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Home My WebLink About208-1257. 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 01-34A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-125 50-029-21609-01-00 9472 Conductor Surface Intermediate Liner Liner 9227 80 2471 7951 5811 824 8900 20" 13-3/8" 9-5/8" 7" 4-1/2" 8666 32 - 112 30 - 2501 27 - 7978 3023 - 8834 8646 - 9470 32 - 112 30 - 2501 27 - 7775 3023 - 8601 8417 - 9227 None 470 2270 4760 5410 7500 8900, 8974, 9017, 9060, 9115, 9143 1490 4930 6870 7240 8430 8838 - 9320 4-1/2" 12.6# 13Cr80 25 - 8658 8605 - 9078 Structural 4-1/2" Baker S-3 Packer 8580 8352 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 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 0028329 25 - 8427 N/A N/A 630 636 73543 67258 6 23 1255 1560 1031 992 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 8580, 8352 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 Bo York (1248) DN: cn=Bo York (1248) Date: 2025.05.20 12:39:30 - 08'00' Bo York (1248) DSR-6/3/25JJL 6/13/25 ACTIVITYDATE SUMMARY 4/26/2025 ***WELL S/I ON ARRIVAL*** RAN 20' x 3.16 DUMMY GUNS, 3.70 CENT TO 8950' SLM ***WELL LEFT S/I ON DEPARTURE *** 4/28/2025 ***WELL S/I ON ARRIVAL*** (SET PLUG / ADPERF) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH NO PUMP TRUCK AND FLUID AVAILABLE TO LOAD THE WELL AND TEST THE PLUG, LAID DOWN THE LUBRICATOR FOR THE NIGHT ***JOB CONTINUE ON 4/29/2025*** 5/6/2025 FL-936 ( HOT OIL TREATMENT ) Pumped 10 bbls 60/40 down FL followed by 145 bbls of 190*F Crude. DSO Notified of well status upon departure. Well SI on departure. 5/12/2025 *** WELL SHUT IN ON ARRIVAL*** ( PLUG SET / ADPERF ) MIRU YELLOW JACKET E-LINE. PT PCE 300 PSI LOW./3000 PSI HIGH, FUNCTION TEST WIRELINE VALVES DRIFT WITH JUNK BASKET GAUGE RING, 3.600" TAG YJOS CIBP @ 8974' CORRELATED TO SLB RESERVOIR SATURATION LOG DATED 24-OCT-2013 SET YJOS CIBP AT 8900' CCL TO MID ELEMENT=12.7' CCL STOP DEPTH=8887.3'. TAG AFTER SET PERFORATE 8838' - 8860' WITH 2.75" 6SPF 60PHASE HSC W/GEODYNAMICS RAZOR CHARGES (.39"EHD, 37.45"TTP) CCL TO TOP SHOT 14.5' CCL STOP DEPTH=8823.5', CONFIRM SHOTS FIRED RDMO YELLOWJACKET E-LINE ***WELL S/I ON DEPARTURE*** JOB COMPLETE 5/12/2025 TFS U4, (Assist E-line) W/ load and test, Initial WHP T/IA/OA= 2400/1000/0, Load TBG with 150 bbls crude, helped pump down plug to target depth took 17 bbls crude at .5 BPM, ***Well left in yellow jacket E-line control*** Daily Report of Well Operations PBU 01-34A 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 01-34A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-125 50-029-21609-01-00 9472 Conductor Surface Intermediate Liner Liner 9227 80 7952 5811 824 8974 20" 9-5/8" 7" 4-1/2" 8739 32 - 112 27 - 7979 3023 - 8834 8646 - 9470 32 - 112 27 - 7775 3023 - 8601 8417 - 9227 none 470 4760 5410 7500 8974 , 9060 , 9115, 9143 1490 6870 7240 8430 8944 - 9320 4-1/2" 12.6# 13Cr80 25 - 8658 8709 - 9078 Structural 4-1/2" Baker S-3 , 8580 , 8352 No SSSV 8580 8352 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 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 0028329 25 - 8427 627 838 72149 71895 28 27 1186 1554 1003 982 N/A 13b. Pools active after work:PRUDHOE OIL 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 11:06 am, Jan 16, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.01.15 16:28:27 - 09'00' Bo York (1248) RBDMS JSB 012825 31 - 2501 DSR-1/16/25SFD 2/10/2025 13-3/8"5380 JJL 2/7/25 2472 2670 SFD31 - 2501 ACTIVITYDATE SUMMARY 12/19/2024 ***WELL S/I ON ARRIVAL*** CONDUCT MAN DOWN DRILL w/ WSS RAN 3' x 1-7/8" STEM, 3.70" G-RING, TAGGED CIBP @ 9000' SLM/9014' MD (No Issues) RAN 34' x 3-3/8" DMY GUN (3.66" swell rings). TO S/D @ 9000' SLM/9014' MD (No Issues) ***WELL LEFT S/I ON DEPARTURE*** 12/20/2024 ***WELL SHUT IN ON ARRIVAL*** (PLUG / ADPERF) RIG UP AKE PCE FUNCTION TEST WLV'S PT 250L 3000H LOAD 150 BARRELS CRUDE WITH THUNDERBIRD SET NS CIBP @ 8974 CCL STOP DEPTH=8961.2 (CCL-ME=12.8') TEST CIBP 500 PSI 10 MINS. PASS PERFORATE (8944-8970) 2.75" GUN 6 SPF 60 DEGREE PHASE CCL STOP DEPTH= 8934.9' (CCL-TS=9.1') PERFORM MAN DOWN DRILL W WSL ***WELL SHUT IN ON DEPARTURE*** JOB COMPLETE 12/20/2024 T/I/O=2300/750/0 Temp=S/I (Assist E-Line with load and test) Pumped 150 BBLS of crude down TBG for load. Pumped an additional 2 BBLS of crude down TBG to pressure test plug to 500 PSI. Final WHPS=500/750/0 E-Line in control of well DSO notified of departure Daily Report of Well Operations PBU 01-34A • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, September 13, 2017 1:08 PM To: AK, OPS EOC Specialists;AK, OPS GC1 Facility OTL;AK, OPS GC1 Field O&M IL;AK, OPS GC1 OSM;AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad EKG;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;Oshiro,Joleen; 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;Tempel,Joshua;Worthington, Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer 01-34 (PTD#2081250)Well barriers restored, MIT Passed All, Producer 01-34 (PTD#2081250) was made under evaluation on 09/07/17 for having sustained inner annulus casing pressure over NOL. Dummy gas lift valves were set and the well passed a MIT-IA on 9/13/17. The passing pressure test confirms two competent well barriers. At this time the well is reclassified as Operable. Plan Forward/Work Completed: 1. Slickline: Change out gas lift valves. 2. DHD: TIFL - Failed 3. Slickline: Set dummy gas lift valves - Complete 4. Fullbore: Assist SL, MIT-IA—Pass 5. Slickline: Set new gas lift valves. Please be mindful of possible fluid packed annuli when bringing well online. Please respond with any questions, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 sawn 1.s E Harmony 4530 1 �' 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, September 7, 2017 1:04 PM To: AK, GWO Well Integrity Engineer;AK, OPS EOC Specialists;AK, OPS GC1 Facility OIL;AK, OPS GC1 Field O&M IL;AK, OPS GC1 OSM;AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad EKG;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;Oshiro,Joleen; 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;Tempel,Joshua;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer 01-34 (PTD# 2081250) Sustained Inner Annulus Casing Pressure Above NOL All, Producer 01-34(PTD#2081250)was reported to have sustained inner annulus casing pressure above NOL on 9/06/17 during freeze protection of the tubing. The pressures were confirmed to be tubing/inner/outer= 2200/2220/20psi. DHD performed a subsequent failing cold TIFL on 9/6/17 indicating a lack of two competent well barriers. 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:Change out gas lift valves. 2. DHD:TIFL 3. Slickline (pending):Set Tubing tail plug 4. Fullbore (pending):Assist SL, MIT-T,CMIT-TxIA 5. Production Engineer:Additional diagnostics as needed Please respond with any questions, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 SCANNED >FPI2 201 Cell 907-980-0552 Harmony 4530 1 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 01-34A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-125 50-029-21609-01-00 9472 Surface Intermediate Liner Liner 9227 2472 7952 5811 824 9014 13-3/8" 9-5/8" 7" 4-1/2" 8778 31 - 2501 27 - 7978 3023 - 8834 8646 - 9470 31 - 2501 27 - 7776 3023 - 8601 8417 - 9227 None 2670 4760 5410 7500 9014, 9060, 9115, 9143 5380 6870 7240 8430 8978 - 9320 4-1/2" 12.6# 13Cr80 25 - 8658 8743 - 9078 Conductor 80 20" 32 - 110 32 - 110 1490 470 4-1/2" Baker S3 Packer 8580, 8352 8580 8352 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 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 0028329 25 - 8427 N/A N/A 734 979 70874 69554 22 2 1810 598 1158 1054 N/A 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 By Grace Christianson at 1:30 pm, Nov 08, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.11.08 12:39:45 - 09'00' Bo York (1248) RBDMS JSB 111623 SFD 2/10/2025WCB 3-14-2024 DSR-11/15/23 ACTIVITY DATE SUMMARY 10/14/2023 ***WELL SHUT IN ON ARRIVAL*** PT PCE 250LP-3500HP LOAD TUBING WITH 150 BBLS OF DEAD CRUDE. SET 4.50" NS CIBP AT 9014', CCL STOP DEPTH=8976.2, ME SET DEPTH=37.8' PLUG HELD 500 PSI OVER TUBING PRESSURE FOR 5 MINS. PERFORATE FROM 8978' - 8998' MD WITH 2.75" GEO RAZOR GUN, 6 SPF, 60 DEG PHASED. TUBING PRESSURE DROPPED 400 PSI AFTER PERFORATING. ***WELL LEFT S/I, OPERATOR NOTIFIED*** 10/14/2023 T/I/O= 2300/1900/0 TFS Unit 2 Assist ELine Pumped 1 bbl 60/40 followed by 150 bbls crude to load Pumped 3 bbls Crude to pressure up on plug FWP's= 800/1550/0 Daily Report of Well Operations PBU 01-34A PERFORATE FROM 8978' - 8998' MD SET 4.50" NS CIBP AT 9014' 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 01-34A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-125 50-029-21609-01-00 9472 Conductor Surface Intermediate Liner Liner 9227 80 7952 5811 824 9060 20" 9-5/8" 7" 4-1/2" 8823 32 - 112 27 - 7979 3023 - 8834 8646 - 9470 32 - 112 27 - 7775 3023 - 8601 8417 - 9227 none 470 4760 5410 7500 9060 , 9115, 9143 1490 6870 7240 8430 9018 - 9320 4-1/2" 12.6# 13Cr80 25 - 8658 8782 - 9078 Structural 4-1/2" Baker S-3 , 8580 , 8352 8580 8352 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 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 0028329 25 - 8427 288 729 33713 72165 457 25 802 1633 871 1179 N/A 13b. Pools active after work:PRUDHOE OIL 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 Kayla Junke at 9:08 am, May 08, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.05.06 10:48:49 -08'00' RBDMS JSB 050923 WCB 1-4-2024 DSR-5/9/23 ACTIVITYDATE SUMMARY 4/8/2023 ***WELL SHUT IN ON ARRIVAL*** (DRIFT) MIRU E-LINE PT PCE 300PSI LOW, 3500PSI HIGH DRIFT 3.65" GAUGE RING TO TAG PLUG AT 9141' ELM SET NS 4.5" CIBP WITH ME AT 9115' CORRELATED TO SLB PERF RECORD 23MAY15 CCL-ME=11.5', CCL STOP AT 9103.5' ***JOB CONTINUES ON 09APR23 WSR*** 4/8/2023 T/I/O=2400/810/10 Assist E-Line w/Load & Test Pump 150 bbls crude to load tbg. Pump add'l 4.25 bbls to pressure up on plug to 1000 psi. FWHPs=400/800/5 4/9/2023 ***JOB CONTINUES FROM 08APR23 WSR*** (ADPERF) CORRELATE TO SLB PERFORATION RECORD DATED 23MAY15 PERFORATE 9068'-9100' 2.875" 6SPF 60PHASE HSC MAXFORCE CHARGES CCL-TS=8.3', CCL STOP 9059.7' RDMO E-LINE ***WELL SHUT IN ON DEPARTURE*** JOB COMPLETE 4/11/2023 T/I/O = 350/1800/50. Temp = 0°. IA FL (Ops request). IA FL @ 5240' (300' above sta # 4, SO). Well just brought online. SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:00 4/27/2023 TFS Unit 4, Assist E-line with load and test, Pumped 153 BBLS of Crude to load and test TBG FWHP=700/1350/0 E-Line in control of well upon departure 4/27/2023 ***WELL S/I ON ARRIVAL*** (NS CIBP AND ADD 24' OF PERF'S 2 7/8'' GEO RAZOR 6 spf 60 DEG PHASE) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH RUN#1 W/CH/ X2 1 11/16'' WB/2.75'' GAMMA RAY CCL/BAKER #10 SETTING TOOL/NS3.5'' CIBP TO SET NS 3.5''CIBP AT 9060' CCL TO MID ELEMENT 12.6 CCL STOP DEPTH 9047.4' THUNDER BIRD PUMP 150 BBLS TO LOAD THE WELL AT ~4 BPM MAX RATE TBG PRESSURE AFTER LOAD THE WELL 0 psi THUNDER BIRD TEST THE PLUG AT 700 psi RUN#2 W/CH/ X2 1 11/16'' WB/2.75'' GAMMA RAY CCL/24' OF 2 7/8'' GUN GEO RAZOR 6 spf 60 DEG PHASE, ADD PERF'S INTERVAL 9018' TO 9042' CCL TO TOP SHOT 9.3' CCL STOP DEPTH 9008.7' JOB COMPLETE AND TURN THE WELL OVER DSO TO POP ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU 01-34A Both CIBPs and both perf sets are shown correctly on the new WBS, below. -WCB SET NS 4.5" CIBP WITH ME AT 9115 PERFORATE 9068'-9100' CIBP TO SET NS 3.5''CIBP AT 9060' RUN#2 W/CH/ X2 1 11/16'' WB/2.75'' GAMMA RAY CCL/24' OF 2 7/8'' GUN GEO RAZOR 6 spf 60 DEG PHASE, ADD PERF'S INTERVAL 9018' TO 9042' STATE OF ALASKA ° ,E.C E I C E D ALASKA OIL AND GAS CONSERVATION COMM, iN REPORT OF SUNDRY WELL OPERATIONS ,JUN 2 2 21)Lr 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Oper : ted m Q 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ ,-7 Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 5.e. "" l6P E7 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5 Permit to Drill Number: 208-125 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21609-01-00 7. Property Designation(Lease Number): ADL 0028329 8. Well Name and Number: PBU 01-34A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 9472 feet Plugs measured 9143 feet true vertical 9227 feet Junk measured feet Effective Depth: measured 9143 feet Packer measured See Attachment feet true vertical 8905 feet Packer true vertical See Attachment feet Casing: Length: Size: MD. TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 32-112 32-112 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 7952 9-5/8"47#L-80 27-7979 27-7775 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9130-9140 feet 9150-9161 feet 9190-9200 feet 9265-9280 feet 9310-9320 feet 8912-8923 feet 8951-8961 feet 9025-9039 feet 9069-9078 feet True vertical depth: 8892-8902 feet 4-1/2"12.6#13Cr8 25-8658 25-8427 Tubing(size,grade,measured and true vertical depth) Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured) /'Np�t Treatment descriptions including volumes used and final pressure: SCANNED ,I1t �' i ,.- 2_ c.b: 13. Representative Daily Average Production or Infection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 170 560 6167 1822 241 Subsequent to operation: 560 3832 7643 1850 320 14.Attachments:(required per 20 AAC 25 070 25 071,a 25 283) 15.Well Class after work: Daily Report of Well Operations 1Z1 Exploratory ❑ Development lI Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16 Well Status after work' Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ,d/i,l. Phone +1 907 564 4424 Date 6//,,//L Form 10-404 Revised 5/2015 Vf- -q-i q it is- A JO. RBDMS` \ 9iluty- 1 2015 Packers and SSV's Attachment ADL0028329 SW Name Type MD TVD Depscription 01-34A PACKER 3033.72 3033.62 7" Baker ZXP Top Packer 01-34A PACKER 8580.94 8351.21 4-1/2" Baker S-3 Hydro Set Packer 01-34A PACKER 8658.02 8427.56 5" Baker ZXP Top Packer 01-34A PACKER 9184 8945.16 2-7/8" Baker KB Packer 01-34A PACKER 9210 8970.64 2-7/8" Baker KB Packer a) Q,OO000Omo CCr- ticoCO •- 0o0 0 o) v o 0 0 N v- O I, C) eaaaaaaLoa o) M LU I. co M r) LU NCD N I- N O I� O N CO N 0 I, ti CO N O) ct `- N I,- 00 0, O CO H V CO Lo N N a- .t Lo c+1 ti C) N O CO 0') N C Q� N Ch 0) LU N CO cN N I� 00 C) o) CO C.) N Q M CN7 17. M O CO N O N ch co CT) C 21 O � J Q 0 Q 000 aooaoo � J X 0 J J M ' �# *k C N 4t N� co # O CO V � Eo Et) oCNA _ _ OM ch N_ N tP N 4 t C)O cc) O C() CO CM JONUaO CO W � Q �O C U w w C) OLLLLXCLtXtZ Z W W W W W W m Q D D H Z Z Z D 0 fn (/) Z J J J H 0 ai / Cl) / z I oi \ a G 0 UJ cn 0\ k k 0o o0 I / o 0 0 k CL CD I- 0 2 Li_ 3 % - \ n \ $ , C § w CO w a csj ƒ 2 % 0 _ 2 R / / E &- 2 f z O 0 b < § E 41) 2 ° W a X 0 -3 -J 0 ? 0_ 2 ® � � QE / w ƒ Ce _ 2 0 2 f b - O Eo ; O \ 2 eco� � 6kke � \ to w < 0 E > C � O �a- O c 0 0 D �_ \ CI| a - t 0 ! < 0 K o_ 2 O Qeco 9 � � � � � � U- _ M. � f22 \ h b / � � q � E � 71 CL � 2D ƒ q ƒ bR / ƒ Eg2d ƒ LO —J E �CC7 / a6 / / / 2 � E2 ƒ 9 co I- ▪cti L F ƒ O e m i > w ± O L ± = o b / / # % LSO / @ ® IW -. UJW / uj •/ I � a6 • / z / -7 / 70k0f / k � / 2@UJW' WN - wa2ui -w , k / % � I ! 0CL< ERr, q � � Io / R R —J —Jm � 022wOo ¥ L O = U k � / / / ƒ / -JE � 5 \ C) z ƒ \ / \ � / � Cl) � � � 220 | 0 | | k q 0 / ƒ g b i : O O O O / $ | 0 L & Lo m m � d d d / a > / h CV CO q r a in « TREE= CNV _ _ ACTUATOR T DR FRAC 01 -34A INITIALSWELL NOT SHOWN TBG OW WHIPSTOCK"'9- ACTUATOR= BAKER C I'ITWL KB.ELE 70' 5/8"CRETACEOUS LEAK COVERED BY 7"SCAB LNR BF. ELEV= 44' I I IN 2008 SIDETRACK. KOP= 4900' 13-3/8"CSG, H 70' Max Angle= 25°@ 7978' 68#,K-55 BUTT, 2179' —14-112"FES X NP,ID=3.813' Datum M)= 9105 13=12.415" 11 Datum TVD= 8800'SS 20"CONDUCTOR 91.5#,1+40,D= 19.124" — —110 3023' H 9-518"X 7"C-2 ZXP LTP w/10'TRACK 13-3/8"CSG,72#,L-80 BUTT,ID=12.347' 2501' * SLV,D=6.276" A 14 3038' H9-5/8"X 7"BKR FLEXLOCK LNR HGR,13=6.18" Minimum ID = 2.31" @ 9220' 01 «4 GAS LFT MAHOS 01 0 ST M3 TVD DEV TYPE VLV LATCH PORT DATE 2-7/8" HES X NIPPLE (INSIDE PKR) X11 I.t •a 5 3500 3500 1 KBG2 DOME BK 12 04/11/09 X11 ,�11' 4 5538 5502 23 KBG2 DOME BK 16 04/11/09 1 9-5/8"CRETACEOUS LEAK H 5650' 111 111 3 6823 6691 21 KBG2 DOME BK 16 04/11/09 111 111 2 7688 7507 21 KBG2 DOME BK 20 04/11/09 111 1)i1 1 8471 8243 10 KBG2 SO BK 24 03/24/12 9-5/8"WMPSTOCK(12/07/08) H 7978'? - 111 'i 9-5/8'CSG,47#,L-80,D=8.681" H —7978 , ��1�, 4, 4'1 MLLOUT WNDOW(01-34A) 7978'-7992' i` S. 8549' —14-1/2"FES X NP,D=3.813" 8580' -I 7"X 4-1/2"BKR S-3 PKR ID=3.870" �i� -01 to- 8613' H4-1/2*HES X NP,D=3.813" 8644' _H4-1/2"HES XN NP,D=3.725' 8646' —7'X 5'C-2 ZXP LTP w/TEBACK 4-1/2"TBG,1Z6#,13CR.80 VAM TOP H 865Tik. �. SLV,I)=4.420" .0152 bpf,D=3.958' CAA. 865T —14-1/2"WLEG, D=3.958" 8663' —7"X 5'MMC HYD LNR HGR, D=4.420" 7"CSG,26#,L-80 BTC-M,D=6.276' H 8834' ` 8670' H5"X 4-1/2"XO,D=3.890" 9143' 14-1/2"WFD ISO BRIDGE j PLUG(05/23/15) PERFORATION SUMMARY 1 9184'-9222' 4-1/2"FLO-GUARD REE LOG: SPERR1' LWD ON 12/16/08 ANGLE AT TOP PERF: 11'@ 9130' lJ `� STRADDLE PATCH Nate:Refer to Ptoduction DB for historical pert data `, D=2.37"(04/21/14) SIZE SPF INTERVAL Opn/Sqz SHOT SOZ ` IR 2-7/8" 3 9130-9140 0 05/22/15 9220' —2-7/8 FES X NP, 2-7/8" 4 9150-9161 C 04/21/14 ID=2.31"(04/21/14) 3-3/8" 6 9190-9200 'C 02/15/10 , 3-318" 6 9265-9280 C 01/25/09 iii3-3/8" 6 9310-9320 C 01/25/09 PERFORATIONS BEI-W FLOGARD STRADDLE PATCH PBTD 9389' 11111 4-1/2'LNR, 12.6#,13CR-80 VAM TOP,.0152 bpf,D=3.958" —I 9470' DATE REV BY COMMENTS . DATE REV BY COMMENTS PRUDHOE BAY UNFF 07/11/86 AUDI INITIAL COMPLETION 10/14/14 CJWJM) PULI FT)XX PLUG(10/02114) WELL 01-34A I 01/14/87 PKR 141 RWO 05/29/15 DLW/JMD ADPERFS/SET ISO FLUG(05/22-23/15) PERMT No: 2081250 12/14/02 IV2ES RWO AR No 50-029-21609-01 12/19/08 N2ES SIDETRACK(01-34A) SEC 8,T10N,R15,1311'FM_&1566'FWL 04/22/14 MD/J11,43 ADPERFS/STRADDLE(04/21/14) ' 05/01/14 STF/JMD SET XX PLUG(04/25/14) BP Exploration(Alaska) BP Exploration Alaska Inc Well: 01-34 Field: Prudhoe Bay North Slope, Alaska, USA Report Production Array Log Analysis Prepared For : BP Exploration Alaska Inc Logging Date : 11/16/2013 Report Date : 12/02/2013 Submitted by: Waqar Khan Phone: +1(281)575-5051 10200 Bellaire Blvd, Houston, Texas-77072 Email: waqar.khan2@halliburton.com HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OF WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS OF RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF BP Exploration Alaska Production Array Log Analysis 1 TABLE OF CONTENTS 1.0 EXECUTIVE SUMMARY ............................................................................................................................. 2 2.0 BACKGROUND AND OBJECTIVES .......................................................................................................... 3 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT ............................................................ 4 4.0 PRODUCTION LOG PROCESSING ........................................................................................................... 7 4.1 FLOWING SURVEY ...................................................................................................................................... 9 BP Exploration Alaska Production Array Log Analysis 2 1.0 EXECUTIVE SUMMARY Production logging was done in Well 01-34 on November 16th, 2013 in flowing conditions with the objective of determining the production profile. As the well is deviated, Resistance Array Tool (RAT) and Spinner Array Tool (SAT) were included in the tool string to accurately estimate the holdup and phase velocities as there can be segregated flow of the three phases due to well deviation. The flowing PL analysis showed the oil production to be coming from all sets of perforations, with the bottom perforation (9310’-9320’) producing the most amount of oil. This set of perforation is contributing about 45% of the total oil flow. The top set of perforations (9190’- 9200’) is producing 61% of the total water production. For the analysis, SAT and RAT along with the gas holdup tool were used to separate out the three phases. The reported surface production while running the PL was 269 STB/D oil and 5365 BPD water with 1.7 MSCF/D. Based on the well test data during logging, the well is in a stable condition. The estimated flow rates at surface condition while flowing from each of the perforations is given in the table below: Perforations Oil Rate Gas Rate Water rate From , ft To , ft STB/D % Mscf/D % STB/D % 9190 9200 79.3 26.1 274 61.9 3437 60.9 9265 9280 89 29.2 66.4 15.0 949 16.8 9309.5 9320 136 44.7 102 23.1 1262 22.3 Total 304.3 442.4 5648 BP Exploration Alaska Production Array Log Analysis 3 2.0 BACKGROUND AND OBJECTIVES The objectives for running the PL were to identity the production profile and also determine the need of setting a plu g across the bottom perforation to try and reduce water production. BP Exploration Alaska Production Array Log Analysis 4 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT Well 01-34 is completed with 4.5 inch production tubing across which the production log was run. The wellbore schematic is presented in the Figure 1. The tool string diagram used for the PL logged is presented in Figure 2. The tool string consisted of the following production logging sensors: Gamma Ray - Casing Collar Locator – Pressure - Resistance Array Tool – Gas holdup – Caliper - Spinner Array Tool – Radioactive Density –Capacitance Water Holdup – Inline Spinner – Temperature – Caged Fullbore Spinner. The data quality is summarized below TOOL USAGE LOG DESCRIPTION LOG QUALITY REMARKS WELL BORE PARAMETERS QP Well bore pressure Good TEMP Well bore temperature Good FLUID TYPE FDR Radioactive density tool uses radioactive source and detector to measure density and is a center sample device Good CWH Uses capacitance to measure the differences between hydrocarbons and water Good RAT Resistivity Array Tool Good UP 160 pass shows an inconsistent response on the RAT tool, possibly due to bubble entrapment and has not been used in the interpretation GHT Gas HoldUp Tool Good FLUID VELOCITY CFB Caged Fullbore Spinner Good Shows good data 9300’ ft and above. ILS Inline Spinner Good SAT Spinner Array Tool Good . BP Exploration Alaska Production Array Log Analysis 5 . Figure 1: Wellbore Schematic BP Exploration Alaska Production Array Log Analysis 6 Figure 2: PL Toolstring BP Exploration Alaska Production Array Log Analysis 7 4.0 PRODUCTION LOG PROCESSING The production log data from the flowing were processed using the PLATO software. The software uses a global probabilistic method for the production log analysis. In this method, known as the Maximum Likelihood method, a well flow model is compared to all available data and improved, by optimization, until the best possible match with the data is obtained. By using this method the result is the most likely interpretation. A comparison between the model and the data is shown in this report and allows the analyst or the reader to determine validity of the answer obtained. Potential sources of discrepancies include tool measurement errors, conflicts between the parameters or conditions that make the underlying empirical models (such as flow regimes) less applicable.  The flow regimes were determined, directly from the flow rates and holdups, according to the Taitel- Dukler analytic model.  The profile factors, to calculate the true fluid velocity from the apparent velocity, were based on the Reynolds numbers.  Solution gas in oil was derived from the correlations (Vasquez-Beggs or Øistein- Glaso). The analysis was performed in six steps:  The data preparation to filter the data, compute gradients and error estimates.  The calibration of the array tools and full-bore flow meter.  The computation of the layered holdup and layered flow-rates.  The profile determination to identify the potential producing and/or injecting zones.  The computation of the flow rates by global optimization.  The computation of surface productions and reporting. BP Exploration Alaska Production Array Log Analysis 8 The water density and viscosity were calculated using a salinity of 20000 ppm. The Craft & Hawkins correlation was used. The oil density and viscosity were calculated using an oil gravity of 25.7 API. The Vasquez & Beggs correlation was used to calculate the solution gas. Viscosity was calculated using the Beggs & Robinson correlation. The Pc and Tc parameters were calculated using the Brown et al. correlation. The gas viscosity was calculated using the Lee Gonzales Eakin correlation. The following gas parameters were used: GasType Miscellaneous SPGG UNITY .750 GP-CO2 UNITY 0 GP-H2S UNITY 0 GP-Nitrogen UNITY 0 Utilizing the above fluid information, measured down hole oil density, temperature & pressure, the following fluid properties were calculated at well conditions: feet Twf Pwf Bwater water water Boil oil oil Rsb Bgas gas gas °F psi UNITY g/cc cP UNITY g/cc cP ft3/bbl UNITY g/cc cP 9025.00 198 2720 1.03 .987 .331 1.36 .754 .762 747 .00607 .151 .0194 9059.00 198 2734 1.03 .987 .331 1.36 .754 .762 747 .00604 .152 .0194 9092.50 198 2748 1.03 .987 .331 1.36 .754 .763 747 .00602 .152 .0195 9126.50 198 2762 1.03 .987 .331 1.36 .754 .763 747 .00599 .153 .0195 9160.00 198 2778 1.03 .987 .331 1.36 .754 .763 747 .00596 .154 .0196 9194.00 199 2792 1.03 .986 .329 1.36 .754 .760 746 .00595 .154 .0196 9227.50 200 2806 1.03 .986 .327 1.36 .754 .758 746 .00593 .155 .0197 9261.50 200 2822 1.03 .986 .327 1.36 .754 .759 746 .00590 .155 .0197 9295.00 200 2836 1.03 .986 .325 1.36 .754 .757 746 .00589 .156 .0198 9329.00 201 2850 1.03 .986 .325 1.36 .754 .757 746 .00587 .156 .0198 To estimate the flow rates, the caliper log recorded during the UP passes was used to estimate the nominal ID throughout the log. Tool information The following capacitance tool characteristics were used HydroWater Hz 28560 (Downhole Measurement) HydroHyd Hz 34533 (Surface Calibration) The following gas holdup tool characteristics were used GasHoldupWater Hz 29821 (Downhole Measurement) GasHoldupGas Hz 14805 (Surface Calibration) BP Exploration Alaska Production Array Log Analysis 9 4.1 FLOWING SURVEY The raw data from the flowing survey are presented in the Figures 3 to 8. Figure 3 has the data from conventional production logging sensors. Figure 4 has the same data that was presented in Figure 3 with the addition of the station measurements. To generate this plot, Emeraude software was used which allows overlay of the station measurements and the logging passes in the same track. Plato can only plot the st ation measurement against time. For the interpretation, since all the passes showed a consistent response, all of them have been used in the interpretation. The response from the Resistance Array Tool is presented in Figure 5. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values. Only the active sensors were used in the interpretation. Figure 6 shows only the active RAT sensors along with the station measurements. The response from the Spinner Array Tool is presented in Figure 7. All the spinners showed a good consistent response. From the raw data it is clear that all three perforations are producing fluids, with the top perforation producing the most fluid owing to the sharp deflection. From the spinner response, the velocity profile was estimated using the slopes calculated from the spinner calibration (Figures 9 and 10). Velocity is highest across the top perforation, indicating this zone as the main contributor. The calibrated RAT response is presented in Figure 11. The estimated SAT velocities and the RAT holdups are used to calculate the flow profile presented in the Figure 12. The final flow profile, after the global optimization, along with the comparison of the measured and theoretical tool values are presented in Figure 13. The production rates at surface conditions estimated from the production log analysis are presented in Figure 14 and are summarized in the table below: feet Profile Q-Water- STP Qp-Water- STP Q-Oil- STP Qp-Oil- STP Q-Gas- STP Qp-Gas- STP BFPD BFPD BFPD BFPD MCFD MCFD 9190.00 9200.00 Produce 5648 3437 304 79.3 442 274 9265.00 9280.00 Produce 2211 949 225 89.0 168 66.4 9309.50 9320.00 Produce 1262 1262 136 136 102 102 BP Exploration Alaska Production Array Log Analysis 10 Raw Data - The figure below summarizes the input data recorded at the well site. - Each pass is shown with a fixed predefined color. Figure 3: Input data from the conventional production logging sensors BP Exploration Alaska Production Array Log Analysis 11 Figure 4: Input data from the conventional production logging sensors along with the station measurements. BP Exploration Alaska Production Array Log Analysis 12 The figure below shows the RAT input data. The first track shows the RAT rotation curves for each pass. The next tracks show the RAT data: A curve for each pass for each of the 12 probes. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values and were not used in the interpretation. Figure 5: Input data from the Resistance Array Tool (RAT) BP Exploration Alaska Production Array Log Analysis 13 Figure 6: Input data from the Resistance Array Tool (RAT) showing just the active sensors along with station measurements BP Exploration Alaska Production Array Log Analysis 14 The figure below shows the SAT input data. The first track shows the SAT rotation curves for each pass. The next track shows the linespeed for each pass. The remaining tracks show the array spinner data: A curve for each pass for each of the 6 array spinners and for the fullbore (ASpinner07) and inline spinner (ASpinner08). The fullbore spinner does not appear to be turning well below 9275’. Figure 7: Input data from the Spinner Array Tool (SAT) and conventional spinners. BP Exploration Alaska Production Array Log Analysis 15 Figure 8: Input data from the Spinner Array Tool (SAT) and conventional spinners along with the station measurements. BP Exploration Alaska Production Array Log Analysis 16 Pre- Processing Figure 8a: Passes showing a consistent response have been used in for averaging out the measurements. BP Exploration Alaska Production Array Log Analysis 17 Calibration of Spinner Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and measured Array Tool responses. Track 2: Line-speed for each pass. Track 3: 'Unwrapped' rotation curve for each pass. Track 4: Normalized layered velocity profile. This profile is optimized by comparing the measured and theoretical SAT response for each pass of each spinner. Tracks 5-10: Measured and theoretical SAT responses for each spinner. Track 11: Measured and theoretical responses for the full-bore spinner. Track 12: Measured and theoretical responses for the inline spinner. Below are the results from the calibration of the SAT data. The determination of this calibration is a layered velocity profile. Figure 9: Velocity profile from SAT data. BP Exploration Alaska Production Array Log Analysis 18 The image below displays cross plots for each SAT spinner and the Inline spinner. The estimated slopes are used for converting the spinner response to flow velocities. Figure 10: Spinner cross plot BP Exploration Alaska Production Array Log Analysis 19 Calibration of Resistance Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and the measured RAT responses. Track 2: 'Unwrapped' rotation curve for each pass. Track 3: Normalized layered RAT profile. This profile is optimized by comparing the measured and theoretical RAT response for each pass for each probe. Tracks 4-15: Measured and theoretical RAT responses for each probe. Below are the results from the calibration of the RAT data. The determination of this calibration is a layered resistivity profile. To obtain this profile, calibrations for water/ hydrocarbon were entered for each probe. Figure 11: Calibrated RAT response. BP Exploration Alaska Production Array Log Analysis 20 Holdup and Velocity Profile: Shown on the image below from left to right: Track 3: Layered velocity profile. Track 4: Layered water holdup profile. Track 5: Layered oil holdup profile. Track 6: Layered gas holdup profile Track 7: Total holdup. Track 8: Cumulative flow rates Track 9: Density of fluid Track 10: Apparent Velocity from Fullbore Spinner Track 11: Apparent Velocity from Inline Spinner Figure 12: Holdup and velocity profile BP Exploration Alaska Production Array Log Analysis 21 Flow Profile The quantitative production rates were determined by comparing the well flow model with all available data. The figure below is provided to verify the agreement of the flow model with the data. In this figure the data is represented by the blue curves, while the calculated tool values are shown in red. The uncertainty interval is represented as a gray band around the data. The uncertainty interval corresponds to one standard deviation. The small fluctuations around the data are to be expected, since the tools have intrinsic errors. Large sustained discrepancies indicate problems with the data, conflicts between parameters or conditions that make the underlying empirical models less applicable. To the right of the figure the flow regimes are shown. Within the transition zones several regimes can exists intermittently. Figure 13: Flow profile at reservoir conditions BP Exploration Alaska Production Array Log Analysis 22 The production rates at surface conditions are presented in the figure below: Figure 14: Flow profile at surface conditions Ima a Pro~ct Well History File Cove~age g 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. O~ ~~- ~ ~ S Well History File Identifier Two-sided III II~IIIIIIII IIIII ^ Rescan Needed III IIIIIIIIII IIIIII Organizing (done) ^ RE AN DIGITAL DATA OVERSIZED (Scannable) C for Items: It I ~~ l ^ Diskettes, No. No/Type: ^ Other ^ Maps: ^ Other Items Scannable by ems: e Greysca , a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ 3 / CJ /s/ Pro "ect Proofin I g II I II II II I I III I I II I Maria ~Y: Date: /s/ ~ d t + ~ =TOTAL PAGES Scannin Pre aration 9 x 30 ~ = (Count does not include cover she BY: Maria Date: ~ I V ~ /s/ Production Scanning Stage 1 Page Count from Scanned File: - ~~ (Count does include co sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: 3 3 /~ /s/ ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s u i n n n i u u u ~i Scanning is complete at this point unless rescanning is required. ReScanned II I I I II II I I III I (II BY: Maria Date: /s/ Quality Checked III IIIIII III IIII III Comments about this file: 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA • Al :A OIL AND GAS CONSERVATION COMM. DN ' REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well Li Plug Perforations U Perforate U Other U Set Straddle Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: BP Exploration(Alaska),Inc Name: Development0 Exploratory ❑ ► 208-125-0 3.Address: P.O.Box 196612 StratigraphiC Service ❑ 6.API Number: Anchorage,AK 99519-6612 ` 50-029-21609-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028329 • * PBU 01-34A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: n. ,4 4. Total Depth measured t 9472 feet Plugs measured 9220 feet 2 1 - 9227.25 true vertical feet Junk measured None feet °7;`'( Effective Depth measured 9220 feet Packer measured See Attachment feet L,i ,' true vertical 8980.44 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 28-108 28-108 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 7968 9-5/8"47#L-80 24-7992 24-7787.23 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perfs Behind Straddle Perforation depth Measured depth 9150-9161 feet 9190-9200 feet 9265-9280 feet 9310-9320 feet True Vertical depth 8911.8-8922.6 feet 8951.04-8960.84 feet 9024.5-9039.18 feet 9068.54-9078.33 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 24-8657 24-8426.55 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): %MED JUN 1 12014 Treatment descriptions including volumes used and final pressure: SCA pen, MAY 2 U 1014 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 294 0 5461 1854 228 Subsequent to operation: 160 0 5738 1856 227 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run ExploratorL❑ Development❑✓ , Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil.. ❑ Gas ❑ WDSPLJJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUGJ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Garry.CatronaBP.Com Printed Name Garry Catron Title PDC PE Signature ida4.47 C Phone 564-4424 Date 5/21/2014 1,1,F 5/2 z //1- offt s/ /iy Form 10-404 Revised 10/2012 Submit Original Only a) U CO d L ;(14L C 4) ) O U 0 L L � O N a) (13 V• Q= Q N (6 Q I— M H m m a) Cn Y Y OX a� X aL) cL) N Y N Y - L cL Y - Y - co - N (d c) OO r N- ti V LO N N E V co +�+ O N — O Q M O O U7 O N M OoO0) O) G7 M O ao oO e O 0 13 < C L M CO CO GD M O LO O N CO CO CO O) O) V a W www W O. >+000UU 0_ a w w d d E < < < < < co •ct 0 0 0 0 0 Cu p 0 0 0 0) 0 0 0 Nrs. CO 0 0p IO N- 0 o •St CO rn (O L) LO ti N N. U ) o 0 0 0 o 0 0 i O) N- - M U) CO CO 7 V CO N V - 0) Ca r CO f� CO - M cr CO CO • CO O) V LC) N N O) CC) p N- In N CO CO (0 • O N CA 0 cN N- CO 0) M N CO j H A— Ln CO- O) CO CO ct N CO 'Cl" N N (\I t— N CO N O Ct O) CO CO CO • E co 6N) CO' ON- N CO CS) Cf) O CA CO C N CO C CO _. 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N46 Orn I N N ""cji U) ^N CD CO C N (2m �a2 '- p 't ao O () N O N + a s '6c - O u) W - O D 'zr0 Iwo' co v Z w d (� cel Y W v X J O 0 2 � _ a W Z 2 cc c X U O u_ m o o (n O u_ N N >W * W Q ? a .co (/) N N moi' TREE= CNV WaLHEND= FIC IN 1 -3 4A NI_ _IAL Tr ELL NOT SHOWN BELLOW WHIPSTOCK"•9- A'CTiIATOR= BAKER C NT AL KB.ELE 70' 5/8"CRETACEOUS LEAK COVERED BY 7"SCAB LNR BF,gFV= 44' 13-3/8"CSG, H 70' I IN 2008 SIDETRACK. KOP= 4900' 68#,K-55 BUTT, Max Angle= 25°@7978' D=12.415' Datum MD= 9105' 2179' —14-1/2"FES X NP,ID=3.813" Datum TVD= 8800'SS 20"CONDUCTOR 91.5#,14-40,D= 19.124" -F-110 3023' 195/8. X 7"C-2 ZXP LW w/10'TACK 13-3/8"CSG,72#,L-80 BUTT,D=12.347" 2501' 0 0 SLV,D=6.276" /II Il�j Minimum ID =2.31" @ 9184' -9222' 1 ' 3038' —19-5/8"X 7'BKR FLEXLOCK LNR HGR D=6.18" ,.. �� 4-1/ 2" STRADDLE w/HES X NIP 1111 I. GAS LFT MANORELs 11 11 sT MD ND DEV TYPE VLV LATCH FORT DATE 1111 ,14 5 3500 3500 1 KBG2 DOME BK 12 04/11/09 1111 ,1'44 5538 5502 23 KBG2 DOME BK 16 04/11/09 9-5/8"CRETACEOUS LEAK -1 5650' 14 /4 3 6823 6691 21 KBG2 DOME BK 16 04/11/09 1111 11. 2 7688 7507 21 KBG2 DOME BK 20 04/11/09 1111 11. 1 8471 8243 10 KBG2 SO BK 24 03/24/12 9-5/8"W- STOCK(12/07/08) —I 7978'? 1111 ‘ 9-5/8"CSG,47#,L-80,D=8.681' --1 —7978 / '141 1 MLLOUT WINDOW(01-34A) 7978'-7992' 8549' —14-1t2"HES X NP,I)=3.813" 8580' --17"X 4-1/2"BKR S-3 PKR,D=3.870" � i 0 , 8613' —14-1/2"HES X NP,13=3.813" Ilt 8644' —14-1/2'HES XN NP,ID=3.725" 8646' 7"X 5"C-2 ZXP LW w TIEBACK i\i, SLV,D=4.420' 865T —14-1/2"WLEG, D=3,958" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, 865Tit, ;G D 8663' 17"X 5'FMC HYD LNR HGR, .0152bpf,D=3.958" , =4.420" 7"CSG,26#,L-80 BTC-M,D=6.276" 8834' 8670' H 5"X 4-1/2"XO,D=3.890" 11 9184'-9222' —4-1/2"FLO-GUARD STRDL PERFORATION SUMMARY / REFLOG: SPERRY LWD ON 12/16/08 :; , w/HES X NP @ 9220', ANGLE AT TDP PERF: 11'@ 9150 �� D=2.31"(04/21/14) Note:Refer to Production DB for historical perf data 4,.. ; 9220' 12-7/8"XX PLUG SIZE SPF INTERVAL Opn/Sqz SHOT SQZ (04/25/14) 2-7/8" 4 9150-9161 0 04/21/14 3-3/8" 6 9190-9200 C 02/15/10 ` 3-3/8" 6 9265-9280 C 01/25/09 3-3/8" 6 9310-9320 C 01/25/09 FBTD —1 9389' 11�ft�4: 4-1/2"LNR, 12.6#,13CR-80 VAM TOP,.0152 bpf,D=3.958" H 9470' DATE REV BY COMMENTS DATE REV BY COMuENTS PRUDHOE BAY UNIT 07/11186 AUDI INITIAL COMPLETION 03/17/10 MV/SV ADFERF(02/15/10) WELL: 01-34A 01/14/87 PKR 141 RWO 04/22/14 MDVJMD ADFE2FS/STRADDLE(04/21/14) PERMIT No: 2081250 12/14/02 N2ES RWO 05/01/14 STF/JMD SET XX PLUG(04/25/14) API No: 50-029-21609-01 12/19/08 N2ES SIDETRACK(01-34A) SEC 8,T1ON,R15, 1311'FNL&1566'FVVL 02/03/09 JKLYSV FERFS(01/25/09) 04/12/09 CJN/SV GLV CJO(04/11/09) BP Exploration(Alaska) STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 01 Z d $ DiZ REPORT OF SUNDRY WELL OPERATIONS 0 2 1. Operations Abandon U Repair Well ❑ Plug Perforations ❑ Perforate U Other /\0C Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other Ei Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development (O Exploratory ❑ 208 -125 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: r Anchorage, AK 99519 -6612 50- 029 - 21609 -01 -00 7. Property Designation (Lease Number): ,_ 8. Well Name and Number: ADL0028329 _ PBU 01 -34A 9. Logs (List Togs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 9472 feet Plugs measured None feet true vertical 92P7.25 feet Junk measured None feet Effective Depth measured 9389 feet Packer measured See Attachment feet true vertical 9145.91 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H -40 28 - 108 28 - 108 1490 470 Surface 2442 13 -3/8" 72# L -80 57 - 2499 57 - 2498.94 4930 2670 Intermediate None None None None None None Production 7968 9 -50 47# L -80 24 - 7992 24 - 7787.23 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet r True Vertical depth feet P See Attachment ED AUG �y / Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 24 - 8657 24 - 8426.55 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9190' - 9200'; 9265' - 9280'; 9310' - 9320' Treatment descriptions including volumes used and final pressure: 44 bbls 12% HCL, 41 bbls 9:1 Mud Acid, Final Pressure = 2800 psig 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 588 11882 3364.5 1372.3 434.38 Subsequent to operation: 339 7241 2257.9 1225.4 280.52 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development III ' 4.. Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 111 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature �"( Phone 564 -4424 Date 8/7/2012 � DMS AUG o s 2ota VLF re e142/ ;� N' Form 10-404 Revised 10/2010 / / � / i Su bmi t Original Only oq Perforation Attachment ADL0028329 Meas Meas SW Operation Pert Operation Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base 01 -34A 2/15/10 APF 9190 9200 8951.04 8960.84 01 -34A 1/25/09 PER 9265 9280 8956.8 8971.48 01 -34A 1/25/09 PER 9310 9320 9000.84 9010.63 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET 01-1 HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Casing / Tubing Attachment ADL0028329 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H -40 28 - 108 28 - 108 1490 470 LINER 5811 7" 26# L -80 3023 - 8834 3022.91 - 8601.18 7240 5410 LINER 744 4 -1/2" 12.6# 13Cr80 8646 - 9390 8415.65 - 9146.89 8430 7500 LINER 80 4 -1/2" 12.6# L -80 9390 - 9470 9146.89 - 9225.29 8430 7500 PRODUCTION 7968 9 -5/8" 47# L -80 24 - 7992 24 - 7787.23 6870 4760 SURFACE 2442 13 -3/8" 72# L -80 57 - 2499 57 - 2498.94 4930 2670 TUBING 8633 4 -1/2" 12.6# 13Cr80 24 - 8657 24 - 8426.55 8430 7500 Packers and SSV's Attachment ADL0028329 SW Name Type MD TVD Depscription 01 -34A PACKER 3023 2955.21 7" Baker C -2 ZXP LT Packer 01 -34A PACKER 8580 8282.58 4 -1/2" Baker S -3 Production Packer 01 -34A PACKER 8646 8347.95 5" Baker C -2 ZXP LT Packer • • Daily Report of Well Operations ADL0028329 ..: , SUMMARY T/ •= 2500/1180 I reeze 'ro ec ■g : ow ine ( Slickline Work Pump bbls neat meth followed by 140 bbls crude down flowline. Pump 5 bbls neat meth followed by 38 bbls crude down tbg. FWHP's= 1800/1180/0 SV, WV =S /I SSV, MV =O IA, OA =OTG 3/18/2012 DSO notified ** *WSR CONT. FROM 3- 18 -12 ** *(under eval) ATTEMPT TO SET 4 1/2" WHIDDON, SD IN ST# 2 @ 7,671' SLM, SCALE RECOVERED IN C -SUB RAN 3.6 CENT AND 2 -1/2" S. BAILER, TAG OBSTRUCTION @ 8,541' SLM, NO SAMPLE RAN 3.805 G. RING AND 4 -1/2" BRUSH, UNABLE TO WORK PAST 8,014' SLM RAN 3.70 G. RING SD @ 8,015' SLM WORKED TOOLS DOWN TO 8,437' SLM RAN 3.625 G. RING SD @ 8,459' SLM WORKED TOOLS DOWN TO 8,537' SLM 3/19/2012 ** *WSR CONT. ON 3- 20 -12 * ** ** *WSR CONT. FROM 3- 19 -12 ** *(under eval.) RAN 3.70" G. RING, SD @ 8,442' SLM, WORK TO 8,504' SLM RAN 3.75" G. RING, SD @ 8,114' SLM, WORK TO 8,321' SLM RAN 3.62" BROACH, SD @ 8,540' SLM, WORK TO 8,569' SLM RAN 3.69" BROACH, SD @ 8,505' SLM, WORK TO 8,539' SLM 3/20/2012 ** *WSR CONT. ON 3- 21 -12 * ** ** *WSR CONT. FROM 3- 20 -12 ** *(under eval) RAN 3.79 BROACH, SD @ 8,013' SLM, WORK TO 8,035' SLM RAN 3.74 BROACH, SD @ 8,359' SLM, WORK TO 8,385' SLM RUNNING 3.724" BROACH @ 8538'SLM (WORKING BROACH) 3/21/2012 ***CONT ON 3 -22 -12 WSR * ** ***CON] FROM 3 -21 -12 WSR * ** (under eval /broach) RAN 3.724" BROACH TO 8538' SLM RAN 3.740" BROACH TO 8510' SLM RAN 3.769" BROACH TO 8421' SLM RAN 3.769" BROACH TO 8434' SLM SPANGS STUCK OPEN DUE TO SCALE 3/22/2012 ***CONT ON 3 -23 -12 WSR * ** * * *CONT FROM 3/22/12 WSR ** *(under eval) RAN 3.769" BROACH TO 8436' SLM, LOST SPANGS & OJ DUE TO SCALE LRS LOAD AND KILL WELL DURING DAY RAN 3.769" BROACH. SET DOWN @ 8436'SLM 3/23/2012 * * *CONT ON 3/24/12 WSR * ** T /I /0= 1920/1800/30 Load Well to secure/ Assist Slickline with scale flush (Slickline) Pumped 5 bbls meth spear followed by 30 bbls diesel and 290 bbls crude to load IA. Loaded tubing with 10 bbls meth spear followed by 40 bbls Diesel, 3 bbls meth, 225 bbls 1 %KCL and 3 bbls meth, 40 bbls diesel for freeze protect. Slickline has well 3/23/2012 control. FWHP's= 200/500/30. * ** CONT FROM 3 -23 -12 WSR * ** (gas lift - integrity) RAN 3.769" BROACH TO 8500'SLM. SET WHIDDON CATCHER SUB @ 8504'SLM PULLED 1" OGLV FROM STA #1 @ 8465'SLM SET 1" BK OGLV (24/64 ") IN STA #1 @ 8465'SLM UNABLE TO LATCH ONTO WHIDDON CATHCHER RAN 3.50" LIB TO 8501'SLM - NO PICTURE OF FISHING NECK - APPEARS TO BE SCALE. 3/24/2012 ***CONT ON 3 -25 -12 WSR * ** • Daily Report of Well Operations ADL0028329 * ** CONT FROM 3 -24 -12 WSR ** *(gas lift integrity) BAILED 1/2 GAL OF SCALE FROM 8502' SLM TO 8505' SLM. STAND BY FOR SCALE TO BE NORMED PT PCE 300/2500# (INTAKE VALVE & MANIFOLD ON TRI -PLEX FROZEN) 3/25/2012 * * *CONT ON 3 -26 -12 WSR*** T /I /O= 90/120/10. Temp= SI. WHPs (Eval high IAP). AL shut -in © casing valve, ALP= 1970 psi. Slickline unit staged in front of well house. 3/26/2012 SV,WV,ALC= closed. SSV,MV =open. IA,OA =open to gauge. NOVP. 12:15 hrs. * ** CONT FROM 3 -25 -12 WSR * ** (gas lift rate /bail) RAN 2.25" X 10' PUMP BAILER TO 8505'SLM, RECOVERED 2 CUPS - METAL MARKS ON BTM RAN 4" GR TO 8505'SLM. COULD NOT STAY LATCHED UP MADE MULTIPLE RUNS W/ 3" X 8' PUMP BAILER TO 8503'/8501', 8513'/8510', 8507' SLM (RECOVERED -1 GAL. OF SCALE) 3/26/2012 ** *CONT. ON 3/27/12 WSR * ** * * *CONT. FROM 3/26/12 WSR * * *( gaslift- integrity) RECOVERED 3/4 GAL. OF SCALE FROM PREVIOUS RUN RAN 3" X 8' P- BAILER TO 8505' SLM, RECOVERED 1/2 CUP SCALE RAN 4" GR TO 8505'SLM. UNABLE TO LATCH CATCHER. RAN 2.25 X 10' PUMP BAILER SET DOWN @ 8504'SLM, WORK DOWN TO 8506'SLM - REVCOVERED 1/3 GAL OF SCALE. 3/27/2012 * ** CONT ON 3 -28 -12 WSR * ** ***CONT FROM 3 -27 -12 WSH * ** (gas lift - integrity) FINISHED RUNNING 2.25" X 10' PUMP BAILER, SET DOWN @ 8505'SLM, WORKED DOWN TO 8506'SLM - RECOVERED 1/2 CUP OF SCALE. RAN 4" GR. SET DOWN @ 8505'SLM. GOT ONE FRICTION BITE, THEN LOST HOLE TO 8503'SLM. RAN 3" X 8' PUMP BAILER 4 TIMES, GOT TOTAL OF 1 1/4 GAL OF SCALE @ 8505'SLM. 3/28/2012 * ** CONT ON 3 -29 -12 WSR * ** ***CONT FROM 12 -28 -12 WSR * ** (gas lift - integrity) RAN 3" X 8' PUMP BAILER TO 8505'SLM - RECOVERED 1/2 CUP SCALE - HEAVY METAL MARKS ON BAILER BTM. RAN 2.25" X 10' PUMP BAILER 2 TIMES, RECOVERED 3/4 CUP WITH METAL MARKS ON BTM RAN 4" GR TO 8505'SLM. GOT FRICTION BITES, UNABLE TO FULLY LATCH G. FN. RAN 2.25" X 10' DRIVE DOWN BAILER W /MOD BALL BTM. SET DOWN @ 8509'SLM. WORKED DOWN TO 8510'SLM - RECOVERED 1 CUP FILL RUNNING IN HOLE W/3.25" CENT, 5' X 1 7/8 ",3.50 "CENT,XO,5' X 2.25" DRIVE DOWN BAILER W /BALL BTM (CURRENTLY IN HOLE) 3/29/2012 ***CONT ON 3 -30 -12 WSR * ** • Daily Report of Well Operations ADL0028329 ***CONT FROM 3 -29 -12 WSR * ** (gas lift - integrity) RAN 3.25" CENT, 5' X 1 7/8 ", 3.50" CENT,XO,2.25" X 5' DRIVE DOWN BAILER W /BALL BTM. TO 8510'SLM. RECOVERED 3 CUPS FILL. RAN 3.25" CENT, 5' X 1 7/8 ", 3.50" CENT,XO,2.25" X 5' DRIVE DOWN BAILER W /BALL BTM. TO 8510'SLM. RECOVERED 1/2 CUP OF FILL - ONE METAL MARK. RAN 4" GR TO 8508'SLM. GOT THREE FRICTION BITES AND PULLED OUT EACH TIME. LATCHED UP ON 4TH ATTEMPT - SHEARED GR, GR PACKED WITH SCALE RAN 3.25" CENT, 5' X 1 7/8 ", 3.50" CENT,XO,2.25" X 5' DRIVE DOWN BAILER W /BALL BTM. TO 8509'SLM. RECOVERED 1 CUP OF FILL RAN 3.25" CENT, 5' X 1 7/8", 3.50 CENT,XO, MODIFIED POCKET POKER W/2.80 BRUSH ON BTM TO 8509'SLM, BRUSHED G -FN. 3/30/2012 * ** CONT ON 3 -31 -12 WSR * ** * ** CONT FROM 3 -30 -12 WSR * ** (gas lift - integrity) RAN 3.25" CENT, 5' X 1 7/8 ", 3.50" CENT,XO,2.25" X 5' DRIVE DOWN BAILER W /BALL BTM. TO 8509'SLM. RECOVERED 3 CUPS OF SCALE. RAN 3.25" CENT, 5' X 1 7/8 ", 3.50" CENT,XO,2.25" X 5' DRIVE DOWN BAILER W /BALL BTM. TO 8509'SLM. RECOVERED 3 CUPS OF SCALE. RAN 3.25" CENT, 5' X 1 7/8 ", 3.50" CENT,XO,2.25" X 5' DRIVE DOWN BAILER W /BALL BTM. TO 8509'SLM. RECOVERED 3 CUPS OF SCALE. RAN 3.25" CENT, 5' X 1 7/8 ", 3.50" CENT,XO,2.25" X 5' DRIVE DOWN BAILER W /BALL BTM. TO 8509'SLM. RECOVERED 3 TO 4 CUPS OF SCALE. RAN 3.25" CENT, 5' X 1 7/8 ", 3.50" CENT,XO,2.25" X 5' DRIVE DOWN BAILER W /BALL BTM. TO 8509'SLM. RECOVERED 4 CUPS OF SCALE. 3/31/2012 * ** CONT ON 4 -1 -12 WSR * ** ***CONT FROM 3 -31 -12 WSR * ** (gas lift - integrity) RAN 3.25" CENT, 5' X 1 7/8 ", 3.50" CENT,XO,2.25" X 5' DRIVE DOWN BAILER W /BALL BTM. TO 8508'SLM. RECOVERED 4 CUPS OF SCALE. RAN 3.25" CENT, 5' X 1 7/8 ", 3.50" CENT,XO,2.25" X 5' DRIVE DOWN BAILER W /BALL BTM. TO 8507'SLM. RECOVERED 5 CUPS OF SCALE. RAN 3.25" CENT, 5' X 1 7/8 ", 3.50" CENT,XO,2.25" X 5' DRIVE DOWN BAILER W /BALL BTM. TO 8506'SLM. RECOVERED 5 CUPS OF SCALE. RAN 3" X 8' PUMP BAILER. SET DOWN © 8500'SLM WORKED DOWN TO 8503'SLM. RECOVERED 1/2 GAL OF SCALE. RAN 3" X 8' PUMP BAILER. SET DOWN @ 8503'SLM. RECOVERED 1 CUP SCALE START RUNNING IN HOLE W/4 1/2" X -LOCK (W /SECONDARY LOCK DOWN) AND FLOW THRU SUB. 4/1/2012 * ** CONT ON 4 -2 -12 WSR * ** T /I /0= 500/1860/30 Temp =SI Assist Slickline Load tbg (Eval TxIA Comm) Freeze protect Flowline with 5 bbls meth spear, 79 bbls crude sweep * ** wsr continued to 04- 4/2/2012 03 -12 * ** • Daily Report of Well Operations ADL0028329 * ** CONTI -ROM 4 -1 -12 WSR **"(gas lift - integrity) SET 4 1/2" X -LOCK (W /SECONDARY LOCK DOWN) W /FLOW THRU SUB @ 2159'SLM HAVE DSO FLOW WELL. LRS FREEZE PROTECT FLOW LINE. * ** CONT ON 4 -3 -12 WSR * ** * ** NOTE: 4 1/2" WHIDDON W /4" G.FN (3.77" BTM OD) SET @ 8505'SLM - STUCK 4/2/2012 IN SCALE * ** ***CONT FROM 4 -2 -12 WSR * ** RAN 3.850" GAUGE RING TO TOP OF LOCK IN SVN @ 2161'SLM. PULLED 4 1/2" LOCK W /FLOW THRU SUB @ 2161'SLM - METAL MARKS OF G -FN ON BTM OF FLOW THRU SUB. RAN 3.25" LIB TO TOP OF WHIDDON @ 7548'SLM - PICTURE OF CLEAN G -FN. RAN 4" GR - TAGGED WHIDDON @ 7548 "SLM & CHASED DOWN TO 7670'SLM - SHEARED GR - GR PACKED WITH PARAFIN OR DRIED OUT DEAD CRUDE RAN 3.25" CENT, 5' X 1 7/8 ",3.50" CENT & 5' X 2.25" DRIVE DOWN BAILER W /BALL BTM TO 7669'SLM PUSHED WHIDDON TO 7676'SLM - RECOVERED 2 CUPS SCALE. RAN 3.25" CENT, 5' X 1 7/8 ",3.50" CENT & 5' X 2.25" DRIVE DOWN BAILER W /BALL BTM TO 7673SLM - RECOVERED 2.5 CUPS SCALE. RAN 3.25" CENT, 5' X 1 7/8 ",3.50" CENT & 5' X 2.25" DRIVE DOWN BAILER W /BALL BTM TO 7673SLM CURRENTLY IN HOLE. 4/3/2012 * ** CONT ON 4 -4 -12 WSR * ** * ** wsr continued from 04- 02 -12 * ** T /I /0= 500/1860730 Temp =Sl Assist Slickline Load tbg (Eval TxIA Comm) Pumped remaining 52 bbls crude down FL had DSO shut in IGV pumped 6.5 bbls meth to pressure up. Pumped 10 bbls meth down tbg followed by 30 bbls diesel to verify if tbg was pluged off. SSL to run gauge ring. pressured tbg up with 10 bbls diesel. SSL to RIH. pumped a total of 69 bbls diesel down TBG. FWHP's= 2100/1900/30 Upon departure DSO notified SLB still on well & in 4/3/2012 control of all VLVS ***CONT FROM 4 -3 -12 WSR * ** (gas lift integrity) RAN 3.25" CENT, 5' X 1 7/8 ",3.50" CENT & 5' X 2.25" DRIVE DOWN BAILER W /BALL BTM TO 7673'SLM - RECOVERED 1/4 CUP SCALE. RAN 3.25" CENT, 5' X 1 7/8 ",3.50" CENT & MODIFIED POCKET POKER W/2.80" BRUSH BTM. BRUSHED G.FN @ 7673'SLM. RAN 4" GR TO 7673' SLM - UNABLE TO LATCH RAN 3.25" CENT, 5' X 1 7/8 ",3.50" CENT & 5' X 2.25" DRIVE DOWN BAILER W/ FLAPPER BTM TO 7673'SLM - EMPTY RAN 4" GR W /BULL NOSE, UNABLE TO LATCH WHIDDON SET 4 1/2" X -LOCK W/ FLOW THROUGH SUB IN SSSVN @ 2,161' SLM/ 2,179' MD RAN CHECK SET- SHEARED 4/4/2012 ** *WSR CONT. ON 4- 5 -12 * ** ** *WSR CONT. FROM 44-12 * ** RD SWCP 4517 4/5/2012 ** *WELL LEFT S/I ON DEPARTURE ** *DSO NOTIFIED • • Daily Report of Well Operations ADL0028329 ***WELL FLOWING UPON ARRIVAL * ** (gas lift entegrity) RAN 4 1/2" GS AND PULLED X -LOCK W /FLOW THRU SUB FROM SVN @ 2161'SLM. CURRENTLY RUNNING 4" GR IN HOLE. 4/26/2012 * ** CONT ON 4 -27 -12 WSR * ** ***CONT FROM 4 -26 -12 WSR * ** (gas lift - integnty /caliper) RAN 4" GR & PULLED WHIDDON @ 8507'SLM. DRIFTED W/2.90" & SAMPLE BAILER TO 9310'SLM (9328'MD, 8' RAT HOLE) BAILER EMPTY - HARD BTM. RUNNING 40 ARM CALIPER (IN PROGRESS) 4/27/2012 * ** CONT ON 4 -28 -12 WSR * ** ***CONT FROM 4 -27 -12 WSR * ** (gas lift - integrity /caliper) LOG FROM TD (9310'SLM) TO SURFACE W /40 ARM CALIPER - GOOD DATA. RIG DOWN 4/28/2012 * ** TURN WELL OVER TO PAD OP, READY TO POP * ** ASRC Unit 1. DS 01 -34A Acid FB with CTU. Arrive on location, Spot Unit, RU. Inlet 6/13/2012 DS1 -34, Outlet DS1 -31. * *Job in Progress Continue on WSR 06/14/12 ** ASRC Unit 1. DS 01 -34A Acid FB with CTU. * *Continue from WSR 6- 13 -12 ** R/U 6/14/2012 complete SB for CTU. Inlet DS1 -34, Outlet DS1 -31. * *Continued on WSR 6- 15 -12 ** CTU #9 1.75" Coil Tubing - Job Scope = Mill Scale, Acid Treatment « <Job continued from 6/14/2012 »> Pop well through ASRC test separator and RIH w/ BOT 3.71" Turbo scale mill and milling assembly. « <Job in Progress »> 6/15/2012 ASRC Unit 1. DS 01 -34A Acid FB with CTU * *Continue from WSR 6- 14 -12 ** Pop Well © 0:30, gas release at block valve on inlet pump tee, ESD equipment, upon inpsection it was determined that it was due to hardline gasket failure. Take valve to valve shop for precautionary inspection. Inlet DS1 -34, Outlet DS1 -31. * *Job in progress continued on 6/15/2012 WSR 6- 16 -12 ** ?/I/0= 1800/1802/7, Temp =S7I, Assist CTU Load IA (CTU) Pumped into IA 3 bbl meth spear followed by 204 bbls 70* crude. Shut down do to gas leak on Well testers block 6/15/2012 valve. * ** wsr continued to 06- 16 -12 * ** CTU #9 1.75" Coil Tubing - Job Scope = Mill Scale, Acid Treatment « <Job continued from 6/14/2012 »> Pop well through ASRC test separator and RIH w/ BOT 3.71" Turbo scale mill and milling assembly. Tagged at 8800ctmd w/ 4klbs. Soft scale. Start milling. GL online. Milled to 9380ctmd. Tagged bottom. Pumped final 10bbls of gel sweep & chased it out to 1st GL vlv. POOH. Left well flowing for 30min to clean up solids. Shut well in. MU acid wash BHA w/ 2.5" JSN. LRS started loading IA w/ crude. 3" plug valve on ASRC inlet line leaked gas when bleeding off WHP. Secured the well. Bled off line pressure. Shut down equipment on the pad to prevent ignition sources. Gas leak stopped. Stand by for ASRC to inspect the valve in API shop. « <Job Continued on 6/16/2012 »> 6/15/2012 CTU #9 1.75" Coiled tubing unit - Job scope = Mill Scale, Acid treatment RIH w/ 2.5 JSN. Load the IA w/ 260 bbls of dead crude at 1.9 bbl /min. Pump 150 bbls of NH4CL w/ F103. 6/16/2012 « <Job in Progress »> • • Daily Report of Well Operations ADL0028329 ASRC Unit 1. DS 01 -34 Acid FB with CTU. **Continue from WSR 6- 15 -12 ** Inlet DS1 -34 Outlet DS1 -31 CTU finished pumping acid and RDMO. POP'd well to production, diverted fluid to tanks when presence of acid in fluid samples. * *Job in 6/16/2012 Progress Continued on WSR 6- 17 -12 ** CTU #9 1.75" Coiled tubing unit - Job scope = Mill Scale, Acid treatment « <Job continued from 06/15/12 »> RIH w/ 2.5 JSN. Load the IA w/ 260 bbls of dead crude at 1.9 bbl /min. Pump 150 bbls of NH4CL w/ F103. Pumped 105bbls of diesel down backside Pumped 62 bbls of Ntt14G1 across per's. Performed pre -acid inj test. 0.5bpm- 424psi, l bpm- 516psi, 1.5bpm- 640psi, 2bpm- 760psi, 2.5bpm -863. Pumped 44bbls of 12% HCI, 44bbls of HF acid @1.8bpm reciprocating across pe's. Follow up w/ 50bbls of NH4CL. Perform post -acid inj test. 0.5bpm- 405psi, 1 bpm- 400psi, 1.5bpm- 485psi, 2bpm- 563psi, 2.5bpm- 648psi. 6/16/2012 POOH. At surface. RDMO. « <Job Complete »> ** *WSR continued from 06- 15 -12 * ** T /I /0= 1800/1802/7, Temp =S /I, Assist CTU Load IA (CTU) Reloaded IA with 260 bbls crude. Pumped 204 bbls on 06 -15 -12 shut down before load was complete due to gas leak on ASRC block valve. CTU has control of 6/16/2012 well. DSO notified of departure. FWHP's= 510/240/0 ASRC Unit 1. DS 01 -34 Acid FB with CTU. * *Continue from WSR 6- 16 -12 ** Inlet DS1- 34 Outlet DS1 -31. Continue Flowback/Cleanup, Diverted back to production at 11:00, start opening inlet choke, Begin 6 hour test @ 21:00. * *Job in Progress Continued on 6/17/2012 WSR 6- 18 -12 ** ASRC Unit 1. DS 01 -34A Acid I-B with CTU. * *Continue from WSR 6- 17 -12 ** Inlet DS1- 34 Outlet DS1 -31. Test well, Finish 6 hour well test, Corrected formation fluid rate 4902 STBFPD, Corrected formation water cut 85.38 %, R /D,Vessel cleanout at Peak. * *Job 6/18/2012 Complete ** T /I /O = 450/1750/400. Temp = 118 *. TIFL PASSED (PRE SIT). AL online. ALP = 1750 psi. SI well to stack out TBG.with AL to 1960 psi. IA FL @ 8471' (sta# 1, SO). Bled IA to production from 1750 psi to 750 psi in 1 hr. IA FL unchanged. Monitor 1 hr, IA FL unchanged. Final WHPs = 2230/750/170. Well back to production (per WIE). 6/21/2012 SV = C. WV, SSV, MV = 0. IA,OA = OTG. NOVP. 1300 T /1 /0= 2500/1405/204 ( Scale Inhibitor Treatment) Rig to TBG. Pump 2 bbls 60/40 meth followed by 87 bbls of 1% TWKCL then 363 bbls Scale Inhibitor from upright tank followed by 93 bbls 1% TWKCL. Pump 30 bbls dead crude down TBG for freeze protect. RDMO. FWHP= 135/1374/163 wing =shut / swab =shut / ssv =open / 6/26/2012 master =open / IA and OA open to gauges. Operator notified. • TREE = CNv WELLHEAD= FMC • SAFE OTES:" * *CHROMETBG LNR& NIPS * ** ACTUATOR = BAKER C O 1 -34A ** *INITIAL WELL NOT SHOWN BELOW KB. ELEV = 70' WHIPSTOCK * * *9 -5/8" CRETACEOUS LEAK COVERED BF. ELEV = 44' I I BY 7" SCAB LNR IN 2008 SIDETRACK KOP = 4900' I Max Angle = 25° @ 7978' Datum NO = 9105' I 2179' H4-1/2" FES X NIP, ID = 1813" I Datum TVD= 8800'SS 7 113 -3/8" CSG, 68#, K -55, ID = 12347' H 30' i 3023' 119 -5/8" X 7" C-2 ZXP LTPw /TIEBACK SLV, ID = 6.276" 113 -3/8" CSG, 72#, L -80, ID = 12.347" H 2501' I► f1 r 3038' H9 -5/8" X 7' BKR FLEXLOCK LNR HGR ID = 6.18" I Minimum ID = 3.725" @ 8644' # ► # # GAS LIFT MANDRELS 4 -1/2" HES XN NIPPLE A •jvj ST NO TVD DEV TYPE VLV LATCH FORT DATE ,,4 NI 0 5 3500 3500 1 KBG2 DONE BK 12 04/11/09 # # 1 6 4 # 4 4 5538 5502 23 KBG2 DONE BK 16 04/11/09 I9 -5/8" CRETACEOUS LEAK H 5650' I # # 4 ►##4 3 6823 6691 21 KBG2 DONE BK 16 04/11/09 •# ► # # 2 7688 7507 21 KBG2 DOME BK 20 04/11/09 ##4 � ## 1 8471 8243 10 KBG2 SO BK 24 0324/12 19 -5/8" WHIPSTOCK (12/07/08) H 8003' I # # 4 , # ‘# 4 •4 MIL LOUT WINDOW (01 -34A) 7978' - 7997 I giit 19-5/8" CSG, 47 #, L -80, ID = 8.681" H 9554' i 8549' IH 412" HES X MP, ID = 3.813" I 8580' —17' X 4 -1 /2" BKR S -3 PKR, ID = 3.870" I PERFORATION SUMMARY t REF LOG: SPERRY LWD ON 12/16/08 'i , ANGLE AT TOP PERF: 11' @ 9190' 8613' H4-1/2" F1ES X NIP, ID = 3.813 Note. Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 8644' I-- 4-1/2" HES XN NIP, ID = 3.725" 3 -3/8" 6 9190 - 9200 0 02/15/10 3 -3/8" 6 9265 - 9280 0 01/25/09 8646' I -17' X 5" C-2 ZXP LTPw/TIEBACK 3 -3/8" 6 9310 - 9320 0 01/25/09 SLV, ID = 4.420" 8657' H4-1/7 WLEG, ID = 3.958" I 8663' 7' X5 "HMCHYD LNR HGR, 412" TBG, 12.6#, 13GR -80 VAM TOP, —1 8657' 411111. ID = 4.420" _0152 bpf, ID = 3.958" 8670' H5" X 4-1/7' XO, ID = 3.890 I 17" CSG, 26#, L -80 BTC-M, ID = 6.276" —1 8834' ` li I PBTD — 1 9389' I vid 14 4 t 6 I4 -1 /2 LNR, 12.6#, 13CR -80 VAM TOP, .0152 bpf, ID = 3.958" H 9470' I DATE REV BY COMMENTS DATE REV BY CONIVIENTS PRUDHOE BAY UNIT 07/11/86 ORIGINAL COMPLETION 03/17 /10 W/SV ADPERF (02/15/10) WELL: 01 -34A 01/14/87 WORKOVER 05/21 /10 JMIJNO DRLG DRAFT CORRECTIONS PERT No: 1 2081250 12/14/02 DACIKK RIG WORKOVER 04/20/12 PJC GLV GO (03/24/12) JET C -SUB AR No: 50 -029- 21609 -01 -00 12/19108 N2ES SIDETRACK (01 -34A) 05/21/12 SET /JMD C-SUB PULLED (04/27/12) SEC 8, T1ON, R15, 1311' FNL & 1566' FWL 02/03/09 JKDYSV PERFS (01/25/09) 04/12/09 CJN/SV GLV C/O (04/11/09) BP Exploration (Alaska) • • PO O —344. Prb Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator @bp.com] ? / Sent: Friday, July 27, 2012 1:51 PM 1 To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS1 DS; Youngmun, Alex; Dos Santos, Higino W Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J Subject: NOT OPERABLE: Producers with Sustained Casing Pressure During TAR All, The following producers were found to have sustained casing pressure on the IA during shut down for turnaround activity. The immediate action is to perform a TIFL on each of the wells to evaluate for IA repressurization. If the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well with a plan forward. 01 -34A (PTD # 2081250) 12 -28A (PTD # 1990330) All the wells listed above are reclassified as Not Operable until start -up operations commence and are stable or the well passes a pressure test confirming integrity. After start -up, the wells will be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents if integrity has not been confirmed. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) SCANNED MAY 0 2 2013 Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 .•.. _._ _ r , , Email: AKDCWeIllntegrityCoordinator (a�BP.com 1 06/23/2011 20g ° 12.$ 21DC 9 Schhnberger No. 5755 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 01 -34A BBSK -00069 PPROF W/ DEFT 29- May -11 1 1 09-08 BGH4 -00054 INJECTION PROFILE 25- May -11 1 1 01 -20 BINC -00032 SCMT 25- May -11 1 1 U -12A BD88 -00110 MEMORY PPROF W /DEFT 30- May -11 1 1 A -08 BBSK -00070 INJECTION PROFILE 1- Jun -11 1 1 L -122 BLPO -00103 MEMORY LEAK DETECT LOG 8-Jun-11 1 1 MPF -80 BJGT -00040 USIT 10-Jun-11 1 1 H -27A BD88 -00117 PPROF WIDEFT AND GHOST 10-Jun-11 1 1 • 3- 291J -32 BP5G -00015 CROSSFLOW 27- Apr -11 1 1 W -207 BG4H -00050 INJECTION PROFILE W/ WFL 16- May -11 1 1 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services • Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 RECEIVED fib ED AU G 2 5 C Ole JUN 2 7 2011 4x Ma, c s • • P6c( of -34A Regg, James B (DOA) (250 From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator @bp.com] Sent: Sunday, April 08, 2012 7:20 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; G GPB FS1 DS; Youngmun, Alex; AK, OPS FS1 DS1 Operator Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); LeBaron, Michael J 4 tz, Subject: OPERABLE: Producer 01 -34A (PTD #2081250) Tubing Integrity Restored All, Producer 01 -34A (PTD #2081250) passed a TIFL on 04/07/2012 after changing out the screened orifice valve. The well has been reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator -:s APR . z ; re Office (907) 659 -5102 Cell (907) 752 -0755 From: AK, D &C Well Integrity Coordinator Sent: Monday, February 27, 2012 3:53 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ry•n; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; G GPB FS1 DS; Youngmun, Alex; AK, OPS FS1 DS1 Operator Cc: Wills, Shane M; King, Whitney Olson, Andrew; Arend, Jon (NORTHERN SOLU . S LLC); Reynolds, Charles (Alaska) Subject: UNDER EVALUATION: Producer 01 -34A (PTD #2081250) Sustained =sing Pressure on IA Above MOASP All, Producer 01 -34A (PTD #2081250) was found to h- «e sustained casing pressure on the IA above MOASP. The tubing /IA/OA = 1770/2350/30 on 02/24/2012. • IFL was performed and the IA fluid level inflowed 7667' during the bleed. The well is reclassified Under Evalua '•n while further diagnostics are conducted. The plan forward: 1. Slickline: Change out Orifice Gas ift Valve 2. Downhole Diagnostics: TIFL A TIO Plot and wellbore sc -matic are attached for reference: Thank you, Mehreen Vazir r /111<:rrxr1, Gerald .tturph ; Well Integrity Coordinator BP Alaska Drilling & Wells 1 II i - - 31-A Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, February 27, 2012 3:53 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; G GPB FS1 DS; Youngmun, Alex; AK, OPS FS1 DS1 Operator Cc: Wills, Shane M; King, Whitney; Olson, Andrew; Arend, Jon (NORTHERN SOLUTIONS LLC); Reynolds, Charles (Alaska) Subject: UNDER EVALUATION: Producer 01 -34A (PTD #2081250) Sustained Casing Pressure on IA Above MOASP Attachments: 01 -34 TIO 02- 27- 12.doc; 01- 34A.pdf All, ✓ r Producer 01 -34A (PTD #2081250) was found to have sustained casing pressure on the IA above MOASP. The tubing /IA/OA = 1770/2350/30 on 02/24/2012. A TIFL was performed and the IA fluid inflowed 7667' during the bleed. The well is recrassified Under Evaluation while further diagnostics are conducted. The plan forward: 1. Slickline: Change out Orifice Gas Lift Valve 2. Downhole Diagnostics: TIFL SCP A TIO Plot and wellbore schematic are attached for reference: bt ?O fs, «01 -34 TIO 02- 27- 12.doc» «01- 34A.pdf» Thank you, rt(; ■c`e Mehreen Vazir (41t<<rraraiu• Gerald l tturph ) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 • Email: AKDCWeIIIntegrityCoordinator @BP.com '' FEB O12 1 PBU 01 -31A PTD # 2081250 2/27/2012 TIO Pressures Plot Well: 01 -34 4,000 3,000 - — Tbg —IF- IA 2,000 - +- OA OOA ODOA On 1,000 - • 12/03/11 12110/11 12/17/11 12/24/11 12/31/11 01/07/12 01/14/12 01/21/12 01/28/12 02/04/12 02/11/12 02/18/12 02/25112 1 TREE = CM/ WELLHEAD = FMC SAFETY NOTES:***CHROME TBG, LNR & NIPS * ** ACTUATOR = BAKER C 01 -34A WHIP T CK 9 CRETACEOUS LEAK COVERED KB. ELEV = 70' BF. ELEV = 44' BY 7" SCAB LNR IN 2008 SIDETRACK. KOP = 4900' i Max Angle = 25° @ 7978' Datum MD = 9105' Li I 2179' I-14 -112" HES X NIP, ID = 3.813" Datum ND = 8800' SS 113 - 3/8" CSG, 68 #, K -55, ID = 12.347" H 30' 1 3023' I— 9 -5/8" X 7" C-2 ZXP LTP w /TIEBACK SLV, ID= 6.276" 113 - 3/8" CSG, 72 #, L -80, ID = 12.347" H 2501' ! 0 Vi ;114 A 3038' H9-5/8" X 7" BKR FLEXLOCK LNR HGR, ID = 6.18" Minimum ID = 3.725" @ 8644' .1. GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 -1/2" HES XN NIPPLE , � 4 MI 5 3500 3500 1 KBG2 DOME 12 04/11/09 4 II 4 5538 5502 23 KBG2 DOME BK 16 04/11/09 I9 -5/8" CRETACEOUS LEAK I—I 5650' I 4 t 4 3 6823 6691 21 KBG2 DOME BK 16 04/11/09 �♦ 4 2 7688 7507 21 KBG2 DOME BK 20 04/11/09 � , • ' 1 8471 8243 10 KBG2 SO BK 28 04/11/09 9 -5/8" WHIPSTOCK (12/07/08) H $003' ( lt,' 4 i ,, MILLOUT WINDOW (01 -34A) 7978' - 7992' 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H l 9554' 1---Al 8549' (– I4 -1/2" HES X NIP, ID = 3.813" I M.T(P -...,,(09 70 s P 8580' H7" X 4-1/2" BKR S -3 PKR, ID = 3.870" I %IA PERFORATION SUMMARY 4- , 8613' H4 -1/2" HES X NIP, ID = 3.813" 1 REF LOG: SPERRY LWD ON 12/16/08 ANGLE AT TOP PERF: 11° @ 9190' 8644' H4 -1/2" HES XN NIP, ID = 3.725" 1 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3-3/8" 6 9190 - 9200 0 02/15/10 8646' I 1 SLV, 7" X 5" C-2 ZXP LTP w /TIEBACK 3 -3/8" 6 9265 - 9280 O 01 /25!09 ID = 4.420" 3 -3/8" 6 9310 - 9320 0 01/25/09 8657 H4 -112" WLEG, ID = 3.958., 0" .958" 1 8663' 1—{ 7" X 5" HMC HYD LNR HGR, 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, --1 8657' L ID = 4.420" .0152 bpf, ID = 3.958" 8670' I—I 5" X 4 -1/2" XO, ID = 3.890" I 17" CSG, 26 #, L -80 BTC-M, ID = 6.276" H 8834' il■ ii I PBTDI 9389' I teit.• 4 -1/2" LNR, 12.6 #, 13CR -80 VAM TOP, .0152 bpf, ID = 3.958" H I 9470' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/11/86 ORIGINAL COMPLETION 03/17/10 MV /SV ADPERF (02/15/10) WELL: 01 -34A 01/14/87 WORKOVER 05/21/10 JM /JMD DRLG DRAFT CORRECTIONS PERMIT No: '2081250 12/14/02 DAC /KK RIG WORKOVER API No: 50- 029 - 21609 -01 -00 12/19/08 N2ES SIDETRACK (01 -34A) SEC 8, T1ON, R15, 1311' FNL & 1566' FWL 02/03/09 JKD /SV PERFS (01/25/09) 04/12/09 CJN /SV GLV C/O (04/11/09) i BP Exploration (Alaska) • z oo - 1 25 O I 'i53 WELL LOG TRANSMITTAL CE To: Alaska Oil and Gas Conservation Comm. October 12, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 01 -34A Run Date: 10/2/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 01 -34A Data in LAS format, Digital Log Image files 1 CD Rom 50- 029 - 21609 -01 Cement Bond Log 1 Color Log 50- 029 - 21609 -01 lifX) MAY 1 b 4011. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 kfinton.wood@halliburton.com Date: 1211 IN Signed: _ _ . 29 -SEP -2011 2o1•t25 Sc bed Z obi No. 5349 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 02 -03B BINC -00036 LDWG EDIT OF RST 1-Jun-11 1 — 1 01-34A BBSK -00069 LDWG EDIT OF RST 29- May -11 1 1 J -28 BBSK -00067 LDWG EDIT OF RST 30- Apr -11 1 1 06 -01 BBSK -00080 LDWG EDIT OF RST 23- Jul -11 1 1 • 1111 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 m,° 1 5 2012 DATA SUBMITTAL COMPLIANCE REPORT 3/1/2010 Permit to Drill 2081250 Well Name/No. PRUDHOE BAY UNIT 01-34A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21609-01-00 MD 9472 TVD 9227 Completion Date 1125!2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATAINFORMATpN Types Electric or Other Logs Run: DIR / GR /RES / PWD, PWD / DRI / GR /DEN / NEU /RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH 1 type... mearrrmz rvu~nuer Name aca~C ~newa rvo arar~ atop ~.n ~cec~iveu a.unnnr~~w pt LIS Verification 7950 9472 Open 3/10/2009 LIS Veri, GR, RPS, RPX, RPD, FET, ROP, NPHI, RHOB, PEF, DRHO, FCNT ` C Lis D 17687~uction/Resistivity 7950 9472 Open 3/10/2009 LIS Veri, GR, RPS, RPX, RPD, FET, ROP, NPHI, RHOB, PEF, DRHO, FCNT Log Induction/Resistivity 25 Col 7897 9472 Open 3/10/2009 MD ROP, EWR, DGR, ALD, CTN 15-Dec-2008 Log Induction/Resistivity 25 Col 7774 9227 Open 3/10/2009 TVD EWR, DGR, ALD, CTN 15-Dec-2008 C / 17688 "'See Notes 0 0 3/10/2009 EWR logs in PDS, EMF and CGM graphics Nell Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments •I it I DATA SUBMITTAL COMPLIANCE REPORT 3/1 /2010 Permit to Drill 2081250 Well Name/No. PRUDHOE BAY UNIT 01-34A MD 9472 ND 9227 ADDITIONAL INFOR N Well Cored? M Chips Received? ~7N"' Analysis ~#- Received? Completion Date 1/25/2009 Operator BP EXPLORATION (ALASK/y INC Completion Status 1-OIL Current Status 1-OIL Daily History Received? p~, ,,N Formation Tops V~' N API No. 50-029-21609-01-00 UIC N Comments: Compliance Reviewed By: Date: L~ STATE OF ALASKA ALASItf~OIL AND GAS CONSERVATION COMMISSI N REPORT OF SUNDRY WELL OPERATIONS R~c~~v~® EEB 2 2 2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ $ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waivei^ Time Extension ^ I~~I~h9fe~ Change Approved Program ^ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^~ Exploratory ^ 208-1250 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API tuber: Anchorage, AK 99519-6612 50-029-21609-01-00 8. Property Designation (Lease Nu ber) : 9. Well Name and Numbef: O ADLO-028329 PBU 01-34A 10. Field/Pool(s): `PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 9472 feet Plugs (measured) None feet true vertical 9227.25 feet Junk (measured) None feet Effective Depth measured 9389 feet Packer (measured) 8580 true vertical 9145.91 feet (true vertical) 8350 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 91.5# H-40 SURFACE - 110 SURFACE - 110 1490 470 Surface 2501 13-3/8" 68#/72# K-55/L-80 SURFACE - 2501 SURFACE - 2501 4930 2270 Intermediate Production 7978 9-5/8" 47# L-80 SURFACE - 7978 SURFACE - 7775 6870 4760 Liner 5811 7"26# L-80 3023 - 8834 3023 - 8601 7240 5410 Liner 824 4-1/2" 12.6# 13CR80 8646 - 9470 8416 - 9225 / 8430 7500 Perforation depth: Measured depth: O 9265 - 9280 O 9310 - 9320 O 9190 - 9200 +~ _ _ True Vertical depth: 9024.5 - 9039.18 9068.54 - 9078.33 8951.04 - 8960.84 _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CR SURFACE - 8657 SURFACE -8427 Packers and SSSV (type, measured and true vertical depth) 7"X4-1/2" S3 PKR 8580 8350 12. Stimulation or cement squeeze summary: Intervals treated (measured): 5 ~~ pp ~~ ~ a` 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: 100 2088 1974 194 Subsequent to operation: 105 2001 1965 230 14. Attachments: 1 . 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 2/19/2010 Form 10-404 Revised 7/2009 ~,~ ,?.t3 /~ RBDMS FEB 2 3 1010 ~~ Submit Original Only flfl • 01-34A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 2/14/2010;"**WELL FLOWING ON ARRIVAL*** (ELINE -ADPERF) INITIAL T/I/O = 200/1225/0. RU ELINE FOR ADPERF. SHUT-IN WELL BEFORE RIH, T/I/O = 950/1275/0. l ***JOB CONTINUED ON 15-FEBRUARY-2010*** 2/15/2010;***JOB CONTINUED FROM 14-FEBRUARY-2010*** (ELINE-ADPERF) ;PERFORATED 9190'-9200', REFERENCED TO HES MWD LOG DATED 16- ? DEC-2008, USING 10' 3-3/8" HSD POWER JET, HMX, 6 SPF, 60 DEG PHASING. FINAL T/I/0 = 1040/1280/0. WELL BROUGHT ON-LINE BEFORE DEPARTURE ***JOB COMPLETE*** FLUIDS PUMPED BBLS 1 DIESEL 2 METH 3 Total TREE = 4 1t8" CNJ Wt1LHEAD= FMG AC1"13ATt?R KB. Elul = 87.T BF. B.EV = 44` KUP = 4900` Max Angle = 26 ~ 8100' Datum MD = 8172' Datum TV D = 8800` SS 13-3/8" CSG, 72#, K-55, ID = 12.347" 30' 13-3/8"CSG, 72#, L-80, ID = 12.347" 2501' 7" x 9-518" Liner lop ZXPPacker w / PBR 3022' Cretaceous PC:1-esk X55()" Stub H 81tT0' 13Ct, = 3.95$" H 8657` Minimum i[~ =:3.725"` ~ 8&4~' 41/2'" HES XIV RIIPPLE pERraR,aT1oN suMtv-AR~ REF LOG: SPCRRY lWD ON 12/16/X0$ ANGIC AT TUP PERF: 12` ~ 9265' MD Note: Refer to Production DB ~r ttistoncal pert data Slll SPF INTERVAL OpniS DATE 3-318" & 9265.- 9280 O 0t125it39 3-318" & 9310 - 9320 Q 01125!09 9-5i$" GStz, 47#, L-80, A7 = 8.681"" ~ 958{#' ~ SAFETYNOT'~ **CNROMETBt`sB INR`* X" Afppk:, ~ = 3.813" CAS 1 IFT MANDRFI S ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3500 3500 1 KBG2 DOME BK 16 Q4/11l09 4 5538 5502 23 KBG2 DOME BK 16 04/11/09 3 6823 6691 21 KBG2 DOME BK 16 04!11/09 2 7688 7507 21 KBG2 DOME BK 20 04/11/09 1 5471 8243 10 KBG2 SO BK 28 04/11/09 MILL WINDOW {01-34A) 7978' - 7992' L,. $549' X' Nippte, iD=3.813" / $580` 7" x 4112" 53 F'tCR 8513' X' Nipp(e, ID=3.813" 8644` XDI [apple; iD = 3.725° 8646' 865T 4112" Liner top wLEC $834` T" L-80, 26#, ID=6.276., 93$9'__ ~-~ PBTD 9470" - 4-1/2", 13Cr, 12.6#, ID-3.958 DATE REV BY COMMENTS DAIS REV BY COMMENTS 07/11/8& ORIGINAL COMPE.ETIGN 02~03t09 JKDfSV PERFS {01/25109) 01114/87 WORKOVER 04112/09 CJNlSV GI.V C!fl 0411 ii09) 12!14/02 DAC/KK RIG WORKOVEF2 02%16101 TP GORRECTIONS 12!19/08 N2ES SIDETRACK (01-34A 1?J2B10$ ITLM GflRRECTIUNS & GLV CICt PRUDHOE BAY UNR" WELL 01-34A ('ERMtT No: 2081250 !n PI No' 50-029-21609-01 SEG 8, T10N, R15, 2401' FEL f 1312' FSL BP Exptorafi~ (Alaska) i Maunder, Thomas E (DQA) From: Hobbs, Greg S (ANC) [Greg.Hobbs(~bp.com] Sent.:: Tuesday, August 44, 2449 4:49 FAIL To: Maunder, Thomas E (DOA) Subject: RE: DS 41-34A (248-125) Page 1 of 2 You made me think on this one- The well had a leak in the casing #hat we were going to drill out below- The LOT was not done at the mill-out. It was done on 1216/08be1ow an RTTS to assure the weak point above the kick-off point would allow drilling. Travis indicated in the permit that a 12.5 FIT was optimum, but an 11.2 FIT would suffice as it allowed a 26 bbl kick tolerance to satisfy our policy. Given the rates and pressures noted during pre-rig tests, it was determined during operations that an 11.2 FIT was the best we could possibly get. The 11.18 FIT was completed on the hole on the casing, and after mill-out at 8404' MD, discussion of a deeper Fl7 (after milling operations that left a mill in the hole, then fishing operations, then a second milling operation with sweeps to remove the metal in a 10.3 system), came to the determination that it would not be any weaker than that taken at the cretaceous leak, for this reason, we took the first FIT as our weak point and drilled ahead. DIMS data from 12!6/48: PJSM. Set RTTS (e~ 3200` and test 9 5/8" easing to 2750 psi for 30 min. Good Test. 08::30-09:00 3,200 0.50 RECOM GLE/aN TSTPRS P Perform an FIT to 11..18 EMw (c,~ 5650'. 09:00-11:00 3,088 2.00 DECQM CLEAN TSTPRS P PJSM. POH to 3088' and rack back 1 stand. Pickup Storm Packer and RtH 65' below the wellhead and set. Test the Storm Packer to 2000 psi for 5 minutes. Good Test These were the operations outlined in the permit- Ria Opera ions 1. Move in. Rig up Nabors rig. 2. Putt BPV. Circulate out freeae protection and displace with 9.6 brine. 3. Run TWC and test to 1404 psi. 4, Nipple down tree. Nipple up B(JPE. 5. Test EiQPE to 3540 psi high., 254 psi low.. Pull TWC. 6. Screw in landing joint. Unseat and pull 4-1/2" tubing hanger to floor '7. Lay down landing joint and hanger. 8/6/2.009 Page 2 of 2 8. Pull 4-112" tbg to cut at 8100' MD. Spout up control tine. Count bands and clamps. 9. RIH with RTTS to 3000'. Pressure test casing above RTTS. o tf test does not pass, contact QDE. (option ~ to run 7" tieback at this pint), o If test passes, continue on. 1Q. Pressure test easing below RTTS to an FIT equivalent of 12.5 ppg at 5650' MD leak. o Ifi test. does not pass., run F2TTS to 5600' and test shave., if new test fails, isolate leak and test to equivalent 12.5 ppg FIT. We held this to 11.2 after pre-rig pump testing- o If test passes, continue on. 11. RIM and set CIBP above tubing stub at °8050' MD. I2. PU and RIH with whipstock.. 13. Orient and set WS at 8025' MD. 14. Displace to 9.6 ppg LSNp milling fluid. 15. Mill window. Pump a sweep. PDOH, LE} window milling assembly. 16. PU 8-1/2" drilling BHA. RIH. 1 "~. Drill 20`, perform FIT'. - We did not do this. one. Hope that clears things up- Greg From; Maunder, Thomas E (130A) [mailto:tom.maunder@alaska.govJ Sent: Tuesday, August 04, 2009 2:.31 PM Ta-. Hobbs, Greg 5 (ANC) Subject: DS 01-34A (208-125) Greg, I was doing some belated review of the operations reports for this well. Was a I_QT/FIT accomplished. after the window was drilled out of the 9-5/8" casing. There was some fishing needed part way through the milling operation ~ 12/6/08, but I don't find any mention of a t_QT as planned in the operations plans in the drilling program. Thanks in advance, Tom Maunder, PE AQGCC 816/2Q09 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 01-34A • March 3, 2009 AK-MW-6161008 01-34A: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-029-21609-01 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-029-21609-01 Digital Log Images: 50-029-21609-01 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ~I3r}~ai~rt _ `burton.com Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 907-273-3536 Fax~,90773; 3. Date: -' Signed: ~; • WELL LOG TRANSMITTAL T®: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: 01-34A Ol-34A: 1 LDWG formatted CD rom with verification listing. API#: 50-029-21609-01 February 26, 2009 AK-MW-6161008 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 l~rton.com ;. BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ;~~ -, Date ~ a ~~ -, ~ ~ `.' _ Signed: ~.--~ Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Tuesday, March 03, 2009 2:54 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU 01-34A / PTD # 208-125 Hi Art, Please reference the following well: Well Name: PBU 01-34A Permit #: 208-125 API #: 50-029-21609-01-00 Top Perf MD: 9265' Bottom Perf MD: 9320" This well began Production on February 26, 2009 Method of Operations is: Flowing Date of Test: 03102/09 Hours Tested: 8 24-Hour Rate 1 Oil-Bbl: 14 24-Hour Rate /Gas-Mcf: 2,096 24-Hour Rate /Water-Bb{: 3,530 Test Rate /Oil-Bbl: 5 Test Rate 1 Gas-Mcf: 699 Test Rate 1 Water-Bbl: 1,177 Choke Size: 75 Gas-Oil Ration: 99,999 Flow Tubing Pressure: 364 Casing Pressure: 1,500 Oil Gravity-API: Unavailable 3/4/2009 STATE OF ALASKA ~'~"~~~~~ ALASKA ~ AND GAS CONSERVATION COMM~SION 3 ~.~C9 ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG r ~O~~±iSSiO~~ `~' staska Oil & was ~on~. "'' 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC25.105 zoMC2s.~~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. W n ®Development ^ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 1/25/2009 , 12. Permit to Drill Number 208-125 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/10/2008 - 13. API Number 50-029-21609-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/15/2008 ~ 14. Well Name and Number: PBU 01-34A FWL, SEC. 08, T10N, R15E, UM 1312 FNL, 1566 Top of Productive Horizon: 2414' FNL, 2185' FWL, SEC. 08, T10N, R15E, UM g. KB (ft above MSL): 67.7' Ground (ft MSL): 39.2' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2416' FNL, 2133' FWL, SEC. O8, T10N, R15E, UM 9. Plug Back Depth (MD+TVD) 9389' 9146' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 698915 y- 5939617 Zone- ASP4 10. Total Depth (MD+TVD) 9472' 9227' 16. Property Designation: ADL 028329 TPI: x- 699566 y- 5938531 Zone- ASP4 - 5938528 Zone- ASP4 th: x- 699514 T tal De 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: y p o 18. Directional Survey ®Yes ^ No S i I r ni nd rioted info r AA 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information er 20 AAC 25.071) "~ , DIR / GR /RES /PWD, PWD / DRI / GR /DEN / NEU /RES w/Yv0`,/~ ~9~7 i~lD ~~~~^: STd.D 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 0" 91. 11 rfa 11 " 1 - " ' ' 1 _ " 2~ sx CS III, 400 sx CS II, Top Job: 150 sx CS II - / " 47# rf 77 ' 1 -1/4" 7 s I 'G' I 7" L- 2' -1/ " 7 r t I ' 4-/' 12 7' 1 1 23. Open to production or inject ion? ®Yes ^ No 24. TuewG RECORD If Yes, IISt each I MD+TVD f T 8 B tt P nterval Open r ti n Siz nd Number): f SIZE DEPTH SET MD PACKER .SET MD ( op ~ o om; er o a o e a o 3-3/8" Gun Diameter 6 spf 4-1/2", 12.6#, 13Cr80 8657' 8580' , MD TVD MD TVD 9265' - 9280' 9025' - 9039' 9078' 9310' 9320' 9069' 2rj, ACID,. FRACTURE, CEMENT SQUEEZE, ETC. - - DEPTH INTERVAL MD AMOUNT ~ KIND OF MATERIAL USED 2256' Freeze Protect w/ 155 BBIs of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PfeSS. Casing Press: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^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. None /-5=09 V Form 10-407 Revised 02/2007 ~ ~ (~` CONTINUED ON REVERSE SIDE I .. ~ ~ ~ ~f~, AUG ~6 ~ 2009 ,~`A~~~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? Yes ®No `Permafrost Top If yes, list intervals and formations tested, brieYly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 8834' 8601' None Shublik 8866' 8633' Sadlerochit 8946' 8711' GOC 9125' 8887 Top CGL I Zone 3 9129' 8891' Base CGL /Zone 2C 9217' 8978' 23S6 /Zone 26 9286' 9045' HOT / 22TS 9310' 9069' OWC / 21 TS /Zone 2A 9364' 9121' Formation at Total Depth (Name): 21TS /Zone 2A 9364' 9121' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Operations, Well Schematic Diagram, Surveys 31. I hereby certify that the forego'ng is true and correct to the best of my knowledge. ~ ~ ~~ Signed Terrie Hubble Title Drilling Technologist Date PBU 01-34A 208-125 Prepared By Name/Number. Te--ie Hubble, 564-4628 Well Number Permit No. / A rOVal NO. Drilling Engineer: Travis Peltier 5644511 INSTRUCTIONS GeNew-L: 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. IreM 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: TPI (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. ITeM 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. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 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. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a beef 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 Page 1 of 1 Leak-Off Test Summary Legal Name: 01-34 Common Name: 01-34 Test Date ~est Type ! Test Depth (TMD) Test Depth (TVD) ~ AMW I Surface Pressure Leak Off Pressure (BHP) ~ _ EMW - - - 12/6/2008 - LOT - - 5,650.0 (ft) -- 5,600.0 (ft) - - 10.30 (ppg) _ - 256 (psi) _ 3,252 (psi) 11.18 (ppg) 12/14/2008 FIT 8,835.0 (ft) 8,602.0 (ft) 8.40 (ppg) 950 (psi) 4,704 (psi) 10.53 (ppg) `. J Printed: 12/30/2008 12:35:28 PM BP EXPLORATION Operations Summary Report Page 1 of 9 ~ Legal Well Name: 01-34 Common Well Name: 01-34 Spud Date: 6/28/1986 Event Name: REENTER+COMPLETE Start: 12/2/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/19/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To I Hours Task I Code ~ NPT ' Phase I' Description of Operations _ __ 6.00 MOB P PRE PJSM. Transport open cellar doors and prep rig for move. 12/2/2008 00:00 - 06:00 r 06:00 - 12:00 6.00 MOB P PRE PJSM. Hold a pre moving safety meeting with all rig personnel 12:00 - 18:00 6.00 RIGU P 18:00 - 00:00 6.00 RIGU P 12/3/2008 00:00 - 03:00 3.00 RIGU P 03:00 - 06:00 3.001 RIGU ~ P 06:00 - 08:00 2.00 RIGU P 08:00 - 12:00 4.00 RIGU P 12:00 - 18:00 6.00 RIGU P 18:00 - 21:00 3.00 RIGU P 21:00 - 00:00 3.00 BOPSU P 112/4/2008 ~ 00:00 - 03:30 ~ 3.50 ~ BOPSUF{ P 03:30 - 04:00 0.50 BOPSU P 04:00 - 07:00 3.00 DHB P 07:00 - 08:00 1.00 PULL P 08:00 - 09:30 1.50 PULL P 09:30 - 23:00 I 13.501 PULL I P and security. Jack up rig and proceed off Pad 10 with escort, turn right on West Dock Road, travel to Spine road turn right then turn right on DS1 access road. Proceed to well 01-34. Spot pits and cuttings tank, berm and trim herculite, spot camp, welding shack, mud shack, and MWD shack. Pressures- Tubing 0 psi, IA 0 psi, OA 175 psi PRE Continued to prep the rig for the well, took on fluid in the pits, prepared to raise the derrick. Raised the derrick and the cattle chute. PRE Run the bridle lines, hang the rig tongs, install the bales on the top drive, P/U DSM lubricator to floor and prepare. to pull BPV. PRE PJSM with Rig Crew and DSM. Rigged up lubricator and pulled BPV. R/D DSM and secured the well. Test the lines to 3500psi. Good Test PRE PJSM. Reverse Circulate pumping 64 bbls before seeing returns 200gpm ~ 300 psi. Switch lines in cellar and circulated the long way 220 gpm @ 420 psi. -Brine losses of 225bb1s PRE PJSM. Drv rod in TWC and test from above to 3500 ^~ test from below to 1000 psi both test for 5 minutes. -Brine losses of 220 bbls PRE PJSM. Nipple down tree and clean out tubing hanger. PRE PJSM. Stab the DSA flange and nipple up the BOP stack. Install the riser, turnbuckles, mousehole, and air up riser boots. PRE PJSM. Make up 4" test joint, cross over, TIW, and dart valve and install in the stack. Filled the stack and perform a body test. Found leak in riser. Removed the riser and fixed the leaking area and reinstalled the riser. Performed a body test again. Good Test. PRE Test BOPE. -Test Upper Pipe Rams to 250 psi low / 3500 psi high with 4" -Test Annular Preventer to 250 psi low / 2500 psi high with 4" test joint. -Test Choke manifold and all BOPE related valves. PRE Continue to test BOPE. -Performed Koomey test -Test Upper Pipe Rams to 250 psi low / 3500 psi high with 4.5" -Test witnessed by WSL Chris Kobuck, Tourpusher Jon Castle and John Crisp of AOGCC. PRE Rig down and clear floor of all BOP testing equipment. DECOMP PJSM. Install lubricator extension and riq up the lubricator and test lubricator to 250 si. Good Testy Pull TWC DECOMP PJSM. Rig up casing equipment and prepare to pull 4.5" tubing. DECOMP PJSM. Make up landing jt. to hanger, back out lockdown screws, and pull tubing hanger to floor. Hanger pulled free ~ 120k. La down han er an fill DECOMP Pull out 4. 12. # 1 r- F 1 xi from 8,100' with no issues filling every 15 joints. PliMetl: 1L'3U/'LUUtl 12:3b:94 YM • BP EXPLORATION Operations Summary Report Legal Well Name: 01-34 .Common Well Name: 01-34 ~ Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 2ES Date ~ From - To ~ Hours Task ,Code ~; NPT __ _ _:_ 12/4/2008 09:30 - 23:00 ~ 13.50 PULL P Start: 12/2/2008 Rig Release: 12/19/2008 Rig Number: i Page 2 of 9 ~ Spud Date: 6/28/1986 End: Phase ', Description of Operations DECOMP -Removed following items from well. -Tubing Hanger -254 full jts. -1 cut jt. (16.71') -3 GLMs -1 X-nipple 23:00 - 00:00 1.00 PULL P DECOMP PJSM. Rig down all casing equipment and clean and clear the floor. 12/5/2008 00:00 - 01:00 1.00 PULL P DECOMP Finish cleaning and clearing the floor and make up the 4" test jt. 01:00 - 01:30 0.50 BOPSU P DECOMP PJSM. Rig up to BOP test lower pipe rams. 01:30 - 02:30 1.00 BOPSU P DECOMP PJSM. BOPE Test the lower pipe rams with 4" test jt. to 250 psi low / 3500 psi high. Good Test. -Test Witnessed by WSL Chris Kobuck and NAD Tourpusher Jon Castle. Witness waived by AOGCC rep. John Crisp. 02:30 - 03:30 1.00 BOPSU P DECOMP Rig down the BOPE Test equipment and install the wear bushing. 03:30 - 04:30 1.00 CLEAN P DECOMP PJSM. Pick up third party tools and BHA handling equipment. 04:30 - 06:30 2.00 CLEAN P DECOMP Load drill pipe into the shed; strap and tally. Prepare to make up BHA. 06:30 - 09:30 3.00 CLEAN P DECOMP PJSM. Make uo the 9 5/8" Scraoer run BHA. BHA consists of the following. -Roller Cone Bit -9 5/8" Casing Scraper -2 Junk Baskets -X-over -3 Drill Collars -2 HWDP -Jars -15 HWDP -X-over 09:30 - 17:00 7.50 CLEAN P DECOMP RIH from 649' to 8100'. Tagged tubing stub ~ 8100'. 17:00 - 18:00 1.00 CLEAN P DECOMP Circulate brine and prepare for displacement. -300gpm f~ 980 psi -Up Wt. 175k /Down Wt. 120k /Rot Wt. 140k -RPM 35 -Torque 4-5k 18:00 - 21:00 3.00 CLEAN P DECOMP PJSM. Displace from 9.8 ppg brine to 10.3 ppg LSND. Pump 50 bbls of Hi-Vis LCM pill, Chased by 10.3 ppg LSND. -335 gpm @ 1050 psi -Monitor Well for 10 minutes -static 21:00 - 21:30 0.50 CLEAN P DECOMP PJSM. Install air slips and prepare to TOH. 21:30 - 00:00 2.50 CLEAN P DECOMP TOH from 8100' to 4462'. -Up Wt. 110k /Down Wt. 75k 12/6/2008 00:00 - 04:00 4.00 CLEAN P DECOMP Continue to TOH from 4462' to 0' racking back everything except for 2 jts. of HWDP and jars. - Up Wt. 110k /Down Wt. 75k 04:00 - 04:30 0.50 CLEAN P DECOMP PJSM. Clean and clear floor and prepare to run the 9 5/8" RTTS. 04:30 - 05:30 1.00 CLEAN N SFAL DECOMP PJSM. Began to make up 9 5/8" RTTS when crack was discovered in the band in the middle of the element. Repair rrirnea: i~~urzuua icso:av rm ~ ~ BP EXPLORATION Page 3 of 9 Operations Summary Report Legal Well Name: 01-34 Common Well Name: 01-34 Spud Date: 6/28/1986 Event Name: REENTER+COMPLETE Start: 12/2/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/19/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/6/2008 04:30 - 05:30 1.00 CLEAN N SFAL DECOMP RTTS. 05:30 - 07:30 2.00 CLEAN P DECOMP M/U RTTS &RIH to 3200' 07:30 - 08:30 1.00 CLEAN P DECOMP ~'JSM. Set RTTS 3200 and test 9 5/8" casing to 2750 psi for 30 min. Good Test. 08:30 - 09:00 0.50 CLEAN P DECOMP Perform an LOT to 11.18 EMW ~ 5650'. 09:00 - 11:00 2.00 CLEAN P DECOMP PJSM. POH to 3088' and rack back 1 stand. Pick up Storm Packer and RIH 65' below the wellhead and set. Test the Storm Packer to 2000 si for 5 minutes. Good Test 11:00 - 14:30 3.50 CLEAN P DECOMP PJSM. Suck out the stack, remove the riser, turnbuckles, and N/D the DSA, tubing spool, and pull the 9 5/8" pack-off. 14:30 - 18:30 4.00 CLEAN P DECOMP Install new 9 5/8" pack-off and N/U new tubing spool and ROPE. Test the pack-off to 3700 psi for 10 minutes. Good Test 18:30 - 19:00 0.50 CLEAN P DECOMP PJSM. Test Tubing spool to 250 psi low / 3500 psi high. Good Test. 19:00 - 22:00 3.00 CLEAN P DECOMP PJSM. Install wear bushing and wear ring and prepare for TOH. Make-up the packer retrieving tool and screw into the Storm Packer. POH from 3200' to 0'. Laydown the Storm Packer and RTTS. 22:00 - 23:00 1.00 CLEAN P DECOMP PJSM. Pick up and rig up the Schlumberger E-line logging tools. 23:00 - 00:00 1.00 EVAL P DECOMP RIH to 8100' and tag the stub. POH logging GR/CCL. 12/7/2008 00:00 - 03:00 3.00 EVAL P IjECOMP Continue logging GR/CCL. 03:00 - 03:30 0.50 CLEAN P DECOMP PJSM. Rig down E-line tools and prepare to make up Whipstock BHA. 03:30 - 06:00 2.50 STWHIP P WEXIT PJSM. Make up Smith Whipstock, running tools, and MWD. Shallow test the MWD 475 gpm ~ 925 psi. Test Failed. 06:00 - 12:30 6.50 STWHIP N SFAL WEXfT PJSM. Lay down MWD and Smith Whipstock. Work out the j issues with the MWD, which turned out to be a bad stroke counter on pump 1 and the tool was reading a "bad bus". The ~ entire tool was changed out and we then we shallow tested 200 ~ gpm ~ 380 psi. Good Test. 12:30 - 20:30 8.00 STWHIP P WEXIT PJSM. Make up the BHA, collars, HWDP and RIH to 8001'. 20:30 - 21:30 1.00 STWHIP P WEXIT Orient the whipstock to 81 degrees right ~ 8003' close the MCV sub, Pressure up the foal to 3000 psi and set the anchor. Pick up 225k and slack off 135k and work 2 times until mill broke free. ~~ 21:30 - 00:00 2.50 STWHIP P WEXIT Mill window from 7978' to 7984'. O\ 34}~ w B 5k 70K /Down Wt. 140k /ROT Wt. 160k • . -GPM 475 -TO 4-5 / 7-9 -Mud Wt. In and Out 10.2+ -1351bs of metal recovered 12/8/2008 00:00 - 01:00 1.00 STWHIP N DFAL WEXIT PJSM. While milling ahead at 7984' we had a sudden TO increase from 7k to 13k, with a pressure drop from 2728 psi to 2329 psi. When the Drill string was picked up a decrese from 175k to 160k was noticed on the u wei ht. After checking the surface equipment the decision was made to TOH. Total Metal recovered - 2701bs 01:00 - 02:30 1.50 STWHIP N DFAL WEXIT Pump a Hi-Vis sweep to clean out the metal shavings in the hole. Nnmeo: i~swzuua 1L:Jb:J4 YM ~ ~ BP EXPLORATION Page 4 of 9 Operations Summary Report Legal Well Name: 01-34 Common Well Name: 01-34 Spud Date: 6/28/1986 Event Name: REENTER+COMPLETE Start: 12/2/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/19/2008 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task 'Code ; NPT ~, Phase Description of Operations N DFAL WEXIT -520 gpm ~ 2650 psi 12/8/2008 01:00 - 02:30 1.50 STWHIP 02:30 - 04:00 1.50 STWHIP N DFAL WEXIT 04:00 - 09:30 5.50 STWHIP N DFAL WEXIT 09:30 - 10:00 0.50 FISH N DFAL WEXIT 10:00-11:00 1.00 FISH N DFAL WEXIT 11:00 - 15:30 4.50 FISH N DFAL WEXIT 15:30 - 16:30 1.00 FISH N DFAL WEXIT 16:30 - 20:00 3.50 FISH N DFAL WEXIT 20:00 - 21:00 1.00 FISH N DFAL WEXIT 21:00 - 22:00 1.00 STWHIP N DFAL WEXIT 22:00 - 00:00 2.00 STWHIP N DFAL WEXIT 12/9/2008 00:00 - 02:30 2.50 STW H I P P WEXIT 02:30-09:00 6.50 STWHIP P WEXIT 09:00 - 10:00 1.00 STWHIP P WEXIT 10:00 - 13:30 3.50 STWHIP P WEXIT 13:30 - 15:00 1.50 STWHIP P WEXIT 15:00 - 15:30 0.50 STWHIP P WEXIT 15:30 - 16:30 1.00 STWHIP P WEXIT 16:30 - 19:00 2.50 DRILL P INT1 19:00 - 00:00 5.00 DRILL N WAIT INT1 12/10/2008 00:00 - 05:30 5.50 DRILL N WAIT INT1 -Monitor Well -static -Pump a Dry Job and prepare to TOH PJSM. Slip and cut drilling line and service the top drive. PJSM. POH from 7984' to surface, L/D the BHA, Rack back the HWDP and collars and L/D the MWD. The upper Watermelon Mill was parted 8 68' bQ~^-~^~+r,o ~~Irncr cnnnP.ctlOn. Clean and clear the rig floor and prepare to go in and fish the remainder of the mill assembly. PJSM. Pick up the BHA and make up the fishing spear as per Baker Fishing hand. TOH from 569' to 7976'. -Up and Down Wt. 80k Locate and engage the fish and set down 10k on it. A slight psi increase was noticed from 1630 psi to 1670 psi. Pick up 1 stand and rack it back, then dropped bar to function the pump out sub ~ 1600 psi. Pump a dry job and prepare to TOH. TOH from 7918' to 569' and then change out the BHA handling equipment. La down the BHA, stand back the HWDP, Drill collars, Baker fishin tools, and the Fish mith Mill . :The mill was in gauge, had a clean break, and didn't show any extensive wear on the mill face. After measuring the fish we recovered the entire fish. Clean and clear floor and prepare to run back in. PJSM. Pick up new mill assembly BHA and run in the hole to 2915'. RIH from 2915' to 7938'. Up Wt. 165k /Down Wt. 152k PJSM. Wash down from 7938' to 7984'. Begin to mill window and rat hole from 7985' to 8005'. -RPM 110 / WOB 3-16k -TO Off 4-5k / On 5-6k -495 gpm ~ 600 psi -Up Wt. 165k /Down Wt. 152k /ROT Wt. 157k Work window up and down with pumps on and off. No Drag Metal Returns today - 285 lbs. Pump Hi-Vis Sweep ~ 520 gpm and 2050 psi. Monitor Well - static. Pump a dry job and prepare to POH PJSM. POH from 8005' to 589'. -Mud Wt In and Out 10.2+ Lay down BHA and rack back drill collars and HWDP. Mill still in gauge. Clean and clear the floor and prepare to pick up drilling BHA Remove wear bushing and pull wear ring. Flush out the BOP stack and function rams and hydril to ensure they are clean. Reinstall the wear ring. Pick ua Bit. Motor, MWD and function test the MWD. Waiting on the weather due to high winds with gusts over 60 mph. Called a Phase 2 level 2 by heavy equipment. Continuing to wait on the wind to slow down so we can go back to work. Wind gusts still in excess of 50mph with a windchill around -55. rrinteo: iuauizwu icaa:.w rive • • BP EXPLORATION Operations Summary Report Legal Well Name: 01-34 Page 5 of 9 ~ Common Well Name: 01-34 Spud Date: 6/28/1986 Event Name: REENTER+COMPLETE Start: 12/2/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/19/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/10/2008 05:30 - 07:30 2.00 DRILL P INT1 Resuming work after waiting on the weather. Resume pick up the drilling BHA #1 to 734'. -Up Wt. 60k /Down Wt. 60k Shallow test the MWD. Good Test 07:30 - 09:00 1.50 DRILL P INTi Pick up drill pipe, singling in the hole to 2592'. Break circulation and re-test MWD. Good Test. 09:00 - 12:00 3.00 DRILL P INT1 Continue to RIH from 2592' to 7895' breaking circulation every 2000'. Line up BHA at 81 degrees right of high side and work through the window with no drag. -Mud Wt. In and Out 10.3 ppg 12:00 - 00:00 12.00 DRILL P INTi Begin drilling 8.5" intermediate hole form 8005' to 8312'. - -Up Wt. 170k /Down Wt. 160k /ROT Wt. 165k -WOB 10k /RPM 80 -TO 4-6k -PSI Off 2830 / On 3050 C~? 520 gpm -Mud Wt. In and Out 10.3 ppg 12/11/2008 00:00 - 12:00 12.00 DRILL P INTi Continue to directionally drill ahead at 8312' to 8552'. -Up Wt. 175k /Down Wt. 165k /ROT Wt. 170k -WOB 5-15k /RPM 100 -TO 4k off / 4-6k on -PSI Off 2790 / On 2980 ~ 520 gpm -Mud Wt. In and Out 10.3 ppg 12:00 - 00:00 12.00 DRILL P INT1 Continue to directionally drill ahead at 8552' to 8835_TVD 8602' -Up Wt. 185k /Down Wt. 165k /ROT Wt. 175k -WOB 5-15k /RPM 100 -TO 3-4k off / 4-6k on -PSI Off 3050 / On 3290 ~ 520 gpm -Mud Wt. In and Out 10.3 ppg 12/12/2008 00:00 - 01:30 1.50 DRILL P INT1 Circulate bottoms up for geology samples. TD called at 8835' per geologist. Pump Low-Vis Sweep to clean up the hole. -RPM 100 / TO 4k -520 gpm C~ 3200 psi -Up Wt. 180k /Down Wt. 167k (Both with pumps on) -Up Wt. 190k /Down Wt. 170k (Both with pumps off) -Monitor Well -Static -Mud Wt. In and Out 10.3 ppg 01:30 - 04:00 2.50 DRILL P INTi Trip out of the hole from 8835' to 8810'. Then MAD pass from 8010' to 7790' at 300 ft/hr. 04:00 - 04:30 0.50 DRILL P INT1 Dropped ball to cycle open the circulating sub at 7790'. -Closed ~ 552 strokes / 2000 psi 04:30 - 05:30 1.00 DRILL P INT1 Circulate bottoms up at 7790' -RPM 100 / TO 3k -550 gpm ~ 2359 psi 05:30 - 12:00 6.50 DRILL P INT1 Trip out of the hole from 7790' to 734'. Change out the handling equipment and then laydown the BHA from 734' to 0'. Download the MWD and clean and clear the floor. 12:00 - 12:30 0.50 BOPSU P INT1 Remove the wear bushing and install the test plug. 12:30 - 16:00 3.50 BOPSU P LNR1 PJSM. Change out the top rams to 7" rams. 16:00 - 17:00 1.00 BOPSU P LNR1 Pick up the 7" test jt. and test the upper rams to 250 psi low and 3500 psi high. GAOd test. Then we pulled the test joint rnmeo: iziawzuuo it:ao:ov rm • • BP EXPLORATION Page 6 of 9 Operations Summary Report Legal Well Name: 01-34 Common Well Name: 01-34 Spud Date: 6/28/1986 Event Name: REENTER+COMPLETE Start: 12/2/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/19/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours ~ Task Code NPT Phase Description of Operations 12/12/2008 16:00 - 17:00 1.00 BOPSU P LNR1 and reinstalled the wear ring. 17:00 - 18:00 1.00 CASE P LNR1 PJSM. Rig up to run 7" casing. 18:00 - 00:00 6.00 CASE P LNR1 Run 7" BTC-M 26# L-80 casing torqued to 7200 ft/Ibs. Baker lock the shoe track, checked. Floats holding. Run in hole to 3899' filling on the fly and topping off every 10 jts. -Up Wt. 112k /Down Wt. 100k 12/13/2008 00:00 - 04:00 4.00 CASE P LNR1 Continue running 7" BTC-M, 26#, L-80 casing torqued to 7200 fUlbs. Run in hole from 3899' to 5823' filling on the fly and topping off every 10 jts. Make up the liner hanger and screw into it with a XO and 15' pup joint. -Up Wt. 160k /Down Wt. 145k /Liner Wt. 145k -Mud Wt in and out 10.3 ppg 04:00 - 07:30 3.50 CASE P LNRi -Trip in hole from 5823' to 7884' on drillpipe. Then screw into the top drive and circulate 1.5X liner volume. Stage up the pumps to 5 bbl/min ~ 620 psi. 07:30 - 08:30 1.00 CASE P LNR1 Continue in the hole from 7884' to 8804'. No issues were seen while in open hole. 08:30 - 09:00 0.50 CASE P LNR1 PJSM. Make up the cement head circulating lines and 1 jt. of 4" drillpipe and run to 8835'. -U Wt. 2 Ok Do t. 1 k 09:00 - 11:00 2.00 CASE P LNR1 Circulate 2X bottoms up with an initial rate of 2 bpm ~ 640 psi and a final rate of 5 bpm C~3 810 psi. 11:00 - 15:00 4.00 CEMT P LNR1 PJSM. Pump 30 bbl 10.0 ppg MudPush and pressure test cement lines to 4500 psi; good test. Pump 140 bbls 11 ppg lead cement followed by 35 bbls of 15.8 ppg tail cement. Drop the top plug and chase with 5 bbls of water, then swap over to the rig pumps and displace the cement with 245 bbls of 10.3 ppg mud. Bump the plug at 4206 strokes and pressure up to r .bleed off the pressure to check the floats. Floats held. Then pressure up 2500 psi to set the zxp acker C~3 3022'. Then we pressured up to 3500 psi to release the runnin tool and ick u 7'.. To confirm the setting o the packer and hanger we set down 65k and then pressured up to 1000 psi and unstung. Circulated a bottoms up to clean out the cement to surface (2bbls) at 490 gpm ~ 1730 psi. Cement in place at 14:00. 15:00 - 16:00 1.00 CEMT P LNR1 Circulate a bottoms up at 420 gpm ~ 1300 psi. -Up Wt. 171 k /Down Wt. 171 k 16:00 - 18:30 2.50 CASE P LNR1 Trip out of the hole from 3022' to 0'. Flush out the BOP stack to clear any cement. 18:30 - 22:00 3.50 CASE P PROD1 Chanoe out the rams from 7" to 3.5 x 6" Variables. Then test 3.5 x 6" and 2 .875 x 5" rams a ainst a 4" and 4.5" test 'oint both test to 250 psi low / 3500 psi high. Good Tests 22:00 - 00:00 2.00 DRILL P PROD1 Pick up 6.125" BHA to 101' and upload the MWD. 12/14/2008 00:00 - 06:30 6.50 DRILL P PROD1 Continue making up production BHA. After making up the XO we shallow tested the MWD. Good Test. Make up the flex collars, load the radioactive sources, RIH to 8562'. 06:30 - 08:30 2.00 DRILL P PROD1 Cut and slip drilling 96' of drilling line. Service the top drive and draw works. 08:30 - 09:00 0.50 DRILL P PROD1 Wash down from 8562' to 8748'. 09:00 - 10:00 1.00 DRILL P PROD1 Pressure test the casin to 3500 si for 30 minutes and chart. Good Test 10:00 - 12:00 2.00 DRILL P PROD1 Continue to wash down to the landing collar ~ 8755' and begin Printed: izisoizuua iz:~osa rnn • BP EXPLORATION Page 7 of 9 Operations Summary Report Legal Well Name: 01-34 Common Well Name: 01-34 Spud Date: 6/28/1986 Event Name: REENTER+COMPLETE Start: 12/2/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/19/2008 Rig Name: NABORS 2ES Rig Number: Date From - To Hours ~ Task Code NPT Phase Description of Operations 12/14/2008 10:00 - 12:00 2.00 DRILL P PROD1 to drill up the shoe track to 8820'. -Up Wt. 165k /Down 140k /ROT 155k -TO 4k On / 3k Off -3500 psi ~ 270 gpm 12:00 - 14:00 2.00 DRILL P PROD1 Displace 10.3 ppg LSND to 8.4 ppg Flo-Pro. Pump a 50bb1 water spaceer, chased by a 40 bbls Hi-Vis sweep, then Flo Pro Mud. -270 gpm C~ 1600 psi 14:00 - 14:30 0.50 DRILL P PROD1 Drill out the float shoe ~ 8834' and 20' of new hole to 8854'. 14:30 - 15:30 1.00 DRILL P PROD1 Circulate a bottoms up for formation samples. -60 rpm -TO 2k -274 gpm ~ 1700 psi 15:30 - 16:00 0.50 DRILL P PROD1 Perform a FIT Test to 963 psi. Mud Wt. 8.4 ppg. EMW 10.5 PP9 . 16:00 - 00:00 8.00 DRILL P PRODi Directionally drill ahead from 8854' to 9284'. -RPM 100 / TO 3k off / TO 4k on -WOB 5-15k -280 gpm C~? 1650 psi off / 1850 on -Up Wt. 165k /Down Wt. 155k /ROT 165k 12/15/2008 00:00 - 03:30 3.50 DRILL P PROD1 Continue to drill ahead from 9284' to 9472' ~ -Up Wt. 170k /Down Wt. 157k /Rot Wt. 165k -TO 3k on / 3-4k Off -279 gpm ~ 1700 psi off / 1850 psi on 03:30 - 06:00 2.50 DRILL P PROD1 Circulate a bottoms up to collect samples for the geologist. led at 9472' MD / 9227' TVD. 06:00 - 10:00 4.00 DRILL P PROD1 Begin to MAD pass from 9472' to the shoe ~ 8835'. Logging speed 325 fph. 280 gpm ~ 1700 psi. 100 rpm rotary. 10:00 - 11:00 1.00 DRILL P PROD1 Drop ball & open Circ sub. Circ casing clean at 500 gpm. Monitor well. Pump dry job. 11:00 - 13:30 2.50 DRILL P PRODi POH to 7" liner top at 3022'. 13:30 - 14:00 0.50 DRILL P PRODi Circ to clean off 7" liner top - 550 gpm X700 psi. 14:00 - 15:00 1.00 DRILL P PROD1 Continue POH to BHA. 15:00 - 17:30 2.50 DRILL P PROD1 LD BHA. Remove nuke source. Download MWD. Clear floor. 17:30 - 00:00 6.50 DRILL N WAIT PROD1 Phase 2 weather conditions worsening to phase 3 by 18:00 hrs. Shut down and WOW. Monitor well. Fuel & water OK. All personnel accounted for. 12/16/2008 00:00 - 06:00 6.00 CASE N WAIT RUNPRD Continue waiting on weather. Phase 2 on Spine Road called at 02:00. Start getting crews swapped out to re-commence operations. 06:00 - 07:30 1.50 CASE P RUNPRD PJSM. Rig up to run 4-1/2" production liner. 07:30 - 11:00 3.50 CASE P RUNPRD PJSM. Run 834' of 4-1/2". 12.6#, 13Cr-80, Vam Top liner. Average torque 4440 fUlbs. Liner weight 35k. 11:00 - 11:30 0.50 CASE P RUNPRD PJSM. Rig down liner running tools. Clear and clean floor. 11:30 - 12:00 0.50 CASE P RUNPRD Pick up 1 stand of drill pipe and circulate 1 liner volume, 13 bbls. 12:00 - 17:30 5.50 CASE P RUNPRD RIH with 4-1/2" liner to 8834' filling every 20 stands. Up weight 160k, down weight 150k. 17:30 - 18:30 1.00 CASE P RUNPRD Stage pumps up to 5 bpm with 675 psi and 30% flow. Pump one annular volume of 300 bbls. 18:30 - 20:30 2.00 CASE P RUNPRD RIH to 9452'. PU/MU cement head and DP single. Run in and P~nl6tl: 1"1J90/'LOOtl 12:334 YM • • BP EXPLORATION Operations Summary Report Page 8 of 9 Legal Well Name: 01-34 Common Well Name: 01-34 Spud Date: 6/28/1986 Event Name: REENTER+COMPLETE Start: 12/2/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/19/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/16/2008 18:30 - 20:30 2.00 CASE P RUNPRD to at 9472'. Strap and mark pipe for setting 2' off bottom. Stage pumps up to 5 bpm with 850 psi and 32% flow. Reciprocate pipe with 12' stroke. Hold pre-job safety meeting with all personnel while batch mixing cement and Mud Push. Pump a total of 267 bbls with final pressure before swapping to cementers at 820 psi. 20:30 - 22:00 1.50 CEMT P RUNPRD Pump 10 bbls of 12.0 ppg Mud Push II. Reciprocate pipe. 20:34-Pressure test lines to 4500 psi. 20:40-Pump remaining 3 bbls of Mud Push II. Reciprocate pipe. 20:41-Start pumping 15.8 ppg Tail Slurry. Stage pumps up to 4 bpm with 550 psi. Reciprocate pipe. 20:48-Finish pumping 25 bbls of cement with 211 qsi: Swap over to rig pumps. 21:00-Continue to reciprocate pipe. Clear lines, drop plug and chase with 30 bbl pert pill. Swap over and displace with 8.5 ppg mud. Latch up at 85.7 bbls with 2000 psi. Stop reciprocation and park pipe 2' off bottom at 9470'. Bump plug with 97 bbls and bring pressure up to 4100 psi to set hanger. CIP at 21:15 with liner top at 8646'. Slack off 60k. Bleed off and check floats - OK. PU to 145k and rotate 15 turns to the right to release from hanger. PU string weight to 165k. Pressure up to 700 psi. Pull up 10' and pump 20 bbls at 2-3 bpm. Slow to 1 bpm and slack off 50k to weight set packer. PU and start rotation at 5 rpm. Slack off again to 50k for packer set verification. Mark for no-go, pull up and kick pumps back up. 22:00 - 22:30 0.50 CEMT P RUNPRD Circulate out cement at 550 gpm with 2200 psi with 8 bbls back to surface. 22:30 - 23:00 0.50 CEMT P RUNPRD Lay down cement head and 2 drill pipe singles. 23:00 - 00:00 1.00 CEMT P RUNPRD Displace to seawater at 550 gpm with 2300 psi. MW in 8.4 ppg, MW out 8.4 ppg Monitor well, well static 12/17/2008 00:00 - 02:00 2.00 CEMT P RUNPRD PJSM. Pump dry job. Blow down. Lay down 4" DP to 7281'. 02:00 - 04:30 2.50 CEMT N SFAL RUNPRD PJSM. Connection on 4" drill pipe became tight. Box end egged and gouged. Would not come loose. Held safety meeting with crew, Toolpusher, Welder and WSL. Proceeded to cut 4" DP above pin end. 04:30 - 11:30 7.00 CEMT P RUNPRD Continue to POOH laying down drill pipe. Lay down running tool and verify packer set. Run in stands from derrick and POOH laying down. 11:30 - 13:30 2.00 CEMT P RUNPRD PJSM. Pull wear ring. Rig up for casing test. Test casing and liner top packer to 3500 psi for 30 minutes and record on chart. Lost 28 psi in the first 15 minutes and 7 psi in the second 15 minutes -PASS. Rig down test equipment. 13:30 - 16:30 3.00 BUNCO RUNCMP PJSM. Rig up torque turn, compensator, long bales and associated completion running equipment. Make dummy run with hanger - OK. 16:30 - 18:00 1.50 BUNCO RREP RUNCMP Repair stabbing board motor. Leaking at by-pass. 18:00 - 00:00 6.00 BUNCO RUNCMP PJSM. Run 4-1/2". 12.6#. 13Cr-80. Vam Too completion tubing to 4761'. Up weight 80k, down weight 80k. Torque to 4440 Nnnted: iU~ui[uuts t~::ts:~a rnn BP EXPLORATION Operations Summary Report Legal Well Name: 01-34 Common Well Name: 01-34 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date From - To Hours .Task Code NPT 12/17/2008 18:00 - 00:00 6.00 BUNCO 12/18/2008 00:00 - 05:00 5.00 BUNCO 05:00 - 07:30 I 2.501 RUN 07:30 - 10:30 3.001 RU 10:30 - 13:30 I 3.00 13:30 - 14:00 0.50 BUNCO 14:00 - 15:00 1.00 BOPSU P 15:00 - 17:30 2.50 WHSUR P 17:30 - 18:30 1.00 WHSUR P 18:30 - 19:30 1.00 WHSUR P 19:30 - 00:00 4.50 WHSUR P 12/19/2008 00:00 - 01:30 1.50 WHSUR P 01:30 - 02:30 1.00 WHSUR P 02:30 - 04:00 I 1.501 RIGD I P Start: 12/2/2008 Rig Release: 12/19/2008 Rig Number: Page 9 of 9 ~ Spud Date: 6/28/1986 End: Phase Description of Operations RUNCMP ft/Ibs. RUNCMP PJSM. Run 4-1/2", 12.6#, 13Cr-80, Vam Top completion tubing. RUNCMP PJSM. Space out completion string. MU pup joints. Land hanger at 8657'. Run in lock down screws. Up weight 123k, down 120k. RUNCMP PJSM. Reverse circulate 130 bbls clean seawater followed by 95 bbls seawater with corrosion inhibitor. Displace with 175 bbls clean seawater. Pump at max rate of 3 bpm. RUNCMP PJSM. Drop ball and rod. Pressure up on tubing to 3500 psi. Packer set at 2100 si. Hold 3500 si for 30 minutes. Lost 15 si first 15 minutes, 0 si second 15 minutes -PASS. Bleed tubina to 2000 psi. Pressure up on annulus to 3500 psi and_, 15 minutes -PASS. eed off annulus pressure then bleed on tubing pressure. Pressure up on annulus and shear DCK valve at 2900 psi. Pump down annulus with 1500 psi indicating some restriction. Pump down tubing with 300 psi. Pump down annulus again with 500 psi. RUNCMP Dry rod TWC. Test from above and below to 1000 psi and hold RUNCMP PJSM. Nipple down BOP stack. Lay down mousehole and riser. Remove turnbuckles and set stack back. RUNCMP NU tree and adapter flange. RUNCMP PJSM. Test tree and adapter flange to 5000 psi for 30 minutes - OK. RUNCMP PJSM. Ri u DSM lubricator. Test to 1000 si. Pull TWC. RD. RUNCMP PJSM. Rig up LRS. Reverse circulate 155 bbls of 80 degree diesel for freeze protect at 2 bpm with 1300 psi. Shut down and rig up to U-tube. Allow to U-tube. RUNCMP PJSM. Finish U-tubing diesel freeze protect to 2256'. RUNCMP PJSM. Ri u DSM lubricator and test to 1000 i - in BPV. Test from below to 1000 psi with little red services - OK. Rig down DSM. RUNCMP Secure well with flanges, bull plugs with needle valves and pressure gauges. Confirm valves are closed. Suck out cellar and clean up. at Printed: 12/30/2008 12:35:34 PM 01-34A, Well History (Post Rig Sidetrack) Date Summary 12/25/08 WELL SHUT IN ON ARRIVAL. PULL BALL ROD FROM 8621' SLM (_644' MD . PULL ST# 5 BEK- DCK 3,470' SLM (3,500' MD). PULL ST# 4 BK-DGLV 5,522' SLM (5,538' MD). SET STA # 5 BK-LGLV 3,470' SLM (3,500' MD). 12/26/08 SET ST #4 BK-OGLV (20/64 PORTS) C~1 5522' SLM (5538' MD). PULLED 4-1/2" RHC PLUG BODY C~3 8625' SLM (8644' MD).=,DRIFT W/ 3.50" CENT., S-BAILER, TAG HARD BOTTOM C~ 9270' SLM, S- BAILER EMPTY. WELL LEFT S/I ON DEPARTURE. 01/09/09 WELL S/I ON ARRIVAL. TAGGED HARD BTM C~3 9.373' SLM W/ 3.375" x 10' DMY GUN, S-BLR (sample of cement). WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. 01/17/09 ON LOCATION, WELL SHUT IN AT WING, SWAB SHUT, IA/OA OPEN TO GAUGES. INITIAL T/I/O: 600/0/0 PSI. RIG UP ELINE FOR DRIFT RUN. ELINE BECAME STUCK AT 9300'. PULLED FREE WITH 300 LBS OVERPULL. ELINE POOH. ENTIRE TOOL STRING HAD CEMENT SLUDGE~D HARD CHUNKS ON IT. TAKING SLICKLINE TO CLEAN OUT WELL PRIOR TO ELINE RIH WITH GUNS. FINAL T/I/O: 500/0/0 PSI. WELL LEFT SHUT IN. NOTIFIED DSO. JOB ATTEMPTED AND NOT COMPLETE. 01/20/09 WELL S/I ON ARRIVAL. DRIFTED W/ 4 1/2" BRUSH, AND 3.70 GAUGE RING TO 9373' SLM. MADE MULTIPLE RUNS W/ 10' x 3.5" BAILER TO 9,374' SLM. RECOVERED 5 GAL, CEMENT/ HYDRATES. TUBING CLEAR DOWN TO 9.374' SLM.. 24' KB/BF CORK = 9,350' MD. 01/21/09 RAN 10' x 3" P. BAILER TO 9,374' SLM. RECOVERED 2.5 GAL CEMENT. RIG DOWN SLICKLINE UNIT. LEFT WELL S/I, NOTIFY DSO ON DEPARTURE. 01/24/09 WELL SHUT-IN ON ARRIVAL. (E-LINE DRIFT AND PERFORATIONS). INITIAL T/I/O = 650/0/0. RIH WITH 20' 3 3/8" DUMMY GUN. MAX OD = 3.65", LENGTH = 31'. TAG TD AT 9385', PULL GR / CCL JEWELRY LOG FROM TD TO BOTTOM GLM AT 8390'. OVERPULLED 300# ON 1ST PULL OFF BOTTOM. OVERPULL DECREASED ON SUBSEQUENT TAGS. CONTINUED TO TAG BOTTOM UNTIL PICK UP WAS CLEAN FOR DEPTH CONTROL. JEWELRY LOG CORRELATED TO HALLIBURTON LWD DATED 16 DEC 08. 01/25/09 ~ PERFORATED 9310'-9320' AND 9265' - 9280'_WITH 3-3/8" POWER JET 3406 HMX, 6 SPF, 60 DEG PHASING. API DATA: PEN = 36.5", EH = 0.37", EXPL. LOAD = 22.7 G/CHG. PERFORATIONS CORRELATED TO SLB JEWELRY LOG DATED 24 JAN 09. JEWELRY LOG CORRELATED TO REFERENCE LOG HALLIBURTON LWD DATED 16 DEC 08. NO DEPTH OFFSET BETWEEN CORRELATION LOG AND REFERENCE LOG. WELL LEFT SHUT IN. ALL VALVES RETURNED TO NORMAL. FINAL T/I/O = 0/0/0 PSI. JOB COMPLETE. Page 1 of 1 perry Drilling Services Survey Report :Company: BP Amoco Dater 12/27/2008 Time: 12:50:03 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 01-34, True N orth ~ Site: PB DS 01 Vertical (TVD) Reference: 01-34A 67.7 I Well: 01-34 Section (VS) Reference: Well (O.OON,O.OOE,152.68Azi) Wellpath: 01-34A Survey'CalculationMethod: Minimum Curvature Db: Oracle Survey -- -- MD Incl Azim TVD Sys TVll - -- N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 28.50 0.00 0.00 28.50 -39.20 0.00 0.00 5939617.00 698915.00 TIE LINE 97.70 0.30 167.11 97.70 30.00 -0.18 0.04 5939616.83 698915.05 BOSS-GYRO 197.70 0.22 186.89 197.70 130.00 -0.62 0.08 5939616.38 698915.09 BOSS-GYRO 297.70 0.22 143.40 297.70 230.00 -0.97 0.17 5939616.04 698915.19 BOSS-GYRO 397.70 0.38 152.20 397.70 330.00 -1.41 0.44 5939615.60 698915.47 BOSS-GYRO 497.70 0.28 132.20 497.69 429.99 -1.87 0.77 5939615.15 698915.82 BOSS-GYRO 597.70 0.30 137.20 597.69 529.99 -2.23 1.13 5939614.80 698916.19 BOSS-GYRO 697.70 0.38 125.40 697.69 629.99 -2.61 1.58 5939614.43 698916.65 BOSS-GYRO 797.70 0.40 134.00 797.69 729.99 -3.05 2.10 5939614.01 698917.18 BOSS-GYRO 897.70 0.43 134.31 897.69 829.99 -3.55 2.62 5939613.52 698917.71 BOSS-GYRO 997.70 0.37 133.11 997.68 929.98 -4.03 3.12 5939613.05 698918.23 BOSS-GYRO 1097.70 0.50 130.70 1097.68 1029.98 -4.54 3.69 5939612.56 698918.81 BOSS-GYRO 1197.70 0.25 149.90 1197.68 1129.98 -5.01 4.13 5939612.10 698919.26 BOSS-GYRO 1297.70 0.17 141.11 1297.68 1229.98 -5.32 4.33 5939611.80 698919.47 BOSS-GYRO 1397.70 0.22 119.70 1397.68 1329.98 -5.53 4.59 5939611.60 698919.74 BOSS-GYRO 1497.70 0.25 102.00 1497.68 1429.98 -5.67 4.97 5939611.47 698920.12 BOSS-GYRO 1597.70 0.32 105.70 1597.68 1529.98 -5.79 5.46 5939611.36 698920.61 BOSS-GYRO 1697.70 0.43 122.70 1697.67 1629.97 -6.07 6.04 5939611.10 698921.20 BOSS-GYRO 1797.70 0.65 130.00 1797.67 1729.97 -6.63 6.79 5939610.55 698921.96 BOSS-GYRO 1897.70 0.73 132.20 1897.66 1829.96 -7.43 7.70 5939609.78 698922.89 BOSS-GYRO 1997.70 0.57 119.31 1997.66 1929.96 -8.10 8.60 5939609.13 698923.81 BOSS-GYRO 2097.70 0.53 57.50 2097.65 2029.95 -8.09 9.43 5939609.16 698924.64 BOSS-GYRO 2197.70 0.45 40.30 2197.65 2129.95 -7.55 10.07 5939609.72 698925.27 BOSS-GYRO 2297.70 0.17 64.50 2297.65 2229.95 -7.18 10.46 5939610.10 698925.65 BOSS-GYRO 2397.70 0.20 206.00 2397.65 2329.95 -7.28 10.52 5939610.01 698925.70 BOSS-GYRO 2497.70 0.40 175.90 2497.65 2429.95 -7.78 10.46 5939609.50 698925.67 BOSS-GYRO 2498.00 0.40 175.90 2497.95 2430.25 -7.78 10.46 5939609.50 698925.67 13 3/8" 2597.70 0.40 138.81 2597.64 2529.94 -8.39 10.72 5939608.90 698925.94 BOSS-GYRO 2697.70 0.48 150.61 2697.64 2629.94 -9.02 11.15 5939608.28 698926.39 BOSS-GYRO Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2007 Well: 01-34 Slot Name: 34 5002921609 Well Position: +N/-S -2358.38 ft Northing: 5939617.00 ft Latitude: 70 14 20.708 N +E/-W 1616.33 ft Easting : 698915.00 ft Longitude: 148 23 37.022 W Position Uncertainty: 0.00 ft Wellpath: 01-34A 500292160901 Drilled From: Tie-on Depth: 01-34 7978.00 ft Current Datum: 01-34A Height 67.70 ft Above System Datum: Mean Sea Level Magnetic Data: 12/8/2008 Field Strength: 57693 nT Declination: Mag Dip Angle: 23.03 deg 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.50 0.00 0.00 152.68 Survey Program for Definitive Wellpath Date: 12/12/2008 Validated: Yes Version: 1 Actual From To Survey Toolcode Tool Name ft ft 97.70 7897.70 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 7978.00 9472.00 01-34A MWD+SAG+CA+IIFR+MS (797 MWD+IFR+MS MWD +IFR + Multi Station perry Drilling Services ~ Survey Report Company: BP Amoco Date:' 12/27/2008 Timc: 12:50:03 Page: 2 Field: Pru dhoe Bay Co-ord inate(NE) Reference: Well: 01-34, True North Site: PB DS 01 Vertica l (TVD) Refer ence: 01 -34A 67.7 Well: 01- 34 Section (VS) Referen ce: Well (O.OON,O.OOE,152.68Azi) i Wellpath: 01- 34A Survey Calculation M ethod: Minimum Curvatu re llb: Oracle Survev ---- MD Incl Azim - TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 2797.70 0.62 128.11 2797.64 2729.94 -9.72 11.79 5939607.60 698927.04 BOSS-GYRO 2897.70 0.90 144.00 2897.63 2829.93 -10.69 12.67 5939606.65 698927.95 BOSS-GYRO 2997.70 1.10 152.40 2997.61 2929.91 -12.17 13.58 5939605.19 698928.90 BOSS-GYRO 3097.70 1.03 150.31 3097.59 3029.89 -13.80 14.47 5939603.58 698929.83 BOSS-GYRO 3197.70 0.97 142.20 3197.58 3129.88 -15.25 15.43 5939602.16 698930.83 BOSS-GYRO 3297.70 1.27 135.90 3297.56 3229.86 -16.72 16.72 5939600.73 698932.16 BOSS-GYRO 3397.70 1.17 149.70 3397.54 3329.84 -18.40 18.01 5939599.09 698933.49 BOSS-GYRO 3497.70 1.00 155.31 3497.52. 3429.82 -20.07 18.89 5939597.44 698934.41 BOSS-GYRO 3597.70 0.92 159.20 3597.51 3529.81 -21.61 19.54 5939595.91 698935.10 BOSS-GYRO 3697.70 0.82 159.70 3697.49 3629.79 -23.04 20.07 5939594.50 698935.67 BOSS-GYRO 3797.70 0.75 169.40 3797.48 3729.78 -24.35 20.44 5939593.20 698936.08 BOSS-GYRO 3897.70 0.60 195.39 3897.48 3829.78 -25.50 20.42 5939592.05 698936.09 BOSS-GYRO 3997.70 0.57 191.80 3997.47 3929.77 -26.49 20.18 5939591.05 698935.87 BOSS-GYRO 4097.70 0.50 201.00 4097.47 4029.77 -27.38 19.92 5939590.15 698935.64 BOSS-GYRO 4197.70 0.75 217.10 4197.46 4129.76 -28.31 19.37 5939589.21 698935.11 BOSS-GYRO 4297.70 0.78 210.10 4297.45 4229.75 -29.42 18.64 5939588.08 698934.41 BOSS-GYRO 4397.70 0.85 204.19 4397.44 4329.74 -30.69 17.99 5939586.80 698933.79 BOSS-GYRO 4497.70 3.22 156.50 4497.38 4429.68 -33.94 18.81 5939583.57 698934.70 BOSS-GYRO 4547.70 4.37 152.50 4547.27 4479.57 -36.92 20.25 5939580.63 698936.21 BOSS-GYRO 4597.70 4.78 152.00 4597.11 4529.41 -40.45 22.10 5939577.15 698938.16 BOSS-GYRO 4697.70 7.05 150.00 4696.57 4628.87 -49.44 27.13 5939568.29 698943.42 BOSS-GYRO 4797.70 9.37 144.81 4795.54 4727.84 -61.41 34.89 5939556.53 698951.50 BOSS-GYRO 4897.70 10.92 141.40 4893.97 4826.27 -75.47 45.49 5939542.76 698962.47 BOSS-GYRO 4997.70 12.92 140.61 4991.81 4924.11 -91.51 58.50 5939527.07 698975.89 BOSS-GYRO 5097.70 14.60 141.20 5088.94 5021.24 -109.98 73.49 5939509.01 698991.36 BOSS-GYRO 5197.70 18.70 139.11 5184.73 5117.03 -131.93 91.89 5939487.55 699010.33 BOSS-GYRO 5297.70 19.95 139.40 5279.09 5211.39 -157.00 113.49 5939463.06 699032.58 BOSS-GYRO 5397.70 22.12 139.70 5372.42 5304.72 -184.32 136.77 5939436.37 699056.58 BOSS-GYRO 5497.70 22.72 139.50 5464.86 5397.16 -213.36 161.49 5939407.99 699082.05 BOSS-GYRO 5597.70 22.62 139.61 5557.14 5489.44 -242.69 186.49 5939379.33 699107.82 BOSS-GYRO 5697.70 22.62 139.50 5649.44 5581.74 -271.96 211.44 5939350.73 699133.53 BOSS-GYRO 5797.70 22.83 139.70 5741.68 5673.98 -301.38 236.48 5939321.98 699159.34 BOSS-GYRO 5897.70 23.22 140.00 5833.71 5766.01 -331.28 261.70 5939292.76 699185.33 BOSS-GYRO 5997.70 22.80 140.31 5925.76 5858.06 -361.29 286.74 5939263.42 699211.16 BOSS-GYRO 6097.70 22.92 140.31 6017.90 5950.20 -391.18 311.55 5939234.20 699236.75 BOSS-GYRO 6197.70 22.52 140.61 6110.14 6042.44 -420.97 336.14 5939205.07 699262.11 BOSS-GYRO 6297.70 22.18 141.11 6202.63 6134.93 -450.46 360.14 5939176.22 699286.89 BOSS-GYRO 6397.70 21.85 141.31 6295.34 6227.64 -479.68 383.63 5939147.64 699311.13 BOSS-GYRO 6497.70 21.92 141.50 6388.13 6320.43 -508.81 406.88 5939119.13 699335.14 BOSS-GYRO 6597.70 21.60 141.31 6481.01 6413.31 -537.78 430.01 5939090.78 699359.02 BOSS-GYRO 6697.70 21.12 141.00 6574.14 6506.44 -566.15 452.85 5939063.02 699382.61 BOSS-GYRO 6797.70 20.80 140.50 6667.52 6599.82 -593.85 475.48 5939035.93 699405.96 BOSS-GYRO 6897.70 20.38 140.90 6761.13 6693.43 -621.07 497.76 5939009.32 699428.94 BOSS-GYRO 6997.70 20.13 141.11 6854.95 6787.25 -647.97 519.54 5938982.99 699451.43 BOSS-GYRO 7097.70 19.85 141.50 6948.92 6881.22 -674.65 540.91 5938956.89 699473.50 BOSS-GYRO 7197.70 19.50 142.70 7043.09 6975.39 -701.22 561.60 5938930.88 699494.87 BOSS-GYRO 7297.70 18.57 143.90 7137.62 7069.92 -727.36 581.09 5938905.26 699515.05 BOSS-GYRO 7397.70 17.97 145.00 7232.58 7164.88 -752.86 599.32 5938880.25 699533.95 BOSS-GYRO 7497.70 18.32 146.70 7327.60 7259.90 -778.64 616.80 5938854.95 699552.10 BOSS-GYRO 7597.70 19.38 148.50 7422.24 7354.54 -805.92 634.10 5938828.14 699570.11 BOSS-GYRO 7697.70 20.82 149.90 7516.15 7448.45 -835.44 651.68 5938799.09 699588.46 BOSS-GYRO 7797.70 22.35 150.70 7609.13 7541.43 -867.40 669.90 5938767.62 699607.52 BOSS-GYRO perry Drilling Services Survey Report Compauy: BP AmoCO Field: Prudhoe Bay Site: PB DS 01 Nell: 01-34 ~Vellpath: 01-34A Date: 12/27/2008 Time: 12:50:03 Page: 3 ~I Co-ordinate(NE) Kcference: Well: 01-34, True North Vertical (TVD) Reference: 01-34A 67.7 Section (VS) Reference: Well (O.OON,O.OOE,152.68Azi) 'i Survey Calculation Method: Minimum Curvature llb: Oracle ___ _ _- Survcv __ _ _ _-- ' ~ Mll Incl - Azim - TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 7897.70 23.50 151.90 7701.23 7633.53 -901.57 688.60 5938733.96 699627.11 BOSS-GYRO 7978.00 24.72 153.21 7774.53 7706.83 -930.68 703.71 5938705.26 699642.98 MWD+IFR+MS 8058.84 23.10 161.50 7848.45 7780.75 -960.82 716.36 5938675.47 699656.42 MWD+IFR+MS 8090.32 22.16 165.03 7877.51 7809.81 -972.41 719.85 5938663.97 699660.22 MWD+IFR+MS 8110.53 21.99 167.40 7896.23 7828.53 -979.79 721.66 5938656.65 699662.22 MWD+IFR+MS 8129.74 21.64 169.70 7914.07 7846.37 -986.78 723.08 5938649.69 699663.83 MWD+IFR+MS 8223.72 17.94 179.46 8002.51 7934.81 -1018.33 726.32 5938618.25 699667.89 MWD+IFR+MS 8252.85 16.61 175.34 8030.32 7962.62 -1026.96 726.70 5938609.62 699668.50 MWD+IFR+MS 8285.94 15.66 172.50 8062.11 7994.41 -1036.10 727.67 5938600.51 699669.71 MWD+IFR+MS 8317.45 15.15 172.29 8092.49 8024.79 -1044.40 728.77 5938592.25 699671.04 MWD+IFR+MS 8348.66 13.71 172.40 8122.71 8055.01 -1052.11 729.81 5938584.57 699672.27 MWD+IFR+MS 8410.02 11.23 176.23 8182.62 8114.92 -1065.28 731.17 5938571.44 699673.98 MWD+IFR+MS 8457.40 9.85 183.82 8229.20 8161.50 -1073.93 731.20 5938562.80 699674.24 MWD+IFR+MS 8503.72 9.04 191.53 8274.90 8207.20 -1081.45 730.21 5938555.25 699673.45 MWD+IFR+MS 8549.96 8.44 200.60 8320.60 8252.90 -1088.18 728.29 5938548.47 699671.70 MWD+IFR+MS 8596.16 8.04 211.69 8366.33 8298.63 -1094.11 725.40 5938542.47 699668.97 MWD+IFR+MS 8644.62 7.75 225.72 8414.33 8346.63 -1099.27 721.28 5938537.20 699664.99 MWD+IFR+MS 8691.40 8.38 239.23 8460.65 8392.95 -1103.22 716.09 5938533.12 699659.91 MWD+IFR+MS 8719.79 8.77 249.06 8488.73 8421.03 -1105.05 712.29 5938531.19 699656.16 MWD+IFR+MS 8752.71 9.40 258.73 8521.24 8453.54 -1106.47 707.31 5938529.63 699651.22 MWD+IFR+MS 8782.85 10.18 266.46 8550.94 8483.24 -1107.12 702.24 5938528.86 699646.16 MWD+IFR+MS 8800.00 10.40 268.55 8567.81 8500.11 -1107.25 699.18 5938528.64 699643.11 9 5/8" 8833.46 10.85 272.38 8600.70 8533.00 -1107.20 693.01 5938528.53 699636.94 7" 8852.20 11.13 274.38 8619.10 8551.40 -1106.99 689.45 5938528.65 699633.37 MWD+IFR+MS 8896.67 10.88 274.12 8662.75 8595.05 -1106.36 680.98 5938529.06 699624.89 MWD+IFR+MS 8990.99 10.29 274.87 8755.46 8687.76 -1105.00 663.71 5938529.95 699607.59 MWD+IFR+MS 9084.05 10.27 275.84 8847.03 8779.33 -1103.45 647.17 5938531.07 699591.02 MWD+IFR+MS 9176.87 11.28 270.09 8938.21 8870.51 -1102.60 629.86 5938531.47 699573.70 MWD+IFR+MS 9270.22 11.93 267.42 9029.66 8961.96 -1103.02 611.09 5938530.55 699554.95 MWD+IFR+MS 9363.87 11.61 268.35 9121.34 9053.64 -1103.72 592.00 5938529.34 699535.89 MWD+IFR+MS 9435.95 11.44 268.87 9191.96 9124.26 -1104.07 577.61 5938528.61 699521.50 MWD+IFR+MS 9472.00 11.44 268.87 9227.30 9159.60 -1104.21 570.46 5938528.28 699514.36 MWD+IFR+MS TREE = 4118" CMJ WELLHEAD= .. FMC ACTUATOR - KB. ELEV = 67.7' SF. ELEV = ,~, 1COP = 4900" Max Angfe = 26 ~ 8100' Datum MD = 9172' Datum TV D = 8800' SS 13-3/8"CSG, 72#, K-55, ID = 12.347" 30' 13-3/8"CSG, 72#, L-80, ID = 12.347" 2501' 7" x 9-5I8" Liner lap ZXP Paoker w! PBR 3022' Cretaceous PC Leak ~~ 5650'~~ Stub ~-{ 8100' 4-112"' TBG, 12.6#, 13Cr, .0152 bpf, ID = 3.958" ~--( 86x7' Minimum 10 = 3.?25" 86A•4' 4-112" HES XN NIPPLE PERFORATION SUMMARY Rt=F LOG: SPERRY LWD ON 12/16/2008 ANGLE. AT TOP PERT: 12° ~ 9265 MD Nate: Refer to Prodr~ction DB for histancal rFdafa SIZE SPF INTERVAL OpNSgz DATE 3-318" 6 9265 - 9280 O 01125109 3-3f8"' 6 9310 -9320 O 01125109 9-518" CSG,. 47#, L-80, ID = 8.681" (--I 9554' 2179' ~ X' Nipple, ID = 3.813" GAS LIFE MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3500 3500 1 KBG2 DOME BK 16 12/26/08 4 5538 5502 23 KBG2 SO BK 20 12/26/08 3 6823 6691 21 KBG2 DMY BK 0 12/17/08 2 7688 7507 21 KBG2 DMY BK 0 12/17/08 1 8471 8243 10 KBG2 DMY BK 0 12/17/08 MILL WINDOW (01-34A) 7978' - 7992' 8549-~ X° t~pp~, 1~3 813" I 8580' 7"' x 4-i/2`" 53 PKf~ $5'13' X' Npp~, 1D=3.813" $544' XN 1~6pple;lD = 3.725. 8646' 865T 4-112" Liner lop wLEG $834' 7" L-80, 26#. ~'3=6,276'. 93$9' PBTD 470' 4-1/2", 13Cr, 12.6#, ID-3.958 DATE REV BY COMMENTS DALE REV SY COMMENTS 0711118fi C)RIGINAL Cl3MPLflwflpN 02/03'09 .iKD/SV PERFS (0112`,~f09) 0'!114187 WGf~ICAVER 12114102 [)AG1KtC RIG Wt?RKOVER 02116101 TP CORRECTIONS 12119148 N2ES SIDETRACK 0134A 12/28108 (ILH GORRECTIQNS & GLV C/O PRUDHOE BAY :UNIT V11ELL: 01-34A F'ERMff Na: X2081250 API Na: 50029-219-01 SEC 8, T10N, R15, 2401' FEL 1 1312` FSL BP Expforattpn{Alaska) • HALLIBURTON Drilling and Formation Evaluation State of Alaska AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 t°~~ ~,'~ ~~, .,~iv Re: Distribution of Survey Data for Well 01-34A Dear Christine Mahnken 10-Feb-09 Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 7,897.70' MD Window /Kickoff Survey 7,978.00' MD (if applicable) Projected Survey: 9,472.00' MD Please acknowledge receipt by signing and returning a copy of this transmittal letter to ... BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 Date !1l ~~ a~..~~{ Signed (An a-mail confirmation, citing the well, to James.Durand@Halliburton.com would be an additional courtesy.) Please call me at 273-3537 if you have any questions or concerns. Thank you Jim Durand Survey Manager Attachment(s) • ~v~ ~ ~~~ 1-34A Leak Off Test ~ • Page 1 of 2 Maunder, Thomas E {DOA} From: Mallery, Joshua [Joshua.Mallery@BP.com] Sent: Tuesday, December 09, 2008 6:42 AM To: Maunder, Thomas E (DOA) Cc: NSU, ADW Dr1g Rig 2es; Hobbs, Greg S (ANC) Subject: RE: 1-34A (208-125) Leak Off Test Tom, Greg and I spoke about the questions you brought up. Our kick tolerance at the window with a 10.9 EMW is infinite. We are comfortable with this result. Thanks for agreeing with us on the lack of need to test at the window. Currently we are milling our window and preparing to drill out. Please call with any further questions. Thanks, Joshua Mallery 907.564.5545 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, December 08, 2008 6:11 PM To: Mallery, Joshua Cc: NSU, ADW Drlg Rig 2es; Hobbs, Greg S (ANC) Subject: RE: 1-34A (208-125) Leak Off Test Josh, I would agree that it is unlikely that any higher EMW would be developed at the presumed Cretaceous leak location. However, I calculate that 256 psi applied at the surface only results in 10.9 EMW at the window depth. How does that affect your kick tolerance? Are you in the hole now preparing to drill out? I will be unavailable for a couple of hours, but will call you ~ 9. Please apprise Greg of my questions. Tom Maunder, PE AOGCC From: Mallery, Joshua [mailto:Joshua.Mallery@BP.com] Sent: Monday, December 08, 2008 5:39 PM To: Maunder, Thomas E (DOA) Cc: NSU, ADW Drlg Rig 2es Subject: I-34A Leak Off Test Tom, As per our conversation on the phone, there is an 11.18 ppg leak off test for our cretaceous leak at 5,650' MD/ 5,605' TVD. The permit to drill states that after we mill our window at 8000' MD/~7795' TVD we wilt take an FIT to 12.5 ppg. Since the cretaceous leak will still be exposed, we intend this FIT to yield the same result as the previous test (11.18 ppg). 12/9/2008 1-34A Leak Off Test ~ • Page 2 of 2 Because, of the same intended results we will proceed ahead with out the FIT after milling our window. Attached is the Leak Off Test. «01-34A LOT 8~ FIT.xIs» Thank you, Joshua Mallery BPX (Alaska) GPB Drilling Engineer 907.564.5545 (OfFCe) 907.244.4351 (Cell) Joshua. Mallery@bp.com 12/9/2008 • • CASING AND LEAK-OFF FRACTURE TESTS Well Name: DS 1-34A Date: 1218/2008 Csg Size/Wt/Grade: 9 5/8" 47#, L-80 Supervisor: Decker Csg Setting Depth: 5,850 TMD 5,600 TVD Mud Weight: 10.3 ppg Leakoff pressure = 258 psi LOT= 11.18 ppg Hole Depth = N/A and Fluid Pumped= 3.2 Bbls Volume Back = 2.5 bbls Estimated Pump Output: 0.071 Barrels/Stroke LEAK-OFF DATA CASING TEST DATA Enter Strokes Enter Pressure Enter Strokes Enter Pressure Here Here Here Here a a a a a a a a a a a a a a a a a _> a a a a a a a 10 85 15 96 20 113 25 135 30 160 35 195 40 220 45 247 46 256 Enter lioltling tnter noising Time Here Pressure Here 1 240 2 230 3 220 4 210 5 200 6 200 7 200 8 195 9 190 10 180 a _> a a a a a a a a _> a a a a _> a a a a J a a a 10 700 15 950 20 1250 25 1500 30 1850 35 2200 40 2500 43 2750 Enter Holding Enter Holding Time Here Pressure Hen 5 2750 10 2750 15 2750 20 2725 25 2725 30 2725 • • 4000 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400 2300 2200 n 2100 m ~ 2000 m 1900 a` 1800 1700 1600 1500 1400 1300 120C 110C 1000 90C 80C 70( 60( 50( 40( 30( 201 101 L 0 216.51 ~I Strokes (# of) f-LEAK-OFF DATA CASING TEST DATA ~ ~ f-LEAK-OFF DATA -CASING TEST DATA 0 5 10 15 20 25 30 Time (Minutes) • • ~~~h~ In1 l1 IS ~U L~ !.'~J ~~Sl. i~; a)~Id l,'il ALASSA OIL A11TD GA.S COI~TSERQATIOI~T CO1~II~IISSI01~ Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 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 O 1-34A BP Exploration Alaska Inc. Permit No: 208-125 Surface Location: 1312' FNL, 1566' FWL, SEC. 08, T10N, R15E, UM Bottomhole Location: 2421' FNL, 2135' FWL, SEC. 08, T10N, R15E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to drill 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, J ~ Daniel T. Seamount, Jr. Chair DATED this ~ 3 day of August, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~ ` ~ ' ~"'-' ~~ ~/~GpB ~` ALAS~IL AND GAS CONSERVATION COMMI~ON ;~h. ~ 20Q$ PERMIT TO DRILL ~°'-~1~ 20 AAC 25.005 ~.s ;~T .. r~n:-,~ ~°~~,~~,,;,.,: ,s~~, 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas Service Multi le Zone ^ ^ P ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if we~ i~,~r~p~&~d for: °" " ^ Coalbed Me(~`ane ~'~as Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 01-34A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 9474' TVD 9228' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1312' FNL 1566' FWL SEC T10N R15E UM 08 7. Property Designation: ADL 028329 Pool , , , , . , Top of Productive Horizon: 2418' FNL, 2230' FWL, SEC. 08, T10N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: September 10, 2008 Total Depth: 2421' FNL, 2135' FWL, SEC. 08, T10N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 24,300' 4b. Location of Well (State Base Plane Coordinates): Surface: x-698915 y- 5939617 Zone-ASP4 10. KB Elevation Plan (Height above GL): 68.5' feet 15. Distance to Nearest Well Within Pool: 530' 16. Deviated Wells: Kickoff Depth: 8000 feet Maximum Hole An le: 25 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3257 Surface: 2377 18. Casin Pr ram: S ecificatia ns To - Settin De h -Bottom uanti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 IBT-M 5834' 3000' 3000' 8834' 8600' 287 sx LiteCrete 157 sx Class 'G' 6-1/8" 4-1/2" 12.6# 13Cr80 Vam To 790' 8684' 8452' 9474' 9229' 114 sx Class'G' 1 g, PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 9580' Total Depth TVD (ft): 9247' Plugs (measured): 8598' Effective Depth MD (ft): 9554' Effective Depth TVD (ft): 9223' Junk (measured): None Casing Length ,, . Size. Cement Volume MD TVD Conductor /Structural 110' 20" 110' 110' Surface 2501' 13-3/8" 2000 sx CS III 400 sx CS II TJ: 150 sx CS II 2501' 2501' Intermediate Production 9554' 9-5/8" 670 sx Class 'G' 300 sx CSI 9554' 9223' Liner Perforation Depth MD (ft): Below Plug: 9346' - 9378' Perforation Depth TVD (ft): 9031' - 9060' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ 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. Printed Name Gre ob Si nature . Contact Travis Peltier, 564-4511 Title Engineering Team Leader Prepared By Name/Number: Phone 564-4191 Date ~' ~ ~ Terrie Hubble, 564-4628 Commission Use On{ Permit To Drill Number:o?~dTfo~~ API Number: 50-029-21609-01-00 Permit Approval See cover letter for Date: other re uirements Conditions of Approval: r~ If box is checked, well may not be used to explore for, test, or produce coalbed me~th/ane, gas hydrates, or gas contained shales: I~I/ Samples Req'd: ^ yes L~J No Mud Log Req'd: ^ Yes LrJ No HZS Measures: Yes ^ No Directional Survey Req'd: [Yes ^ No Other: ~~~ PS t ~~~ ~ S~ ~ APPROVED BY THE COMMISSION ~~ Date ~ ~ ,COMMISSIONER Form 10-401 ~ Revised 12/x605 Submit In Uupl-cate . «_ 5 ~F~, ~uG ~ ~ 2ooa ~ Planned Well Summary~ Well 01-34A Well Producer Target Zone 2 T e Rota Sidetrack Ob'ective API Number: 50-029-21609-01 Current Status 01-34 is shut-in Estimated Start Date: 10-Se t-2008 Time to Com lete: 14.5 Da s Surface Northin Eastin Offsets TRS Location 5,939,617 698,915 1312' FSL / 2401' FEL 10N, 15E, 08 Target Northin Eastin TVDss Offsets TRS Location 5,938,529 699,611 8,650 2862' FSL / 3050' FEL 10N, 15E, 08 Bottom Northin Eastin TVDss Offsets TRS Location 5,938,523 699,516 9,160 2859' FSL / 3145' FEL 10N, 15E, 08 Planned KOP: 8000'MD / 7726'TVDss Planned TD: 9,474'MD / 9,160' TVDss Ri Nabors 2ES BFE: 44' RTE: 68.5' Directional -Sperry P08 Maximum Hole Angle: ~25° in the 8-1/2" intermediate section (C~ KOP) --11 ° in the 6-1/8" horizontal section Close A roach Wells: All wells pass major risk criteria for close approach. Surve Pro ram: MWD Standard + IFR /Cassandra / MS Nearest Pro ert Line: 24,300' to the PBU propert line Nearest Well within Pool: 01-34 is 530' away. Contacts Name Phone # E-mail Drilling Engineer Travis Peltier 564-4511 travis.geltier@bp.com Geologist Priya Maraj 564-4181 privai.maraj @bp.com Pad Engineer James Dean 564-4668 james.dean@bp.com 01-34A Permit to Drill Application Page 1 Formation Markers Ol-34A~sed on 50R) Commercial Hydrocarba Est. Pore Est. Pore Est. Formation To s Uncertain n Bearin Press. Press. UG4 -4650 20' no UG3 -4777 20' no UGl -5512 20' no WS2 -6054 20' no WSl -6320 20' no CM3 -6576 20' no CM2 -7051 20' no CMl -7780 20' no KOP @ 8000' MD THRZ -8140 20' no BHRZ -8333 20' no LCU -8368 20' no TJA -8436 20' no TSGR -8533 20' yes TSHA -8563 20' no TSAD -8639 20' yes 42SB -8764 20' yes 3260 si 7.1 TCGL -8815 20' no BCGL -8899 20' no 23SB -8980 20' es HOT -9000 20' es 21TS -9071 20' es 3260 si 6.9 TZ1B -9110 20' no Casina/Tubina Proaram Hole Csg / WtIFt Grade Conn Burst Collapse Length Top Bottom Size Tbg (psi) (psi) MD / MD / O.D. TVDrkb TVDrkb 8-'h" 7" 26# L-80 IBT-M 7,240 5,410 5,834' 3,000' / 3,000 8,834' / 8,600 6-1/8" 4'/z" 12.6# 13Cr- 80 Vam Top 160 10, 10,530 790° 8,684' / 8,452' 9,474' / 9,229' Tubing 4 ~/z" 12.6# 13Cr- 80 Vam Top 10,160 10,530 8,684' 0' / 0' 8,684' / 8,452 01-34A Permit to Drill Application Page 2 Mud Program Whi stock Millin Mud Pro erties: LSND Whip Stock Window 9-5/8", 47# Densit PV YP API FL HTHP FL MBT PH 10.2 -10.3 16 - 30 30 <8.0 N/C N/C 9.0 - 10 Intermediate Mud Pro erties: LSND 8-1/2" hole section Depth Interva Density (pp PV YP API FL HTHP FL MBT PH 8,000'-8,834' 10.2 - 10.3 15 - 25 26 - 30 4.0 - 6.0 <10.0 <15 9.0 - 10 Production Mud Pro erties: FLOPRO SF Reservoir Drill-in Fluid 6-1/8" hole section De th Interval Densi PV YP LSVR API FI H MBT 8,834'-9,474' 8.4 - 8.5 8 - 12 22 - 28 >20,000 6.0 - 8.0 9.0 - 9.5 < 3 Logging Program 8-1/2" Intermediate: Sample Catchers - as required by Geology Drilling: Dir/GR/Res/PWD Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - as required by Geology Drilling: PWD/Dir/GR/DenMeu/Res Open Hole: None Cased Hole: None Cement Proaram Casin Size: 7" 26#, L-80 Intermediate Liner Basis: Lead: 5106' of 7" x 9-5/8" annulus " annulus Lead TOC: 2,800' MD TOL + 200' DP x 9-5/8 Tail: 834' of open hole with 40% excess, plus 95' of 7" x 9-5/8" and 80' shoe track Tail TOC: 7,906' MD Total Cement Spacer 30 bbls of Viscosified Spacer weighted to 10.70 ppg (Mud Push) Volume: Lead 160.1 bbls, 900 ft , 287 sks, 11.0 LiteCrete + adds - 3.35 ft /sk Tail 32.4 bbls, 181.6 ft , 157 sks 15.8 Ib/ al Class G + adds - 1.16 ft /sk Tem BHST =186° F, BHCT TBD b Schlumber er Casin Size 4.5" 12.6#, L-80 Production Liner Basis: Lead: None Tail: 640' of open hole with 40% excess, 80' shoe track, 150' 4-'h" x 6-1 /8" liner lap, and 200' of 7" x 4" DP excess. Tail TOC: 8,484' MD 0200' above Liner Top) Total Cement Volume• Spacer 12 bbls of Viscosified Spacer weighted to 12.0 ppg (Mud Push) Lead None Tail 23.5 bbls, 133 ft , 114 sks 15.8 Ib/ al Class G + adds -1.17 ft /sk Tem BHST = 197° F, BHCT TBD b Schlumber er 01-34A Permit to Drill Application Page 3 Surface and Anti-Coll~on Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. At surface 01-09 is 60' to the north and 01-10 is 120' to the south are the centers. Close Approach Shut-in Wells: All wells pass major risk criteria. Hydrogen Sulfide DS-01 is designated as an H2S site. Recent H2S data from the pad is as follows: Date of Well Name H9S 1 evel Reading #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data (H2S alarms from rigs, etc.) 01-10 15 m 03/22/03 01-31 5 m 08/17/04 01-15A 10 m 05/13/06 01-26A 10 m 07/30/06 Ol-07A 140 m 04/25/01 DS 1 is a high level H2S drill site. Use extra caution while working. Faults The well path is not expected to intersect any mapped faults. The only faults in the vicinity of the planned well are located 650 feet to the north and 800 feet to the east. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP regular test frequency will be 14 days during drilling phase and 7 days during decompletion and surface casing work. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP 3257 si C~1 8800' TVDss 7.2 EMW Maximum surface ressure 2377 si .10 si/ft as radient to surface Kick tolerance 25.7 bbls with an 11.2 FIT assumin 9.6 reservoir and 4" drill i e Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin Test 3500 si surface ressure with RTTS at 3000' MD Inte rit Test - 8-1/2" hole 11.2 FIT from leak at 5250' in Production Casin Prnrlur_tinn Interval Maximum antici ated BHP 3257 si C~ 8800' TVDss 7.2 EMW Maximum surface ressure 2377 si .10 si/ft as radient to surface Kick tolerance Infinite with a 8.8 FIT Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin "Liner Test 3500 si surface ressure Inte rit Test - 6-1/8" hole 8.8 FIT after drillin 20' of new hole Planned com letion fluids 8.5 Seawater / 7.2 Diesel 01-34A Permit to Drill Application Page 4 BPXA requests a variance to th~visions of 20 AAC 25.035 (e)(10)(A) reg~ng the initial testing of the BOPE when installed as follows: If the lower set of pipe rams cannot. be tested during the primary BOP test (due to the proximity to the test plug), that set of rams will be tested at the earliest opportunity during path-forward de- completion work, i.e., after the completion has been pulled from the well. Spacing issues with the wellhead height and tubing spool preclude us from installing a spacer spool in the BOP stack. Disposal No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. 01-34A Permit to Drill Application Page 5 Drillir~'Ei Hazards and Contind'~ncies POST THIS NOTICE IN THE DOGHOUSE Well Control A. The Ivishak in this fault block is expected to be under-pressured at 7.2 ppg EMW. This pressure is estimated based on offset well pressures. 3500 psi test pressure is in accordance with the RP for Prudhoe production well casing tests. II. Lost Circulation/Breathing A. The 01-34A is not expected to intersect any mapped faults. The only faults in the vicinity of the planned well are located 650 feet to the north and 800 feet to the east. B. No significant lost circulation events have occurred in the offset wells to 01-34. These wells are 01-01, 01-10, 01-11, 01-15 and 01-15A. III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for the intermediate section is 26 bbls and production hole section is infinite for the planned mud weights. The FIT will prove up adequate formation strength for expected ECD's. B. Integrity Testing Test Point Test Depth Test EMW (Ib/gal) t e 9 5/8" 20-ft minimum from the 9 5/8" FTT 11.2 minimum window window 7" shoe 20-ft minimum from the 7" shoe FIT 8.8 minimum IV. Stuck Pipe A. Directional work will be required in the production hole section. Hole cleaning and differential sticking tendency will be of concern. Watch for signs of tight hole and short trip /back ream as required to avoid stuck pipe. VI. Hydrogen Sulfide A. DS-01 is designated as an H2S site; H2S levels of potentially lethal concentrations have been recorded on this pad. Use extra caution while working. VII. Faults A. Little faulting is expected along the planned trajectory. See Section II on lost circulation for more details. VIII. Anti-Collision Issues B. All wells pass major risk criteria for close approach. CONSULT THE DS-01 DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 01-34A Permit to Drill Application Page 6 Operations Summary History 01-34 was originally drilled in 1986 as a conventional well to target Zone 26 & 2C sands in the GDWFI portion of drill site 01 and first produced oil in February 1987. After a series of failed TIFLs a caliper surrey was run on 7/30/02 and indicated that the tubing was in poor mechanical condition with multiple holes in 5 joints, showing between 86% and 93% wall loss. A RWO in December 2002, change the tubing due to multiple holes. Well 01-34 is a close offset of water injector 01-11 i since 2001; the water cut and rate on 01-34 raised slowly rising and had a notable change in late 2004 when the water cut increased 30%, the gas rate dropped 20 mmscfpd, and the GOR dropped 10,000. The oil rate has remained relatively flat and the well stabilized at this rate since. After the field wide shut down in 2006 the well was slugging. It was drifted and found an obstruction at 2347' SLM. On Dec 4 a HOT was pumped to remove plug, 5 days later the well was drifted and a second plug was found at 5596' SLM. On April 02, 07 during a SL brush & flush scale was found; the lab analysis of the sample identified barium and strontium sulfate. Cretaceous fluids crossed flow the Ivishak damaging the reservoir. Additionally to the lab samples of the scale, a failed attempt to flow the well was perform corroborating the damage. The well is currently SI for Cretaceous leak. As part of the pre-rig evaluation 01-34 pass aMIT-OA to 2,000 psi on Sep 09, 2007. To date, the well has produced approximately 14.1 MMBO and is an important off take of the GDWFI area. Notify the field AOGCC representative with intent to plug and abandon Pre Riq Operations 1. SLICK: Remove PXX 8,598' MD. Drift tubing and tag bottom if possible. 2. COIL: If tagged bottom is below perforated interval, lay in cement from tagged bottom to at least 9200' MD. If tagged bottom is above perfs, contact town engineer. Volume per foot of 9-5/8", 47#, L-80: 0.0732 bbl/ft Volume per foot of 4-1 /2", 12.6#, L-80: 0.0152 bb/ft If unable to tag due to fill or junk, contact ODE and discuss adjustment of cement volume to compensate for tagged bottom and potential for bullheading cement. Use squeeze pressure of 1000 psi if operations allow. This plug is for zonal isolation. Freeze protect tubing with diesel to 2200' TVD. SBHP: 3200 psi SBHT: 190 °F 3. SLICK: WOC. Drift to TOC. 4. E-LINE: Jetcut tubing at 8,100' MD. 5. FULLBORE: Bleed casing and annulus pressures to zero. 6. WELLHEAD: Function tubing and casing LDS. Repair/replace as required. Perform PPPOT-T and PPPOT-IC. 7. OTHER: Set a BPV. Remove well house and flow line. Level pad as necessary. Riq Operations 1. Move in. Rig up Nabors rig. 2. Pull BPV. Circulate out freeze protection and displace with 9.6 brine. 3. Run TWC and test to 1000 psi. 4. Nipple down tree. Nipple up BOPE. 5. Test BOPE to 3500 psi high, 250 psi low. Pull TWC. 6. Screw in landing joint. Unseat and pull 4-1/2" tubing hanger to floor 7. Lay down landing joint and hanger. 8. Pull 4-1 /2" tbg to cut at 8100' MD. Spool up control line. Count bands and clamps. 9. RIH with RTTS to 3000'. Pressure test casing above RTTS. o If test does not pass, contact ODE. (option is to run 7" tieback at this point). 01-34A Permit to Drill Application Page 7 o If test passes; continue on. 10. Pressure test casing below RTTS to an FIT equivalent of 12.5 ppg at 5650' MD leak. o If test does not pass, run RTTS to 5600' and test above. If new test fails, isolate leak and test to equivalent 12.5 ppg FIT. o If test passes, continue on. ~~~ ~, ~~ 11. RIH and set CIBP above tubing stub at 8050' MD. v 12. PU and RIH with whipstock. 13. Orient and set WS at 8025' MD ~~~~ -,v"~.~ ~~~ 14. Displace to 9.6 ppg LSND milling fluid. 15. Mill window. Pump a sweep. POOH, LD window milling assembly. 16. PU 8-1/2" drilling BHA. RIH. 17. Drill 20', perform FIT. 18. Drill to TD, increasing mud weight to 10.3 ppg prior to entering the HRZ. 19. At TD, Circulate sweep. Short trip to the window. Circulate sweep. POH and LD BHA. 20. Rig up liner running equipment. Run 7" 26# liner. 21. Circulate bottoms up at the window. Continue in to TD. 22. Circulate hole prior to cement. 23. Cement liner in place. Set liner hanger/packer. 24. Circulate out contaminated mud and cement. POH. LD running tool. 25. MU and RIH with 6-1/8" BHA to top of liner. Circulate bottoms up. 26. Test 7" liner to 3500 psi for 30 minutes. Chart same. 27. Drill cement and float equipment. Displace well to Flo Pro drilling fluid. 28. Drill 20'. Perform FIT. 29. Drill production section as per directional plan. 30. MAD Pass in the up direction. 31. Circulate sweep. Short trip. Circulate sweep. POOH, LD BHA. 32. PU and MU 4-1/2" liner. 33. RIH with 4-1/2" 13CR liner on DP. 34. RU cement equipment. Circulate liner at TD. 35. Cement liner in place. Set liner hanger/packer. 36. POH, LD excess DP. 37. RU to run tubing. 38. Run 4-1/2" 13CR-80 completion. 39. Space out and land tubing. 40. Reverse in corrosion inhibited brine 41. Set packer. Individually test the tubing and annulus to 3500 psi for 30 minutes. 42. Nipple down the BOPE. Nipple up the tree. 43. Freeze protect the well to 2200' TVD. Install BPV. 44. RDMO. Release rig. Post Rig Operations 1. Pull the ball and rod / RHC plug. 2. Perforate 50' production section with 3-3/8", 6spf PowerJet guns. 3. Install gas lift valves 4. Install well house and instrumentation. 5. "S" riser modifications will be required if the tieback is run. The rig will call the SSEP WTI Construction Engineer three days before they move off the well to if the tieback is run. Estimated Pre-rig Start Date: 08/26/2008 Estimated Spud Date: 09/10/2008 01-34A Permit to Drill Application Page 8 ~~.~- _: WELLHEAD = FMC ACS'UATOR = AXELSON KB. ELEV = 70' BF. ELEV = 44' KOP = 4900' IuYx Angle = 26 ~ 8100' Dz' NID = 9172' Qa ND= 8800' SS 13-3/8" CSG, 68i1t, K-55, ID = 12.34T' 30' 13-3/8" CSG, 728, L-80, ID = 12.34T' 250' Minimum ID = 3.726" ~ 8787' 4-1/2" HES XN NIPPLE 4-12" TBG, 12.68, 13-CR, .0152 bpf, 10 = 3.958" B-1/4" X 4-12" UNIQUE OVERSHOT, ID = 3.958" 861 01-34 SAFETY NOTES: CHROME TBG. 2201' H 4-12" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3308 3308 1 MMG DOME RK 16 12/17/02 3 5627 5584 23 MMG SO RK 20 12/17/02 2 7501 7331 18 MMG DMY RK 0 12/14/02 1 8440 8193 24 MMG DMY RK 0 12/14/02 7373' TOC (Estimated) 8(x$3' 4-1 /2" HES X NIP, ID = 3.813" 8674' 9-5l8" X 4112" BKR SB-3 PKR, ID = 3.875" 8(98' -~4-12" HES X NIP, ID = 3.813" 8598' 4-1/2" Pxx PLUG (07/02107) 8679' H9-5/8" X 4-1/2" BKR SB-3 PKR, ID = 3.875" 8787' 4-1/2" HES XN NIP, ID = 3.725" 14-12" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" I FERFORATION SUMMARY REF LOG: BHCS ON 07109/86 ANGLE AT TOP PERF: 23 ~ 9346' Note: Refer to Production DB for historical perf data SIZE SPF WTERVAL Opn/Sgz DATE 3-3/8" 4 9346 - 9361 C 0220/87 3-378" 4 9373 - 9378 C 0220/87 19-5/8" CSG, 47*, L-80, ID = 8.881 " I I 9580' I b 6 i $$QO' -14-1/2" TUBING TAE, ID = 3.958" 8763' ELMD TT LOGGED 02/20/87 DATE REV BY COMMB~fTS DATE REV BY COMMENTS r' ~~186 OWGINALCOMPLETION 08718/03 CMO/TLP PERFANGLECORRECTION !87 WORKOVER 07/02/07 SWGPJC SET PXX PLUG 8596' 1Z11410T DACIKK RGMIORKOVER 02/16101 TP CORRECTIONS 12/03702 PC/tlh CASING CORRECTION 12/17/02 DTR/KK GLV CIO PRUDHOE BAY UNfT WELL:'61-34 PERMIT No: 1861140 API No: 50-029-21609-00 SEC 8, T10N, R15, 2808.41' 8 FEL 82835.54' FNL BP Exploratbn IAlaska) WELLHEAp = FMC ACTi1ATOR = AXELSON KB. ELEV = 70' BF. ELEV = 44' KOP = 4900' Max Angle = 26 (~ 8100' DF MD = 9177 D6 ND = 8800' SS 13-3/8" CSG, 68#, K-55, ID = 12.34T' 13-3/8" CSG, 7211, L-80, ID = 12.34T' SAFETY NOTES: CHROME TBG. 01-34 Pre-Ri 2201' {-~ 4-12" HES X NIP, ID = 3.813" 30' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3308 3308 1 MMG DDME RK 16 12/17/02 3 5627 5584 23 MMG SO RK 20 12/17/02 2 7501 7331 1 B MMG DMY RK 0 12/14/02 1 8440 8193 24 MMG DMY RK 0 12/14!02 Getaceous PC Leak 5650' Re-rig Jet Cut ^-8100 4-12" TBG, 12.6#, 13-CR, .0152 bpi, ID = 3.958" 8618' ^ 1/4" X 4-1/2" UNIQUE OVERSHOT, ID = 3.958" 8625' Minimum ID = 3.726" ~ 8787' 4-1/2" HES XN NIPPLE ~' 4-1/2" TBG-PC, 12.6M, L-80, .0152 bpf, ID = 3.958" 8800' Perf Cement Plug Top 8200' - - ~-. `zmr " b . • • ~ • ~. • a :~ .• • 9-5/8" CSG, 4711, L-80, ID = 8.681" 9554' ~ ~7D~ 9580' 7373' TOC (estimated) e e~~~ 0.7VJ - ~_~ M" uCC Y IJID III = Z A14" -~-~- .. - .....,.. 8574' 9-5/8" X 4-12" BKR SB-3 PKR, ID = 3.875" 8598' 4-1/2" HES X NIP, ID = 3.813" 8679' H9-5/8" X 41/7' BKR SB-3 PKR, ID $787' 4-1/2" HES XN NIP, ID = 3.725" 8800' -j 41 /2" TUBING TA L, ID = 3.958" 8763' ELMD TT LOGGED 02/20/87 PERFORATION SLIMIMRY REF LOG: BHCS ON 07109/86 ANGLEAT TOP PERF: 23 ~ 9346' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpNSgz DATE 3.3/8" 4 9346 -9361 C 0220/87 3.318" 4 9373 -9378 C 0220187 DATE '111186 REV BY COMMENTS DATE OIiGINALCOMPLETION 08/18103 REV BY CMO/TLP COMMENTS PERFANGLECORRECTION PRUDHOE BAY UNIT WELL: '61-34 ,N4187 t1VORKOVER 07!02/07 SWCIPJC SET PXX PLUG Q 8598' PERMIT No:'1861140 12114102 DACIKK RIGVVORIQOV62 API No: 50-029-21609-00 02/16/01 TP CORRECTIONS SEC 8, T10N, R15, 2808.41' 8 FEL 82835.54' FNL 12/03102 PCdlh CASING CORRECTION 12/17/02 DTRIKK GLV C!0 BP Ezploratlon (Alaska) QATE `/11/x6 REV BY COMVBdTS QATE ORgNALCOMPLETION 08118103 REV BY CMO/TLP CONNBJTS PERFANGLECORRECTION PRUDFIOE 8AY UIWT WELL:'61-34 ,M4167 WORlmU6t 0710Z/07 SWCJPJC SET PAC PLl1G 8598' PERMT No: 1861140 12M4102 OI-CIIO( RIG WOI~ODVBt API No: 50-029-21609-00 02/16/01 TP CORRECTIONS SEC 8, T10N, R15, 2808.41' 8 FH. 8 2835.54' FNL 12/03102 PC1Nh CASMIG CORRECTION 12/17/02 I)TRIKK GLV CJO ~ 6tploratkin )Alaska) COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM BP Amoco Co-ordinate (N/E) Rcfcrcncc: Well Centre: OI-34, True Nonh cprh Fm Depth To Survey/Plan Tool Plan: Ol-34A Wp 8. 0 (01-34/Plan 01-34A) [7~ Vertical (TVD) Reference: 40GL ~ 28.5 68.50 '~~~iiM~~IFF~ ' Iwlution Mothud: Minimmm Curvature Section (VS) Reference: Slot- 34 (O.OON,O.OOE) 000.00 9473.00 Planned: 01-34A Wp 8.0 V12 MW D+IFRi MS Crea[ed By: Sperry Drilling Da[c: 7/1/2008 Ertor System: ISCWSA Measured Dcpih Rcfcrcncc: 40GL 128.5 68.50 Scan Method: Tmv Cylinder Nonh Calculation Method: Minimum CurvaNre Ertor Surfaco: Elliptical i Casing WELL DETAILS CASING DETAILS - - Name ~ N/-S { E/-W Noshing Fasting Latitude L ongitude Slot OI-34 -23 58.38 1616.33 5939617.00 698915.110 70°14'24708N 148°23'3Z022W 34 No. TVD MD Name Size _ - 1 8601.46 8835.83 7" 7.000 ~ ! ---- - ~ ~ ~ I DETAIL ~~~~- 2 9228.47 9473.68 4 1/2" 4.500 ~ ~ - ' -- i , Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VScc Target HMLL~BURTON ~ I l 8000.00 25.13 153.63 7794.5 2 -938.75 707.71 0.00 0.00 1158.85 ' I I ! 2 8020A0 25.45 159?0 7812.6 1 -946.57 711.12 12A0 85.00 1167.37 _ - - - - - _ . - ~ 3 8779.57 10.57 267.69 8546.1 5 -1105.67 699.15 4.00 159.88 1303.23 $6~'V~C®~ I / ~f ~~~1~1 6f'1" __ _ _ 4 8944.30 10.57 ?67.69 8708.09 -1106.89 668.96 Q.00 0.00 1'90.45 (] g ~ i --- - - -- -- - - - -- S 8954.89 10.58 _70A0 8718.50 -11(16.93 667.01 4A0 89.96 (_89.59 OI-34A TI rev 3 - - - _ ~ ~ - 6 9104.89 10.58 270.00 8865.95 -1106.93 639.47 OAO 0.00 1276.95 I - - - - - - -~ - - ~ 7 9473 A(1 i 10.58 270.00 9227.80 -1106,93 571.88 0.00 0.00 1245.93 750 _. i-_. I_. _. .- -._ .._~;_: ~- _ - ' ' Start Dir 12 100' `. 800 0' MD; 779 4.52 I Start Dir 4 100' :8020' MD, 781 2.61' V D I _ i i - - C M;QI ... _ I Soo( ~ i I I -: ~ ~ - - -~ - _ - - - - _ - - - _ ~ - _ -_ - - - - - ' ~ - - - I , - a -, TFIRZ 10 i I u ~ ' B ~ - - > i I-CU ' E i} : $779 .57 MD; 8 546.1 'T VD 2 850 TJA t li 4° UO 944 3' ' MD 70 09'TVD 8 F _ _S a I r lI : :8 , ~ . - - ~ _ _ ~~~~ En it ; Sy54 .89' MD 8 718. 'T VD ~ ~ , I , - - _Y'SAt~ 34A G -Poly. - - ! . ' - ' 01-34 T rev 3 : _ _ ~ L. ~ - `- - - . 42SBy0 _ - -- - -- - _ - - - FORMATION TOP DETAI LS _. - -- - - - ~ - -- TCGL J 1 ° ~' ~' - - - - - - - .- - - - - _ _. - • - - -- - f -_ _ __. - - __ - _: ! No. TVDPath MDPath Formation - - - ~ - - ~~ - - _ 1 7848.50 8059.51 CM 1 i ~ _ 2 8308.50 8437.33 THRZ - T 21TS l - - ; 3 8401.50 863.99 BHRZ - _ ._ Z18 L1 .. ~ , P an 1 3 - 4 01-3 4 (Ol 34 ) I 1 ' - 1 2„ i r , ! 6 87 TSGR 860 50 8835 31 01-34A Wp 8 I _ ; ~ w i 7 . . .50 8866.39 TSHA 86 - - - - ..- -- _ ..- _.. _ - I i .. , ~ "^ - - - 8 50 8943 70 TSAD 8707 ! ~ T ta DcP~ 9473' MD 922 .8` TVD '~ _ 9 . . 50 9070.86 4256 8832 _ _ ..... .. _ _- __ __ - i - _- -- -- - - ~ ~ , - _- - -- - 10 . 8895.50 9134.95 TCGL - - - - - _ _ - ' II 50 9208 19 BCGL 8967 ~ - 12 . . 50 9390 59 ~ _3SB 9048 ~ - - - _ - - i _ - - 13 . . 9068.50 9310.94 HOT ~ i - ~ - - - - -- _ - - - 14 9139.50 9383.17 21TS _ - - - - -- -- - - - - - ~ - - - - -- - -- -.. 15 9186.50 9430.98 TZIB ' !- -- - ~ I ~ I- - _ - s 1 TARGET DETAILS ~ i ~ I ! ~, ~, ~ , - ~ ~ TVD +N/-S +E/-W N Fastin Shape Northin ame g g Ol-34AGco-Poly 8718.50 -1106.93 667A1 5938528.12 699610.95 Polygon 10 00 15 00 20 00 25 00 3000 +>uU Ol-34ATIrcv3 8718.50 -1106.93 667.01 5938528.12 699610.95 Point Vertical Section at 152.6 8° [SOOft/in] COMPANY DETAILS BP Amoco Calculation Method: Minimum Curvature Errur System: ISCWSA Scan Method: Trav Cylinder Nonh Ertor Surf~acc: Elliptical ~ Casing Warning Method: Rules Based HALLIBUf-~TC)N Sperry drilling Serviaee -853 -91 L 1. O z y 0 FORMATION TOP DETAILS No. TVDPath MDPath Formation I 7848.50 8059.51 CMl 2 8208.50 8437.33 THRZ 3 8401.50 8632.99 BHRZ 4 8436.50 8668.38 LCU 5 8504 50 8737.26 T1A 6 8601.50 8835 87 TSGR 7 8631.50 8866 39 TSHA 8 8707.50 8943 70 TSAD 9 8832.50 9070.86 4286 10 8895.50 9134.95 TCGL II 8967.50 9208.19 BCGL 12 9048.50 9290.59 2386 13 9068.50 9310.94 HOT 14 9139.50 9383.17 21TS IS 9186.50 9430.98 TZ16 REFERENCE INFORMATION SURVEY PROGRAM 'o-ordinate (N/E) Reference Well Centre: OI-34, True North Depth Fm Depth To Survey/Plan Tool Plan: OI-34A Wp S.0 (01-34/Plan OI-34A) Vertical (TVD) Reference: 406E i 28.5 68.50 Section (VS) Reference: Slot - 34 (O.OON,D.OOE) 8000.00 9473.00 Planned: 01-34A Wp 8.0 V 12 MWD{ IF Ri MS Created By: Sperry Dulling Date: 7/1/2008 Measured Depth Reference: 406E i 28.5 68.50 Calculation Method: Minimum Curvaure WELL DETAILS I Name i N/-S i E/-W Northing Easting Latitude Longitude Slot ' 1 - ~ ~ - ~ , i ~ ~ -_ 0134 -2358.38 1616.33 5939617.00 698915.00 7U°14'20.708N 148°23'37.022W 34 - __- - _. -. _. -_ - _- _- .. . I_ - -_ ~ TARGET DETAILS , - .. ~ _ __ _,. Name 'PVU +N/-S +E/-W Nort mg aasng ape ~ - -- - - 750( ~ 01-34A Gco-Poly 871850 -1106.93 667.01 5938528.12 699610.95 Polygon I ' i ~ (11-34ATlrcv3 8718.50 -1106.93 667.01 5938528.12 699610.95 Point an 01 34A ! _ - ~ _ . ' 0 -34A WP B ~ /. _ Ol-34A Gco Poly _ . - - 01-34A I rev 3 1 _ - ~ -~' -~' 4 -'- , _ , ' i I I _ ', I - - -- -- --- - -- - Tl -_--- - i_.._ ~ TVD MDASINGDETAILS _ I __ _. -- - ~ - - 1 -, -- --- - - I _. _ ~. No. Name Sizc 1 8601.46 8835.83 7" 7.000 ', _ _-- - - ~ - -~- _-- -- i--- -- ~ _ _ _ _ 2 9228.47 9473.68 4 1/2" 4.500 -- -- - - _ - SECTION DETAILS _I ~~ _.. _ i -. I I Scc MD Inc Azi TVD iN/-S iE/-W DLcg TFacc VSec Target ' ---- - - ~ ~ ~ ~ ~~ ~ ~' ~ 1 8000.00 25.13 153.63 7794.52 -938.75 707.71 (1.00 0.00 1158.85 - ~ - - ~ ~ 2 8024(10 25.45 159.20 7812.61 -946.57 711.12 12.00 85.00 1167.37 3 8779.57 1457 267.69 8546.15 -1105.67 699.15 4.00 159.88 1303.23 4 8944.30 1457 267.69 8708A9 -1106.89 668.96 0.00 0.00 1290.45 459 525 591 65 5 8954.89 IU.58 270.00 8718.50 -I IU6.93 66ZUI 4.00 89.96 1289.59 UI-34A TI rcv3 6 9104.89 10.58 270.0(1 8865.95 -1106.93 639.47 0.00 0.0(1 1276.95 Wes[(-)/East( 7 9473.00 10.58 270.00 9227.80 -1106.93 57L88 0.00 0.00 1245.93 Sperry-Sun BP Planning Report Company: BP Amoco Date: 7/1/2008` Time: 16:01:51 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeIL 01-34, True North Site:. PB DS 01 Vertical (TVD) Reference: 40GL+28.5 68.5 Well: 01-34 Section (VS) Reference: Well (O.OON,O.OOE,152.68Azi) Wellpath; Plan 01-34A Survey Calculation Method: Minimum Curvature Db: `'Oracle Plan: 01-34A Wp 8.0 Date Composed: 12/6/2007 Version: 12 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea bevel Geomagnetic Model: bggm2007 Site: PB DS 01 TR-10-15 UNITED STATES :North Slope Site Position: Northing: 5941932.14 ft Latitude: 70 14 43.905 N From: Map Easting: 697237.60 ft Longitude: 148 24 24.004 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg Well: 01-34 Slot Name: 34 01-34 Well Position: +N/-S -2358.38 ft Northing: 5939617.00 ft Latitude: 70 14 20.708 N +E/-W 1616.33 ft Easting : 698915.00 ft Longitude: 148 23 37.022 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft' ft in _ in - 8835.83 8601.46 7.000 8.500 7" 9473.68 9228.47 4.500 6.125 4 1 /2" Formations MD TVD Formations Lithology Dip Angle. Dip Direction ft ft deg deg 0.00 CM2 0.00 0.00 8059.51 7848.50 CM1 0.00 0.00 8437.33 8208.50 THRZ 0.00 0.00 8632.99 8401.50 BHRZ 0.00 0.00 8668.38 8436.50 LCU 0.00 0.00 8737.26 8504.50 TJA 0.00 0.00 8835.87 8601.50 TSGR 0.00 0.00 8866.39 8631.50 TSHA 0.00 0.00 8943.70 8707.50 TSAD 0.00 0.00 9070.86 8832.50 42S6 0.00 0.00 9134.95 8895.50 TCGL 0.00 0.00 9208.19 8967.50 BCGL 0.00 0.00 9290.59 9048.50 23S6 0.00 0.00 9310.94 9068.50 HOT 0.00 0.00 9383.17 9139.50 21 TS 0.00 0.00 9430.98 9186.50 TZ1B 0.00 0.00 Targets Map Map <-- Latitude ---> <-- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg: Min Sec Dip.. Dir. ft ft ft ft ft 01-34A Geo-Poly 8718.50 -1106.93 667.01 5938528.12 699610. 95 70 14 9.821 N 148 23 17.637 W -Polygon 1 8718.50 -979.25 449.34 5938650.00 699390. 00 70 14 11.077 N 148 23 23.963 W -Polygon 2 8718.50 -985.85 699.27 5938650.00 699640. 00 70 14 11.012 N 148 23 16.699 W -Polygon 3 8718.50 -1235.78 692.67 5938400.00 699640. 00 70 14 8.554 N 148 23 16.892 W -Polygon 4 8718.50 -1229.18 442.75 5938400.00 699390. 00 70 14 8.619 N 148 23 24.155 W -Plan hit target 01-34AT1 rev3 8718.50 -1106.93 667.01 5938528.12 699610. 95 70 14 9.821 N 148 23 17.637 W -Plan hit target Sperry-Sun i BP Planning Report Company; BP Amoco Date: 7/1/2008 Time; 16:01:51 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) References WeIL•-01-34,True North Site: PB DS 01 Vertical (TVD) Reference: 40GL+28.5 68.5 Well: 014 Section (VS) Reference: Well (t).OON,O:OOE,152.68Azi) Wellpath: Plan 01-34A Survey Calculation Method: Minimum Curvature Dbc Oracle Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg :deg ft ft ft deg/100ft deg/100ft;deg/100ft deg 8000.00 25.13 153.63 7794.52 -938.75 707.71 0.00 0.00 0.00 0.00 8020.00 25.45 159.20 7812.61 -946.57 711.12 12.00 1.57 27.86 85.00 8779.57 10.57 267.69 8546.15 -1105.67 699.15 4.00 -1.96 14.28 159.88 8944.30 10.57 267.69 8708.09 -1106.89 668.96 0.00 0.00 0.00 0.00 8954.89 10.58 270.00 8718.50 -1106.93 667.01 4.00 0.08 21.79 89.96 01-34A T1 rev 3 9104.89 10.58 270.00 8865.95 -1106.93 639.47 0.00 0.00 0.00 0.00 9473.00 10.58 270.00 9227.80 -1106.93 571.88 0.00 0.00 0.00 0.00 Survey MD, Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MaPE TooUGo ft deg deg ft ft ft ft ft deg/100ft ft ft 8000.00 25.13 153.63 7794.52 7726.02 1158.85 -938.75 707.71 0.00 5938697.30 699647.19 Start Dir 1 8020.00 25.45 159.20 7812.61 7744.11 1167.37 -946.57 711.12 12.00 5938689.57 699650.81 Start Dir 4° 1 8059.51 23.97 160.54 7848.50 7780.00 1183.76 -962.07 716.81 4.00 5938674.23 699656.90 CM1 8100.00 22.47 162.09 7885.71 7817.21 1199.54 -977.19 721.93 4.00 5938659.25 699662.42 MWD+IFR 8200.00 18.84 166.88 7979.27 7910.77 1234.05 -1011.11 731.47 4.00 5938625.60 699672.85 MWD+IFR 8300.00 15.39 173.79 8074.84 8006.34 1262.09 -1040.03 736.57 4.00 5938596.82 699678.72 MWD+IFR 8400.00 12.26 184.33 8171.95 8103.45 1283.52 -1063.82 737.21 4.00 5938573.06 699679.98 MWD+IFR 8437.33 11.24 189.67 8208.50 8140.00 1289.80 -1071.36 736.30 4.00 5938565.49 699679.27 THRZ 8500.00 9.79 200.92 8270.12 8201.62 1298.23 -1082.36 733.37 4.00 5938554.42 699676.63 MWD+IFR 8600.00 8.54 225.00 8368.88 8300.38 1306.15 -1095.56 725.08 4.00 5938541.01 699668.69 MWD+IFR 8632.99 8.51 233.91 8401.50 8333.00 1307.26 -1098.73 721.37 4.00 5938537.74 699665.07 BHRZ 8668.38 8.70 243.30 8436.50 8368.00 1307.64 -1101.48 716.86 4.00 5938534.88 699660.64 LCU 8700.00 9.05 251.18 8467.74 8399.24 1307.24 -1103.36 712.37 4.00 5938532.88 699656.20 MWD+IFR 8737.26 9.66 259.54 8504.50 8436.00 1305.90 -1104.87 706.52 4.00 5938531.22 699650.39 TJA 8779.57 10.57 267.69 8546.15 8477.65 1303.23 -1105.67 699.15 4.00 5938530.22 699643.04 End Dir 8800.00 10.57 267.69 8566.24 8497.74 1301.64 -1105.82 695.41 0.00 5938529.97 699639.30 MWD+IFR 8835.83 10.57 267.69 8601.46 8532.96 1298.86 -1106.09 688.84 0.00 5938529.53 699632.74 7" 8835.87 10.57 267.69 8601.50 8533.00 1298.86 -1106.09 688.83 0.00 5938529.53 699632.74 TSGR 8866.39 10.57 267.69 8631.50 8563.00 1296.49 -1106.31 683.24 0.00 5938529.16 699627.15 TSHA 8900.00 10.57 267.69 8664.54 8596.04 1293.89 -1106.56 677.08 0.00 5938528.75 699621.00 MWD+IFR 8943.70 10.57 267.69 8707.50 8639.00 1290.50 -1106.88 669.07 0.00 5938528.22 699613.00 TSAD 8944.30 10.57 267.69 8708.09 8639.59 1290.45 -1106.89 668.96 0.00 5938528.21 699612.89 Start Dir 4° 1 8954.89 10.58 270.00 8718.50 8650.00 1289.59 -1106.93 667.01 4.00 5938528.12 699610.95 01-34A T1 9000.00 10.58 270.00 8762.85 8694.35 1285.79 -1106.93 658.73 0.00 5938527.90 699602.67 MWD+IFR 9070.86 10.58 270.00 8832.50 8764.00 1279.82 -1106.93 645.72 0.00 5938527.56 699589.66 42S6 9100.00 10.58 270.00 8861.15 8792.65 1277.36 -1106.93 640.37 0.00 5938527.41 699584.32 MWD+IFR 9104.89 10.58 270.00 8865.95 8797.45 1276.95 -1106.93 639.47 0.00 5938527.39 699583.42 MWD+IFR 9134.95 10.58 270.00 8895.50 8827.00 1274.42 -1106.93 633.95 0.00 5938527.25 699577.90 TCGL 9200.00 10.58 270.00 8959.45 8890.95 1268.94 -1106.93 622.01 0.00 5938526.93 699565.96 MWD+IFR 9208.19 10.58 270.00 8967.50 8899.00 1268.25 -1106.93 620.50 0.00 5938526.89 699564.46 BCGL 9290.59 10.58 270.00 9048.50 8980.00 1261.30 -1106.93 605.37 0.00 5938526.49 699549.33 23S6 9300.00 10.58 270.00 9057.75 8989.25 1260.51 -1106.93 603.65 0.00 5938526.45 699547.61 MWD+IFR ; 9310.94 10.58 270.00 9068.50 9000.00 1259.59 -1106.93 601.64 0.00 5938526.39 699545.60 HOT 9383.17 10.58 270.00 9139.50 9071.00 1253.50 -1106.93 588.38 0.00 5938526.04 699532.34 21TS 9400.00 10.58 270.00 9156.05 9087.55 1252.08 -1106.93 585.29 0.00 5938525.96 699529.25 MWD+IFR ; 9430.98 10.58 270.00 9186.50 9118.00 1249.47 -1106.93 579.60 0.00 5938525.81 699523.57 TZ1 B 9473.00 10.58 270.00 9227.80 9159.30 1245.93 -1106.93 571.88 0.00 5938525.61 699515.86 Total Dep : 9 3 WELL U[TAILS ANTI-COLLISION SETTINGS COMPANY UF.TAILS SURVEY PROGRAM Nanc N/-S ~Fl-W Nutthing E:a.Sinc LaSiwJc L~ugirtlJc SloS UP Am~wro 0.pth Fm n~pm r~ Smvcy/Plan Toul Incerpolalion Melhod:MD Interval: 50.00 0134 -235%.38 IGla it 54i4G17.a1 G4R415.UI1 70'14'2070%N 14%'?3'37L'_?W 34 Dcplh Range From: 8000.110 To: 9473.011 Calculaliun Mahal: Minivwn Cwvartuc %OW.IIO 4473.UI1 Planuvl. 111-34A Wp x.U Vl_' MWU ~IFR-MS Maximum Rangc: 1144.45 Reference: Plan: 01-34A Wp 8.0 s~o„rM:hh~d: 71 vJCy ~Jrrrvnnh ertrtr sa+n«: nlipliWl ~ caalnx Weming MiKhoJ: RWcs Basal 160 150 125 100 75 50 25 0 25 50 ~5 100 '125 •1 JO 160 olour To MD PWn U134A o134A - 250 - 500 PaKaweupam ma4 Tie un MU: xaln.oo - 750 wR: - 1000 Rn: Damn,: 411GL-zas arson 1250 vszlirtl, U;~S Dripill smmng - 1500 alyla w-s E/-w PrrtnlTVo - 1750 Is3.G%° a.oo uuo z%so - 2000 - 2250 - 2500 LECr:ND - 2750 ~ UI-II (UI-III, Maja'RisA - 300Q 01-IS (01-IRA PIanl. Majur Risk ~ UI-34(01-341, NOERRORS PIa1 Ill-J4A - 3250 - al-34A wp ao - 3500 - 3750 - 4000 - 8000 8250 - 8500 8750 - 9000 9250 9500 - 9750 - 10000 Removed. I ;an for Plans le @ No Errors SGLTION DETAILS Inc ~' TVD ~NI-S rE/-W DLeg TFace VS.r TarpiK S.I3 IS3.Gl 7744.5'_ -41R.75 707.71 O.fNI O.W 115%.NS 5.45 ISY?II 7R1?.(I -446.57 711.1? I?110 85.(NI IIa7.17 1.57 '_a7 G9 R54fi.la -I IUS.a7 GYY.IS 4-W 154.%R IlU3?3 1.57 '_fi7b9 670R.U4 -I 104.%9 GfiR_4fi O.W O.W 12w145 1.Sx ?711.W %71 %.50 -I10(~43 aG7.01 4.W %9 YG 12%4.SY 111-14A TI rcv3 1.5R 2711.W R%65.45 -1 IOG.43 b3947 O.W 0.181 1276-45 1.58 '751.00 42^_7R0 -IIW.43 571.R8 LLW U.W I_^45.43 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [SOft/in] Sperry-Sun Anticollision Report Company: BP Amoco Date: 7/1/2008. Time: 16:02:17 Page: t Field: Prudhoe Bay Reference Si te: PB DS-01 Co-ordinate(NE) Reference: Well: 01-34, True North Reference Well: 0 1-34 Vertical (TVD) Reference:. 40GL+28. 5 68.5. Reference Wellpath: Plan 01-34A Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 ofreference -There are TilreYd~~ls in this fRhTtCipal Plan 8~ PLANNED PROGRAM Interpolation Method: MD Inte rval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 9473.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1144.45 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 12/6/2007 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 98.50 8000.00 1 : Sperry-Sun BOSS gyro multi (98.50-9578.BQ)~GYRO Sperry-Sun BOSS gyro multishot 8000.00 9473.00 Planned: 01-34A Wp 8.0 V1 2 MWD+IFR +MS MWD +IFR + Multi Station Casing Points MD TVD Diameter . Hole Size Name ft ft in in 8835.83 8601.46 7.000 8.500 7" 9473.68 9228.47 4.500 6.125 4 1 /2" Summary <------ -- Offset Wellpath ------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB DS 01 01-11 01-11 V2 4837.90 5100.00 153.76 168.95 -15.19 FAIL: Major Risk PB DS 01 01-18 01-18A Plan VO Plan: 1 7905.97 8200.00 1128.87 2414.99 -1286.12 FAIL: Major Risk PB DS 01 01-34 01-34 V1 2498.50 2500.00 0.00 0.91 -0.91 FAIL: NOERRORS Site: PB DS 01 Well: 01-11 Rule Assigned: Major Risk Wellpath: 01-11 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistance Area :Deviation. Warning. ft ft ft ft ft ft deg deg in ft ft ft 28.50 28.50 33.00 33.00 0.00 0.00 297.57 297.57 4.000 892.24 0.52 891.72 Pass 92.72 92.72 100.00 100.00 0.14 0.21 297.58 130.47 4.000 892.35 2.22 890.12 Pass 194.21 194.21 200.00 200.00 0.27 0.52 297.60 111.83 4.000 892.59 4.56 888.04 Pass 292.53 292.52 300.00 300.00 0.24 0.83 297.62 151.83 4.000 892.82 6.37 886.45 Pass 390.76 390.76 400.00 400.00 0.42 1.15 297.64 145.84 4.000 893.26 8.84 884.42 Pass 491.23 491.22 500.00 500.00 0.55 1.46 297.65 163.56 4.000 893.77 11.17 882.60 Pass 591.11 591.10 600.00 600.00 0.64 1.77 297.66 160.81 4.000 894.25 13.37 880.88 Pass 689.76 689.75 700.00 700.00 0.88 2.08 297.67 171.45 4.000 894.82 16.03 878.79 Pass 789.52 789.51 800.00 800.00 1.12 2.40 297.68 164.42 4.000 895.48 18.70 876.78 Pass 889.11 889.10 900.00 900.00 1.43 2.71 297.69 163.41 4.000 896.17 21.55 874.62 Pass 989.86 989.84 1000.00 1000.00 1.51 3.02 297.71 164.48 4.000 896.85 23.74 873.11 Pass 1088.10 1088.08 1100.00 1100.00 1.57 3.54 297.72 166.83 4.000 897.55 26.43 871.11 Pass 1191.92 1191.90 1200.00 1200.00 1.64 4.06 297.73 150.17 4.000 898.15 29.26 868.89 Pass 1293.03 1293.01 1300.00 1300.00 1.47 4.58 297.74 155.94 4.000 898.39 31.31 867.08 Pass 1392.14 1392.12 1400.00 1400.00 1.51 5.10 297.73 176.99 4.000 898.60 33.98 864.62 Pass 1491.77 1491.75 1500.00 1500.00 1.72 5.62 297.72 194.68 4.000 898.85 37.18 861.67 Pass 1590.70 1590.68 1600.00 1600.00 2.00 6.14 297.70 192.23 4.000 899.14 40.55 858.59 Pass 1688.97 1688.95 1700.00 1700.00 2.28 6.66 297.69 176.21 4.000 899.56 43.95 855.61 Pass 1785.96 1785.93 1800.00 1800.00 2.58 7.18 297.69 168.32 4.000 900.20 47.36 852.84 Pass 1884.58 1884.54 1900.00 1900.00 2.93 7.70 297.69 165.76 4.000 901.08 50.95 850.13 Pass 1986.31 1986.27 2000.00 2000.00 3.06 8.22 297.68 176.44 4.000 901.91 53.93 847.98 Pass 2091.03 2090.98 2100.00 2100.00 2.95 8.22 297.64 235.94 4.000 902.41 54.63 847.78 Pass 2193.87 2193.81 2200.00 2200.00 2.74 8.22 297.58 256.36 4.000 902.55 55.03 847.52 Pass 2293.94 2293.89 2300.00 2300.00 2.57 8.23 297.54 235.70 4.000 902.63 55.54 847.08 Pass 2395.42 2395.36 2400.00 2400.00 2.55 8.23 297.54 92.53 4.000 902.72 56.48 846.24 Pass 2492.44 2492.38 2500.00 2500.00 2.69 8.23 297.57 120.77 4.000 902.97 57.88 845.10 Pass 2589.89 2589.84 2600.00 2600.00 2.94 8.06 297.60 155.77 4.000 903.55 59.10 844.45 Pass Alaska Department of Natural Resources Land Administration System Page 1 of~ ! • • .~w ,;r . _ ,;, - ,~-~ _ ., ~*~.. - ~~ :+~ ~ -:ca~der`s Search State Cabins ~I~tu~ ~[iu ~ __ .~_ ,,. Alaska DNR Case Summary File Type: A~~._.____3 File Number: _ 28329„__ ~ Printable Case File_$ummary. See Township, Range, Section and Acreage? New Search Yes ~' No ~~..- - ____ ~~+,~ Mer~.3 ~ Case Abstract ~ Case Detail I Land Abstract ~. Iile: ADL 28329 ~~~`"~' ~ Search for Status Plat Updates As oI~OR!1 I,'2008 Customer: 000107377 L3P EXPLORATION (ALASK<~) 1NC PO BOX 1 966 1 2/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA. ANCHORAGE AK 995196612 Case Type: ~4 OIL & GAS LEASE COMP DNR Unit. 780 OIL AND GAS File Location: DOG DIV OIL AN D GAS Case Status: 35 ISSUED Staters Date: 09/14/1965 Total Acres: 2501.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridia~r: l To~~~i~~faiC~: OIQN R~mde: 015E Sectiorz~ OS ~5'c~~tiou:]c•r~~s: 64Q Search Slats ;L9~~ri~lcan: U Tulcra~ltii~: (_110N Range: O I SE Sectirur: U6 .~'ec~run _Icrc~.~~: 609 al~~rr~li~m: U 7uu~frshij>~ QION Range: (115E Sectiurr.~ 07 Src~Iiun:l~re.~~: 612 lk~ricliu~r: L! 7~ni~n~frii~: 0 I (l~l Ru»~°: 01 SE Secti~~n: (l~; Sc~ctinn ~-lcr~~s: 640 Leal Description U_5-28-1965 * ~ *SALE N OTICE LEUAL DESCRIPTION* * ~` C1=1-1~9 TION-RISE-UM~,6,7,8 201.00 U- 3- 7 ~t'I "~ .ttt'1l'11a"~if'"'` Last updated on 0811112008. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28329&... 8/11 /2008 ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME P,~~ ~/- ~~~ PTD# o?O~Jo3cS0 Developments Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~.e.11Q~10~' / Ay POOL: _ ~i~l/Dr~OE' ~Ar Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. API No 50- " API number are , . between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), alt records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and AP[ 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 may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are frst caught and 10' sample intervals throw h tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of welt) until after (Comnanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. 1Companv Name) must contact the Commission to obtain advance approval of such water well testing ro am. Rev: 1/112008 WELL PERMIT CHECKLI5T Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Wefl Name: PRUDMOE BAY UNIT 01-34A Program DEV Well bore sag ^ PTD#:2081250 Company BP EXPLORATION (ALASKA) INC Initial Classfrype DEV ! PEND GeoArea 890 Unit 11650 OnlOff Shore ~ Annular Disposal ^ Administration 1 Permitfeeattached-------- -- - -- - ----- ----- NA- - ----- - -- ----- - -- ----- --- -- -- --... 2 tease number appreR~ate- - - - - - - - - - - - - - - - - - - Yes - ---------------------------------- - --------- - --- ------------ 3 Uniquewelknameandnumber- -- ------- ------ - --- ------Yes- ------- -- -- ----------- ------ --- -- -------- 4 WelUocatedirtadefinedpgci ---_.. - -- -- -- - ---- - Yes- -- --- -- ------ --- ------ ---- -- - --------- 5 -Ullelllocatedpropardkstancefromdriliingunit-boundary--------------- ---------Yes- ---------------------------------------------------------------------- 6 Well located properdiskancefromotherwelJs______________- ---__ --Yes- ----------------------------------------------------------------____-- 7 Suffioientaoreageayailabigin_dlillinqunit______________________ _________Yes- ------1569 acres.___.-__--_-_______._________________----------_------_--- 8 Ifdeviated,is-wellboreplat-included----- -- --- -- - - -- ------Y~- --- --- --- - - - ---------- - - - -- -- --- ------ - 9 Operator onlyaf[eotedparly - --- -- --- ---- ----- -- --- --Yes- --- --- -- - - - -- ------ - - --- -- -- -- -- -- -- - 10 Operatothas.appropriatebondinfgrce______.._-____________ _________Yes_ ._____BlanketBond#6184193.__-__..____________.___._--_,.- 11 Pemliteanbelssuedwlthoutconservationorder___________________ ________Yes- ---------------------------------......-------------------------------_-- Appr Date 12 Pe[mftcanbBkssuedwlthoutadministrative_appCOVaI__,_-.________ ________Yes. -----------------------------------------------.----------------___--- ACS 8111!2008 13 Can permit-beapRrovedbefors15•dayWait---------------------- --------Yes- --------------------------------------------------------------------,--- 14 WelUocatedwkthinarsaandstrataauthorizedkylnjectionO[de[#(putlp#in_comments)_(For_NA_ ________________________________-_--------_-------.---_---_--_---_-_--- 15 Aliwells_within1l4_roileareaof[eyiewidentifisd(F9[&eNicewell9nly)___-_ ____-____ NA__ ________________________-_____________-_--_-------------------------____ 16 Pte-producadinjectoeduraUonotpre-ptoduotionlesathan3months(Por_servicewellonly)---NA- ------------------------------------------------------------------------- 17 _Honconven,gasconformsloA$31,05.03Q(j.1.A),Q•~.A-D1 -- -- - - - ------ -~-. _ -- -- -- -- --- - - --------- ---- -- - - -- ------- Engineering 18 Conductorstung-provlded___-_----___---____._ ........ ......__.NA._ _.-Gonduciorset_inD$01-34(1136.1'4a.___-___________---__-__....---------_----- 19 Surface_casln9prQtec_taallknownU&DV11s---------------------- ----------N.A-- ------Noa9uifers,-A1446,_Gon~lusiQn_5.--------------------------------------_-------- 20 CMT_voladequate-tocirculateonconductor8,surf-cag_______________ _________NA_ --_-_Surfacac~i-ngsetinD~01-34•----------------------------------------------- 21 CMT_voladequake_tptl@-inlongatringtoaurfcsg__________________ ________Yes_ _-____Newintem)ediaie-liner_toba fully cemented.--___-_________--__--__--__--__-_ 22 CMT-wilJcoverahknown-productivehor~zons------------------- -----__--Yes- --------,--------.----------------------------------------------___._-- 23 CasiDgdesignsadequateforG,TB&_permafrost------------------ ---------Yes- -----------------------------------------------.----------.------------- 24 Adequate tankage_or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ - - - - - -Rig equipped with steel pits. Noleserve pii planned•_ All waste-to approved disposal well(s). _ _ - _ _ . _ _ _ _ _ _ _ 25 If-a-re-drill,has-a10~403forabandonment been approved------------- ---_--__ Yes_ _-_---308-226--------------------------------------.-.--------------_-._-- 26 .Adequate welibo-re separationpropoged- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - - _ - - - P[oximihC artalys~ performed, Nearest segment is P&A portion of DS 01.34 and paths diverge._ - - - - _ _ _ _ _ _ 27 ifdivertar_required, does itmeetregulati9ns--------------------- ----_-----NA-. ------BOPStaCkwillalreadY-beir~place.-------------------,-----------------------.- Appr Date 28 Drilling fluid. program schematic & equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes . - - _ - - -Maximum expected formation pressure 7,2_~MW._ PlaDned MVy up to-10,3_in 8.5"hole_and 6.5 in zone._ _ _ _ . _ _ TEM 811212008 29 BOP)_s,dolheymeetrsgulation---_._____.____---_--_ -.- --.__Yes- ----------------------------------------------------------------____-- ' (1,(yt, Y 30 BOPS-press rating appropriate; fast to-(put prig in-comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ MA$P calculated at 1377 psi. 3600.psi_BQP testplanned, _ _ _ _ _ _ - - _ _ - - _ _ - - _ _ - - _ _ .. _ _ _ _ _ _ _ _ _ ~ ~., y", 31 Ch9ke_manifold comRlies wIAPI-RP-53 (May 841 - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 ?Norkwihoccurwithout_operatiotrshutdow~____-_____________ ____ ____Yes_ -------------------------,---------------------_----_------____-- 33 Is presence Qf H1S gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - _ _ . - _ H1S is present 9n D$1._ Mud should preclude H2& on_ rig. Rig has sensors and alarms._ - - - - . - _ - - _ - - - _ 34 _Mechanicalcooditionofwellsw'tthinAORyerkfiiedLFOrservicewellonl~_-_- _. -__-. NA-_ -------------------------.-------------------...---_..------------_- -- Geology 35 Pem)itcap be issuedwlo hyd[ogen_au~de measures - - - - - - - - - - - - - - - - - - - - - Ko- _ _ _ _ _ Max H2$ lev_el on-padlfacility=14Oppro tOlwell_91,07A._ _ _ _ _ _ _ _ _ - _ - - - _ - _ - - - _ _ - _ _ _ _ _ _ _ - _ _ 36 Data_plesentedonpotentialove~pressurezones------- - -- - ------ Yes- ------- --- - - - - --------- - ------- -- ------- - --- Appr Date 37 Seismicalnalysrsofshallowgaszones______..---,---------- ---- ---- NA-- _-.-_----------------__-_________-_____-.----__-_-- -------------- ACS 811112008 38 Seabed-conditionsurvey_(if off_-shore)------------------------- --------- NA-- -------------------------- 39 Contactnamelphoneforweekly_pr29ressreperls[explotatoryonlyj_------ ---------Yes- ------TravisPelC~er-5644511.-.-------------------------_----------------------- Geologic i C i Date: Engineering Date Publ' o e C ' si er C Date oner: omm ss om lo s lJ Welt 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. 1-34a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Feb 19 16:20:18 2009 Reel Header Service name .............LISTPE Date . ...................09/02/19 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................09/02/19 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 Mw0006161008 T. ONYEKWELU D. MASKELL SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FW L ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD ~o~- ~a s scientific Technical Services Scientific Technical Services 01-34A 500292160901 BP Exploration Alaska, Inc. Sperry Drilling Services 19-FEB-09 MWD RUN 4 MAD RUN 4 Mw0006161008 Mw0006161008 T. ONYEKWELU T. ONYEKWELU D. MASKELL D. MASKELL 8 lON 15E 1312 1566 67.70 39.20 Page 1 1~-~~s ~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1-34a.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 7978.0 6.125 7.000 8835.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS DRILLED OFF OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 7978'MD/7774'TVD IN 1-34. THE WHIPSTOCK WAS POSITIONED, THE WINDOW MILLED, AND A BIT OF RAT DRILLED DURING MWD RUN 2 - NO DATA ARE PRESENTED. NO PROGRESS WAS MADE DURING MWD RUN 1. 4. MWD RUNS 3,4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 3 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD) AND DRILLSTRING DYNAMICS-ROTATING (DDSR). MWD RUN 4 ALSO INCLUDED COMPENSATED THERMAL NEUTRON (CTN) AND AZIMUTHAL LITHO-DENSITY (ALD). MAD PASS DATA OVER THE INTERVAL 9472'MD-8754'MD (BIT DEPTHS) ACQUIRED WHILE POOH AFTER REACHING FINAL TD ARE PRESENTED SEPARATELY. S. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. DORTCH (SAIC/BP) DATED 17 FEBRUARY 2009, QUOTING AUTHORIZATION FROM PRIYA MARAJ (BP). MWD DATA ARE CONSIDERED PDC FOR 1-34A. 6. MWD RUNS 1-4 REPRESENT WELL 1-34A WITH API# 50-029-21609-01. THIS WELL REACHED A TOTAL DEPTH OF 9472'MD/9227'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED-HOLE SIZE). Page 2 1-34a.tapx CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = NON-ROTATED INTERVALS REFLECTING ALD SENSOR DEPTHS. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" BIT MUD WEIGHT: 8.4 PPG MUD SALINITY: 6600 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT File Header service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/19 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER THESE CURVES ARE SMOOTHED WITH FOR ALL CURVES. FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 7950.0 9415.5 RPS 7970.0 9422.5 RPX 7970.0 9422.5 RPD 7970.0 9422.5 RPM 7970.0 9422.5 FET 7978.5 9422.5 ROP 8004.5 9472.0 NPHI 8825.0 - 9387.5 NCNT 8825.0 9387.5 RHOB 8825.0 9402.5 PEF 8825.0 9402.5 DRHO 8825.0 9402.5 FCNT 8825.0 9387.5 Page 3 ~~ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED 1-34a.tapx DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 3 MWD 4 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 7950.0 8835.0 8835.0 9472.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum specification Block sub-type...0 Name service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MwD PU 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 7950 9472 8711 3045 7950 9472 FCNT MWD CP30 131.1 2475.38 690.531 1126 8825 9387.5 NCNT MWD CP30 14988.8 48460.4 28447 1126 8825 9387.5 RHOB MWD G/cc 0.953 3.192 2.34233 1156 8825 9402.5 DRHO MWD G/CC -1.726 0.673 0.0501972 1156 8825 9402.5 RPD MWD OHMM 0.28 2000 33.0503 2815 7970 9422.5 RPM MWD OHMM 0.31 2000 29.5937 2815 7970 9422.5 RPS MWD OHMM 0.41 1308.64 14.5931 2815 7970 9422.5 RPX MWD OHMM 0.37 1308.57 12.9126 2815 7970 9422.5 FET MWD HR 0.32 70.47 8.14537 2798 7978.5 9422.5 GR MWD API 13.66 488.37 131.069 2932 7950 9415.5 PEF MWD B/E 1.19 12.67 2.45646 1156 8825 9402.5 ROP MWD FPH 0.05 195.74 69.4103 2936 8004.5 9472 NPHI MWD PU 7.74 52.45 22.7801 1126 8825 9387.5. Page 4 1-34a.tapx First Reading For Entire File..........7950 Last Reading For Entire File...........9472 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/19 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.002 Physical EOF File Header service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/19 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 8691.5 RAT 8754.5 NPHI 8827.0 FCNT 8827.0 NCNT 8827.0 RHOS 8827.0 DRHO 8827.0 RPS 8827.0 RPD 8827.0 RPM 8827.0 FET 8827.0 RPx 8827.0 PEF 8827.0 all MAD runs merged using earliest passes. STOP DEPTH 9417.0 9472.0 9389.5 9389.5 9389.5 9404.5 9404.5 9424.0 9424.0 9424.0 9424.0 9424.0 9404.5 MERGED DATA SOURCE PBU TOOL CODE MAD RUN N0. MAD PASS NO. MERGE TOP MERGE BASE MwD 4 1 8691.5 9472.0 REMARKS: MERGED MAD PASS. Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Page 5 1-34a.tapx optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum Specification Block sub-type...0 Name Service order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MAD CP30 4 1 68 4 2 NCNT MAD CP30 4 1 68 8 3 RHOB MAD G/CC 4 1 68 12 4 DRHO MAD G/CC 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPS MAD OHMM 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 FET MAD HR 4 1 68 36 10 GR MAD API 4 1 68 40 11 PEF MAD B/E 4 1 68 44 12 RAT MAD FPH 4 1 68 48 13 NPHI MAD PU-S' 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8691.5 9472 9081.75 1562 8691.5 9472 FONT MAD CP30 130.52 2704.84 667.745 1126 8827 9389.5 NCNT MAD CP30 15060.3 46716.5 28466.2 1126 8827 9389.5 RHOB MAD G/CC 1.584 3.004 2.35797 1156 8827 9404.5 DRHO MAD G/CC -1.161 0.417 0.0534247 1156 8827 9404.5 RPD MAD OHMM 0.19 2000 42.7773 1195 8827 9424 RPM MAD OHMM 0.44 2000 53.5179 1195 8827 9424 RPS MAD OHMM 0.06 2000 26.4032 1195 8827 9424 RPX MAD OHMM 0.28 154.86 20.7371 1195 8827 9424 FET MAD HR 3.17 81.76 11.2411 1195 8827 9424 GR MAD API 11.97 539.53 64.2002 1452 8691.5 9417 PEF MAD B/E 1.11 13.22 2.43959 1156 8827 9404.5 RAT MAD FPH 0.68 1515.32 270.672 1436 8754.5 9472 NPHI MAD PU-S 6.77 52.51 23.6176 1126 8827 9389.5 First Reading For Entire File..........8691 Last Reading For Entire File...........9472 File Trailer service name... .......STSLI6.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/19 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Page 6 • 1-34a.tapx service sub Level Name... Version Number. ........1.0.0 Date of Generation.......09/02/19 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 7950.0 8787.0 SEMP 7970.0 8779.0 SEDP 7970.0 8779.0 SExP 7970.0 8779.0 SESP 7970.0 8779.0 SFXE 7978.5 8779.0 SROP 8004.5 8835.0 LOG HEADER DATA DATE LOGGED: 12-DEC-O8 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8835.0 TOP LOG INTERVAL (FT): 8005.0 BOTTOM LOG INTERVAL (FT): 8835.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 7.8 MAXIMUM ANGLE: 24.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 1 EWR4 ELECTROMAG. RESIS. 4 11204306 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 7978.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 10.25 MUD VISCOSITY (S): 48.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 7700 FLUID LOSS (C3): 3.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .650 98.0 MUD AT MAX CIRCULATING TERMPERATURE: .450 143.6 MUD FILTRATE AT MT: .700 98.0 MUD CAKE AT MT: .680 98.0 Page 7 • NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 1-34a.tapx Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units .. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MwD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 RoP MwD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7950 8835 8392.5 1771 7950 8835 RPD MwD030 OHMM 0.52 2000 16.8182 1619 7970 8779 RPM MwD030 OHMM 0.51 2000 7.7454 1619 7970 8779 RPS MWD030 OHMM 0.54 1308.64 3.47348 1619 7970 8779 RPX MWD030 OHMM 0.52 1308.57 3.87988 1619 7970 8779 FET MwD030 HR 1.46 70.47 12.6103 1602 7978.5 8779 GR MWD030 API 55.2 425.98 189.226 1675 7950 8787 ROP MWD030 FPH 0.11 144.85 41.7961 1662 8004.5 8835 First Reading For Entire File..........7950 Last Reading For Entire File...........8835 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/19 maximum Physical Record..65535 File Type ................Lo N2Xt File Name...........STSLIB.004 Physical EOF Page 8 • 1-34a.tapx File Header service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/19 Maximum Physical Record..65535 File Type. ............LO Previous .File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH SGRC 8787.5 SBD2 8825.0 CTFA 8825.0 TNPS 8825.0 SESP 8825.0 SFXE 8825.0 CTNA 8825.0 SEXP 8825.0 SEDP 8825.0 SNP2 8825.0 SEMP 8825.0 SCO2 8825.0 SROP 8835.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN EWR4 ALD 4 STOP DEPTH 9415.5 9402.5 9387.5 9387.5 9422.5 9422.5 9387.5 9422.5 9422.5 9402.5 9422.5 9402.5 9472.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Electromag Resis. 4 Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: header data for each bit run in separate files. 4 .5000 Page 9 15-DEC-08 Incite 74.11 Memory 9472.0 8835.0 9472.0 10.3 11.9 TOOL NUMBER 178505 241446 228501 231386 6.125 8835.0 Fresh water Gel 1-34a.tapx MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 50.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 1100 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMP ERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.850 85.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.000 163.0 MUD FILTRATE AT MT: 1.900 76.0 MUD CAKE AT MT: 1.970 76.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..... .....0 Data Specification Block Type .....0 Loging Direction ............ .....DOwn optical log depth units...... .....Feet Data Reference Point ......... .....undefined Frame Spacing....... ....... .....60 .lIN Max frames per record ........ .....undefined Absent value ................. .....-999 Depth units. .. .. .. ..... Datum specification Block sub -type...0 Name service order units size N sam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MwD040 CP30 4 1 68 4 2 NCNT MwD040 CP30 4 1 68 8 3 RHOB MwD040 G/CC 4 1 68 12 4 DRHO MWD040 G/CC 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 B/E 4 1 68 44 12 ROP MWD040 FPH 4 1 68 48 13 NPHI MwD040 Pu-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8787.5 9472 9129.75 1370 8787.5 9472 FONT MWD040 cP30 131.1 2475.38 690.531 1126 8825 9387.5 NCNT MWD040 CP30 14988.8 48460.4 28447 1126 8825 9387.5 RHOB MWD040 G/cc 0.953 3.192 2.34233 1156 8825 9402.5 DRHO MWD040 G/CC -1.726 0.673 0. 0501972 1156 8825 9402.5 RPD MwD040 OHMM 0.28 1843.71 55.0232 1196 8825 9422.5 RPM MwD040 OHMM 0.31 2000 59.1693 1196 8825 9422.5 RPS MWD040 OHMM 0.41 825.36 29.6455 1196 8825 9422.5 RPX MWD040 OHMM 0.37 806.03 25.14 1196 8825 9422.5 Page 1 0 • 1-34a.tapx FET MWD040 HR 0.32 65.11 2.16475 1196 8825 9422.5 GR MWD040 API 13.66 488.37 53.5737 1257 8787.5. 9415.5 PEF MwD040 B/E 1.19 12.67 2.45646 1156 8825 9402.5 ROP MWD040 FPH 0.05 195.74 105.434 1274 8835.5 9472 NPHI MwD040 PU-S 7.74 52.45 22.7801 1126 8825 9387.5 First Reading For Entire File..........8787.5 Last Reading For Entire File...........9472 File Trai l Service service version Date of Maximum Fi 1 e Tye Next Fi 'r name... .......STSLIB.004 sub Level Name... Number. ........1.0.0 Generation.... .09/02/19 Physical Record..65535 ~e ................LO le Name...........STSLIB.005 Physical EOF File Header Service name... .......STSL2B.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/19 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MAD Curves and log header data DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY for each pass of each run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 8691.5 9417.0 SRAT 8754.5 9472.0 SFXE 8827.0 9424.0 SNP2 8827.0 9404.5 SC02 8827.0 9404.5 TNPS 8827.0 9389.5 SESP 8827.0 9424.0 SEMP 8827.0 9424.0 CTFA 8827.0 9389.5 SEDP 8827.0 9424.0 SEXP 8827.0 9424.0 CTNA 8827.0 9389.5 5BD2 8827.0 9404.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWA RE VERSION: Page 11 15-DEC-08 Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) 1-34a.tapx 74.11 Memory 9472.0 8754.0 9472.0 VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY CTN COMP THERMAL NEUTRON EWR4 Electromag Resis. 4 ALD Azimuthal Litho-Dens BOREHOLE AND CASING DATA 10.3 11.9 TOOL NUMBER 178505 241446 228501 231386 OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 8835.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 50.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 1100 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.850 85.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.000 163.0 MUD FILTRATE AT MT: 1.900 76.0 MUD CAKE AT MT: 1.970 76.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MAD041 CP30 4 1 68 4 2 NCNT MAD041 CP30 4 1 68 8 3 RHOB MAD041 G/CC 4 1 68 12 4 Page 12 • 1-34a.tapx DRHO MAD041 G/CC 4 1 68 16 5 RPD MAD041 OHMM 4 1 68 20 6 RPM MAD041 OHMM 4 1 68 24 7 RPS MAD041 OHMM 4 1 68 28 8 RPx MAD041 OHMM 4 1 68 32 9 FET MAD041 HR 4 1 68 36 10 GR MAD041 API 4 1 68 40 11 PEF MAD041 B/E 4 1 68 44 12 RAT MAD041 FPH 4 1 68 48 13 NPHI MAD041 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8691.5 9472 9081.75 1562 8691.5 9472 FONT MAD041 CP30 130.52 2704.84 667.745 1126 8827 9389.5 NCNT MAD041 CP30 15060.3 46716.5 28466.2 1126 8827 9389.5 RHOB MAD041 G/CC 1.584 3.004 2.35797 1156 8827 9404.5 DRHO MAD041 G/CC -1.161 0.417 0.0534247 1156 8827 9404.5 RPD MAD041 OHMM 0.19 2000 42.7773 1195 8827 9424 RPM MAD041 OHMM 0.44 2000 53.5179 1195 8827 9424 RPS MAD041 OHMM 0.06 2000 26.4032 1195 8827 9424 RPx MAD041 OHMM 0.28 154.86 20.7371 1195 8827 9424 FET MAD041 HR 3.17 81.76 11.2411 1195 8827 9424 GR MAD041 API 11.97 539.53 64.2002 1452 8691.5 9417 PEF MAD041 B/E 1.11 13.22 2.43959 1156 8827 9404.5 RAT MAD041 FPH 0.68 1515.32 270.672 1436 8754.5 9472 NPHI MAD041 Pu-S 6.77 52.51 23.6176 1126 8827 9389.5 First Reading For Entire File..........8691.5 Last Reading For Entire File...........9472 File Trailer Service name... .......STSLIB.005 service sub Level Name... Version Number. ........1.0.0 Date of Generation.......09/02/19 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................09/02/19 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................09/02/19 Ori gin ...................STS Reel Name ................UNKNOWN Scientific Technical services Page 13 Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF End Of LIS File 1-34a.tapx Writing Library Page 14 Scientific Technical Services BP Exploration Alaska Inc Well: 01-34 Field: Prudhoe Bay North Slope, Alaska, USA Report Production Array Log Analysis Prepared For : BP Exploration Alaska Inc Logging Date : 11/16/2013 Report Date : 12/02/2013 Submitted by: Waqar Khan Phone: +1(281)575-5051 10200 Bellaire Blvd, Houston, Texas-77072 Email: waqar.khan2@halliburton.com HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OF WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS OF RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF BP Exploration Alaska Production Array Log Analysis 1 TABLE OF CONTENTS 1.0 EXECUTIVE SUMMARY ............................................................................................................................. 2 2.0 BACKGROUND AND OBJECTIVES .......................................................................................................... 3 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT ............................................................ 4 4.0 PRODUCTION LOG PROCESSING ........................................................................................................... 7 4.1 FLOWING SURVEY ...................................................................................................................................... 9 BP Exploration Alaska Production Array Log Analysis 2 1.0 EXECUTIVE SUMMARY Production logging was done in Well 01-34 on November 16th, 2013 in flowing conditions with the objective of determining the production profile. As the well is deviated, Resistance Array Tool (RAT) and Spinner Array Tool (SAT) were included in the tool string to accurately estimate the holdup and phase velocities as there can be segregated flow of the three phases due to well deviation. The flowing PL analysis showed the oil production to be coming from all sets of perforations, with the bottom perforation (9310’-9320’) producing the most amount of oil. This set of perforation is contributing about 45% of the total oil flow. The top set of perforations (9190’- 9200’) is producing 61% of the total water production. For the analysis, SAT and RAT along with the gas holdup tool were used to separate out the three phases. The reported surface production while running the PL was 269 STB/D oil and 5365 BPD water with 1.7 MSCF/D. Based on the well test data during logging, the well is in a stable condition. The estimated flow rates at surface condition while flowing from each of the perforations is given in the table below: Perforations Oil Rate Gas Rate Water rate From , ft To , ft STB/D % Mscf/D % STB/D % 9190 9200 79.3 26.1 274 61.9 3437 60.9 9265 9280 89 29.2 66.4 15.0 949 16.8 9309.5 9320 136 44.7 102 23.1 1262 22.3 Total 304.3 442.4 5648 BP Exploration Alaska Production Array Log Analysis 3 2.0 BACKGROUND AND OBJECTIVES The objectives for running the PL were to identity the production profile and also determine the need of setting a plu g across the bottom perforation to try and reduce water production. BP Exploration Alaska Production Array Log Analysis 4 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT Well 01-34 is completed with 4.5 inch production tubing across which the production log was run. The wellbore schematic is presented in the Figure 1. The tool string diagram used for the PL logged is presented in Figure 2. The tool string consisted of the following production logging sensors: Gamma Ray - Casing Collar Locator – Pressure - Resistance Array Tool – Gas holdup – Caliper - Spinner Array Tool – Radioactive Density –Capacitance Water Holdup – Inline Spinner – Temperature – Caged Fullbore Spinner. The data quality is summarized below TOOL USAGE LOG DESCRIPTION LOG QUALITY REMARKS WELL BORE PARAMETERS QP Well bore pressure Good TEMP Well bore temperature Good FLUID TYPE FDR Radioactive density tool uses radioactive source and detector to measure density and is a center sample device Good CWH Uses capacitance to measure the differences between hydrocarbons and water Good RAT Resistivity Array Tool Good UP 160 pass shows an inconsistent response on the RAT tool, possibly due to bubble entrapment and has not been used in the interpretation GHT Gas HoldUp Tool Good FLUID VELOCITY CFB Caged Fullbore Spinner Good Shows good data 9300’ ft and above. ILS Inline Spinner Good SAT Spinner Array Tool Good . BP Exploration Alaska Production Array Log Analysis 5 . Figure 1: Wellbore Schematic BP Exploration Alaska Production Array Log Analysis 6 Figure 2: PL Toolstring BP Exploration Alaska Production Array Log Analysis 7 4.0 PRODUCTION LOG PROCESSING The production log data from the flowing were processed using the PLATO software. The software uses a global probabilistic method for the production log analysis. In this method, known as the Maximum Likelihood method, a well flow model is compared to all available data and improved, by optimization, until the best possible match with the data is obtained. By using this method the result is the most likely interpretation. A comparison between the model and the data is shown in this report and allows the analyst or the reader to determine validity of the answer obtained. Potential sources of discrepancies include tool measurement errors, conflicts between the parameters or conditions that make the underlying empirical models (such as flow regimes) less applicable.  The flow regimes were determined, directly from the flow rates and holdups, according to the Taitel- Dukler analytic model.  The profile factors, to calculate the true fluid velocity from the apparent velocity, were based on the Reynolds numbers.  Solution gas in oil was derived from the correlations (Vasquez-Beggs or Øistein- Glaso). The analysis was performed in six steps:  The data preparation to filter the data, compute gradients and error estimates.  The calibration of the array tools and full-bore flow meter.  The computation of the layered holdup and layered flow-rates.  The profile determination to identify the potential producing and/or injecting zones.  The computation of the flow rates by global optimization.  The computation of surface productions and reporting. BP Exploration Alaska Production Array Log Analysis 8 The water density and viscosity were calculated using a salinity of 20000 ppm. The Craft & Hawkins correlation was used. The oil density and viscosity were calculated using an oil gravity of 25.7 API. The Vasquez & Beggs correlation was used to calculate the solution gas. Viscosity was calculated using the Beggs & Robinson correlation. The Pc and Tc parameters were calculated using the Brown et al. correlation. The gas viscosity was calculated using the Lee Gonzales Eakin correlation. The following gas parameters were used: GasType Miscellaneous SPGG UNITY .750 GP-CO2 UNITY 0 GP-H2S UNITY 0 GP-Nitrogen UNITY 0 Utilizing the above fluid information, measured down hole oil density, temperature & pressure, the following fluid properties were calculated at well conditions: feet Twf Pwf Bwater water water Boil oil oil Rsb Bgas gas gas °F psi UNITY g/cc cP UNITY g/cc cP ft3/bbl UNITY g/cc cP 9025.00 198 2720 1.03 .987 .331 1.36 .754 .762 747 .00607 .151 .0194 9059.00 198 2734 1.03 .987 .331 1.36 .754 .762 747 .00604 .152 .0194 9092.50 198 2748 1.03 .987 .331 1.36 .754 .763 747 .00602 .152 .0195 9126.50 198 2762 1.03 .987 .331 1.36 .754 .763 747 .00599 .153 .0195 9160.00 198 2778 1.03 .987 .331 1.36 .754 .763 747 .00596 .154 .0196 9194.00 199 2792 1.03 .986 .329 1.36 .754 .760 746 .00595 .154 .0196 9227.50 200 2806 1.03 .986 .327 1.36 .754 .758 746 .00593 .155 .0197 9261.50 200 2822 1.03 .986 .327 1.36 .754 .759 746 .00590 .155 .0197 9295.00 200 2836 1.03 .986 .325 1.36 .754 .757 746 .00589 .156 .0198 9329.00 201 2850 1.03 .986 .325 1.36 .754 .757 746 .00587 .156 .0198 To estimate the flow rates, the caliper log recorded during the UP passes was used to estimate the nominal ID throughout the log. Tool information The following capacitance tool characteristics were used HydroWater Hz 28560 (Downhole Measurement) HydroHyd Hz 34533 (Surface Calibration) The following gas holdup tool characteristics were used GasHoldupWater Hz 29821 (Downhole Measurement) GasHoldupGas Hz 14805 (Surface Calibration) BP Exploration Alaska Production Array Log Analysis 9 4.1 FLOWING SURVEY The raw data from the flowing survey are presented in the Figures 3 to 8. Figure 3 has the data from conventional production logging sensors. Figure 4 has the same data that was presented in Figure 3 with the addition of the station measurements. To generate this plot, Emeraude software was used which allows overlay of the station measurements and the logging passes in the same track. Plato can only plot the st ation measurement against time. For the interpretation, since all the passes showed a consistent response, all of them have been used in the interpretation. The response from the Resistance Array Tool is presented in Figure 5. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values. Only the active sensors were used in the interpretation. Figure 6 shows only the active RAT sensors along with the station measurements. The response from the Spinner Array Tool is presented in Figure 7. All the spinners showed a good consistent response. From the raw data it is clear that all three perforations are producing fluids, with the top perforation producing the most fluid owing to the sharp deflection. From the spinner response, the velocity profile was estimated using the slopes calculated from the spinner calibration (Figures 9 and 10). Velocity is highest across the top perforation, indicating this zone as the main contributor. The calibrated RAT response is presented in Figure 11. The estimated SAT velocities and the RAT holdups are used to calculate the flow profile presented in the Figure 12. The final flow profile, after the global optimization, along with the comparison of the measured and theoretical tool values are presented in Figure 13. The production rates at surface conditions estimated from the production log analysis are presented in Figure 14 and are summarized in the table below: feet Profile Q-Water- STP Qp-Water- STP Q-Oil- STP Qp-Oil- STP Q-Gas- STP Qp-Gas- STP BFPD BFPD BFPD BFPD MCFD MCFD 9190.00 9200.00 Produce 5648 3437 304 79.3 442 274 9265.00 9280.00 Produce 2211 949 225 89.0 168 66.4 9309.50 9320.00 Produce 1262 1262 136 136 102 102 BP Exploration Alaska Production Array Log Analysis 10 Raw Data - The figure below summarizes the input data recorded at the well site. - Each pass is shown with a fixed predefined color. Figure 3: Input data from the conventional production logging sensors BP Exploration Alaska Production Array Log Analysis 11 Figure 4: Input data from the conventional production logging sensors along with the station measurements. BP Exploration Alaska Production Array Log Analysis 12 The figure below shows the RAT input data. The first track shows the RAT rotation curves for each pass. The next tracks show the RAT data: A curve for each pass for each of the 12 probes. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values and were not used in the interpretation. Figure 5: Input data from the Resistance Array Tool (RAT) BP Exploration Alaska Production Array Log Analysis 13 Figure 6: Input data from the Resistance Array Tool (RAT) showing just the active sensors along with station measurements BP Exploration Alaska Production Array Log Analysis 14 The figure below shows the SAT input data. The first track shows the SAT rotation curves for each pass. The next track shows the linespeed for each pass. The remaining tracks show the array spinner data: A curve for each pass for each of the 6 array spinners and for the fullbore (ASpinner07) and inline spinner (ASpinner08). The fullbore spinner does not appear to be turning well below 9275’. Figure 7: Input data from the Spinner Array Tool (SAT) and conventional spinners. BP Exploration Alaska Production Array Log Analysis 15 Figure 8: Input data from the Spinner Array Tool (SAT) and conventional spinners along with the station measurements. BP Exploration Alaska Production Array Log Analysis 16 Pre- Processing Figure 8a: Passes showing a consistent response have been used in for averaging out the measurements. BP Exploration Alaska Production Array Log Analysis 17 Calibration of Spinner Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and measured Array Tool responses. Track 2: Line-speed for each pass. Track 3: 'Unwrapped' rotation curve for each pass. Track 4: Normalized layered velocity profile. This profile is optimized by comparing the measured and theoretical SAT response for each pass of each spinner. Tracks 5-10: Measured and theoretical SAT responses for each spinner. Track 11: Measured and theoretical responses for the full-bore spinner. Track 12: Measured and theoretical responses for the inline spinner. Below are the results from the calibration of the SAT data. The determination of this calibration is a layered velocity profile. Figure 9: Velocity profile from SAT data. BP Exploration Alaska Production Array Log Analysis 18 The image below displays cross plots for each SAT spinner and the Inline spinner. The estimated slopes are used for converting the spinner response to flow velocities. Figure 10: Spinner cross plot BP Exploration Alaska Production Array Log Analysis 19 Calibration of Resistance Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and the measured RAT responses. Track 2: 'Unwrapped' rotation curve for each pass. Track 3: Normalized layered RAT profile. This profile is optimized by comparing the measured and theoretical RAT response for each pass for each probe. Tracks 4-15: Measured and theoretical RAT responses for each probe. Below are the results from the calibration of the RAT data. The determination of this calibration is a layered resistivity profile. To obtain this profile, calibrations for water/ hydrocarbon were entered for each probe. Figure 11: Calibrated RAT response. BP Exploration Alaska Production Array Log Analysis 20 Holdup and Velocity Profile: Shown on the image below from left to right: Track 3: Layered velocity profile. Track 4: Layered water holdup profile. Track 5: Layered oil holdup profile. Track 6: Layered gas holdup profile Track 7: Total holdup. Track 8: Cumulative flow rates Track 9: Density of fluid Track 10: Apparent Velocity from Fullbore Spinner Track 11: Apparent Velocity from Inline Spinner Figure 12: Holdup and velocity profile BP Exploration Alaska Production Array Log Analysis 21 Flow Profile The quantitative production rates were determined by comparing the well flow model with all available data. The figure below is provided to verify the agreement of the flow model with the data. In this figure the data is represented by the blue curves, while the calculated tool values are shown in red. The uncertainty interval is represented as a gray band around the data. The uncertainty interval corresponds to one standard deviation. The small fluctuations around the data are to be expected, since the tools have intrinsic errors. Large sustained discrepancies indicate problems with the data, conflicts between parameters or conditions that make the underlying empirical models less applicable. To the right of the figure the flow regimes are shown. Within the transition zones several regimes can exists intermittently. Figure 13: Flow profile at reservoir conditions BP Exploration Alaska Production Array Log Analysis 22 The production rates at surface conditions are presented in the figure below: Figure 14: Flow profile at surface conditions