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210-100
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, March 17, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC C-37B PRUDHOE BAY UNIT C-37B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/17/2025 C-37B 50-029-22360-02-00 210-100-0 N SPT 8430 2101000 2250 617 2490 2292 2252 0 2 3 3 OTHER P Brian Bixby 1/31/2025 MIT-T as per C.O. #736. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT C-37B Inspection Date: Tubing OA Packer Depth 610 616 619 622IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB250131132851 BBL Pumped:1 BBL Returned:1 Monday, March 17, 2025 Page 1 of 1 9 9 9 9 9 9 999 99 9 9 9 9 9 2LOSURGXFHU ,$UHPHGLDOFHPHQW MIT-T as per C.O. #736 James B. Regg Digitally signed by James B. Regg Date: 2025.03.17 11:45:09 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, March 17, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC C-37B PRUDHOE BAY UNIT C-37B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/17/2025 C-37B 50-029-22360-02-00 210-100-0 N SPT 8430 2101000 2250 957 2475 2388 2365 3 8 8 6 OTHER P Brian Bixby 1/31/2025 CMIT TxIA as per C.O. # 736. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT C-37B Inspection Date: Tubing OA Packer Depth 953 2504 2422 2394IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB250131133206 BBL Pumped:3.2 BBL Returned:3 Monday, March 17, 2025 Page 1 of 1 9 9 9 9 9 9 9 99 99 9 9 9 9 9 9 2LOSURGXFHU ,$UHPHGLDOFHUPHQW CMIT TxIA C.O. # 736 James B. Regg Digitally signed by James B. Regg Date: 2025.03.17 11:42:48 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, February 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC C-37B PRUDHOE BAY UNIT C-37B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 02/17/2023 C-37B 50-029-22360-02-00 210-100-0 N SPT 8430 2101000 2108 1274 2517 2302 2267 0 0 0 0 OTHER P Adam Earl 1/4/2023 MIT-T tested as per CO736 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT C-37B Inspection Date: Tubing OA Packer Depth 881 899 899 897IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230106112655 BBL Pumped:0.5 BBL Returned:0.4 Friday, February 17, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, February 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC C-37B PRUDHOE BAY UNIT C-37B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 02/17/2023 C-37B 50-029-22360-02-00 210-100-0 N SPT 8430 2101000 2108 847 2527 2413 2386 0 1 2 2 OTHER P Adam Earl 1/4/2023 CMIT-T&I/A Tested as per CO 736 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: PRUDHOE BAY UNIT C-37B Inspection Date: Tubing OA Packer Depth 759 2535 2516 2506IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230106113703 BBL Pumped:4.2 BBL Returned:3.8 Friday, February 17, 2023 Page 1 of 1 CMIT-T&I/A Tested as per CO 736 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:210-100 6.50-029-22360-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11625 11586 8993 None None None None Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36 - 116 36 - 116 1490 470 Surface 3293 13-3/8" 35 - 3328 35 - 3250 5020 2260 Intermediate 9021 9-5/8" 32 - 9053 32 - 8437 7930 6620 Production 665 7" 8893 - 9558 8297 - 8817 8160 7020 Perforation Depth: Measured depth: 9027 - 11570 feet True vertical depth:8415 - 8994 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# L-80 30 - 9558 31 - 8817 Packers and SSSV (type, measured and true vertical depth) No Packer Liner 2424 2-3/8" 9201 - 11625 8565 - 8992 11200 11200 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 265521291060 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Wyatt Rivard wrivard@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.777.8547 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8992 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028305 PBU C-37B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 374 30 74 268260 1650 By Samantha Carlisle at 2:56 pm, Apr 20, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.04.20 13:37:35 -08'00' Stan Golis (880) DSR-4/20/21MGR29JUL2021 RBDMS HEW 4/21/2021 SFD 4/20/2021 ACTIVITY DATE SUMMARY 4/5/2021 T/I/O= 2375/875/vac Temp= SI, (PERFORATING) Assist Pollard SL by pumping 35 bbls of 180* F crude down TBG. SL in control of well upon departure, FWHP's=1500/900/vac 4/5/2021 ***WELL SI ON ARRIVAL*** HOT BRUSH & FLUSH TBG DWN TO DMY SSSV @ 2106' MD w/ FULL BORE BRUSH & 2.83" G-RING TO REMOVE PARAFFIN. LRS PUMPED 35 BBLS 180* CRUDE FOR BRUSH & FLUSH. PULLED 2.75" DMY SSSV @ 2106' MD. (ia climbed 25 psi over 3 hour period) DRIFT TBG w/ 2.71" CENT, 2.5" SAMPLE BAILER, UNABLE TO PASS 2144' SLM DUE TO PARAFFIN. ***IN PROGRESS, JOB CONT. ON 4/6/21*** 4/6/2021 ***JOB CONT. FROM 4/5/21*** HOT BRUSH & FLUSH TBG DWN TO 6500' SLM w/ FULL BORE BRUSH, 2.70" G- RING TO REMOVE PARAFFIN (worked through paraffin dwn to 4500' slm) LRS PUMPED 55 BBLS CRUDE FOR BRUSH & FLUSH DRIFT TBG TO 9100' SLM w/ 2.72" CENT, 3' x 2.5" SAMPLE BAILER (no issues) ***JOB COMPLETE, WELL LEFT SI, DSO NOTIFIED OF STATUS** 4/6/2021 T/I/O= 1725/880/vac, Temp=AMB, (PERFORATING) Assist Pollard SL by pumping 55 bbls of 180*F crude down Tbg for B&F. Pollard in control of well upon departure. FWHP's=1250/980/1 4/7/2021 T/I/O = 1280/900/20. Temp = SI. WHPs (Eval T x IA). No AL. IA valve has a extra casing valve piggybacked. SV, WV, SSV = C. MV = O. IA, OA = OTG. 11:20 4/8/2021 ...Well shut in on arrival... (HES EL - adperf) UNABLE TO PASS 8,771' WITH 2-1/2" PERF GUN (possibly existing cement sheath from IA cement job milled out to 2.73" from 6,700' - 8,875') REBULD 2" PERF GUN. ...Continued on 9-APR-21.... 4/9/2021 ...Continued from 8-APR-21... (HES EL - adperf) PERFORATE 9,027' - 9,029' WITH 2' x 2" MAXFORCE CHARGES WITH 7GR, 6 SPF, 60 DEG PHASING HSC. API 19B PENETRATION = 20.3", ENTRANCE HOLE = 0.28". ***Job Complete. Well shut in on departure. SL to reset DSSSV.*** 4/17/2021 ***WELL S/I ON ARRIVAL*** (Perforating) SET 2.75" XDB DSSSV (1.75" min id - Oal = 35") AT 2,086' SLM / 2,106' MD. RAN 3-1/2" CHECK SET TO X-LOCK AT 2,086' SLM (Tool indicates good set). ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** Daily Report of Well Operations PBU C-37B MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 6, 2021 TO: Jim Regg !7 _ P.I. Supervisor �\ �� <j 1/l ���'� SUB.IECT: Mechanical Integrity Tests f Hilcorp North Slope, LLC C -37B FROM: Bob Noble PRUDHOE BAY UNIT C -37B Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry -1 I — NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT C -37B . API Well Number 50-029-22360-02-00 Inspector Name: Bob Noble Permit Number: 210-100-0 Inspection Date: 12/14/2020 Insp Num: mitRCN201214144816 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Wellc-37B Type Inj N -TVD Tubing 117 2230 2148 - 2124 - PTD _101000 Type -- Test psi - 2200 IA +-- 136 -- 169 170 - j 171 - PTD T e Test � SPT _ -- I BBL Pumped: 0.5 BBL Returned: o OA 8 9 =L 9 1- 9 — Interval OTHER P/F Notes: MIT -T for post squeeze as per Sundry 319-363. ✓ !I - Ll; l C�"fl Wednesday, January 6, 2021 Page 1 of I Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:210-100 6.50-029-22360-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11625 11586 8993 None None None None Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36 - 116 36 - 116 1490 470 Surface 3293 13-3/8" 35 - 3328 35 - 3250 5020 2260 Intermediate 9021 9-5/8" 32 - 9053 32 - 8437 7930 6620 Production 665 7" 8893 - 9558 8297 - 8817 8160 7020 Perforation Depth: Measured depth: 9188 - 11570 feet True vertical depth:8554 - 8994 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# L-80 30 - 9558 30 - 8817 Packers and SSSV (type, measured and true vertical depth) No Packer Liner 2424 2-3/8" 9201 - 11625 8565 - 8992 11200 11780 12. Stimulation or cement squeeze summary: Intervals treated (measured): 241-bbls of 15.8-ppg Class G cement in IA. Final treating pressure = 4138-psi. Left 900-psi on well after cement job complete. Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 262160025435 405108 1900 8356 70 289 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Aras Worthington aras.worthington@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-4763 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8992 Sundry Number or N/A if C.O. Exempt: 319-363 No SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 IA Cement Squeeze Operations shutdown Change Approved Program 5 IA cemented from 8862' to 4940'. Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028305 PBU C-37B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): CBL Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:17 am, Jan 06, 2021 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2021.01.05 12:18:47 - 09'00' Stan Golis MGR17FEB2021 RBDMS HEW 1/13/2021 SFD 1/13/2020DSR-1/6/21 ACTIVITY DATE SUMMARY 12/6/2019 ***WELL S/I ON ARRIVAL*** (Cement Squeeze) R/U SWCP 4518. ****JOB CONTINUED ON 07-DEC-2019**** 12/7/2019 ***JOB CONTINUED FROM 06-DEC-2019*** (Cement Squeeze) PULL HES 3-1/2" EVO-TRIEVE PLUG FROM 9165' MD. DRIFT W/ 3-1/2" GR, G-FN XO, 10' x 2-3/8" SPACER PIPE, 2-3/8" PTSA STINGER ASS. TO DEPLOY SLV @ 9201' MD. ***WELL TURNED OVER TO DSO*** 12/14/2019 ***WELL FOUND S/I ON ARRIVAL***(cement squeeze) SET 2-3/8'' SPACER PUPS, AND PTSA W/ 2-3/8" R-PLUG INTO TOL AT 9201' MD. SET 3-1/2" WFD WP PKR W/ NS QCLL INTO TOP OF 2-3/8" SPACER PUPS AT 9163' MD. ****CONT WSR ON 12-15-19**** 12/14/2019 T/I/O= 2300/800/200. LRS unit 46 to assist Slickline (CEMENT SQUEEZE (OA/IA DWNSQZ) Pumped 3 bbls 60/40, followed by 125 bbls of crude down TBG to load. Pumped 32 bbls 100* Crude into IA to load. ******** Job Continued to 12/15/2019********* 12/14/2019 T/I/O = 2350/750/250. Temp = SI. Tbg & IA FL (SL call-in). No AL. Tbg FL @ 6280' (681' above Sta #1, Dmy, 55 bbls). IA FL @ 580' (36 bbls). SL in control of well upon departure. 12:50 12/15/2019 T/I/O = 257/827/414 Temp-SI. ********Job continued from 12/14/2019******* LRS Unit 46 assist SL (CEMENT SQUEEZE OA/IA DWNSQZ). CMIT-TxIA PASSED at 2529/2614 psi. Pumped 23 bbls of 72* Crude into TBG/IA to achieve test pressure. First 15 minutes, TBG lost 108 psi and the IA lost 105 psi. Second 15 minutes, TBG lost 30 psi and the IA lost 30 psi. Bled back 13.1 bbls. SL in control of well upon departure. WFO notified upon departure. FWHP's = 769/796/358 12/15/2019 ****CONT WSR FROM 12-14-19****(cement squeeze) LRS PERFORM PASSING CMIT-Tx IA TO 2500 psi (see LRS log for details) SET 3-1/2" WHIDDON CATCHER @ 9125' SLM. PULL RK-DGLV FROM STA #1 (6961' MD) & STA #2 (4439' MD) SET RK-LGLV IN STA #2 (4439' MD) & RK-OGLV IN STA #1 (69614' MD) PULL EMPTY 3-1/2" WHIDDON CATCHER FROM 9125' SLM. EQUALIZE 2-3/8" RR-PLUG @ 9204' MD. ****CONT WSR ON 12-16-19**** 12/16/2019 ****CONT WSR FROM 12-15-19****(cement squeeze) PULL 2-3/8" RR-PLUG FROM 9167' SLM ****WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED**** 12/19/2019 T/I/O = 260/490/110. Temp = SI. WHPs (Monitor TxIA). No AL. SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:50 12/19/2019 T/I/O = 260/500/110. Temp = SI. WHPs (Monitor TxIA). No AL. IAP increased 10 psi since 03:50 this morning. SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:50 12/21/2019 T/I/O = 260/510/110. Temp = SI. WHPs (Monitor TxIA). 2" hardline PBGL rigged up from TBG of C-04 to IA CV. TP unchanged, IAP increased 30 psi and OAP unchanged. SV, WV, SSV = C. MV = O. IA, OA = OTG. 02:30 Daily Report of Well Operations PBU C-37B Daily Report of Well Operations PBU C-37B 12/21/2019 T/I/O = 260/520/120. Temp = SI. Assist Ops w/POP. PBGL rigged up from C-04. IA FL @ 600' (37 bbls). OA FL @ near surface. Bled OAP several times through the job. T/I/O = 200/1440/225. *** CONTINUED WSR ON 12/22/19 *** 12/22/2019 ***CONTINUED WSR FROM 12/21/19*** T/I/O = 200/1440/225. Temp = 45°. Assist Ops w/POP. PBGL rigged up from C-04. Bled OAP to BT from 255 psi to 50 psi in 1 min, returned ~0.15 bbls. Final WHPs = 200/1440/60. Temp = 47°. SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:45 12/23/2019 T/I/O = 300/1550/180. Temp = 50°. WHPs (Monitor TxIA). PBGL rigged up from C- 04. WHT increased 5° deg F, TP increased 100 psi, IAP increased 110 psi, OAP increased 90 psi overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 01:30 12/24/2019 T/I/O = 180/1250/180. Temp = 45°. WHPs (Monitor TxIA). PBGL rigged up from C- 04. OPs decreased gas lift rate. WHT decreased 5°, TP decreased 120 psi, IAP decreased 300 psi, OAP unchanged overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 01:30 12/24/2019 T/I/O = 180/1090/180. Temp = 48*. WHPs (Monitor T x IA). PBGL rigged up from C- 04. The TP & OAP remained unchanged and the IAP decreased 160 psi overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:40 12/26/2019 T/I/O = 170/1090/200. Temp = 48°. WHPs (Monitor TxIA). PBGL rigged up from C- 04. WHT decreased 3°, TP decreased 10 psi, IAP decreased 160 psi, OAP increased 20 psi overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 00:45 12/27/2019 T/I/O = 180/1080/200. Temp = 43°. WHPs (Monitor Tx IA). PBGL rigged up from C- 04. WHT decreased 5°, TP increased 10 psi, IAP decreased 10 psi, OAP increased 30 psi overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:30 12/28/2019 T/I/O = 180/960/160. Temp = 35F. WHPs (monitor TxIA). No AL. Poor boy rigged up from C-04, online. WHT decreased 8°. TP unchanged, IAP decreased 120 psi, OAP decreased 40 psi overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:45 12/29/2019 T/I/O = 170/1800/160. Temp = 30°. WHPs (monitor TxIA). No AL. PBGL rigged up from C-04, online. Temp decreased 5°, TP decreased 10 psi, IAP increased 840 psi, OAP unchanged overnight. Clear hydrates/debris from IA CV & jewelry. Assist Ops w/ installing heater in well house. SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:00 12/30/2019 T/I/O = 180/1740/280. Temp = 26F. WHPs (monitor TxIA). PBGL rigged up from C- 04. Heater in wellhouse. Temp decreased 4°, TP increased 10 psi, IAP decreased 60 psi, OAP increased 120 psi overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:45 12/31/2019 T/I/O = 170/1370/210. Temp = 34°. WHPs (monitor TxIA). PBGL rigged up from C- 04. Heater in wellhouse. Temp increased 8°, TP decreased 10 psi, IAP decreased 370 psi, OAP decreased 70 psi overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:30 1/1/2020 T/I/O = 170/1360/170. Temp = 38°. WHPs (monitor TxIA). PBGL rigged up from C- 04. Heater in wellhouse. Temp increased 4°, TP unchanged, IAP decreased 10 psi, OAP decreased 70 psi overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 21:30 Daily Report of Well Operations PBU C-37B 1/4/2020 T/I/O = 170/1470/0+. Temp = 44°. WHPs (monitor TxIA). PBGL rigged up from C- 04. Heater in wellhouse. Temp increased 6°. TP unchanged, IAP increased 110 psi, & OAP decreased to 0+ psi overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:30 1/5/2020 T/I/O = 180/1400/260. Temp = 52°. WHPs (Eval TxIA). No AL. PBGL rigged up from C-04, online @ 1410 psi. Temp increased 8°, TP increased 10 psi, IAP decreased 70 psi, OAP increased 260 psi overnight. Heater installed in well house working properly. SV = C. WV, SSV, MV = O. IA, OA = OTG. 10:30 1/8/2020 T/I/O = 170/1450/180. Temp = 40°. WHPs (eval TxIA). PBGL is online. Temp decreased 4°. IAP increased 50 psi, OAP increased 180 psi from 1/5/20. SV = C. WV, SSV, MV = O. IA, OA = OTG. 01:40. 1/8/2020 T/I/O = 160/1450/140. Temp = 40°. WHPs (Eval TxIA). PBGL rigged up from C-04, online. TP decreased 10 psi, IAP unchanged, OAP decreased 40 psi overnight. SV = C.. WV, SSV, MV = O. IA, OA = OTG. 22:25 1/9/2020 T/I/O = 180/1410/180. Temp = 34°. WHPs (eval TxIA). PBGL rigged up from C-04, online. TP increased 10 psi, IAP decreased 40 psi, OAP unchanged overnight. Cleared debris from PBGL & IA jewelry. SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:30 1/10/2020 T/I/O = 180/1440/170. Temp = 34°. WHPs (eval TxIA). PBGL rigged up from C-04, online. TP unchanged, IAP increased 30 psi, & OAP decreased 10 psi overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:30 1/11/2020 T/I/O = 290/1730/270. Temp = 42°. WHPs (Eval TxIA). PBGL rigged up from C-04, online. TP increased 90 psi, IAP increased 290 psi, & OAP increased 100 psi overnight. Heater installed in WH and working properly. SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:50 1/13/2020 T/I/O = 190/1600/370. Temp = 74°. WHPs (Eval TxIA). PBGL rigged to IA is online. OA FL @ surface. TP decreased 100 psi, IAP decreased 130 psi, and the OAP increased 100 psi since 1/11/20. SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:20 1/14/2020 T/I/O = 290/1760/380. Temp = 66°. WHPs (Eval TxIA). PBGL rigged to IA is online. TP increased 100 psi, IAP increased 160 psi, OAP increased 10 psi, & decreased 8° overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:20 1/16/2020 T/I/O = 1660/1380/Vac. Temp = SI. WHPs (eval TxIA). PBGL has beed rigged off of IA. Ops lock on WV. Heater in wellhouse and working properly. Tree cap bled back to 0 psi and door left open. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:15. 1/17/2020 T/I/O = 1420/1420/VAC. Temp = SI. WHPs (eval TxIA). No AL. Heater working properly. Bled treecap. SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:30 1/18/2020 T/I/O = 1440/1440/VAC. Temp = SI. WHPs (eval T x IA). No AL. TP and IAP increased 20 psi overnight. OAP unchanged. SV, WV, SSV = C. MV = O. IA, OA = OTG. 11:00 1/19/2020 T/I/O = 1460/1460/Vac. Temp = SI. WHPs (Eval T x IA) No AL. TBG FL @ 6710' (49' below #1, S/O, 58 bbls). IA FL = Inconclusive. IA valve @ 3 o'clock position has an extra valve piggy backed. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:45 Daily Report of Well Operations PBU C-37B 1/20/2020 T/I/O = 1490/1490/Vac. Temp = SI. WHPs (Eval TxIA). No AL. IA FL inconclusive. No heater in wellhouse. TP & IAP increased 30 psi overnight. SV, WV = C. SSV, MV = O. IA, OA = OTG. 15:20 1/21/2020 T/I/O = 1510/1510/Vac. Temp = SI. WHPs (Eval TxIA). No AL. TP & IAP increased 20 psi overnight, OAP unchanged. SV, WV = C. SSV, MV = O. IA, OA = OTG. 14:30 1/22/2020 T/I/O = 1540/1540/Vac. Temp = SI. WHPs (Eval TxIA). No AL. TP & IAP increased 30 psi, OAP unchanged overnight. SV, WV = C. SSV, MV = O. IA, OA = OTG. 16:30 1/23/2020 T/I/O = 1620/1600/10. Temp = SI. WHPs (Eval TxIA). No AL. TP increased 80 psi, IAP increased 60 psi, and the OAP increased 10 psi overnight. SV, WV = C. SSV, MV = O. IA, OA = OTG. 16:25 1/24/2020 T/I/O = 1660/1660/20. Temp = SI. WHPs (Eval TxIA). No AL. TP increased 40 psi, IAP increased 60 psi, and the OAP increased 10 psi overnight. SV, WV = C. SSV, MV = O. IA, OA = OTG. 12:30 1/26/2020 *** WELL SHUT IN ON ARRIVAL*** (secure well) R/U SLICKLINE UNIT SWCP 4516 ***JOB CONTINUED AFTER WEATHER HOLD*** 1/29/2020 T/I/O = 1890/1890/60. Temp = SI. Bleed IAP to 1500 psi (Not Op well). No AL. IA FL @ 6961' (#1 SO, 427 bbls). Bled IAP to C-36 production from 1890 psi to 1280 psi in 1 hr 40 min. TP increased 20 psi, IA FL inconclusive, and the OAP decreased 60 psi. Monitored for 1 hr. TP increased 50 psi, IAP increased 100 psi, IA FL inconclusive, and the OAP increased 20 psi. Monitored for an additional 6 hrs. TP increased 110 psi, IAP increased 310 psi. Final WHPs = 2070/1690/130. LRS in control of valves upon departure. 22:00 1/29/2020 T/I/O=2040/1680/125 Temp=S/I (LRS unit 42 Secure Well) Pumped 5 bbls 60/40 and 190 bbls down IA to load. ***Continue on 01/30/2020*** 1/30/2020 ***Continued from 01/29/20*** CMIT TxIA ***PASS***@ 2560x2586. Max applied 2750, Target 2500. Continue to load IA with remaining 103 bbls crude (293 bbls total). IAP would come up and fall indicating possible hydrates in IA. Pumped 300 bbls of 180* F down IA to help clear hydrates. Pumped 3 bbls 60/40 followed by 125 bbls 70* crude to load TBG. Pumped 47 bbls crude down IA to achieve test pressure. 1st 15 min lost 135x130 TxIA psi. 2nd 15 min lost 40x30 TxIA psi. Bled back ~ 47 bbls. Hang tags, AFE sign, FWHP's 537/690/-11. SLB on well upon departure. 1/30/2020 T/I/O = 730/730/Vac. Temp = SI. WHPs (Eval TxIA). No AL. SLB SL in control of well upon departure. 12:15 1/30/2020 ***CONTINUED FROM 1/26/20 WSR*** (Secure well) LRS PUMPED 593 BBLS OF CRUDE DOWN IA (~500bbls @ 180*). LRS LOADED TUBING W/ 125 BBLS OF CRUDE. SET 1.781" RR-PLUG IN 1.781" R-NIPPLE AT 9,159' SLM / 9,204' MD. LRS PERFORMED SUCCESSFUL CMIT-T x IA TO 2560 PSI. ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** 3/28/2020 T/I/O = 620/1030/1260. Temp = SI. Bleed IAP to 400 psi (Eval Secure). No AL. IA FL @ 780' (48 bbls). Bled IAP to OT from 1030 psi to 400 psi in 40 minutes. During IA bleed, TP decreased 20 psi & OAP decreased 100 psi. Monitor for 30 minutes. TP unchanged, IAP increased 70 psi , OAP unchanged, & IA FL inflowed 330'. Final WHPs = 600/470/60. SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:30 Daily Report of Well Operations PBU C-37B 3/29/2020 T/I/O = 610/580/140. Temp = SI. WHPs (Post Bleed). No AL. TP increased 10 psi, IAP increased 110 psi, OAP increased 80 psi overnight. SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:45 11/3/2020 ***WELL S/I ON ARRIVAL***(cement squeeze) DRIFT 2.71" TO 7300' SLM SET 2.70" WHIDDON C-SUB @ 8744' SLM PULL RK-OGLV, STA# 1 @ 6961' MD PULL RK-LGLV, STA@ 2 @ 4439' MD ***CONT. TO 11/4/20 WSR*** 11/4/2020 ***CONT. FROM 11/3/20 WSR*** (cement squeeze) SET RK-DGLV IN ST#2 @ 4439' MD. SET RK-DGLV IN ST#1 @ 6961' MD. PULLED 3-1/2" WHIDDON CATCHER SUB FROM 8743' SLM.(empty) DRIFTED TBG W/ 2.60" x 32" DRIFT & SAMPLE BAILER TO LTP @ 9163' MD.(no issues) ***CONT'D ON 11/05/20 WSR*** 11/5/2020 ***CONT'D FROM 11/04/20 WSR***(cement squeeze) EQUALIZED & PULLED 1.781" RR-PLUG FROM LTP @ 9204' MD. ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** 11/17/2020 T/I/O= 500/550/150. LRS unit 72 Assist Slickline with Brush and Flush (CEMENT SQUEEZE). Pumped 80 bbls of 180* F crude into the TBG. Final T/I/O= 600/640/550 11/17/2020 ***WELL S/I ON ARRIVAL*** BRUSHED & HOT FLUSHED TBG / GAUGED 2.68" TO LTP @ 9163' MD. DRIFTED W/ DUMMY BRIDGE PLUG (55" x 2.71"), AND 2.73" CENT (74" OAL). ENCOUNTERED TIGHT SPOT @ 8781' MD. REQUIRES LIGHT SPANG LICKS TO PASS. DRIFTED CLEANLY W/ 2.70" BAIT SUB, AND 2.73" CENT (27" OAL) TO 9163' MD. ***WELL LEFT S/I*** 11/18/2020 ...Well shut in on arrival... (HES Eline - CBP, Punch TBG) SET BAKER 3-1/2" CBP MID ELEMENT AT 8875' (mid joint). 1-11/16" SHORTY SETTING TOOL STRIPPED THREAD AT TOOL JOINT JUST ABOVE THE PRESSURE CHAMBER. ...Well shut in on departure. Continued on 19-Oct-20... ***FISH LIH - 7' x 1.69" Setting Tool, Box end of tooljoint looking up.*** 11/19/2020 ...Well shut in on arrival... (HES Eline - CBP, Punch TBG) RIG DOWN. MAINTAINENCE. ***Job Incomplete, Will return after slickline fishes setting tool.*** 11/20/2020 ***WELL S/I ON ARRIVAL*** FISHED 1 11/16" SHORTY SETTING TOOL FROM 8852' SLM. ***WELL LEFT S/I*** Daily Report of Well Operations PBU C-37B 11/21/2020 ...Well shut in on arrival... (HES Eline - tubing punch) PUNCH TBG FROM 8856.5' - 8861.5' WITH 5' x 2" TITAN TUBING PUNCH, 4 SPF, 0 DEG. LRS MAINTAINED LLR TBG TO IA OF 0.5BPM AT 400PSI DIFFERENTIAL W HILE PUNCHING. AFTER PUNCH LLR INCREASED TO 0.6BPM AT 0PSI DIFFERENTIAL CONFIRMING PUNCH. LRS ESTABLISH CIRCULATION TBG TO IA OF 5BPM ONCE TOOLSTRING WAS AT AURFACE. ***Job Complete. Well shut in on departure, ready for circ out.*** 11/21/2020 T/I/O= 270/570/107 TEMP= SI Assist Eline as directed Pumped 18 bbls crude down TBG to obtain test pressure of 2200 psi unable to obtain test . Rigged up jumper hose from TBG to IA Pumped an additional 38 bbls crude down down Tbg and IA to see if plug is holding with pressure on the IA See Log. Plug was confirmed to be holding per Eline WSL. Pumped 10 bbls crude down TBG up the IA to establish a LLR of .52 bpm @ 1980 psi (SEE LOG FOR DETAILS). Pumped 46 bbls crude down TBG taking returns up the IA to C-36 FL to establish a LLR of 4.3 bpm @ 2180 psi after E-line shot perfs. Freeze protected Hardline with 2 bbls 60/40 HEL in control of well upon LRS departure. CV"s=OTG FWHP's=1500/1500/300 11/22/2020 T/I/O=1491/1466/266 Temp+SI LRS unit 46 Circ well to Diesel (CEMENT SQUEEZE(OA/IA DWNSQZ) Pumped 625 bbls Diesel down TBG taking returns up the IA to C-36 FL. to Circ well to Diesel. Freeze protected hardline with 2 bbls 60/40. SV/WV/SSV=Closed MV=Open CV's=OTG FWHP's=1570/1570/425 11/24/2020 CTU #9 1.75" 0.156 WT Objective: Cement IA MIRU. Swap bops as they are due. Perform partial bop test. Lay down for the night. ***In progress*** 11/25/2020 CTU #9 1.75" coil 0.156WT Objective: Cement IA MU Northern Solutions drift bha (1.73" max OD). Perform full body PT on new bops before RIH. Drift clean to CBP, correct depth to plug set depth, pu 40' and paint red tie in flag for retainer run. POOH. Leave unit over night. ***In progress*** 11/25/2020 LRS unit 46 Heat Diesel transport (CEMENT SQUEEZE (OA/IA DWNSQZ). Heated Diesel transport #39013 to 90* *** WSR Continued on 11/26/20*** 11/26/2020 *** WSR Continued from 11/25/20*** Travel to LRS Yard. 11/26/2020 CTU #9 1.75" coil 0.156WT Objective: Cement IA MU Northern Solutions one trip retainer. Set retainer 30' obove CBP at 8845' ELMD. Pump 241 bbls of 15.8ppg class G cement into IA. Est TOC in IA=5017' When OOH trap 900psi on well. Jet bop stack. RD for cement to cure. 30hrs to 500psi compressive strength. ***In progress*** Daily Report of Well Operations PBU C-37B 11/27/2020 CTU #9 1.75" coil 0.156WT Objective: cement IA Standby for cement to cure to 500psi compressive strength. Greased entire tree and choke trailer post cement. MU BOT milling bha in prep for milling in the am. ***In progress*** 11/28/2020 CTU #9 1.75" coil 0.156WT Objective: Cement IA MU 2.74" BOT reverse clutch mill. RIH. Initial set down in tubing=6694'. Minimal motorwork with weight losses experienced, likely contaminated/green cement. Begin milling from here with intermittent gel pills. Milled cement to 6961' and had repeated stalls like we were stalling on metal/GLM#1. CAMCO 3.5"x1.5" m andrel ID on tubing tally are listed as 2.73" ID. This does not make sense and is likely a typo. This is the original completion and there was a 2.75" SWS RHC plug and landing nipple run in the original tubing tail and those plugs had to have come through those GLMs. The CTD side track performed in 2010 had a 2.74" OD linter top packer that was ran also. Potentially a cement ramp is causing the tight gage mill to kick off into the pocket of the mandrel. Decision to POOH and inspect mill and not further damage GLM #1. Face edges of reverse clutch mill were worn smooth/scarred from milling on metal likely. Center of mill had quite a bit of cement and water courses had residual cement. Circ sub holes were clear of cement, disconnect looked good. Will size down to a 2.72" PDC mill. Leave tools hanging for early am start. ***In progress*** 11/29/2020 CTU #9 1.75" coil 0.156WT Objective cement IA RIH w/ BOT 2.72" milling bha w/2.72" PDC mill. Tag 6965' CTM. Begin milling from here. Make long wiper trip w/10bbl gel pill from 8800' back up to starting milling point 6900' before milling retainer. Performed quick MIT-T to 700 on tubing, IA did not track during a 5 min PT (see log). Continue in hole to mill retainer/CBP. Time mill cement retainer from ~8811'. Mill through retainer down to 8815 ctmd. Pump gel sweep and chase OOH. ~25' of cement left and CBP to mill. Crew houring out. Come back tomorrow to finish ~25' of cement and CBP. ***In progress*** Daily Report of Well Operations PBU C-37B 11/30/2020 CTU #9 1.75" coil 0.156WT Objective: cement IA, AOGCC MIT-T, CMIT-TxIA RU 2.72" PDC mill, stab on well. Attempt state witnessed AOGCC MIT-T, IA tracked during PT. Will have to proceed with SL step to set Evo trieve/DSSSV plug. RIH to mill remaining cement and retainer with same 2.72" PDC mill as yesterday (mill looked good). Start milling at 8815' CTMD. Experience several stalls after making ~2' of hole. On final stall lost ability to circulate through coil. POOH and inspect bha. Mud motor parted between transmission and stator. Discuss fishing plan for tomorrow. *** LIH BOT Xtreme motor.Transmission housing and bit box 2.13"x 2.50' + Rotor (stator housing recovered) 1.375"x 4' + PDC mill 2.72"x 0.46' OAL:6.96'*** ***In progress*** 12/1/2020 CTU #9 1.75" coil 0.156WT Objective: cement IA RIH with BOT fishing bha Bowen overshot w/2.13" spiral grapple. Make two attempts to no avail (see log for detail). Make a 3rd attempt to fish the 1-3/8" motor with grapple basket. Latched up on second try after jetting hard on it. Quite a few overpulls coming through area we milled cement. Make several down up pases to make sure we had fish and to wear off debris. POOH. Fish recovered. All tools acounted for. Lay down for the night. ***BOT fish recovered*** ***In progress*** 12/2/2020 CTU #9 1.75" coil 0.156WT Objective: cement IA Weekly bop test ***In progress*** 12/3/2020 Coil Unit #9 1.75" Coil Tubing - Jpb Scope = Mill remaining cement and CBP Ran BOT venturi 2.68" OD, tagged at 8805 ctm, venturi'd with diesel, tagged a couple of times, POOH. Venturi was full, cement mainly with a few reubber pieces. Swapped to a milling assembly with 2.73" 4 bladed concave mill. Started milling above the previous tag depth and stalled at 8821, loss ground back up to ~8819, decided to PUH and and dry tag to collect stuff up again. Continue milling cement. Stalled at 8846' which looked like the bottom of cement. Drilling break till we hit the plug at 8859'. Mill CBP. ***Continue Job on 12/4/2020 WSR*** 12/4/2020 CTU#9 1.75" CT. Job Scope: Mill - Post IA Cmt Mill CBP at 8859'. Chase plug to 9102' ctm. Did not tag the LTP. Pooh. Freeze protect Coil. Freeze Protect Tbg w/ 22 bbls Diesel. Prep to blow reel down with N2 then went on weather hold. ***Job Complete*** Daily Report of Well Operations PBU C-37B 12/9/2020 ***WELL S/I ON ARRIVAL***(cement squeeze) MADE 2 RUNS W/ 10' x 2.50" PUMP BAILER TO 9140' SLM (recovered 1 cup cement) (tight spots from 7,000' to 9,140') RAN 1.50" LIB TO ST#1 @ 6,691' MD FOR DEPTH CORRECTION (unable loc station) RAN HES MEMORY CEMENT BOND LOG FROM 8,370' SLM TO 4000' SLM (TOC @ 4940') ***JOB CONTINUED ON 12-10-20 WSR*** 12/10/2020 T/I/O=225/0/0 SI Perform Pre AOGCC MIT & CMIT (CEMENT SQUEEZE OA/IA DWNSQZ) MIT T ***FAILED*** CMIT TxIA ***PASSED*** to 2090/2099 psi Pumped 3.7 bbls DSL down TBG to achieve test pressure of 2200 psi. TBG consistantly lost ~150 psi in 5 mins with 3 attempts. IA on vac. RU to IA and fill void with diesel. Increase IA pressure to 650 psi and tbg tracked to 500 psi verifying communication between T & IA. Open up jumper line to equalize pressures. Pumped 20 bbls DSL (total) down TxIA to achieve test pressure of 2200 psi. 15 min loss of 82/97 psi, 30 min loss of 30/26 psi for total loss of 112/123 psi in 30 mins. Bleed TxIA to 0 psi Bled ~3 bbls back. Tags hung on WV/IA Pad Op/W SL notified FWHP=0/0/0 12/10/2020 ***CONTINUED FROM 12-09-20 WSR***(cement squeeze) RAN 1.5" LIB TO ST#2 @ 4,439' MD (+8' correction) SET 3-1/2" AD-2 TBG STOP @ 6,618' SLM SET 3-1/2 DDIC PACK OFF PLUG W/ PRONG (ME ~6,626' MD) SET 3-1/2" DSSSV (min ID = 1.75") IN SVLN @ 2,106' MD ***JOB CONTINUED ON 12-10-20 WSR*** 12/11/2020 ***CONTINUED FROM 12-10-20***(cement squeeze) CMIT-TxIA PASS MIT-T FAILED R/D HES SLICKLINE UNIT 046 ***WELL LEFT S/I ON DEPARTURE*** 12/12/2020 T/I/O = 0/0/0. Temp = SI. MIT-T **PASSED**, CMIT-TxIA **PASSED** (eval TxIA). No AL. T FL @ surface. IA FL @ surface. Pumped 0.31 bbls of diesel to increase TP to 2205 psi. TP lost 76 psi in 1st 15 min & 25 psi in 2nd 15 min for a 30 min total of 101 psi. Pumped 4.5 bbls of diesel to increase TP & IAP to 2188 psi. TP/IAP lost 65/65 psi in 1st 15 min, 22/22 psi in 2nd 15 min for a 30 min total of 87/87 psi. Bled TP & IAP to 0 psi, 3.3 bbls. Tag hung. Final WHPs = 0/0/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:00 PPPPOT-T Stung into test void 0 psi, monitor for 30 min, no change in pressure. Pressured test void to 5000 psi for 30 min test, lost 250 psi in 1st 15 min, lost 250 2nd 15 min (FAIL). Bled test void to 0 psi. Monitored test void and hanger neck seal monitor ports during MIT-T and CMIT-TxIA. 0 psi noted in test void and monitor port during MIT-T. During MIT-TxIA noted 0 psi on neck seal monitor port and 1,100 psi on test void indicating leak path from IA to tubing hanger test void. Daily Report of Well Operations PBU C-37B 12/14/2020 T/I/O = 117/136/8. Temp = SI. MIT-T **Passed** to 2124 psi & CMIT-T x IA **Passed** to 2117/2117 psi (AOGCC witnessed by Bob Noble). Max applied pressure = 2230 psi. Test pressure = 2000 psi. Used .5 bbls of DSL to pressure the TBG to 2230 psi. The TBG lost 82 psi in the first 15 minutes and 24 psi in the second 15 minutes for a total loss of 106 psi. Equalized TBG x IA and pressured up the TBG & IA to 2201/2201 psi w/ 3.2 bbls of DSL. The TBG/IA lost 63/63 psi in the first 15 minutes and 21/21 psi in the second 15 minutes for a total loss of 84/84 psi. Bled the TP & IAP (3.1 bbls, all fluid). FWPs = 0/0/10. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:15 12/17/2020 ***WELL S/I ON ARRIVAL***(cement squeeze) PULLED 3-1/2" DSSSV FROM SVLN @ 2106' MD. PULLED PRONG FROM 3-1/2" DDIC PLUG @ 6616' MD. PULLED RK-DGLV FROM ST#2 @ 4439' MD. SET RK-OGLV(24/64") IN ST#2 @ 4439' MD. PULLED 3-1/2" DDIC PLUG BODY @ 6616' MD.(missing element, no valve) ***CONT'D ON 12/18/20 WSR*** 12/18/2020 ***CONT'D FROM 12/17/20 WSR***(cement squeeze) RAN 3-1/2" BRUSH & 2.62" 3-PRONG WIRE GRAB TO AD-2 TBG STOP @ 6607' SLM.(recovered ~3/4 element) PULLED 3-1/2" AD-2 TBG STOP FROM 6607' SLM. SET 2.75" DSSSV W/ DREAM CATCHER IN SVLN @ 2106' MD. CONFIRMED GOOD SET W/ 3-1/2" CHECK SET.(sheared) ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well C-37 (PTD 210-100)Sundry #:319-363Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCCby the rig workover (RWO) “first call” engineer.AOGCC written approval of the change is required before implementing the change. SecPageDateProcedure ChangeNew 403 Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC Written Approval Received (Person and Date)N/AN/A04/30/2020Changed proposed TOC in IA from ~7800’to~5000’MD. NTSAJWMel Rixse 04/30/2020N/AN/A12/10/2020Changed set depth of tubing plug for witnessed MITs to ~6600’MDNAJWAJWMel Rixse 12/10/2020Approval: Stan GolisAsset Team Operations Manager DatePrepared: Aras WorthingtonFirst Call Operations Engineer DateNote: The Sundry change made on 04/30/2020 was made under BP operationalcontrol. Therefore, digital signature by Stan Golis is not an approval of that change but anacknowledgement that thechange was made.Digitally signed by ArasWorthington (4643)DN: cn=Aras Worthington (4643),ou=UsersDate: 2020.12.14 10:06:12 -09'00'ArasWorthington(4643)Digitally signed by Stan GolisDN: cn=Stan Golis,ou=UsersDate: 2021.01.04 10:21:15 -09'00'Stan Golis Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/21/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU C-37B (PTD 210-100) RCBL Radial Cement Bond Log 12/09/2020 Please include current contact information if different from above. PTD: 2101000 E-Set: 34454 Received by the AOGCC 12/22/2020 Abby Bell 12/23/2020 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �� 1. 1�13�712� DATE: Monday, December 21, 2020 P.I. Supervisor SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC C -37B FROM: Bob Noble PRUDHOE BAY UNIT C -37B Petroleum Inspector Src: Inspector Reviewed By:, P.I. Supry �J NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT C -37B Insp Num: mitRCN201214145358 Rel Insp Num: API Well Number 50-029-22360-02-00 Inspector Name: Bob Noble Permit Number: 210-100-0 Inspection Date: 12/14/2020 Monday, December 21, 2020 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C -37B Type Inj N-' TVD Tubing 2124 2201 - 2138 _ 2117- PTD1 2101000 171 I 2201 -- -- - - - 2138 - 2117 1 iType Test l SPT Test psi 2200 13131, Pumped: 3 2 BBL Returned: 31 QA 9 133 --�-- 133 133 - Interval) OTHER P/F f P Notes: CMIT-T x IA, for post squeeze as per Sundry 319-363. Monday, December 21, 2020 Page 1 of 1 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/01/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL C-37B (PTD 210-100) PATCH SETTING RECORD 11/21/2020 Please include current contact information if different from above. Received by the AOGCC 12/02/2020 PTD: 2101000 E-Set: 34312 Abby Bell 12/02/2020 CASED HOLE Well Log Transmittal To: AOGCC Natural Resources Technician 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907)793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) 21010,0 31144 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: 1) Leak Detect 2) Signed Print Name: BP Exploration (Alaska), Inc. SIM Data Manager Attn: Marion Kendall MB 7-5 900 Benson Blvd. Anchorage, AK 99508 GANCPDCAUSAANC hou xwh BP corn and READ Cased Hole, Inc. Attn: Diane Williams 130 West International Airport Road Suite C Anchorage, AK 99518 D i a ne.wi I I iams@readcased ho le. corn 09 -Jul -19 C-376 CD RECEIVED AUG 2 9 2019 AOGCC 50-029-22360-02 Date: ?0 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245.8952 E-MAIL: READ-ANCHORAGE[(DREADCASEDHOLECOM WEBSITE: WWW.READCASEI)HOLE.COM http. reedrasedhole-mysharepointwmpersoval/diane_williams readcasedhole_com DocumemsDesktopBP Transmicdocx THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Travis Semmens Intervention & Integrity Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU C -37B Permit to Drill Number: 210-100 Sundry Number: 319-363 Dear Mr. Semmens: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage. Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 �. a ogc c.a loska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner ^+ DATED this day of August, 2019. RBDMS-L6A AUG 13 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 rdu W W...Ji�* A U1 0 F 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown IS Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approvetl Program O Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other IA Cement Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4, Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number: 210-100 1 Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22360-02-00 ' 7, If perforating: What Regulation or Conservation Order governs well spacing in this pool? H e. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU C -37B ' 9. Property Designation (Lease Number): 10. Field/Pools: ' AOL 028305 PRUDHOE BAY, PRUDHOE OIL t 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft) : Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11625 8992 11586 8993 None None Casing Length Sin MD TVD Burst Collapse Structural Conductor 80 20" 36-116 36 -116 1490 470 Surface 3293 13-3/8" 35-3328 35-3250 5020 2260 Intermediate 9021 9-5/8" 32-9053 32 - 8437 6870/7930 4760 / 6620 Liner 673 7" 8885-9558 8289-8817 1 8160 7020 Liner 2449 2-3/8" 9176-11625 8544-8992 1 11200 11780 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9188 - 11570 8554 - 8994 3-1/2" 9.2M L-80 30-9558 Packers and SSSV Type: No Packer Packers and SSSV MD (ft) and TVD (ft): No Packer No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: September 15, 2019 15, Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby cenify that the foregoing is true and the procedure approved herein will not Contact Name: Semmens, Travis be deviated from without prior written approval. Contact Email travis.semmensiflibp.com Authorized Name: Semmens, Travis Contact Phone: +1 907 5645352 Authorized Title: Intervention & Integrity Engineer Authorized Signature: 7— Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 31��3�3 Plug Integrity SOP Test Mechanical Integrity Test ❑ Location Clearance ❑ v> 4-s Other��3G6'�tp 7, Tv T�npp fw.n, l-6 *.-��a� ✓d���a�� 'CLI ��QE (j Post Initial Injection MIT Req'd? Yes No Hill~ 4lfstirlt0.1 -�"r MIT' -T ��ut1rw• t Spacing Exception Required? Yes ❑ No Subsequent Form Required: Q jl 16-`1 r APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date. OO I 1 g/r, 4011 ORIGINAL RBDMS L"I AUG 13 2019 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from date f ap approve / ��% 11,9 Attachmentsplilliicate M C -37B Tubing Leak Cement Job Intervention Engineer Travis Semmens (907) 297-9672 Production Engineer Brian Glasheen (907) 564-5905 Expected Start Date: September 15, 2019 4v� C -37B History C -37B is a natural flowing producer that was completed in 1993. The well went through two sidetracks, with the final sidetrack in 2010 targeting Z -IA with 940' of perforations shot after completion. The well requires in-situ gas lift to flow. The well has a leak in the tubing at 8228'MD, which was discovered in 2016 and remedied with a patch. In early July a leak detect log revealed that the patch was leaking through the top, so the patch was pulled and the well made not operable. The well passed a CMIT-TxIA but failed an MIT -IA. The purpose of this program is to return C -37B to "Operable" status by fixing the tubing leak Current Status This well is classified as "Not Operable" by BP. Objective Cement the IA to cover a tubing leak at —8228' MD. Cement will be circulated down the tubing and up the IA through tubing punch at 8430' MD. The proposed TOC in the IA is 7800' MD (7325' TVD) which is 4075' TVD below the surface casing show and is —3150' MD deeper than the estimated top of UG4. Economics Well C -37B was found to have a Tubing leak at 8228' MD. At the last test this well produced 435 BOPD, by repairing this well with an 1A cement squeeze, it is estimated that an additional 320 mbo can be produced over the next 2 years. Without an IA remedial squeeze, the well has no utility in the foreseeable future. Post -Job Evaluation -MIT-T -CMIT-TxIA Long -Term Integrity Monitoring -Biennial CMTT-TxlAs and MIT -Ts Procedural steps Slickline 1. Set LTP with PTSA E-Line/Relay 2. Set composite bridge plug @ —8480' MD. 3. Punch the 3-1/2" tubing @ —8430' MD 4. Set cement retainer above tubing punch. Coiled Tubing 5. Pump 40 bbls Class G cement into the inner IA up to 8080' MD ✓ 6. Wait for cement to gain compressive strength 7. Mill out cement retainer, residual cement and the bridge plug. 8. Jet debris off LTP and push remaining plug components to bottom Relay/Slickline 9. RBT or SCMT to determine TOC ), � g u { � 5 47. 4 ©G-- C, 10. Set plug in LTP 11. MIT -T 12. Pull plug It 1 13. Update AKIMS to include biennial MIT -T and MIT -IA. Proposed Cement Blend Paramaters Cement lob (9-5/8" x 3-1/2") IA volume from 8430' MD to 4965' MD 1 40 bbls Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg+/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: I Minimum 5 hours Activity Time (hours) Shearing time, quality control, PJSM 1 Cement displacement 4 Cement contamination 1 Safety 1 Minimum required thickening time: 7 Tf6£= 3. RJN = -677:7' 673, BE/ = 36.48' ?--- 2050' 20'COPDIA Angle = 99° @ 10666' 91.50, H40, jrnwD 9624 D =19.124' MTVD= ..gBUp•SS 9-5/8' CBG, 47#, NT -80 BDIT, D= 8.1 1338' CSO, SM, L-80 BTC D=12. D = B-535- Minimum .535 Minimum ID = 1.75" @ 2106' 3-1/2" DSSSV 9-5/8- LNI2, 47#, NT -80 MM. D= 8.681' 1-i 9063' I -9663 (-LW 28#. Wr 0 M , .o371 Dpf, D- 6.184• 1-i -9663 H FEWORATION SLIWMRY Rff LOG: SLB M MJGRCa-ON 09/10710 AWXEAT TOP PEW: 35@ 9188' Mte: Refer to Rodwtbn DB for tatorkal pert data SIZEISFFI 1 ME iVAL I OpgSqz SHOT SOZ 2' 6 9188-9190 O 0821/11 1.56' 6 9813-9824 O 05125/19 1.58' 6 9829 - 9895 O 0528/19 1 5B' 6 9853-9866 O 0526/19 L56' 6 10040-10170 O 09/11/10 1.5(' 6 10240-10380 O 09/11/10 1.56' 6 10460-10490 O 09/11/10 1.56" 6 10570-10600 O 09/11/10 1.56" 6 10650-10830 O 09/11/10 1.56' 6 11000-11140 O 09711/10 1.56" 6 11230 -11260 O 09/11/10 1.56' 6 11310-11570 O 09/11/10 D = 1995'. SAFETY NOTES: WELLANGLE>70°@9840— C -37B WTHP TOCK �L13ORES NOTSHOWN BELOW O 2106' 3-12' OTB XDB SSSVN, ID 21OW 3-12' DSSSV, D= 1.75-105704 19) GAR 15 r W Nr#!R 9 7 1 1 1 ST MD I TVD I DEV TYPE I VLV I LATCH I FORE I DATE 09/16101 NDR3ci CTDSIDETRACK (C37A) 05706719 MS/JMD RAL FLLG, SET FATC71 SET DSSSV 09711/10 24439 0528/19 JGUJMD ADPER=S(OS/Ml9) 4270 24 CA I DDM£ RC 16 05/2417 1 6961 6567 24 CA I SO RK 1 20 052417 MILLOUT NINDDW (C-378) 9559'-9583' DATE I REV BY I CONANTS 11 DATE Tiv BY ooktvsars 96103793 09 SIISPBIDEDCOMPLEDON 1127/17 JPK/JM USffUUO(1123/17) 08708183 DIB ONGIMAL COMPLETION 02/18119 GJBIJRC RAL PATCWLTR'DSSSV-SET LTP 09/16101 NDR3ci CTDSIDETRACK (C37A) 05706719 MS/JMD RAL FLLG, SET FATC71 SET DSSSV 09711/10 NORDICI CTDSIDEfRACK(C37B) 0528/19 JGUJMD ADPER=S(OS/Ml9) 09/06117 BSE/ "NGED OUT P4,%W ORFTCE OTV18/19 DDJMD ADDED 0103, Rff, & BF BB/ - UT]ATE 09rM17 ZV/JMD EDITS TOUSITU GLM &SEAL ASSY D-1.81, PR DHOE BAY LUT WELL: C -37B P6diT No:'2101000 AR Pb: 50-029-22360-02 T11K R14E 1119 FPL & 879' FEL BP Blplorallon(Alaska) TREE= OW iWBIHBkO = R.0 C -37B SAfETYNOTES: WELLANGLE>70'@9940'-- ACTUATOR= UAKERC PREVIOUS WELL BORES NOT SHOWN BELOW BEV EV = 67.T WHIPSTOCK ^• 0, FHO, 19.124' D=8.681' 13816- CSG 660, L-50 BIC. D- 12AIS' I GAS LOFT MAN FEES ST LO TVD MV TYPE VLV LATCH PORT DATE 2 4439 1 4270 8567 24 24 CA DOLE CA SO f8( FB( 16 20 0524/17 05/21/17 Minimum ID =1.75" @ 2106' TOC 7800' MD 3-1/2" DSSSV PEWOFIATCN SLhMRY Fill LOG SLB MCN GRK)CL ON 09/10110 ANGLEATTOPPERP35•a 9188' Note: Refer to Production 0B for hLstoriMl pert data SIZE SPF INTERVAL I Opn/Sgz SHOT T SOZ 2' 6 9188-9190 O 08/21/11 MM17 &/JI.D 9MT0N-SInJQM86rALA59Y 1.56' 6 9813-9824 O 05/26/19 1.58' 6 9829-9845 O 0528/19 1.58' 6 9853 - 9866 O OSM19 1.5E 6 10040-10170 O 09/11/10 1.56' 6 10240-10380 O 09/11/10 1.56' 6 10460-10490 O 09/11/10 1.58' 6 10570 -10600 O 09/11/10 1.56' 6 10650-10630 O 09/11/10 1.58' 6 11000-11140 O 09/11/10 1.58' 6 11230-11280 O 09/11/10 1.56' 6 11310-11570 O 09/11/10 Estimated UG4 Top: 4650' MD Tubing Punch: 8430' MD NILLOUT MNODWIC-878) 9556'-9563' DATEFEV BY comma"DATE FEV BY COWANTS 0610383 D9 SUSPEND® COMPLEnON 1127117 JPK/JLDOISTIU0O(112M7) ORMS1931 m6 ORDINAL COMPLETION 02/18119 C=Ifl7 RAL PATOVLTR'D6SSV -SET LTP 00/1881 CI CTD SIOETRACK(C-37A) 05106119 MSI.RO RAI PLUG, S[T PATO{SET T]6SSV 0H7110 1 CTD SIOETRACK(C•37B) 05/28119 JGUJAD AOPE FS(05/26f19) o9ml7 iBSE/ "NSED OUT IN -MU CRFICE 96118119 DO/,M ADDED OKB, Fes, 8 BF R"-LFOA-FE MM17 &/JI.D 9MT0N-SInJQM86rALA59Y PRLEFi0EBAY UNIT VM3L 0378 R3MT M: 2101000 AR No: 50-029-2238002 TI IR R14E 1110 FTL 6879' FEL BP &ploratlon (Alaska) Cement Plug #2 TREE= Cww pumped - surface waLrEAD= AMC cement plug pumped ACTUATOR= BAKER down TBG, then up oR. aei = 671' the OA & IA REF ELN = 87.T OR EL _ 38.48' KOP=2050 20' CONDUCTOR, Max Angle = 99' a 10666' 91.5#, H-40, Dah1m WD= 9624' D=19.124' Datum ND= 6800'55 9-51W CSG, 47#, NT -60 BUTT, 0=11.6111- 14-185 I9 -SW CSG. 53-5#. Nr -60 BUTT. D = 8.535 H 6864' I Minimum ID = 1.75" @ 2106' 3-1/2" DSSSV 19-518' LNZ 4719. NT -80 BUTT. D= SAW' H 9063' 1 V*IFSTOCK(0&19/10) H 9558- I T LNis, 29#. NT -00 ASCO, .0371 bPf. D-6.184' H —9663 F PERFORATION SL&WRY REF LOG SLB WCM7GRICCL ON 09/10110 AN I-EATTOP PH7F: 35-09189 We: Refer m Frodwbon DB for historical perf data SIZE SPF INTERVAL OprVSgz SEDT SOZ 2' 6 9188-9190 O 08121/11 I RK16 RK 1.56' 6 9813-91124 O 0526119 1.56' 6 9829 - 9845 O 0526119 1.56' 6 9853 - 9866 O 0526/19 1.56' 6 10040 -10170 O 09/11710 1.59' 6 10240 - 10380 O 09/11/10 1.56' 6 10460-10490 O 09/11/10 1.56' 6 10570-10800 O 09/11/10 1.56' 6 10650-10830 O 09/11710 1.56' 6 11000- 11140 O 09/11/10 1.56' 6 11230-11260 O 09/11/10 1.56' 6 11310-11570 O 09/11/10 SAFETY NOTES: WELL ANGLE> 70" a 9940— 7 B PREVIOUS WELL BORES NOT SHOWN BELOW WHIPSTOCK"' � ; n 2106' 3-12'OTBXDBSSSVN.O=2.750' GAS LFT MANOF93 4 STJ RUITVDIDLVITYPEI 06!0313 09 SUS�COMPLETION 11/27/17 OFSITUO'O(I 23/17) VLV LATCHlPOffrl DATE 2 1 4439 6961 4270 6567 24 1 CA 24 CA I DOW SO I RK16 RK 05/24/17 20 0524/17 W-82411' —j 3.112' NS PATCH w /OCLL , o = 1.8 Cement Plug # I pumped -reservoir and intermediate 8893' 9-516' X 7- TWV LTP w/ LNR RANGER 8046' PSTTOCMW10110) 9176'I"' 103 LTP W MS FMA (OTA7119) 06!0313 09 SUS�COMPLETION 11/27/17 OFSITUO'O(I 23/17) 9201'2.7(rDEPLOYMENT SLV, D=2250' —92W 2-31' R NP. D = 1.781' W9LLOUTWNDOW (C-378) 9556'-9563' DATE REV BY COWTr NTS DATE CONT 305 06!0313 09 SUS�COMPLETION 11/27/17 OFSITUO'O(I 23/17) 091M3 DIS ONGRAL COMPLETION 02/18'19 FULL PATCFVLTPIOSSSV - SET LTP 09/78101 C1 CTD SIDETRACK (C -37A) 05106/19 ft1L PLLGA SET PATCFt SET DSSSV IDDY.AWAMMOKE1. 09111110 C1 CTDSIDETRACK(C-378) 0528119 AOPERFS (0526719) 09/ON77 BSE/ CHANGED OUT 14SRU ORFI E 06/18119 REF, & BF ELEV -UPDATE 0920/17 N/JI.D 8XIS TOMSRU OLM&SEAL ASSY 13 FRLUFDE BAY INT WELL: C -37B PE MTNb:2101000 AA No 50-02922360-02 BP 1-2phoration (Alaska) by S C -37B Tubing Leak Cement Job Intervention Engineer Travis Semmens (907) 297-9672 Production Engineer Brian Glasheen (907) 564-5905 Expected Start Date: September 15, 2019 History C -37B is a natural flowing producer that was coi sidetrack in 2010 targeting Z -IA with 940' of pi flow. The well has a leak in the tubing at 8228 early July a leak detect log revealed that the pab made not operable. The well passed a CMIT-T� The purpose of this program is to return Current Status This well is classified as "Not C -37B detyd in 1993. The well went through two sidetracks, with the final o tions shot after completion. The well requires in-situ gas lift to which was discovered in 2016 and remedied with a patch. In was leaking through the top, so the patch was pulled and the well but failed an MIT -IA. to "Operable" status by fixing the tubing leak M Objective Cement the IA to cover a tub' g leak at —8228' MD. Cement will be circulated down the tubing and up the IA through tubing punch at 84 ' MD. The proposed TOC in the IA is —4965' MD (4750' TVD) which is 1500' TVD below the surfa/to g show but is —315' MD deeper than the estimated top of UG4. Economics Well C -37B was fouve a Tubing leak at 8207' MD. At the last test this well produced 435 BOPD, by repairing this well wcement squeeze, it is estimated that an additional 320 mbo can be produced over the next 2 years. WitA remedial squeeze, the well has no utility in the foreseeable future. Post -Job Evaluation -MIT-T -CMIT-TxIA Long -Term Integrity Monitoring -Biennial CMIT-TxlAS and MIT -Ts Procedural steps Slickline 1. Set LTP with PTSA E-Line/Relay 2. Set composite bridge plug @ —8480' MD. 3. Punch the 3-1/2" tubing @ —8430' MD 6L 4el 4. Set cement retainer above tubing punch. Coiled Tubing 5. Pump 213 bbls Class G cement into the innerIA up —8080' MD 6. Wait for cement to gain compressive strength 7. Mill out cement retainer, residual cement and;e bridge plug. 8. Jet debris off LTP and push remaining Relay/Slickline 9. RBT or SCMT to determine TOC 10. Set plug in LTP 11. MIT -T 12. Pull plug DHD 13. Update AKIMS to Dnents to bottom biennial MIT -T and MIT -IA. 2 Proposed Cement Blend Paramaters Cement mob f9-5/8" x 3-1/2") 7G �J I IA volume from 8430' MD to 4965' MD 913 hhle Cement Type/weight: Class G 1" ppg mixed on the fly. Field blend to be =lab +/- 0.1 ppg Slurry Temperature: betweprfi 800 and 110°F Fluid Loss: 40- Occ Compressive Strength: 00 psi in 48 hrs. Thickening Time: Minimum 5 hours Activit Time hours Shearing time, quality control, PJSM 1 Cement displacement 4 Cement contamination 1 Safety t Minimum required thickening time: 7 TFam= CNV WELLHEAD= RAC ACRIATOR= BAKER OKB. ELSI --- 67.T tiff ELE = --- B7.T MAW KOP= -- 2850' .. Mai Angle = 99' 106fi6' DaWm AU=. —._ 9624' DaM1mTVD= 880P SS 7 SAFETY NOTES: WELL ANGLE> 70'@ 9840' — C-3 • W PREVIOUS WELL BORES NOT SHOWN BELOW TREE= tlW WELLHEAD= FMC AONATOR= _ BAKaic oIB. aEv = — s7—r riff ELev 2" KOP= Mm Angle -=99* 36.48' 2050 0 10666' Dat m MD = 9624' DalunTVD= a800'SS 191.50• H40• D =19.124' Minimum ID =1.75" @ 2106' 3-1/2" DSSSV 9-5/8" LNR D=2.992• R#ORATION SLAOIARY FEF LOG: SLB I.1CFa./GR/CCL ON 09/10/10 ANGLEATTOPFH1F:35'@ 9188' Nitta: Refer to Rodwbon OB for lector l perf data SIZE SPF NTEiVAL I OWSgz SEDT SOZ 2" 6 9188-9190 O 0821/11 09rM17 ZV/&M EDITS TO 94SITU GLM &SEAL ASSY 1.56' 6 9813-9824 O 0526/19 1.56' 6 9829 - 9845 O 0526/19 1.56' 6 9853-9866 O 0528/19 1.56' 6 10040 - 10170 O 09/11/10 1.56' 6 10240-10380 O 09/11/10 1.56' 6 10460-10490 O 09/11/10 1.56" 6 10570-10600 O 09111/110 1.58' 6 10650-10830 O 09/11/10 1.56" 6 11000-11140 O 09/11/1 1.58" 6 11230-11260 O 09/11/ 1.56" 6 11310-11570 O 09/11 0 7 SAFETY NOTES: WELL ANGLE> 70" @ 9840"" C-3 PREVIOUS • W H PSTOCK WELL BORES NOT SHOWN BELOW C�af^ D = 2.750' 20 Estimated U434 Top: 4650' MD TOC-4965'MD j l / O �e p e 8430' MD MluourmNllow(c-a7� sssa•-9ssa 047E REV BY COIuMAaws DATE I REV BY O]M.BVIS 06/03/93 09 StMWEDEOCOMPLERON 1127/17 JRG.MD PiSRU CJO (1123!17) 09106`93 D76 ORIGINAL COMPLETION 07J1BM§TGMJkC HILL PATCVLTRDSSSV-SET L -FP 09/16101 IOROICI CTDSIDETRACK(C-37A) 05MI9 !A AU HJLLPLMSETPATCH,SETDSSSV 0911190 KMIOICI CTDSIDEMCK(C-376) 0528/19 JCY./.MrD AD8RF5(05/26/19) 09/06/17 BSEP CLANGDOUTPLSfNORFICE06118/19 DEYMD ADDEOOIB•RIR=.&BFBEV-LFnkW 09rM17 ZV/&M EDITS TO 94SITU GLM &SEAL ASSY RAUHDEBAY LM WELL: G3713 PHdJT N>: "1101000 AR Na: 50-029-22360-02 TI 1N, R14E• 1110 FNL & 879' FEL SP 6gdoration (Alaska) F Rixse, Melvin G (CED) From: Rixse, Melvin G (CED) Sent: Wednesday, August 7, 2019 1:24 PM To: Travis.Semmens@bp.com Subject: PTD 210-100, PBU C-376, Sundry Request 319-363, Tubing Leak Travis, Why not replace the patch? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin. Rixsegalaska.gov). _ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS s 5L.iJL.wdL.L.0 JUN 18 2019 1. Operations Performed Size: MD: TVD: Burst: Abandon ❑ Plug Perforatlons ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations v �a....tt V eGCG �.[.I 11625 Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ feel Plug for Rednll ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: Reset Tubing Patch 8 Junk measured None feet Change LTP 2. Operator Name: BP Exploration (Alaska), Inc 14. Well Class Before Work Packer 5. Permit to Dnll Number 210-100 3. Address: P.O. Box 196612 Anchorage, Development 0 Exploratory ❑ 8993 feel Packer AK 9951 9-6612 Stratigraphic ❑ Service ❑ 1 6. API Number. 50-029-22360-02-00 7. Property Designation (Lease Number): ADL 028305 8. Well Name and Number: PBU C-376 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pools Measured depth: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Size: MD: TVD: Burst: Collapse: Structural Total Depth: measured 11625 feet Plugs measured None feel 20" true vertical 8992 feet Junk measured None feet Effective Depth: measured 11586 feet Packer measured None feet 32-8437 true vertical 8993 feel Packer true vertical None feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Conductor 80 20" 36-116 36-116 1490 470 Surface 3293 13-3/8" 35-3328 35-3250 5020 2260 Intermediate 9021 9-5/8" 32-9053 32-8437 6870 / 7930 4760 / 6620 Liner 673 7" 8885 - 9558 8289-8817 8160 7020 Liner 2424 2-3/8" 9201-11625 8565-8992 11200 11780 Perforation Depth: Measured depth: 9188-11570 feet True vertical depth: 8554-8994 feet 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): including volumes used and final pressure: 3-1/2" 9.2# L-80 30-9558 30-8817 None No SSSV Installed 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 150 21815 9 0 717 Subsequent to operation: 573 8148 33 0 265 14. Attachments: (required per 20 nac 25.07025.071, a 25.283) 15. Well Class after work Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Glasheen, Brian P Contact Name: Glasheen, Brian P Authorized Title: Production n9i r Contact Email: Brian.GlasheenObp.com Authorized Signature: Date: 6 / 10 / 4 Contact Phone: +1 907 564 5905 Form 1Mend Pnwem nd"nrr r L i i - , .— I / i Iorq2T(trlYr(�4 � 17Ji0U1V10 v JUN 19 2019 aupmn un9inai unry **'WELL S/I UPON ARRIVAL*** (profile modification) DRIFT W/ 2.84" NO-GO TO DSSSV @ 2,106' MD PULLED DSSSV FROM SVLN @ 2,106' MD PULLED TOP 37' SECTION OF PATCH FROM 8,128' MD (missing one element) RAN 3-1/2" BRUSH & 2 -PRONG WIRE GRAB (recovered 3/4 piece of element) PULLED NEXT 2 SECTIONS OF SPACER PIPE AND WFD WIDEPAK PACKER FROM 8,222' / 8,233' MD (intact) 2/6/2019 ***CONT WSR ON 2/7/19*** T/I/0=2400/2100/300 SI (LRS Unit 46 - Assist Slickline: Load & Test) Load IA w/ 5 bbls 60/40 followed by 490 bbls 120* crude. Load Tubing w/ 5 bbls 60/40 followed by 120 bbls 120* crude.. Freeze Protect Flowline w/ 5 bbls 60/40 followed by 72 bbls crude down FL for FP. SL set LTP assembly. CMIT TxIA to 2716/2730 psi —PASS—* Target pressure=2500 psi Max applied=2750 psi Pumped 15.52 bbls down TxIA to achieve test pressure of 2750 psi. 15 min loss of 23/23 psi, 30 min loss of 19/18 psi, for total loss of 42/41 psi in 30 mins. Bled TxIA to 11.3psi. Bled back -xx bbls. Pad Op/WSL notified Tags hung on WV/IA AFE sign hung on MV ***FLUID PACKED ANNULUS' SL on well upon departure. CVs OTG 2/7/2019 FWHP=253/250/-5 ***CONT WSR FROM 2/6/19*** (profile modification) RAN 20'x 2.70" DUMMY WHIPSTOCK, 2.50" LIB TO TOP OF LTP @ 9,146' SLM (clean) PULLED 35KB LTP FROM 9,146' SLM / 9,177' MD (intact) LRS LOADED IA W/ 490bbls CRUDE, LOAD T W/ 120bbls CRUDE SET 35KB LTP W/ 1.781" R -PLUG INSTALLED IN DEPLOYMENT SLEEVE @ 9,176' MD 2 7/8" R NIPPLE @ 9207' MD LRS PERFORMED PASSING CMIT TxIA TO 2636psi 2/7/2019 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS* ***WELL S/I ON ARRIVAL"* (Profile Modification) HES RELAY UNIT #46 EQ 2-3/8" RX PLUG @ 9204' MD PULL 2-3/8" RX PLUG @ 9204' MD 4/29/2019 —JOB CONTINUED ON 30 -APR -2019*** ***JOB CONTINUED FROM 29 -APR -2019*** (Profile Modification) HES RELAY UNIT #46 DRIFT w/ 20'x 1.71" DUMMY GUNS TO 9842' SLM RAN 1.56" X 20' TITAN MILLENIUM GUNS TO 9580' SLM (unable to pass dogleg) RAN 1.56" X 11' TITAN MILLENIUM GUNS TO 9560' SLM (unable to pass dogleg) RAN 3-1/2" NS LOWER PACKER ASSEMBLY, UNABLE TO PASS SSSV NIP @ 2106' MD (packing swollen). 4/30/2019 ***JOB CONTINUED ON 01 -MAY -2019*** ***JOB CONTINUED FROM 30 -APR -2019*** (Profile Modification) HES RELAY UNIT #46 B & F W/ HOT OIL, 2.70" G -RING, 3.5" BRUSH, TAG LTP @ 9140' SLM / 9173' MD SET 3-1/2" NS LOWER PKR AT 8246' MD MID -ELEMENT (top - 8243' md). SET PKR TEST TOOL @ 8230' SLM/8243' MD. TEST LWR PKR TO 1000 PSI, PASS AND PULL TOOL. RIH W/ 3-1/2" GS, 33.24' NS PATCH SECTION. S/D ON SSSV NIPPLE @ 2084' SLM / 2106' MD. PULL 3-1/2" X 33.24' NS PATCH SECTION FROM 2084' SLM / 2106' MD. LAY DOWN FOR WINDS. 5/1/2019 *"JOB CONTINUED ON 02 -MAY -2019*** *"JOB CONTINUED FROM 02 -MAY -2019*** (Profile Modification) HES RELAY UNIT #46 END WEATHER STANDBY @ 04:00 SET 3-1/2" NS PATCH SECTION W/ QCLL RECEPTACLE @ 8230' SLM (33.24' oal, 2.72" max od). PERFORM PASSING P/T TO 1000 PSI ON NS QCLL RECEPTACLE (-20 psi/15min). SET 3-1/2" NS PATCH SECTION W/ QCLL RECEPTACLE @ 8205' SLM (34.13' oal, 2.72" max od). PERFORM PASSING P/T TO 1000 PSI ON NS QCLL RECEPTACLE (-17 psi/15min). SET 3-1/2" NS LTP @ 8172' SLM (40.13' oal, 2.72" max od). SET 2-3/8" RX PLUG IN RX NIP @ 9204' MD ***JOB CONITNUED ON 04-MAY-2019*** —3-1/2" NORTHERN SOLUTIONS PATCH, BOTTOM ELEMENT = 8246' MD, TOP ELEMENT = 8141' MD, TOP 5/3/2019 OF PATCH = 8138' MD, BOTTOM OF PATCH = 8248' MD, DAL IH - 11 Or, MIN ID = 1.81 "*** Dailv Report of Well Ocierations PBU C -37B "*JOB CONTINUED FROM 03 -MAY -2019*" (Profile Modification) HES RELAY UNIT #46 SET 3-1/2" DSSSV @ 2106' MD RAN 3-1/2" CHECK SET TO DSSSV @ 2106' MD (sheared) LRS PERFORM PASSING MIT -T (see Irs log) PULLED DSSSV FROM SVLN @ 2106' MD EQ RX PLUG @ 9204' MD PULLED RX PLUG @ 9204' MD SET 3-1/2" DSSSV @ 2106' MD RAN CHECK SET TO 2106' MD (sheared) 5/4/2019 *"JOB CONTINUED ON 05 -MAY -2019'** '"JOB STARTED ON 05 -MAY -201 9- (Profile Modification) HES RELAY UNIT #46 FINISHED RIGGING DOWN. FINAL T/I/O = 0/0/100. 5/5/2019 *"WELL S/1 ON DEPARTURE, DSO NOTIFIED"* CTU#8 1.5" CT Job Scope: Depth Log /Adperf Continue RIH w/ HES Logging Tools w/ 1.74" Bullnose. Drift to 10020'. Log from 10020'- 8900'. Flagged Pipe at 9820'. Pooh. Receive data - however log is very inconsistent throughout the interval. Decision made to re -log with another Sondex Tool. RIH w/ HES Logging Tools w/ 1.74" Bullnose. Drift to 10050'. Log from 10050'- 8900'. Flagged Pipe at 9819.8'. Pooh. Got data - however log is again very inconsistent throughout the interval. Troubleshoot CT- wiring system. ET's replace Encoder system. 5/24/2019 "*Continue Job on 5/25/19 WSR*'* CTU#8 1.5" CT Job Scope: Depth Log /Adperf Troubleshoot encoders on SLB and HES equipment. Sib ET's found nothing wrong with CT Unit Encoder System nor did HES. Decision to run PDS & HES Memory Logs in Tandem. RIH w/ PDS/HES GR/CCL Tools w/ 1.74" Bullnose. Drift down to 10050'. Log 50 -fpm pass from 10050'- 6900'. Flagged pipe at 8899.82' pds / 8899.82' hes'. Make 2nd 60 -fpm pass from 10050'- 8100'. Flagged pipe at 9819.44'pds / 9819.42' hes. Pooh. Both HES & PDS logs look good. Using HES 60fpm Up Pass= 22' Correction. Correlate to Slb MCNL 10 -Sept -2010. MU & RIH w/ HES 1.56" x 13' Perf Gun #1. 5/25/2019 "*Continue Job on 5/26/19 WSR'** CTU#8 1.5" CT Job Scope: Depth Log /Adperf Continue RIH w/ HES Pert Gun #1. Correct depth at flag. Perforate Interval 9853'- 9866' ctm. Pooh. All shots fired, ball recovered. MU & RIH w/ HES 1.56" x 16' Pert Gun #2. Correct depth at flag. Pe orate Interval 9829' - 9845' ctm. ball on seat 22.7 bbl Indication of firing at 3000psi. Pooh. MU & RIH w/ HES 1.56" x 16' Perf Gun #3. Perforate Interval 9813'- 9824' ctm. ball on seat 22.7 bbl Indication of firing at 2980psi. Freeze protect TBG 24 bbls 50/50 MeoH. Rig Down CTU. 5/26/2019 "'Job Complete"* TREE= CTW WEiLFEAD= FkIC ACTUATOR= BAI032C OKB. ELEV = 67.7' �ELEV 67.r BF- E LLV = 36.48' KOP- 2050' Max Angle= 9W 70866• Da1unMD= 9813-9824 D4tu TVD= 880EF 91.5#, H-40, 9624' D =19.124' SS r-80 BUTT, D = 8.E L-80 BTG D= 12., = 8.535' I 1891' 1 Minimum ID = 1.75" @ 2106- 3-112'0 DSSSV 19-5/8' LNR 47f1, NT -80 BUTT. D = 8.68V1 L-80 TDS, 2-3/8' D=6. PERFORATION SUMIMRY REF LOG SLB MCNUGR/CCL ON 09/10/10 ANGLEATTOPPERF: 35'@ 9188' Note: %far to Roduction DB for historical pert data S¢E SPF ME32VAL Cpn/S� SHOT SO2 2' 6 9188-9190 O 0821/11 G7 DOME CA SO 1.56' 6 9813-9824 O 05/26/19 1.56' 6 9829 - 9645 O 0526/19 1.56' 6 9853-9866 O 05/26/19 1.56' 6 10040-10170 O 09/11/10 1.56' 6 10240-10380 O 09/11/10 1.56' 6 10460-10490 O 09/11/10 1.56' 6 10570 - 10600 O 09/11/10 1.58' 6 10650-10830 O 09/11/10 1.56' 6 11000-11140 0 09/11/10 1.56' 6 11230-11260 O 09/11/10 1.56' 6 11310-11570 0 09/11/10 SAFETY NOTES: WELL ANGLE> 70" Q 9840' "' C -3 7 B PREVIOUS WELL BORES NOT SHOWN BELOW OTOS XDB SSSV N, 0: DSSSV, ID =1.75' (05 GAS LFT MANDREL s ST MD I ND DEVI TYPE I V LATCH I PORT DATE 2 1 4439 6961 4270 6567 24 24 G7 DOME CA SO PoC RK 16 20 0524/17 0524/17 NS PATCH X 7- Z- YMENT SLV, ID = D =1.781' MILLOUT WINDOW (C -37B) 9558' - 9563' PRUDFOE BAY UNIT WELL: CwWB 7 LTP P9RBr No: 12101000 DSSSV API No: 50-029-22360-02 SEC 19, T11N, R14E, 1110' FNL & 879' F EL - UFDAT® FKR TOP SP Exploration (Alaska) STATE OF ALASKA *ALASKA OIL AND GAS CONSERVATION COMMIS ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change A proved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 21 Re-enter Susp Well ❑ Other: Set atc m 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 210-100 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22360-02-00 7. Property Designation (Lease Number): ADL 0028305 8. Well Name and Number: PBU C -37B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: RECEIVED Total Depth: measured 11625 feet Plugs measured feet true vertical 8992 feet Junk measured feet J U N 26 6 2 0 { 7 3 Effective Depth: measured 11586 feet Packer measured See Attachment feet true vertical 8993 feet Packer true vertical See Attachment feet AOG C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 91.5# H-40 35-115 35-115 1490 470 Surface 3293 13-3/8" 68# L-80 33-3326 33-3248 5020 2260 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9188 - 9190 feet feet 10040 - 10170 feet 10240 -10380 feet 10460 - 10490 feet 10570 - 10600 feet 10650 - 10830 feet 11000 - 11140 feet 11230 - 11260 feet 11310 - 11570 feet True vertical depth: 8554 - 8556 feet feet 9026 - 9024 feet 9021 - 9020 feet 9021 - 9023 feet 9026 - 9025 feet 9020 - 9016 feet 9010 - 9007 feet 9006 - 9006 feet 9006 - 8994 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and See Attachment See Attachment See Attachment true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED JUL 2 5 20117, 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: 169 4837 10 420 221 Subsequent to operation: 194 7850 11 930 236 14. Attachments: (required Per 20 AAc 25.070.25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations m Exploratory ❑ Development m Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Glasheen, Brian P Contact Name: Glasheen, Brian P Authorized Title: Production Eng' eer Contact Email: Brian.Glasheen@bp.com Authorized Signature: Date: �6 t Contact Phone: +1 907 564 5905 Form 10-404 Revised 04/2017 1 ' TL -7-/ 7 ( 1 --7—I 117 RB DMS w J U N 2 8 2017 Submit Original Only 0 . Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED JUN 26 2017 RE: BP Exploration (Alaska), Inc. AOGGC Report of Sundry Well Operations Summary June 23, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of Patch to Repair the Well C-3713, PTD # 210-100. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 0 0 Casing / Tubing Attachment PBU C -37B Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 35 - 115 35 - 115 1490 470 SURFACE 3293 13-3/8" 68# L-80 33---F- 3326 33 - 3248 5020 2260 INTERMEDIATE 1819 9-5/8" 47# NT -80 31 - 1850 31 - 1848 6870 4760 INTERMEDIATE 5012 9-5/8" 53.5# N-80 1850 - 6863 1848 - 6476 7930 6620 INTERMEDIATE 2189 9-5/8" 47# NT -80 6863 - 9052 6476 - 8436 6870 4760 LINER 674 7" 29# N-80 8884 - 9558 8288 - 8817 8160 7020 LINER 2424 2-3/8" 4.7# L-80 9201 - 11625 8565 -F 8992 11200 11780 TUBING 1 4-1/2" 12.6# L-80 29 - 30 29- 30 8430 7500 TUBING 9528 3-1/2" 9.2# L-80 30 - 9558 30 - 8817 10160 10530 0 0 • • Packers and SSV's Attachment C-37B SW Name Type MD TVD Depscription C-37B PACKER 8128 7617.9 NS 350 LT Packer C-37B PACKER 8233 7711.35 3-1/2"WF Patch Packer C-37B PACKER 8892.05 8295.7 7" Liner Top Packer C-37B PACKER 9177 8544.78 3-1/2" Baker KB Top Packer • • I- N Q p O C w a 0 •c m c v Q Q 0 •5 0 a*0o ami O = N ate) it Q 2 J Q w w , rn 4- LE F- a o -1 cn w ix ce M 2 0 aa)) N .a O W LU LU - ea o N- 0 o 3 o N F- z z H NU � � C1 v i s Z D v c II ° Q v voD O O ce v ca O •N aa) u. aa) 0 O 0 0 O 0)j , v° CY c 0 a J O Z ovv a) n - UW <Z J o N - LL ceLL 3 a) W 2 0 c CD Q © z LL J J o6 — 73 4i 2 LT. 0 `.-p v LL — J LU L O O i O U 'a Q LL LL O O (_ * O N C V CO c Q LL O O O Q N II J N r CO Q co OJ fA N Q U w JQ .72 O d < 00 0 0 0co -0 0 Y -�O• i, Q _ ?, Z 0 Qw Q C� 0 0 0 0 N a °° ++ W 0 N N CO or LL c U w ,x Z Z Z Z 0 ° E as II OD T- -- ca W CL d N m w CC CO a) � 2 < Q = ChF' m - c0 0 0o Q-co ZF- W W w W F- ° = 0- I N c= z Q Q Q a v E ° o N N o rnw OU O Q ¢ Q Q v c.'i roc c 0 w0- o W o - Q 0- o a a) LU ZLu ZO C7 O 0 CWu) d p W U � Q Q00 co I_ 0i_ _ F- W O io b CV J (n .�. * -J ? .Q � � Q „O < WN- pa)6. _o Q * Z oS 06 « • CO Q' � *it C7 Q0 = = �r m JF- Lo o • O ' 0 �10 • � = U n � « N O 1`.. 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CO q co / CO LC) $ I ILL= CNV • WELLHEAD= FMCS NOTES: WELL ANGLE>70° 9840"** ACTUATOR= BAKER C C PREVIOUS WELL BORES NOT SHOWN BELOW INITIAL KB.ELE 67.7' WHIPSTOCK*** BF.6.EV= 32' KOP= 2050' Max Angle= 99°@ 10666' 20"CONDUCTOR, — 110' 2106' ,—{3-V2 OTIS XDB SSSV N,C=2 750" 1 Datum MD= 9624' 91.5# H.40, ---- 2106' j—3-1/2"OTIS DSSSV,D=1.75"(05/24/17) Datum TVD= 8800'SS D=19.124" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 9-5/8"CSG,47#,NT-80 BUTT,ID=8.681" — 1891' 2 4439 4270 24 CA DOME RK 16 05/24/17 LI >G 1 6961 6567 24 CA SO RK 20 05/24/17 13-3/8"CSG,68#,L-80 BTC,13=12.415" H 3328' 9-5/8"CSG,53.5#,NT-80 BUTT,D=8 535" 1-1 6864' 8128' —NS 350-272 LTP&UPPER PATCH ASSY w/QCLL SEAL ASSY,MWD=1.75"(05/23/17) 8233' —3-1/2"WFD LOWER PATCH WP LE PKR, MN D=1.81"(05/15117) Minimum ID = 1" @ 9190' 1 8.893' 1 9-5/8"X 7"TIWLTP w1LNRHANGER { INSITU PROFILE GLM 9045' —I EST TOC(09/10/10) 9-5/8"LIR,47#,NT-80 BUTT,13=8.681" — 9053' y 91 9177' 1-135 KB SPECIAL CLEARANCE LTP,D=1.81"(4/21/17) i/ 9190' —INSITU PROFLE GLM 1"D w/16164 FORT OGLV- TOP OF 2-31$"LNR — 9201' r AND NS SEAL LOCATOR STINGER(03/30/17) iii r` \, 3-1/2"VM-#PSTOCK(08/19/10) --f 9558' `•�i P 9201' —12.70"DEPLOYMENT SLV,D=2.250" el P-v 3-1/2"TBG,9.2#,L-BO TDS,.0087 bpf,D=2.992" --1 —9863 jj 9212' --12-3/$"FWJOWT,D=1.920" 7"LIR,29#,NT-80 NSCC,.0371 bpf,D=6.184" —9563 I�� s i MLLOUT WINDOW(C-378) 9558'-9563' i pil PERFORATION SUMMARY REF LOG_SLB MCNUGR/CCL ON 09/10/10 ANGLE AT TOP FE3 :35°@ 9188' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SO2 ' 2" 6 9188-9190 0 08/21/11 1.56" 6 10040- 10170 0 09/11/10 I 1.56" 6 10240-10380 0 09/11/10 1 56" 6 10460-10490 0 09/11/10 1.56" 6 10570- 10600 0 09/11/10 I 1.56" 6 10650-10830 0 09/11/10 ' 1.56" 6 11000- 11140 0 09/11/10 1.56" 6 11230- 11260 0 09/11/10 I 1.56" 6 11310- 11570 0 09/11/10 I I PBTD — 11586' •, 2-3/8"LNR,4 7#,L-80 STL, 0039. bpf,D=1.995" H 11625' •��� DATE REV BY COMVE'ITS DATE FEV BY COMvU'ffS PRUDHOE BAY UNIT 06/03/93 D9 SUSPB3DED COMPLETION 05/23/17 BTN/JMD SET LOWER PATCH(05/15/17) WELL C-37B 09/06/93 D16 ORIGINAL COMPLETION 06/01/17 LLG/JMD SET UPPER PATCH&DSSSV PERP/1T No:"1101000 09/16/01 NORDIC1 CTD SIDETRACK(C-37A) 06/01/17 JPK/JMD GLV GO(05/24/17) AR Pio: 50-029-22360-02 09/11/10 NORI7C1 CTD SIDETRACK(C-378) SEC 19,T11N,R14E, 1110'FM.&879'FEL 04/21/17 JMG/JMD RESET LTP(04/21/17) 04/25/17 JMG/JMD GLV C/O(04/21/17) BP Exploration(Alaska) • • vL cr- 37 P PrL z(0i000 Regg, James B (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Friday, May 26, 2017 3:09 PM To: AK, GWO Well Integrity Engineer; AK, OPS GC3 Facility OTL;AK, OPS GC3 Operators;AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Special Projects;AK, GWO SUPT Slickline;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS Well Pad CX; Glasheen, Brian P;AK, OPS GC3 Field OTL;Wallace, Chris D (DOA);AK, GWO SUPT Well Integrity; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA);AKIMS App User; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington, Aras J;AKIMS App User;AK, GWO Well Integrity Well Information Subject: OPERABLE: Producer C-37B (PTD #2101000) 2 Barriers Restored Post-Tubing Patch All, Producer C-37B (PTD#2101000) was made Not Operable on 05/26/16 after failing a cold TIFL. The well was secured with a down hole plug, and passed a CMIT-TxIA to 2,800psi on 05/28/16. A leak detection log ran on 08/02/16 indicated possible tubing leaks at 8,168' 8,200' and 8,230'.The well was made Under Evaluation on 05/06/17 and was allowed to flow for diagnostics of the insitu gas lift packer. Well testing confirmed correctly sized insitu gas lift packer. Tubing integrity was restored on 05/23/17 after setting a tubing patch across tubing holes and confirmed by a subsequent passing MITIA. This well is now reclassified as Operable. Please mind fluid pack annuli when POPing well. Jack Lau (41141.11611e: Adrienne MI,e}) BP Alaska-Well Integrity Superintendent sows AL 1 42G17 W: 907.659.5102 C: 907.943.0296 H: x2376 From: AK, GWO Well Integrity Engineer Sent: Saturday, May 06, 2017 5:34 PM To: AK, GWO Well Integrity Engineer; AK, OPS GC3 Facility OTL; AK, OPS . Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, GWO •'T Special Projects; AK, GWO SUPT Slickline; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Ens , AK, OPS Prod Controllers; AK, OPS Well Pad CX; Glasheen, Brian P; AK, OPS GC3 Field OTL; 'chris.wallace@.. -ska.gov'; AK, GWO SUPT Well Integrity Cc: AK, GWO DHD Well Integrity; AK, GWO Projects - Integrity; AK, OPS FF Well Ops Comp Rep; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; AKIMS App User; D- psey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Ster''cki, Oliver R; Worthington, Aras J; AK, GWO Well Integrity Well Information Subject: UNDER EVALUATION: Produc= C-37B (PTD #2101000) Flow for Repair Diagnostics All, • 0 r 1- > C c0 r r r D � rrrrr " v ( � 3 a - > � to o > t o � _ � ovE O u 4 > 'J Z r r r r r r r r N CO O y 41 O i'_1 a v c C ? CD W L `.0 d @ a) @ i a.+ O 1- 0 N W @ O v Q@ Q < tt -J a. m Q _c u E a C m O J Q.Y W O CO tp CO CO O O t0 tD v O .J a 0 o _ '� �- Q _ _ t7) 01 E ate-, _c 'u6 O N Q 3 7O) mm 7 7 O i s i N c J 7= 3 7 @ W — 0 0 0 Q Q Q Q Q C CO 0 L `4 ' M r N t0CY) CC' N N 0 4 L C U a 0 +- Z2 > \o a Q F Z N .�., C 4 CL CI 0 0 0 0 0 0 0 13.0 0 p 00 W W W W W W W W W in c) ' H LL LL LL LL LL LL LL LL LL 4-' QJ 0) v -0 O Q J J J J J J J J J a 0 > a"' v En 1- 0 0 0 Q Q Q Q Q Q 61 in C `� L = a+ d. z z z z z z z z z U s v O v LL LL LL LL LL LL LL LL LL - c > EC u a V Z r C 0 u 4 V fes.. O y ra O @D L O V cL F re 0 0 ce LL Q 0 2 0_ O O b v In N Ore tin O i+ m 0 a N E o o 73 7a 7 w w w o a NM Ti9 J @ o f w v• E 0 Q W y d N N Q ib. a W O OA >' m a U U D d PI C.) J, E 1- v O 0010 o g We s < CI W Z x p Z Z x 10 R7 W Q', > > T ,>2 Z •►3 13 `3 a E . E E E V ts t----711111 -911910. 0 g m m m i -m m Z z § Z z Z O O O o 0 0 D 0 0 o x x x 2 x x m R F a --10001_ 00u) 00 W 0 0 0 z > > J Y N a a a 0 a a Ml] a iii :`� CO '7 }W � CMO 0 0 M M 0 V X In 0 J O M 0 0 0 0 0 0 0 O 0 CO lT moo 4,4 0 0 O O O O O O O O E 0 # to LL LL c0 01 Cf V 0) Ili Q Z /'� z N MINN z Y 2 v 0 Eas di 1.1 `.J N 000000000 a (13 Lium o 3irf f O WQ N r N O O N O O 2 C S�+ O O O O O O O 0 O a _ CO to CO CO c0 0) CO CO N 1- 0 N N N - O M o') 0 N N N N N N N N N N yEj C n 0) t71 O) O) O) O) to O1 01 c O O000 N N N N N N N N N @ o O 0 0 0 0 0 0 0 0 C 00 0 0 0 0 0 0 0 V Y 0 ✓ 5 C N N N to N in to N 0 C m L z �i E a) 00 0 0a, ea W �( 1 K u '7, U t 8 Ts Z ��+ m Z m co co N N 4+ Er C CV rev) ^ N N. M N 4 C') 7 N. N • C C w -U - c �� aQ ON _ix00a_ o0 JJ -1 0 Z � u 0 12 .i. ,i "' C +-' CO u a r1 `� ^ CO .0 4J C 000, baa - it a` a 4m -240_00 • • -2_13sco WELL LOG TRANSMITTAL DATA LOGGED ACI PROACTIVE DINOSTIC SERVICES, INC. RECEIVED� py /L01�O ,i1ut'F M. K.BENDER JUL 06 SIG To: AOGCC AOGCC Makana Bender 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2— 1 900 Benson Blvd. Anchorage,AK 99508 ciancpdc@bp.com and ProActive Diagnostic Services, Inc. 1\10142 1 8 2.J1E Attn: Diane F.Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Leak Detection 26-May-16 C-37B BL/CD 50-029-22360-02 2) Signed : �""�" '� 6_6k.* Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(WMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFIles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, May 26, 2016 5:20 PM To: AK, OPS GC3 Facility OTL;AK, OPS GC3 Operators;AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Glasheen, Brian P;AK, OPS GC3 Field OTL; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R;AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA); Holt, Ryan P; AK, D&C Well Integrity Coordinator Subject: NOT OPERABLE: Producer C-37B (PTD#2101000) Sustained Inner Annulus Casing Pressure All, Producer C-37B(PTD#2101000) was reported to have sustained inner annulus casing pressure over MOASP on April 28, 2016. A cold TIFL performed on April 30, 2016 failed due to casing re-pressurization indicating a potential lack of two competent barriers in the wellbore and was reclassified as Under Evaluation for additional diagnostics. Subsequent attempts to restore integrity have failed within 28 days. The well is now reclassified as Not Operable until integrity can be restored. Plan Forward: Restore Integrity 1. Well Integrity: Not Operable 2. Slickline: Change out GLV's 3. Pumping: MITIA Please call with any questions. Thank you, SCANNED SEP 2 6 2016 Jack Lau (Alterncrte:)Aclrienne Mcl'e� BP Alaska-Well Integrity Superintendent �• ? 8r9a tilal:G;1 Office: 907.659.5102 Email: AKDCWellIntegrityCoordinator@BP.com Fro . • D&C Well Integrity Coordinator Sent: Sunday, ` . : '16 3:40 PM To: AK, OPS GC3 Facility OTL; , e' GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Servic- e.- ations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East V!- I It Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; 'Glasheen, Brian P'; AK, OPS GC3 Field OTL; 'chris.wallace@alaska... Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity En.' -- • Sternicki, Oliver R; AK, OPS FF Well • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday, May 01, 2016 3:40 PM To: AK, OPS GC3 Facility OTL;AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers;AK, OPS Well Pad CX; Glasheen, Brian P;AK, OPS GC3 Field OTL; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; AK, OPS FF Well Ops Comp Rep; Pettus, Whitney; Regg, James B (DOA); Holt, Ryan P Subject: UNDER EVALUATION: Producer C-37B (PTD #2101000) Sustained Inner Annulus Casing Pressure All, Producer C-37B (PTD#2101000)was reported to have sustained inner annulus casing pressure over MOASP on April 28, 2016.The pressures were confirmed to be TBG/IA/OA= 2450/2403/0 psi.A subsequent cold TIFL performed on April 30, 2016 failed due to casing re-pressurization indicating a potential lack of two competent barriers in the wellbore. At this time, the well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Hot TIFL 2. Evaluate pull & reset DSSSV with extra packing. 3. Hot TIFL Please call with any questions. SCANNED MAY 0 9 2016 Thank you, Jack Lau (A lternate:)Adrienne McVey BP Alaska-Well Integrity Superintendent GY Y Organization Office: 907.659.5102 Email: AKDCWeIllntegrityCoordinator@BP.com From` TK;D C Well Integrity Coordinator Sent: Monday,-A 17, 2015 10:49 AM To: AK, OPS GC3 Facility L PS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Haffener, Jordan; AK, OPS GC3 Field OTL Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity€n neer; AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; AK, OPS FF Well Ops Comp Rep; Pettus, Whitney Subject: OPERABLE: Producer C-37B (PTD #2101000) MIT-IA Passed post DSS t STATE OF ALASKA • O4LASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate,❑a`�� Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well L✓J Re-enter Susp Well 0 Other:LTP Repair I3 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: `210-100 3. Address: P.O.Box 196612 Anchorage, Development I Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: • 50-029-22360-02-00 7. Property Designation(Lease Number): ADL 0028305 . 8. Well Name and Number: + PBU C-37B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: • PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured . 11625 feet Plugs measured 9128 feet c 9 t1 true vertical . 8992 feet Junk measured None feet SEP 0 201 l Effective Depth: measured 9128 feet Packer measured 9174 feet !w true vertical 8503 feet Packer true vertical 8.519.39 feet / D .s�C ' Casing: Length: Size: MD: TVD: Burst: Collapse: v Structural Conductor 80 20"91.5#H-40 30-110 30-110 1490 470 Surface 3293 13-3/8"68#L-80 35-3328 35-3250 5020 2260 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9188-9190 feet 10040-10170 feet 10240-10380 feet 10460-10490 feet 10570-10600 feet 10650-10830 11000-11140 feet 11230-11260 feet 11310-11570 feet True vertical depth: 8554-8556 feet 9026-9024 feet 9021-9020 feet 9021-9023 feet 9026-9025 feet 9020-9016 9010-9007 feet 9006-9006 feet 9006-8994 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.3#L-80 21 -9558 21 -8817 Packers and SSSV(type,measured and 35 KB Liner Top Packer 9174-9178 8,542.27-8,545.61 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: scWIED JAN 1 12.016 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 196 10056 3 0 301 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development m ' Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El ' Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Summerhays,Nita M(WIP'•c Technologies) Email Nita.Summerhays@bp.com Printed Name ummerhays := M . -RO Technologies) Title Petrotechnical Data Manager Signa'"'='// yj ' ��� - Phone +1 907 564-4035 Date 09/09/2015 f�/� Lfiri,•�.......•,.y Form 10-404 Revised 5/2015 1/7-1._ q/11115- ��� SE1 1 2015 Submit Original Only R ��� RBDM 777����J f"P L J • • Daily Report of Well Operations PBU C-37B ACTIVITYDATE SUMMARY ***WELL S/I ON ARRIVAL*** (leak detection log) DRIFT W/2.75" DUMMY WHIPSTOCK TO WFD WRP AT 9,128' MD 8/13/2015 ***CONT ON 8/14/15 WSR*** ***CONT WSR FROM 8/13/15*** (leak detection log) ATTEMPT TO EQ & PULL 3-1/2"WFD WRP AT 9,128' MD RAN 2.611"CENT&2.60" LIB TO 9,126' MD (impression of fill) BAIL W/2.25" PUMP BAILER TO 9,126' SLM (-1 cup of scale) ATTEMPT TO EQ & PULL 3-1/2"WFD WRPAT 9,128' MD BAIL W/2.50" PUMP BAILER TO 9,126' MD (—3 cups of scale) PULL 3-1/2"WFD WRPAT 9,128' MD RAN 3-1/2' DOGLESS GS TO 35 KB LTP AT 9,174' MD (sheared) 8/14/2015 ***CONT 8/15/15 WSR *** T/I/O =S1 Assist SL as directed (LEAK DETECTION LOG) Pumped 5 bbls Meth down TBG, 8/15/2015 followed by 90 crude. End Ticket,job continued on 8/16/15 ***CONT FROM 8/14/15 WSR*** (leak detection log) PULL 35 KB LTP AT 9,174' MD (missing 75% of the elements/has both stiffener rings) - recovered missing WRP elements DRIFT W/3-1/2" BRUSH &2.26"WIRE GRABS TO 9,164' SLM (nothing retrieved) RAN 2.20"CENT, 1.75"x 10' PUMP BAILER TO 9,184' SLM (ring on centralizer, no recovery) RAN 2.70" BAITED STINGER DRIFT TO 9,201' MD SET LOWER LTP STINGER SECTION (max OD 2.70" )AT 9,201 MD SET 35 KB SPECIAL CLEARANCE UPPER LTP SECTION AT 9,174' MD **LTP OAL 34.84'** **NOTE: ONE AND A HALF PACKER ELEMENTS LEFT IN HOLE (1"x 4" and 1"x 8") 8/15/2015 ***CONT ON 8/16/15 WSR *** ***CONT WSR FROM 8/15/15*** (leak detection log) SET 3-1/2" CAT STANDING VALVE AT 9,136' SLM LRS PERFORMS PASSING CMIT Txl/A TO 2400 PSI LRS PERFORMS FAILING MIT-I/ATO 2400 PSI SET 3-1/2" DSSSV AT 2,089' SLM/2,106' MD LRS PERFORMS PASSING MIT-IAAND MIT-T TO 2400 PSI PULL 3-1/2" DSSSV AT 2,089' SLM/2,106' MD PULL 3-1/2" CAT STANDING VALVE FROM 9,136' SLM SET 3-1/2" DSSSV AT 2,089' SLM/2,106' MD RAN 3-1/2" CHECK SET(sheared) LRS PERFORMS PASSING MIT-IA TO 2400 PSI 8/16/2015 *** CONT ON 8/17/15 WSR *** ***Job continued from 8/15/15 WSR*** CMIT TxIA 2400 psi ***PASSED*** MIT IA 2400 psi ***PASSED*** MIT T 2400 psi ***PASSED*** Pumped 26 bbls crude down TBG, attempted MIT T/Failed. Pumped 5 bbls meth followed by 48.5 bbls crude down IA to achieve test pressure of 2400 psi on TxIA. 2nd attempt 15 min loss of 29/25 psi, 30 min loss of 15/16 psi, for total loss of 44/41 psi in 30 mins. SL set DMY SSSV. Pumped 19 bbls crude down IA to achieve test pressure of 2400 psi. 15 min loss of 31 psi, 30 min loss of 16 psi, for total loss of 47 psi. Bleed IAP to 500 psi. Pumped 3.2 bbls crude down TBG to achieve test pressure of 2400 psi. 15 min loss of 144 psi, 30 min loss of 48 psi, for total loss of 192 psi in 30 mins. Bleed TBG to 1000 psi/SL to pull DMY SSSV. Bleed TxIA to 500 psi. Pumped 9 bbls crude down IA for passing MIT-IA SL on well upon departure CVs OTG Tags hung on WV/IA AFE sign hung on MV***FLUID PACKED WELL*** FWHP= 280/300/100 8/16/2015 SV/WV/MV/SSV/SLICK LINE IA/OA OPEN *** CONT FROM 8/16/15*** (leak detection log) SWCP 4522 R/D 8/17/2015 ***WELL S/I ON DEPARTURE*** • • Daily Report of Well Operations PBU C-37B BBLS Type 2 DIESEL 10 METH 193 CRUDE 205 Total s • Q o 0 0 0 0 co co co N- CO CO CO N N I- N- O 0Nvvl� O U y 0 0 0 0 0 0 0 L O N O O O CO a N m Ln CO (..0 00 O O CO CO CO N LO d- CO N O N- N 00 - O O) CO CO N- CO CA CO CO h i l i ; I- CO CO CO LO CO CO CO CO CO V N CO N CO CO CO G) O CO O N " N CO N CO CO CO CO CO O O O CO N- CS) 6) o a41 CO - 5 < ti M V (4' O LC) c- CO CO O C) I CO CO CO CO CO N N C 0000) • m a o 0 0 0 0 0 co 00 CO co co J _ Z Z •N CI) Lc) CO *k *k Z - _ O) U �' M N CO N ON i) CO ti M r O O c."4 F' M C) O) 00 V I� C CO N CO COO CO J CON- NN- NO) W Q Q C w o a N U U w w Z I w W W w m O D F- H Z Z D U (nZZJJI— IK:h= C]w WELLPEAD= FMC • Silk NOTES: WELL ANGLE>70°@ 9840'••• ' ACTU KB.Fl F Oa 7' _3 7 B WHIPPREVS OCK US FI III BORES NOT SHOWN BELOW NT1ABF.ELEV= 32' KOP= 2050' Max Angle= 99'©10666' 20'CONDUCTOR 110' a2106' —13-1/2-OTS SSS/N,D=2.750" Datum MD= 9624' 91 a .5#,11-40, • Datum TVD= 8800'SS D=19.124" GAS LFT MANDRELS 9-5/8-CSG,47#,NT-80 BUTT,D=8.681" — 1891' •ST MD TVD CEV TYPE' VLV LATCH FORT DATE 13-3/8'CSG,68#,L-80 BT =12.415" H 3328' 2 4439 •4270 24 CA DAY RK 0 02/17/15 C,1) 1 6961 6567 24 CA DMV RK 0 02117/15 9-5/8"CSG,53.5#,NT-80 BUTT,D=8.535' H 6864' Minimum ID = 1.81" © 9174' _, 8893' 9-5/8"X7"TfWLTPw/LWHANGER 35 KB LINER TOP PACKER y r:' 9045' —EST TOC(09/10/10)l P:, 9-5/8'Lt*,47#,NT-80 BUTT,D=8.681" — 9053' d *' 9128' SLMD I—3-1/2" .WD WRP SPEaAAL CLEARANCE(2/17/15) • 9174' 35 KB LTP,D=1_81'(09/16/14) ; 9190' —IISfTU PROFILE GLM w/WTEGRAL FLOW SLV- COW BRIE)TO 16/64"PORT OGI V(9/16/14) 4 TOP OF 2-3/8'LW H 9201' R OAL 32.4T-1"W W GLV OUT/NO I©WHEN IN lim :::111 r• ` 9201' _—2.70"DEPLOY M "IT SLV,ID=2.250" V. t 13-1/2"VN-FSTOCK(06/19/10) H 9558' p 9212" 23/8"PUPJOM,D=1.920" 3-1/2"TBG,9.2#,L-80 MS,.0087 bpi,D=2.992' — -'9863 'irG( r LW,29#,NT-80 NSCX),.0371 bpf,D=6.184" H I -9563 e �► 1i '' MLLOUT VITDOW(C-37B) 9556'-9563' N i PERFORATION SUMMARY I REF LOG:SLB I CNUGR/CXL ON 09/10/10 ANGLE AT TOP FH2F:35°© 9188 I Nate:Refer to Roduction CB for historical perf data SIZE SPF INTERVAL OprdSgz SHOT SOZ 2" 6 9188-9190 0 08/21/11 I 1.56" 6 10040- 10170 0 09/11/10 1.56" 6 10240-10380 0 09/11/10 I 1.56' 6 10460-10490 0 09/11/10 1.56' 6 10570- 10600 0 09/11/10 I 1.56" 6 10650- 10830 0 09/11/10 1.56' 6 11000- 11140 0 09/11/10 I 1.56' 6 11230- 11260 0 09/11/10 1.56" 6 11310-11570 0 09/11/10 - I FBTD -I 11586' I ••i 2-3/8"LW,4.7#,L-80 STL,.0039 bpf,0=1.995" H 11625' 4' DATE REV BY C OP.6.U'ITS DATE REV BY OD&41.1134TS FRUCHDE BAY UNT 06/03/93 D9 SUSPENDED COM PLETION 09/18/14 JK/PJC LW w/NSfTU GLM CORRECTION VVf3L, C-37B 09/06/93 016 ORIGINAL COMPLETION 09/23/14 LEC/PJC LTPCORRECTION PE321.4T No:' 101000 09/16/01;NORDIC1 CTU SIDETRACK(C-37A) ,02/20/15 JTM'JIID'GLV GO&SET ARP(02/17/15) API No: 50-029-22360-02 09/11/10 NORDIC 1 CTDSIDETRACK(C-378) SEC 19,T11N,R14E, 1110'FM_&879'FE_ 09/09/13 SWCIJFIC'GLV C10(08/19/13) 09/16/14 OLW/PJC'CIO LTPw/INSlTU GL MArDRI1 1, BP Exploration(Alaska) • 2.N0-\00 o$3-oco3 25G1`{ 25613 WELL LOG ` D5 Z LOGGED /o TRANSMITTAL I M.K.BENDER AE COVED PROACTIVE DIAGNOSTIC SERVICES, INC. APR 0 9 2015 AOGCC To: AOGCC Makana Bender 333 W. 7th Ave SEAMED MAY 0 '7 2015 Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 gancpdc@bp.com and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 09-Mar-15 C-37B BL/ CD 50-029-22360-02 2) LeakPointTM Survey 08-Mar-15 07-24 BL/ CD 50-029-20945-00 Signed : o_ejfAeft Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(C7MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Archives\MasterTemplateFdes\Templates\Distnbut on\TransmrtalSheets\BP_Transmit docx Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q1 0 - J Q Q Well History File Identifier Organizing (done) ❑ Two-sided II 1 I IIIIII III ❑ Rescan Needed I I 11 11111 I RES9AN DIGITAL DATA OVERSIZED (Scannable) rir for Items: Ge scale It ems: ❑ Diskettes, No. 1 ❑ Maps: Other, No/T yp e: �y �0,• ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Adinal Date: ...„, /s/ Al P Project Proofing I I 11111 BY: Date: J /s/ ,I' Scanning Preparation Q2 x 30 = 60 + 19 = TOTAL PAGES 7'? (Count does not include cover sheet) BY: Maria Date: cal 41/if /s/ Production Scanning III III II VIII 11111 Stage 1 Page Count from Scanned File: V D (Count does include cover et) Page Count Matches Number in Scanning Preparation: YES NO 9 9 P BY: Date: 441114- /s/ me Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 11311111111111 ReScanned I 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III III IIII I 19/99/91111 1A/cl1 Hictnni Fit=rns/ctr Pmnc An, 0 C J 9 8 0 °m al U = 0 f0 N N Z 0 0 Z CO to.�U _C 0 co N = a' U L J to n. N 0 21 C O �. = N a a W C c N a LL o m J Co w p a o a—�-E us cc a Ua m E 0 U �° = ~c g Z > , , a t z 0 2 Li 0 2 N 22 0> m > U0 U d CO� c Q To o a 0 0 a m N N N J N V N N N N 0 N O Q N Q J N N O CO W cC N W M W M Z `- ,- .- t� r t� h CO CO .4 E c d ▪ 7 C C O O C C C C C C y N E `� C) C) N co Cl) N C) C) C) a) N N N C = = a O. t6 CO a a. o. Q. a a CO m E 0 O O D U 0 0 0 0 0 O U 0 o I.I. Q U w 0 c m a co co N U) to In 0 In In co m O z m r co N co N tin co .o Co co N co N co co a0 d y CL • U z EyE ce y Z O J C 0) CO 0 O N In In N 2 Cl) In co co O co co O N O N 0 0 CO O CO d U) C) 0) CO CO 0) 0) 0) 0) O) 0) CO CO W W J U m o Z Q S oo m ` N ce z C) o J a '° CL 0 co O tag ? o 0 0 N c ZI J 2 m U U U i0 5 0 ` N N N _N a a) O) R N tO In N O E a o to U � 0 E m ct Q C a .2 O▪ _ To C N d Q m rn V U C o C) a /� 0 A D 0 J co Q a o U a) oI a_ Q a Z Z E T T 0 as 13 as U O Z Z c J > > o a a as a M co co m N N N N a O O z C C a' a' CL CC c F- a m CO ci Co cu Co ca y E O O o o E E E E E N C) c co• co Z co ,- N C) C) IC IC N co E CO y E O Co y O 0 Z Z 0 0 0 C7 0 31 0 0 m 0 E O > z J d d v co co N CO CO N- N- O . c m .3 E o o O Q Z w C W 0 Z N N N N N N 2 O O l0-. C) Q O N a+ a a) F E E .` V O lL N N co N 'NO N t0 0 0 0 C 17)a Q J J \ J \ a z in E Q' Z W J �U U\U , 1 a U U O \ E 0 Q '" _ as W0 0 � _TD a aG J O H a W J W W J J J W Ce J W 0 0 N O O to CeJ N Z I/ Cl o) U_ N 5 0 N O z a J 0 0 O z = ii Cl) lb- CO IX Q a=i O Z U Z Zy Ill g lt a v W W J > V m o 8 0 Z W a H Q y u, o J o _ .; 13- co E . N _ 03 o 2 r- s 0 LL o a O o E I I,- J CO I QM U F- 0 E 0 N aCO ty m ch w N CO m 7 0 Q cc �- a 15 A Qz o o a 0 E U 1//1 z Ti N O co Z p o } 3N N 0 0 LL Z v d E Lo J a) a 0 >N N c� Z .. V « O o y R CI) C >_ E o = a m 8 E E a a 2 a 0< Q 0 0 STATE OF ALASKA 4" _# ?.1, • AL,- JKA OIL AND GAS CONSERVATION COMMIS,,,JN 1;.: s ,, REPORT OF SUNDRY WELL OPERATIONS Ali n ` " '°' 1.Operations Abandon U Repair Well IA Plug Perforations U Perforate U Other , H J Performed: Alter Casing ❑ Pull Tubing"' Stimulate-Frac ❑ Waiver ❑ Time Extension") Change Approved Program ❑ Operat.Shutdowns Stimulate-Other ❑ Re-enter Suspended Well"' 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development 19 Exploratory ❑ 210-100-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-22360-02-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028305 ' PBU C-37B 1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 11625 feet ' Plugs measured None feet true vertical 8992.22 feet Junk measured None feet Effective Depth measured 11586 feet Packer measured See Attachment feet true vertical 8993.28 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 78 20"91.5#H-40 32-110 32-110 1490 470 Surface 3297 13-3/8"68#L-80 31-3328 31-3250.38 5020 2260 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9188-9190 feet 10040-10170 feet 10240-10380 feet 10460-10490 feet 10570-10600 feet 10650-10830 feet 11000-11140 feet 11230-11260 feet 11310-11570 feet 1 True Vertical depth 8553.9-8555.54 feet 9026.38-9023.92 feet 9021.22-9019.57 feet 9020.79-9022.93 feet 9026.07-9025.47 feet 9020.16-9016 feet 9010.42-9007.49 feet 9006.33-9005.98 feet 9005.51-8993.95 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.3#L-80 29-9863 29-9027.08 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 459 20589 25 0 694 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Explorator10 Development 0 • Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U . Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCO 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 Nita Summerhays Email Nita.Summerha s• BP.com I Printed Name Nita Summerhays . Title Petrotechnical Data Technician i /_ Signatu:a0j !T/ : _�_� , j,�� Phone 564-4035 Date 8/20/2013 -■ /o " RBE DUI n S SEP - 5 1Q1 'I q//e//3 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028305 ACTIVITYDATE ate. -***WELL S/I UPON ARRIVAL*** (profile mod) TAGGED DEPLOYMENT SLV AT 9171' SLM W/20' x 2.74" DRIFT&2.50" LIB (picture of sly). 7/25/2013 ***JOB CONT. ON 7/26/13*** T/I/0=2400/17$0/140 SI Assist SL with LTP set (WELLHEAD/ I REE REPAIR) Standby 7/25/2013 for SL. ***Job continued on 7-26-13 WSR*** ****JOB CONT. FROM 7/25/13****(profile mod) SET BAKER 35 KB LT PKR W/ HES DPU @ 9173' SLM/9201' MD (top @ -9175' md) 7/26/2013 ***WELL LEFT S/I & PAD OP NOTIFIED ON DEPARTURE*** ***Job continued from 7-25-13 WSR*** Pumped 5 bbls 60/40 followed by 95 bbls crude down TBG to load for SL to set LTP. Pad Op notified SL on well upon departure CVs 7/26/2013 OTG FWHP=150/1750/350 FLUIDS PUMPED BBLS 2 DIESEL 5 60/40 METH 95 CRUDE 102 TOTAL as C.000000 �0.) Cp � N � COCOCOO O f� f • N O N 0 • 0 0 0 0 0 O O E O) CO O I� r N CO co co m r co CO CO 0 CO N LO co CO OD O I- N 1' Cr) Cr) O N 0 N O N CA CO Cr) 0 N CO CD CO N CO CO CO c) CA CO N ▪ 0 M O co M Cr) N co co CD O C7 N c, 0 � C000) U[) NCO to OD O M W .0 CA 0) C) 0) a CO Ncoaaccoo — O) CAN Cr) CCOOCCV) COMN C SI C H 0 a O O o n, � c? J 1— J J = IL 4# ZZ N N � ZN 4tCOCV) 4:k _ V - c C.) O N E0 co = N M ) Cj co 47 N O 0) M _ Ca OD N- N Co co 0 00)) M • N- 0 N co N (V) 00) J 0 00 CD I- rn > » UCH ' O OOLQLZ 0ZWWO0cm OZZCLCCDD O J J 0 O U) • a) Y U co a 0 0 I- C o a) . c O. J m N a. Q O.H d ▪ OO H CO I_ a) a) C - J (0 m _ � N � _ r M t v Q O co tri M 01; CO O c O Q w - c o co Ce CO a aY • C..) C.) Q Q a. a as Emm Zchci U U Cl) !Kw= OW VVELLFFAD FMC SAFE NOTES: WELL ANGLE>70°@ 9840'. ACTUATOR= BAKER C C -37 B -0 WELL&C-37A NOT SHOWN BELOW INITIAL KB ELE 67.T BF.ELEV= 32' I KOP= 2050' Max Angle= 99°@ 10666' 20'COPDUCTOR, -I 110' I r 210-67-1---13-1/2"OTIS SSSVN,D=2.750" l Datum MD= 9624' 91.55#,H-40, Datum TVD= 8800'SS D=19.124" GAS LIT MAM) S 9-5/8"CSG,47#,NT-80 BUTT,D=8.681" H 1891' ST MD TVD DEV TYPE VLV LATCH FORT CATE 2 4439 4270 24 CA DOME RK 16 09/08/11 13-3/8"CSG,68#,L-80 BTC,13=12.415" H 3328' I`il 1 _6961_6567 24 CA SO FE 20 _06/07/12 9-5/8"CSG,53.5#,NT-80 BUTT,13=8.535" --I 6864' Minimum ID = 1.81" @ 9175' III M 8893' H9-5/8"xr ITN LTPw/LNRHANGER I I 3-1/2" BKR BOT KB LTP RI ,' 9045• IH EST TOC(09/10/10) 11 9-5/8"LNR,47#,NT-80 BUTT,ID=8.681' --I 9053' 1�1 4 1�1►� ► 9175' H3-1/2"BKR BOT KB LIP,0=1.81"(07/26/13) 11 A. TOP OF 2-3/8"LNR H 9201' VI t 1 9201' I-12.70"DEPLOYMENT SLV,D=2250",S, -. 9212' I-12-3/8" JOINT,JOT,D=1.920" I rili 3-1/2"VVHPSTOCK(08119/10) H 9558 Hiii 4• 3-1/7 TBG,9.2#.L-80 TDS,.0087 bpf,13=2.992" —I —9863 \►•1►•4 •7"LNR,29#,NT-80 NSCC,.0371 bpf,D=6.184" H —9563 ►1 A ••v liV !i1 1.1►•� .4'►►, MLLOUT VVNDOW(C-37B) 9558'-9563' PERFORATION SUMMARY REF LOG:SLB MCNUGR/CCL ON 09/10/10 ANGLE AT TOP FERF:35°@ 9188' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ r 6 9188-9190 O 08/21/11 1.56" 6 10040-10170 O 09/11/10 1.56" 6 10240-10380 O 09/11/10 1.56' 6 10460-10490 0 09/11/10 1.56" 6 10570-10600 0 09/11/10 1.56" 6 10650-10830 O 09/11/10 1.56" 6 11000-11140 0 09/11/10 1.56" 6 11230-11260 0 09/11/10 1.56" 6 11310-11570 O 09/11/10 I PBTD --I 11586' I •♦•.1 2-3/8"LM,4.7#,L-80 STL,.0039 bpf,D=1.995" H 11625' I .•∎•• DATE REV BY COMFITS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/03/93 D9 SUSPENDED COMPLETION 06/12/12 CDiJIJMD GLV C/O(06/07/12) WELL: C-37B 09/06/93 D16 ORIGINAL COMPLETION 07/06/12 CDJ/JMD C/O LTP&CORRECTED MN13(06/ PERMIT No:'2101000 09116101 NORDIC1 CTD SIDETRACK(C-37A) 08/15/13 CJN'JM) SET BKR BOT LIP(07/26/13) API No: 50-029-22360-02 09/11/10 NORDIC1 CTD SIDETRACK(C-37B) SEC 19,T11N,R14E,1110'FNL&879'FE_ 05/16/11 AK/PJC FINAL DRLG CORRECTIONS 08/28/11 JCM PJC ADPERF(08/21/11) BP Exploration(Alaska) STATE OF ALASKA AL k OIL AND GAS CONSERVATION COMf1ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Repair Well Pi Plug Perforations ❑ Perforate ❑ Other ❑ 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: Name: BP Exploration(Alaska), Inc Development 0 Exploratory ❑ - 210-100-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-22360-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: _ ADL0028305 PBU C-37B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 11625 feet Plugs measured None feet true vertical 8992.22 feet Junk measured None feet Effective Depth measured 11586 feet Packer measured See Attachment feet true vertical 8993.28 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 78 20"91.5#H-40 32-110 32-110 1490 470 Surface 3297 13-3/8"68#L-80 31 -3328 31 -3250.38 5020 2260 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.3#L-80 29-9563 29-8819.76 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: RECEIVED Intervals treated(measured): AUG 21 2012 Treatment descriptions including volumes used and final pressure: AOG a C 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 59 3934 2 0 1998 Subsequent to operation: 384 9097 13 0 226 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil — 0 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 Nita Summerhays Prepared by Nita Summerhays 564-4035 Printed Name Nita Summerhays Title petrotechnical Data Technician I Sign re 1oi/1 L /id i„ -� Phone 564-4035 Date 8/16/2012 Form 10-404 Revised 10/2010 F#BDMS AUG 2 2 2012 '�' Of ��/(v Submit Original Only Daily Report of Well Operations ADL0028305 "*WELL S/I ON ARRIVAL"**(gas-lift integrity) RAN 2.70" DRIFT W/2.50" LIB TO LTP @ 9140' SLM/9181' MD (impression of G fishing neck) RAN PDS 24arm CALIPER FROM LTP @ 9140' SLM TO SURFACE SET 3-1/2"WCS @ 9137' SLM/9181' MD PULLED STA.#1 FROM 6953' SLM/6961' MD 6/6/2012 ***CONT. ON 6/7/12 WSR*** ***CON r. FROM 6/6/12 WSR***(gas-lift integrity) SET STA.#1 RK- OGLV(5/16" PORTS) @ 6953' SLM/6961' MD PULLED 3-1/2" EMPTY WCS FROM 9137' SLM/9181' MD PULLED BKR LTP FROM 9140' SLM/9181' MD MADE ATTEMPTS TO FISH LTP ELEMENTS W/3-1/2" BLB, 2.625"WIRE GRAB 6/7/2012 ***CONT. ON 6/8/12 WSR*** ***CONT. FROM 6/7/12 WSR***(gas-lift integrity) MADE ATTEMPTS AT FISHING ELEMENTS W/3-1/2" BLB, 2.625 WIRE GRAB(no elements recovered) RAN 2-1/2"x 10' PUMP BAILER TO LINER TOP @ 9167' SLM/9201' MD (no elements recovered) RAN 2.70" DRIFT&2.50" LIB TO LINER TOP @ 9167' SLM/9201' MD (impression of liner top) RAN 2.0" LIB TO 2-3/8" PUP JOINT @ 9180' SLM/9212' MD (impression inconclusive) SET BAKER LINER TOP PACKER W/3- .188"ORIFICES @ 9172' SLM/9203' MD ' 6/8/2012 ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** FLUIDS PUMPED BBLS _ _ 3 DIESEL 3 TOTAL • • Perforation Attachment ADL0028305 Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth ND Depth Name Date Code Top Base Top Base C-37B 8/21/11 APF 9188 9190 8553.9 8555.54 C-37B 9/11/10 PER 10040 10170 8958.68 8956.22 C-37B 9/11/10 PER 10240 10380 8953.52 8951.87 C-37B 9/11/10 PER 10460 10490 8953.09 8955.23 C-37B 9/11/10 PER 10570 10600 8958.37 8957.77 C-37B 9/11/10 PER 10650 10830 8952.46 8948.3 C-37B 9/11/10 PER 11000 11140 8942.72 8939.79 C-37B 9/11/10 PER 11230 11260 8938.63 8938.28 C-37B 9/11/10 PER 11310 11570 8937.81 8926.25 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH 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 Packers and SSV's Attachment ADL0028305 SW Name Type MD TVD Depscription C-37B PACKER 8893 8228.84 7"TIW Liner Top PKR C-37B PACKER 9203 8498.43 3-1/2" Baker Liner Top Packer m I.0 O co O O O M eOt� NIOO (O � _ O 1� ti N p f� r N V O O O O o . 0) COON. N- NO a— 00 00 0 Q m a- 00 - CO CO CO N LO M 00 CO N- CV V Cr) Cr) N- ✓ O N CO N- O O) O 00 Cr) to CO CO CO N 00 CO CO a- 00 Cr) 00 co CN LO M O co O N- co CO co M CNI aFJ O co (NI a- M 00 .0 — U.3 cc el O CtLO) ▪ o V a co N 0c0 O O CCO a- O CD N co co c M oo M N co =Q I . a 0 0 0 0 0 • •o o0 00 C = J Z Z J J y N % Z # 4t CO M• U ON -0�0c cocf) NCh U? f7 N O O a— Cr) Z _ S CO CC) N CO 000 O) co C r— 00 a— N tC) J O CV a— N C') O O 00 IT) U O AU 0 r a o o Iai. Z VZwwOOCLm O Z Z CL CL > UJJa_ dco1- TREE= CIW WELLHEAD= FMC SP -NOTES: WELL ANGLE>70°@ 9840'. ACTUATOR= BAKER C C -3 7 B """ J CKL& C-37A NOT SHOWN BELOW KB ELEV= 67 7' BF. ELEV= 32' I KOP= 2050' Max Angle= 99°@ 10666 CONDUCTOR, 110' — 1 I 2106' H3-112'011S SSSVN, ID=2.750" I Datum MD= 9624' 91.5#,H-40, I Datum TVD= 8800'SS ID=19.124" GAS LIFT MANDRELS 9-5/8"CSG,47#, NT-80 BUTT,ID=8.681" _---1 1891' ST MD 71/D DEV TYPE VLV LATCH PORT DATE 2 4439 4270 24 CA DOME RK 16 09/08/11 13-3/8"CSG,68#,L-80 BTC,ID=12.415" H 3328' 1 6961 6567 24 CA SO RK 20 06/07/12 9-5/8"CSG,53.5#, NT-80 BUTT,ID=8.535" H 6864' / Minimum ID = 1.81" @ 9203' I L 8893' H9-5/8"XT'TNVLTPw/LNR HANGER A 3-1/2" BKR KB LTP w/ORIFICE SUB J ,/' '' 9045' 1HEST TOC(09/10/10) 9-5/8"LNR,47#,NT-80 BUTT, ID=8.681" 9053' �� A►Z� 2N 9203' I-3-12"BKR KBLTPw/ORIFICE SUB,ID=1.81" ) Li 1.4 �A� 06/08/12 / ��/� %/ TOP OF 2-3/8"LNR H 9201' 11• � I V �� 9201' :1-12.70"DEPLOYMENT SLV, ID=2.250" K, .0 9212' 1-12-3/8"PUP JOINT, ID=1.920" I 3-1/7'WHIPSTOCK(08/19/10) —I 9558' I 01►�4 •.04 • 3-1/2"TBG,9.2#,L-80 TDS, 0087 bpf, ID=2.997 --I —9863 �4�►.- .i�� 7"LNR 29#,NT-80 NSCC,.0371 bpf,ID=6.184" -9563 �'A ee, �•• .4.4 044 0.# MILOUT WINDOW(C-37B) 9558'-9563' ■■ • 0 PERFORATION SUMMARY REF LOG: SLB MCNL/GR/CCL ON 09/10/10 I ANGLE AT TOP PERF.35°t 9188' Note: Refer to Production DB for historical perf data ISIZE SPF INTERVAL Opn/Sqz DATE 2' 6 9188-9190 0 08/21/11 1.56" 6 10040- 10170 0 09/11/10 I 1.56" 6 10240- 10380 0 09/11/10 1.56" 6 10460- 10490 0 09/11/10 I 1.56" 6 10570- 10600 0 09/11/10 1.56" 6 10650- 10830 0 09/11/10 1.56" 6 11000- 11140 0 09/11/10 I 1.56" 6 11230- 11260 0 09/11/10 1.56' 6 11310- 11570 0 09/11/10 I I I PBTD H 11586' i♦1 2-3/8"LNR,4.7#, L-80 STL, .0039 bpf, ID=1 995" H 11625' .0,•,,,i DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/03/93 D9 SUSPENDED COM PLETION 08/28/11 JGWPJC ADPERF(0821/11) WELL. C-37B 09/06/93 016 ORIGINAL COM PLETION 09/20/11 RCT/PJC SET LTP&GLV C/0(09/07-08/11) PERMIT No `2101000 09/16/01 NORDIC1 CTD SIDETRACK(C-37A) 09/21/11 BSE/PJC LTP MN ID CORRECTION API No 50-029-22360-02 09/11/10 NORDIC1 CTD SIDETRACK(C-37B) 06/12/12 CD1/JMD GLV C/0(06/07/12) SEC 19,T11 N,R14E, 1110'FNL&879'FEL 05/16/11 AK/PJC FINAL DRLG CORRECTIONS 07/06/12 COJ/JMD C/0 LTP&CORRECTED MIN I0(06/08/12) 08/28/11 CMI PJC ADPERF(0821/11) 1 BP Exploration(Alaska) n 10Ur., Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] ��trlrf/lv Sent: Monday, June 11, 2012 8:49 AM f I To: AK, D&C Well Integrity Coordinator; Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC3&PCC OSM; AK, OPS GC3 Facility& Field OTL; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, OPS Prod Controllers; Meixueiro, Paulina; AK, OPS Well Pad CX Cc: Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M; LeBaron, Michael J; King, Whitney; AK, D&C DHD Well Integrity Engineer Subject: OPERABLE: Producer C-37B (PTD#2101000)Tubing Integrity Confirmed All, Producer C-37B (PTD# 2101000) passed a TIFL on 06/10/12 after the orifice gas lift valve was changed out. The passing TIFL confirms tubing integrity has been restored. This well is reclassified as Operable. Please call if you have any questions. Thank you, Whitney King filling in for Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 From: AK, D&C Well Integrity Coordinator Sent: Thursday, May 24, 2012 8:45 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC3&PCC oSM; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, OP •rod Controllers; Meixueiro, Paulina; AK, OPS Well Pad CX Cc: Walker, Greg (D&C); AK, D&C DHD Well Integrity Enginee Subject: UNDER EVALUATION: Producer C-37B (PTD #210 000) Sustained Casing Pressure on IA Above MOASP All, Producer C-37B (PTD#2101000) has confirmed s-stained IA casing pressure above MOASP. The wellhead pressures were tubing/IA/OA equal to 2450/2240Nac on 0, 21/2012. A cold TIFL was performed on 05/23/2012 and failed. The well has been reclassified as Under Evaluatio The well may be online while work is performed to restore integrity. Plan forward: 1. Operations: Put well on production 2. Downhole Diagnostics: Re-TIFL 3. Slickline: Change out orifice gast valve (if TIFL fails) A TIO plot and wellbore schematic have been included for reference. Please call if you have afiy questions or concerns. Thank you, i Mehreen Vazir 1 8 - 1 1C - ti O N n < E o O o 7 0 U .drn g m to - r w I'D Lo t U• to v NQt4 N Q QriQ co cu corn O co m n o O o F C O Y n U h U N WI- C U Q (NI J 0 1 w Of 6 o) a 6 Of Of o)o);6 Of o 7 7 7 7 7 7 7 7 7 Q O a Q Q Q Q Q Q Q Q a Q oaoA a Oo 01 f.), O I- x C 0 o Q •a w >- a 0 O C O 0 a) J � w z co IL IL 0 0 LL O n. Q 0 Z 0 1- 001- z a yJay — 2 a. 2 Z 2 Z Z 2 W W i- aay0 0000 1- p w D- 2 m j y LL Z M 3 LL XU. Z 22NOIZ2OZO ~aZ f3EC/ 0.o 0aaaaaoa Z z vc op0,- � ,-5R0o C3 C3 } O 4 4 o Q o Q o Q co o co co m 0V �4 �Va1-- � a a m m2 20 � :D u mC) iC13Q ?N co � Q > W Z m m m Q m m m m m Q 0 N d w co o 2 _J co w G N w t9 O 7 y N 0 0 N C A. IIU ` CL � •° N .o 4;ca O N Q C d ° m c : ui N y R co N � Z W p Jp 0 LIJ pO 4C C.4 am4 $i STATE OF ALASKA ALASKA. _AND GAS CONSERVATION COMMISSIG. REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other 0 LINER TOP PACKER Performed: Alter Casing ❑ Pull Tubing❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat.Shutdown❑ Perforate IS Re-enter Suspended Well ❑ 2.Operator BP Exploration(Alaska),Inc. 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development IO Exploratory ❑ • 210-100 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 r 50-029-22360-02-00 8.Property Designation(Lease Number): 9.Well Name and Number: ADL-028305 „ PBU C-37B 10.Field/Pool(s): PRUDHOE BAY FIELD/PRUDHOE OIL POOL Z,7..4/ Sam-',` 11.Present Well Condition Summary: Total Depth measured 11625 feet Plugs(measured) None feet true vertical 8992 feet Junk(measured) None feet Effective Depth measured 11586 feet Packer(measured) 8893 9186 feet true vertical 8993 feet (true vertical) 8297 8552 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20",91.5#,H-40 32'-110' 32'-110' 1490 470 Surface 3297' 13-3/8",68#,L-80 31'-3328' 35'-3250' 5020 2260 Production 1861' 9-5/8,47#,NT-80 30'-1891' 30'-1888' Production 7192' 9-5/8,53.5#,L-80 1891'-9053' 1888'-8437' 7930 6620 Liner 678' 7",29#,NT-80 8885'-9563' 8289'-8820' 8160 7020 Liner 2424' 2-3/8",4.7#,L-80 9201'-11625' 8565'-8992' 11200 11780 Perforation depth: Measured depth: SEE ATTACHED- _ _ _ - True Vertical depth: _ - Tubing:(size,grade,measured and true vertical depth) 3-1/2"9.3# L-80 29-9563 29-8820 Packers and SSSV(type,measured and true vertical depth) 7"TIW Liner Top PKR 8893 9186 3-1/2"Baker Liner Top Packer 9186 8552 RECEIVED 12.Stimulation or cement squeeze summary: SEP 2 7 2011 Intervals treated(measured): Treatment descriptions including volumes used and final pressure: AIeska Oil&Gas Cons. Commission Ancnorago 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 273 2611 2 158 Subsequent to operation: 268 2592 2 177 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 • Service ❑ Stratigraph❑ Daily Report of Well Operations X 16.Well Status after work: Oil . 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE 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: NA Contact Joe Lastufka Printed Na •e Lastufk� I Title Data Manager Signatu : n, 0,1_,.._ Phone 564-4091 Date 9/27/2011 . mil p ��QQ '],�, 2 r `/ Submit Original Only Form 10-404 Revised 10/20N9��MS SEP 2 8 10 `,/ — r� r NI%. 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U N000000000 QQmmLLLLM220 1 C-37B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMNIARY a " 8/12/2011 ***CONT WSR FROM 8/11/11 ***(profile mod) LRS PUMP 180* DIESEL(see LRS log) RAN 3-1/2" BLB,2.625"GAUGE RING TO 1209'SLM, RAN 2.35"GAUGE RING TO LINER TOP AT 9164'SLM (9201'MD) RAN 2.70"_GAUGE RING TO—6000'SLM, BRUSH TBG W/3-1/2"BLB, 2.70"GAUGE RING TO LINER TOP AT 9164'SLM(9201'MD) DRIFT TBG WITH 2.74" DUMMY WRP DRIFT TO 9164'SLM(9201' MD) ***WELL LEFT SHUT IN ON DEPARTURE, PAD OP NOTIFIED*** 8/12/2011 T\I\O= 1300\1300\140 Assist S-line (Brush and Flush)Pumped 5 bbl meth spear followed by 116 bbls of 180*F diesel down Tbg for brush&flush. FWHP'S=400\1370\460. Valves in following positions upon departure: SV,SSV=S-line. WV=closed. M, IA, OA= OTG. S- line in control of well upon LRS departure. DSO notified. 8/19/2011 ***WELL SHUT-IN UPON ARRIVAL*** (E-LINE SCMT) INTIAL T/I/O= 180/1320/120 PSI RIGGED UP ELINE UNIT&CURRENTLY RUNNING IN W/SCMT LOGGING STRING FINAL T/I/O= 180/1320/120 PSI ***CONTINUED ON 20-AUG-2011*** 8/19/2011 T/I/0=290/1310/120. Temp=SI. T FL(Pre E-Line). No AL. T FL @ 330'(3 bbls). SV,WV=C. SSV, MV=0. IA, OA=OTG. NOVP. 8/20/2011 i***JOB CONTINUED FROM 19-AUG-2011***(E-LINE SCMT- ADPERF) INITIAL T/I/O= 180/1320/120 PSI ;PERFORM SCMT LOGGING PASSES FROM 9196'-8800'. (FIELD PICK TOP OF CEMENT @ 8985') LAY DOWN EQUIPMENT FOR DAY. 'ARRIVE ON LOCATION, RIG UP AND PRESSURE TEST SURFACE EQUIPMENT CURRENTLY RUNNING IN WITH 2"HSD GUN ***CONTINUED ON 21-AUG-2011*** 8/21/2011 ***JOB CONTINUED FROM 20-AUG-2011`**_(E__I _______ ..______ (E-LINNE SCMT-ADPERF) INITIAL T/I/O=295/1320/120 PSI PERFORATED 2'INTERVAL©9188'-9190'W/2"2006 POWER JET HMX GUN (6 SPF, 60 DEG PHASING. ENTRY HOLE DIAMETER=0.23". PENETRATION = 19") FINAL T/I/O=480/1320/120 PSI ***JOB COMPLETE. NOTIFY DSO. LEAVE LOCATION*** i I ` I 8/28/2011 jT/I/O=2500/2170/280. Temp=SI. WHP's(Eval high IAP). No AL. SV,WV=C. SSV, MV=0. IA,OA=OTG. NOVP. i I I ' 8/29/2011 T/I/0=2500/1170/270. Temp=SI. Bleed IA to 1500 psi(Eval high IAP).T FL=below deployment sleeve @ 9201'. IA FL=—700'. Bled IAP to C-39 production to 1400 psi in 1.25 a hrs(gas),IA FL is unchanged. IAP increased 50 psi to 1450 psi during 1 hr. monitor.OAP I decreased to 90 psi during bleed. !FWHP's=2480/1450/90. `WV,SV=C. SSV, MV=O. IA, OA=OTG. NOVP.**Job complete** 8/30/2011.T/I/0=2480/1480/180. Temp=SI. IA FL. (Post IA bleed). No AL. IA FL @ 700'. Tubing pressure unchanged, IAP increased 30 psi, OAP increased 90 psi& IA FL unchanged. I SV,WV=C. SSV, MV=O. IA&OA=OTG. NOVP. ' � I 9/3/2011 ***WELL SHUT IN ON ARRIVAL*** (under eval) DRIFT&TAG DEPLOYMENT SLV W/10'x2.74"DMY WHIPSTOCK @ 9178'SLM. 1***JOB CONTINUED ON 9/4/11*** 1 � I E 9/4/2011 ***JOB CONTINUED FROM 9/3/11*** (profile mod) PREFORMED SBHPS(unable to reach btm stop). GOOD DATA. SET 3-1/2"KEYLESS X CATCHER ON LINER TOP @ 9174'SLM. PULL STA.#1 RK-OGLV FROM 6961'MD/6962'SLM. PULL STA.#2 RK-LGLV FROM 4439'MD/44430'SLM. SET STA.#2 RK-DGLV @ 4439'MD/4430'SLM. ***JOB CONTINUED ON 9/5/11*** f [ 9/5/20111***JOB CONTINUED FROM 9/4/11*** (profile mod) LRS ATTEMPT TO LOAD IA&PRESSURED UP TO 3,000 PSI AFTER 45 BBLS. PULL STA.#2 RK-DGLV @ 4439'MD. LRS STILL IS UNABLE TO PUMP DOWN IA W/GLM#1  OPEN. PULL 3-1/2"KEYLESS X CATCHER FROM 9174'SLM. LRS BEGIN PUMPING DOWN TBG TO THAW ICE PLUG IN IA. ***WELL TURNED OVER TO DSO*** 9/5/2011,T/I/O=2200/2110/300 Temp=SI Assist Slickline, Load IA&Tbg for MIT-IA (Eval high IAP) Pumped 5 bbls neat methanol and 45 bbls crude down IA, pressured up to 3000 psi. IA (appears to be frozen. Bled back— 10 bbls from IA. Slickline pulled DGLV from station#2. Pumped 10 bbls crude down IA and pressured up to 3000 psi. Rig off of IA and onto Tbg. 'Pumped 5 bbls neat methanol,followed by 346 bbls of 180*F crude down Tbg attempting to thaw suspected ice plug in IA.Pumped 272 bbls of 200*F 1%KCI, 17 bbls crude and 5 bbls :neat methanol down Tbg. Rig up to IA.***Continue WSR on 9-6-11*** I ! 9/6/2011 ***Continued WSR from 9-5-11*** Assist Slickline, MIT-IA PASSED to 2000 psi (Eval high 1 IAP) Pumped 5 bbls neat methanol,followed by 75 bbls crude into IA to make sure ice plug was gone. Pumped an additional 112 bbls of 180*F crude into IA.SSL to RIH and set Icatcher,then set DGLV in station#2.Pumped another 313 bbls crude into IA to load.With 1283 bbls pumped into IA,had Pad Op open wing to bleed TP down. Pumped 217 bbls into IA with wing open.SSL to RIH and set DGLV in station#1. Pressured up IA with 28 bbls crude. IAP fell off rapidly after shutting down pump. SSL to RIH with LIB found open pocket at station#2.SSL set DGLV in station#2. IA pressured up to 2000 psi with 5.4 bbls crude. IA lost 78 psi in 1st 15 mins and 28 psi in 2nd 15 mins for a total pressure loss of 106 psi in 30 mins. RD from IA flange and PT'd to 4000 psi.***Continue WSR on 9-7-11*** 9/6/20111***WELL SHUT IN ON ARRIVAL*** SET 3 1/2"KEYLESS X-CATCHER @ 9174'SLM SET RK-DGLV IN STA#2 @ 4439'MD, LRS LOADED IA, SET RK-DGLV IN STA#1 @ 6961'MD, LRS UNABLE TO REACH TEST PRESSURE 'TAGGED STA#2 w/1.70"LIB-IMPRESSION OF OPEN POCKET RECOVER STA#2 RK-DGLV FROM CATCHER @ 9174'SLM. !SET STA#2 RK-DGLV IN STA#2 @ 4439'MD. I LRS MIT-IA TO 2,000 PSI (pass). E 1 PULL 3-1/2"KEYLESS X-CATCHER FROM 9174'SLM. l***JOB CONTINUED ON 9/7/11*** 9/7/2011 ***Continued WSR from 9-6-11*** Assist Slickline set special liner top packer with orifice 1(Eval high IAP) Pumped 5 bbls neat methanol and 26 bbls crude down Tbg to flush water land help set packer orifice. Freeze Protect flow line with 10 bbls neat methanol and 96 bbls 'crude(WOA procedure). FWHP's= 150/60/-0 . SV,WV, SSV-closed. MV, IA, OA-open. 9/7/2011***JOB CONTINUED FROM 9/06/11*** (profile mod) SET 3-1/2"BAKER SPECIAL LINER TOP PACKER W/ORIFICE @ 9186'SLM ;SET 3-1/2"KEYLESS X-CATCHER @ 9149'SLM MADE 1 ATTEMPT TO PULL RK-DGLV FROM STA#2 ***CONT. ON 09/08/11 WSR*** t � f [ 9/8/2011 ***CONT. FROM 09/07/11 WSR***(prof mod) PULLED RK-DGLV FROM ST#1 @ 6959'SLM/6961'MD 'PULLED RK-DGLV FROM ST#2 @ 4429'SLM/4439'MD SET RK-LGLV IN ST#2 @ 4429'SLM/4439'MD !SET RK-OGLV IN ST#1 @ 6959'SLM/6961'MD PULLED EMPTY 3-1/2"KEYLESS X-CATCHER ***WELL LEFT SHUT IN, DSO NOTIFIED*** FLUIDS PUMPED BBLS 35 NEAT METH 272 1%KCL 5 METH 1013 CRUDE 124 DIESEL 1449 TOTAL TREE= CM/ SAFETY N is WELL ANGLE>70°@ 9840'. WELLHEAD= FMC ACTUATOR C 3 7 ACTUATTOR R _ = BAKER C S ***ORIG W���&C-37A NOT SHOWN BELOW KB.ELEV= 67.E WHIPSTOCK*** BE. ELEV= 32' I KOP= 2050' 20"CONDUCTOR, 110' Max Angle= 99°© 10666' X - I 2106' H 3-1/2"OTIS SSSVN,ID=2.750" I Datum MD= 9624' 91.5#,H-40, Datum TVD= 8800'SS ID=19.124" ' GAS LIFT MANDRELS 9-5/8"CSG,47#,NT-80 BUTT, ID=8.681" —{ 1891' ST MD ND DEV TYPE VLV LATCH PORT DATE 2 4439 4270 24 CA DOME RK 16 09/08/11 13-3/8"CSG,68#, L-80 BTC, ID=12.415" --I 3328' x 1 6961 6567 24 CA SO RK 20 09/08/11 9-5/8"CSG,53.5#,NT-80 BUTT, ID=8.535" --I 6864' Minimum ID = 1.78" @ 9208' • I 8893' H9-5/8"X 7"TIW LTPw/LNR HANGER I LINER WIPER PLUG IN DEPLOY SLV I I (0c-'e' 8/2C Pt 1► I 9045' 'HEST TOC(09/10/10)I SG 4I 4 9-5/8"LNR,47#, NT-80 BUTT, ID=8.681" -I 9053' �•� �� Ilk /•1 '- 9181' H3-1/2"BKR KB LTP w/ORIFICE SUB, ID=1.81" TOP OF 2-318"LNR 9201' �y• 9201' 1-12.70"DEPLOYMENT SLV, ID=2.250" 1,1s _it 9212' I—I2-3/8"PUP JOINT,ID=1.920" I 12 0 NO 3-1/2"WHIPSTOCK(08/19/10) -I 9558' 011♦ •�4 3-1/2"TBG,9.2#,L-80 TDS, .0087 bpf, ID=2.992" -I —9863 I �•• X404 7"LNR,29#,NT-80 NSCC, .0371 bpf,ID=6.184" —I —9563 11 y 1 ..1A ► i, 1 v,,,,y, ,,A ,',.;.:i.11 j� v` MILLOUT WINDOW(C-3713) 9558'-9563' PERFORATION SUMMARY REF LOG:SLB MCNL/GR/CCL ON 09/10/10 I ANGLE AT TOP PERF:35°@ 9188' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9188-9190 0 08/21/11 I 1.56" 6 10040- 10170 0 09/11/10 1.56" 6 10240- 10380 0 09/11/10 1.56" 6 10460- 10490 0 09/11/10 I 1.56" 6 10570- 10600 0 09/11/10 1.56" 6 10650- 10830 0 09/11/10 I 1.56" 6 11000- 11140 0 09/11/10 1.56" 6 11230- 11260 0 09/11/10 I 1.56" 6 11310- 11570 0 09/11/10 I I PBTD --I 11586' I -♦�♦4' •2-3/8"LNR,4.7#,L-80 STL, .0039 bpf,ID=1.995" -I 11625' I ♦♦♦� DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/03/93 D9 SUSPENDED COM PLETION 04/03/11 PJC DRLG DRAFT CORRECTIONS WELL: C-37B 09/06/93 D16 ORIGINAL COM PLETION 05/16/11 AK/PJC FINAL DRLG CORRECTIONS PERMIT No:1101000 09/16/01 NORDICI CTD SIDETRACK(C-37A) 08/28/11 JCM/PJC ADPERF(08/21/11) API No: 50-029-22360-02 09/11/10 NORDIC1 CTD SIDETRACK(C-37B) 09/20/11 RCT/PJC SET LTP&GLV C/O(09/07-08/11) SEC 19,T11 N,R14E, 1110'FNL&879'FEL 09/19/10 PJC DRLG DRAFT CORRECTIONS 09/21/11 BSE/PJC LTP MIN ID CORRECTION 09/19/10 MSS/PJC GLV C/O(09/18/10) BP Exploration(Alaska) ti! ERABLE: Producer C-37B (PTD # 1 01000) Tubing Integrity Restored Page 1 of 2 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWeIllntegrityCoordinator @bp.com] '1 q q/7'l Sent: Wednesday, September 07, 2011 1:57 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS GC3&PCC OSM; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, OPS Prod Controllers; Glasheen, Brian P Cc: Walker, Greg (D&C) Subject: OPERABLE: Producer C-37B (PTD#2101000)Tubing Integrity Restored All, Producer C-37B (PTD#2101000) passed an MIT-IA on 09/06/2011 after dummy gas lift valves were set. The passing test proves two competent barriers in the wellbore and the well is reclassified as Operable. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIllntegrityCoordinator @BP.com From: AK, D&C Well Integrity Coordinator Sent: Tuesday,August 30,2011 2:27 PM To: 'Regg,James B(DOA)';'Maunder,Thomas E(DOA)'; 'Schwartz,Guy L(DOA)';AK,OPS GC3&PCC OSM;AK,OPS GC3 Facility&Field OTL;AK,OPS GC3 Wellpad Lead;Cismoski,Doug A; Daniel, Ryan;AK,D&C Wireline Operations Team Lead;AK,D&C Well Services Operations Team Lead;AK,RES GPB West Wells Opt Engr;AK,RES GPB East Wells Opt Engr;AK,OPS Prod Controllers;Glasheen,Brian P Cc: AK,D&C Well Integrity Coordinator; King,Whitney;Walker,Greg(D&C) Subject: UNDER EVALUATION: Producer C-37B(PTD#2101000)Sustained IA Pressure Above MOASP All, Producer C-37B (PTD#2101000) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing/IA/OA equal to 400/2080/200 on 08/28/2011. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. Plan forward: 1. Slickline: Dummy gas lift valves 2. Fullbore: MIT-IA to 3000 psi xp , A TIO plot and wellbore schematic have been included for reference. /tb}Nce << File: Producer C-37B (PTD#2101000) TIO Plot.doc>> Please call if you have any questions or concerns. 9/7/2011 4 C2 ERABLE: Producer C-37B (PTD #'''01000) Tubing Integrity Restored Page 2 of 2 Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager(907) 659-5100 Ext. 1154 9/7/2011 • < 0 < ooc -210000 • C _n, CO •a • • • • • • • • •r •T • •0 • • • • • • • • •C) I ti C') 6 • CO CO LIO O O O M N M CV r CN U ° a M p o • pp c TREE_' CM/ SAFETY S: WELL ANGLE>70°@ 9840'. WELLHEAD= FMC C B ACTUATOR= BAKER C C -3 7 B W HI STOCKL&C-37A NOT SHOWN BELOW KB.ELEV= 67.7' , BF.ELEV= 32' KOP= 2050' Max Angle= 99'@ 10666' 20"CONDUCTOR, 110' 2106' J3-1/2"OTIS SSSVN,ID=2.750" Datum MD= 9624' 91.5#,H-40, Datum TVD= 8800'SS ID=19.124" GAS LIFT MANDRELS 9-5/8"CSG,47#,NT-80 BUTT, ID=8.681" —I 1891' ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 4439 4270 24 CA DOME RK 16 09/18/10 13-3/8"CSG,68#.L-80 BTC,ID=12.415" —1 3328' 1 6961 6567 24 CA SO RK 20 _09/18/10 9-5/8"CSG,53.5#,NT-80 BUTT, ID=8.535" --I 6864' IV Minimum ID = 1.78" @ 9208' I II 8893' I-19-5/8"X 7"TIW LIP w/LNR HANGER I LINER WIPER PLUG IN DEPLOY SLV V ,' 9045' I—i EST TOC(09/10/14) 9-5/8"LNR,47#, NT-80 BUTT, ID=8.681" —I 9053' A 11 • 1 `h_ 11 �'TOP OF 2-3/8"1LNR I--I 9201' IN 9201' �J-12.70"DEPLOYMENT SLV, ID=2.250" , UN A 9212' 1-12-3/8"PUP JOINT,ID=1.920" I 3-1/2"WHIPSTOCK(08/19/10) —I 9558' 141. ∎,,j 3-1/2"TBG,9.2#,L-80 TDS, .0087 bpf, ID=2.992" -I —9863 I� •�•v 4,∎ 7"LNR,29#. NT-80 NSCC. .0371 bpf, ID=6.184" —9563 1:1; j���el �►� ',# MILLOUT WINDOW(C-37B) 9558'-9563' PERFORATION SUMMARY REF LOG:SLB MCNL/GR/CCL ON 09/10/10 I ANGLE AT TOP PERF:90°@ 10040' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 6 10040-10170 0 09/11/10 I 1.56" 6 10240- 10380 0 09/11/10 1.56" 6 10460- 10490 0 09/11/10 I 1.56" 6 10570- 10600 0 09/11/10 1.56" 6 10650- 10830 0 09/11/10 1.56" 6 11000- 11140 0 09/11/10 I 1.56" 6 11230- 11260 0 09/11/10 1.56" 6 11310-11570 0 09/11/10 I I I PBTD —I 11586' 1 414 2-3/8"LNR,4.7#,L-80 STL,.0039 bpf, ID=1.995" -1 11625' I ∎'•'4 DATE REV BY COMMENTS - DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/03/93 D9 SUSPENDED COM PLETION 04/03/11 PJC DRLG DRAFT CORRECTIONS WELL: C-37B 09/06/93 D16 ORIGINAL COM PLETION 05/16/11 AK/PJC FINAL DRLG CORRECTIONS PERMIT No:*2101000 09/16/01 NORDICI CTD SIDETRACK(C-37A) API No: 50-029-22360-02 09/11/10 NORDICI CTD SIDETRACK(C-37B) SEC 19,T11 N,R14E, 1110'FNL&879'FEL 09/19/10 PJC DRLG DRAFT CORRECTIONS 09/19/10 MSS/PJC GLV 0/0(09/18/10) BP Exploration(Alaska) bp BP Exploration(Alaska)Inc. Attn:Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage,Alaska 99519-6612 August 22, 2011 RECEIV p AUG 31 2011 Mr. Tom Maunder Mirka Off&Gas Cron.Gom isstop Alaska Oil and Gas Conservation Commission 333 West 7th Avenue QfC13rt Anchorage, Alaska 99501 a(0 r 100 Subject: Corrosion Inhibitor Treatments of GPB C-Pad n _ 37B Dear Mr. Maunder, lJ / Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator i BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) C-Pad 7/19/11 Corrosion Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# API# Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C-01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C-02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C-03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C-048 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C-05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C-06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C-07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C-08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C-09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C-10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C-11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C-12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C-13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C-15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C-16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C-178 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C-188 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C-198 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C-20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C-21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C-22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C-23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C-24A 2040580 500292081601 Sealed NA NA NA NA NA C-25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C-26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C-27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C-28B 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C-29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C-30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C-31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C-32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C-33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C-34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C-358 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C-36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C-378 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C-38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C-39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 NA C-41A 2041880 500292238501 Sealed NA NA NA NA C-42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 id" BAKER HUGHES www bakerhughes.com West g s 795 East 94l^Avenue Anchorage,AK 99515 Tel: 907-267-6612 1,442 Fax: 907-267-6623• July 7, 2011 Attention: Christine Mahnken State of Alaska-AOGCC 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Subject: Final Log Distribution—BP Exploration (Alaska), Inc. C-37B Prudhoe Bay Unit North Slope Borough,AK API#: 50-029-22360-02 Rig: Nordic-1 SO#: 3317848 Please find enclosed the following final deliverables for the above well: a< Set of Color Prints (to follow) 1 Data CD We sincerely appreciate the opportunity to provide our products and services to you and look forward to working with you in the future. Should you have any questions, you can contact me at(907) 267-3420. Regards, Jim Woods Geoscience Advisor Enclosures JW/dh bp Date 01-08-2011 0 Transmittal Number:93175 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 13-21A a,0 -Oa O 35(O3' 05-08A 9t0-06-5 c9O(oc C-37B 910-COO ao(o3Co 18-10CPB1 9/0-1/07 2060'5- 18-10C l O-t i 3 3 0 a 0 �2E5- X-19BL2PB1 -to aotoaa G-29B @ID- IqI 00Gocg / X-19BL2 a to- lo3 avloa b X-19BL2-01 atv-104-e &v GQ K-11A ,a/U-/23 c9 OloA3 B-04APB1 �'O-c�'}5 gOC°!9 04-22AL1 avo- /5t! c9000D B-04A 9;0-0 c 1 6 Qc■tgi41 Please S.ty. . d Return one copy of this transmittal. Thank You, Doug Dortch Petrotechnical Data Center s 40C-Cg. Attn: C is O.kr-rtvi-1V-€,- 550 West 7th Avenue, Suite 802 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E.Benson Blvd. PO Box 196612 Anchorage,AK 99519-6612 a N E E o U ?et; {r o um Nm mmom cc, Y l c a co o Oil N L m<W A m a Q��C m 112 2t -3.2 o U 0 o v n sagA2 02M I Mme'.�,!/ ,...0 T - t W m m w a" a E `o � O o u '•°q •I4'4' 4 t 0 N U 2 U , I , 4. , " I. a N a m 00000000000000 R 3 a n o o a 3 a s m v W N N N N e N N O O N O o morn a m�oom OOOa 0 0 0 o o o 0 0 o 8 1- 6 i �W O g Q� Q� w 0 4:)‘ 00.0■0740.74T B� ! z ® z o o w - a N J J J 2 r o m r z z z z m m o U m o a N N N N 2 2 2 2 N N N N W N z ....�f f�S'K O'K KR 2 Oamn-nmmrn..,.ow 2 L. O O Qq pO 0,—0 0 0 0 0 0 0 N, .a 4 R $Q 0 0 0 0 0 0 0 0 0 > `+ W n NNN Nm QQ=MR'mNtlK m mccOMa33vumun m a mmmmmaammmmmmm Z U CTI •- .4 N C+W W C W I C e ¢gq U YN W N W N N n m a D m 33'617. °9,,-9,40 y J J J 3 J▪0 0 J W y o D a Q W m Y O l O , c` gill 00 a W W J( E N lt m Y L Z 6T-Li a dF J a y§ama °ten. `V CO v. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ®Oil ❑Gas ❑SPLUG ❑Other ❑Abandoned ❑Suspended lb. Well Class: 20MC 25.105 20AAC 25.110 ® Development ❑Exploratory ❑GINJ ❑WINJ ❑WAG ❑WDSPL ❑Other No.of Completions One ❑ Service ❑Stratigraphic 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska)Inc. 9/12/2010 210-100 3. Address: 6.Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 9/6/2010 50-029-22360-02-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 9/9/2010 PBU C-37B 1110'FNL, 879' FEL, SEC 19,T11 N, R14E, UM 8. KB(ft above MSL): 67.70 15.Field/Pool(s): Top of Productive Horizon: 1028'FSL, 1723'FWL, SEC 17,T11 N, R14E, UM GL(ft above MSL): 32.7 Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD): Oil Pool 2469'FSL,2672'FWL, SEC 17,T11 N, R14E, UM 11586' 8993' 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 664495 y- 5960111 Zone- ASP4 11625' ✓ 8992' ADL 028305 TPI: x- 667041 y- 5962306 Zone- ASP4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth:x- 667953 y- 5963769 Zone- ASP4 N/A 18.Directional Survey: ®Yes ❑No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD, DIR, Memory CNL/GR/CCL, GR/ROP/Res 9558' 8817' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM To BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 32' 110' 32' 110' 30" -260 sx Arctic Set 13-3/8" 68# L-80 35' 3328' 35' 3250' 16" 1097 sx PF'E'.420 sx Class'G' 9-5/8" 47#/53.5# NT-80/L-Bo 32' 9053' 32' 8437' 12-1/4" 665 sx Class'G' 7" 29# NT-80 8885' 9558' 8289' 8817' 8-1/2" 330 sx Class'G' 2-3/8" 4.7# L-80 9201' 11625' 8565' 8992' 3" 53 sx Class'G' V 24. Open to production or injection? IN Yes ❑No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD) (MD+TVD of Top&Bottom;Perforation Size and Number): 1.56"Gun Diameter,6 SPF 3-1/2",9.3#, L-80 9558' MD ND MD ND 10040'-10170' 9026'-9024' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 10240'-10380' 9021'-9020' 10460'-10490' 9021'-9023' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 10570'-10600' 9026'-9025' .t.,}yi'j,= (I)j` 2500' Freeze Protected with Diesel 10650'-10830' 9020'-9016' I n 11 11000'-11140' 9010'-9007' 11230'-11260' 9006'-9006' 11310'-11570' 9006'-8994' r G F,/ 9 t 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,Gas Lift,etc.): September 28,2010 Flowing Date of Test: Hours Tested: Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 9/22/2010 12 Test Period 4 371 532 0 128 1436 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 200 1500 24-Hour Rate ♦ 741 1064 0 28. CORE DATA Conventional Core(s)Acquired? ❑Yes ®No Sidewall Core(s)Acquired? ❑Yes 0 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 anal I I AAC 250.071. RE None NOV 2 4 2010 RBDMS NOV 26 at . skis ; &Gas cots.G atOsors Form 10-407 Revised 12/2009 CONTINUED ON REVERSE . . go Submit Original Only V-t- 1-is-4 � ��� G 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well Tested? Q ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. 22TS 9600' 8848' None 21 TS/Zone 2A 9660' 8898' Zone 1B 9753' 8974' Zone 1A/TDF 9823' 9014' MHO/HOT 9870' 9028' Formation at Total Depth(Name): Zone lA 11625' 8992' 31.List of Attachments: Summary of Daily Drilling Reports,Well work summary,Well Schematic Diagram and Surveys. 32.I hereby certify that the foregoing is true and corre to the best of my knowledge. Signed: Son. a Stewma j` ` Title: Drilling Technologist Date: 1 1 7 PBU C-37B 210-100 Prepared By Name/Number. Sondra Stewman,564-4750 Well Number Permit No./Approval No. Drilling Engineer: Amanda Suddreth, 564-5543 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: 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 ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: 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. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only TREE= CIW WELLHEAD= FMC � SSAFE 1TES: WELL ANGLE>70°@ 9840'. ACTUATOR= BAKER C „IMO - ***ORIG WELL&C-37A NOT SHOWN BELOW KB.ELEV = 67.7' WHIPSTOCK*** BF.ELEV= 32' KOP= 2050' Li Max Angle= 99°@ 10666' 2106' H3-1/2"OTIS SSSVN,ID=2.750" Datum MD= 9624' 0 Datum TVD= 8800'SS GAS LIFT MANDRELS 20"CONDUCTOR,91.5#, H-40, ID=19.124" 110' ST MD TV D DEV TYPE VLV LATCH PORT DATE 2 4439 4270 24 CA DOME RK 16 09/18/10 13-3/8"CSG,68#, L-80 BTC, ID=12.415" H 3328' 1 6961 6566 24 CA SO RK 20 09/18/10 8893' H9-5/8"X 7"TM/LTP w/TIEBACK SLV, ID=" 1 Minimum ID = ?" © ?' `7 I I 8903' H9-5/8"X 7"TIW LNR HGR, ID=? I t•� 1 ,1 9045' H EST TOC(09/10/10) 9-5/8"LNR,47#, NT-80, ID=8.681" —I 9053' I--J X11 A r. Ili 1 04 TOP OF 2-3/8"LNR H 9201' ,�, �' 9201' 1--12.70"DEPLOYMENT SLV, ID=2.250" I I 'i1 111'4 A 111o� 1114 MILLOUT WINDOW(C-37B) 9558'-9563' 114 144 01 3-1/2"TBG, 9.3#,L-80 TDS, .0087 bpf, ID=2.992" 9558' bk. 111.E 1:4 ,1� 9558' —I3-1/2"WHIPSTOCK(08/19/10) I 7"LNR,26 4, NT-80 NSCC, .0371 bpf, ID=6.184" 9559' ' 1 �0 9600' 3.1,'2"E7S r f07 21 c:: 'slip i 9872' H TUBING PUNCH(07/28/10) I ��� 0°. 9885' H ,2"HES C122(07/2c 10) I PBTD I—i 11586' 1 ' 1 \ 111111. *0 2-3/8"LNR,4.7#,L-80 STL, .0039 bpf, ID=1.995" J—I 11625' I ill U _. PERFORATION SUMMARY REF LOG:SLB MCNL/GR/CCL ON 09/10/10 ANGLE AT TOP PERF:90°@ 10040' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 6 10040- 10170 0 09/11/10 1.56" 6 10240- 10380 0 09/11/10 1.56" 6 10460- 10490 0 09/11/10 El 1.56" 6 10570- 10600 0 09/11/10 1.56" 6 10650- 10830 0 09/11/10 4 1.56" 6 11000- 11140 0 09/11/10 1.56" 6 11230- 11260 0 09/11/10 1.56" 6 11310- 11570 0 09/11/10 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/03//93 ORIGINAL COMPLETION 10/05/10 ?/JMD DRLG DRAFT CORRECTIONS WELL: C-37B 09106193 RWO PERMIT No: 2101000 09/16/01 NORDIC1 CTD SIDETRACK(C-37A) API No: 50-029-22360-02-00 09/11/10 NORDICI CTD SIDETRACK(C-37B) SEC 19,T11 N, R14E, 1110'FNL&879'FEL 09/19/10 PJC DRLG DRAFT CORRECTIONS 09/19/10_MSS/PJC GLV C/O(09/18/10) BP Exploration(Alaska) North America -ALASKA- BP Page 1 of 1 Operation Summary Report Common Well Name:C-37 AFE No Event Type:MOBILIZATION(MOB) Start Date:9/4/2010 End Date: X3-00WFH-C(845,271.00) Project:Prudhoe Bay Site: PB C Pad Rig Name/No.:NORDIC 1 Spud Date/Time:10/30/1993 12:00:00AM Rig Release:9/12/2010 Rig Contractor:NORDIC CALISTA UWI:500292236000 Active Datum:45:37 5/8/1993 00:00 @67.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/4/2010 00:00 - 02:00 2.00 RIGU P PRE ACCEPT RIG AT 00:00.CHECK AND ZERO SLB WEIGHT INDICATOR.SET INJECTOR ASIDE. FINISH NU BOPE. 02:00 - 04:00 2.00 RIGU P PRE PICKUP BHI TOOLS. INSTALL FLOW CROSS. 04:00 - 10:30 6.50 BOPSUR P PRE BOPE SHELL TEST.GREASE ALL VALVES ON BOP.PERFORM ANNUAL HIGH PRESSURE TEST ON KILL AND CHOKE HOSES,MUD t61 MANIFOLD TO 5000 PSLPVT=290 BBLS 10:30 - 21:00 10.50 BOPSUR P PRE BOPE TEST WITH AOGCC JEFF JONES WITNESS.PVT=284BBLS 21:00 - 21:30 0.50 RIGU P PRE PULL TWC. Printed 10/14/2010 12:27:26PM North America -ALASKA- BP Page 1 of 5 Operation Summary Report Common Well Name: C-37 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 9/5/2010 End Date: X3-00WFH-C(949,550.00) Project:Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 I Spud Date/Time: 10/30/1993 12:00:00AM Rig Release:9/12/2010 Rig Contractor:NORDIC CALISTA UWI:500292236000 Active Datum:45:37 5/8/199.3. 00:00 @67.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/4/2010 21:30 - 22:40 1.17 STWHIP P WEXIT PU INJECTOR AND FILL COIL WITH 40 BBLS MUD. 22:40 - 23:40 1.00 STWHIP P WEXIT PRESURE TEST INNER REEL HARDLINES TO 4,000 PSI. 23:40 - 00:00 0.33 STWHIP P WEXIT INNER REEL VALVE AND PACK OFF TEST. PVT=232BBLS. 9/5/2010 00:00 - 03:00 3.00 STWHIP P WEXIT OPEN INNER REEL VALVE AND CIRCULATE FOR SLACK MANAGEMENT.POP OFF AND CHECK FOR WIRE.RIG UP COIL CUTTER TO INJECTOR.CUT 300'OF COIL TUBING.MU CTC.PULL TEST AND PRESSURE TEST CTC, OK.MU STINGER AND NOZZLE THEN PUMP WIRE FORWARD.RECOVER THE WIRE FROM STINGER.MAKE UP BHI TO UQC AND PRESSURE TEST TO 4000 PSI,OK. 03:00 - 04:15 1.25 STWHIP P WEXIT MU 2.74"FAT RADIUS WINDOW MILL ASSEMBLY WITH 2.5 DEG MOTOR.PU AND STAB ON INJECTOR. 04:15 - 04:40 0.42 STWHIP P WEXIT RIH WITH MILLING ASSEMBLY. 04:40 - 05:00 0.33 STWHIP N SFAL WEXIT TROUBLE SHOOT PROBLEM WITH STRIPPER LUBE.REPLACE HASKEL PUMP FOR STRIPPER. 05:00 - 07:00 2.00 RIGU P WEXIT CONTINUE TO RIH.TAG UP ON GLM AT 4458'. WORK PAST WITH LOW SIDE TOOLFACE. CONTINUE INTO 9040'MD. 07:00 - 08:15 1.25 STWHIP P WEXIT RUN TIE-IN LOG TO 9150'MD.CORRCTION P4j� +6.5'. 08:15 - 08:45 0.50 STWHIP P WEXIT CONTINUE TO RIH.TAG UPON WHIPSTOCK 1 AT 9557.8'. 08:45 - 09:15 0.50 STWHIP P WEXIT DISPLACE WELL OVER TO 8.5 PPG QUIKDRIL. 09:15 - 12:00 2.75 STWHIP P WEXIT MILL 2.74"WINDOW FROM 9558'.PUMP AT 1.7 BPM WITH 2400 PSI OFF BOTTOM,2790 PSI ON BOTTOM.WOB 1K-4K.TIME MILL 0.1' EVERY 9 MINUTES. 12:00 - 16:10 4.17 STWHIP P WEXIT MILL WINDOW FROM 9559.5'. PU 1'. PU WT 11115 21K. RESUME TIME MILL @ 0.1'EVERY 9 MINUTES. 16:10 - 17:00 0.83 STWHIP P WEXIT INCREASE ROP TO 0.1'EVERY 6 MINUTES. APPROXIMATELY 3'INTO WINDOW. 17:00 - 17:50 0.83 STWHIP P WEXIT STALLED @ 9562.7'. PU 1'. CONTINUE TIME MILLING @ 0.1'EVERY 6 MINUTES. 17:50 - 18:45 0.92 STWHIP P WEXIT ERATIC MILLING,POSSIBLE CENTER OF 7" AT 9563.3' 18:45 - 19:10 0.42 STWHIP P WEXIT MILLED THROUGH 7"AT 9563.4'. BOTTOMS UP 60%METAL 40%CEMENT. 19:10 - 21:30 2.33 STWHIP P WEXIT SAMPLE SHOWS MILLING FORMATION. TIME DRILL PAST BIT TO BEND 2.31'. 21:30 - 22:10 0.67 STWHIP P WEXIT 3K WOB AT 9565.5'NO MOTOR WORK,THICK WEAR PAD ON MOTOR HANGING UP ON WS. PU 1'AND RUN BACK IN. UP WT 28K. WORKED PAST LIP AND BACK TO DRILLING FORMATION. 22:10 - 22:45 0.58 STWHIP P WEXIT MILLING AT 9569'WOB=4.1K AND 173 PSI MOTOR WORK.CIRCULATING PRESSURE 2721 PSI. Printed 10/14/2010 12:16:35PM North America -ALASKA- BP Page 2 of 5 Operation Summary Report Common Well Name:C-37 I AFE No Event Type:RE-ENTER-ONSHORE(RON) 1-Start Date: 9/5/2010 End Date: X3-00WFH-C(949,550.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 10/30/1993 12:00:00AM Rig Release:9/12/2010 Rig Contractor:NORDIC CALISTA UWI:500292236000 Active Datum:45:37 5/8/1993 00:00©67.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:45 - 00:00 1.25 STWHIP P WEXIT MILLING AT 9570.7'WOB=4.3 AND 511 PSI MOTOR WORK.CIRCULATING PRESSURE 3021 PSI.AT 9573.4 PICK UP CLEAN THROUGH WINDOW.RAN A TIE IN LOG AND PAINTED A TIE IN FLAG WITH EOP AT 9095'. 9/6/2010 00:00 - 00:30 0.50 STWHIP P WEXIT POOH TO TIE IN @ 9136. 00:30 - 01:00 0.50 STWHIP P WEXIT PIANT FLAG @ 9095'EOP. 01:00 - 02:45 1.75 STWHIP P WEXIT TAG UP AND FLOW CHECK. 02:45 - 03:15 0.50 STWHIP P WEXIT LID MILL 2.74'NOGO. 103:15 - 03:30 0.25 STWHIP P WEXIT MU CRAYOLA MILL AND WEATHERFORD MOTOR.NOGO ON MILL IS 2.74". 03:30 - 05:30 2.00 STWHIP P WEXIT STAB INJECTOR ON WELL. RIH.PUMPING MIN RATE. 05:30 - 10:30 5.00 STWHIP P WEXIT TIE IN WI 6.5'CORRECTION.PAINT FLAG WAS RIGHT ON DEPTH.TRIED TO DRY DRIFT TAGGED AT 9561'.PICKED UP 10'BEGAN MILLING 1.0 FPM. 18K DOWN WT.28.5K UP WT.PUMPS AT 2375 PSI AND 1.51 BPM. TWO STALLS AT 9558'.CONTINUE TO REAM TO 9566'.BACKREAM THROUGH WINDOW. WORK DOWN THROUGH WINDOW WITH MINIMAL PUMP TO PREVENT PLUGGING OFF BHA.DECIDE TO ORIENT 30 DEGREES LEFT AND BACKREAM THROUGH WINDOW. WORK BACK DOWN THROUGH WINDOW WITH MINIMAL PUMPS.ORIENT BACK TO ORIGINAL ORIENTATION PLUS 30 DEGREES RIGHT AND BACKREAM THROUGH WINDOW. SHUT PUMPS DOWN AND WORK BOTH WAYS THROUGH WINDOW WITH NO PROBLEMS. 10:30 - 12:30 2.00 STWHIP P WEXIT OPEN EDC AND POOH. 12:30 - 13:30 1.00 STWHIP P WEXIT BREAK OUT AND LAY DOWN DRESS OFF BHA #2.CRAYOLA MILL 2.74",2.73 NO-GO.LAY DOWN MILL AND MOTOR. 13:30 - 14:30 1.00 DRILL P PROD1 MU BUILD DRILLING BHA.SAME BHA JUST CHANGE TO HYC BICENTER BIT AND BHI EXTREME 2.1 MOTOR.BHA#3. 14:30 - 16:00 1.50 DRILL P PROD1 RIH WITH BHA#3. 16:00 - 16:15 0.25 DRILL P PROD1 TIE IN LOG WITH+7'CORRECTION. 16:15 - 18:30 2.25 DRILL P PROD1 CLEAN TROUGH WINDOW. DRILLING AHEAD 1.6 BPM,2600 PSI, ECD 9.9, PVT 290BBL 18:30 - 18:45 0.25 DRILL P PROD1 WIPER TRIP TO WINDOW FROM 9700'. -1 6 18:45 - 21:30 2.75 DRILL P PROD1 9700'ROP=78FPH, IN RATE 1.56,CIRC PRESS 2780,PVT=292BBL, IN DEN 8.51,OUT DEN 8.57, ECD=9.97,UP WT 27K,DOWN WT 14.5K, FS 2400 PSI 21:30 - 22:00 0.50 DRILL P PROD1 WIPER TO WINDOW FROM 9850'.BLED OA FROM 450 DOWN TO 0. 22:00 - 00:00 2.00 DRILL P PROD1 9850'ROP=12FPH, IN RATE 1.56,CIRC PRESS 2800,PVT=287BBL, IN DEN 8.51,OUT DEN 8.57, ECD=9.99,UP WT 27.5K,DOWN WT 15K, FS 2400 PSI. 9/7/2010 00:00 - 00:20 0.33 DRILL P PROD1 CONTINUE DRILLING AHEAD at 9900'. 00:20 - 02:40 2.33 DRILL P PROD1 WIPER TRIP TO WINDOW FROM 9910'.OPEN EDC AND JET FULL RATE WHILE P001-1. Printed 10/14/2010 12:16:35PM North America -ALASKA- BP Page 3 of 5 Operation Summary Report Common Well Name: C-37 1 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:9/5/2010 End Date: X3-00WFH-C(949,550.00) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 10/30/1993 12:00:00AM Rig Release:9/12/2010 Rig Contractor:NORDIC CALISTA UWI:500292236000 Active Datum:45:37 5/8/1993 00:00 @67.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ft) 02:40 - 03:00 0.33 DRILL P PROD1 LAY DOWN BUILD BHA#3(HYC BIT AND 2.1 BENT MOTOR). 03:00 - 03:20 0.33 DRILL P PROD1 PICK UP LATERAL BHA#4(HUGES BIT AND 1.1 BENT MOTOR. 03:20 - 05:45 2.42 DRILL P -_ PROD1 STAB ON INJECTOR AND RIH.TIE IN TO RA TAG+7FT. 05:45 - 07:00 1.25 DRILL P ■- PROD1 ON BOTTOM DRILLING AT 9910'. FS 2300, 1.49BPM,8.51 PPG,PVT 2 283.. DRILL TO 10050FT. 07:00 - 07:40 0.67 DRILL P PROD1 WIPER TO THE WINDOW&TO TD-CLEAN BOTH WAYS. 07:40 - 09:20 1.67 DRILL P -_ PROD1 DRILL FROM 10050FT.FS 2300, 1.49BPM, 8.51 PPG,PVT 283.DRILL TO 10200FT. 09:20 - 10:20 1.00 DRILL P - PROD1 WIPER TO THE WINDOW&TO TD-CLEAN BOTH WAYS. 10:20 - 12:20 2.00 DRILL P - PROD1 DRILL FROM 10200FT.FS 2300, 1.49BPM, 8.51 PPG,PVT 283.DRILL TO 10350FT. 12:20 - 13:35 1.25 DRILL P -_ PROD1 WIPER TO THE WINDOW&TO TD-CLEAN BOTH WAYS.TIE-IN,+2FT. 13:35 - 15:30 1.92 DRILL P - PROD1 DRILL FROM 10350FT.FS 2300, 1.49BPM, 8.51 PPG,PVT 283. DRILL TO 10490FT. 15:30 - 16:50 1.33 DRILL P -_ PROD1 WIPER TO THE WINDOW&TO TD-WORK DOWN THRU 10481 FT TO TD. 16:50 - 17:50 1.00 DRILL P PROD1 DRILL LATERAL 60L-90R TF FROM 10490FT USING 8.6PPG QUICKDRILL AT 1.63 BPM,2715 PSI FS,110-175 PSI MW,130-160 FT/HR ROP, 2-3K WOB,10.2PPG ECD,PVT=261 17:50 - 18:15 0.42 DRILL P - PROD1 WIPER TRIP THROUGH SHALES FROM 10,592' TO 10,340'. RUN BACK IN HOLE. 18:15 - 18:50 0.58 DRILL P PROD1 DIRECTIONALLY DRILL LATERAL 5OR TF FROM 10490FT USING 8.6PPG QUICKDRILL AT 1.63 BPM,2790 PSI FS,110-175 PSI MW, 130-160 FT/HR ROP,2-3K WOB,10.2PPG ECD, PVT=256 18:50 - 20:00 1.17 DRILL P PROD1 WIPER TRIP FROM TD TO 9570'AND BACK TO TD AT 10,660'. NO ISSUES ON TRIP BACK DOWN. TRUCKS FOR MUD SWAP ARRIVING ON LOCATION. 20:00 - 20:45 0.75 DRILL P ■- PROD1 DIRECTIONALLY DRILL LATERAL 1.63 BPM, 2900 PSI FS,110-145 PSI MW,110-145 FT/HR ROP,2.1-2.4K WOB,10.2PPG ECD,PVT=253 20:45 - 21:00 0.25 DRILL P ■- PROD1 WIPER TRIP FROM TD TO 10,560'AND BACK TO TD AT 10,715'. WIPE THROUGH 10,650-10,680'SEVERAL TIMES. 21:00 - 21:45 0.75 DRILL P ■- PROD1 DIRECTIONALLY 90-130 PSI MW,175-200-2 0 FT/HR 3200 PSI,90-130 PSI MW,175-200 FT/HR ROP,1.6-1.63K WOB,10.4 PPG ECD,PVT=249 21:45 - 22:15 0.50 DRILL P -_ PROD1 WIPER TRIP TO 9570'. CONDUCT TIE-IN,TRIP BACK IN TO TD. +8'CORRECTION ON TIE-IN. 22:15 - 23:15 1.00 DRILL P -_ PROD1 RIH TO 10,771' BEGIN ISOLATING PITS FOR FLUID SWAP. 23:15 - 23:45 0.50 DRILL P PROD1 DIRECTIONALLY DRILL LATERAL WHILE CONDUCTING MUD SWAP TO SAME QUICKDRILL 8.6 PPG MW AT 1.58 BPM,3195 PSI,105 PSI MW,140-180 FT/HR ROP, 1.98-2.72K WOB,10.4 PPG ECD, PVT IN TRANSITION;WORKING WITH PIT 1 AS ACTIVE WHILE CLEANING PITS AND TAKING ON FLUIDS Printed 10/14/2010 12:16:35PM North America -ALASKA- BP Page 4 of 5 Operation Summary Report Common Well Name:C-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:9/5/2010 End Date X3-00WFH-C(949,550.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 1 Spud Date/Time: 10/30/1993 12:00:00AM Rig Release:9/12/2010 Rig Contractor:NORDIC CALISTA UWI:500292236000 Active Datum:45:37 5/8/1993 00:00 @67.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:45 - 00:00 0.25 DRILL P PROD1 WIPER TRIP TO 10,700'. RIH TO TD. 9/8/2010 00:00 - 00:30 0.50 DRILL P PROD1 DIRECTIONALLY DRILL LATERAL WHILE CONDUCTING MUD SWAP TO SAME QUICKDRILL 8.6 PPG MW AT 1.62 BPM,3200 PSI,135 PSI MW,130-140 FT/HR ROP, 2.64-2.72K WOB,10.4 PPG ECD, PVT IN TRANSITION;WORKING WITH PIT 1 AS ACTIVE WHILE CLEANING PITS AND TAKING ON FLUIDS 00:30 - 02:15 1,75 DRILL P PROD1 WIPER TO 10,590'. ATTEMPT TO RIH TO TD. CANNOT MAKE IT PAST 10,580'WITH SEVERAL ATTEMPTS. CONDUCT WIPER TRIP TO 9580'. RIH TO TD WITH NO PROBLEMS. 02:15 - 02:30 0.25 DRILL P PROD1 DIRECTIONALLY DRILL LATERAL WITH QUICKDRILL 8.6 PPG MW AT 1.58 BPM,2920 PSI,135 PSI MW,115-130 FT/HR ROP, 2.54-2.64K WOB,10.1 PPG ECD,PVT 350 BBLS. TOTAL MUD DISPOSED 312 BBLS. 02:30 - 03:45 1.25 DRILL P PROD1 CONDUCT SHORT WIPER TRIP DUE TO WOB, ROP SPIKES. CANNOT GET BACK DOWN TO TD. CONDUCT WIPER TRIP TO 10,000'. RIH TO TD. f/ 03:45 - 04:20 0.58 DRILL P PROD1 DIRECTIONALLY DRILL LATERAL WITH QUICKDRILL 8.6 PPG MW AT 1.59 BPM,2830 PSI,105 PSI MW,60-85 FT/HR ROP,2.08-2.30K WOB,10.2PPG ECD,PVT 343 BBLS. STACKING OUT AT 10,943'. 04:20 - 06:25 2.08 DRILL P PROD1 WIPER TRIP TO WINDOW.RIH TO TD. 06:25 09:50 3.42 DRILL P PROD1 DRILL LATERAL FROM 10943FT WITH QUICKDRILL 8.5 PPG MW AT 1.64 BPM,2500 PSI FS,300-400 PSI MW,60-90 FT/HR ROP, 2.00-2.30K WOB,10.17PPG ECD,PVT 340 BBLS.ADD 1%NXS LUBE TO MUD SYSTEM. WITH MULTIPLE WIPERS, DRILL TO 11107FT. 09:50 - 10:50 1.00 DRILL P -_ PROD1 WIPER TO THE WINDOW.RATTY FROM 10940FT TO 10880FT,OTHERWISE CLEAN. 10:50 - 11:05 0.25 DRILL P -_ PROD1 LOG DOWN ACROSS RA TAG FOR TIE-IN PLUS 11F . 11:05 - 11:55 0.83 DRILL P PROD1 WIPER TO TD,SLIGHT SET DOWN AT 10600FT. IT APPEARS THAT THE ADDITION OF 1%NXS LUBE HELPED WITH WEIGHT TRANSFER ISSUES. 11:55 - 13:40 1.75 DRILL P PROD1 DRILL LATERAL FROM 11117FT WITH QUICKDRILL 8.5 PPG MW AT 1.61 BPM,2680 PSI FS,275-375 PSI MW,110-150 FT/HR ROP, 1.60-2.0K WOB,10.2PPG ECD,PVT 337 BBLS. DRILL TO 11251 FT. 13:40 - 15:45 2.08 DRILL P -_ PROD1 WIPER TO THE WINDOW,SLIGHT OP AT 10590FT.WIPER TO TD-CLEAN. 15:45 - 17:25 1.67 DRILL P PROD1_, DRILL LATERAL FROM 11250FT WITH QUICKDRILL 8.5 PPG MW AT 1.61 BPM,2800 PSI FS,250-300 PSI MW,110-125 FT/HR ROP, 1.10-1.5K WOB,10.17PPG ECD,PVT 326 BBLS. DRILL TO 11417FT. 17:25 - 19:50 2.42 DRILL P -_ PROD1 WIPER TO THE WINDOW. WIPER TO TD. WIPE THROUGH 11,360'SEVERAL TIMES. Printed 10/14/2010 12:16:35PM North America -ALASKA- BP Page 5 of 5 Operation Summary Report Common Well Name: C-37 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 9/5/2010 End Date: X3-00WFH-C(949,550.00) Project: Prudhoe Bay Site:PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 10/30/1993 12:00:00AM Rig Release:9/12/2010 Rig Contractor: NORDIC CALISTA UWI:500292236000 Active Datum:45:37 5/8/1993 00:00©67.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:50 - 21:10 1.33 DRILL P PROD1 DRILL LATERAL FROM 11417FT WITH QUICKDRILL 8.5 PPG MW AT 1.61 BPM,2800 PSI FS,100-110 PSI MW,100-134 FT/HR ROP, 1.25-1.5K WOB,10.17PPG ECD,PVT 306 BBLS. DRILL TO 11,550FT. 21:10 - 23:30 2.33 DRILL P PROD1 WIPER TO THE WINDOW AND TIE-IN;+6' CORRECTION. WIPER TO TD. NO PROBLEMS ON TRIP BACK IN. 23:30 - 00:00 0.50 DRILL P PROD1 DRILL LATERAL FROM 11417FT WITH QUICKDRILL 8.5 PPG MW AT 1.61 BPM,2810 PSI FS,250-300 PSI MW,100-110 FT/HR ROP, .99-1.5K WOB,10.17PPG ECD,PVT 298 BBLS. DRILL TO 11,593FT. 9/9/2010 00:00 - 02:00 2.00 DRILL P PROD1 DRILL LATERAL FROM 11417FT WITH QUICKDRILL 8.6 PPG MW AT 1.61 BPM,2810 PSI FS,250-400 PSI MW,40-63 FT/HR ROP,1.75-2.75K WOB,10.17PPG ECD,PVT 294 BBLS. DRILL TO 11,593FT. -NOT MAKING FURTHER PROGRESS; CONSULT WITH GEO AND DECIDE TO CALL TP AT 11.629'. 02:00 - 04:45 2.75 DRILL P PROD1 WIPER TRIP TO WINDOW. TIE IN WITH+2.5' CORRECTION. WIPER TRIP TO TD WITH NO ISSUES.TAG TD @ 11625FT. 04:45 - 05:50 1.08 DRILL P PROD1 POH SPOTTING LINER RUNNING PILL, 1.6BPW2500PSI.NO ISSUES. 05:50 - 08:30 2.67 DRILL P PROD1 PULL ABOVE WINDOW.OPEN EDC.POH PUMPING 2BPM/2400PSI.PAINT EOP FLAGS AT 9000FT&6938FT.CONTINUE TO POH.JOG AT SURFACE. PJSM REGARDING LD DRILLING BHA. 08:30 - 09:05 0.58 DRILL P PROD1 FLOW CHECK. POP OFF WELL. BLOW DOWN &LD DRILLING BHA. BIT WAS 2-2,WITH MOTOR RUBBER INSIDE. Printed 10/14/2010 12:16:35PM North America -ALASKA- BP Page 1 of 5 Operation Summary Report Common Well Name:C-37 AFE No Event Type: COM-ONSHORE(CON) Start Date:9/9/2010 I End Date: X3-00WFH-C(1,140,170.00) Project:Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 10/30/1993 12:00:00AM Rig Release:9/12/2010 Rig Contractor:NORDIC CALISTA UWI:500292236000 Active Datum:45:37 5/8/1993 00:00 @67.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/9/2010 09:05 - 09:55 0.83 CASING P RUNPRD BREAK OFF BHI UQC.SEAL E-LINE CABLE. MU CT TO 1 JT OF 2-1/16"CSH.STAB ONTO WELL.CIRCULATE E-LINE OUT OF REEL. POP OFF WELL&CUT 265FT OF E-LINE CABLE.LD CSH.CUT OFF 25FT OF COIL. 09:55 - 10:50 0.92 CASING P RUNPRD MU BOT CTC. PULL TEST TO 25K.PRESSURE TEST TO 4000PSI. 10:50 - 11:20 0.50 CASING P RUNPRD RU ELEVATORS.RU ECKELS.RU SAFETY JOINT.RU 1"CSH LINER DRIFT. 11:20 - 11:30 0.17 CASING P RUNPRD PJSM REGARDING MU LINER. 11:30 - 14:45 3.25 CASING P RUNPRD MU LINER PER PROGRAM,74 JTS OF 2-3/8" STL LINER.DRIFT FIRST 15 JTS WITH 1"CSH. MU HEAD PIN, FILL LINER.MU DEPLOYMENT SLEEVE.PU 6 JTS OF 2-1/16"CSH.PU INJECTOR&MU TO BHA. 14:45 - 18:30 3.75 CASING P RUNPRD RIH WITH LINER.CIRC,0.25BPM/842PS1. SWAP REEL TO SLICK KCL WHILE RIH TO KEEP BELOW RELEASE PRESSURES.WT CK ABOVE WINDOW,NO PUMPS.30K PUW,17K RIW.RIH PAST WINDOW-CLEAN.SET DOWN AT 11060FT,38K PUW.SET DOWN EVERY 30FT THERE AFTER.WORK LINER DOWN HOLE.SET DOWN REPEATABLY AT 11351 FT. WORK PAST ON THE 15TH TRY.WORK DOWN&SET DOWN EVERY 30FT.WORK TO 11625FT. 18:30 - 19:00 0.50 CASING P RUNPRD DROP 5/8"STEEL TO RELEASE FROM LINER, HOLDING 200PSI BACK PRESSURE. PLACE STRING IN 10K DOWN WEIGHT. BALL LANDED,PRESSURE UP AND LINER RELEASED AT 2600 PSI. PU 4'TO CONFIRM. SET BACK DOWN. 19:00 - 21:15 2.25 CASING P RUNPRD CONTINUE TO DISPLACE WITH KCL AND MIXING BIOZAN TO PREPARE FOR CEMENTING. -FLOW RATES: -765 PSI AT 1 BPM -1684 PSI AT 1.5 BPM -1986PSIAT1.9BPM 21:15 - 21:45 0.50 CASING P RUNPRD PJSM ON CEMENT JOB Printed 10/14/2010 12:15:27PM North America -ALASKA- BP Page 2 of 5 Operation Summary Report Common Well Name:C-37 'AFE No Event Type:COM-ONSHORE(CON) Start Date: 9/9/2010 End Date: X3-00WFH-C(1,140,170.00) Project:Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 10/30/1993 12:00:00AM Rig Release:9/12/2010 Rig Contractor:NORDIC CALISTA UWI:500292236000 Active Datum:45:37 5/8/1993 00:00 @67.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 21:45 - 23:45 2.00 CASING P RUNPRD PUMP CEMENT JOB PER WELL PI AN -LINE UP, PUMP FLUID TO SLB CEMENTERS TO FILL AND WARM LINES. -LINE UP VALVES ON CTD REEL,BYPASS FILTERS AND MM -PRESSURE TEST LINES,CEMENT LINE IRON AND INNER REEL IRON TO 6500 PSI FOR 5 MINUTES C/ Gri -BATCH MIX CEMENT PER WELL PLAN; l~ BATCHED AT 2223 HRS -PUMP 11 BBLS OF 15.8 PPG CLASS"G" CEMENT TO CTD REEL -SHUT DOWN, RIG PUMPS TAKE OVER; SEND FLUID TO SLB CEMENTERS TO CLEAN LINE -PUMP CEMENT DOWN LINE AT 1.5 BPM, 1700 PSI -SHUT DOWN PUMPS,PU 13'AND PUMP 5 BBLS TO EXHAUST CEMENT -SET DOWN TO RELEASE LINER WIPER PLUG;PUMP PLUG DOWN WITH LATCH AT 2500 PSI -8.9 BBLS ON BACK SIDE CONTINUE TO PRESSURE UP TO 3200 PSI AND HOLD FOR 2 MINUTES -BLEED OFF PRESSURE AND CHECK FLOATS;GOOD -CIP 2340 -PRESSURE UP TO 600 PSI, PU OUT OF LINER TOP WITH GOOD PRESSURE DROP ONCE OUT -CIRCULATE ABOVE LINER TOP 23:45 - 00:00 0.25 CASING P RUNPRD POH WHILE PUMPING KCL TREATED WITH BIOZAN AT 1.95 BPM. ONCE BIOZAN DEPLETED,SLOWED RATE TO 1.8 BPM. -RD CEMENTERS 9/10/2010 00:00 - 01:30 1.50 CASING P -_ RUNPRD POH. OFFLOAD CEMENT RETURNS WHILE POH. CIRCULATE CLEAN KCL AROUND. 01:30 - 02:30 1.00 CASING P -_ RUNPRD INSPECT DERRICK,SERVICE CROWN, SERVICE COIL INJECTOR HEAD. 02:30 - 03:30 1.00 CASING P RUNPRD RD INJECTOR HEAD FROM CASING RUN. LAY DOWN LINER RUNNING BHA. RUNNING TOOL PINS SHEARED COMPLETELY,5/8" BALL RECOVERED. 03:30 - 08:35 5.08 EVAL P OTHCMP PJSM ON MAKING UP CLEANOUT BHA. CLEAR AND CLEAN FLOOR FOR CLEANOUT BHA. -MU CLEANOUT BHA: 1.75"MILL, MOTOR, CIRCK SUB WITH DISCONNECT,1"WORK STRING,HIGH LOAD DISCONNECT,2 JOINTS 2-1/16TH CSH,QUICK CONNECT.MU HEAD PIN&BREAK CIRCULATION DURING HALF WAY THROUGH MU OF 1"CSH WORK STRING.MU HEAD PIN&CIRC AFTER PU CSH.MU BHA TO INJECTOR.STAB ONTO WELL. BREAK CIRCULATION,0.35BPM/480PSI 08:35 - 09:50 1.25 EVAL P -_ OTHCMP RIH WITH CLEAN OUT BHA(BHA#5). CIRCULATE 0.3BPM/430PSI. 09:50 - 11:30 1.67 EVAL N WAIT _ OTHCMP SLOWLY RIH&WAIT FOR CEMENT CS TO REACH 500PS1. Printed 10/14/2010 12:15:27PM North America -ALASKA- BP Page 3 of 5 Operation Summary Report Common Well Name:C-37 1AFE No Event Type:COM-ONSHORE(CON) Start Date:9/9/2010 End Date: X3-00WFH-C(1,140,170.00) Project:Prudhoe Bay 'Site:PB C Pad - Rig Name/No.: NORDIC 1 Spud Date/Time: 10/30/1993 12:00:00AM Rig Release:9/12/2010 Rig Contractor: NORDIC CALISTA UWI:500292236000 Active Datum:45:37 5/8/1993 00:00 @67.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:30 - 12:30 1.00 EVAL P OTHCMP RIH. PUMP 35BBLS OF SLICK 2%KCL WITH 2PPB BIOZAN FOLLOWED BY SLICK 2%KCL AT 1.05BPM/2940PSI.WITH BIO PILL EXITING THE MILL,SET DOWN AT 11286FT,NO MW. WORK TO 11303FT. 12:30 - 12:50 0.33 EVAL P ■- OTHCMP WIPER TO AT 11 7 0FT,2L1(PLYPUH DOWN AGAIN AT 11270FT.SLOWLY PUH& CIRCULATE OUT BIO PILL. 12:50 - 13:30 0.67 EVAL P ■ OTHCMP RIH FROM 11075FT,1.05BPM/2975PSI.RIW= 10.5K.TAG THRICE AT 11569FT WITH MOTOR WORK EACH TIME. 13:30 - 15:20 1.83 EVAL P OTHCMP POH. NO CEMENT SEEN IN THE RETURNS. 15:20 - 17:30 2.17 EVAL P OTHCMP TAG UP.FLOW CHECK.POP OFF WELL.LD 3 JTS OF 2-1/16'CSH TUBING.HELD KICK WHILE TRIPPING DRILL.STAND BACK 1"CSH WORK STRING IN DERRICK.SMALL PIECE OF POSSIBLE LWP ATTACHED TO SIDE OF MILL. 17:30 - 18:30 1.00 EVAL P ■- OTHCMP ONTO INJECTOR.CLMU OSE SWIZZLE R.STICK BHA.STAB ONTO WELL.CLOSE MASTER.JET BOP STACK&DEAD LEGS. 18:30 - 19:00 0.50 BOPSUR P ■ OTHCMP FUNCTION TEST BOP -CLEAR AND CLEAN FLOOR FOR RUNNING LOGGING TOOLS 19:00 - 20:00 1.00 EVAL P OTHCMP PJSM ON RIGGING UP,RUNNING LOGGING TOOLS -BRING LOGGING TOOLS TO RIG FLOOR -RU LOGGING BHA(BHA#6 20:00 - 23:00 3.00 EVAL P OTHCMP RIH WITH LOGGING BHA ON 1"CS HYDRIL WORK STRING. MU CTC,CONTINUE RIH ON COIL TO 8800'FOR PRIMARY DEPTH CONTROL TIE-IN. 23:00 - 00:00 1.00 EVAL P OTHCMP LOG DOWN FROM 8800'TO PBTD AT 30'/MIN. ■- -SLB CEMENTERS CONFIRM 2000 PSI COMPRESSIVE STRENGTH AT 2300 HRS 9/11/2010 00:00 - 01:30 1.50 EVAL P OTHCMP LOG DOWN FROM 8800'TO PBTD AT 30'/MIN. TAG PBTD AT 11,572'THREE TIMES. -LOG UP AT 60'/MIN FROM PBTD WHILE LAYING IN 120K LSRV 8.6PPG WITH 2%NXS LUBE LINER PILL IN THE LINER ONLY. 01:30 - 03:00 1.50 EVAL P OTHCMP FLAG AT 8800'. POH TO LOGGING BHA. 03:00 - 03:15 0.25 EVAL P OTHCMP TAG AT SURFACE. BREAK OUT FROM BHA. 03:15 - 04:30 1.25 EVAL P OTHCMP STAND BACK 1"CSH 04:30 - 04:45 0.25 EVAL P OTHCMP LD LOGGING BHA 04:45 - 07:00 2.25 EVAL P OTHCMP CNL LOGGER INTERPRET LOGS AND SEND TO TOWN GEOLOGISTS FOR VERIFICATION. -PRESSURE TEST LINER TO 2000 PSI WHILE WAITING;ON PFRFORATION INSTRl1CTION PRESSURE TEST LINER LAP TO 2000PSI- FAILED TWICE,200PSI LOSS IN 1 MIN. 07:00 - 07:20 0.33 PERFOB P OTHCMP PJSM REGARDING MU PERF GUNS. 07:20 - 11:00 3.67 PERFOB P OTHCMP MU PERF GUN BHA,73 PERF GUNS,15 STANDS OF 1"CSH(CHECK EACH CONNECTION),3 JTS OF 2-1/16"CSH.PU& MU INJECTOR TO BHA. 11:00 - 13:20 2.33 PERFOB P -_ OTHCMP RIH WITH PERF BHA.TAG BOTTOM TWICE AT 11575FT, CORRECT TO 11585FT. Printed 10/14/2010 12:15:27PM North America -ALASKA- BP Page 4 of 5 Operation Summary Report Common Well Name:C-37 AFE No Event Type: COM-ONSHORE(CON) Start Date:9/9/2010 End Date: X3-00WFH-C(1,140,170.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 1 Spud Date/Time: 10/30/1993 12:00:00AM Rig Release: 9/12/2010 Rig Contractor: NORDIC CALISTA UWI:500292236000 Active Datum:45:37 5/8/1993 00:00©67.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:20 - 13:50 0.50 PERFOB P OTHCMP PERFORATE WELL FROM 10040FT-10170FT, (1-' 10240FT-10380FT,10460FT-10490FT, 17)1. 10570FT-10600FT,10650FT-10830FT, 11000FT-11140FT,11230FT-11260FT, 11310FT-11570FT USING 1.56"6SPF POWER JET 1606.GOOD INDICATION OF GUNS FIRING WITH LOSSES(ASSUME GUNS FILLING UP). 13:50 - 14:50 1.00 PERFOB P OTHCMP SLOWLY POH IN THE LINER. 14:50 - 15:10 0.33 EVAL P OTHCMP STOP AT 9800FT&FLOW CHECK-NO FLOW. FILL HOLE-—1.5BBL LOSS. 15:10 - 16:50 1.67 PERFOB P OTHCMP PAINT EOP FLAG AT 6800FT.CONTINUE TO POH. 16:50 - 18:00 1.17 PERFOB P OTHCMP TAG UP.FLOW CHECK.POP OFF WELL. STAND BACK INJECTOR.LD 3 JTS OF 2-1/16" CSH.STAND BACK 1"CSH. 18:00 - 21:30 3.50 PERFOB P OTHCMP ' - • =Li , -• MONITOR WELL-STATIC. ACTUAL HOLE FILL EQUALED CALCULATED HOLE FILL. 21:30 - 22:15 0.75 PERFOB P OTHCMP RD FROM PERF RUN. CLEAR AND CLEAN RIG FLOOR. 22:15 - 22:30 0.25 ZONISO P OTHCMP PJSM ON PICKING UP AND RUNNING LINER TOP PACKER 22:30 - 23:15 0.75 ZONISO P OTHCMP MU CTC. CONTINUE MAKING UP LINER TOP PACKER RUNNING BHA. PU 3"HYDRAULIC .. KB LINER TOP PACKER(TURNED DOWN TO . 2.75"TO RUN THROUGH SSSVN AT 2106') WITH 6.02'2.25"SEAL ASSEMBLY. 23:15 - 00:00 0.75 ZONISO P OTHCMP PUMP DOWN COIL AND THROUGH ASSEMBLY. CLEAR. RIH WITH LINER TOP PACKER ASSEMBLY AT AVERAGE OF 75 FPM WHILE PUMPING AT.2 BPM,170 PSI. 9/12/2010 00:00 - 02:30 2.50 ZONISO P OTHCMP RIH WITH 3"HYDRAULIC KB LINER TOP PACKER(TURNED DOWN TO 2.75"TO RUN THROUGH SSSVN AT 2106')WITH 6.02'2.25" SEAL ASSEMBLY -RUNNING AT 75 FPM,.2 BPM,145 PSI -8.3 MW IN,8.2 MW OUT -TAG AT 9188'WITH 190 PSI INCREASE IN PRESSURE;SET DOWN 10K AND MOVE TO 9195' -PU TO UP WEIGHT TO 9189'AND PICK UP ADDITIONAL 1' -SET DOWN AND TAG AT 9190' -SET BACK DOWN WITH 10K TO 9195' 02:30 - 03:15 0.75 EVAL P OTHCMP CONDUCT LINER PRESSURE TEST TO 250 PSI LOW FOR 5 MINUTES. CONTINUE TO PRESSURE UP TO 2000 PSI AND TEST FOR 30 MINUTES. GOOD TEST WITH 20 PSI BLEED OFF IN FIRST 15 MINUTES AND 10 PSI BLEED OFF IN SECOND 15 MINUTES. CONSULT WITH TOWN ENGINEER,DECISION IS TO POH WITH PACKER. 03:15 - 04:50 1.58 ZONISO P OTHCMP POH WITH LINER TOP PACKER 04:50 - 05:30 0.67 ZONISO P OTHCMP LD LINER TOP PACKER RUNNING TOOL AND PACKER 05:30 - 06:20 0.83 WHSUR P OTHCMP MU,RIH WITH FREEZE PROTECT BHA. FREEZE PROTECT WITH DIESEL TO 2500' 06:20 - 06:50 0.50 WHSUR P OTHCMP LAY IN DIESEL FP. Printed 10/14/2010 12:15:27PM North America -ALASKA- BP Page 5 of 5 Operation Summary Report Common Well Name:C-37 AFE No Event Type:COM-ONSHORE(CON) Start Date:9/9/2010 End Date: X3-00WFH-C(1,140,170.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 10/30/1993 12:00:00AM Rig Release:9/12/2010 Rig Contractor:NORDIC CALISTA UWI:500292236000 Active Datum:45: 37 5/8/1993 00:00 @67.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:50 - 07:20 0.50 WHSUR P OTHCMP CLOSE SWAB.PUMP 2OBBLS OF FW. 07:20 - 07:30 0.17 WHSUR P OTHCMP PJSM REGARDING PUMPING NITROGEN, 07:30 - 09:10 1.67 WHSUR P OTHCMP BLOW DOWN REEL.LET BLEED OFF.POP OFF WELL&MU PULL BACK GRAPPLE. 09:10 - 09:25 0.25 WHSUR P OTHCMP OPEN WELL-VAC. PJSM&T-BAR IN BPV. CLOSE IN WELL.GREASE TREE.SUCK DOWN PITS,CUTTINGS BOX&TIGER TANK.SUPER SUCK CUTTINGS BOX.DISCONNECT HARDLINE FROM RIG. • 09:25 - 11:00 1.58 RIGD P OTHCMP UNSTAB&PULL BACK COIL.SECURE ON REEL WITH SHIPPING BAR.CUT OFF EXCESS COIL.REMOVE INNER REEL HARDLINE. 11:00 - 13:45 2.75 RIGD P OTHCMP PERFORM LOTO ON KOOMEY UNIT.OPEN ALL RAM DOORS ON BOP&INSPECT SAME. 13:45 - 15:50 2.08 RIGD P OTHCMP ND BOP'S.ND XO FLANGE.NU TREE CAP. PRESSURE TEST WITH DIESEL TO 250PIS/3500PS1. LOWER REEL TO GROUND. 15:50 - 16:00 0.17 RIGD P OTHCMP RELEASE RIG AT 1600. Printed 10/14/2010 12:15:26PM C-37B, Well History Date Summary 09/12/10 T/I/O=0/0/0. Set 4 1/16" CIW 'H' BPV#151 w/T-bar for Nordic 2 RDMO. RKB=24.53'. 09/12/10 T/I/O=0/0/0;Torqued all tree flange nuts to spec. (see log) post Nordic 1 CTD;Tested barriers to 500 psi. for 5 min. PASSED;Tested lubricator to 500 psi low and 3500 psi high for 5 min.each PASSED; Pulled 4- 1/16" CIW H BPV#151 thru tree; 1-1'ext used,tagged @ 114"; Set 4-1/16"CIW H TWC thru tree after integrity test of 500 psi low and 3500 psi high PASSED; Shell tested tree (including THA to MV flange)to 500 psi for 5 min. PASSED 5000 psi for 5 min. PASSED; Pulled TWC#256 and pressure tested tree cap to 500 psi low and 5000 psi high for 5 min. PASSED; RDMO***Job complete*** 09/18/10 ***WELL S/I ON ARRIVAL***(post ctd) SET 3-1/2" SLIP-STOP @ 7012 SLM PULLED RK-DGLV FROM STA#1 @ 6955' SLM/6961' MD AND RK-DGLV FROM STA#2 © 4497' I t`j1" SLM/4439' MD SET STA#2 RK-LGLV © 4,439' MD �� SET STA#1 RK-OGLV CO 6,961' MD PULLED 3-1/2" SLIP-STOP Q 7012' SLM ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** 09/20/10 ASRC Test Unit#2,transport equipment to location, Rig up,begin Flow back, ***Job in Progress*** ***Inlet C-37, Outlet C-35*** 09/21/10 ASRC Test Unit#2, Continue Flow back,Working choke open, Monitoring for solids, ***Job in Progress*** ***Inlet C-37, Outlet C-35*** 09/22/10 ASRC Test Unit#2,Continue flow back, Monitor for solids, Start 12 hour test, DRIL Performed Well Control Drill, DRIL Performed Emergency Drill, ***Job in Progress*** ***Inlet C-37B, Outlet C-35*** 09/23/10 ASRC Test Unit#2, End 12 hour test,Attempt to flow well w/o A/L, DRIL Performed Well Control and Emergency Drills, Begin Rig down ***Job in Progress*** ***Inlet C-37B,Outlet C-35*** 09/24/10 ASRC Test Unit#2, Complete Rig down, Leave location, ***Job Complete*** ***Inlet C-37B, Outlet C-35*** 10/28/10 T/I/0=1000/1500/600 .Temp=60 RG-2401 (Surface casing corr. mitigation) PJSM. Strapped conductor 56". Install spill containment. Pumped 30.6 gal RG-2401 to fill conductor. RDMO. Page 1 of 1 BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB C Pad C-37 - Slot 37 500292236000 C-37B Survey: MWD Survey Report - Geographic 09 September, 2010 hn Mal BHUGH } o,ES Survey Report- Geographic ,a big LNTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well C-37-Slot 37 Project: Prudhoe Bay TVD Reference: 45:37 5/8/1993 00:00 Q 67.70ft(generic drilling Site: PB C Pad MD Reference: 45:37 5/8/1993 00:00©67.70ft(generic drilling Well: C-37 North Reference: True Wel lbore: C-37B Survey Calculation Method: Minimum Curvature Design: C-37B Database: EDM.16-ANC Prod-WH24P Project Prudhoe Bay,GPB, PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor 1 Site PB C Pad,TR-11-14 1 Site Position: Northing: 5,957,218.72ft Latitude: 70°17'22.367 N From: Map Easting: 662,550.03ft Longitude: 148°41'2.797 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 1.24 ° Well C-37 API No 500292236000 Well Position +N/-S 0.00 ft Northing: 5,960,111.90 ft Latitude: 70° 17'50.401 N +E/-W 0.00 ft Easting: 664,495.49 ft Longitude: 148°40'4.275 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore C-37B API No 500292236002 Magnetics Model Name Sample Date Declination_ Dip Angle Field Strength ■ (°) (°) (nT) BGGM2009 4/1/2010 22.26 80.93 57,687 Design C-376 Audit Notes: Version: Phase: ACTUAL Tie On Depth: 9,529.69 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 34.70 0.00 0.00 44.65 Survey Program Date: 9/9/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 305.20 9,529.69 1 :MWD-Standard(C-37) MWD MWD-Standard 9,557.30 11,625.00 MWD(C-37B) MWD MWD-Standard 9/9/2010 10:57:06AM Page 2 COMPASS 2003.16 Build 71 BAKER HUGHES Survey Report- Geographic by I\TL:Q Company: North America-ALASKA-BP Local Co-ordinate Reference: Well C-37-Slot 37 Project: Prudhoe Bay TVD Reference: 45:37 5/8/1993 00:00 @ 67.70ft(generic drilling Site: PB C Pad MD Reference: 45:37 5/8/1993 00:00 @ 67.70ft(generic drilling Well: C-37 North Reference: True Wellbore: C-37B Survey Calculation Method: Minimum Curvature Design: C-37B Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,529.69 50.17 59.66 8,798.54 1,971.66 2,561.07 5,962,139.01 667,012.62 70° 18'9.787 N 148°38'49.602 W TIP 9,557.30 51.01 58.36 8,816.07 1,982.65 2,579.36 5,962,150.39 667,030.66 70° 18'9.895 N 148°38'49.069 W KOP 9,591.68 35.68 44.58 8,841.05 1,996.91 2,597.92 5,962,165.06 667,048.90 70°18'10.036 N 148°38'48.527 W 9,627.42 32.37 23.52 8,870.77 2,013.17 2,609.10 5,962,181.55 667,059.72 70°18'10.195 N 148°38'48.201 W 9,660.18 32.36 5.84 8,898.51 2,029.97 2,613.50 5,962,198.45 667,063.75 70°18'10.361 N 148°38'48.073 W 9,690.42 32.58 349.37 8,924.07 2,046.06 2,612.82 5,962,214.51 667,062.72 70°18'10.519 N 148°38'48.092 W 9,720.66 36.02 340.93 8,949.06 2,062.48 2,608.41 5,962,230.83 667,057.95 70°18'10.680 N 148°38'48.221 W 9,750.78 44.11 348.19 8,972.11 2,081.15 2,603.36 5,962,249.38 667,052.49 70°18'10.864 N 148°38'48.368 W 9,780.18 52.35 351.07 8,991.68 2,102.70 2,599.45 5,962,270.84 667,048.12 70°18'11.076 N 148°38'48.482 W 9,810.34 61.04 353.13 9,008.22 2,127.65 2,596.01 5,962,295.71 667,044.13 70°18'11.321 N 148°38'48.582 W 9,840.32 69.85 352.83 9,020.67 2,154.68 2,592.68 5,962,322.66 667,040.21 70°18'11.587 N 148°38'48.678 W 9,870.50 79.75 354.11 9,028.57 2,183.58 2,589.38 5,962,351.48 667,036.28 70°18'11.872 N 148°38'48.774 W 9,900.52 89.20 354.33 9,031.46 2,213.28 2,586.37 5,962,381.10 667,032.62 70°18'12.164 N 148°38'48.862 W 9,931.18 93.63 359.62 9,030.70 2,243.87 2,584.76 5,962,411.64 667,030.34 70°18'12.464 N 148°38'48.909 W 9,960.82 94.36 5.92 9,028.64 2,273.38 2,586.18 5,962,441.18 667,031.12 70°18'12.755 N 148°38'48.867 W 9,990.90 92.21 9.88 9,026.91 2,303.12 2,590.31 5,962,471.00 667,034.59 70°18'13.047 N 148°38'48.746 W 10,023.40 89.88 12.98 9,026.32 2,334.97 2,596.75 5,962,502.98 667,040.33 70°18'13.360 N 148°38'48.558 W 10,050.60 89.60 17.49 9,026.44 2,361.20 2,603.90 5,962,529.36 667,046.90 70°18'13.618 N 148°38'48.349 W 10,080.62 90.67 15.45 9,026.37 2,389.99 2,612.41 5,962,558.33 667,054.78 70°18'13.901 N 148°38'48.101 W 10,110.62 90.68 10.23 9,026.02 2,419.23 2,619.07 5,962,587.70 667,060.80 70°18'14.189 N 148°38'47.906 W 10,140.56 92.06 5.82 9,025.30 2,448.86 2,623.25 5,962,617.41 667,064.33 70°18'14.480 N 148°38'47.784 W 10,170.42 93.34 8.31 9,023.90 2,478.46 2,626.92 5,962,647.08 667,067.35 70°18'14.771 N 148°38'47.677 W 10,200.06 92.67 12.71 9,022.34 2,507.55 2,632.31 5,962,676.29 667,072.11 70°18'15.058 N 148°38'47.519 W 10,230.60 91.01 15.89 9,021.36 2,537.12 2,639.85 5,962,706.02 667,079.00 70°18'15.348 N 148°38'47.299 W 10,260.80 89.91 18.14 9,021.12 2,566.00 2,648.69 5,962,735.08 667,087.20 70°18'15.632 N 148°38'47.041 W 10,290.52 89.60 22.53 9,021.24 2,593.86 2,659.01 5,962,763.15 667,096.91 70°18'15.906 N 148°38'46.740 W 10,320.70 90.06 26.93 9,021.33 2,621.26 2,671.64 5,962,790.83 667,108.93 70°18'16.176 N 148°38'46.371 W 10,352.00 92.46 29.28 9,020.65 2,648.86 2,686.38 5,962,818.74 667,123.06 70°18'16.447 N 148°38'45.941 W 10,380.46 91.93 32.54 9,019.56 2,673.26 2,700.98 5,962,843.45 667,137.13 70°18'16.687 N 148°38'45.515 W 10,411.14 90.12 35.15 9,019.01 2,698.73 2,718.07 5,962,869.29 667,153.65 70°18'16.938 N 148°38'45.017 W 10,441.14 87.11 38.66 9,019.73 2,722.71 2,736.07 5,962,893.65 667,171.12 70°18'17.173 N 148°38'44.492 W 10,471.18 86.10 39.85 9,021.51 2,745.93 2,755.04 5,962,917.28 667,189.58 70°18'17.402 N 148°38'43.938 W 10,500.88 84.76 35.45 9,023.88 2,769.36 2,773.12 5,962,941.10 667,207.14 70°18'17.632 N 148°38'43.411 W 10,530.78 88.99 37.29 9,025.51 2,793.40 2,790.82 5,962,965.51 667,224.31 70°18'17.868 N 148°38'42.894 W 10,560.94 89.17 39.30 9,025.99 2,817.06 2,809.51 5,962,989.58 667,242.48 70°18'18.101 N 148°38'42.349 W 10,594.36 91.84 39.39 9,025.70 2,842.90 2,830.70 5,963,015.88 667,263.09 70°18'18.355 N 148°38'41.731 W 10,631.06 97.44 43.25 9,022.73 2,870.36 2,854.83 5,963,043.86 667,286.62 70°18'18.625 N 148°38'41.027 W 10,666.34 98.73 44.32 9,017.77 2,895.58 2,879.00 5,963,069.60 667,310.22 70°18'18.873 N 148°38'40.322 W 10,708.88 88.77 44.89 9,014.99 2,925.76 2,908.77 5,963,100.42 667,339.33 70°18'19.170 N 148°38'39.453 W 10,741.12 87.11 39.33 9,016.15 2,949.65 2,930.37 5,963,124.78 667,360.39 70°18'19.405 N 148°38'38.823 W 10,770.94 89.78 37.45 9,016.96 2,973.02 2,948.88 5,963,148.54 667,378.38 70°18'19.634 N 148°38'38.283 W 10,800.98 91.44 40.24 9,016.64 2,996.41 2,967.71 5,963,172.33 667,396.70 70°18'19.864 N 148°38'37.734 W 10,842.82 90.89 44.61 9,015.79 3,027.28 2,995.93 5,963,203.81 667,424.23 70°18'20.168 N 148°38'36.911 W 10,870.62 89.54 41.83 9,015.68 3,047.53 3,014.96 5,963,224.48 667,442.82 70°18'20.367 N 148°38'36.355 W 10,901.66 92.03 38.68 9,015.26 3,071.22 3,035.01 5,963,248.59 667,462.35 70°18'20.600 N 148°38'35.770 W II. 10,929.96 93.01 38.60 9,014.01 3,093.30 3,052.67 5,963,271.06 667,479.51 70°18'20.817 N 148°38'35.255 W 10,963.34 92.79 42.18 9,012.32 3,118.69 3,074.27 5,963,296.91 667,500.55 70°18'21.066 N 148°38'34.625 W 10,990.24 93.10 47.34 9,010.94 3,137.76 3,093.18 5,963,316.38 667,519.04 70°18'21.254 N 148°38'34.073 W • 11,020.86 92.82 50.49 9,009.36 3,157.85 3,116.22 5,963,336.98 667,541.63 70°18'21.451 N 148°38'33.401 W 11,050.50 91.93 50.45 9,008.13 3,176.70 3,139.06 5,963,356.32 667,564.06 70°18'21.637 N 148°38'32.735 W 11,080.78 90.37 53.64 9,007.52 3,195.31 3,162.93 5,963,375.45 667,587.51 70°18'21.820 N 148°38'32.039 W 11,110.64 89.72 56.82 9,007.50 3,212.34 3,187.46 5,963,393.01 667,611.65 70°18'21.987 N 148°38'31.323 W 11,140.50 90.31 58.10 9,007.49 3,228.40 3,212.63 5,963,409.62 667,636.47 70°18'22.145 N 148°38'30.589 W 9/9/2010 10.:57:06AM Page 3 COMPASS 2003.16 Build 71 rGa11a�� BHUGHES Survey Report-Geographic OP 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well C-37-Slot 37 Project: Prudhoe Bay TVD Reference: 45:37 5/8/1993 00:00 @ 67.70ft(generic drilling Site: PB C Pad MD Reference: 45:37 5/8/1993 00:00©67.70ft(generic drilling Well: C-37 North Reference:. True Wellbore: C-37B Survey Calculation Method: Minimum Curvature Design: C-37B Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical ' Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 11,170.44 91.20 54.77 9,007.10 3,244.95 3,237.57 5,963,426.71 667,661.04 70° 18'22.308 N 148°38'29.861 W 11,204.02 90.06 52.59 9,006.73 3,264.84 3,264.62 5,963,447.18 667,687.65 70°18'22.503 N 148°38'29.072 W 11,230.32 91.69 49.39 9,006.33 3,281.39 3,285.05 5,963,464.17 667,707.71 70°18'22.666 N 148°38'28.476 W 11,260.26 89.63 45.33 9,005.98 3,301.66 3,307.07 5,963,484.92 667,729.27 70°18'22.865 N 148°38'27.834 W 11,294.32 91.20 40.30 9,005.73 3,326.64 3,330.21 5,963,510.40 667,751.86 70°18'23.111 N 148°38'27.159 W 11,320.72 89.88 34.65 9,005.48 3,347.58 3,346.26 5,963,531.68 667,767.45 70° 18'23.316 N 148°38'26.690 W 11,361.04 90.28 29.63 9,005.43 3,381.71 3,367.71 5,963,566.27 667,788.14 70° 18'23.652 N 148°38'26.065 W 11,390.76 91.26 30.16 9,005.03 3,407.47 3,382.52 5,963,592.35 667,802.38 70° 18'23.905 N 148°38'25.632 W 11,420.68 92.70 32.84 9,004.00 3,432.96 3,398.14 5,963,618.18 667,817.44 70° 18'24.156 N 148°38'25.176 W 11,450.70 95.31 35.77 9,001.90 3,457.70 3,415.01 5,963,643.27 667,833.77 70°18'24.399 N 148°38'24.684 W 11,480.66 93.44 39.13 8,999.61 3,481.41 3,433.18 5,963,667.37 667,851.41 70°18'24.632 N 148°38'24.154 W 11,511.18 95.13 42.49 8,997.33 3,504.44 3,453.06 5,963,690.83 667,870.78 70°18'24.859 N 148°38'23.574 W 11,541.00 92.67 45.51 8,995.30 3,525.84 3,473.73 5,963,712.67 667,890.97 70° 18'25.069 N 148°38'22.971 W 11,572.12 92.67 47.68 8,993.85 3,547.20 3,496.31 5,963,734.52 667,913.08 70° 18'25.279 N 148°38'22.312 W 11,600.28 91.44 51.37 8,992.84 3,565.46 3,517.71 5,963,753.25 667,934.08 70° 18'25.458 N 148°38'21.688 W 11,625.00 91.44 51.37 8,992.22 3,580.89 3,537.02 5,963,769.09 667,953.04 70°18'25.610 N 148°38'21.124 W TD 9/9/2010 10:57:06AM Page 4 COMPASS 2003.16 Build 71 SEAN PARNELL, GOVERNOR 0 ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-37B BP Exploration (Alaska), Inc. Permit No: 210-100 Surface Location: 1110' FNL, 879' FEL, SEC. 19, T11N, R14E, UM Bottomhole Location: 2407' FSL, 2570' FWL, SEC. 17, T11N, R14E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-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. Sincerely, ak),/, Cathy P. Foerster c7(-6-clay DATED this / day of August, 2010. cc: Department of Fish 85 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ECE1VEDot ` ALASI' 'IL AND GAS CONSERVATION COMMIT IN 1UL 2 7 2010 • PERMIT TO DRILL 20 AAC 25.005 Alaska t9&Gas Cam,C omission 1 a.Type of work: 1 b.Proposed Well Class: 1 c. Specify if d for: YP P ®Development Oil 0 -Win] 0 Zone �{�$�� ❑ Drill ®Redrill ❑ Stratigraphic Test ❑Development Gas ❑Service-Supply ❑Multiple Zone ❑Coalbed Gas aGE Hydrates ❑ Re-Entry ❑ Exploratory ❑Service-WAG ❑Service-Disp ❑Shale Gas 2. Operator Name: 5.Bond: ® Blanket ❑Single Well 11. Well Name and Number: BP Exploration(Alaska)Inc. Bond No. 6194193 PBU C-37B 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O.Box 196612,Anchorage,Alaska 99519-6612 MD 11525' TVD 8929'ss Prudhoe Bay Field/Prudhoe , 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Bay Oil Pool Surface: ADL 028305 1110'FNL, 879'FEL, SEC 19,T11N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1065'FSL,2069'FWL, SEC 17,T11N, R14E, UM September 14,2010 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2407'FSL,2570'FWL, SEC 17,T11N, R14E, UM 2560 22,580' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 67.70 feet 15.Distance to Nearest Well Open Surface: x- 664495 y-5960111 Zone- ASP4 GL Elevation above MSL: 32.7 feet to Same Pool: 450' 16.Deviated Wells: Kickoff Depth: 9570 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 93 degrees Downhole: 3,252 Surface: 2,372 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 3" 2-3/8" 4.7# L-80 STL 2315' 9210' 8504'ss 11525' 8929'ss 49 sx Class'G' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): 12583' 8909' None 12553' 8911' None Casing Length Size Cement Volume MD ND Conductor/Structural 78' 20" 260 sx Arctic Set(Aoorox) 110' 110' Surface 3293' 13-3/8" 1097 sx PF'E'.420 sx Class'G' 3328' 3250' Intermediate 9021' 9-5/8" 665 sx Class'G' 9053' 8437' Production _ Liner 1678' 7" 330 sx Class'G' _ 8885'-10563' 8289'-9010' Liner 1057' 4-1/2" (Cemented over with 2-3/8"Cement) 10428'-11485' 9017'-8976' Liner 2654' 2-3/8" 172 sx Class'G' 9936'-12590' 8982'-8908' Perforation Depth MD(ft): 10965'-12470' Perforation Depth ND(ft): 8993'-8916' 20.Attachments: ❑ Property Plat ®BOP Sketch ®Drilling Program ❑Time vs Depth Plot ❑Shallow Hazard Analysis ❑Diverter Sketch ❑Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the •,�in! 's nd correct. Contact Amanda Suddreth,564-5543 Printed Name J. Af,f/ , Title .igineering Team Leader A',' / - Prepared By Name/Number Signature Phone 564-4711 Date ? Z6 !v Terrie Hubble,564-4628 Commission Use Only Permit �• •rill API Number: Permit loyal Pate: I See cover letter for Numbe: va/O/� 50-029-22360-02-00 (.4 1 l> other requirements Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coalbed ethane,gas hydrates,or gas contained shales: Er S0 C) �'� /-�OP I C S Samples Req'd: ❑Yes I!0 No Mud Log Req'd: ❑Yes Other: og eq' I�No - 2500 es- A.-,..'-4-1-4.,/ 1 e s f- ("ft) H2S Measures: "Yes ❑No Directional Survey Req'd: gYes ❑No APPROVED BY THE COMMISSION C Date — C% �� 7 ,COMMISSIONER Form 10-401 Revised 07/2009 This permit is valid for 24 months from the date of f pprova (20 AAC 25.005(9)) Submit In Duplicate ORIGINA L 7 7430 -lo ,� .7#o C-37B - Coiled Tubing To: Alaska Oil & Gas Conservation Commission From: Amanda Rebol bp CTD Engineer Date: July 14, 2010 Re: C-37B Permit to Drill Application Approval is requested for a permit to drill a through-tubing CTD sidetrack from C-37A. This well will depart 3-1/2" tubing and 7" liner off a 3-1/2" monobore whipstock, targeting reserves in Zone 1A. This sidetrack will effectively replace the high GOR parent wellbore. Coil Tubing Sidetrack: Drill and Complete Summary Pre-Rig Work: (scheduled to begin August 14, 2010) 1. F MIT-IA to 3000psi, MIT-OA to 2000psi 2. S Drift well with dummy whipstock to -9900' 3. E Set CIBP at -9867'. Tubing punch -7' above CIBP 4. F Confirm circulation through tubing punch 5. E Set cement retainer inside 3-1/2"tubing in full joint @ 9600' MD 6. C Sting into cement retainer and pump 24bbls of cement to fill the 3-1/2"x 7"annulus 7. E Set Weatherford LSX 3-1/2" monobore whipstock @ 9550' MD 8. D Bleed wellhead pressures down to zero 9. 0 Remove wellhouse, level pad, remove flow line 10. V Set TWC (within 24 hours of MIRU Nordic 1) P �( T Rig Work: (scheduled to begin on September 14, 2010) 1. MIRU Nordic 1; test BOPs to 250 osi low and 3500 osi high. 2. Mill 2.74"dual string window through 3-1/2" 9.3#L-80 tubing and 7"26# L-80 liner. 3. Drill Build: 3" in Zone 2, 582' (30 deg/100 planned) Nit 4. Drill Lateral: 1393'of lateral in Zone 1A (12 deg/100 planned) ' 5. Run 2-3/8"carbon liner, leaving TOL @ 9210' MD i h'S 6. Pump primary cement leaving TOC at 9210', 10.1 bbls of 15.8 ppg liner cmt planned - D 7. Cleanout liner and MCNLJGR/CCL log • 8. Test liner lap to 2000 psi. • 9. Perforate well as per asset(800') • 10. Run 3-1/2" liner top packer, if necessary 11. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's C-37B - Coiled Tubing Drill�..j Mud Program: • Well kill: 8.6 ppg seawater/brine • Milling/drilling: 8.6 ppg Power-vis Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. - Hole size: 3" 9,550' - 11,525' • Casing Program: • 2-3/8" 4.7#, L-80, STL solid liner 9,210' MD— 11,525' MD . • A minimum of 10.1 bbls of 15.8 ppg cement will be to cement the solid liner(TOC at 9,210') - • If liner lap fails, a linter top packer will be run • Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi._ • The annular preventer will be tested to 250 psi and 2,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 92 deg • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run • Distance to nearest property line—22,580'to the North • Distance to nearest well within pool—450' (C-19A;this well is beyond the TD of C-37B) Anticollision Summary • No anti-collision issues Logging • MWD directional and GR will be run over all of the open hole section. • A cased hole GR/CCL/CNL log will be run. Hazards • C-Pad is not considered a high-level H2S pad. The maximum recorded H2S level on C-Pad is 25ppm on well C-39A(4/16/2007). • Lost circulation risk is moderate. There is one fault crossing planned while drilling; however, this crossing is anticipated to be in a low permeability portion of the reservoir, and shouldn't cause severe losses. If losses are encountered, take appropriate steps for lost circulation mitigation. Reservoir Pressure • Reservoir pressure is estimated to be 3,252 psi at 8,800'TVDss (7.1 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft)to surface is 2,372 psi. Amanda Rebol CTD Engineer TREE= 4-1/16" WELLHEAD 1 FMC C�3 7A SOTES: WELL ANGLE>70°@ 9820' ACTUATOR= NA KB. ELEV = 67.7' BF.ELEV= 32' I KOP= 2050' Max Angle= 101 @ 12291' I O 2106' H 3-1/2"OTIS SSSVN, ID=2.750" Datum MD= 9643' Datum ND= 8800'SS 20"CONDUCTOR, 91.5#, H-40, ID=19-124" 110' GAS LIFT MANDRELS 13-3/8"CSG,68#, L-80 BTC, ID= 12.415" -I 3328' ST MD ND DEV TYPE VLV LATCH FORT DATE I I 2 4439 4203 24 CAMCO DMY RK 0 01/23/10 L 1 _6961 6499_ 24 CAMCO DMY RK _ 0 01/23/10 Minimum ID = 1.92" @ 9940' PIN BORE @ 2-3/8" LINER 8887' H9-5/8"x 7"TM/TIEBACK SLV, lD=? I TOP OF 7"LNR -I 8893' I--� 8893' H9-5/8"x 7"TM/LNR HGR, ID=? I 9-5/8"LNR,47#, NT-80, ID=8.681" H 9052' I-4 I I 9893' H 3-1/2"SWS NIP, ID=2.750" I TOP OF 2-3/8"LNR H 9936' I 173 9936' H3.00"BKR DEPLOY SLV, ID=1.97" I E E.-- 9945' 1_17"X 3-1/2" BKR S-3 PKR, ID=4.00" I I I 9961' I--I3-1/2"SWS NIP, ID=2.750" I 3-1/2"TBG,9.3#, L-80 TDS, .0087 bpf, ID=2.992" H 9966' -/ \-1 9966' H3-1/2"WLEG, ID=2.992" I 9983' -1 ELMD H LOGGED 12/26/93 I II 10428' I_17"X 4-1/2"TM/SS HORIZ PKR, ID=4.00" I 7"LNR,26#, NT-80 NSCC, .0371 bpf, ID=6.184" H 10563' HAI \\\ PERFORATION SUMMARY .\ REF LOG: MCNL/GR/CCL ON 09/15/01 ... ANGLE AT TOP PERF:93 @ 10965' . \ Note: Refer to Production DB for historical perf data " .\ SIZE SPF INTERVAL Opn/Sqz DATE .. �. 1.56" 4 10965- 11560 0 09/15/01 .. 1.56" 4 11770- 12010 0 09/15/01 ... PBTD 12553' 1.56" 4 12200- 12470 0 09/15/01 4-1/2" SLTD 10591 - 11461 SLOT 09/03/93 ` 4-1/2"SLTD LNR, 12.24#, L-80 NSCT, .0150 bpf, ID=3.933" 11485' ' ♦• .4 2-3/8" LNR,4.43#, L-80,STL, .0038 bpf, ID=1.99" H 12590' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/03/93 ORIGINAL COMPLETION WELL C-37A 09/06/93 RWO PERMIT No '2011430 09/16/01 CH/KAK CTD EXTENSION(CMT'D LNR) API No: 50-029-22360-01 08/22/08 RLM/SV PULL LTP SEAL ASSY (07/26/08) SEC 19,T11 N, R14E, 1110'FNL&878'FEL 02/02/10 PJC DRAWING CORRECTIONS 02/02/10 RCT/PJC GLV C/O(01/23/10) BP Exploration(Alaska) TREE= 4-1/16" w 7 WELLHEAD= FMC MC -3 WELL ANGLE>70°@ 9820' ACTUATOR= NA KB.ELEV= 67.7' Proposed CTD Sidetrack BF.ELEV= 32' II KOP= 2050' Max Angle= 101 @ 12291' I 2106' IH 3-1/2"OTIS SSSVN, ID=2 750" Datum MD= 9643' O Datum ND= 8800'SS 20"CONDUCTOR,91.5#, H-40, ID=19-124" 110' 13-3/8"CSG,68#, L-80 BTC, ID=12.415" - 3328' GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE LI 2 4439 4203 24 CAMCO DMY RK 0 01/23/10 1 6961 6499 24 CAMCO_DMY RK _ 0 01/23/10 Minimum ID = 1.75" @ 9200' 3-1/2" BAKER KB LTP I - 8887' H9-5/8"x 7"TM/TIEBACK SLV, ID=? I [TOP OF 7"LNR I 8893' I J 8893' H 9-5/8"x 7"IN LNR HGR, ID=? I I TOC 3-112"x 7" IA 1-1 9045' I 9-5/8"LNR,47#, NT-80, ID=8.681" H 9052' H 36° 9200' I3-1/2"BKR KB LTP ID= 1.75" I TOP OF 2-318' LNK, TOC -1 9210' I x 500 9550' 1-13-1/2"monobore w hipstock TUBING PUNCHES — -9872 / `_ �-��� --HES CIBP — 9885' ' ' 9893' H3-1/2"SWS NIP, ID=2.750" I 1-13.00"I 9936' BKR DEPLOY SLV, ID= 1.97" 2-3/8"L-80 Liner,Cemented&Perf'd H I I z— 9945' h 7"X 3-1/2"BKR S-3 PKR, ID=4.00" I PBTD H ?? I I 9961' IH 3-1/2"SWS NIP, ID=2.750" I TOP OF 2-3/8"LNR,TOC -I- 9936' 3-1/2"TBG,9.3#, L-80 TDS, .0087 bpf, ID=2.992" H 9966' I-/ \ I 9966' 1-13-1/2"WLEG,ID=2.992" I D9983' H ELMD TT LOGGED 12/26/93 I . I 10428' I_17"X 4-1/2"TM/SS HORIZ PKR, ID=4.00" I 122 LNR,26#, NT-80 NSCC, .0371 bpf, ID=6.184" -{ 10563' I--4 .. PERFORATION SUMMARY REF LOG: MCNL/GR/CCL ON 09/15/01 `\ .. `\ \ ANGLE AT TOP PERF:93 @ 10965' .. Note:Refer to Production DB for historical perf data . �.\ SIZE SPF INTERVAL Opn/Sqz DATE . 1.56" 4 10965- 11560 0 09/15/01 5-. 1.56" 4 11770- 12010 0 09/15/01 \... %. PBTD 12553' 1.56" 4 12200- 12470 0 09/15/01 . 4-1/2" SLID 10591 - 11461 SLOT 09/03/93 [4-1/2"SLID LNR, 12.24#, L-80 NSCT, .0150 bpf, ID=3.933" 11485' V. '� 2-3/8"LNR,4.43#, L-80,STL, .0038 bpf, ID=1.99" --I 12590' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/03/93 ORIGINAL COMPLETION 04/19/10 MSE PROPOSED CTD SIDETRACK WELL: C-37 09/06/93 RWO PERMIT No: 09/16/01 CH/KAK CTD EXTENSION(CMT'D LNR) API No: 50-029-22360-0 08/22/08 RLM/SV PULL LTP SEAL ASSY (07/26/08) SEC 19,T11 N, R14E, 1110'FNL&878'FEL 02/02/10 PJC DRAWING CORRECTIONS 02/02/10 RCT/PJC GLV C/O(01/23/10) BP Exploration (Alaska) l • W_ NaW `hin 4= a m w H z t 0 0. a) w a 0) m •a a ca u) a Q J w w QI Z 1-- co o Cl) 0) L ti m a) z Qt ca �` m r M 01 L ° oar ..0 mt cn a - 0 13 O ti c c CD c°1 tica co co 4 a CO 01 0 , III " co n o o 0 0 0 o co 0 0 0 0 L N I 0 0 O co O 0 o O O O .- 0 0 0 O a \,o_ E 0 L 00 a0 LU N O) (D 0 0 0 a m '/'a �o W U U LL v F+ CU 0 f' O C C co Z N O O a) a0 n M R CO LD n 0 U) Is- n CO O V CO n CO 0 CO n CO N- to (O 0) a a Co Ln LU N O N O (O O a0 O 0 co N- O O N co LO LO co a) a0 7 O /��/�� 0 N N N N N N CO CO CO V @ © N y M M M M M M co- M co- co. 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ON3Se+ a` a 8 Illihbk ■ = i 0 IIl4; , ,` . z, $ A e� o - 0 �+f M en to �+f rf M rn e� M N N N N N N N N N P b (1111:1 06)(+)quoN/(-)q;nos (6u 6uplip oueue6)8OLL9 0 0000£661/9/S LE:S4 r u BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB C Pad C-37 Plan 3, C-37B Plan 3 Travelling Cylinder Report 13 July, 2010 0 bp re.it II BPPASSPORT • BAKER by Travelling Cylinder Report 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well C-37-Slot 37 Project: Prudhoe Bay TVD Reference: 45:37 5/8/1993 00:00 @ 67.70ft(generic drilling rig) Reference Site: PB C Pad MD Reference: 45:37 5/8/1993 00:00 @ 67.70ft(generic drilling rig) Site Error: 0.00ft North Reference: True Reference Well: C-37 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan 3, C-37B Database: EDM.16-Anc Prod-WH24P Reference Design: Plan 3 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB C Pad C-03-C-03-C-03 9,610.00 9,800.00 456.86 234.54 246.03 Pass-Major Risk C-03-C-03A-C-03A 9,610.00 9,800.00 456.86 234.54 246.03 Pass-Major Risk C-03-C-03B-C-03B 9,616.42 9,950.00 251.61 222.29 30.88 Pass-Major Risk C-03-C-03B-C-03B wp08.1 Cont Plan 9,623.47 9,825.00 352.30 224.30 171.66 Pass-Major Risk C-04-C-04-C-04 Out of range C-04-C-04A-C-04A 11,425.00 12,380.00 938.45 652.73 287.63 Pass-Major Risk C-04-C-04APB1 -C-04APB1 Out of range C-04-C-04APB2-C-04APB2 Out of range C-04-C-04APB3-C-04APB3 Out of range C-04-C-04B-C-04B Out of range C-04-C-04B-Plan#5 Out of range C-04_DIMS-C-04-C-04 Out of range C-04_DIMS-C-04A-C-04A Out of range C-04_DIMS-C-04B-C-04B Out of range C-13-C-13-C-13 Out of range C-13A-C-13A-C-13A Out of range C-14-C-14-C-14 Out of range C-19-C-19-C-19 11,525.00 10,300.00 1,139.26 1,127.81 403.88 Pass-Major Risk C-19A-C-19A-C-19A 11,525.00 10,300.00 1,139.26 1,127.81 403.88 Pass-Major Risk C-19B-C-19B-C-19B 11,525.00 10,300.02 1,139.25 1,127.81 403.85 Pass-Major Risk C-19BPB1 -C-19BPB1 -C-19BPB1 11,525.00 10,300.02 1,139.25 1,127.81 403.85 Pass-Major Risk C-33-C-33-C-33 Out of range C-33-C-33A-C-33A Out of range C-33-C-33A-Plan#2 Out of range C-33-C-33PB1 -C-33PB1 Out of range C-35_DIMS-C-35-C-35 Out of range C-35_DIMS-C-35A-C-35A Out of range C-35_DIMS-C-35B-C-35B Out of range C-36-C-36-C-36 Out of range C-36A-C-36A-C-36A Out of range C-36APB1 -C-36APB1 -C-36APB1 Out of range C-37-C-37-C-37 9,550.00 9,550.00 0.00 2.25 -0.67 FAIL-Major Risk C-37-C-37A-C-37A 9,550.00 9,550.00 0.00 2.24 -0.74 FAIL-Major Risk C-37-C-37APB1 -C-37APB1 9,550.00 9,550.00 0.00 2.17 -0.67 FAIL-Major Risk C-37-C-37APB2-C-37APB2 9,550.00 9,550.00 0.00 2.17 -0.67 FAIL-Major Risk C-37_DIMS-C-37-C-37 Out of range C-37_DIMS-C-37A-C-37A Out of range C-37_DIMS-C-37APB1 -C-37A PB1 Out of range C-37_DIMS-C-37APB2-C-37A PB2 Out of range C-38-C-38-C-38 Out of range C-42-C-42-C-42 10,275.00 11,103.00 632.70 290.38 342.37 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 7/13/2010 2:34:52PM Page 3 of 24 COMPASS 2003.16 Build 71 C-37B - Coiled Tubing Drillh.j Ali Measurements are from top of Riser 7/232010 a) C-37B top of bag BAG bttm of bag ~tip m'racle of blind'shears Blind/Shears '�• TOTs middle of ppe.slips 2" combi pipeslips I I I middle of flow cross Mud Cross Mud Cross I I _ middle of rams 2 3`8" x 3-1/2" V B Rs TOTs middle of sli s 2" combi pipe/slips ppe' p 1 1 I Swab Valve Flow Tee Alaska Department of Natural P-sources Land Administration System Page 1 off/ Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28305 Printable Case File Summary See Township,Range, Section and Acreage? ® Yes O No New Search LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28305 !twap._. Search for Status Plat Updates As of 07/29/2010 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2480.000 Date Initiated: 05/28/1965 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction:AA-NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 014E Section: 17 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 014E Section: 18 Section Acres: 599 Meridian: U Township: 011N Range: 014E Section: 19 Section Acres: 601 Meridian: U Township: 011N Range: 014E Section: 20 Section Acres: 640 Legal Description 05-28-1965 ***SALE NOTICE LEGAL DESCRIPTION*** C14-12611N 14E UM 17,18,19,20 2480.00 U-3- 7 End of Case Summary Last updated on 07/29/2010. http://dnr.alaska.gov/projects/las/Case Summary.cfm?FileType=ADL&FileNumber=2830... 7/29/2010 To: Alaska Oil &Gas Conservation Commission From: Amanda Rebol b p CTD Engineer Date: July 14, 2010 \ rp Z to—/lX Re: C-37A Sundry Approval S;defr �� S"s�'��`` ''�`� ) I ' Sundry approval is requested for well C-37A. C-37 was originally drilled as a horizontal producer targeting Zone 1A. The well was completed with a slotted liner, but after initial and subsequent attempts, the well could not be brought on production. The 7" intermediate liner was perforated in Z 1 B/Z 1 A and proved to be productive, making the well a vertical Z 1 B/Z 1 a producer. C-37 reached MGOR by 1995,then cycled from 1996-2001 before a coil toe-out extension was planned and completed. This coil sidetrack ran a 2-3/8" liner to cover the 7"perfs,but the liner lap test failed; a liner top packer was run to isolate the new completion and perforations. The sidetrack was a strong producer from 2001-2007, until MGOR was reached and it became a cycler. In July 2008, the liner top packer was pulled to allow logging access. However, service coil was unable to drift to the end of the wellbore, reaching 10,950', which is just above the top set of perforations. Collapsed liner was suspect of causing this failed drift. After the logging attempts were completed, the liner top packer was not re-set; due to the likelihood of collapsed pipe, the intent was to commingle production with the parent vertical adperfs in the 7" liner. Production increased when the well was brought back on,but the well was cycling again within months and has continued to cycle with diminishing on-time and recharge. C-37A underwent well integrity screening in Jan/Feb 2010, passing a MIT-IA (3000psi)but failing a MIT-OA(2000psi) due to an open casing shoe. PPPOT-T and PPPOT-IC both passed. REASON FOR SIDETRACK C-37A will have zero on-time in the future because of high gas rates. Due to the collapsed 2-3/8" liner, there are no wellwork opportunities remaining. A coil sidetrack will effectively target untapped production to the NW of the parent wellbore. The proposed plan for C-37B is to drill a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig on or around September 14, 2010. As part of the pre-rig work, a cast-iron bridge plug will be set in the 3-1/2" tubing, isolating the existing perforations. The tubing will then be punched, with a cement retainer set above the punch; the IA will then be cemented off. A monobore whipstock will be set above the retainer in the 3-1/2" tubing. The C-37B sidetrack will exit the 3-1/2" tubing and 7" liner and kick off in Zone 2, landing in Zone 1 A and drilling laterally above the HOT/BSAD. The well will be completed with a cemented and perforated 2-38"liner. A schematic diagram of the proposed sidetrack is attached for reference. TRANSMITTAL LETTER CHECKLIST WELL NAME /-$!/ PTD# ,=?/0400 /Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: 0�c4.'4•y0E'f�' 9/ POOL: , '4,+ ' 31/©/G 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), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that 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 first caught and 10' sample intervals through target 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 well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 N a°) a u) !n a) 5 `o m T) c Q c 0 m 0 1 1 > L w O Q -? 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O O O C ; p CO 6 CO N U O N co O to p `y N 0) C n r N N ww. O E•N N rn U E N o I E a. U Q 0) C• O J O a U P- Q Q w a Q Q Well History File APPENRIX Information of detailed nature that is not . particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. tapescan.txt **** REEL HEADER **** MWD 11/05/16 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 10/09/09 3317848 01 2.375" CTK *** LIS COMMENT RECORD *** 111111 III ! 111111 III Remark File Version 1.000 1111111111111111111 Extract File: ldwg.las -Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 9024.5000: Starting Depth STOP.FT 11625.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska) , Inc. WELL. WELL: C-37B FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 70 deg 17' 50.401"N 148 deg 40' 4.275"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 09 Sep 2010 API . API NUMBER: 500292236002 -Parameter Information Block #MNEM.UNIT Value Description SECT. 19 Section TOWN.N T11N Township RANG. R14E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . KB Log Measured from FAPD.F 67.70 Feet Above Perm. Datum DMF . KB Drilling Measured From EKB .F 67.70 Elevation of Kelly Bushing EDF .F 0 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 1 14 C41 4° (a6 tapescan.txt CASE.F N/A Casing Depth 051 . DIRECTIONAL Other Services Line 1 -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TvDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well . (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance sub (Inner and Outer Downhole Pressure, vibration and Downhole weight on Bit) , a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth shifted to a Primary Depth Control (PDC) log provided by Schlumberger GR CNL dated 10 sep 2010 per Jennifer Flight with BP Exploration (Alaska) , Inc. (8) The sidetrack was drilled from C-37 through a milled window in a 7 inch liner and 3 1/2 inch tubing. Top of window 9557 ft.MD (8748.4 ft.TvDSS) Bottom of window 9562 ft.MD (8751.6 ft.TvDSS) (9) Tied to C-37 at 9530 feet MD (8748.4 feet TvDSS) . (10) The interval from 11602 ft to 11625 ft MD (8925.1 ft. to 8924.7 ft. TVDSS) was not logged dine to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP AVG -> Rate of Penetration, feet/hour TVDSS -> True vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 9027.12, 9028.76, ! 1.64258 9033.89, 9035.33, ! 1.43652 9039.84, 9041.9, ! 2.05273 9047.44, 9047.85, ! 0.410156 9058.61, 9058.2, ! -0.410156 9064. 57, 9064.36, ! -0.206055 9067.23, 9067.23, ! 0 9070. 52, 9070.31, ! -0.205078 9074.42, 9074.21, ! -0.205078 9078.32, 9077.91, ! -0.411133 9080. 58, 9080.99, ! 0.410156 9085.09, 9084.27, ! -0.820312 9086.12, 9085.91, ! -0.205078 9087.55, 9087.14, ! -0.411133 9090.22, 9089.81, ! -0.410156 9092.69, 9092.07, ! -0.615234 9096.38, 9095.56, ! -0.820312 9100.9, 9100.08, ! -0.820312 9108.47, 9107.44, ! -1.02637 9116.06, 9114.42, ! -1.64258 9120.58, 9119.75, ! -0.821289 9122.63, 9121.81, ! -0.820312 9125.71, 9125.5, ! -0.205078 9128.79, 9128.17, ! -0.616211 9135.76, 9134.33, ! -1.43652 9143. 56, 9142.54, ! -1.02637 9146.64, 9145.82, ! -0.820312 9153.01, 9153.21, ! 0.205078 9549.92, 9548.89, ! -1.02637 9562.03, 9562.85, . 0.820312 Page 2 tapescan.txt 9563.26, 9564.49, ! 1.23145 9570.24, 9571.06, ! 0.821289 9573.93, 9575.17, ! 1.23145 9582.14, 9582.55, ! 0.411133 9584.2, 9584.81, ! 0.616211 9595.69, 9596.92, ! 1.23145 9602.03, 9603.47, ! 1.43652 9611.47, 9613. 52, ! 2.05273 9617.22, 9619.48, ! 2.25781 9626.04, 9627.28, ! 1.23145 9645.46, 9646.28, ! 0.821289 9652.23, 9653.47, ! 1.23145 9665.58, 9667.22, ! 1.6416 9673.99, 9674.61, ! 0.615234 9677.07, 9677.69, ! 0.615234 9679.94, 9681.38, ! 1.43652 9683.02, 9683.64, ! 0.615234 9684.66, 9686.1, ! 1.4375 9687.74, 9688.77, ! 1.02637 9689.8, 9691.03, ! 1.23145 9695.34, 9696.77, ! 1.43652 9703.32, 9704.75, ! 1.43652 9706.6, 9707.63, ! 1.02637 9709.07, 9709.48, ! 0.410156 9717.07, 9717.89, ! 0.820312 9725.28, 9726.31, ! 1.02637 9727.95, 9728.97, ! 1.02637 9734.34, 9734. 55, ! 0.206055 9736.81, 9738.24, ! 1.43652 9744.2, 9745.84, ! 1.64258 9757.37, 9757.78, ! 0.411133 9760.21, 9760.41, ! 0.205078 9762.7, 9763. 52, ! 0.821289 9770.09, 9771.32, ! 1.23242 9775.84, 9777.07, ! 1.23145 9779.12, 9780.56, ! 1.4375 9781.79, 9784.25, ! 2.46289 9786.51, 9787.33, ! 0.821289 9789.8, 9790.62, ! 0.820312 9797.39, 9799.03, ! 1.64258 9802.11, 9802.93, ! 0.820312 9804.43, 9805.26, ! 0.821289 9809.98, 9811, ! 1.02637 9817.98, 9818.8, ! 0.821289 9830.91, 9831.94, ! 1.02637 9841.38, 9842, ! 0.616211 9846.51, 9845.69, ! -0.821289 9850.21, 9848.97, ! -1.23145 9853.08, 9853.08, ! 0 9862.44, 9862.23, ! -0.205078 9867. 57, 9868.19, ! 0.615234 9871.97, 9873.41, ! 1.43652 9874.23, 9876.28, ! 2.05273 9881.21, 9881.21, ! 0 9884.9, 9886.34, ! 1.43652 9892.91, 9893.73, ! 0.821289 9898.13, 9900.8, ! 2.66895 9900.59, 9903.26, ! 2.66895 9912.09, 9914.14, ! 2.05273 9918.86, 9919.48, ! 0.616211 9928.51, 9929.74, ! 1.23145 9935.08, 9935.69, ! 0.615234 9935.9, 9936.31, ! 0.411133 Page 3 tapescan.txt 9937.74, 9938.15, ! 0.410156 9940, 9940.21, ! 0.205078 9942.67, 9944.72, ! 2.05273 9946.19, 9946.81, ! 0.616211 9953.99, 9954.81, ! 0.821289 9960.56, 9961.38, ! 0.820312 9977.63, 9977.63, ! 0 9982. 55, 9982.14, ! -0.411133 9988.1, 9988.71, ! 0.616211 9996.31, 9997.33, ! 1.02637 10000.9, 10001.3, ! 0.411133 10009.1, 10009.1, ! 0 10014.9, 10016.1, ! 1.23242 10023.9, 10023.7, ! -0.205078 10028, 10028.4, ! 0.410156 10037, 10036.6, ! -0.411133 10040.2, 10040, ! -0.205078 10057.4, 10057.6, ! 0.205078 10092.7, 10093.1, ! 0.411133 10135.9, 10134.3, ! -1.6416 10153, 10154.4, ! 1.43652 10159.9, 10159.9, ! 0 10163.4, 10163.4, ! 0 10166.5, 10168.2, ! 1.6416 10172.3, 10173.5, ! 1.23145 10174.3, 10176.2, ! 1.84668 10182.3, 10183.8, ! 1.4375 10187.9, 10189.9, ! 2.05273 10192.8, 10194.5, ! 1.6416 10205.2, 10205.4, ! 0.205078 10218.4, 10218.2, ! -0.205078 10223.9, 10224.7, ! 0.821289 10228, 10228.8, ! 0.821289 10230.7, 10231.3, ! 0.616211 10235.8, 10236.7, ! 0.820312 10238.7, 10239.1, ! 0.410156 10242, 10243, ! 1.02637 10245.3, 10246.5, ! 1.23145 10250.8, 10253.1, ! 2.25781 10275.6, 10277.9, ! 2.25781 10281.8, 10283.2, ! 1.43652 10291.3, 10291.5, ! 0.205078 10293.9, 10294.5, ! 0.616211 10302.1, 10301.5, ! -0.615234 10303.8, 10303.8, ! 0 10314.7, 10312, ! -2.66797 10341.9, 10338.6, ! -3.28418 10356.3, 10354.1, ! -2.25781 10369.5, 10367.9, ! -1.64258 10378.5, 10375.6, ! -2.87402 10384.5, 10382.2, ! -2.25781 10392.9, 10391.1, ! -1.84668 10403.4, 10401.7, ! -1.6416 10406.6, 10407.7, ! 1.02637 10408.7, 10409.5, ! 0.821289 10421.6, 10420.8, ! -0.820312 10434.5, 10431.9, ! -2.66895 10438.4, 10435.8, ! -2.66797 10442.1, 10439.3, ! -2.87305 10442.8, 10440.9, ! -1.84766 10447.5, 10445, ! -2.46289 10453, 10451.2, ! -1.84766 10461.2, 10457.5, ! -3.69434 Page 4 tapescan.txt 10468.8, 10464. 5, ! -4.31055 10470.6, 10468, ! -2.66797 10473.7, 10471.7, ! -2.05273 10476.6, 10473.3, ! -3.2832 10482.8, 10481. 5, ! -1.23145 10489.1, 10487.1, ! -2.05176 10497.3, 10495.9, ! -1.4375 10502.8, 10501, ! -1.84668 10513.3, 10511.1, ! -2.25781 10519.2, 10516.9, ! -2.25781 10524.4, 10522.6, ! -1.84668 10534.3, 10531.2, ! -3.0791 10540.4, 10536.3, ! -4.10449 10542.5, 10539, ! -3.48926 10548.4, 10546.5, ! -1.84668 10551.5, 10549.8, ! -1.64258 10553.9, 10553.1, ! -0.821289 10558.4, 10557.4, ! -1.02637 10574.8, 10572.9, ! -1.84766 10586, 10582.6, ! -3.48926 10596.7, 10593.6, ! -3.0791 10604.9, 10604.1, ! -0.821289 10608.2, 10609.2, ! 1.02637 10625.6, 10626.8, ! 1.23242 10633.4, 10634, ! 0.616211 10634.8, 10635.5, ! 0.615234 10642, 10643.5, ! 1.43652 10644.5, 10645.9, ! 1.43652 10651.5, 10651.3, ! -0.205078 10654.3, 10654.3, ! 0 10667.5, 10669.2, ! 1.6416 10680.1, 10681.7, ! 1.64258 10688.5, 10688.1, ! -0.411133 10693.8, 10693.8, ! 0 10696.5, 10697.1, ! 0.615234 10715, 10716.4, ! 1.43652 10719.3, 10720.3, ! 1.02637 10724.6, 10726.1, ! 1.4375 10747, 10750.3, ! 3.28418 10762.4, 10764.2, ! 1.84766 10765.5, 10767.1, ! 1.64258 10789.2, 10788.4, ! -0.821289 10813.1, 10809.4, ! -3.69531 10818.8, 10812.6, ! -6.1582 10821.9, 10817, ! -4.92578 10829.1, 10825.8, ! -3.28418 10834.4, 10830.9, ! -3.48926 10842.8, 10841.1, ! -1.64258 10853.3, 10851.1, ! -2.25781 10862.8, 10858. 5, ! -4.31055 10887.7, 10882.7, ! -4.92578 10894, 10888.9, ! -5.13184 10902.8, 10896.7, ! -6.1582 10905.1, 10899.2, ! -5.95312 10910.4, 10903.3, ! -7.18359 10916.4, 10909.2, ! -7.18359 10920.7, 10912.3, ! -8.41504 10923.6, 10916, ! -7.59473 10928.5, 10919.2, ! -9.23633 10942.9, 10939.4, ! -3.48926 10944.8, 10941.3, ! -3.48926 10970.6, 10968.6, ! -2.05176 10977.2, 10974.7, ! -2.46289 Page 5 tapescan.txt 10980.5, 10977.6, ! -2.87402 10987, 10984.6, ! -2.46289 11001.2, 10999.4, ! -1.84766 11036.5, 11032.2, ! -4.31055 11045.8, 11041.4, ! -4.31055 11049, 11045.1, ! -3.90039 11070.4, 11068, ! -2.46289 11075.8, 11073.7, ! -2.05273 11115.1, 11113.8, ! -1.23145 11118.2, 11117.8, ! -0.410156 11140.5, 11138.3, ! -2.25781 11144.6, 11142.6, ! -2.05176 11149.6, 11146.7, ! -2.87402 11162.1, 11160.2, ! -1.84766 11164.1, 11162.1, ! -2.05176 11175.5, 11172.5, ! -3.0791 11205.3, 11205.5, ! 0.206055 11208.6, 11208, ! -0.615234 11214, 11215, ! 1.02637 11219.1, 11219.5, ! 0.411133 11221.8, 11222.2, ! 0.410156 11225.9, 11226.9, ! 1.02637 11258.4, 11260.1, ! 1.64258 11269.2, 11268.4, ! -0.821289 11273.5, 11273.5, ! 0 11286.8, 11284.8, ! -2.05273 11293.4, 11290.9, ! -2.46289 11298.5, 11296.8, ! -1.64258 11303.9, 11303.9, ! 0 11352.4, 11352, ! -0.410156 11360.2, 11360.6, ! 0.410156 11398.6, 11401.9, ! 3.2832 11402.1, 11406, ! 3.89941 11429.8, 11432.1, ! 2.25781 11442.5, 11445.6, ! 3.07812 11450.5, 11453.4, ! 2.87305 11488.7, 11490.6, ! 1.84668 11507, 11508.2, ! 1.23145 11516, 11515.2, ! -0.821289 11519.5, 11519.3, ! -0.205078 11530.2, 11531.6, ! 1.43652 11545.8, 11547.4, ! 1.6416 11554.4, 11554.4, ! 0 11558.3, 11558.3, ! 0 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 333 records. . . Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 Page 6 tapescan.txt *** LIS COMMENT RECORD *** III ! ! III II IIII1111 Remark File version 1.000 The data presented here is final and has been depth shifted to a Primary Depth Control (PDC) log provided by Schlumberger GR CNL dated 10 Sep 2010 per Jennifer Flight with BP Exploration (Alaska) , Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0. 500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 62 Tape File Start Depth = 9024.500000 Tape File End Depth = 11625.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 71 records. . . Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 Page 7 • tapescan.txt *** LIS COMMENT RECORD *** 111111 IIII11111 ! III Remark File version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 124 Tape File Start Depth = 9022.750000 Tape File End Depth = 11625.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 3 133 records. . . Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 10/09/09 3317848 01 **** REEL TRAILER **** Page 8 tapescan.txt MWD 11/05/16 BHI 01 Tape Subfile: 4 2 records. . . Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LIS U Tape Subfile 2 is type: LIS DEPTH GR ROP 9024.5000 -999.2500 -999.2500 9025.0000 -999.2500 -999.2500 11625.0000 -999.2500 17.2000 Tape File Start Depth = 9024.500000 Tape File End Depth = 11625.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP 9022.7500 -999.2500 -999.2500 9023.0000 -999.2500 -999.2500 11625.0000 -999.2500 17.2000 Tape File Start Depth = 9022.750000 Tape File End Depth = 11625.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet 0 Tape Subfile 4 is type: LIS Page 9
