; CMIT-TxIA Pass to 2650 psi > 03/11/18: Set DGLVs in sta #11 & 12 > 03/11/18: Caliper shows 75% Wall Pen @ 8,326', 50% throughout. 46% Wall Loss at 8,326' Procedure: DHD – MIT OA – 1200 psi CMIT-TxIA to 3,500-psi, run eline LDL if failing. Cycle LDS PPPOT-T H-13 Integrity RWO Well: H-13A PTD: 209-044 PPPOT-IC (confirm failure) SL – Drift EL – Shoot string shot near collapse DHD – Bleed WHP’s to 0 Valve Shop – Set and test TWC Nipple Down Tree and tubing head adapter. Inspect lift threads. Tubing barriers: tubing tail plug and TWC Casing barriers: Production packer and tubing hanger NU BOPE configured top down, Annular, 4-1/2” x 5-1/2” VBRs, Blinds and integral flow cross. Proposed RWO Procedure: 1. MIRU Thunderbird #1 Rig. 2. Test BOPE to 250psi Low/3,500psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8” x 5-1/2” VBR’s with 4-1/2” and 5-1/2” test joints. Test the Annular preventer with a 4-1/2” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. Pull TWC. 4. MU landing joint or spear 5. BOLDS and pull hanger to the floor. a. PU weights are expected to be ~130K b. 5-1/2” 17# L80 yield: 397k# 6. Circ out diesel freeze protect 7. Pull 5-1/2” tubing to floor, circulate bottoms up. If unable to pull off seal bore: A. Eline cut above tubing collapse, RWO RIH with fishing string and pull overshot, continue workover B. Eline cut above tubing collapse, RWO install guide and swedge collapse via mill 8. Run 4 ½” L80 tubing per proposed schematic/tally. 9. Land Hanger and reverse in corrosion inhibited 8.4ppg 1%KCl 10. Drop ball and rod and set packer with 3,500psi pump pressure. 11. Perform MIT-T to 3,500 psi and MIT-IA to 3,500 psi for 30 charted minutes. 12. Shear valve in upper GLM. 13. Set TWC 14. Rig down Thunderbird #1. Post rig valve shop work 1. ND BOPE 2. NU tree and tubing head adapter. or, Check for flow. . POOH with 5-1/2" tubing. Lay down the same. H-13 Integrity RWO Well: H-13A PTD: 209-044 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC and freeze protect to ~2,200ft with diesel. Post rig Slickline Work 1. Pull Ball and rod and RHC profile 2. Set GLV’s per GL Engineer 3. Pull PX plug set in tubing tail 4. RDMO & pop well Additional Post Rig Work: 1. Schedule SVS testing with AOGCC per regs Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing H-13 Integrity RWO Well: H-13A PTD: 209-044 Current WBS: H-13 Integrity RWO Well: H-13A PTD: 209-044 Proposed WBS: H-13 Integrity RWO Well: H-13A PTD: 209-044 BOP Schematic: Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: May 12, 2021Subject: Changes to Approved Sundry Procedure for Well H-13ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date O • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, March 18, 2018 8:51 AM To: AK, GWO Well Integrity Engineer; Regg,James B (DOA);AK, OPS EOC Specialists;AK, OPS GC2 Facility OIL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK, OPS Well Pad LV;AK, OPS Well Pad MN;AK, OPS Well Pad RJ;AK, OPS WELL PAD 5;AK, OPS Well Pad SW;AK, OPS WELL PAD W;AK, OPS Well Pad Z;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Frankenburg,Amy;Wellman,Julie Cc: Wallace, Chris D (DOA);AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua; Worthington,Aras J;AK, GWO Well Integrity Well Information Subject: NOT OPERABLE: H-13A (PTD#2090440) Failed MIT-T,Well to remain secured All, Producer H-13A(PTD#2090440)was made under evaluation on 2/27/18 for having sustained inner annulus casing pressure above NOL. On 3/12/18 slickline performed pressure test diagnostics and determined the well has a tubing failure somewhere between 8,399'-8276'. The well was left secured with a tubing tail plug and verified with a passing CMIT-TxIA to 2,650psi. At this time the well is reclassified as Not Operable and will remain shut in and secured. The production engineer will evaluate the well for a plan forward. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 �'�� E� Cell: 907-341-9068 WO .-.+a-....r..v«+M From: , - 0 Well Integrity Engineer Sent: Tuesday, Fe. •- • 27, 2018 1:32 PM To: 'Regg, James B (DOA) (jim. - a . alaska.gov)'; AK, OPS EOC Specialists; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, 0' - Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OP - Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z; ••s West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Frankenburg, Any, A ellman, Julie Cc: 'chris.wallace@alaska.gov'; AK, GWO Completions Well Integrity; AK, '; 'HD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Informa a 'K, OPS FF Well Ops Comp Rep; 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, February 27, 2018 1:32 PM To: Regg,James B (DOA);AK, OPS EOC Specialists;AK, OPS GC2 Facility OIL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead; AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK, OPS Well Pad LV;AK, OPS Well Pad MN;AK, OPS Well Pad RJ;AK, OPS WELL PAD S;AK, OPS Well Pad SW;AK, OPS WELL PAD W;AK, OPS Well Pad Z;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOp5ProdEOCTL; Frankenburg, Amy; Wellman,Julie Cc: Wallace, Chris D (DOA);AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J Subject: UNDER EVALUATION: H-13A(PTD#2090440) inner annulus casing pressure above NOL All, Producer H-13A(PTD#2090440)was reported to have inner annulus casing pressure above NOL on 02/27/18.The pressure was reported to be 2,410 psi.The well has had four TIFLs since 07/12/17.To meet operability criteria,the well cannot exceed four TIFLs in a one year period before a positive pressure test is conducted to reprove barrier integrity. The well is now classified as UNDER EVALUATION to conduct MITs. Plan forward: 1. Slickline: Change out screened orifice 2. Fullbore: Perform MITs 3. Well Integrity Engineer:Additional diagnostics as needed. Please respond if in conflict. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 SCANNED F X 2 8 :i o j c 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday,August 26, 2017 5:27 AM To: AK, GWO Well Integrity Engineer;AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Shriver,Tyson; Wellman,Julie; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington,Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer H-13 (PTD#2090440) Barriers Confirmed All, Producer H-13 (PTD#2090440)was reported to have sustained inner annulus casing pressure above NOL on 8/8/17. Slickline changed out the gas lift valves on 08/25/17 and DHD performed a passing cold TIFL on 8/25/17. A passing PPPOT-T was performed on 11/26/14 along with a passing CMIT-IA to 2500psi on 11/29/14 indicting that the well has two competent barriers to formation. At this time the well is reclassified as OPERABLE. Plan Forward/Work Completed: 1) Slickline: Perform gas lift valve change out-Complete 2) DHD: TIFL, and monitor of IA pressurization-Complete 3) Well Integrity Engineer: Additional diagnostics as needed Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 SCANNED 5 F P 15 201-4 Harmony 4530 1 • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday,August 8, 2017 7:33 AM To: AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Shriver,Tyson;Wellman,Julie; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer H-13 (PTD#2090440) Sustained Inner Annulus Pressure Above NOL Attachments: H-13A.pdf All, Producer H-13 (PTD#2090440)was reported to have sustained inner annulus casing pressure above NOL on 8/8/17. The pressure were confirmed to be T/I/O=2420/2420/Opsi. A review of the T/I/O history indicates TxIA communication when shut in. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1) Slickline—Perform gas lift valve change out 2) DHD-TIFL,and monitor of IA pressurization 3) Well Integrity Engineer—additional diagnostics as needed Please respond with any questions, Joshua Stephens me) !1,1,-.1) 2 0 ZOI,, Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 W 0.641....01.1~.w, 1 • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q~ - Q ~- ~. Well History File Identifier Or anizin (done) g 9 ^ Two-sided III II IIIIIIIII II III ^ Rescan Needed III II'IIIIIII IIIIII RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: t g D ~ ~ O !s/ BY: Maria a e: p Project Proofing II I II ~I II V III I I II I BY: Maria Date: ~ ~ /s! Scannin Pre aration 9 ~,_ x 30 = ~ + ~ =TOTAL RAGES ~~ ~ ~ (Count does not include cover sheet) BY: Maria Date:. ~ ,,,~ ~ ~ V _. /s/ Production Scanning """"""" " "' Stage 1 Page Count from Scanned File: ~ ~ (Count does include cove eet) Page Count Matches Number in Scanni g Preparation: YES NO BY: Maria Date: g ~ ~ ~ ~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II ~I II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III II~III III II'I II 10!6/2005 Well History File Cover Page.doc • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Reg Alaska Oil and Gas Conservation Commission u544' . QED AUG g LUIS 333 West 7 Avenue d Coq - © L Anchorage, Alaska 99501 JJ Subject: Corrosion Inhibitor Treatments of GPB H -Pad 3) Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad H that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald • Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Date: 03/17/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date 1 ft bbls ft na gal H -01A 1951100 50029200990100 0.7 NA 0.7 NA 5.10 2/17/2010 H -02A 2021600 50029201000200 0.5 NA 0.5 NA 5.10 2/16/2010 H -03 1710190 50029201030000 0.2 NA 0.2 NA 1.70 2/16/2010 H -04A 2031610 50029201040100 0.3 NA 0.3 NA 3.40 2/14/2010 H -05B 2091000 50029201060200 0.3 NA 0.3 NA 5.10 3/9/2010 H -06 1770020 50029202380000 0.1 NA 0.1 NA 0.85 2/16/2010 H -07A 2001280 50029202420100 0.6 NA 0.6 NA 3.40 2/15/2010 H -08 1770230 50029202470000 0.4 NA 0.4 NA 3.40 2/15/2010 H -09 1800640 50029204820000 21.6 5.0 0.8 7/12/2010 3.40 7/8/2011 H -10A 1971900 50029204870100 0.3 NA 0.3 NA 1.70 2/19/2010 H -11 1800680 50029204850000 0.3 NA 0.3 NA 1.70 2/18/2010 H -12 1800670 50029204840000 0.3 NA 0.3 NA 1.70 2/18/2010 _1p H -13A 2090440 50029205590100 0.1 NA 0.1 NA Trace 2/18/2010 H -14B 2071160 50029205800300 0.1 NA 0.1 NA Trace 2/18/2010 H -15 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010 H -16 2000650 50029205920200 0 NA NA NA NA NA H -17A 1971520 50029208620100 21.5 6.0 0.4 7/12/2010 1.70 7/8/2011 H -18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010 H -19B 1980940 50029208830200 3.5 NA 3.5 NA 23.80 2/24/2010 H -20 1830070 50029208960000 6.7 NA 6.7 NA 47.60 2/22/2010 H -21 1860710 50029215750000 0.5 NA 0.5 NA 3.40 2/15/2010 H -22A 1970480 50029215880100 0.1 NA 0.1 NA 0.85 2/15/2010 H -23A 1950850 50029217940100 5 NA 5 NA 32.30 2/17/2010 H -24A 2071330 50029215120100 0.7 NA 0.7 NA 3.40 2/28/2010 11-25 1852680 50029214780000 0.1 NA 0.1 NA 0.85 2/26/2010 H -26 1852770 50029214870000 2.3 NA 2.3 NA 17.90 2/23/2010 H -27A 2030590 50029214560100 0.1 NA 0.1 NA 0.85 2/21/2010 H -28 1880440 50029218060000 0.5 NA 0.5 NA 3.40 2/17/2010 H -29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010 11-30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010 H -31 1940140 50029224440000 0.7 NA 0.7 NA 5.10 2/18/2010 H -32 1940250 50029224490000 0.3 NA 0.3 NA 1.70 2/18/2010 11-33 1940380 50029224580000 0.1 NA 0.1 NA 1.70 2/16/2010 H -34 1971640 50029228030000 1.3 NA 1.3 NA 13.60 2/19/2010 • 11-35 1951490 50029226000000 1.7 NA 1.7 NA 15.30 2/16/2010 H -36A 2000250 50029226050100 1.3 NA 1.3 NA 11.90 2/17/2010 H -37A 2000970 50029227720100 1.2 NA 1.2 NA 10.20 2/20/2010 H -38 2081670 50029234020000 Dust cover NA NA NA NA 3/17/2012 DATA SUBMITTAL COMPLIANCE REPORT 8/25/2010 Permit to Drill 2090440 Well Name/No. PRUDHOE BAY UNIT H-13A Operator BP EXPLORATION (ALASKA INC API No. 50-029-20559-01-00 MD 10390 ND 8899 Completion Date 6/17/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Ye DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / RES / GR, MCNL / GR /CCL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name scale meaia No Start Stop c:h hiecervea comments og Neutron 25 Blu 7928 10268 Case 8/10/2009 MCNL, TNN, TNF, GR< CCL 17-Jun-2009 ~ D C Lis 18413 D'Neutron 7920 10272 Case 8/10/2009 LIS Veri, GR, CNT Plus Graphics Rpt LIS Verification 8905 10388 Open 8/28/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS D C Lis 18445 nduction/Resistivity 8905 10388 Open 8/28/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS Plus Graphics og Induction/Resistivity 25 Col 9065 10390 Open 8/28/2009 MD MPR, GR Lo Induction/Resistivity 5 Col 9065 10390 Open 8/28/2009 TVD MPR, GR og Gamma Ray 25 Col 9065 10390 Open 8/28/2009 MD GR og See Notes 5 Col 8890 10390 Open 8/28/2009 Depth Shift Monitor Plot og Neutron 25 Blu 7230 10299 Case 2/1/2010 MCNL, Lee TNN, TNF, GR, CCL 29-Nov-2009 ~~ ED C Lis 19284 'Neutron 9303 10304 Case 2/1/2010 LIS Veri, GR, CNT Plus Graphics Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 8/25/2010 Permit to Drill 2090440 Well Name/No. PRUDHOE BAY UNIT H-13A MD 10390 TVD 8899 ADDITIONAL INFORM/~TION Well Cored? Y J~f:`fl~U Chips Received? ~~ Analysis Y'T 1F~~ Received? Completion Date 6/17/2009 Operator BP EXPLORATION (ALASKIy INC Completion Status 1-OIL Current Status 1-OIL Daily History Received? "-" N Formation Tops ~YJ N API No. 50-029-20559-01-00 UIC N Comments: Compliance Reviewed By: ~-~ Date: ~~ ~-~.1 ~rV STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED MAY2o2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ l~~t~ , Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ~~~ Change Approved Program ^ Operat. Shutdown ^ Perforate 0 Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^~ Exploratory ^ 209-0440 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 ~ 50-029-20559-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: \ ADLO-028284 PBU H-13A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10390 feet Plugs (measured) None feet true vertical 8898.81 feet Junk (measured) None feet Effective Depth measured 10353 feet Packer (measured) 8335' true vertical 8902.22 feet (true vertical) 7978' Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2695 13-3/8" 72# L-80 SURFACE - 2695 SURFACE - 2695 4930 2670 Intermediate Production 8906 9-5/8" 47# L-80 SURFACE - 8906 SURFACE - 8906 6870 4760 Liner 673 7" 29# L-80 8411 - 9084 8048 - 8676 8160 7020 Liner 2015 3-1/2"X3-3/16"X2-7/8" 8375 - 10390 8015 - 8899 9.2#/6.2#/6.16# Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# LL-80 SURFACE - 8355' SURFACE - 7996' 4-1 /2" 12.6# L-80 8355' -8466' 7997' - 8099' Packers and SSSV (type, measured and true vertical depth) 9-5/8"X5-1/2" TIW PKR 8335' 7978' 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: 148 3233 874 212 Subsequent to operation: 362 3039 1237 216 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development Q Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre to Title Data Management Engineer Signature pD~ MAI 2 ~ ~A~ne 564-4944 Date 5/14/2010 Form ~• f~y1 H-13A 209-044 PERF ATTAI:NMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base H-13A 6/17/09 PER 10,120. 10,320. 8,903.54 8,904.97 H-13A 10/1/09 APF 10,080. 10,110. 8,903.87 8,903.69 H-13A 10/1/09 APF 10,150. 10,180. 8,903.19 8,903.78 H-13A 10/1/09 APF 10,200. 10,230. 8,904.41 8,905.39 H-13A 10/1/09 APF 10,300. 10,320. 8,905.93 8,904.97 H-13A 3/25/10 APF 9,380. 9,385. 8,887.11 8,889.18 H-13A 5/9/10 APF 9,370. 9,375. 8,882.67 8,884.94 H-13A 5/9/10 APF 9,375. 9,380. 8,884.94 8,887.11 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 e H-13A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/8/2010~'~""WELL FLOWING ON ARRIVAL""`"` (E-LINE ADPERFS) INTITIAL T/I/O = 200/1325/650 SHUT WELL IN TO RIH ATTEMPTED TO PERFORATE, COULD NOT PASS DOG LEG AT 9125'. ***JOB CONTINUED ON 09-MAY-2010*** 5/9/2010!***JOB CONTINUED FROM 08-MAY-2010*"* (E LINE ADPERFS) INITIAL T/I/O = 200/1325/650 TOOL STOPPED DUE TO DEVIATION AT 9,383'. PERFORATED INTERVALS x.;370' TO 9,375' AND 9375' TO 9380' WITH 2" HSD 6SPF PJ-2006 60 DEG PHASED GUN. MADE TWO 5FT RUNS, 10FT GUN WOULD NOT PASS DOG LEG AT 9130'. ALL DEPTHS CORRELATED TO SLB MCNL 17-JUN-2009 FINAL WHP T/I/0 = 900/1100/0. HANDED OVER TO DSO, WELL SHUT-IN ON DEPARTURE, ***JOB COMPLETE*** FLUIDS PUMPED BBLS 1 DIESEL 1 METH 2 Total TREE _ _ MCEV OY 13-318" CSG, 72#, L-80, ID = 12.347" I---I 2695' Minimum ID = 2.3" @ 8380' ALUMINUM BUSHING 5-112" TBG, 17#, L-80, .0232 bpf, ID = 4.892" I-j 8355' TOP OF 7" LNR I-1 8412, 3-112" LNR, 9.2#, L-80 STL, ~ 8424' ,0087 bpf, ID = 2.992" ~ 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I-I 8466' 9-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" ~ 8907' 4-112" THRU TUBING WHIPSTOCK (05(04/09) 90$0' ELMD 7" LNR 29#, L-80 BTRS, .0371 bpf, ID = 6.184" 9800' PERFORATION SUMMARY REF LOG: MCNLIGRICCL ON 06/17/09 ANGLE AT TOP PERF: 63° @ 9380' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9380 - 9385 O 03/26/10 2" 6 10080 - 10110 O 10101!09 2" 6 10120 - 10320 O 06/17/09 2" 6 10150 - 10180 O 10/01 /09 2" 6 10200 - 10230 O 10/01/09 2" 6 10300 - 10320 O 10101!09 H-13A 2001' -~5-1/2" CAM SSSV LAND NIP, ID = 4.562" 2589' 9-5/8" DV PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3006 3005 1 CAMCO DOM RK 16 07!02109 11 4938 4828 21 CAMCO SO RK 20 07102109 10 5953 5773 22 CAMCO DMY RK 0 05115!81 9 6095 5905 22 CAMCO DMY RK 0 05/15/81 8 6629 6401 22 CAMCO DMY RK 0 05/15/81 7 6776 6538 22 CAMCO DMY RK 0 05!15/81 6 7114 6851 23 CAMCO DMY RK 0 05115!81 5 7259 6985 22 CAMCO DMY RK 0 05115!81 4 7588 7291 21 CAMCO DMY RK 0 05/15/81 3 7727 7420 22 CAMCO DMY RK 0 05!15181 2 8064 7729 24 CAMCO DMY RK 0 04!01(00 1 8208 7861 23 CAMCO DMY RK 0 05/15/61 8276' ~5-1/2" SLIDING SLV, ID = 4.562" I 8315' TBG SEAL ASSY 8335' 9-5/8" x 5-1/2" TMJ PKR, ID = 4.75" $355' 5-112" X 4-112" XO, ID = 3.958" 8375' 3.70" BTT DEPLOYMENT SLV, ID = 3.00" 8380' ALUMINUM BUSHING, ID = 2~ 8399' 4-112" X NIP, ID = 3.813" $424' 3-1/2" X 3-3/16" XO, ID = 2.786" 8431' 4-1/2" XN NIP (MILLED 05!13109}, ID = 3.80" 8466' 4-112" TBG TAIL & SHEAR OUT SUB, ID = 3.958" 8428' ELMD TT LOGGED 07/02/97 MILLOUT WINDOW (H-13A} 9066' - 9084' 3-3/16" LNR, 6.2#, L-80 TCII .0076 bpf, ID = 2.80" 102$7' 3-3/16" X 2-718" XO, ID = 2.377" I 10287' I PBTD ~-{ 10353' 2-718" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" I DATE REV BY COMMENTS DATE REV BY COMMENTS 04/22/82 ORIGfNAL COMPLETION 03/30/10 TO/PJC GLV CORRECTIONS 06/18!09 NORDIC CTD SIDETRACK (H-13A} 07!16!09 DMS/SV GLV C/O (07!02109} 09!28109 SM/JMD DRLG DRAFT CORRECTIONS 10/08/09 MLUSV ADD/REPERF (10!01/09} 03/26!10 MV/ PJC ADPERFS PRUDHOE BAY UNIT WELL: H-13A PERMIT No: 109044 API No: 50-029-20559-01-00 Sec. 21, T11N, R13E, 1652' FNL & 1264' FEL BP 6cpioration (Alaska) STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COMMISST~N REPORT OF SUNDRY WELL OPERATIONS E~EI~~ APR 0 ? 2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ I . Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ A-1GfI0t~dP Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory ^ 209-0440 3. Address: P.O. Box 196612 Stratigraphic^ Service .API Number: Anchorage, AK 99519-6612 50-029-20559-01-00 8. Property Designation (Lease Number) : 9. Well Name and Nurr~er: ADLO-028284 ~ PBU H-13A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11, Present Well Condition Summary: Total Depth measured 10390 feet Plugs (measured) None feet true vertical 8898.81 feet Junk (measured) None feet Effective Depth measured 10353 feet Packer (measured) 8335' true vertical 8902.22 feet (true vertical) 7978' Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surtace 2695 13-3/8" 72# L-80 SURFACE - 2695 SURFACE - 2695 4930 2670 Intermediate Production 8906 9-5/8" 47# L-80 SURFACE - 8906 SURFACE - 8906 6870 4760 Liner 673 7" 29# L-80 8411 - 9084 8048 - 8676 8160 7020 Liner 2015 3-1/2"X3-3/16"X2-7/8" 8375 - 10390 8015 - 8899 9.2#/6.2#/6.16# Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# L-80 SURFACE - 8355' SURFACE - 7996' 4-1/2" 12.6# L-80 8355' -8466' 7997' - 8099' Packers and SSSV (type, measured and true vertical depth) 9-5/8"X5-1/2" TIW PKR 8335' 7978' 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: 95 3779 1772 222 Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^Q Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 4/2/2010 ~ 5 ~~~ Form 1 - H-13A 209-044 PERF OTTO[:HMENT LuJ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base H-13A 6/17/09 PER 10,120. 10,320. 8,903.54 8,904.97 H-13A 10/1/09 APF 10,080. 10,110. 8,903.87 8,903.69 H-13A 10/1!09 APF 10,150. 10,180. 8,903.19 8,903.78 H-13A 10/1/09 APF 10,200. 10,230. 8,904.41 8,905.39 H-13A 10/1/09 APF 10,300. 10,320. 8,905.93 8,904.97 H-13A 3/25/10 APF 9,380. 9,385. 8,887.11 8,889.18 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 H-13A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY I 3/22/2010 ~"WELL S/1 ON ARRIVAL"*"(pre adperf) DRIFTED TO DEVIATION AT 9388' SLM W/ 2.00" DMY GUN, S.BLR TO 9388' ~SLM. NO SAMPLE. ***WELL LEFT S/I, PAD OP NOTIFIED*** ~ 3/25/2010***WELL SHUT IN ON ARRIVAL"*" (E-LINE PERF) INITIAL T/I/0=1600/1700/0 PSI PERFORATE 9380'-9385' WITH 2" PJ HSD 6 SPF 60 DEG PHASING GUN. """JOB IN PROGRESS AND CONTINUED ON 26-MAR-2010**" ~._ _ ~ ~. _ --____ r_._~ ~. 3/26/2010,**'`LOG CONTINUED FROM 25-MAR-2010'`*" RIG DOWN E-LINE. ` =FINAL T/I/O = 1550/1680/0 PSI I***JOB COMPLETE. DSO NOTIFIED OF DEPARTURE*** FLUIDS PUMPED BBLS 2 METH 2 TOTAL TREE= MCEVOY 'WELLHEAD ''MCEVOY (ACTUATOR= OTIS KB. ELEV = BF. ELEV = 82.55' 45.35' KOP = 3300' Max Angle = 100° @ 9793' Datum MD = 9370' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 2.3" @ 8380' ALUMINUM BUSHING 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" (~ 8355` TOP OF 7" LNR I-~ 8412' 3-112" LNR, 9.2#, L-80 STL~ -,8424' .0087 bpf, ID = 2.992" 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" ~ 8907' 4-112" THRU TUBING WHIPSTOCK (05!04!09) 9080' E~MD 7" LNR 29#, L-80 BTRS, .0371 bpf, ID = 6.184" 9$00' PERFORATION SUMMARY REF LOG: MCNL/GR/CCL ON 06(17!09 ANGLE AT TOP PERF: 63° @ 9380' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnJSgz DATE 2" 6 9380 - 9385 O 03/26/10 2" 6 10080 - 10110 O 10!01/09 2" 6 10120 - 10320 O 06/17/09 2" 6 10150 - 10180 O 10/01/09 2" 6 10200 - 10230 O 10/01/09 2" 6 10300 - 10320 O 10101!09 H -13A 2001` ~-i5-1/2" CAM SSSV LAND NIP, ID = 4.562" 2589' 9-5/8" DV PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3006 3005 1 CAMCO DOM RK 16 07/02!09 11 4938 4828 21 CAMCO SO RK 20 07/02/09 10 5953 5773 22 CAMCO DMY RK 0 05!15181 9 6095 5905 22 CAMCO DMY RK 0 05/15!81 8 6629 6401 22 CAMCO DMY RK 0 05/15/81 7 6776 6538 22 CAMGO DMY RK 0 05/15/81 6 7114 6851 23 CAMGO DMY RK 0 05/15/81 5 7259 6985 22 CRMCO DMY RK 0 05/15181 4 7588 7291 21 CAMCO DMY RK 0 05/15/81 3 7727 7420 22 CAMCO DMY RK 0 05/15/81 2 8064 7729 24 CAMCO DMY RK 0 04/01100 1 8208 7861 23 CAMCO DMY RK 0 05/15/81 8276' --~ 5-1/2" SLIDING SLV, ID = 4.562" 8315' TBG SEAL ASS 8335' 9-518" x 5-112" TM/ PKR, ID = 4.75" $355' 5-1 t2" X 4-112" XO, ID = 3.958" $375' 3.70" BTT DEPLOY MENT SLV, ID = 3.00" 8380' ALUMINUM BUSHING, ID = 2.3" 8399' - 4-1/2" X NIP, ID = 3.813" 8424' 3-112" X 3-3116" XO, ID = 2.786" 8431' 4-1/2" XN NIP (MILLED 05/13!09), ID = 3.80" 8466' 4-1 /2" TBG TAIL & SHEA R OUT SUB, ID = 3.958" 8428' ELMD TT LOGGED 07/02197 MILLOUT WINDOW (H-13A} 9066' - 9084' L.. 102$7' 3-3116" X 2-7/8" XO, ID = 2.377" 3-3/16" LNR, 6.2#, L-80 TCII .0076 bpf, ID = 2.80" PBTD ~-{ 10353' 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" I-) 10390' DATE REV BY COMMENTS DATE REV BY COMMEMS 04/22/82 ORIGINAL COMPLETION 03/30(10 TO/PJC GLV CORRECTIONS 06/18/09 NORDIC CTD SIDETRACK (H-13A) 07/16/09 DMS/SV GLV C/O (07/02/09) 09/28!09 SM/JMD DRLG DRAFT CORRECTIONS 10/08/09 MLVSV AD/REPERF (10/01(09) 03/26/10 MV/ PJC ADPERFS PRUDHOE BAY UNIT WELL: H-13A ' PERMIT No: 209044 API No: 50-029-20559-01-00 Sec. 21, T11N, R13E, 1652' FNL & 1264' FEL BP 6cploration (Alaska) S~hlumberger Alaska Oata & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # NO.5460 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD 13-35 6146-00084 INJECTION PROFILE ~- 2-27 B3S0-00043 GLS - p 11/10/09 1 1 17-09 BSJN-00031 LDL ~ - Q 01!07/10 1 1 05-38 AYKP-00063 PRODUCTION PROFILE - 01/11/10 1 1 P2-52 17-09 AGI-Ot 01-198 H-13A B2NJ-00050 AYKP-00064 BBKA-00003 AWJI-00062 B2NJ-00042 MEMORY XY CALIPER USIT ~ USIT () I - C MCNL _ MCNL C -- 01/21/10 01/24/10 01/22/10 01/18/10 12/03/09 1 1 1 1 1 1 1 1 1 1 07-26 07-19A 2-14/0-16 BALL-00007 63S0-00036 AZCM-00050 .. ( RST - p RST ~-(~ RST ( - r 11!29109 12/08/09 12/25/09 1 1 1 1 1 P1-24L1 12034915 o OH LDWG EDIT (FLEX _ Q 12/08/09 1 1 W-217 W-217 PB1 09AKA0091 09AKA0091 OH MWO/LWD EDIT _ OH MWDlLWD EDIT 08/08/08 11/23/09 11/15/09 1 2 2 1 1 1 PLEASE ACKNOWLEDGE REC EIPT BY SIGNIN G AND RETURNING oNE coav reru rn• tir txploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~ C~ ~~- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 _' - ~' _.. .. • • Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble @bp.com] Sent: Monday, October 12, 2009 2:45 PM To: Saltmarsh, Arthur C (DOA) Cc: Preble, Gary B (SAIC) Subject: PBU H -13A / PTD # 209 -044 Hi Art, The data listed below is a follow -up to a previously submitted 10 -407. This well was put on production for a few days in July with very poor flow and what we thought was an inaccurate well test. Since then, the well has been tested further (also with poor results) and put back on production. Basically, I am now reporting the current test data. Some perfs were added on October 1st and Gary Preble will be filing a 10 -404 (if he hasn't already) for that operation. Well Name: PBU H -13A Permit #: 209 -044 API #: 50- 029 - 20559 -01 -00 Top Perf MD: 10080' t MAR 7+° Bottom Perf MD: 10320' This well began Production on July 12, 2009 (Reported previously on 10 -407) Method of Operations is: Flowing Date of Test: October 11, 2009 Hours Tested: 11 24 -Hour Rate / Oil -Bbl: 60 24 -Hour Rate / Gas -Mcf: 2,669 24 -Hour Rate / Water -Bbl: 1,132 Test Rate / Oil-Bbl: 28 Test Rate / Gas -Mcf: 1,223 Test Rate / Water -Bbl: 519 Choke Size: 94 Gas -Oil Ration: 44,842 Flow Tubing Pressure: 240 Casing Pressure: 1,280 Oil Gravity -API: 36 10/12/2009 STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMIS~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Pertorations ^ Stimuiate^ Other ^ Pertormed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^~ Exploratory ^ ~`" 209-0440 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 w~ 50-029-20559-01-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-028284 `~. PBU H-13A 10. Field/Pool(s): ~ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured '\, 10390 feet Plugs (measured) None feet true vertical 8898.81 feet Junk (measured) None feet Effective Depth measured 10353 feet Packer (measured) 8335' true vertical 8902.22 feet (true vertical) 7978' Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2695 13-3/8" 72# L-80 SURFACE - 2695 SURFACE - 2695 4930 2670 Intermediate Production 8906 9-5/8" 47# L-80 SURFACE - 8906 SURFACE - 8906 6870 4760 Liner 673 7" 29# L-80 8411 - 9084 8048 - 8676 8160 7020 Liner 2015 3-1/2"X3-3/16"X2-7/8" 8375 - 10390 8015 - 8899 9.2#/6.2#/6.16# Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# L-80 SURFACE - 8355' SURFACE - 7996' 4-1 /2" 12.6# L-80 8355' -8466' 7997' - 8099' Packers and SSSV (type, measured and true vertical depth) 9-5/8"X5-1/2" TIW PKR 8335' 7978' ~~ V ~V 12. Stimulation or cement squeeze summary: ~ r T ~ $ zQ09 l• Intervals treated (measured): ~~aska Oii ~ Gas Cons. Commission Treatment descriptions including volumes used and final pressure: Anchorage 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 49 2787 75 173 Subsequent to operation: 14. Attachments: 15. Well Class after work: ,~ Copies of Logs and Surveys Run Exploratory^ Development ~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pr ble Title Data Management Engineer Signature ~' Phone 564-4944 Date 10/7/2009 F rm 1 ~-~~er~ ~~~~~~~1 ~ ~~-y-o9 H-13A 209-044 PERF OTTA[:HMFNT Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base H-13A 6/17/09 PER 10,120. 10,320. 8,903.54 8,904.97 H-13A 10/1/09 APF 10,080. 10,110. 8,903.87 8,903.69 H-13A 10/1/09 APF / 10,150. 10,180. 8,903.19 8,903.78 H-13A 10/1/09 APF i 10,200. 10,230. 8,904.41 8,905.39 H-13A 10/1/09 APF 10,300. 10,320. 8,905.93 8,904.97 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 n I..~ • i H-13A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 9/30/2009 CTU #5 1.75" (.134 wall) Job Scope: Ad Perf MIRU CTU. MU WFD MHA & ~ PDS Logging Tools with 2.2 Carrier. RIH to tag depth of 10,344' ctmd. Logged up to 9800' painting flags at 10,300' and 10,000'. POOH check for data. No 3 data P/U a new logging tool RBIH to log. ***Job in Progress*** 1 I 10/1/2009 v ~ CTU #5 1.75" (.134 wall) Job Scope: Ad Perf MIRU CTU. MU WFD MHA & PDS Logging Tools with 2.2 Carrier. RIH to tag depth of 10,344' ctmd. Logged up to 9800' painting flags at 10,300' and 10,000' POOH. At surface confirmed l good data + 2' Correction~I~tIH w / SLB 20' 2006PJ - 6 SPF gun. Correct to f flag + 2' launch 1/2" aluminum ball. Top shot 10300' Bottom shot at 10320'. j OOH with all shots fired, MU Ru .RIH with 30' of 2" 2006PJ HMX 6 SPF Guns to PBTD, PU to flag and correct depth to top shot. Launched 1/2" aluminum ball and perforate from 10,200' to 10,230'. OOH with all shots fired, MU Gun Run #3. RIH tag PBTD o ag and correct depth to top shot. ~ PUH to top shot depth of 10,150' Bottom shot at 1018 'and drop 1/2" aluminum ball to fire 30' 0 2006PJ HMX 6 SPF Guns. At surface confimed (all guns fired. RIH w /run #4 with 30' of 06PJ HMX 6 SPF guns. Tag j PBTD ck at flag at 102 5' drop 1/2" ball to fire guns with Top shot at 10080' bottom shot at 10110' ***Job in Pro ress*** j 10/2/2009 CTU#5 1.75" CT [1.34 wall] Job scope add perfs POOH with guns run #4. I Freeze protect well with 38 bbls of 50/50 methanol. At surface all gun fired R/D land move to E-35 '"'""'Job complete"""""~' z ____ ~ ____ __.. ~____ _. _ _ FLUIDS PUMPED BBLS 60 1% KCL 53 60/40 METH 211 50/40 METHANOL 324 TOTAL /0 300- 3~~ /e Zon-23o la JSo-/8o / pO~V' 1 iv Zia ~+~ ri.--~ BAKER MV6F~E5 Baker Atlas PRINT DISTRIBUTION LIST CUMYANY BY EXYLUKA"1'lUN (ALASKA) INC WELL NAME H-13A CUUN7'Y NUK'fH SLUYE BUKUUGH STATE ALASKA FIELD PRUDHOE BAY UNIT THIS DISTRIBUTION LIST AUTHORIZED BY: DATE 8/27/2009 CATRINA GUIDRY SO #: 2636462 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKAI INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: ~ ,~r~l Page 1 of 1 INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: ChristinE Mahnken Reference: H-13A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 2636462 ~cgl - c~-l~i l ~~-/MI5 Sent by: Catrina uidry Date: 08/27/09' ~ ' Received by: Date: AtJG 2 $ 2009 v v • ~iE has Cons. Corn~mission PLEASE ACKNOWLEDGE RECEIPT BY SIGNING ~~'URNING OR FAXING YOUR COPY FAX: (907) 267-6623 ®' i .,, ..,.i Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 08/05/09 ~~~~ N0.5329 Alaska Data & Consulting Services Company: State of Alaska ?_528 Gambell Street, Suite 40o Alaska Oil & Gas Pons Comm Anchorage, AK 99503-2838 Attn: Christine Msahnken AFl'M: Oeth 333 West 7th Ave, Suite 100 Anchorage, AK 9<I501 Well Job # Log Description Date BL Color CD P-216 AWJI-00039 MEM PROD PROFILE - 07/14/09 1 1 P2-12 AXWS-00013 PRODUCTION PROFILE 07/12/09 1 1 C-36A AY1M-00017 IBP SET RECORD W/CROSSFLOW G d 07/08/09 1 1 W-45 AXBD-00035 MEM TEMP & PRESS SURVEY ~ c ~ 07/09/09 1 1 H-13A B2NJ-00009 MCNL L L f L 06/17!09 1 1 F-OSA AY1M-00028 RST G 07/01/09 1 1 01-18 AY3J-00038 _ CH ED T P C TBG PUNCH/JEWELRY LOG 07/10/09 1 . --. ~-~ ..-.~.-•• •• ~~.•.. ~- ..~...-.. ... , .,..a......a .vnv nc ~ a~rnvmu vwc ~.vr r Llilin ~ VG 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 STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~i~~ JUL. 1 6 2009 tiasl~~ ail Cis Cons. Commission 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.~os zoAACZS.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class:AttC 01'e~t? ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 6/1 2009 12. Permit to Drill Number 209-044 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/8/2009 ~ 13. API Number 50-029-20559-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 6/14/2009 ~ 14. Well Name and Number: PBU H-13A` 1652 FNL, 1264 FEL, SEC. 21, T11N, R13E, UM Top of Productive Horizon: 1277' FNL, 887' FWL, SEC. 22, T11 N, R13E, UM 8. KB (ft above MSL): 82.6' ~ Ground (ft MSL): 45.35' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1813' FNL, 1730' FWL, SEC. 22, T11N, R13E, UM 9. Plug Back Depth (MD+TVD) 10353' ~ 8902' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 643332 y- 5959136 Zone- ASP4 10. Total Depth (MD+TVD) 10390' 8899' 16. Property Designation: ADL 028284 TPI: x- 645475 y- 5959553 Zone- ASP4 Total Depth: x- 646329 y- 5959033 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No mi I ctr ni n rint d information r 2 AA 25. 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (11JD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 2 C 25.071) MWD DIR / RES / GR, MCNL ! GR / CCL ~iVODL/~ O~~ ~ Q ~~59~ `T : YO 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu ds Concr to 13- / " 2# L-80 urf 5' rf 17-1/2" 3 rm frost II 9-5/ " 47# L-80 Surface 8 06' Surfa 89 6' 12-1/4" 1208 cu ft'G' 130 cu ft Permafrost'C' 7" 29# L-80 8411' 4' 8048' 8676' 8-1/2" 380 cu ft CI s 'G' 3-1/2" x 3-3/16" 9.2# / 6.2# L- 75' 1 3 1 889 ' 4-1/ " 124 cu C x 2-7/8" / 6.16# 23. Open to production or inject ion? ®Yes ^ No 24. fiuawc RECORD If Yes, Ilst each i (MD+TVD of Top & Bottom; Pe nterval Open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter 6 spf 5-1/2", 17# x 4-1/2", 12.6#, L-80 8466' 8335' , MD TVD MD TVD 10120' - 10320' 8904' - 8905' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with Diesel 26. PRODUCTION TEST Date First Production: July 12, 2009 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date Of Test: HOUfS Tested: No Test Yet PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-I'IOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ..L I ION None ~ 0~~ A -r_,..,,,d,~,,,~ Form 10-407 Revised 02/2007 CoNTINUeD ,. ~~~~(~ ~ 6 249 ,_..~~~ ~~a3 ~° 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND S ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. 42N /Zone 4A 9181' 8758' None Top CGL /Zone 3 9284' 8830' Base CGL /Zone 3 9430' 8905' Base CGL /Zone 3 9851' 8909' Formation at Total Depth (Name): Base CGL /Zone 3 9851' 8909' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. C~7 ~ Signed Terrie Hubble Title Drilling Technologist Date ~ °~d PBU H-13A 209-044 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number P rmi No. / A royal No. Drilling Engineer: Sean McLaughlin, 564-4387 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPf (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. heal 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITene 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • BP EXPLORATION Operations Summary Report Page 1 of 9 Legal Well Name: H-13 Common Well Name: H-13 Spud Date: 4/24/1981 Event Name: REENTER+COMPLETE Start: 6/6/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date III From - To Il Hours ', Task Code NPT Phase Description of Operations 6/6/2009 109:00 - 11:00 _._ __ __ _- 2.00 ~ MOB P PRE Set rig down on R Pad. PU mats and clean up around R-21 11:00 - 15:00 I 4.001 MOB I P I I PRE 15:00 - 20:00 I 5.001 MOB I P I I PRE 20:00 - 22:30 I 2.501 MOB I P I I PRE 22:30 - 00:00 1.50 MOB P PRE 6/7/2009 00:00 - 02:00 2.00 MOB P PRE 02:00 - 03:00 1.00 MOB P PRE 03:00 - 08:00 5.00 BOPSU P PRE 00:00 - 15:05 5.25 BOPSUR P PRE 15:15 - 16:45 1.50 RIGU P PRE 16:45 - 18:00 1.25 RIGU P PRE 18:00 - 18:30 0.50 STMILL P WEXIT 18:30 - 22:30 4.00 STMILL P WEXIT 22:30 - 23:00 0.50 STMILL P WEXIT 23:00 - 00:00 1.00 STMILL P WEXIT 6/8/2009 00:00 - 00:45 0.75 STMILL P WEXIT 00:45 - 01:30 0.75 STMILL P WEXIT 01:30 - 04:10 2.67 STMILL P WEXIT 04:10 - 08:00 3.83 ILL I 08:00 - 09:10 1.17 STWHIP P WEXIT Post Pad Inspection w/ DSO Tool Service continuing to lay rig mats on R Pad access road Use 75T crane to set 13-5/8" stack on transport skid WO Tool Service to lay mats on R Pad access road. Original plan was to use plywood on one side, but a TS THA determined that the sheets weighed too much and it was too windy to safely use them Move new shaker into place SWS replace worn gripper blocks and service injector Move office trailer to H Pad w/ Security escort Move rig off R Pad and onto access road. Move rig over one mile of rig mats to the Spine Road stopping one time to back up on double mats. Turn onto Spine & the onto GC2 Access road. Tool Service laying rig mats over GC2 pipeline. Move rig onto H pad. RD tree cap. Move tree scaffolding away from well. ND XO on bottom of BOP's. Spot cellar plywood. Spot Herculite liner. Spot T mats. Spot rig mats. Spot rig over well. Rig accept at Sam. RU Handy berm. NU BOP's. Spot cuttings box. Spot office trailer. Take on rig water. RU lubricator. Continue installation of new shaker. Install electrical to shaker Prep injector/gooseneck. Pull CT to floor and stab into injector BOPE test. The States right to witness was waived by Chuck Scheve Continue installation of new shaker PU injector, seal end of wire. Adjust wt cell Finish installation of new shaker. Reinstall railings and wall Fluid pack CT. Pump slack back. PT packoff and inner reel valve as part of BOPE test MI Swaco install screens on shaker and adjust Welder install piperack beam Crew chg/safety mtg Blow back coil. Pop off well. RU coil cutter. Cut coil - 70ft to find wire. RD coil cutter. Test wire. Dress coil. Install SLB CTC & pull test to 40k. Behead BHI. Pressure test CTC &BHI UOC to 4k. Open well, Opsi. Flow check. MU window milling BHA per program. Window mill was 3.80" no-go. RIH, cir 0.4bpm/240psi, taking returns to Tiger tank, mostly diesel & minor amounts gas. Continue to RIH. Wt ck at 8600', 36k up, 27k down. Increase rate to 2.5bpm/2100psi. Log down for tie-in from 9000' (-18ft corr. Mill cement from 9066ft to 9084ft using 2.5bpm/2500psi w/ 1.5-2.5K Ibs WOB. i win ow rom using pm psi w - s WOB. Mill O.ift every 6min. Mill from 9087.0' 2.42/2400 w/ 0-100 psi diff, 1.5-2.5k wob w/ 9.55 ECD Printed: 6/29/2009 3:05:26 PM BP EXPLORATION Operations Summary Report Page 2 of 9 ~ Legal Well Name: H-13 Common Well Name: H-13 Spud Date: 4/24/1981 Event Name: REENTER+COMPLETE Start: 6/6/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To ' Hours I Task Code NPT Phase Description of Operations 6/8/2009 09:10 - 09:55 0.75 STWHIP P WEXIT Mill from 9088.0' 2.41/2330 w/0-100 psi diff, 1.5-2.Ok wob w/ 9.54 ECD Mill to 9088.75'. PUH clean to chk freespin. Ream back down 09:55 - 11:00 1.08 STWHIP P WEXIT Mill from 9088.75' w/ 2.40/2020 w/ 100-300 psi diff, -2.Ok wob w/ 9.54 ECD 11:00 - 12:00 1.00 STWHIP P WEXIT Mill from 9090.0' w/ 2.4/2020 w/ 200 psi diff, 1.6-2.3k wob w/ 9.54 ECD 12:00 - 12:45 0.75 STWHIP P WEXIT Mill from 9091.0' at increased penetration rate and appear to_ have exited window b 9093' 12:45 - 13:50 1.08 STWHIP P WEXIT Drill from 9095.0' 2.40/2020 w/ 250 psi diff, 2.0-3.Ok wob w/ 9.55 ECD Drill to 9103' 13:50 - 14:45 0.92 STWHIP P WEXIT Backream and ream. Dry tag was clean 14:45 - 16:15 1.50 STWHIP P WEXIT POOH circ thru mill 2.47/2220 16:15 - 17:15 1.00 STWHIP P WEXIT LD milling BHA 17:15 - 18:00 0.75 DRILL P PROD1 MU build BHA w/ used bi bit, 3.2 deg motor w/ res tool 18:00 - 19:45 1.75 DRILL P PROD1 RIH w/ BHA #2 circ thru EDC 19:45 - 19:55 0.17 DRILL P PROD1 Log down for tie-in from 9010ft (-18ft corr. 19:55 - 20:05 0.17 DRILL P PROD1 Continue to RIH w/ build section BHA. Run through window - clean. 20:05 - 20:50 0.75 DRILL P PROD1 Drill build section from 9105ft.' varies due to vibrations/2200/0 TF w/ 200 - 500 psi MW ECD=9.50 ppg 1-3k Ibs DHWOB ROP's=15 to 40 FPH PVT = 99 (conducting mud swap to new Geovis) Drill to 9,112 ft. 20:50 - 22:50 2.00 DRILL N DFAL PROD1 POH for tool failure. 22:50 - 23:00 0.17 DRILL N DFAL PROD1 Tag up. Flow check. Close EDC. Pop off. Blow BHA. LD BHA. Inspect motor & bit - ok, milk motor - ok. Test line - ok. 23:00 - 23:50 0.83 DRILL N DFAL PROD1 MU new BHI coil track tools & same 3.2AK0 motor & Hycalog bit. 23:50 - 00:00 0.17 DRILL N DFAL PROD1 RIH w/ BHA #3. 6/9/2009 00:00 - 01:35 1.58 DRILL N DFAL PROD1 Continue to RIH w/ BHA #3. 01:35 - 01:50 0.25 DRILL N DFAL PROD1 Log down for tie-in from 9010ft (-19ft corr. 01:50 - 02:00 0.17 DRILL N DFAL PROD1 Continue to RIH. Close EDC. Slight bobble through window. 02:00 - 05:25 3.42 DRILL P PROD1 Drill build section from 9113ft. ', 2.4/2125/0-100 R w/ 200 - 300 psi MW ~~ ECD=9.11 ppg 1-3k Ibs DHWOB ROP's=15 to 75 FPH PVT = 349 Drill to 9246ft 05:25 - 05:35 0.17 DRILL P PROD1 Wiper to the window & to TD -clean. 05:35 - 06:30 0.92 DRILL P PROD1 Drill build section from 9246ft. 2.5/2200/75-900 R w/ 200 - 300 psi MW ECD=9.22 ppg 1-3k Ibs DHWOB ROP's=45 to 150 FPH PVT = 350 Drill to 9300' 06:30 - 10:30 4.00 DRILL P PROD1 fr 300' w/ numerous stalls hi h vibs, having to surrey off bottom Drill w/ 2.47/2530/90L w/ 100-300 psi diff, 0.5-2.5k wob w! 9.22 Printetl: 6/29/2009 3:05:26 PM ~~ BP EXPLORATION Page 3 of 9 Operations Summary Report Legal Well Name: H-13 Common Well Name: H-13 Spud Date: 4/24/1981 Event Name: REENTER+COMPLETE Start: 6/6/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: .Date From - To Hours Task ~~ Code NPT ' Phase_~' Description of Operations 6/9/2009 06:30 - 10:30 4.00 DRILL P PROD1 ECD. Drill in spurts of 10-20'/hr, then 60-100'/hr. Assume top of Z3 -9350' when P rate went to avg 20'/hr. Add more and more wt to bit and won't stall. Drill to 9400' 10:30 - 10:45 0.25 DRILL P PROD1 Wiper thru window was clean 10:45 - 12:15 1.50 DRILL P PROD1 Open EDC. POOH for bit circ thru EDC 3.78/2830 12:15 - 13:15 1.00 DRILL P PRODi At surface. Get off well. Unstab coil. Change out bit (6-2-1) for Hyc bi-center. Stab coil. Test tools. 13:15 - 14:30 1.25 DRILL P PROD1 Run in hole. 14:30 - 15:00 0.50 DRILL P PROD1 Log GR tie in. Subtract 20' correction. 15:00 - 15:30 0.50 DRILL P PRODi Run in hole. Wlndow smooth. Some motor work in build. 15:30 - 23:45 8.25 DRILL P PROD1 Drill ahead from 940 '. 2230 psi fs at 2.49 bpm in/out. 200-300 psi motor work. 1-3k dhwob. ECD's 9.1 Drill to 9500'. 23:45 - 00:00 0.25 DRILL P PROD1 POH. 6/10/2009 00:00 - 03:00 3.00 DRILL P PROD1 Continue to POH. Rubber coming over the shaker. Open EDC & jet 4bpm/3000psi. Got lots of cuttings over the shaker. Jog in/out 100ft from surface. 03:00 - 04:40 1.67 DRILL P PROD1 Tag up. Flow check. Pop off well. Blow down & LD BHI coil trac tools. Reconfigure coil trac tools for next run & test same. LD motor & bit. Bit was 7-2 w/ rubber inside. 04:40 - 05:30 0.83 DRILL P PROD1 MU lateral BHA (1.2 deg mtr w/ Hyc bi-center). Get onto well. Power up & test tools. Set counters. 05:30 - 07:00 1.50 DRILL P PROD1 RIH w/ BHA #5. 07:00 - 07:15 0.25 DRILL P PROD1 Log GR tie in . 07:15 - 07:45 0.50 DRILL P PROD1 Wiper trip to TD. Build section smooth, even with 1.2 deg lateral BHA. 07:45 - 11:15 3.50 DRILL P PROD1 Drill ahead from 9500'. 2250 psi fs at 2.50 bpm in/out. 200-300 psi mtr work. 2-3k# dhwob. BHP/ECD: 4187 psi / 9.14 ppg. IA/OA PVT: 31 psi / 23 psi. PVT: 295 bbls. ROP: 50-80 fph. A lot of BHA vibration while drilling. Resistivity decreasing. Decide to climb +/- 30' TVD. Drill to 9631'. 11:15 - 12:15 1.00 DRILL P PROD1 Make wiper trip to window. 2200 psi fs at 2.54 bpm in/out. PVT: 285 bbls. 12:15 - 14:15 2.00 DRILL P PROD1 Drill ahead from 9631'. 2210 psi fs at 2.52 bpm in/out. 300 psi mtr work. Drill to 9750'. 14:15 - 15:00 0.75 DRILL P PROD1 Make wiper trip to window. Did not see shales at 9230' or 9245'. 15:00 - 20:10 5.17 DRILL P PROD1 Drill ahead from 9750'. 2350 psi fs at 2.66 pm in/out. 200-300 psi mtr work. 2-3k# dhwob. BHP/ECD: 4245 psi / 9.25 ppg. IA/OA PVT: 106 psi / 228 psi. PVT: 245 bbls. ROP: 50-80 fph. Still having a lot of BHA vibration while drilling. Drill to 9900' w/ 11ohm rock. 20:10 - 22:10 2.00 DRILL P PROD1 Wiper to the window, clean in the hole section. Open EDC & jet 7" liner 3.85bpm ~ 30'/min, PUH to 7500ft. Lots of cuttings going over the shaker. 22:10 - 22:35 0.42 DRILL P PROD1 Log down for tie-in from 9000' (+3' corr. Printetl: 6/29/2009 3:OS26 PM ~ ~ BP EXPLORATION Page 4 of 9 Operations Summary Report Legal Well Name: H-13 Common Well Name: H-13 Spud Date: 4/24/1981 Event Name: REENTER+COMPLETE Start: 6/6/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To I', Hours Task 'Code NPT Phase Description of Operations 6/10/2009 22:35 - 23:15 0.67 DRILL P PROD1 Close EDC. Wiper to TD w/ reduce rate through build section - clean. 23:15 - 00:00 0.75 DRILL P PROD1 Drill ahead from 9900'. 2400 psi fs at 2.70 bpm in/out. 200-300 psi mtr work. 2-4.5k# dhwob. BHP/ECD: 4250 psi / 9.27 ppg. IA/OA PVT: 96 psi / 358 psi. PVT: 243 bbls. ROP: 10-80 fph. DHT=150F ST=106F 6/11/2009 00:00 - 00:45 0.75 DRILL P PROD1 Continue to drill from 9920'. 2400 psi fs at 2.70 bpm in/out. 200-300 psi mtr work. 2-4.5k# dhwob. BHP/ECD: 4250 psi / 9.25 ppg. ROP: 10 fph. Stacking & won't stall, last sample had lots of chert. Drill to 9926'. 00:45 - 04:00 3.25 DRILL P PROD1 POH for new bit. OH section was clean. Open EDC & jet while POH 3.5bpm/2900psi. Jog in/out 04:00 - 04:30 0.50 DRILL P PROD1 Tag up. Flow check. Pop off. Short chain BHA & remove bit (cored 8-3). Inspect motor - ok. MU new T-rex HYC bit & same BHA & motor. 04:30 - 06:00 1.50 DRILL P PRODi RIH w/ BHA #6. 06:00 - 06:30 0.50 DRILL P PROD1 Log GR tie in from 9000'. Subtract 11' correction. 06:30 - 07:00 0.50 DRILL P PRODi Make wiper trip at 1.5 bpm rate to end of build. Set down on small ledge at +/- 9250'. Orient to 90R and pass through ok. Continue wiper to TD. 07:00 - 12:15 5.25 DRILL P PROD1 Drill ahead from 9926'. 2320 psi fs at 2.60 bpm in/out. 400-500 psi mtr work. 2-2.5k# dhwob. IA/OA/PVT: 43 psi / 1 psi / 201 bbls. BHP/ECD/TVD: 4244 psi / 9.26 ppg / 8826 ft. Drill ahead in Zone 2-3 interface. ROP: 20-40 fph. A lot of chert in samples. Good resistivity (10-11 ohms). Drill to 10,050'. 12:15 - 13:15 1.00 DRILL P PROD1 Make wiper trip to window. Hole smooth. 13:15 - 14:00 0.75 DRILL P PROD1 Drill ahead from 10050'. ROP WOB combination indicate bit is worn. 14:00 - 17:30 3.50 DRILL P PROD1 Wiper to window. Open EDC. Clean out 7". Circulate out of hole. 3200 psi at 3.72 bpm. Increased and steady amount of solids at shaker with increased pump rate. 17:30 - 18:30 1.00 DRILL P PROD1 At surface. Get off well. Short chain BHA & remove bit (6-5), motor was good. MU new bit. 18:30 - 20:00 1.50 DRILL P PROD1 RIH w/ BHA #7. 20:00 - 20:10 0.17 DRILL P PROD1 Log down for tie-in from 9025' (-10' corr. 20:10 - 20:40 0.50 DRILL P PROD1 Wiper to TD w/ reduce rate through build section -clean. 20:40 - 23:30 2.83 DRILL P PROD1 Drill ahead from 10,050'. 2930 psi sat pm in/out. 400-500 psi mtr work. 2-2.5k# dhwob. IA/OA/PVT: 28 psi / 1 psi / 192 bbls. BHP/ECD/TVD: 4324 psi / 9.44 ppg / 8823 ft. Bottom's up was chert w/ pyrite. Drill to 10,086'. Low ROP & high WOB. 23:30 - 00:00 0.50 DRILL P PROD1 POH for new bit. 6/12/2009 00:00 - 02:00 2.00 DRILL P PROD1 Continue to POH. Nnntea: tiizaizuua 3:US:Ltl YM BP EXPLORATION Page 5 of 9 Operations Summary Report Legal Well Name: H-13 Common Well Name: H-13 Spud Date: 4/24/1981 Event Name: REENTER+COMPLETE Start: 6/6/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: i ' ' t Phase Description of Operations , Task Code NPT I From - To Hours Date -._r -- 6/12/2009 02:00 - 03:00 1.00 DRILL P PROD1 Tag up. Flow check. Pop off. Short chain BHA & remove bit (cored 8-3). Inspect motor - ok. MU new HCC bi-center bit & same BHA & motor. 03:00 - 04:40 1.67 DRILL P PROD1 RIH w/ BHA #8. 04:40 - 04:55 0.25 DRILL P PROD1 Log down for tie-in from 9100' (-5' corr. 04:55 - 05:30 0.58 DRILL P PROD1 Wiper to TD w/ reduce rate through build section -clean. 05:30 - 09:30 4.00 DRILL P PROD1 Drill ahead from 10,086'. 2700 psi fs at 2.70 bpm in/out. 400-500 psi mtr work. 2-2.5k# dhwob. IA/OA/PVT: 28 psi / 10 psi / 241 bbls. BHP/ECD/TVD: 4324 psi / 9.44 ppg / 8820 ft. Drilling parameters indicates bit is likely shot. Drill to 10,150'. 09:30 - 11:30 2.00 DRILL P PROD1 Wiper to window. Open EDC. Circulate out of hole. 11:30 - 12:00 0.50 DRILL P PROD1 Jog in and out of hole. SLB mechanic adjusting injector hydraulics. 12:00 - 12:45 0.75 DRILL P PROD1 Get off well. Change HCC bicenter (8-5-I) to Smith re-build bi-center with "hard rock" cutters. Check BHA for wear. Get on well. 12:45 - 14:30 1.75 DRILL P PROD1 Run in hole. Circ at min rate. 14:30 - 15:00 0.50 DRILL P PROD1 Log gr tie in from 8950'. Subtract 5' correction. 15:00 - 15:30 0.50 DRILL P PRODi Run in to open hole. 15:30 - 17:40 2.17 DRILL P PROD1 Drill ahead from 10150'. Tag btm and drill 0.5 ft at 1.65 bpm to establish a pattern for bit. 2400 psi fs at 2.51 bpm in/out. 200-300 psi mtr work. 2k# dhwob. BHP/ECD/TVD: 4347 psi/9.49 ppg/ 8821 ft. Reduced flow rate used to control vibration. ROP: 15-30 fph. Some stalling. Drill to 10,180' 17:40 - 20:30 2.83 DRILL P PROD1 Wiper to window. Open EDC. Circulate out of hole. 20:30 - 21:15 0.75 DRILL P PROD1 Tag up. Flow check. Pop off. Short chain BHA & remove bit (cored 6-2). Inspect motor - ok. MU new HYC T-rex bi-center bit & same BHA & motor. 21:15 - 23:00 1.75 DRILL P PROD1 RIH w/ BHA #10. 23:00 - 23:10 0.17 DRILL P PROD1 Log down for tie-in from 9100' (-6' corr. 23:10 - 23:40 0.50 DRILL P PROD1 Wiper to TD w/ reduce rate through build section -clean. 23:40 - 00:00 0.33 DRILL P PROD1 Drill ahead from 10180'. Lightly tag btm & establish a pattern for the bit. 2800 psi fs at 2.7 bpm in/out. 200-300 psi mtr work. 2-3k#dhwob. BHP/ECD/TVD: 4366 psi/9.53 ppg/ 8820 ft. ROP: 15-30 fph. 6/13/2009 00:00 - 03:20 3.33 DRILL P PROD1 Drill ahead from 10180'. 2800 psi fs at 2.7 bpm in/out. 200-300 psi mtr work. 2-3k# dhwob. BHP/ECDlTVD: 4366 psi/9.53 ppg/ 8820 ft. ROP: 15-30 fph. Drill to 10,255'. F'flfl[(?tl: ti/ly/LUU`J :i:US:Lti NM ~ ~ BP EXPLORATION Page 6 of 9 Operations Summary Report Legal Well Name: H-13 Common Well Name: H-13 Spud Date: 4/24/1981 Event Name: REENTER+COMPLETE Start: 6/6/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours I' Task Code NPT Phase Description of Operations 6/13/2009 03:20 - 06:00 2.671 DRILL P PROD1 POH for new bit. Wiper to window. 06:00 - 07:00 I 1.001 DRILL I P 07:00 - 10:00 3.00 DRILL P PROD1 PROD1 10:00 - 11:30 I 1.501 DRILL I P I I PROD1 11:30 - 13:15 1.75 DRILL P PROD1 13:15 - 13:30 0.25 DRILL P PROD1 13:30 - 14:00 0.50 DRILL P PROD1 14:00 - 16:00 2.00 DRILL P PROD1 16:00 - 18:45 2.75 DRILL P PROD1 18:45 - 20:00 1.25 DRILL P PROD1 20:00 - 21:40 1.67 DRILL P PROD1 21:40 - 21:50 0.17 DRILL P PROD1 21:50 - 22:15 0.42 DRILL P PROD1 22:15 - 00:00 1.75 DRILL N DFAL PROD1 6/14/2009 00:00 - 00:30 0.50 DRILL N DFAL PROD1 00:30 - 01:40 1.17 DRILL N DFAL PROD1 01:40 - 03:20 1.67 DRILL N DFAL PROD1 03:20 - 03:30 0.17 DRILL N DFAL PROD1 03:30 - 04:10 0.67 DRILL N DFAL PROD1 04:10 - 05:05 0.92 DRILL P PROD1 05:05 - 06:00 0.921 DRILL N DFAL PRODi 06:00 - 06:30 0.50 DRILL P PROD1 06:30 - 08:00 1.50 DRILL N DFAL PROD1 08:00 - 09:00 1.00 DRILL N DFAL PROD1 09:00 - 10:30 1.50 DRILL N DFAL PROD1 10:30 - 11:00 0.50 BOPSU P PRODi 11:00 - 12:00 1.00 DRILL N DFAL PROD1 12:00 - 14:00 2.00 DRILL N DFAL PROD1 14:00 - 14:15 0.25 DRILL N DFAL PROD1 Open EDC. Circulate out of hole. Get off well. Unstab coil. Stand back BHA. Bit was 8-3. Smith bicenter is not effective in Zone 3. Rig up to manage a-coil slack. Reverse circ 3.3 bpm at 2850 psi. Heard a-line movement inside reel. Cut 40' coil and 10' a-line. MU and test a-coil head. MU lateral BHA. Change out some Inteq tools. Re-run motor. Stab coil. Test tools. Get on well. Run in hole. Log gr tie in from 8980'. Subtract -6 correction. Wiper in hole to btm. Hole smooth. Drill ahead from 10,255'. 2600 psi fs at 2.58 bpm in/out.200-350 psi fs Start out with low WOB to establish pattern. Drill to 10,291'. Bit is toast. Circulate out of hole. 2827 psi fs at 2.58 bpm in. Tag up. Flow check. Pop off. Blow down BHA. LD BHA & remove bit 7-3. Inspect motor - ok. MU new BHA, new HYC DS49 PDC bit & new motor. RIH w/ BHA #12. Log down for tie-in from 9000' (-5' corr. Wiper to TD w/ reduce rate through build section -clean to 9800'. p POH, HOT is toast. rTVC'c~c~`~ot.~,~ ~` Continue to POH. Tag up. Flow check. Pop off. Blow down BHA. LD BHA & replace HOT. MU BHA. RIH w/ BHA #13. Log down for tie-in from 9000' (-5' corr. Wiper to TD w/ reduce rate through build section -clean. Drill ahead from 10,290'. _ 2940 psi fs at 2.58 bpm in/out.200-350 psi fs Start out with low WOB to establish pattern. Drill to 10,324'. HOT is toast. , POH for new HOT. Wiper to window -clean. Open EDC. Circulate out of hole. Log tubing tail for TOL placement. Continue to POH. LD BHA. Inspect injector after hearing noise. t ou Function test BOPs. Make up replacement lateral BHA. With 3-3/4" Hycalog t-rex bit. Run in hole. Circ at min rate. Log gr tie in from 8980'. Subtract 5' correction. Printed: 6/29/2009 3:05:26 PM ~ ~ BP EXPLORATION Operations Summary Report Page 7 of 9 ~ Legal Well Name: H-13 Common Well Name: H-13 Spud Date: 4/24/1981 Event Name: REENTER+COMPLETE Start: 6/6/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task 'Code' NPT Phase Description of Operations 6/14/2009 14:15 - 15:00 0.7! )RILL (N ~ DPRB PROD1 Run in hole. Maintain as drilled TF. 15:00 - 16:45 1.751 DRILL N ~ DPRB ~ PROD1 16:45 - 17:30 0.75 DRILL N DPRB PROD1 17:30 - 19:05 1.58 DRILL N DPRB PROD1 19:05 - 19:25 0.33 DRILL N DPRB PROD1 19:25 - 20:10 0.75 DRILL P PROD1 20:10 - 22:00 1.83 DRILL N DFAL PROD1 22:00 - 23:55 1.92 DRILL P PROD1 23:55 - 00:00 0.08 DRILL P PROD1 6/15/2009 00:00 - 01:20 1.33 DRILL P PROD1 01:20 - 02:00 0.67 DRILL P PROD1 02:00 - 03:20 1.33 DRILL P PROD1 03:20 - 07:15 3.92 DRILL P PROD1 07:15 - 08:15 1.00 DRILL P PRODi 08:15 - 10:30 2.25 CASE P RUNPRD 10:30 - 15:30 5.00 CASE P RUNPRD 15:30 - 18:00 2.50 CASE P RUNPRD 18:00 - 22:10 4.17 CASE P RUNPRD 22:10 - 22:25 0.25 CASE P RUNPRD Unable to get past ledge at 9234'. Try several TF changes, pump rates, running speeds. Hard set down, no progress. Pull out of hole. Hold PJSM in Ops Cab. Get off well. Change out bit to Hyc bicent trex, and AKO to 1.8 deg. Stab coil. Test tools. Get on well. Run in hole. Log down for tie-in from 9000' (-oft corr. Wiper to TD w/ reduce rate through build section -clean. 8nhble at 10.302'. HOT failed. RIH w/ min rate & taa bottom 10,324'. POH. Slowly wiper up hole & back to TD -clean. Drill ahead from 10,324'. 2800 psi fs at 2.58 bpm in/ 2.4bpm out. 200-350 psi fs 2-3k# dhwob. BHP/ECD/TVD: 4390 psi/9.58 ppg/ 8823 ft. ROP: 15-50 fph. PVT = 296 Drill to 10,390'. Call it TD. / Wiper to the window -clean. Continue to wiper to the window -clean. Open EDC &PUH. Log down for tie-in from 9000' (+2' corr. Slowly PUH to 8170'. Log CCL down across tubing tail for TOL placement. Close EDC & wiper to TD. Set down at 9234', bobble past (unable to steer). Continue to wiper to TD. Tag bottom at 10,390' POH. Slowly PUH through 9234' area. RIH w/out pumps. Won't go. Got it past w/ 0.5bpm. Slowly PUH & work area -clean. Open EDC & circ OOH. Paint EOP flag at 8300'. Hold PJSM in ops cab. Flow check. Get off well. Unstab coil. LD Inteq tools. Rig up floor to run liner. Bring tools to floor. Hold PJSM to discuss running liner. Pump slack. Cut wire. MU coil connector. Test same. MU 4 jts 2-7/8", 57 jts 3-3/16" and one jt 3-1/2" STL/TCII with cementralizers and jewelry. MU SELRT tool and 2 jts PH6 tbg w/disconnect. Stab coil. Get on well. Run in hole. 42k# up wt at 9050 ft. Continue to run in hole. Tag at 10,390' & flag is at the horses head -perfect, good job att. C/O w/ day crew. PUH to ball drop position. Perform UO on reel. Drop 5/8" steel ball w/ 2% slick KCL. Ball on seat at 43.2 bbls away, sheared at 3300psi. PUH -released from liner. Swap well to 2% slick KCL, 2.88bpm in/2.75bpm out. Final rate 2.91 bpm in / 2.81 bpm out C~ 1685psi, 1.57bpm in / 1.46bpm out C~ 640psi. RU SLB cementers. Mix 135bb1s of 2ppb biozan PJSM regarding cementing Ops. Printed: 6/29/2009 3:05:26 PM BP EXPLORATION Page 8 of 9 Operations Summary Report Legal Well Name: H-13 Common W ell Name: H-13 Spud Date: 4/24/1981 Event Nam e: REENTE R+COM PLET E Start : 6/6/2009 End: Contractor Name: NORDIC CALIST A Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/15/2009 22:25 - 23:15 0.83 CASE P RUNPRD C-pump 2% KCL to SLB unit. Prime up w/ 2% slick KCL & batch up SLB cement unit. Cement is at weight at 23:00. Pump 2ppb bio to the reel iron, 4.5bbls to catch fluid. Pressure test SLB cement line to 4000psi. 23:15 - 00:00 0.75 CEMT P RUNPRD Pump 22bbls 15.8ppg class 'G' cement at 1.7bpm. Displace with 135bb1s of 2% slick KCL w/ 2ppb biozan, followed by 2% slick KCL. Simultaneously, clean up SLB cement truck. 6/16/2009 00:00 - 00:30 0.50 CEMT P RUNPRD SD pumps, PUH 13' & exhaust 2 bbls of cement out of coil, 4.5bbls total pumped. Sting back into deployment sleeve, set down as same depth previously when we released from the liner. Attempt to lauch LWP, didn't see any pressure spike & getting returns. SD pumps. PUH higher - 15' & sting back into liner, same depth. LWP launched early! Displace LWP &LWP landed 4bbls early. Pressure upto 2500psi. Check floats - ok. Pressure up 1000psi & unstinq. At least 16.8bbls of cement behind i e. Worst case TOC = 8550' (inside 7"), however 2 bbls of exhausted cement maybe inside the finer. 00:30 - 02:15 1.75 CEMT P RUNPRD POH pumping w/ 0.1 bpm returns. 02:15 - 05:15 3.00 CEMT P RUNPRD Tag up. Flow check. Pop off well. LD SELRT BHA (minor amts of cement on BHA). MU mill BHA. 05:15 - 06:30 1.25 CEMT N DFAL RUNPRD RIH w/ mill BHA. Circ min rate. Swap active system to slick 2%KCI w/ 2ppb biozan. Wt ck at 8000', 31 k up , 22.5 RIW. 06:30 - 12:30 6.00 CEMT P RUNPRD D to at 8389'. PUH. Mill deployment bushing from 8388'. 1.62bpm in/out ~ 1900psi. Mill ahead. Several stalls. Time mill ahead very slowly 12:30 - 13:45 1.25 CEMT N DFAL RUNPRD Run in hole. 1910 psi fs at 1.65 bpm. Ta PBDT at 10,353' uncorrected) No hard or soft cement noted. 13:45 - 14:45 1.00 CEMT N DFAL RUNPRD Monitor btms up for signs of cement. Trace of ranular cement noted in btms u onl . 14:45 - 16:30 1.75 CEMT N DFAL RUNPRD Hold PJSM in ops cab. At coil connector. 16:30 - 19:45 3.25 CEMT N DFAL RUNPRD Get off well. Unstab. Drop ball and open circ sub. Stand back CSH in derrick (32 stands). LD one single and clean out tools. 19:45 - 22:35 2.83 EVAL P LOW ER1 PJSA for PU & MU of logging BHA PU & MU SLB memo to in tools on CSH BHA 22:35 - 00:00 1.42 EVAL P LOWERi RIH with SLB memory logging tools 6/17/2009 00:00 - 02:25 2.42 EVAL P LOW ER1 Log from 8,000' to PBTD ~ 30fpm Tag PBTD ~ 10,353' Log rom PB D to 8,1 0 60fpm 02:25 - 04:25 2.00 EVAL P LOWERi POH to surface PJSA for Standing back injector &CSH into derrick & UD logging tools 04:25 - 06:30 2.08 EVAL P LOWERI Stand back injector on floor &CSH into derrick LD logging tools Process log data. 06:30 - 07:45 1.25 EVAL P LOWERI Hold PJSM. Pressure test liner lap to 2000 psi. Hold for 30 minutes. Printed: 6/29/2009 3:05:26 PM • BP EXPLORATION Page 9 of 9 Operations. Summary Report Legal Well Name: H-13 Common Well Name: H-13 Spud Date: 4/24/1981 Event Name: REENTER+COMPLETE Start: 6/6/2009 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/17/2009 06:30 - 07:45 1.25 EVAL P LOWERi Record same. Good test, bleed off to 1965 after 30 min. Bleed down tbg. 07:45 - 09:30 1.75 PERFO P LOWERI Hold PJSM. Load pipe shed with guns. Bring tools to rig floor. MU 20 2". 6sof.2006PJ nuns on a-fire head, on 64 its CSf 09:30 - 11:45 11:45 - 14:00 2.25 2.25 PERFO PERFO P P LOWERi LOWERi MU pert BHA. Run 64 jts 1-1/4" CSH from derrick with disconnects and check valves. Stab coil. Get on well. Run in hole. Ta PBDT at 10 353'. Subtract 8' correction. PU to 2' below btm shot at 10,322'. 14:00 - 14:30 0.50 PERFO P LOWERI Cycle pumps to send pressure sequence to firing head. Listening device indicated guns fired. Perf interval: 10 120' to 10 320'. 6 s f 60 de hasin 2006PJ 2" guns. 14:30 - 17:00 2.50 PERFO P LOWERI Pull out of hole. Hole fill correct. Flow checks static. Hold BHA PJSM. 17:00 - 19:25 2.42 PERFO P LOWERI Get off well. Unstab coil. Stand back CSH in derrick. 19:25 - 19:40 0.25 PERFO P LOWERI PJSM discussed hazard mitigation for LD of pert guns 19:40 - 21:00 1.33 PERFO P LOWERI LD Perf guns Gun #4 dischar ed outside of scallo s 21:00 - 21:15 0.25 PERFO P LOWERI PJSM discussed hazard mitigation for LD of CSH 21:15 - 23:35 2.33 PERFO P LOWERi LD CHS 23:35 - 23:45 0.17 PERFO P LOWERI PJSM to MU Freeze protect BHA & PU Injector 23:45 - 00:00 0.25 PERFO P LOWERI MU Freeze protect BHA & PU Injector 6/18/2009 00:00 - 00:15 0.25 WHSUR P POST MU Freeze protect BHA & PU Injector 00:15 - 03:00 2.75 WHSUR P POST Displace well with Seawater to 2,000' 03:00 - 03:15 0.25 WHSUR P POST PJSM for pumping diesel for Freeze Protect 03:15 - 04:55 1.67 WHSUR P POST POOH while Freeze Protectin well with diesel from 2,000' 04:55 - 05:10 0.25 WHSUR P POST PJSM for standing back injector & LD FP BHA 05:10 - 06:00 0.83 WHSUR P POST Stand back injector & LD FP BHA 06:00 - 06:45 0.75 WHSUR P POST Hold PJSM. Set BPV with DSM crew and dry rod. 06:45 - 12:00 5.25 WHSUR P POST ND BOPs. Continue to prep rig for move. Finish cleaning pits. NU and test tree cap. LOTTO equipment for move as required. 12:00 - 12:30 0.50 RIGD P POST Back off well. Spot rig on pad. 12:30 - 14:00 1.50 RIGD P POST Clean up area around well head. Release rig at 14:00 Printetl: s/Z9/2009 3:OS:z6 F'M • ~~~~ BAKER Nu~NE~ INTEi~ North America - Prudhoe Bay PB H Pad H-13 -Slot 13 ALASKA - BP H-13A Design: H-13A Survey Report -Geographic 15 June, 2009 by ~R ^ BAI Survey Report -Geographic 1NTEQ Company: North America - ALASK,4 - BP Local Co-ordinate Reference: Well H-13 -Slot 13 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB H Pad MD Reference: 19:13 4/24/1981 00:00 @ 82.60ft (generic drillinc Well: H-13 North Reference: True Wellbore: H-13A Survey Calculation Method: Minimum Curvature Design: H-13A Database: EDM .16 - Anc Prod - WH24P 'roject Prudhoe Bay, North Slope, UNITED STATES dap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level ieo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point dap Zone: Alaska Zone 04 Using geodetic scale factor Site PB H Pad, TR-11-13 Site Position: Northing: 5,957,572.25ft Latitude: 70° 17' 30.055 N From: Map Easting: 641,366.07ft Longitude: 148° 51' 19.802 W Position Uncertainty: 0.00 ft Slot Radius: O.000in Grid Convergence: 1 08 Well H-13 Well Position +NI-S +E/-W Position Uncertainty Wellbore Magnetics Design Audit Notes: Version: Vertical Section: API No 500292055900 0.00 ft Northing: 5,959,136.00 ft Latitude: 0.00 ft Easting: 643,332.00 ft Longitude: 0.00 ft Wellhead Elevation: ft Ground Level: H-13A API No 500292055901 Model Name Sample Date Declination (°) BGGM2007 3/12/2009 22.70 -_ -- H-13A 1.0 Phase: ACTUAL Depth From (TVD) +NI-S (ft) (ft) -43.00 0.00 Survey Program Date: 6/15/2009 From To (ft) (ft) Survey (Wellbore) 100.00 9,000.00 1 : Sperry-Sun BOSS gyro multi (H-13) 9,080.00 10,390.00 MWD (H-13A) Dip Angle (°) 80.91 Tie On Depth: +E/-W (ft) 0.00 70° 17' 45.067 N 148° 50' 21.650 W 0.00 ft Field Strength (nT) 57.685 9,000.00 direction (°) 93.06 Tool Name Description BOSS-GYRO Sperry-Sun BOSS gyro multishot MWD MWD -Standard 6/15/2009 2:44:19PM Page 2 COMPASS 2003.16 Build 70 ~~~ • sw N11GElS INTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay 'Site: PB H Pad Well: H-13 Wellbore: H-13A Design: H-13A Survey Survey Report -Geographic Local Go-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: ~ ~a Well H-13 -Slot 13 Mean Sea Level 19:13.4/24/1981 00:00 @ 82.60ft (generic drillinc True Minimum Curvature EDM .16 - Anc Prod - WH24P Measured TVD Below Map Map Depth Inclination Azimuth System +NI-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft} {ft) (ft) (ft) Latitude Longitude 9,000.00 TIP ~, 9,080.00 ~~, KOP ~I 9,101.81 ~, 9,130.87 9,163.22 9,190.42 9,220.06 ', 9,250.83 ', 9,280.45 ~I 9,311.49 9,341.56 ~ 9,370.58 9,400.54 9,431.57 9,454.49 9,487.73 9,517.75 !, 9,547.74 9,577.62 9,607.98 9,638.21 9,668.07 !i 9,702.16 i 9,731.90 9,761.86 9,793.46 9, 823.80 9,853.79 ~ 9,884.05 j 9,914.93 9,946.76 I 9,975.84 ' 10,004.30 10,036.23 10,070.15 10,101.13 ~I 10,129.55 10,165.96 ~, 10,199.92 10,235.34 10,271.07 ', 10,301.01 ~! 10,330.01 '~ 10,346.80 ~I 10,390.00 TD-2718" 21.02 21.88 645,408.44 70° 17' 49.576 N 148° 49' 20.853 W 25.22 90.70 8,609.27 458.66 2,094.44 5,959,634.48 645,417.15 70° 1T 49.575 N 148° 49' 20.599 W' 32.64 93.99 8,634.68 458.04 2,108.47 5,959,634.12 645,431.19 70° 17' 49.569 N 148° 49' 20.190 W 38.36 125.44 8,661.23 451.55 2,125.51 5,959,627.96 645,448.35 70° 1T 49.505 N 148° 49' 19.694 W, 42.90 144.09 8,681.94 439.10 2,137.87 5,959,615.76 645,460.94 70° 1T 49.382 N 148° 49' 19.333 W', 46.08 158.64 8,703.14 420.94 2,147.70 5,959,597.79 645,471.12 70° 1T 49.204 N 148° 49' 19.047 W', 46.71 175.92 8,724.45 399.36 2,152.55 5,959,576.31 645,476.38 70° 1T 48.991 N 148° 49' 18.906 W 46.73 190.96 8,744.82 377.96 2,151.26 5,959,554.88 645,475.50 70° 1T 48.781 N 148° 49' 18.943 W ~, 46.79 190.42 8,766.08 355.74 2,147.07 5,959,532.59 645,471.73 70° 1T 48.562 N 148° 49' 19.066 W'~, 54.48 178.50 8,785.18 332.64 2,145.40 5,959,509.47 645,470.50 70° 1T 48.335 N 148° 49' 19.115 W', 62.59 168.32 8,800.34 308.14 2,148.33 5,959,485.02 645,473.90 70° 1T 48.094 N 148° 49' 19.030 W'. 70.31 156.36 8,812.34 282.07 2,156.72 5,959,459.13 645,482.78 70° 1T 47.838 N 148° 49' 18.785 W''. 72.00 141.67 8,822.41 256.99 2,171.80 5,959,434.34 645,498.34 70° 1T 47.591 N 148° 49' 18.346 W 75.24 133.28 8,828.89 240.81 2,186.66 5,959,418.45 645,513.50 70° 17' 47.432 N 148° 49' 17.913 W 79.65 122.87 8,836.13 220.86 2,212.17 5,959,398.99 645,539.38 70° 17' 47.236 N 148° 49' 17.170 W 83.78 121.36 8,840.45 205.07 2,237.32 5,959,383.68 645,564.83 70° 17' 47.080 N 148° 49' 16.436 W 85.08 125.16 8,843.37 188.70 2,262.28 5,959,367.80 645,590.09 70° 17' 46.919 N .148° 49' 15.709 W 84.93 130.43 8,845.97 170.47 2,285.79 5,959,350.01 645,613.95 70° 17' 46.740 N 148° 49' 15.024 W 84.75 136.31 8,848.70 149.71 2,307.76 5,959,329.68 645,636.31 70° 17' 46.536 N 148° 49' 14.384 W 89.08 137.37 8,850.33 127.70 2,328.40 5,959,308.07 645,657.37 70° 17' 46.319 N 148° 49' 13.782 W 92.03 135.84 8,850.04 106.01 2,348.91 5,959,286.77 645,678.29 70° 17' 46.106 N 148° 49' 13.185 W 96.12 134.93 8,847.62 81.81 2,372.78 5,959,263.04 645,702.61 70° 17' 45.868 N 148° 49' 12.489 W 97.76 133.43 8,844.02 61.23 2,393.96 5,959,242.87 645,724.17 70° 17' 45.665 N 148° 49' 11.872 W 98.91 132.85 8,839.68 40.96 2,415.59 5,959,223.02 645,746.18 70° 17' 45.466 N 148° 49' 11.242 W 100.02 130.56 8,834.48 20.23 2,438.86 5,959,202.73 645,769.84 70° 17' 45.262 N 148° 49' 10.564 W 97.87 126.37 8,829.76 1.59 2,462.32 5,959,184.55 645,793.65 70° 17' 45.078 N 148° 49' 9.880 W 94.14 124.35 8,826.63 -15.66 2,486.64 5,959,167.76 645,818.30 70° 17' 44.909 N 148° 49' 9.171 W 90.89 121.01 8,825.30 -31.98 2,512.08 5,959,151.93 645,844.04 70° 17' 44.748 N 148° 49' 8.430 W 88.74 117.80 8,825.40 -47.14 2,538.98 5,959,137.29 645,871.22 70° 17' 44.599 N 148° 49' 7.646 W 89.51 115.49 8,825.89 -61.41 2,567.42 5,959,123.56 645,899.93 70° 17' 44.459 N 148° 49' 6.817 W 92.91 113.80 8,825.27 -73.53 2,593.84 5,959,111.95 645,926.57 70° 17' 44.339 N 148° 49' 6.048 W 93.96 111.02 8,823.57 -84.36 2,620.10 5,959,101.62 645,953.03 70° 17' 44.233 N 148° 49' 5.282 W 92.40 107.55 8,821.79 -94.89 2,650.19 5,959,091.67 645,983.31 70° 17' 44.129 N 148° 49' 4.405 W 89.54 103.94 8,821.22 -104.09 2,682.82 5,959,083.10 646,016.11 70° 17' 44.038 N 148° 49' 3.454 W 90.55 99.75 8,821.20 -110.45 2,713.13 5,959,077.32 646,046.54 70° 17' 43.976 N 148° 49' 2.571 W 91.20 95.51 8,820.76 -114.22 2,741.29 5,959,074.09 646,074.76 70° 17' 43.939 N 148° 49' 1.750 W 88.62 91.88 8,820.82 -116.56 2,777.62 5,959,072.43 646,111.12 70° 17' 43.915 N 148° 49' 0.691 W 88.03 88.22 8,821.81 -116.59 2,811.56 5,959,073.05 646,145.05 70° 17' 43.915 N 148° 48' 59.702 W 88.28 96.19 8,822.95 -117.95 2,846.90 5,959,072.36 646,180.42 70° 17' 43.901 N 148° 48' 58.672 W 89.48 102.26 8,823.65 -123.68 2,882.15 5,959,067.31 646,215.76 70° 17' 43.845 N 148° 48' 57.645 W 91.88 104.91 8,823.30 -130.71 2,911.24 5,959,060.84 646,244.98 70° 17' 43.776 N 148° 48' 56.797 W 94.64 108.15 8,821.65 -138.94 2,938.99 5,959,053.14 646,272.88 70° 17' 43.695 N 148° 48' 55.988 W 95.29 111.46 8,820.19 -144.61 2,954.73 5,959,047.77 646,288.72 70° 17' 43.639 N 148° 48' 55.530 W 95.29 111.46 8,816.21 -160.35 2,994.76 5,959,032.80 646,329.05 70° 17' 43.484 N 148° 48' 54.363 W 90.11 8,514.82 458.95 2,056.47 5,959,634.05 645,379.19 70° 17' 49.578 N 148° 49' 21.706 W 90.64 8,589.28 458.76 2,085.73 5,959,634.41 6/15/2009 2:44:19PM Page 3 COMPASS 2003.16 Build 70 ~ ~~ s, Ilitv~s LNTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Site: PB H Pad Well: H-13 Wellbore: H-13A Design: H-13A Targets Target Name - hit/miss target Dip Angle Dip Dir. ND -Shape l°) (°) (ft) Survey Report -Geographic ~ ~ Local Co-ordinate Reference: Well H-13 -Slot 13 ND Reference: Mean Sea Level MD Reference: 19:13 4/24/1981 00:00 @ 82.60ft (generic drillincr North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P +N/-S +E/-W Northing Easting (ft) (ft} (ft) (ft) H-13A Fault 1 0.00 0.00 0.00 575.31 1,774.43 5,959,745.00 645,095.00 - actual wellpath mi sses target center by 8520.28ft at 9000.OOft MD (8514.82 ND, 458.95 N, 2056.47 E) - Polygon Point 1 0.00 575.31 1,774.43 5,959,745.00 645,095.00 Point 2 0.00 385.70 2,275.94 5,959,565.00 645,600.00 Point 3 0.00 361.39 3,025.67 5,959,555.00 646,350.00 Point 4 0.00 257.11 3,248.74 5,959,455.00 646,575.00 Point 5 0.00 53.32 3,444.91 5,959,255.00 646,775.00 Point 6 0.00 -774.18 4,089.29 5,958,440.00 647,435.00 Point 7 0.00 53.32 3,444.91 5,959,255.00 646,775.00 Point 8 0.00 257.11 3,248.74 5,959,455.00 646,575.00 Point 9 0.00 361.39 3,025.67 5,959,555.00 646,350.00 Point 10 0.00 385.70 2,275.94 5,959,565.00 645,600.00 H-13A Target 3 0.00 0.00 8,850.00 187.34 2,187.14 5,959,365.00 645,515.00 - actual wellpath misses target center by 44.07ft at 9487.73ft MD (8836.13 ND, 220.86 N, 221 2.17 E) - Point H-13A Target 1 0.00 .0.00 8,617.00 459.12 2,097.30 5,959,635.00 645,420.00 - actual wellpath m isses target center by 1.02ft at 9109.96ft MD (8616.57 ND, 458.58 N, 2098.04 E) - Point H-13A Target 5 0.00 0.00 8,840.00 -421.34 3,420.85 5,958,780.00 646,760.00 - actual wellpath m isses target center by 500.23ft at 1 0390.OOft MD (8816.21 ND, -160.35 N, 2994.76 E) - Point H-13A Target 4 0.00 0.00 8,845.00 -150.31 2,845.87 5,959,040.00 646,180.00 - actual wellpath m isses target center by 39.05ft at 10239.94ft MD (8823.09 ND, -118.48 N, 2 851.47 E) - Point H-13A Target 2 0.00 0.00 8,860.00 614.97 2,055.26 5,959,790.00 645,375.00 - actual wellpath m isses target center by 263.54ft at 9190.42ft MD (8681.94 TVD, 439.10 N, 2137.87 E) - Point H-13A Polygon 0.00 0.00 0.00 381.33 1,980.78 5,959,555.00 645,305.00 - actual wellpath m isses target center by 8515.51ft at 9000.OOft MD (8514.82 TVD, 458.95 N, 2056.47 E) - Polygon Point 1 0.00 381.33 1,980.78 5,959,555.00 645,305.00 Point 2 0.00 192.69 1,907.16 5,959,365.00 645,235.00 Point 3 0.00 3.26 2,398.68 5,959,185.00 645,730.00 Point 4 0.00 -510.76 3,389.13 5,958,690.00 646,730.00 Point 5 0.00 -337.49 3,482.46 5,958,865.00 646,820.00 Point 6 0.00 56.15 3,034.85 5,959,250.00 646,365.00 Point 7 0.00 92.91 2,680.46 5,959,280.00 646,010.00 Point 8 0.00 293.48 2,129.14 5,959,470.00 645,455.00 Casing Points Latitude Longitude 70° 17' 50.723 N 148° 49' 29.926 W 70° 17' 46.906 N 148° 49' 17.899 W 70° 17' 49.579 N 148° 49' 20.516 W 70° 17' 40.915 N 148° 48' 41.947 W 70° 17' 43.583 N 148° 48' 58.702 W 70° 17' 51.112 N 148° 49' 21.740 W 70° 17' 48.815 N 148° 49' 23.913 W Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (~n) tin) 10,390.00 8,816.21 2 7/8" 2.875 4.125 t-X15/2009 2:44:19PM Page 4 COMPASS 2003.16 Build 70 ~L~ 1!S Survey Report -Geographic 1NTEQ Company: North America -ALASKA - B P LocaF Co-ordinate Reference: Well H-13 -Slot 13 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB H Pad MD Reference: 19 : 13.4/24!1981 00:00 @ 82.60ft (generic drillinr ` Well: H-13 North Reference: True Wellbore: H-13A Survey Calculation Method: Minimum Curvature Design: H-13A Database: EDM .16 - Anc Prod - WH24P Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) lft) Latitude Longitude H-13A Fauft 1 0.00 0.00 0.00 575.31 1,774.43 5,959,745.00 645,095.00 70° 17' 50.723 N 148° 49' 29.926 W - actual wellpath misses target center by 8520.28ft at 9000.OOft MD (8514.82 TVD, 458.95 N, 2056.47 E) - Polygon Point 1 0.00 575.31 1,774.43 5,959,745.00 645,095.00 Point 2 0.00 385.70 2,275.94 5,959,565.00 645,600.00 Point 3 0.00 361.39 3,025.67 5,959,555.00 646,350.00 Point 4 0.00 257.11 3,248.74 5,959,455.00 646,575.00 Point 5 0.00 53.32 3,444.91 5,959,255.00 646,775.00 Point 6 0.00 -774.18 4,089.29 5,958,440.00 647,435.00 Point 7 0.00 53.32 3,444.91 5,959,255.00 646,775.00 Point 8 0.00 257.11 3,248.74 5,959,455.00 646,575.00 Point 9 0.00 361.39 3,025.67 5,959,555.00 646,350.00 Point 10 0.00 385.70 2,275.94 5,959,565.00 645,600.00 H-13A Target 3 0.00 0.00 8,850.00 187.34 2,187.14 5,959,365.00 645,515.00 70° 17' 46.906 N 148° 49' 17.899 W - actual wellpath misses target center by 44.07ft at 9487.73ft MD (8836.13 TVD, 220.86 N, 2212.17 E) - Point H-13A Target 1 0.00 0.00 8,617.00 459.12 2,097.30 5,959,635.00 645,420.00 70° 17' 49.579 N 148° 49' 20.516 W - actual wellpath misses target center by 1.02ft at 9109.96ft MD (8616.57 TVD, 458.58 N, 2098.04 E) - Point H-13A Target 5 0.00 0.00 8,840.00 -421.34 3,420.85 5,958,780.00 646,760.00 70° 17' 40.915 N 148° 48' 41.947 W - actual wellpath misses target center by 500.23ft at 10390.OOft MD (8816.21 TVD, -160.35 N, 2 994.76 E) - Point H-13A Target 4 0.00 0.00 8,845.00 -150.31 2,845.87 5,959,040.00 646,180.00 70° 17' 43.583 N 148° 48' 58.702 W - actual wellpath misses target center by 39.05ft at 10239.94ft MD (8823.09 TVD, -118.48 N, 28 51.47 E) - Point H-13A Target 2 0.00 0.00 8,860.00 614.97 2,055.26 5,959,790.00 645,375.00 70° 17' 51.112 N 148° 49' 21.740 W - actual wellpath misses target center by 263.54ft at 9190.42ft MD (8681.94 TVD, 439.10 N, 2137.87 E) - Point H-13A Polygon 0.00 0.00 0.00 381.33 1,980.78 5,959,555.00 645,305.00 70° 17' 48.815 N 148° 49' 23.913 W - actual wellpath misses target center by 8515.51ft at 9000.OOft MD (8514.82 TVD, 458.95 N, 2056.47 E) - Potygon Point 1 0.00 381.33 1,980.78 5,959,555.00 645,305.00 Point 2 0.00 192.69 1,907.16 5,959,365.00 645,235.00 Point 3 0.00 3.26 2,398.68 5,959,185.00 645,730.00 Point 4 0.00 -510.76 3,389.13 5,958,690.00 646,730.00 Point 5 0.00 -337.49 3,482.46 5,958,865.00 646,820.00 Point 6 0.00 56.15 3,034.85 5,959,250.00 646,365.00 Point 7 0.00 92.91 2,680.46 5,959,280.00 646,010.00 Point 8 0.00 293.48 2,129.14 5,959,470.00 645,455.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) lft) Name (in) (in) 10,390.00 8,816.21 2 7/8" 2.875 4. 125 Design Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 9,000.00 8,514.82 458.95 2,056.47 TIP 9,080.00 8,589.28 458.76 2,085.73 KOP 6/15/2009 2:44:19PM Page 5 COMPA SS 2003.16 Build 70 ~a~ • s ~i~es Survey Report -Geographic 1NTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well H-13 -Slot 13 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB H Pad MD Reference: 19:13 4!24/1981 00:00 @ 82.60ft (generic drillinc .Well: H-13 North Reference: True Wellbore: H-13A Survey Calculation Method: Minimum Curvature Design: H-13A Database: EDM .16 - Anc Prod - WH24P Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/-S +E!-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) H-13A Fault 1 0.00 0.00 0.00 575.31 1,774.43 5,959,745.00 645,095.00 - actual wellpath mi sses target center by 8520.28ft at 9000.OOft MD (8514.82 TVD, 458.95 N, 2056.47 E) - Polygon Point 1 0.00 575.31 1,774.43 5,959,745.00. 645,095.00 Point 2 0.00 385.70 2,275.94 5,959,565.00 645,600.00 Point 3 0.00 361.39 3,025.67 5,959,555.00 646,350.00 Point 4 0.00 257.11 3,248.74 5,959,455.00 646,575.00 Point 5 0.00 53.32 3,444.91 5,959,255.00 646,775.00 Point 6 0.00 -774.18 4,089.29 5,958,440.00 647,435.00 Point 7 0.00 53.32 3,444.91 5,959,255.00 646,775.00 Point 8 0.00 257.11 3,248.74 5,959,455.00 646,575.00 Point 9 0.00 361.39 3,025.67 5,959,555.00 646,350.00 Point 10 0.00 385.70 2,275.94 5,959,565.00 645,600.00 H-13A Target 3 0.00 0.00 8,850.00 187.34 2,187.14 5,959,365.00 645,515.00 - actual wellpath mi sses target center by 44.07ft at 9487.73ft MD (8836.13 TVD, 220.86 N, 221 2.17 E) - Point H-13A Target 1 0.00 0.00 8,617.00 459.12 2,097.30 5,959,635.00 645,420.00 - actual wellpath mi sses target center by 1.02ft at 9109.96ft MD (8616.57 TVD, 458.58 N, 2098.04 E) - Point H-13A Target 5 0.00 0.00 8,840.00 -421.34 3,420.85 5,958,780.00 646,760.00 - actual wellpath mi sses target center by 500.23ft at 1 0390.OOft MD (8816.21 TVD, -160.35 N, 2994.76 E) - Point H-13A Target 4 0.00 0.00 8,845.00 -150.31 2,845.87 5,959,040.00 646,180.00 - actual wellpath mi sses target center by 39.05ft at 10239.94ft MD (8823.09 TVD, -118.48 N, 2 851.47 E) - Point H-13A Target 2 0.00 0.00 8,860.00 614.97 2,055.26 5,959,790.00 645,375.00 - actual wellpath m isses target center by 263.54ft at 9190.42ft MD (8681.94 TVD, 439.10 N, 21 37.87 E) - Point H-13A Polygon 0.00 0.00 0.00 381.33 1,980.78 5,959,555.00 645,305.00 - actual wellpath mi sses target center by 8515.51ft at 9000.OOft MD (8514.82 TVD, 458.95 N, 2056.47 E) - Polygon Point 1 0.00 381.33 1,980.78 5,959,555.00 645,305.00 Point 2 0.00 192.69 1,907.16 5,959,365.00 645,235.00 Point 3 0.00 3.26 2,398.68 5,959,185.00 645,730.00 Point 4 0.00 -510.76 3,389.13 5,958,690.00 646,730.00 Point 5 0.00 -337.49 3,482.46 5,958,865.00 646,820.00 Point 6 0.00 56.15 3,034.85 5,959,250.00 646,365.00 Point 7 0.00 92.91 2,680.46 5,959,280.00 646,010.00 Point 8 0.00 293.48 2,129.14 5,959,470.00 645,455.00 Casing Points Latitude Longitude 70° 17' 50.723 N 148° 49' 29.926 W 70° 17' 46.906 N 148° 49' 17.899 W 70° 17' 49.579 N 148° 49' 20.516 W 70° 17' 40.915 N 148° 48' 41.947 W 70° 17' 43.583 N 148° 48' 58.702 W 70° 17' 51.112 N 148° 49' 21.740 W 70° 17' 48.815 N 148° 49' 23.913 W Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (m) (m) 10,390.00 8,816.21 2 7/8" 2.875 4.125 - 10 390.00 -- - - - --- --- 8,816.21 -160.35 2,994.76 TD Checked By: Approved By: Date: 6/15/2009 2:44:19PM Page 6 COMPASS 2003.16 Build 70 VELLHEAD = MCEVO`r ACTUATOR ~ OTI~ ;B. ELEV = 82.55 iF. ELEV = 45.35 ;OP = 3300 fax Angle = 26° @ 9600 )atom MD = 9310 )atom TVD = 8800' S~ 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ ' ~ ~ SAFE ^ C)TES POSSIBLE COLLAPSED LNR FROM proposed CTD Sidetrack 9424'~133'.ID=3.70°. 2001' S-1/2" CAM SSSV LAND NIP, ID = 4.562" GAS LIFT MANDRELS Minimum ID = 2.30" @ 8420' Deployment Sleeve (TOE) ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3006 3006 1 CAMCO DMY RK 0 02/23/0 11 4938 4828 21 CAMCO DMY RK 0 02/23/0 10 5953 5773 22 CAMCO DMY RK 0 9 6095 5905 22 CAMCO DMY RK 0 8 6629 6401 22 CAMCO DMY RK 0 7 6776 6538 22 CAMCO DMY RK 0 6 7114 6850 23 CAMCO DMY RK 0 5 7259 6985 22 CAMCO DMY RK 0 4 7588 7291 21 CAMCO DMY RK 0 3 7726 7419 22 CAMCO DMY RK 0 2 8064 7729 24 CAMCO DMY RK 0 1 8208 7861 23 CAMCO DMY RK 0 $276' -15-1/2" SLIDING SLV, ID = 4.562" 8315' TBG sEAL asst 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~ 8355' TOP OF 4-112" TBG 8355' TOP 3-1!2" x s-3/16" x 2-7/8" LNR 8375' TOP OF 7" LNR 8412' •1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~~ 8466' 9-5/8" CSG, 47#, L-80, ID = 8.681" whipstock 8907' 9080' PERFORATION SUMMARY REF LOG: SBL ON 05/14/81 ANGLE AT TOP PERF: 90° @ 10120' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10120-1-320 Open 06/17/09 PBTD 9759' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9800' 8335' 9-5/8" x 5-112" TIW PKR, ID = 4.75" 8355' 5-1/2" X 4-1/2" x0 g3gg' 4-112" X NIP, ID = 3.813" ~ 8431' ~-j4-1/2" XN NIP, ID MILLED TO = 3.80" 8466' 4-112" TBG TAIL ID = 3.958" 8428' ELMD TT LOGGED 07/02/97 8470' roc 102$$' ~~3-3/16 x 2-7/8 X-over 3-3/16" x 2-718" cmt'd and perf'd ~~ 10390' 9398' FISH: TBG END LOCATOR ARM 9420' FISH: CENT ARM/ROLLER WHEEL (02/24/0 DATE REV BY COMMENTS DATE REV BY COMMENTS 04/22/82 ORIGINAL COMPLETION 03/06/09 DTR/SV SET XXN PLUG (03/03/09) 02/16/01 SIS-SET CONVERTED TO CANVAS 06/16/09 Nordic 2 Sidetracked for more oil.... 03/01/01 SIS-LG FINAL 09/26/01 RN/TP CORRECTIONS 05/29/06 CO/DTM FERF CORRECTIONS (6/13/04) n nZmzma 1 TFA /C\/ 1 FicH / rl v r/n rmnzmU~ 11 1 1 0 22 PRUDHOE BAY UNIT' WELL: H-13A PERMIT No: API No: 50-029-20559-01 Sec. 21, T11 N, R13E RP Fvnl..raYinn lAlva4nl i a( ~ j t ALASiSA OII, A1~TD G~A,S COI~TSERQA'I'I011T COMIrIISSIOI~T John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box196612 Anchorage AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU H-13A BP Exploration Alaska Inc. Permit No: 209-044 Surface Location: 1652' FNL, 1264' FEL, SEC. 21, T11N, R13E, UM Bottomhole Location: 2067' FNL, 2159' FWL, SEC. 22, T11N, R13E, UM Dear McMullen: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an .applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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). Sincerely, P ath P. oerster Com 'ssioner DATED this ~ day of April, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA . C~ ~ ~ ALAS~IL AND GAS CONSERVATION COMMjf 4~ ~~JQ~~~ PERMIT TO DRILL ~~f ~ ~`~ ~. ~*. ~t3i'~1i11tSSlUtI 20 AAC 25.005 ~ s ,~iaska t~tf ~. ~S8 ~~9 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1~tt$~if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU H-13A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10927 TVD 8840ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028284 Oil Pool FEL, SEC. 21, T11N, R13E, UM FNL, 1264 1652 Top of Productive Horizon: R13E UM 814 FWL SEC. 22 T11 N 1194' FNL 8. Land Use Permit: 13. Approximate Spud Date: May 15, 2009 , , , , , Total Depth: 2067' FNL, 2159' FWL, SEC. 22, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 25400' 4b. Location of Well (State Base Plane Coordinates): Surface: x-643332 y-5959136 Zone-ASP4 10. KB Elevation (Height above GL): 82.6 feet 15. Distance to Nearest We11 Within Pool: 1420' 16. Deviated Wells: Kickoff Depth: 9100 feet Maximum Hole An le: 91 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3209 Surface: 2329 1 P m: ifi n T- in D h- m f e, .f.` r Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/ " ~-~~s"xz-~i8" 6. x L- 0 TCII/STL 15' 8412' 1 7' 8 40' 1 7 cu ft I s' 19. PRESE Total Depth MD (ft): Total Depth T 9805 9 29 NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) VD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 8431' 9759 9287 9420' & 9398' Casing ` Length Size Cement Volume MD TVD Conductor l Structural 1 1 ' Surface 2695' 1 - /8" 3720 P rmafr II 26 ' Intermediate Pr / " 1 I rm r ' Liner 138 ' 7" 380 u I ss 'G' 411' - 98 4 ' - 4' Perforation Depth MD (ft): 9350' -9462' Perforation Depth TVD (ft): 8919' - 9020' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Sean McLaughlin, 564-4387 Printed Name John II Title Engineering Team Leader Prepared By NameMumber: Si nature ~--- Phone 564-4711 Date ~ ~ 4 Sondra Stewman, 564-4750 Commission Uae Onl Permit To Dri m r:o? O~ API Number: 50-029-20559-01-00 Permit Approval See cover letter for te: ~ /'~' of r r 're nts Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^ yes ~No Mud Log Req'd: ^ Yes Ir~No \ HZS Measures: Yes ^ No Directional Survey Req'd: I~Yes ^ No Other: J~~~S°. ~G.t~~~5't ~e~-~~DS\~~u~`~`1h, Ci~.I~~~Cs-f ~~~' U APPROVED BY THE COMMISSION DateGf-~ ~Gf ,COMMISSIONER Form 10-401 Revised 12/2005. Submit In Duplicate f°{ d +an C L-u by BPXA Prudhoe Bay H-13A CTD Sidetrack April 8, 2009 CTD Sidetrack Summary Pre-Rig Work: (Scheduled to begin on April 20, 2009) 1. O MIT-IA - 3000 psi Pass 2/23/09 2. S DGLV's 3. S Drift for 4-1/2" X 7" Thru tubing whipstock to 9150' MD 4. E Set whipstock at 9080'MD. 5. C Mill XN nipple at 8431' MD to 3.80" with left hand motor and mill. 6. C Down squeeze 40 bbl of 15.8 ppg cmt past whipstock to abandon existing perforations. 7. OMIT-Tubing 2000 psi 8. O AC-LDS; AC-PPPOT- T 9. O PT tree (MV,SV,WV), 10. O Bleed gas lift and production flowlines down to zero and blind flange 11. O Remove S-Riser, Remove wellhouse, level pad Rig work: (Scheduled to begin on May 15, 2009 using Nordic rig 2) _ 1 MIRU and test BOPE to 250 psi low and 3500 psi high -_ W 2. Mill 3.8" window at 9080' and 10' of rathole. Swap the well to Flo-Pro. 3. Drill Build: 4.125" OH, 620' (35 deg/100 planned) 4. Drill Lateral: 4.125" OH, 1227' (15 deg/100 planned) with resistivity 5. Run 3-3/16" x 2-7/8" solid L-801iner leaving TOL at 8412' °~-h~~ ~~ 6. Pump primary cement leaving TOC at 8780', 28 bbls of 15.8 ppg liner cmt planned ~~'~' 7. Cleanout liner and MCNL/GR/CCL log 8. Test liner lap to 2000 psi. 9. Perforate liner per asset instructions (700' ) 10. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.6 ppg Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.125" (bi-center bits used) Casing Program: fully cemented liner • 3-3/16", L-80 6.2# TCII 8,412' and - 10,300' and • 2-7/8", L-80 6.16# STL 10,300'md -10,927' and • A minimum of 28 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 8,780' Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 91 deg at 10,927'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line - 25,400 ft. • Distance to nearest well within pool -1420 ft. (H-146 NE) Logging • MWD directional, Resistivity and Gamma Ray will be run over all of the open hole section. • Cased hole MCNUGR/CCL will be run. Hazards • The maximum recorded H2S level on H pad is 180 ppm on well H-22A. • One planned fault crossing, calculated risk of lost circulation is high in this area. Reservoir Pressure • The reservoir pressure on H-13A is expected to be 3,209 psi at 8,800' TVDSS. (7.0 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 2,329 psi. Sean McLaughlin CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble TREE = 6-3/8" MCEVOY WELLHEAD = MCEVOY ACTUATOR = O11S KB. ELEV= 82.55' BF. ELEV = 45.35' KOP = 3300' Max Angle = 26° @ 9600' Datum MD = 9310' Datum ND = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I-i 2695' Minimum ID = 3.70" @ 9424' POSSIBLE COLLAPSED LINER 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~~ 8355, TOP OF 4-1 /2" TBG 8355' TOP OF 7" LNR I-I $412' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFORAl10N SUMMARY REF LOG: SBL ON 05/14/81 ANGLE AT TOP PERF: 25° @ 9375' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpNSgz DATE 3-1/8" 4 9350-9370 S 02/12/98 2-7/8" 6 9375-9400 C 03/03/98 3-3/8" 4 9380-9400 C 02/20/98 3-3/8" 6 9424-9430 S 06/02/94 3-3/8" 6 9442-9462 S 06/02/94 PBTD 9759' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9800' 9420' 9398' DATE REV BY COMMENTS DATE REV BY COMMENTS 04/22/82 ORIGINAL COMPLETION 03/06/09 DTR/SV SET X)OV PLUG (03/03/09) 02/16/01 SIS-SLT CONVERTED TO CANVAS 03/01/01 SIS-LG FINAL 09/26/01 RN/TP CORREC110NS 05/29/06 CO/OTM PERF CORRECTIONS (6/13/04) 03/03/09 TFA/SV FISH / GLV C/O (02/23/09) FISH: CENT ARM/ROLLER WHEEL (02/24/09) II (FISH: TBG END LOCATOR ARM I PRUDHOE BAY UNIT WELL: H-13 PERMIT No: 81-0170 API No: 50-029-20559-00 Sec. 21, T11N, R13E BP Exploration (Alaska) H -13 94247RJ433~, ID~3.7p LE COLLAPSED LNR FROM 2001' 5-1/2" CAM SSSV LAND NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3006 3006 1 CAMCO DMY RK 0 02/23/09 11 4938 4828 21 CAMCO DMY RK 0 02/23/09 10 5953 5773 22 CAMCO DMY RK 0 9 6095 5905 22 CAMCO DMY RK 0 8 6629 6401 22 CAMCO DMY RK 0 7 6776 6538 22 CAMCO DMY RK 0 6 7114 6850 23 CAMCO DMY RK 0 5 7259 6985 22 CAMCO DMY RK 0 4 7588 7291 21 CAMCO DMY RK 0 3 7726 7419 22 CAMCO DMY RK 0 2 8064 7729 24 CAMCO DMY RK 0 1 8208 7861 23 CAMCO DMY RK 0 8I 276' I~ 5-112" SLIDING SLV, ID = 4.562" I 8315' TBG SEAL ASSY 8335' 9-5/8" x 5-1/2" TIW PKR ID = 4.75" 8355' 5-1l2" X 4-1/2" XO 8399' 4-1/2" X NIP, ID = 3.813" 8431' 4-1/2" )OON PLUG (03/03/09) 8431' -~1/2" ~V NIP, ID = 3.72 8466' 4-1/2" TBG TAIL ID = 3.958" 8428' ELMD TT LOGGED 07/02!97 9262' I~ MARKER JOINT TREE = 6-3/8" MCEVOY WELLHEAD = MCEVOY ACTUATOR = OTIS K~B. ELEV = 82.55' BF. ELEV = 45.35' KOP = 3300' Max Angle = 26° @ 9600' Datum MD = 9310' Datum TVD = 8800' SS • ~ -13 A g 2440 3F~, ID~3 70' LE COLLAPSED LNR FROM Proposed CTD Sidetrack 2001' 5-1/2" CAM SSSV LAND NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 3006 3006 1 CAMCO DMY RK 0 02/23/09 11 4938 4828 21 CAMCO DMY RK 0 02/23/09 10 5953 5773 22 CAMCO DMY RK 0 9 6095 5905 22 CAMCO DMY RK 0 8 6629 6401 22 CAMCO DMY RK 0 7 6776 6538 22 CAMCO DMY RK 0 6 7114 6850 23 CAMCO DMY RK 0 5 7259 6985 22 CAMCO DMY RK 0 4 7588 7291 21 CAMCO DMY RK 0 3 7726 7419 22 CAMCO DMY RK 0 2 8064 7729 24 CAMCO DMY RK 0 1 8208 7861 23 CAMCO DMY RK 0 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 2695' Minimum ID = 3.70" @ 9424' POSSIBLE COLLAPSED LINER 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" I-j 8355' TOP OF 4-1 /2" TBG 8355' TOP 3-1/2" X 3-3/16" X 2-7/8" LNR 8412' TOP OF 7" LNR ~ $412' ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 9-5/8" CSG, 47#, L-80, ID = 8.681" whipstock 8276' ~ 5-1/2" SLIDING SLV, ID = 4.562" 8315' TBG SEAL ASSY 8335' 9-5/8" x 5-1/2" TNV PKR, ID = 4.75" 8355' 5-1/2" X 4-1/2" XO 8399' 4-1/2" X NIP, ID = 3.813" $431' ~4-1/2" XN NIP, ID MILLED TO = 3.80" 8466' 4-1/2" TBG TAIL ID = 3.958" 8428' ELMD TT LOGGED 07/02/97 8907' 8790' Toc 9080' 10300' PERFORATION SUMMARY REF LOG: SBL ON 05/14/81 ANGLE AT TOP PERF: 25° @ 9375' Note: Refer to Production DB for historical p ert data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 9350-9370 S 02/12/98 2-7/8" 6 9375-9400 C 03/03/98 3-3/8" 4 9380-9400 C 02/20/98 3-3/8" 6 9424-9430 S 06/02/94 3-3/8" 6 9442-9462 S 06/02/94 PBTD 9759' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9800' 0 22 13-3/16 x 2-7/8 X-over ~ 3-3/16" x 2-7/8" cmt'd and perf'd ~ 9398' ~ FISH: TBG END LOCATOR ARM 9420' FISH: CENT ARM/ROLLER WHEEL (02/24/09) DATE REV BY COMMENTS DATE REV BY COMMENTS 04/22/82 ORIGINAL COMPLETION 03/06/09 DTR/SV SET XXN PLUG (03/03/09) 02/16/01 SIS-SLT CONVERTED TO CANVAS 03/10/09 MSE PROPOSED CTD SIDETRACK 03/01/01 SIS-LG FINAL 09/26/01 RN/TP CORRECTIONS 05/29/06 COlDTM PERF CORRECTIONS (6/13/04) 03/03;'' ~ ,_ ._ 1'~ < ;? ;t _ _____. ._ ~ -~ PRUDHOE BAY UNfr WELL: H-13A PERMIT No: API No: 50-029-20559-01 Sec. 21, T11N, R13E BP Exploration (Alaska) risr BAKER N1~6HES INTEQ North America -ALASKA - BP Prudhoe Bay PB H Pad H-13 -Slot 13 Plan 4, H-13A Plan: Plan 4 Baker Hughes INTEQ Planning Report 13 March, 2009 by • i ~li~~ BAK[R MYaNEf INTEQ Company: North America -ALASKA - BP Project: Prudhoe Bay Site: PB H Pad Well: H-13 Wellbore: Plan 4, H-13A Design: Plan 4 BP Exploration Alaska Baker Hughes INTEQ Planning Report bP Local Co-ordinate Reference: Well 1+13 -Slot 13 TVD Reference: Mean Sea Level MD Reference: 19:13 4/24/1981 00:00 @ 82.60ft (generic drillinc North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM .16 - Anc Prod - WH24P Project Prudhoe Bay, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Site PB H Pad, TR-11-13 Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Slot Radius: System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,957,572.25 ft Latitude: 70° 17' 30.055 N 641,366.07 ft Longitude: 148° 51' 19.802 W 0 " Grid Convergence: 1.08 ° Well H-13 -Slot 13, H-13 Well Position +N/-S 0.00 ft Northing: 5,959,136.00 ft Latitude: 70° 17' 45.067 N +E/.W 0.00 ft Easting: 643,332.00 ft Longitude: 148° 50' 21.650 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Wellbore Plan 4, H-13A Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 3/12/2009 22.70 80.91 57,685 f __ Design j Audit Notes: Version: i Vertical Section: Plan 4 Phase: PLAN Depth From (TVD) +N/-S (ft) (ft) -43.00 0.00 Tie On Depth: 9,000.00 +E/-W Direction (ft) (°) 0.00 135.00 3/13/2009 10:32:09AM Page 2 COMPASS 2003.16 Build 70 R ~ BP Exploration Alaska BA MYfiME: Baker Hughes INTEQ Planni ng Report by INTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Well H-13 -Slot 13 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB H Pad MD Reference: 19:13 4/24/1981 0 0:00 @ 82.60ft (generic drillinc Well: H-13 North Reference: True Wellbore: Plan 4, H-13A Survey Calculation Method: Minimum Curvature Design: Plan 4 Database: EDM .16 - Anc Prod - WH24P Survey Tool Program Date 3/13/2009 From To (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 9,000.00 1 : Sperry-Sun BOSS gyro multi (H-13) BOSS-GYRO Speny-Sun BOSS gyro multishot 9,000.00 10,927.00 Plan 4 (Plan 4, H-13A) MWD MWD -Standard - - -- I Planned Survey MD Inc Azi TVDSS N/S E/W Northing Easting DLeg V. Sec TFO (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) (°) 9,000.00 21.02 90.11 8,514.82 458.95 2,056.47 5,959,634.05 645,379.19 0.00 1,129.62 0.00 TIP 9,090.00 21.99 90.64 8,598.55 458.73 2,089.46 5,959,634.46 645,412.18 1.10 1,153.10 11.57 KOP 9,100.00 22.77 91.80 8,607.80 458.65 2,093.27 5,959,634.45 645,415.98 9.00 1,155.85 30.00 9,110.00 23.57 92.89 8,616.99 458.49 2,097.20 5,959,634.37 645,419.92 9.00 1,158.74 28.93 End of 9 Deg / 100 DLS 9,140.00 33.05 102.51 8,643.39 456.41 2,111.22 5,959,632.55 645,433.97 35.00 1,170.13 30.00 4 9,170.00 39.25 116.95 8,667.64 450.32 2,127.71 5,959,626.78 645,450.57 35.00 1,186.09 60.00 5 9,200.00 39.15 133.60 8,690.96 439.46 2,143.07 5,959,616.21 645,466.14 35.00 1,204.64 97.0 9,300.00 53.29 178.97 8,761.84 375.61 2,167.41 5,959,552.85 645,491.69 35.00 1,266.99 84.06 9,370.00 70.29 199.16 8,795.08 315.52 2,156.94 5,959,492.57 645,482.37 35.00 1,302.08 51.57 6 9,400.00 70.63 188.02 8,805.14 288.09 2,150.31 5,959,465.02 645,476.26 35.00 1,316.79 -90.00 9,500.00 76.32 151.93 8,834.46 195.62 2,167.12 5,959,372.90 645,494.83 35.00 1,394.06 -86.26 9,600.00 86.81 118.11 8,849.54 127.09 2,236.17 5,959,305.70 645,565.17 35.00 1,491.35 -75.66 9,627.14 90.00 109.16 8,850.30 116.22 2,261.00 5,959,295.31 645,590.20 35.00 1,516.59 -70.54 End of 35 Deg / 100 DLS 9,700.00 90.00 100.41 8,850.30 97.65 2,331.38 5,959,278.08 645,660.91 12.00 1,579.49 -90.00 9,727.14 90.00 97.16 8,850.30 93.50 2,358.20 5,959,274.45 645,687.81 12.00 1,601.38 -90.00 8 3/13/2009 10:32:09AM Page 3 COMPASS 2003.16 Build 70 ~~ ~ ^ BP Exploration Alaska . ~ MYfIiBEf Baker Hughes INTEQ Planni ng Report by INTEQ Company: North America -ALASKA - BP Local Go-ordinate Reference: Well H-13 -Slot 13 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB H Pad MD Reference: 19:13 4/24/1981 00:00 @ 82.60ft (generic drillinC Well: H-13 North Reference: True Wellbore: Plan 4, H-13A Survey Calculat ion Method: Minimum Curvature Design: Plan 4 Database: EDM .16 - Anc Prod - WH24P Planned Survey MD Inc Azi TVDSS N/S E/W Northing Easting DLeg V. Sec TFO (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) (°) 9,800.00 90.15 105.90 8,850.20 78.96 2,429.52 5,959,261.26 645,759.38 12.00 1,662.10 89.00 9,900.00 90.35 117.90 8,849.76 41.73 2,522.13 5,959,225.81 645,852.68 12.00 1,753.91 89.0 10,000.00 90.54 129.90 8,848.98 -13.94 2,604.98 5,959,171.74 645,936.57 12.00 1,851.86 89.06 10,027.14 90.59 133.15 8,848.71 -31.93 2,625.30 5,959,154.14 645,957.23 12.00 1,878.94 89.16 9 10,100.00 90.58 124.41 8,847.96 -77.52 2,682.04 5,959,109.65 646,014.82 12.00 1,951.30 -90.00 10,200.00 90.55 112.41 8,846.97 -125.00 2,769.83 5,959,063.85 646,103.50 12.00 2,046.96 -90.09 10,277.14 90.51 103.15 8,846.26 -148.54 2,843.20 5,959,041.72 646,177.30 12.00 2,115.48 -90.21 10 10,300.00 90.51 105.90 8,846.06 -154.27 2,865.33 5,959,036.41 646,199.53 12.00 2,135.18 90.00 10,400.00 90.49 117.90 8,845.18 -191.49 2,957.94 5,959,000.97 646,292.83 12.00 2,226.98 90.02 10,500.00 90.45 129.90 8,844.35 -247.15 3,040.79 5,958,946.90 646,376.72 12.00 2,324.93 90.13 10,527.14 90.44 133.15 8,844.14 -265.14 3,061.11 5,958,929.30 646,397.37 12.00 2,352.02 90.23 11 10,600.00 90.44 124.41 8,843.58 -310.73 3,117.85 5,958,884.80 646,454.97 12.00 2,424.37 -90.00 10,700.00 90.41 112.41 8,842.84 -358.22 3,205.64 5,958,839.00 646,543.64 12.00 2,520.03 -90.07 10,800.00 90.37 100.41 8,842.15 -386.42 3,301.39 5,958,812.63 646,639.91 12.00 2,607.68 -90.1 10,827.14 90.36 97.15 8,841.98 -390.56 3,328.21 5,958,809.00 646,666.80 12.00 2,629.57 -90.2 12 10,900.00 91.11 105.86 8,841.04 -405.08 3,399.53 5,958,795.85 646,738.37 12.00 2,690.27 85.00 10,927.00 91.39 109.09 8,840.45 -413.19 3,425.27 5,958,788.24 646,764.27 12.00 2,714.20 85.11 2 7l8" 3/13/2009 10:32:09AM Page 4 COMPASS 2003.16 Build 70 ~R ^ BP Exploration Alaska sw NYGNtS Baker Hughes INTEQ Planning Report INTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Project: Prudhoe Bay TVD Reference: Site: PB H Pad MD Reference: Well: H-13 North Reference: Wellbore: Plan 4, H-13A Survey Calculation Method: Design: Plan 4 Database: ', Targets Target Name - hitlmiss target Dip Angle Dip Dir. TVD +N/-S -Shape j°) (°) (~) (ft) I ~ H-13A Fault 1 0.00 0.00 0.00 575.31 - plan misses target center by 8520.28ft at 9000.OOft MD (8514.82 TVD, 458.95 N, 2056.47 E) - Polygon Point 1 0.00 575.31 Point 2 0.00 385.70 Point 3 0.00 361.39 Point 4 0.00 257.11 Point 5 0.00 53.32 Point 6 0.00 -774.18 Point 7 0.00 53.32 Point 8 0.00 257.11 Point 9 0.00 361.39 Point 10 0.00 385.70 H-13A Target 3 0.00 0.00 8,850.00 187.34 - plan misses target center by 17.02ft at 9522.53ft MD (8839.40 TVD, 176.99 N, 2178.76 E) - Point H-13A Target 1 0.00 0.00 8,617.00 459.12 - plan hits target center - Point H-13A Target 5 0.00 0.00 8,840.00 -421.34 - plan misses target center by 9.16ft at 10925.24ft MD (8840.50 TVD, -412.62 N, 3423.61 E) - Point H-13A Target 4 0.00 0.00 8,845.00 -150.31 - plan misses target center by 1.66ft at 10280.18ft MD (8846.23 TVD, -149.24 N, 2846.16 E) - Point H-13A Target 2 0.00 0.00 8,860.00 614.97 - plan misses target center by 259.02ft at 9200.OOft MD (8690.96 TVD, 439.46 N, 2143.07 E) - Point H-13A Polygon 0.00 0.00 0.00 381.33 - plan misses target center by 8515.51ft at 9000.OOft MD (8514.82 TVD, 458.95 N, 2056.47 E) - Polygon Point 1 0.00 381.33 Point 2 0.00 192.69 by Well H•13 -Slot 13 Mean Sea Level 19:13 4/24/1981 00:00 @ 82.60ft (generic drillinc True Minimum Curvature EDM .16 - Anc Prod - WH24P - - - +EI-W Northing Easting (ft) (~1 (ft) Latitude Longitude 1,774.43 5,959,745.00 645,095.00 70° 17' 50.723 N 148° 49' 29.926 W 1,774.43 5,959,745.00 645,095.00 2,275.94 5,959,565.00 645,600.00 3,025.67 5,959,555.00 646,350.00 3,248.74 5,959,455.00 646,575.00 3,444.91 5,959,255.00 646,775.00 4,089.29 5,958,440.00 647,435.00 3,444.91 5,959,255.00 646,775.00 3,248.74 5,959,455.00 646,575.00 3,025.67 5,959,555.00 646,350.00 2,275.94 5,959,565.00 645,600.00 2,187.14 5,959,365.00 645,515.00 70° 17' 46.906 N 148° 49' 17.899 W 2,097.30 5,959,635.00 645,420.00 70° 17' 49.579 N 148° 49' 20.516 W 3,420.85 5,958,780.00 646,760.00 70° 17' 40.915 N 148° 48' 41.947 W 2,845.87 5,959,040.00 646,180.00 70° 17' 43.583 N 148° 48' 58.702 W 2,055.26 5,959,790.00 645,375.00 70° 17' 51.112 N 148° 49' 21.740 W 1,980.78 5,959,555.00 645,305.00 70° 17' 48.815 N 148° 49' 23.913 W 1,980.78 5,959,555.00 645,305.00 1,907.16 5,959,365.00 645,235.00 3/13/2009 10:32:09AM Page 5 COMPASS 2003.16 Build 70 art BAKiR NY6MEf INTEQ BP Exploration Alaska Baker Hughes INTEQ Planning Report bP Company: North America -ALASKA - BP Local Co-ordinate Reference: Well 1+13 -Slot 13 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB H Pad MD Reference: 19:13 4/24/1981 00:00 @ 82.60ft (generic drillinc= Well: H-13 North Reference: True Wellbore: Plan 4, H-13A Survey Calculation Method: Minimum Curvature Design: Plan 4 Database: EDM .16 - Anc Prod - WH24P I_ ._ Point 3 ~ Point 4 Point 5 Point 6 Point 7 Point 8 Casing Points 0.00 0.00 0.00 0.00 0.00 0.00 3.26 2,398.68 5,959,185.00 645,730.0( -510.76 3,389.13 5,958,690.00 646,730.0( -337.49 3,482.46 5,958,865.00 646,820.0( 56.15 3,034.85 5,959,250.00 646,365.0( 92.91 2,680.46 5,959,280.00 646,010.0( 293.48 2,129.14 5,959,470.00 645,455.0( Measured Depth (ft) ~ 10,927.00 Vertical Depth (ft) 8,840.45 7/8" Name Casing Hole i Diameter Diameter (..) („) 2-7/8 4-1/8 _ - - Plan Annotations - _ - - - - -, ~ Measured Vertical Local Coordinates Depth Depth +N/-S +FJ-W ', (ft) (ftj (ft) (ft) Comment ~ 9,000.00 8,514.82 458.95 2,056.47 TIP 9,090.00 8,598.55 458.73 2,089.46 KOP 9,110.00 8,616.99 458.49 2,097.20 End of 9 Deg / 100 DLS 9,140.00 8,643.39 456.41 2,111.22 4 9,170.00 i 8,667.64 450.32 2,127.71 5 ~ 9,370.00 8,795.08 315.52 2,156.94 6 9,627.14 8,850.30 116.22 2,261.00 End of 35 Deg / 100 DLS 9,727.14 8,850.30 93.50 2,358.20 8 10,027.14 8,848.71 -31.93 2,625.30 9 10,277.14 8,846.26 -148.54 2,843.20 10 10,527.14 8,844.14 -265.14 3,061.11 11 10,827.14 8,841.98 -390.56 3,328.21 12 10,927.00 8,840.45 -413.19 3,425.28 TD Checked By: Approved By: Date: 3/13/2009 10:32:09AM Page 6 COMPASS 2003.16 Build 70 by Project: Prudhoe Ba M li N rm z2 ro WELLBORE DETAILS: Plan 4, H-13A REfERENCEINFOf2MAnON y Site: PBHPad . agne o : MagrreYC Frew Parent Welbore: H-13 CouminatelN~E)Reference: Well H-13-SIOt13, TrueNoM Well: H-13 Wellbore: Plan 4, H-13A so-e,gma~ae4 c~ OipAngle: 80.91 Tie on MD: 9000.00 VeNraIITVD)Reterence~ Mean Sea Levd Secfion (VSIReference. Sk1-131000N,OOOE) Plan: Plano (H-131PIa0 4, H-73A) : B'~ Measured Depth Reference: 19 134241795100:00@ 82 608 IgenericdrilGn9~9) Cakulaton McSad-. Miromum0urvalu2 WELL DETAILS: H-13 Ground Level: 0.00 +WS +E/-W Northing Easlirg LalitWde Longitutle Slot 0.00 0.00 5969136.00 643332.00 70° 1 T 45.067 N 148° 50' 21.650 W 13 SECTION DETAILS ANNOTATIONS Sec MD Inc Azi ssTVD +W-S aEl-W DLeg TFace VSec Target Annofatbn 1 9000.00 21.02 90.11 8514.82 458.95 2056.47 0.00 0.00 1129.62 TIP 2 9090.00 21.99 90.64 8598.55 458.73 2089.46 1.10 11.57 1153.10 KOP 3 9110.00 23.57 92.89 8616.99 458.49 2097.20 9.00 30.00 1158.74 Endof9Deg1100DLS 4 9140.00 33.05 102.51 8643.39 456.41 2111.22 35.00 30.00 1170.13 4 5 9170.00 39.25 116.95 8667.64 450.32 2127.71 35.00 60.00 1186.09 5 6 9370.00 70.29 199.16 8795.08 315.52 2156.94 35.00 97.00 1302.08 6 7 9627.14 90.00 109.16 8850.30 116.22 2261.00 35.00 270.00 1516.59 End of 35 Deg 1100 DLS 8 9727.14 90.00 97.16 8850.30 93.50 2358.20 12.00 270.00 1601.38 8 9 10027.14 90.59 133.15 8848.71 -31.93 2625.30 12.00 89.00 1878.94 9 10 10277.14 90.51 103.15 684626 -148.54 2843.20 12.00 270.00 2115.48 10 11 10527.14 90.44 133.15 8844.14 -265.14 3061.11 12.00 90.00 2352.02 I 11 12 10827.14 90.36 97.15 8841.98 -390.56 3328.21 12.00 270.00 2629.57 ~ 12 13 10927.00 91.39 109.09 8840.45 413.19 3425.28 12.00 85.00 2714.20 TD 0 ~_ a Q U .~ ~r~.r BAKER NuaNEs INTEQ u Vertical Section at 135.00° (50 fUin) West(-)/Bast(+) (100 fdin) by W O O ,.' 1; 7O O Mean Sea Let Project: Prudhoe Bay AzimNnb Rue NaM MegneYCNaM:YL 10 WELLBORE DETAILS: Plan 4, H-13A REFERENCE INFORMATION Site: PBHPed . Magreoc Faa Parent Wellbore: H-t3 CouNinate (NrEl Reference: Wed H-13-SIo113, True NOM Well: H-73 soa~gm_s~aea cam, T MD 9000 00 veNral(1VDIRehrence. Mean Sea lsvm WellbOre: PIan 4, H-73A dpArgle: tm.91° ie on : . Secfion (VS)Relerence: Slot-13(e00N,000E) Plen: Plan 4 (H-13/Plan 4 H-13A) °a- y n~ Measures Depth Reference: 19:13424/110000 @82,fiefl (ga erlc driltln9d9) , 2M~ cG Calculation Method: Minimun Curvature ~~~r BAKER HU6HES INTEQ -14tH IH § 600 -- -14 H-14 4 , --- ~, H- 4/H-14 soo f y0 aoo 300 -- 200 -- 's .100 - --- 000 - -- o° a ~\ 900 --- / ~~ H-14/ -148 800 --- 700 ~ ~~ 0 600 ~ 'y ~p cR 7800 ~ $ 9A °o kI-I .H-13 500 ~ 0/ 0 400 ---- - -- 5/H-3 "' H-U2! I-Il_ BI ' c o c o 300 fI-U'_i I-U2A Bi O 200 - ~ ~ ~ o --_ a ~ 100 ~ -- ~ o~ 0 _ Ru l 100 - 20U ~ - 9~ _ - ____ SA -300 -14-32 - /H-3 IPBI 400 1 - /H-I~ II-3 / I-37L1 5a - f.37 i -37A D i R-}OGf /H-10 tyy00 H- 3/PIan ,H- -500 -1 APBf -16 B~ ~- ~ ____- _-..--_. 00 o° o ,~ 5 _600 _ ... _.. . .__ _ 700 -- - ,~ ~tio -~ ~ -800 - - ----- -- -900 ~~ r 6600 qp II-OG H-0G - AP 17f( Li~PSI 0 2 ~ /H I - H IN iGFI (llA- -OII O1 - - -_ H-03/f -O3 ~ H 23 H-23 IA `I 1, u -, ~~ ~ ,~~ ..~., .,..~ ~..~ ~~~ "' ,~~ ow ,w .ow ,goo ,mow ,moo ,YOO voo .o ~ „ rood i>oo _ooo uw a~w yaw wuu sauu ~ouu cruu -,ravr iruu auoo ~wv ~~uu »uu ~ruu »uu eauo West(-)/East(+) (100 ft/in) n LJ r~a~ BAKER Mlr1GHES INTEQ North America Prudhoe Bay PB H Pad H-13 Plan 4, H-13A Plan 4 - ALAS KA - B P Travelling Cylinder Report 12 March, 2009 by ~ii~ • BP Exploration Alaska BAKER NYBMtf Travelling Cylinder Report INTEQ Company: North America -ALASKA - BP Local Co-ordinate Reference: Project: Prudhoe Bay TVD Reference: Reference Site: PB H Pad MD Reference: Slte Error: O.OOft North Reference: Reference Well: H-13 Survey Calculation Method: .Well Error: O.OOft Output errors are at Reference Wellbore Plan 4, H-13A Database: .Reference Design: Plan 4 Offset TVD Reference: P Well H-13 -Slot 13 Mean Sea Level 19:13 4/24/1981 00:00 @ 82.60ft (generic drilling rig) True Minimum Curvature 1.00 sigma EDM .16 - Anc Prod - WH24P Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Wel{ -Wellbore -Design (ft) (ft) (ft) (ft) PB H Pad H-01 - H-01 - H-01 Out of range H-01A - H-01A - H-01A Out of range H-01AP61 - H-01APB1 - H-01AP61 Out of range H-02 - H-02 - H-02 Out of range H-02 - H-02A - H-02A Out of range H-02 - H-02A - H-02A wp17 Out of range H-02 - H-02AP61 - H-02a wp15 Out of range H-03 - H-03 - H-03 Out of range H-06 - H-06 - H-06 Out of range H-09 - H-09 - H-09 Out of range H-10 - H-10 - H-10 Out of range H-10AP61 - H-10APB1 - H-10AP61 Out of range H-13 - H-13 - H-13 9,124.89 9,125.00 1.33 11.73 -7.48 FAIL -Major Risk H-14 - H-14 - H-14 Out of range H-14 - H-14A - H-14A Out of range H-14 - H-14AP61 - H-14APB1 Out of range H-14 - H-14AP62 - H-14AP62 Out of range H-14 - H-14APB3 - H-14APB3 Out of range H-14 - H-14APB4 - H-14AP64 Out of range H-14 - H-146 - H-146 10,400.00 12,360.00 1,271.75 316.13 972.70 Pass -Major Risk H-14 - H-146 - H-14B RST wp07 10,450.00 12,543.02 1,175.96 298.59 886.57 Pass -Major Risk H-21 - H-21 - H-21 9,550.00 9,425.00 1,286.27 518.59 770.79 Pass -Major Risk H-23 - H-23 - H-23 10,725.00 9,750.00 1,004.67 730.15 281.69 Pass -Major Risk H-23A - H-23A - H-23A 10,725.00 9,450.00 1,107.32 658.70 518.09 Pass -Major Risk H-23APB1 - H-23AP61 - H-23APB1 10,725.00 9,450.00 1,107.32 658.70 518.09 Pass -Major Risk H-35 - H-35 - H-35 Out of range H-37 - H-37 - H-37 Out of range H-37 - H-37A - H-37A Out of range H-37 - H-37APB1 - H-37AP61 Out of range H-37 - H-37L1 - H-37L1 Out of range H-37 - H-37L1 P61 - H-37L1 PB1 Out of range H-37 - H-37P81 - H-37P61 Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/12/2009 4:03:33PM Page 3 of 12 COMPASS 2003.16 Build 70 rements are i ~_ of bag . - . - BAG Dowel I of bag Blind/Shears of pipes 2 3/8" combi ram/slips • H-13A TOTs Mud Cross I I Mud Cross middle of flow cross of blind/shears variable bore wipe 3 1/2"-2 7/8" of pipelslips 2 3/8" combi ram/slips Swab Valve TOTs Flow Tee Alaska Department of Natural ~ources Land Administration System ~ Page 1 of/Z ~ ~•4 '=Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources ~• Alaska DNR Gase Summary File Type: A~~ File Number: 28284 ~ Printable Case File Summary See Township, Range, Section and Acreage? New Search ~' Yes ~) No LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28284 '~'=; Search for Status Plat Updates As of 04/13/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784. OIL & GAS LEASE COMP DNR Unit.• 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status.• 35 ISSUED Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated.• 05/28/ 1965 OO~ce of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date• 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: 011 N Range: 013E Section: 15 Section Acres: 640 Plats Meridian: U Township: O11N Range: 013E Section: 16 Section Acres: 640 Meridian: U Township: 011 N Range: 013E Section: 21 Section Acres: 640 Meridian: U Township: Ol1N Range: 013E Section: 22 Section Acres: 640 Legal Description OS-28-1965 * * *SALE NOTICE LEGAL DESCRIPTION* C14-95 Tl l N-R13E- UM 15,16, 21, 22 2560.00 End of Case Summary Last updated on 04/13/2009. Search. n1,&FileNumber=~R?R 4/13/ .009 TRANSMITTAL LETTER CHECKLIST WELL NAME P~'~ ~ fell PTD# 0?090~.SLp /Development Service Exploratory Stratigraphic Test Non-Conventional WeII FIELD: _ .~.CL/Dh/OGC"' ~ Ay POOL: _ ~.G~6l.D~~~ ~•Qy O/G Circle Appropriate Lette r /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS ~rL{gT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existin g (If last two digits API number wel l in } Permit No. ,API No. 50- - _ between GO-~.9) are Production should continue to be reported as a function of the original AP[ number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -,) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that ma occur y . DRY DI"(~CH SAMPLE All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throe h tar et zones. Non-Conventional Welt Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for (name of well) until after (Comaanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _(Comnany Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: i / 11/2008 '~~ n ~ Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 -T C _ --Well Name: PRUDHOE BAY UNIT H-13A _ --Program DEV _ Well bore seg ^ PTD#:2090440 Company BPEXPLORATION-(ALASKA INC - .Initial ClasslType DEV/ PEND GeoArea _890 - Unit 11650 ___ OnlOff Shore On_. ___ Annular Disposal ^ Administration 1 Permit fee attached NA 2 Lease number appropriate.. Yes 3 Unique well-name and number Yes ~I 4 Well located in a-defined pool. Yes Prudhoe Bay Oil Pool.- - !, 5 Well located proper distance from drilling unit boundary Yes - - - - - ', 6 Well located proper distance_from_otherwells Yes 7 Sufficient acreage available in drilling unit Yes 2560 acres. 8 If deviated, is wellbore plat_included - Yes - 9 Ope[ator only affected party- - _ Yes 10 Operator has-appropriate-bond in force Yes Blanket Bond # 6194193. 11 Permit can be issued without conservation order. Yes Appr Date '112 Permit-can be issued without administrative-approval - Yes 13 '' Can permit be approved before 15-day wait- Yes , ACS 4113!2009 '14 Well located within area and strata authorized by Injection Order # (put 10# in_comments)-(For. N_A 15 All wells within 1l4 mile area of review identified (For service w_el_I only). NA- - - ',16 Pre-produced injector: duration of pre-production less than-3 months (For servicewell_only) NA- ~117 Nonconyen, ga_s conforms to AS31.05.030Q,1.A),Q,2_.A-D) - - _ N_A - - '118 Conductor stung provided NA Conductorset in H-.13 (181.017). Engineering 1119 Surface casing-protects all known. USDWs NA Altaquifers exempted AE01. 20 C_MT vol-adequate to circulate on conductor & surf_csg - NA Surface casing set in H-13. ',21 C_MT-vol-adequate to tie-in long string to surf csg NA Production casing set in H-13. '22 CMT will coyer all known productive horizons- - - - Yes 23 .Casing designs adequate for C, T, B &-permafrost- - Yes 24 Adequate tankage. or reserve pit Yes Rig equipped with steel pits. No reserve planned.. All waste. to approved disposal_well(s). j25 If a_re-drill, has a 1.0-403 for abandonment been approved Yes 30.9-217 26 Adequate wellbore separationgroposed Yes Pr_oximityanalysis performed. Nearest segment P&A portion-of H-13 and paths diverge. '127 If diverter required, does it meet. regulations- NA BOP stack_will already be_in place.- App '28 r Date I Drilling fluid program schematic & equip list_adequate Yes Maximum expected formation- pressure 7.0_EMW, MW planned B.Ei ppg. TEM 4/13!2009 129 BOPEs, do they meetregulation Yes 30 BOPE-press rating appropriate; test to-(put prig in comments). Yes MASP calculated at 2329 psi. 3500_psi BOP testplanned, _ X31 Chokemanifold complies wlAPl RP-53 (May 84)- - - - - - - - Yes 132 Work will occur without operation shutdown- Yes '33 Is presence of H2S gas. probable Yes H2S is known at H pad.. Mud should preclude H2S on rig.- Rig has sensors and alarms... 34 Mechanical condition of wells within AOR verified (For-service well only) NA 35 Permit can be issued w/o hydrogen-sulfide measures No- - Max level H2S on H pad i& 180ppm on well H-22A. Geology 36 Data_presented on_ potential overpressure zones NA- Appr Date '37 Seismic analysis-of shallow gas-zones NA --- ACS 4/13/2009 X38 1 Seabed condition survey (ifoff-shore) NA 139 Contact namelphone for weekly_p_rogress reports [exploratory only] - - Yes - Sean McLaughlin - 564-4387 Geologic Engineering Public Date: Date Date Commissioner: Commissione : ~ / Commi~ ne~~ ~//~ JII~// ~- J ~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • tapescan.txt **** REEL HEADER **** MWD 09/08/26 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 09/06/15 2636462 Ol 3" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: one line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 8905.0000: Starting Depth STOP.FT 10388.0000: Ending Depth sTEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: H-13A FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 17' 45.067"N 149 deg 50' 21.650"w CNTY. COUNTY: North slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 15 Jun 2009 API API NUMBER: 500292055901 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 21 TOWN.N T11N RANG. R13E PDAT. MSL EPD .F 0 LMF DF FAPD.F 82.6 DMF DF EKB .F 0 EDF .F 82.6 EGL .F 0 Description section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Page 1 ~Og -D~l`/ 4 f U ~~L~ u CASE.F N/A OS1 DIRECTIONAL • tapescan.txt Casing Depth other services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to lob this well.. (6) Tools ran in the string included casing Collar Locator, an Electrical Disconnect and Circulating sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma sub, and a Hydraulic orienting Sub with a Near Bit Inclination sensor. (7) Data presented here is final and has been depth ad'usted to a Primary Depth Control (PDC) tog provided by schlum~erger GR CNL dated 17 Tun 2009 per Roger sels with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from H-13 through a milled window in a 7 inch liner. Top of window 9084 ft.MD (8593.0 ft.TVDSS) Bottom of window 9093 ft.MD (8601.3 ft.TVDSS) (9) Tied to H-13 at 9000 feet MD (8514.8 feet TvDSS). (10) The interval from 10350 feet to 10390 feet MD (8819.9 feet to 8816.2 feet TvDSS) ' was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP~4VG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected (OHMM) TvDSS -> True vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 8903.48, 8905.25, ! 1.76367 8904.36, 8906.83, ! 2.46875 8916.36, 8915.83, ! -0.529297 8924.47, 8923.94, ! -0.529297 8925.88, 8925.17, ! -0.705078 8932.05, 8935.76, ! 3.7041 8937.52, 8940.17, ! 2.64551 8941.75, 8944.75, ! 2.99805 8944.22, 8947.04, ! 2.82227 8948.46, 8952.51, ! 4.05566 8957.1, 8961.68, ! 4.58594 8958.86, 8962.92, ! 4.05664 8963.97, 8966.09, ! 2.11719 8968.56, 8969.79, ! 1.23438 8977.73, 8979.32, ! 1.58691 8980.38, 8981.79, ! 1.41113 8985.32, 8986.02, ! 0.705078 9082.35, 9083.23, ! 0.881836 9091.88, 9090.47, ! -1.41016 9094.35, 9093.46, ! -0.881836 9098.23, 9097.7, ! -0.529297 9102.63, 9102.81, ! 0.176758 9106.16, 9107.4, ! 1.23438 9108.81, 9109.87, ! 1.05762 9114.98, 9114.98, ! 0 9121.68, 9122.04, ! 0.352539 Page 2 • 9127.15, 9128.91, 9130.32, 9131.03, 9132.44, 9132.44, 9134.56, 9134.91, 9141.12, 9140.24, 9142, 9142.18, 9146.2, 9145.49, 9148.35, 9148.7, 9151.7, 9151.52, 9154.88, 9154.88, 9158.93, 9159.28, 9168.28, 9165.99, 9171.98, 9169.69, 9176.92, 9176.04, 9179.21, 9178.51, 9181.51, 9180.8, 9186.44, 9186.09, 9189.62, 9189.44, 9192.44, 9191.56, 9205.17, 9202.18, 9208.17, 9205.7, 9212.23, 9210.11, 9214.52, 9212.41, 9218.75, 9218.75, 9226.34, 9226.69, 9230.92, 9230.04, 9234.63, 9233.39, 9240.8, 9239.39, 9246.44, 9245.21, 9249.44, 9249.09, 9253.15, 9252.62, 9254..2, 9254.03, 9260.87, 9259.81, 9265.63, 9265.1, 9267.75, 9266.69, 9277.98, 9276.74, 9284.15, 9282.92, 9287.15, 9286.44, 9290.32, 9289.97, 9298.08, 9297.56, 9301.79, 9300.55, 9305.65, 9304.24, 9312.88, 9311.65, 9315.17, 9314.29, 9316.58, 9316.06, 9322.41, 9321.52, 9325.23, 9324.52, 9328.05, 9327.34, 9329.81, 9329.46, 9337.75, 9337.93, 9349.94, 9349.41, 9354.17, 9353.46, 9362.28, 9361.58, 9368.46, 9366.87, 9373.39, 9373.57, 9395.79, 9395.62, 9400.17, 9399.81, 9401.93, 9402.28, 9404.75, 9405.28, 9441.44, 9441.61, 9467.17, 9466.99, 9523.69, 9523.52, 9526.69, 9526.34, tapescan.txt 1.76367 0.705078 0 0.353516 -0.881836 0.175781 -0.706055 0.353516 -0.176758 0 0.353516 -2.29297 -2.29297 -0.881836 -0.705078 -0.705078 -0.352539 -0.176758 -0.881836 -2.99902 -2.46973 -2.11719 -2.11621 0 0.353516 -0.881836 -1.23535 -1.41113 -1.23438 -0.352539 -0.529297 -0.175781 -1.05859 -0.529297 -1.05762 -1.23438 -1.23438 -0.705078 -0.352539 -0.52832 -1.23438 -1.41113 -1.23438 -0.881836 -0.52832 -0.881836 -0.706055 -0.705078 -0.352539 0.176758 -0.529297 -0.705078 -0.706055 -1.58789 0.176758 -0.176758 -0.353516 0.352539 0.529297 0.175781 -0.175781 -0.176758 -0.353516 Page 3 • i • tapescan.txt 9532.69, 9532.69, ! 0 9535.33, 9536.21, ! 0.881836 9539.04, 9539.39, ! 0.352539 9568.23, 9568.58, ! 0.352539 9572.63, 9572.63, ! 0 9611.81, 9611.1, ! -0.705078 9692.11, 9691.93, ! -0.175781 9701.63, 9702.33, ! 0.706055 9747.04, 9746.69, ! -0.352539 9768.38, 9769.09, ! 0.706055 9787.52, 9787.34, ! -0.176758 9792.46, 9791.05, ! -1.41016 9799.51, 9798.1, ! -1.41113 9805.16, 9802.51, ! -2.64551 9807.63, 9805.33, ! -2.29297 9812.65, 9811.24, ! -1.41113 9829.23, 9828.53, ! -0.705078 9861.77, 9861.42, ! -0.352539 9903.04, 9901.98, ! -1.05762 9923.67, 9922.09, ! -1.58691 9924.91, 9923.5, ! -1.41113 10024.1, 10022.5, ! -1.58691 10053, 10052.2, ! -0.881836 10056.7, 10055.2, ! -1.58789 10058.7, 10057.8, ! -0.881836 10063.6, 10061.7, ! -1.93945 10065, 10063.4, ! -1.58691 10067.5, 10065.4, ! -2.11621 10068.9, 10067.5, ! -1.41113 10070.5, 10069.8, ! -0.706055 10080.4, 10080, ! -0.352539 10085.5, 10085, ! -0.52832 10094.2, 10091.7, ! -2.46875 10100.7, 10097.2, ! -3.52734 10107.9, 10106, ! -1.94043 10113.9, 10113.2, ! -0.705078 10118.2, 10116.2, ! -1.94043 10128.2, 10125.7, ! -2.46973 10137, 10135.1, ! -1.94043 10140.4, 10137.4, ! -2.99805 .10144.9, 10141.9, ! -2.99805 10161, 10159.2, ! -1.76367 EOZ END BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 206 records... 10 bytes 132 bytes *** LIS COMMENT RECORD *** Page 4 • • tapescan.txt !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth control (PDC) log provided by schlumberger GR CNL dated 17 Tun 2009 per Roger Sels with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) optical Lod Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.500 * F 1 ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code samples units Size Length 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD 68 1 F%HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 83 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File start De th = 8905.000000 Tape File End Depth = 10388.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet **** FILE TRAILER **** Tape subfile: 2 96 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 Page 5 • • tapescan.txt *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) opticall Loy Depth Scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD Code samples units 68 1 F%HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 166 Tape File start Depth = 8902.750000 Tape File End Depth = 10390.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 3 179 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 09/06/15 2636462 O1 Page 6 • tapescan.txt **~* REEL TRAILER ***~ MWD 09/08/26 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 8905.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8905.5000 56.7049 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9000.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9100.0000 26.2528 8.1786 5.3974 12.7441 13.4594 10.1212 9200.0000 28.1458 81.8548 21.8350 36.4888 29.8514 27.9361 9300.0000 31.5584 96.2805 28.8185 50.8645 38.9266 32.5200 9400.0000 42.7167 47.5833 15.4505 18.8215 17.0021 15.8168 9500.0000 21.1479 34.2922 5.9748 7.1640 6.3558 5.9794 9600.0000 21.3061 58.0061 4.6848 4.8766 4.6103 4.4087 9700.0000 24.2074 52.7091 5.0742 5.3322 5.2012 5.1662 9800.0000 38.0673 48.5892 7.0999 7.8136 6.6583 5.7147 Page 7 • tapescan.txt 9900.0000 27.3402 77.3736 12.8739 13.3563 11.9946 10.8064 10000.0000 24.6000 32.5869 8.9457 10.4200 9.9840 10.2083 10100.0000 22.6893 37.4072 17.4831 20.7386 20.3390 20.9147 10200.0000 26.6604 25.4398 11.8398 12.5698 11.5513 11.0663 10300.0000 40.5193 44.4799 12.7574 13.6382 12.9130 12.2867 10388.0000 -999.2500 28.4613 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 8905.000000 Tape File End Depth = 10388.000000 Tape File bevel Spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 8902.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8903.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9000.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9100.0000 26.0000 8.6000 5.1450 12.5030 13.8960 10.6130 9200.0000 25.1000 78.1000 21.5140 34.5180 26.2620 23.2320 9300.0000 43.8000 69.9000 28.5680 51.3000 35.7930 29.9290 9400.0000 52.8000 60.6000 15.8960 18.8930 17.3400 16.6070 9500.0000 22.3000 17.5000 6.0080 7.2900 6.3240 5.8600 9600.0000 18.9000 59.5000 4.7000 4.8680 4.7270 4.6430 9700.0000 27.3000 52.7000 5.0490 5.2470 5.1310 5.0870 9800.0000 30.9000 47.1000 7.0790 7.8090 6.7010 5.8130 Page 8 tapescan.txt 9900.0000 27.1000 79.0000 12.3350 11.1470 10000.0000 26.2000 52.8000 9.7870 10.0010 10100.0000 27.8000 39.1000 21.6120 22.5940 10200.0000 28.0000 24.8000 12.6810 12.3500 10300.0000 68.5000 48.8000 12.4400 11.6540 10390.0000 -999.2500 27.1000 -999.2500 -999.2500 Tape File Start Deppth = 8902.750000 Tape File End Dept h = 10390.000000 Tape File Level spacing = 0.250000 Tape File Depth units = feet 0 Tape Subfile 4 is type: LIS 13.0110 8.7090 17.5130 12.9410 12.6520 -999.2500 13.6390 10.1730 21.3880 13.2210 13.7560 -999.2500 Page 9