The URL can be used to link to this page

Home My WebLink About202-0327. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 11-17A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-032 50-029-21598-01-00 10740 Conductor Surface Intermediate Production Liner 9115 80 2475 9998 889 10148 20" 13-3/8" 9-5/8" 4-1/2" 8588 28 - 108 27 - 2502 25 - 10023 9848 - 10737 28 - 108 27 - 2501 25 - 8481 8336 - 9112 10259, 10642 470 1950 4760 7500 10148, 10153, 10274, 10380 1490 3450 6870 8430 10106 - 10633 4-1/2" 12.6# 13Cr80 23 - 9870 8551 - 9016 Structural 4-1/2" BAKER S3 Packer 9812 8308 Bo York Operations Manager David Bjork david.bjork@hilcorp.com 907.564.4672 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028325, 0028328 23 - 8355 N/A N/A 293 553 31858 69465 3684 14 1577 1155 800 935 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 9812, 8308 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:41 pm, Jun 04, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.06.04 12:32:54 - 08'00' Bo York (1248) DSR-6/18/25JJL 6/13/25 ACTIVITYDATE SUMMARY 5/13/2025 ***WELL SHUT IN ON ARRIVAL*** ( PLUG SET ZONE ) MIRU YELLOWJACKET E-LINE. PT PCE 300 PSI LOW./3000 PSI HIGH, FUNCTION TEST WIRELINE VALVES DRIFT JUNK BASKET GAUGE RING, 3.600" TAG PKR @ 10180' CORRELATED TO YJOS MULTI SENSOR CALIPER LOG DATED 03-JUNE-2024 SET THE CIBP AT 10153' CCL TO MID ELEMENT=12.7' CCL STOP DEPTH=10140.3' TAG AFTER SET THUNERBIRD TESTED PLUG TO 750PSI, PLUG DID NOT HOLD. CALLED TO TOWN, DECISION TO RIG DOWN WAS MADE RDMO YELLOWJACKET E-LINE ***WELLÂ S/I ON DEPARTURE *** JOB INCOMPLETE 5/13/2025 TFS U4, (Assist E-line) W/Load well, Initial WHP T/IA/OA= 2400/1600/0, pumped 155 bbls crude down TBG to load and secure well, pumped an additional 23 bbls crude to help pump down plug for E-line, job postponed due to plug seating issue, Final WHP T/IA/OA= 250/2000/0 ***Well left in YJ E-line control*** 5/28/2025 ***WELL S/I ON ARRIVAL*** SET 3.79" WHIDON CATCHER @ 9857' MD PULLED 1.5" SOV & SET 1.5" DLGV w/RK LATCH @ STA #6 @6093' MD PULLED 1.5" GLV & SET 1.5" DGLV w/ RK LATCH @ STA #7 @4133' MD ATTEMTED TO PT TBG TO 2400 PSI ( FAIL ) CONTINUE ON 5-29-25 5/28/2025 T/I/O=1600/2075/0 Assist S-line Pumped a total of 54.6 BBLS Crude to Test the Plug for Slickline. Attempted to Reach 2400 psi, and get a good Test on the Plug. Pumped 30 BBLS Crude for the first test at 0.5 BPM reached MAP of 2400 psi on the Tubing. After 15 min TBG lost 400 psi. After 45 mins Fluid Still at Surface on the TBG. 2nd Test Pumped 16 BBLS Crude to Reach MAP of 2400 psi at 1 BPM. After 20 Minutes the TBG lost 585 psi. Pumped 8.6 BBLS Crude at 1.5 BPM to Reach 2400 psi. Establishing a LLR of 15 Gallons per Minute. No Change IA or OA and Flowline During these Tests. ***JOB CONTINUES to 05-29-2025*** 5/29/2025 ***JOB CONTINUES from 05-28-2025*** Ran a 30 minute plug test, The Tubing lost a total of 700 psi in 30 mins. 1st 15 min TBG lost 350 psi. 2nd 15 min TBG lost 350 psi. After Slickline pulled the Catcher performed another pressure test on the TBG. Pumped 15.2 BBLS Crude to Reach a Map of 2400 psi. After 15 Min the TBG lost 325 psi. Slickline Set a Standing valve, Pumped 6.7 BBLS Crude to reach a Map of 2400 psi. 1st 15 min TBG lost 40 psi. 2nd 15 min TBG lost 15 psi. Total loss of 55 psi in 30 min test. Bled back to starting pressure. Bled back 6 bbls. Pollard SL in control of well upon TFS departure FWHPS = 1600/2050/0 5/29/2025 ***CONTINUE FROM 5-28-25*** PULLED 3.79" CATCHER SUB @ 9853' SLM SET 3.80" XN-CAT STANDING VLV @ 9857 MD PT TBG TO 2400PSI FOR 30 MIN ( PASSED ) PULLED 3.80" XN-CAT STANDING VLV @ 9857 MD ***WELL S/I ON DEPARTURE*** JOB COMPLETE Daily Report of Well Operations PBU 11-17A Daily Report of Well Operations PBU 11-17A 5/30/2025 *** WELL S/I ON ARRIVAL*** ( PLUG SET / ADPERF ) MIRU YELLOWJACKET E-LINE. PT PCE 300 PSI LOW./3000 PSI HIGH, FUNCTION TEST WIRELINE VALVES CORRELATED TO YJOS MULTI SENSOR CALIPER LOG DATED 03-JUNE-2024 SET YJOS 3.5" CIBP AT 10148' CCL-ME=11.8', CCL STOP DEPTH=10136.2'. TAG AFTER SET PERFORATE 10106' - 10137' WITH 3.375" 6SPF 60PHASE HSC W/GEODYNAMICS BASIX CHARGES (.45"EHD, 46.32"TTP) CCL TO TOP SHOT = 8.5' CCL STOP DEPTH = 10097.5. CONFIRM SHOTS FIRED RDMO YELLOWJACKET E-LINE ***WELL S/I ON DEPARTURE*** JOB COMPLETE 5/30/2025 T/I/O = SSV/1650/VAC. Temp = SI. Bleed IAP to 1000 psi (Assist Ops w/ POP). No IA companion valve, open @ LV (buried under snow), Double blocked in manifold. IA FL @ 960'. Bleed IAP to production to 1030 psi in 3 hrs (gas). Ops BOL @ 22:30. Monitored WHP's for 5.5 hrs. IAP increased 120 psi & IA FL unchanged. OAP unchanged. Released from man watch. Final WHPs = 980/1150/VAC. SV = C. WV, SSV, MV = O. IA, OA = OTG. 05:00 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 11-17A Patch Perforations Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 202-032 50-029-21598-01-00 10740 Conductor Surface Intermediate Production Liner 9115 80 2475 9998 889 10274 20" 13-3/8" 9-5/8" 4-1/2" 8700 28 - 108 27 - 2502 25 - 10023 9848 - 10737 28 - 108 27 - 2501 25 - 8481 8336 - 9112 10259 , 10642 470 1950 4760 7500 10274 , 10380 1490 3450 6870 8430 10185 - 10633 4-1/2" 12.6# 13Cr80 23 - 9870 8621 - 9016 Structural 4-1/2" BAKER S- 3 PERM 8308 9812 8308 Bo York Operations Manager David.Wages@hilcorp.com (907) 564-5006 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028328 23 - 8355 326 176 37769 16931 3293 6390 1546 1966 812 341 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV 9812 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations / Dave Wages Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.07.16 15:18:11 - 08'00' Bo York (1248) By Grace Christianson at 9:12 am, Jul 17, 2024 RBDMS JSB 071924 DSR-7/17/24WCB 9-30-2024 ACTIVITYDATE SUMMARY 5/28/2024 ***WELL S/I ON ARRIVAL*** RIH W/ 30' X 3.68" PATCH PACKER DRIFT ***CONTINUE 5/29/24*** 5/29/2024 ***CONTINUE FROM 5/28/24*** RAN 30' X 3.68" PATCH PACKER DRIFT S/D @ 10,275' SLM (NO OBSTRUCTIONS) ***WELL LEFT S/I*** 6/3/2024 ***WELL FLOWING ON ARRIVAL*** (24 ARM CALIPER LOG TO USE CALIPER TO IDENTIFY PATCH SET DEPTH) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH, FUNCTION TEST WLVS WHILE LOG REPEAT PASS TOOL HANG UP AT 10180' CLOSE CALIPER AND GET FREE , BACK DOWN AND TOOL TAG AGAIN AT 10267' MD REOCORD UP MAIN PASS FROM 102767' TO SURFACE,TENSION SPIKE AGAIN AT 10180' WHILE LOGGING MAIN PASS LOG CORRELATED TO SLB PERFORATION RECORD DATED 22JAN16 CALIPER LOG COMPLETE, LAID DOWN LUBRICATOR FOR TONIGHT. ***JOB CONTINUE ON 6/4/2023*** 6/4/2024 ***JOB CONTINUE FROM 6/3/2023*** SET LOWER PACKER PT PCE 300 PSI LOW /3000 PSI HIGH CORRELATE GR/CCL TO YJT CALIPER DATED 03-JUN-24 SET NS 450-368 LOWER PACKER ASSEMBLY WITH ME @ 10243' CCL TO MID ELEMENT 45.5' CCL STOP DEPTH 10197.5' TOP OF PACKER AT 10209', BOTTOM OF PACKER AT 10247' RDMO YJT E-LINE *** WELL SI ON DEPARTURE, PACKER SET, READY FOR SL*** 6/21/2024 ***WELL S/I ON ARRIVAL*** (Patch tubing/ liner) SET NS 450 MONO-PAK STRADDLE PATCH (29.81' lih, 2.88" id) IN LOWER ANCHOR @ 10,209' MD. TOP OF PATCH @ 10,180' MD, ME = 10,182' MD. ****WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** Daily Report of Well Operations PBU 11-17A (g) SET NS 450 MONO-PAK STRADDLE PATCH (29.81' lih, 2.88" id) IN LOWER( ANCHOR @ 10,209' MD. TOP OF PATCH @ 10,180' MD, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ECL',,' .- . 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program Ali Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: SET CIBP 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number. 202-032 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stmtigmphic ❑ Service ❑ 1 6. API Number: 50-029-21598-01-00 7. Property Designation (Lease Number): ADL 028325 & 028328 8. Well Name and Number: PBU 11-17A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071). 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 10740 feet Plugs measured 10215, 10274, 10380 feet true vertical 9115 feet Junk measured 10642 feet Effective Depth. measured 10215 feet Packer measured 9812 feet true vertical 8648 feet Packer true vertical 8308 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 28-108 28-108 1490 470 Surface 2475 13-3/8" 27-2502 27-2501 3450 / 5380 1950/2670 Intermediate 9998 9-5/8" 25-10023 25-8481 6870 4760 Production Liner 889 4-1/2" 9848-10737 8335-9112 8430 7500 Perforation Depth: Measured depth: 10185 -10633 feet True vertical depth: 8621-9016 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr8O 23-9870 23-8354 Packers and SSSV (type, measured and 4-112" BAKER S-3 PERM PACKER 9812 8308 true vertical depth) No SSSV Installed 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-Mcr Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 569 45296 609 2016 864 Subsequent to operation: 939 53113 38 2019 847 14. Attachments: (required per 20MC25.07025071,&25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Straligraphic ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sun dry Number or N/A if C.O. Exempt: WA NIA Authorized Name: Alatalo, Travis Contact Name: Alatalo, Travis Authorized Title: Production Engineer Contact Email: Travis.AlataloAbp.com Authorized Signature:/TTR C-l/'t.�� Date: r ! Contact Phone: +1 9075645351 Form 10404 Revised 04/2017 •i Submit Original Only Daily Report of Well Operations PBU 11-17A ACTIVITYnATF SUMMARY 11/8/2018 ***WELL FLOWING UPON ARRIVAL*** (profile modification) DRIFTED W/ 3.70" WRP DRIFT, 2 1/2" SAMPLE BAILER TO HARD TD @ 10,259' SLM (bailer empty) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS` ***WELL FLOWING ON ARRIVAL*** (SLB E -LINE CIBP SETTING) SHUT IN WELL. INITIAL T/I/O (SHUT IN) = 2300/100/0 RIG UP 12/4/2018 ***JOB CONTINUED 5 -DEC -2018*** ***JOB CONTINUED FROM 4 -DEC -2018*** RIG UP, PT LUBRICATOR TO 3500 PSI RUN 1: RIH W/ BKR 10/ WFT 4-1/2" CIBP. MAX OD = 3.50" SET WFT 4-1/2" CIBP AT 10216', TOP OF PLUG @ 10215', CCL TO MID -ELEMENT = 7', CCL STOP DEPTH = 10209' LOG TIED INTO SLB "GR / CCL - 2.875 POWERJET OMEGA & 4.5" PLUG" DATED 17 -APR - 2015. FINAL T/I/O = 2300/1000/0 12/5/2018 ***JOB COMPLETE, POP PRIOR TO DEPARTURE*** TRff= 6"FMC VVBIHEAD= FM: GEN4 ACTUATOR= AXE -SON OKB. AEV = 57' BE BBV = 27.4' KOP= 10022' Max Angle = 44@7997' Datum M)= 2-71W Datum TVD= 8800 SS i BTRS, 12.415' Minimum ID = 3.725" @ 9857' HES XN NIPPLE TBG, 12.69,13CR-80, .0152 bpf, D = 3.958' PERFORATION St&WRY REF LOG: FMuD DENNED ON 07/31/02 ANGLEATTOPPBW: 26° @ 10185' Note: Refer to Production OB fm hstoncal pert data SIZE SPF IN03RVAL OpnlSgz SHOT SOZ 2' 6 10185-10195 O 0122/16 7 4133 2-71W 6 10228 - 10241 C 04/18/15 6 6093 2-7/8" 6 10247 - 10257 C 06/21/14 5 6751 2-718' 6 10261 - 10267 C 06/21/14 4 7409 2-7/8" 6 10284 - 10294 S 10/07102 08/13105 2-7/8' 6 10295- 10300 S 09/02/02 08/13105 3-318' 6 10300- 10306 C 10/25/05 1 9721 2-7/8" 6 10396 - 10400 C 0822102 2-7/8' 6 10446-10458 C 0822/02 2" 6 10623 - 10633 c 08/31/05 TOPOF WHFSTOCK 10022' 1 9-58" CSG. 47#. L-80 NSCdBTC. D= 8.661' I 11-17A SAFfEY NOTES:4-12" CHROME TBG. I 22OW I GAS LFr MANDR13-S ST M) I TVD I DEV I TYPE VLV I LATCH I POR! DATE 8 3014 3012 10 W. GM DIM RK 0 08/16105 7 4133 4018 35 M4GM DOW RK 16 08/16/05 6 6093 5503 41 MMGM SO RK 20 0521/14 5 6751 6000 40 MACdd DMY RK 0 08109102 4 7409 6517 36 MMGM DMY RK 0 08/09/02 3 8068 7019 44 WMIGM DMY R( 0 08/09102 2 8768 7521 44 MWM DFM' RK 0 08/09/02 1 9721 8234 37 M4GM DFM R( 0 08/09/02 1 9791' 1 19-5/8' X 4-12' BKR S-3 PIOL D= 3.875' 1 9857' H4-12' FPS XN NP, D = 3.725' 9848' 9-5/8" X 4-12' BKR ZXP PKR w nlEBACK SLV, D = 6.280' 9870' 4-112- VILPG. D=3.958' 9868' ELM) Tr LOGG® (0822/02) MLLOUr WPDOW (11-17A) 10023' - 10039' I 10274' I 10655' PRIDHOE BAY UW WELL: 11-17A PERMT$b: 2020320 APINo: 50-029-21598-01 SBC 34, T11N, 1115E� 769' FFL 8 665' FVVL DATE REV BY COMJ134rS DATE REV BY OOM 13frS I OW121W ORIGINAL COMPLETION 0421115 LAC/JM) SETCBP/ADPBiFS(4/17-18/15) 08109102 DAVM RIGSIDErRACK(11-17A) 0125116 DHS/JM) ADPEWS(01123116) 11/17/10 CSFVRIC GLV CORRECTOPB 12/13118 KFMJM) SETCBP(12105/18) 0522114 JLS/JM) GLV C/O (0521/14) 0624/14 CS/JAD ADFERFS(0621/14) BP EKploratlon(Alaska) 0624/14 JM) ADDED MLLOUr VMDOW STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 202-032 3. Address: P.O.Box 196612 Anchorage, Development ® Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21598-01-00 7. Property Designation(Lease Number): ADL 0028328 8. Well Name and Number: PBU 11-17A 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 10740 feet Plugs measured 10274/10380 feet true vertical 9115 feet Junk measured 10642 feet FEB 12 2016 Effective Depth: measured 10274 feet Packer measured 9810 feet true vertical 8700 feet Packer true vertical 8306.18 feet AOGCC Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 28-108 28-108 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate Production 9997 9-5/8"47#L-80 25-10021 25-8479 6870 4760 Liner 891 4-1/2"12.6#L-80 9846-10737 8335-9112 8430 7500 Perforation Depth: Measured depth: 10185-10195 feet 10185-10195 feet 10228-10241 feet 10247-10257 feet 10261-10267 feet 10295-10300 10284-10294 feet 10295-10300 feet 10300-10306 feet 10396-10400 feet True vertical depth: 8621-8630 feet 8621-8630 feet 8660-8671 feet 8676-8685 feet 8689-8694 feet 8718-8722 8709-8717 feet 8718-8722 feet 8722-8728 feet 8805-8808 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 23-9868 23-8353 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 783 42908 1471 1513 846 Subsequent to operation: 797 41697 1841 2023 854 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 Q Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I3 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 Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 0/,y,�%�„_ Phone +1 907 564 4424 Date 2/12/16 Form 10-404 Revised`5/2015 , V TL Z!l i/l L Submit Original Only /i •00 RBDMS t.,,-- FEB 1 2 2016 • S m 0.000000 ea 0 Lc) IN. CD O - N O U y 0 0 0 0 0 i 0 M co C) C4) CO M CD CO CO N d) N M CO 0 N • CA to d' A— co N 03 CO 00 CO CO CO Lo cc) Cc) N N CA CV CO N O 0) U, 00 0 c0 N r r 0 O CI < r opco000nNI- Ch cr N N 0 N CON C • co O O O 0 0 t- 1- co M 2r- .N N CD CV . CV co CO o) 00 cO CO = V (NIce) v- C.\,1 r 4 — 4 CO 0 r- 0 N- � C N d0) 0 00) • Z O C� wwv • Zrectouj m O » cZD • • Packers and SSV's Attachment PBU 11-17A SW Name Type MD TVD Depscription 11-17A TBG PACKER 9810.39 8306.18 4-1/2" BAKER S-3 PERM PACKER 11-17A PACKER 9853.56 8341.24 4-1/2" Baker ZXP Packer . • II d -, Ioq b6Lu - \ � Lc6D Lu $ � o / / mCL / G / o & ma C ® ± ' c o S � Q / L � E o , / < < R N c : _J Lu / in / / / � O � co/| 00 / \ 0 / � _1 ƒ $ OF W 0 C o > o « k ƒ ƒ 0Jc � co WI ret@ O LL " 2 ,9; 0 ‹ 0 CC 0 CL / O- � u , 0 OQ / \ 22 \ k � � f0 < 7 � g � $ bk3 / w \ ƒ ƒ r ƒ � 0- r-,: Lii < ƒ G ? E o \ � - 4 > oOc < w t _IG -' lZOiIcO D o � > 0 > \ / >< LI .ce Ce ct 2 I- w o ƒ I / LU q 0_ >4 7RE7k � � ® c) mE2b Oa > 0 5 < / / / R 2 C3 O b .J O 2 p m b O O O 7 0 2 & Lii > I= F. 0b > O00 / Q0WO � ƒ \ O - + Z ® ® ® c2 ƒ \ Z _J \ § U \ / -Jz _1 \ L & _ L - = L < > I0 ƒ R < & 7 / k : / / � / / kgRT- / a w < CO CO \ / - q d q » 2 0 [Nth= 6'RAC • WEILHFAD= FMC CEN4 SAFTEY NOTES:4-1/2"CHROME TBG. ACTUATOR= AXH.SON 11 -17A 0KB.ELEV= 57' BF.E EV= 27.4' KOP= 10022' Max Angie= 44'@ 7997' Datum M)_ I I 2200' —{4 1/2"HES X NP,D=3.813" Datum ND= 880(7 SS GAS LF-i MANDFiB S ST :MTV' DEV TYPE VLV LATCH R)RT DATE 13-318"CSG,72#,L-80,ID=12.347" H 2505' 8 3014 3012 10 MMGM DMY RK 0 08/16/05 7 4133 4018 35 MMGM DOME RK 16 08/16/05 I 6 6093 5503 41 MMGM SO RK 20 05/21/14 LI 5 6751 6000 40 MMGM DMY RK 0 08/09/02 4 7409 6517 36 fi/1101GM DMY RK 0 08/09/02 Minimum ID =3.725" @ 9857' 3 8068 7019 44 MMGM DMY RK 0 08/09/02 HES XN NIPPLE 2 8768 7521 44 MMGM DMY RK 0 08/09/02 1 9721 8234 37 MMGM DMY RK 0 08/09/02 ' I 9791' H4-1/2"IIMXMP,D=3.813' E g 9812' H9-5/8"X 4-1/2'BKR S-3 PKR,D=3.875" ' , 9836' -14-1/2"HES X NP,D=3.813" 9857' —{4-1/2"HES XN NP,D=3.725" 4-1/2"TBG,12.6#,13-CR-80,.0152 bpi,D=3.958" H 9868' Ai �k- 9868' h 4-1/2"WLEG,D=3.958' FE OF2AT10N SUMMARY H9-5/8"X 4-1/2'BKR ZXP PKR,D=6.280" REF LOG: MD DBWM3J ON 07/31/02 9868' H B..M0 TT LOGGED(08/22/02) I ANGLE AT TOP MT: 26"@ 10185' Note:Refer to Production CB for historical perf data SIZE SFT= I4TfftVAL Opn/Sqz SHOT SO2 2" 6 10185-10195 0 01/22/16 MLLOUT VVI'DOW(11-17A) 10023'-10039' 2-7/8" 6 10228-10241 0 04/18/15 2-7/8' 6 10247-10257 0 06/21/14 ` 2-7/8" 6 10261-10267 0 06/21/14 ` 2-7/8" 6 10284-10294 S 10/07/02 08/13/05 2-7/8" 6 10295-10300 S 09/02!02 08/13/05 `` -10274' 1 4_1/2"WFD CUP(04/17/15) 3-3/8" 6 10300-10306 C 10/25/05 2-7/8" 6 10396-10400 C 08/22/02 2-718" 6 10446-10458 C 08/22/02 �� 2" 6 10623-10633 C 08/31/05 41°! — W.' / . ` 10380' -1 BKR CUP(10/26/05) .4. 141 Jr ` JTOP OF WHPST(X:K -� 10022' ��i�i �i�i�i � ` 10642' —OLID FASDRLL PLUG(08/27/05) CEP(02/2/3/02) --I 10125' ` ,;; ;;\��;\� FISH-CA-R-20-RK-06/07/96 -1 10640` `\ \\\\k• PBTD H 10857' P810 —1 10655' vs- /..../....t�� 44 9-5/8"CSG,47#,L-80,0=8.681" H 10871' ..........1 4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.958" —{ 10737' DATE REV BY COMMENTS DATE REV BY C OMVENTS PRIEFDE BAY UNIT 06/12/86 ORIGINAL COMPLETION 04/21/15 LACI.A4) SET CIBP/ADPE S(4/17-18/15) WELL: 11-17A 08/09/02 DAY/KK FIG SIDETRACK(11-17A) 01/25/16 DHS/JMO ADMIRES(01/23/16) PERMIT No: 2020320 11/17/10 CSRPJC GLV CORRECTIONS API No: 50-029-21598-01 05/22/14 JLS/JMD GLV GO(05/21/14) SID 34,T41N,R15E,769'FM_&665'FWL 06/24/14 CS/JMD ADPERFS(06/21/14) 06/24/14 JM) ADDED MLLOUT WINDOW BP Exploration(Alaska) STATE OF ALASKA KA OIL AND GAS CONSERVATION COW JON REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon U Plug Perforations LI' Fracture Stimulate U Pull Tubing U Operations shutdown ❑ Performed Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrdl ❑ Perforate New Pool El Repair Well ❑ Re-enter Susp Well ❑ Other ng p ,__,,,,/ 2 Operator 4 Well Class Before Work 5 Permit to Dnll Number BP Exploration(Alaska),Inc Name Development 0 Exploratory❑ 202-032-0 3 Address P 0 Box 196612 Stratigraphic ❑ Service❑ 6.API Number: Anchorage,AK 99519-6612 50-029-21598-01-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028328 PBU 11-17A :9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 10740 feet Plugs measured See Attachment feeR E D E I V E D true vertical 9114 77 feet Junk measured 10642 feet MAY 19 2015 Effective Depth measured 10274 feet Packer measured See Attachment feet /� true vertical 8699 96 feet true vertical See Attachment feet( -C Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91 5#H-40 28 02-108 02 28 02-108 02 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 9996 64 9-5/8"47#L-80 24 71 -10021 35 24 71-8479 38 6870 4760 Liner 891.4 4-1/2"12 6#L-80 9845 95-10737 35 8335 04-9112 33 8430 7500 Perforation depth Measured depth 10228-10241 feet 10247-10257 feet 10261-10267 feet 10284-10294 feet 10295-10300 feet 10300-10306 feet 10396-10400 feet 10446-10458 feet 10623-_10633 feet True Vertical depth 8659 57-8671 08 feet 8676 37-8685 15 feet 8688 64-8693 88 feet 8708 62-8717 23 feet 8718 09-8722 37 feet 8722 37-8727 5 feet 8804 71 -8808 2 feet 8848.69-8859 31 feet 9007 38-9016 48 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 22 51-9868 05 22 51-8353 06 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 i Intervals treated(measured) SEAMED JUN 2015 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 115 12345 6860 1482 498 Subsequent to operation 778 36167 2964 1520 967 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run ❑ Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations 0 16 Well Status after work Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C O.Exempt N/A Contact Garry Catron Email Garry Catron@BP.Com Printed Name Garry Catron Title PDC PE Signature 1 1 � Phone 564-4424 Date 5/18/2015 VTL 577 5 J i 5-- ,# . , Mer Form 10-404 Revised 10/2012 Submit Onginal Only 11-17A 202-032-0 Plugs Attachement SW Name Date MD Description 11-17A 4/18/2015 10274 4-1/2" WFD CIBP 11-17A 10/26/2005 10380 4-1/2" Baker CIBP LU U 0_ C G L 0 Y Q W 0• 0 V N M d Q-(n X a W• N N Q M CO m N N szt E V co v- .- Q > r N M N M \N M co co '^ N vJ O cn Q rn co L O MM 03 03 RS a CC CC N W W o. • Q Q d d d E < < tar— N- Z Cl) p_O00000 � ocoLC) r,- o LU N- O) CO O v — N N- U ) o o 0 co co co i O) co r- LC) CO CO 7 V - a) d' a) V op C0 co V co co c0 CO O M M N O a0 C O) a0 O M OO N M O) co co I- V _ N O N O • N a) N LO 00 M 4 I• N CO N ( M N CO G) co co N 00 O co O O O a) CO N O) 03 2 QN CO LO CO CO CO CO N CO N N O) N 0) C M 0 F- 9 ano °O Q 0 °o � � ooO _ d *k CO CO N N LO �j V CO CO N• .1•1 O) - CO L U N M ' N O) co CO L a)O O) O • 00 (53 0) 00 ) CD O) N O) J Z D)O 0 •E 1- w w U 0 l LL tL Z Z W O 00 OZCCDDD I IH a w 0 a 0 H in (/) J II 0 -J 0 Q - O to N 6 O Lo 06 I I 0 II 0 aI O (/) c1S c W 2 HH O a. C/) N (0 0 w••' 0 UOZ H i • a) 0yvN E U LL aQ Q (n N O j Z 0 H H O pp Iii 0 o Q J * EE _ - OZ , M = J II N 0 + _ N Z 0 � , to H v d CO W a- Ocs4 '� ON J0 6 O E 0 * Cl- JO = OJO � (n "- a * ma J N - H - LLI t ° > -Lnpc inFeQ ? oN N 12 a 0• < 77 ma4a W r-- CL ct - LL O ?> N En Qa G1 O D H > 00 N- J d Ce Qpm LUXv- Oo0Q uwa >+ O 'LO N._ CO in Z Nf DO J \ O LL _ Z Ln co JOWo (n00HH ( 0 = * O � _ � W W Z tlOH Z I- = 0 0 = 0 .- Q II H - ZZ1Z - Z O > - o _1 Z Z I a H U CI- 2 O JH _ DJZO0 toIj O J J ~ J W W U U Z � I- (O P2 W Q d W' OC m m H O I� J J m N * � = WO � 447OWpWZ � U) * zL (t0 () * * 0Q — LL * 0 In E; O O N N 7 r co C; Q TREE= 6'FMC WELL1fAD= FMC GEN 4 ,AFTEY NOTES:4-1f2"CHROME TBG. ACTUATOR= AXELSON 11 -17 A OKB.ELEV= 57' BF.ELEV= 27.4' KOP=_._ 10022' Max Angle= 44"@ 7997' Datum MD= U I 2200' —4-1/2'HES X NP,D=3.813" Datum TVD= 8800'SS GAS LFT MANDR�S STT MD zvu DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80,ID=12.347" H 2505' 8 3014 3012 10 MMGM MY RK 0 08/16/05 7 4133 4018 35 MMGM DOME RK 16 08/16/05 _ I 6 6093 5503 41 MMGM SO RK 20 05/21/14 Iyl 5 6751 6000 40 MMGM DMY RK 0 08/09/02 4 7409 6517 36 Mv13M DM' RK 0 08/09/02 Minimum ID = 3.725" @ 9857' 3 8068 7019 44 MMGM DMY RK 0 08109/02 HES XN NIPPLE 2 8768 7521 44 MMGM DMY RK 0 08/09/02 1 9721 8234 37 MMGM DMY RK 0 08/09/02 ' I 9791" —4-1/2"HES X NP,K".)=3.813" Z Z--1 9812' H9-5/8"X 4-112"BKR S-3 PKR,D=3.875' ' I 9836' —14-1/2"HES X NP,D=3.813" I I 9857' —j4-112"HES XN NO3,D=3.725" 4-1/2"TBG,12.6#,13-CR-80,.0152 bpf,D=3.958" —{ 9858' --4 9_ 9868' —4-1/2"WLEG,D=3.958" 1432FORATION SUIMMRY Z 9855' --+9-5/8"X 4-1/2"BKR ZXP PKR,D=6.280" REF LOG: MWD DENINEU ON 07/31/02 I 9868' —I ELMO TT LOGGED(08/22/02) 1 ANGLE AT TOP PERF: 27°@ 10228' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2-7/8" 6 1022$- 10241 0 04/18/15 ML LOUT VV'1)OW(11-17A) 10023'-10039' 2-7/8" 6 10247-10257 0 06/21/14 2-7/8" 6 10261-10267 0 06/21/14 2-7/8" 6 10284-10294 S 10/07/02 08/13/05 2-7/8" 6 10295-10300 S 09/02/02 08/13/05 3-3/8" 6 10300- 10306 C 10/25/05 N 10274' 1-1_4-1/2"WFD CBP(04/i7/15) 2-7/8" 6 10396-10400 C 08/22/02 2-7/8" 6 10446-10458 C 08/22/02 / 2" 6 10623-10633 C 08/31/05 �/ - - 1••4 _ rif `vi 10380' HBKRCBP(10/26/05) TOP OF WHPSTOCK —I 1002T 11 • 1 4sb0642' —MILLED FASDRLL PLUG(08Y27/OS) CBP(02/2/3/02) — 10125' lik • • •\` \�\\�\\" FISH-CA-R20-RK-06!07/96 H 10640' �\ \\\ \� ik \\`\\\\. PBTD -1 10857' PBTD �� — 10655' �� • 11111111111111111111 11111111111111111111. 47 — 1.....1...1..E 9-5/8"CSG, #,L 80,D_8.68/" —1 10871' 4-1/2"LNR, 12.6#,L-80,.0152 bpf,D=3.958' --f 10737` DATE REV BY COMMENTS DATE REV BY COMJB'ITS PRIIOHOE BAY WIT 06/12/86 ORIGINAL COMPLETION 04/21/15 LACIJMD SET C)3RADPERFS(4/17-18/15) WELL: 11-17A 08/09/02 DAV/KK RIG SIDETRACK(11-17A) FERMI No: 2020320 11/17/10 CSR/PJC GLV CORRECTIONS AR No: 50-029-21598-01 05/22/14 JLS/JMD GLV CIO(05/21/14) SEC 34,T11N,R15E,769'FNL&665'FML 06/24/14 CS/JMD ADFERFS(06/21/14) 06/24/14 JMD ADDED MLLOUTWINDOW BP Exploration (Alaska) ( Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~O~ - 03'd-.. Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 ~scan Needed 1111111111111111111 OVERSIZED (Scannable) RE?AN \,!l"color Items: 0 Greyscale Items: DIGITAL DATA ~iskettes, No. '.' 0 Other, No/Type: 0 Maps: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: 0 Logs of various kinds: NOTES: Scanning Preparation ~ x 30 = /Po + D D~::7~~~.'~~IIII¡llllllmtJ Date { tJ ~ot 151 ~ P l ~ ,,' T~TAL PAGES bTt.. . (Count d..oes not ¡rlelude cover sh e ¡() Date: I; 0 t~ () if /s/ / r . 1111111111111\ 11111 BY: Helen ~ Project Proofing BY: Helen Maria BY: Helen Maria Production Scanning Stage 1 Page Count from Scanned File: bs (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: . /'" YES, V ,. Helen (Mar~ Date:tD ~. Olf If NO in stage 1, page(s) discrepancies were found: YES NO NO Isl rnP Stage 1 BY: BY: Helen Maria Date: /s/ II II .lll III 1111111111111111111 Date: /5/ Quality Checked 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: 8/24/2004 Well History File Cover Page.doc • bp BP Exploration (Alaska) Inc. e , Attn: Well Integrity Coordinator, PRB -20 . , Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 21, 2010 �� 4 Zt�� Mr. Tom Maunder Alaska Oil and Gas Conservation Commission AN JQii 333 West 7 Avenue Anchorage, Alaska 99501 R:t,, %0 f' '� fAhs, c 7- i sion Subject: Corrosion Inhibitor Treatments of GPB DS 11 a� C7 ,,,_ o " Dear Mr. Maunder, / j f ■4 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 11 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 • • 1 1 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -11 Date: 12/21/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 11 -01A 1921120 50029206440100 NA Sealed NA NA 6/25/2010 11 -02 1811280 50029206490000 NA Sealed NA NA 6/25/2010 11 -03A 1911520 50029206660100 NA Sealed NA NA 6/25/2010 11 -04A 1940230 50029204800100 NA Sealed NA NA 6/25/2010 11 -05A 1961570 50029206700100 NA Sealed NA NA 6/25/2010 11 -06A 2042250 50029206740100 NA Sealed NA NA 6/25/2010 11 -07 1811770 50029206877000 NA Sealed NA NA 6/25/2010 11 -08 1842290 50029212450000 NA Sealed NA NA 6/27/2010 11 -09A 1961280 50029214020100 NA 25 NA 42.50 6/29/2010 11 -10 1851590 50029213940000 NA 5 NA 28.90 6/30/2010 11 -11 1851410 50029213820000 NA Sealed NA NA 6/27/2010 11 -12 1841950 50029212120000 NA Sealed NA NA 9/12/2010 • 11 -13A 1921100 50029212290100 NA Sealed NA NA 9/12/2010 11 -16 1860780 50029215817000 _ NA Sealed NA NA 6/27/2010 11 -17A 2020320 50029215980100 NA Sealed NA NA 6/27/2010 11 - 1861120 50029216070000 NA Sealed NA NA 6/27/2010 11 -22A 1950870 50029220356000 NA 1 NA 9.35 7/1/2010 11 -23A 1940810 50029216100100 NA Sealed NA NA 7/1/2010 11 -24A 1932040 50029216230100 NA Sealed NA NA 6/26/2010 11 -25A 1990820 50029204880200 NA Sealed NA NA 6/26/2010 11 -26 1861340 50029216280000 NA 1.9 NA 5.10 6/28/2010 11 -27 1861480 50029216380000 NA 3.5 NA 11.90 6/28/2010 11 -28A 2000950 50029219580100 NA Sealed NA NA 6/28/2010 11 -29 1940250 50029224660000 NA 0.2 NA 1.70 6/28/2010 11 -31A 1961830 50029225090100 NA 1.4 NA 6.80 6/28/2010 11 -32 1941310 50029225120000 NA 6.7 NA 59.50 6/30/2010 11 -33 1940900 50029224900000 NA 0.5 NA 2.55 6/30/2010 11 -34 1941380 50029225160000 NA 0.5 NA 3.40 11/27/2009 11 -35 1940650 50029224760000 NA 0.6 NA 5.10 6/30/2010 11 -37 1961740 50029227160000 NA 4 NA 42.50 7/1/2010 11 -38A 1982160 50029227230100 NA 2.1 NA 22.10 6/28/2010 • Date: 08-27-2009 Transmittal Number:93091 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. ; ~~, ~ ~ ~,_ ; ~- ,-~ : ~r~ ~~r~`~ ,bq~ ~~~ l ~~ ~ ~ ~~ I ~'~~ i~r°`~ -e___. ~ t -c~3 1~ If vou have anv auestions. olease contact Joe Lastufka at (9071564-4091 Delivery Contents Bottom SW Name Date Com an Run To De th De th Descri tion BAKER CARBON/OXYGEN LOG 12-09 09-06-2008 HUGHES 1 8840 9079 GAMMA RAY RESERVOIR PERFORMANCE BAKER MONITO CAFiBON OXYGEN 12-09 03-03-2009 HUGHES 1 8926 8952 ANALYSIS BAKER RESERVOIR PERFORMANCE 12-09 09-07-2008 HUGHES 1 8840 9079 MONITOR RESERVOIR PERFORMANCE BAKER MONITOR GASVIEW 12-09 02-09-2009 HUGHES 1 8926 8952 SATURATION ANALYSIS BAKER INTERPRETATION OF RPM 12-09 09-07-2008 HUGHES ~ DATA CD-ROM - RPS/GSA PRM RPM/COA CARBONlOXYGEN BAKER LOG/GR META, LAS, PDF 12-09 08-19-2009 HUGHES FORMAT BAKER RESERVOIR PERFORMANCE 11-17A 08-17-2008 HUGHES 1 9850 10370 MONITOR RESERVOIR PERFORMANCE BAKER MONITOR GASVIEW 11-17A 01-30-2009 HUGHES 1 10107 10362 SATURATION ANALYSIS BAKER INTERPRETATION OF RPM 11-17A 08-17-2008 HUGHES DATA CD-ROM - RPM/GSA PRM BAKER META, LAS, AND PDF 11-17A OS-19-2009 HUGHES FORMAT BAKER RESERVOIR PERFORMANCE 14-18B 08-24-2008 HUGHES 1 10580 11043 MONITOR RESERVOIR PERFORMANCE BAKER MONITOR GASVIEW 14-18B 01-29-2009 HUGHES 1 10700 11018 SATURATION ANALYSIS BAKER INTERPRETATION OF RPM 14-18B OS-24-2008 HUGHES DATA CD-ROM - RPM/GSA PRM BAKER META, LAS, AND PDF 14-18B 08-19-2009 HUGHES FORMAT BAKER RESERVOIR PERFORMANCE M-04 08-25-2008 HUGHES 1 11100 11370 MONITOR M-04 01-29-2009 BAKER 1 11212 11374 RESERVOIR PERFORMANCE Petrotechnical Data Center LR2-( 900 E. Benson Blvd. PO Box 1966[2 Anchorage, AK 99~ 19-6612 ~ • J • BP Alaska Interpretation of RPM Data Well: 11-17A Field: Prudhoe Bay Report Status: Final Report Authors: Yonghwee Kim and Rafay Ansari Reviewed: David Chace Logged Date: 17th August 2008 Report Date: uly 2009 ~/%~ B~AKER NU6HES Baker Atlas ~ ~,~,~~u, ~ ' ~~ ~a ,~~ ~~~~~,~~~~.,. ..~~~~:~~' ~-~ . ~~~~~,~ ~~; .~~~~~ ~ .~~ . a~'~.~,~~~~ , ,rx.~ 3.~ ~~~~~ '~' "" ~". >~~w ~.x r*~~? <:~~~ ~,~~,~,~ ,,~,~~~, ~. r ~ ~~ ~ ~ ~ ~ ° ~„,~~;_~~~,. , ~ . . ~ ~ . . ~ ~ . ~ ~ts .. . ::.?: . .. . i:sx. ~ ~. , .> ~;:,. , ` ` ..< ~ , . z~x _~ v ~.... . . ys',; .. ~.~-,:~"t~" ~ ~ ~ ~.. ~~ ~ ~ 5,~ , ~ ~ ~ ~ ~ ' ~...~~ ~..z,..:.~~.',z; ., . , .~:.~su~°f,:c~~.. ~w::.~<~~..: . ~~~ ~r°~" ,. , ~ ~`~,~ _,'~~~~`t;",: http://www.bake rhug hes.com/bake ratlas ~~~ ,~~.. ~~ .._~~~> > ~~~~~~ ~ , ~~,~.:,~r„ , .,~~ ~~~~~~~~a ~ ~ : ~:~~~~~ ,: _~,~~~ x.~~~ =x~~~ ~ „ "~ , ~a _ ~`~ s~~a+~;% . ,~, :.a~ ~~ ~:~'.~.._= ~.~;xs, , ~ ~~. ': ~w~~..Y ~ ',~~~ - _~~•.. ,.w~ t':` ~' ~ ~x- i ~oa - a~a • • ~ IN MAKING INTERPRETATIONS OF LOGS OUR EMPLOYEES WILL GIVE THE CUSTOMER THE BENEFTI' OF THEIR BEST JUDGEMENT, BUT SINCE ALL INTERPRETATIONS ARE OPINIONS BASED ON INFERENCES FROM ELECTRICAL OR OTHER MEASUREMENTS WE CANNOT AND DO NOT GUARANTEE THE ACCURACY OR THE CORRECTNESS OF ANY INTERPRETATION. WE SHALL NOT BE LIABLE OR RESPONSIBLE FOR ANY LOSS, COST, DAMAGES, OR EXPENSES WHATSOEVER INCURRED OR SUSTAINED BY THE CUSTOMER RESULTING FROM ANY INTERPRETATION MADE BY ANY OF OUR EMPLOYEES. n u ~ I~ • BP Alaska- Prudhoe - Well 11-17A- RPM Sat ation Analysis Page i CONTENTS INTRODUCTION 1 1.1 Objectives 1 1.2 Results 1 1.3 Data Set 1 1.4 Sequence of Events 2 2 ANALYSIS AND INTERPRETATION 2.1 RPM Overview 2.2 GasView Analysis Methodology ~ 3 DA7A DISCUSSION 3.1 GasView Analysis and Discussion RPM REFERENCES LIST OF TABLES AND FIGURES Table 2.1 Parameters Used for Input to GasView Modelling Figure 2.1 GasView Response Chart Figure 2.2 Example of GasView Results Figure 3.1 Processed GasView Results Baker Hughes Inc. BP Alaska- Prudhoe - Well 11-17A- RPM Sa tion Analysis Page 1 1 INTRODUCTION (Source: BP Logging Program) 11-17A is a gas lifted producer in the GDWFI area. This well is currently producing but at the limits of the gas handling capacity of Flow Station 2. Running a RPM will not have a production impact on the field. • Current Status: Gas Lift Producer: • Last test: 250 BFPD, 246 BOPD, 59,981 GOR, 2% WC (7/28/08) • Max Deviation: 44 degrees @ 7997' MD • Min. ID: 3.725" @ 9857', HES XN Nipple • Last TD tag: Set CIBP @ 10,380' on 10/25/05 • Last Downhole Ops: Set CIBP @ 10,380' on 10/25/05 • Latest H2S level: 40 ppm (6/27/08) • Tie-in Log: MWD DEN/NEU on 7/31/2002 and Jewelry Log 8/22/2002 r 1.1 Objectives This RPM (Reservoir Performance Monitor) log will provide information on the Sag formation which should be gas filled at this location. Through comparison with the log data from other wells, we will have a better understanding of the capacity and limitation of this pulsed neutron log tool in the Sag formation. Also, the log will provide a quantitative estimate of gas saturation and fluid saturation for future adperfs in the Ivishak. 1.2 Results I~ • The RPM data was of very good quality and repeatability, and an analytical result of good confidence has been achieved. • By utilizing GasView methodology, a gas saturation curve (Sg) has been calculated while two water saturation curves (Sw and Sw_HT) provided by BP have been displayed for comparison. Water saturation curves agree well mostly with Sg except at the bottom of the well which may be due to the presence of conglomerate. • In ivishak interval, analysis shows that gas is present mostly in the sand sections above 10,270 ft. Below 10,280 ft GasView analysis indicates liquid filled formation. 1.3 Data Set This well was logged on 17th Aug 2008. The RPM data has been recorded through two different borehole/completion configurations. 1) 12.25inch borehole and 9.625inch casing (9,900-10,022 ft) 2) 6.125inch borehole and 4.5inch casing (10,022-10,380 ft) Three passes were recorded at 10 ft/min. The GasView passes were recorded with a source output of 800,000 cps (counts per second). 1.4 Sequence of Events • Log was correlated to MWD-SLD/L-DEN/CTN-COMP/T-NEU (reference log) DATE 31st Jul 2002. • Log started at i 3:30 on f 7th Aug 2008 and finished at 18:30 on the same day. • The top logged interval was 9,850 ft and the bottom logged interval was 10,370 ft. I ~ Baker Hughes Inc. BP Alaska- Prudhoe - Well 11-17A- RPM Sat tion Analysis Page 2 2 ANALYSIS AND INTERPRETATION 2.1 RPM Overview The Baker Atlas RPM is a pulsed neutron instrument capable of acquiring data in several modes. PNC (Pulsed Neutron Capture) data is used to evaluate the formation saturation in known high salinity formations and to identify gas, while C/O (Carbon/Oxygen) is used to evaluate the formation saturation in low- or unknown-salinity formations. Further to the water saturation calculation modes the tool can also be operated in AFL (Annular Flow Log) mode to quantify water velocity in both continuous passes and stations. Also, borehole holdup can be calculated utilizing the PNHI (Pulsed Neutron Holdup Indicator) mode; this is particularly useful in horizontal or highly deviated wells where the accuracy of conventional production logging instruments is greatly reduced. More recently, the modified RPM-C tool has allowed us to carry out gas saturation analysis ( GasViews"" ) analysis from three detector PNC data. ~ 2.2 GasView Analysis Methodology Baker Atlas has enhanced the Reservoir Performance Monitor (RPM) service by introducing three features: improved instrumentation, a new characterization, and advanced interpretive techniques. The GasView service utilizes the improved resolution of the RPM-C tool, a new gas response characterisation, and a new petrophysical algorithm to deliver a better method for identifying gas and measuring gas saturation. The three detector RPM-C instrument allows gas detection ratios to be taken over longer spacing than conventional instruments. These new measurements are substantially more sensitive to the change in neutron-gamma distribution that indicates a change from liquid to gas-filled porosity. This improved sensitivity allows the instrument to resolve the presence of gas where conventional instruments cannot, and it provides better resolution in the gas saturation calculation. Characterization of tool response allows more accurate quantification of saturation. A global tool response characterization database has been constructed for standard open hole and cased hole completions. This includes varying combinations of mineralogy, fluid density, and gas pressure/density. The following table states the parameters which have been used in the modelling of the predicted curve response for Prudhoe well 11-17A. Table 2.1 Parameters used in GasView modellin of well 11-17A ~ Parameter Value Borehole Size 6.125 inch Casin Size 4.5 inch Borehole Fluid Water Matrix T e Sandstone Gas Densit 0.26 /cc Oil Densit 0.8 /cc Water Densit 1.00 /cc A GasView job planner is available to design optimal logging programs. The following chart shows the expected response of the RIN13 curve (this chart is an example only and not relevant to this specific case of well 11-17A). Baker Hughes Inc. i• BP Alaska- Prudhoe - Well 11-17A- RPM Sat tion Analysis Page 3 Delta Sig~w vs Famaeon Pwosily I DeMa Sigma vs Forrculim Watu SefnNy I Gas Coefficient FJe I rpR 6as Chart I ~ ~ Ratio~. Plot Detector degree d fit BAK~ ~~ gaz ~nans ~ . a ~~ NYGNES Baker Atlas Bordwb fluid densRiy Fametion ik~id densAy: Fartielion qaa density: 0.10 0.69 0.69 SavaEQUalron p~/EMpoit CoellcroMs RIN wet I • OAO OAS 0.10 0.15 0.20 025 0.30 0.35 gas Porosity ] OK Cancel Figure 2.1 GasView Response Chart The Dynamic Gas Envelope (DGE) interpretation explicitly accounts for variations in porosity and shale volume in the saturation result. While these effects must be removed from the saturation solution, they are included in the visual DGE representation for greater insight into the processing. See example GasView results below. For results of well 11-17A, see section 3.1. I~ I ~ Baker Hughes Inc. • BP Alaska - Prudhoe - Well 11-17A- RPM Sat tion Analysis Page 4 EXAMPLE W et side of DGE Gas side Measure used fo analy d curve r gas sis ~ of D6E I ~ GAS--Curve depaRure from the wet side f th DGE i di t th f o e n ca e presence o gas, es and the degree of departure indicates • the gas saturation. ~ WET-The measured curve moving along the wet side of the envelope indicates h b f t e a sence o gas. ~ The correspondence of the measured curoe and the D6E water line in wet zones is an ' indicator of the integriry of the interpretation and the validiry of the porosity calculations. ~ ~ Figure 2.2 Example of GasView Results Baker Hughes Inc. BP Alaska- Prudhoe - Well 11-17A- RPM Sat ation Analysis Page 5 3 DATA DISCUSSION 3.1 GasView Analysis and Discussion A GasView analysis has been carried out using the three passes logged on the 17th Aug 2008. All passes were recorded at 10 ft/min with a source output of 800,000 cps. All the passes have been shifted on depth using open hole GR provided by BP. All data looks to be of good quality and repeatability. Curves from three recorded passes have been averaged to create one final data set to be used for analysis. A result of good confidence has been achieved. The pre-modelling software for GasView uses a number of lab test calibration points, these lab tests are carried out using pure quartzite for a sandstone environment and tombstone marble for limestone environment. It is very unlikely that this type of matrix would be present down hole therefore a single value calibration is made to the RIN13 curve to correct for material differences in the matrix. This parameter should be used to normalize the RIN13 curve in a zone of known saturation. ~ In the process of the GasView analysis, RIN13 normalization value was used as -2 and the shale calibration value was 96. Also, note that the pick up depth is 10,362ft based on the BKS change (BKS- short spaced background countrate). The results of this analysis can be observed in Figure 3.1. The results show the Dynamic Gas Envelope (DGE explained in section 2.2) overlaid with the normalized RIN13 curve. The position of the RIN13 curve between the Gas line (red) and the Liquid iine (blue) of the DGE determines the gas saturation. The figure shows how the measured curve moves between the liquid and gas lines and the resulting gas saturation curve (Sg). The formation gas density used in preliminary processing was 0.15 g/cc. Final results shown in this report were generated using 0.26 g/cc for the formation gas density. The open perforation interval (10,298-10,304 ft) was used for wet zone normalization since the well was under injection while logging. Shale calibration was performed using the tool response from 10,196- 10,205 ft. The analysis shows high gas saturations (mostly above 90%) in the sand sections above 10,270 ft. It gradually drops and goes to zero at 10,285 ft. Below this depth, GasView analysis indicates liquid filled formation except a spike in the open perf section. ~ ~ Baker Hughes Inc. BP Alaska - Prudhoe - Well 11-17A- RPM Sat ion Analysis Page 7 Baker Hughes Inc. Figure 3.1 Processed GasView Results ~ BP Alaska - Prudhoe - Well 11-17A- RPM Sat ion Analysis Page 8 RPM References ' Chace, D.M., Trcka, D.E., and Dawe, B.A., "Application and interpretation of continuous oxygen activation logs for measuring complex water flow profiles in injection wells," SPE 69th Annual Technical Conference and Exhibition, New Orleans, Louisiana, Paper 28412, 1994. Trcka, D., van den Berg, F., Manan, W.A., Peeters, M., and Mickael, M., "Measuring three-phase holdups in horizontal wellbores using pulsed neutron instruments," SPE Annual Technical Conference and Exhibition, Denver, Colorado, Paper 36561, 1996. Gilchrist, W.A. Jr., Prati, E., Pemeper, R., Mickael, M.W., and Trcka, D., "Introduction of a New Through- Tubing Multifunction Pulsed Neutron Instrument," SPE paper 56803, Annual SPE Technical Conference and Exhibition, Houston, Texas, Oct. 1999. Trcka, D.E., and Chace, D.M., "Improved method for measuring annular water flow in injection wells using continuous oxygen activation logging," SPE 68th Annual Technical Conference and Exhibition, ~ Houston, Texas, Paper 26450, 1993. Chace, D.M., Trcka, D.E., Wang, J., Bousche, O., van der Spek, A., al Nasser, H., "A new production logging service for horizontal wells," SPWLA 39th Annual Symposium, Keystone, CO, 1998, Paper H. Mickael, M.W., Trcka, D.E., Pemper, R., "Dynamic Multi-Parameter Interpretation of Dual-Detector Carbon/Oxygen Measurements", SPE Annual Technical Conference and Exhibition, Houston, Texas, Oct. 1999. Chace, D., Trcka, D., Georgi, D., Wang, J., Bousche, O., van der Spek, A., al Nasser, H., "New instrumentation and methods for production logging in multiphase horizontal wells," SPE MEOS, Bahrain, Paper 53220, 1999. David Chace, Jianrong Wang, Roman Mirzwinski, Jorge Maxit, and Darryl Trcka, "Applications of a New Multiple Sensor Production Logging System for Horizontal and Highly-Deviated Multiphase Producers", SPE paper 63141, Annual SPE Technical Conference and Exhibition, Dallas, Texas, October, 2000. Trcka, D., Oliver, D., Mickael M., Chace, D., Georgi, D., and Wang, J., "Reservoir performance monitoring in the new millennium", Proceedings of the Tunisian Oil Conference, April, 2000. Riley, S., Guivarch, B., Chace, D.M., Trcka, D.E., Clark, J., "Production logging in horizontal gravel- packed highly viscous oil producers in the North Sea", SPE Annual Technical Conference and Exhibition held in Denver, Colorado, Oct. 2003. ~ I ~ Baker Hughes Inc. . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc a STATE OF ALASKA . ALA" OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS RECEIVED NOV 2 3 20('JS 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Opera!. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 53.85 KB 8. Property Designation: ADL-028328 11. Present Well Condition Summary: Total Depth measured 10740 true vertical 9114.77 Effective Depth measured 10655 true vertical 9036.56 Casing Conductor Surface Production Liner Length 72 2477 9997 869 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 4-1/2" 12.6# L-80 Perforation depth: Measured depth: 10300 - 10306 True Vertical depth: 8722.37 - 8727.5 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 731 x Plug Perforations [2] Perforate New Pool 0 Perforate [2] 4. Current Well Class: Development M Stratigraphic D Stimulate 0 WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to DriIlNwnber: 'ssiol Exploratory 0 Service D 6. API Number: 50-029-21598-01-00 9. Well Name and Number: 11-17A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool feet feet Plugs (measured) Junk (measured) 10380 10642 feet feet MD 29 - 101 28 - 2505 25 - 10022 9868 - 10737 TVD Burst Collapse 29 - 101 1490 470 28 - 2504.89 4930 2670 25 - 8479.92 6870 4760 8353.02 - 9112 8430 7500 4-1/2" 12.6# 13Cr80 24 - 9868 4-1/2" Baker S-3 Perm Packer 4-1/2" Top Packer 9812 9855 5CANNEC DEC 1 (; 2005 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure shut-in 9354 0 0 240 15. Well Class after Droposed work: Exploratory 0 Development M¡ Service 16. Well Status after proposed work: Oil M Gas D WAG D GINJ D WINJ D WDSPL Tubing pressure 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Sharmaine Vestal ... _ I . ..,.. Signab~_~~ ~ Form 10-404 Revised 04/2004 V Contact Sharmaine Vestal Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Phone 564-4424 Date 11/23/2005 tJÝ Submit Original Only ~ e e 11-17A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE ~~III?~"'·~22~'2~.·.i§Q:M~~~),~'B~1'~'1~1{î:rd ,.!._ +'.t 10/25/2005 T/I/O = 1700/1650/0. Assist E-Line pump as directed. Pumped 100 bbls Diesel to displace Tubing. Pumped 12 bbls Diesel to pt CIBP to 1700 psi. Lost 50 psi in 15 min. Bled back pressure. Final WHP's = 1150/1650/0. 10/25/2005 SET BAKER CIBP @ 10380', RAN IN WITH 6' HSD GUN & SHOT 10300' TO 10306' CORRELATED TO SWS PERFORATION RECORD & JEWELRY LOG DATED 22-AUG-2002 CCL STOP DEPTH = 10291.9' CCL TO TOP SHOT = 8.1' iPERFORATED INTERVAL = 10300' - 10306' CIBP SET: CCL STOP DEPTH = 10371.4' CCL TO MID ELEMENT = 8.6' PLUG SET DEPTH = 10380' **NOTIFY DSO OF WELL STAUTS** 1 0/29/2005T/=200/1350/0. Temp=Cool. IA FL (for the GLE). IA FL @ 6093' sta # 6 (SO). Rate=3.5 mil. gas. FLUIDS PUMPED BBLS 112 I Diesel TOTAL 112 · STATE OF ALASKA ., ALA~ .1 OIL AND GAS CONSERVATION COMrv.. __110N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 53.85 KB 8. Property Designation: ADL-028328 11. Present Well Condition Summary: Total Depth measured 10740 true vertical 9114.77 Effective Depth measured 10655 true vertical 9036.56 Casing Conductor Surface Production Liner Length 72 2477 9997 869 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 4-1/2" 12.6# L-80 Perforation depth: Measured depth: 10396 - 10400 True Vertical depth: 8804.71 - 8808.2 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10284-10294; 10295-10300' Treatment descriptions including volumes used and final pressure: see attached fluid summary T/I/O 175/1500/10 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 142 x Plug Perforations 0 Perforate New Pool D Perforate 0 4. Current Well Class: Development ;?" Stratigraphic Stimulate 0 WaiverD TimeExtênsï'6nD Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory 0 202-0320 Service 6. API Number: 50-029-21598-01-00 9. Well Name and Number: 11-17A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool feet feet Plugs (measured) Junk (measured) None 10642 feet feet MD 29 - 101 28 - 2505 25 - 10022 9868 - 10737 Burst 1490 4930 6870 8430 Collapse 470 2670 4760 7500 TVD 29 - 101 28 - 2504.89 25 - 8479.92 8353.02 - 9112 10446 - 10458 ,~. t,· "Eín ') -íl <2no¡::'~ 10623 _ 10633 ~~C:ANNt,[) ~£ì - r' t.' ).,_.tJ .'<P 9007.38 - 9016.48 8848.69 - 8859.31 4-1/2" 12.6# 13Cr80 24 - 9868 4-1/2" Baker S-3 Perm Packer 4-1/2" Top Packer 9812 9855 RBDMS BFl SEP 2 1 2DD5 Representative Daily Average Production or Injection Data Gas-Met I Water-Bbl I Casing Pressure SHUT - IN 15228 I 9781 I 15. Well Class after proposed work: Exploratory r Development P' 16. Well Status after proposed work: Oil P' Gas r WAGr Tubing pressure 50 389 Service r WDSPL r GINJ r WINJ r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Signat~~y Form 10-404 Revised 04/2004 ?Ltdl /"--, r"') 1 I" ~\ t\,' A L I ',' ' \"'1: ,\ t l)' t\ \~\...) , ~ '\i Phone 564-4424 Date 9/19/2005 Submit Original Only ) 11-17 A ) DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 8/12/2005 CTU # 9. Cement Squeeze. RU. ***Continue on 8/13/05 WSR*** 8/13/2005 Cement Sqz. / CTU #9. ***Continued from 8/12/05 WSR*** MIRU. Kill well with 1 % KCL. Injectivity after fluid packed was 5.3 bpm at 900 psi WHP. At static, well on vac. Pump 77 bbls diesel down backside. Do acid treatment with 20 bbls 12 - 10 DAD acid and 50 bbl overflush. Injectivity went from 1.9 bpm @ 590 psi to 1.9 bpm @ 1160 psi. Static after acid job at 190 psi WHP. Pump 44 more bbls diesel down backside. Static at 340 psi WHP. Pump 43.5 bbls of 15.8 ppg LARC cement. Squeeze app 3.2 bbls behind pipe. Ramp WHP up to 2800 psi (3500 DP). hold squeeze pressure for 1 hour, lost 182 psi. Cleanout with 79 bbls 1.5# biozan to flag at 10339' and up to 9700' making 3 down and up passes. Pump 5 bbls TEA across perforations. Chase out at 80% washing all jewerly completely. ***Continue on 8-14-05 WSR*** 8/14/2005 CTU # 9. Cement Squeeze. ***Continue from 8/13/05 WSR***. Freeze protect tubing to 2500' with 38 bbls 50/50 methanol. Trap 600 psi on WHo RD. Secure location. *** Job Complete*** 8/15/2005 ***WELL WAS SHUT-IN UPON ARRIVAL*** (GL post cmt sqz) TAGGED TOC @ 10,277' SLM WITH 3.25" CENT., 5' 1 1/2" STEM, AND 3.625" GAUGE RING. SET WCS @9,830' SLM. PULLED STA'S 6 & 7. ***JOB IN PROGRESS CONTINUED ON WSR 8-16-05*** 8/16/2005 ***CONTINUED FROM WSR 8-15-05*** BROKE WIRE @ STA # 8, APPEARS TO BE LATCHED. PULLED STA# 8 AND SET 1 1/2" DGLV WITH RK LATCH. SET 1 1/2" LGLV (1/4" PORTS, 1,500# TRO, RK LATCH) IN STA# 7. SET 1 1/2" OGLV (5/16" PORTS, RK LATCH) IN STA# 6. PULLED WCS. (EMPTY). RDMO. ****LEFT WELL SHUT-IN, NOTIFIED DSO OF WELL STATUS**** 8/26/2005 CTU #9 Mill: MIRU **** Continued on 8/27/05 WSR **** 8/27/2005 CTU #9 Mill: Continue RU from 8/26/05 WSR. Weekly BOPE test. MU/RIH with WFD 2-7/8" mtr and 3.70" junk mill. Tag cement @ 10360' dwn. Mill through plug @ 10369'. Push Fasdrill to TO @ 10642'. FloPro sweep off bottom, POOH @ 80%. Drop circ sub ball and FP to 2500' with meth. RDMO. ***Leave well SI for Upcoming Add Perf*** 8/31/2005 CORRELATED TO SWS PERFORATION RECORDED DATED 22-AUG- 2002 TAGGED TD AT 10634 FT PERFORATED 10623.3 - 10633.3 FT WITH 2" HSD 2006 PJ HMX 6 SPF FLUIDS PUMPED BBLS 78 Diesel 20 120/0 HCL/100/0 Xylene DAD acid 167 50/50 Methanol 413 1 % KCL 43 FloPro w/E166 slicking agent (150k LSRV) 47.7 15.8 ppg LARC cement TOTAL ) >\. ¥À~1t\ DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 ,..-- Operator BP EXPLORATION (ALASKA) INC ft:o~50-1:.~tf:r- Permit to Drill 2020320 Well Name/No. PRUDHOE BAY UNIT 11-17 A MD 10740 /" TVD 9115 r- Completion Date 8/22/2002 Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, DEN, NEW RES Well Log Information: Electr Digital Dataset Med/Frmt Number Name LIS Verification Directional Survey Directional Survey rProduction Log/ Data Type ~t ~ ~D ~g Log Log Run Scale Media No 1 1 1 5 Blu 5 Blu 5 Blu 5 Blu Log ~ Log Log ~c tJ I cl ~ "-\ ~ )... Spinner ..,,/ Pressure \.Grad iometer 41449 Perforation ..~ ~g ~perature ~ D 41'Š45 LIS Verification ~ C Pdf ~OO Density ( t.) \t¡- J...k'f ... 5 Blu Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORM~I. ION Well Cored? Y~ Chips Received? '? I r~ Daily History Received? Formation Tops Analysis Received? ","Y/N - Current Status 1-01L UIC N ---~._._-_.- Directional Survey Yes -----,._- ~_._------_.- (data taken from Logs Portion of Master Well Data Maint) ~ Interval OH/ Start Stop CH Received Comments -~-- 9721 10688 <1Ji1--2/28/2003 9996 10740 Open 8/23/2002 9996 10740 Open 8/23/2002 """W'~ 10200 1 0550 Case 11/1/2002 10200 1 0550 Case 11/1/2002 10200 1 0550 Case 11/1/2002 10200 10550 Case 11/1/2002 9680 10610 Case 11/29/2002 1 0200 10550 Case 11/1/2002 9721 1 0688 ~/28/2003 9740 10740 Open 4/23/2004 MWD, CTN, DGR, GRAPHIC IMAGES Sample Set Number Comments ÐN @/N ---~------~ DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2020320 Well Name/No. PRUDHOE BAY UNIT 11-17 A Operator BP EXPLORATION (ALASKA) INC MD 10740 TVD 9115 Completion Date 8/22/2002 Completion Status 1-01L Current Status 1-01L Comments: Compliance Reviewed By: ~ Date: API No. 50-029-21598-01-00 UIC N ----------- \ C) ~~ q--- .......... ~ ( ;J.ez. -032.. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COmIll. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 J\nchorage, Alaska 99501 April 20, 2004 RE: MWD Formation Evaluation Logs: 11-17~ AK-MW-22126 11-17A: Digital Log Images 50-029-21598-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petro-technical Data Center LR2-1 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: ¥f f s~ .W~ RECEIVED /, 2 ,'; 2004 Alaska Oil & GasCóns. Commisabn Anchorage , .. ( STATE OF ALASKA l ALASKh ùlL AND GAS CONSERVATION CO~\h.ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Suspend 0 Repair Weill!] Pull Tubing 0 Operation Shutdown 0 Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate 0 WaiverD Stimulate 0 Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 202-0320 OtherD Name: BP Exploration (Alaska), Inc. 53.85 8. Property Designation: ADL-0028328 11. Present Well Condition Summary: Stratigraphic D 9. Well Name and Number: 11-17A 10. Field/Pool(s): Prudhoe Bay Field I Prudhoe Oil Pool Exploratory 0 Service 0 6. API Number 50-029-21598-01-00 Development ŒJ 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 10740 feet true vertical 9114.8 feet Plugs (measured) None Effective Depth measured 10655 feet Junk (measured) None true vertical 9036.6 feet Casing Length Size MD TVD Burst Collapse Conductor 72 20" 91.5# H-40 29 101 29.0 - 101.0 1490 470 Liner 891 4-1/2" 12.6# L-80 9848 - 10739 8336.7 - 9113.9 8430 7500 Li ner 35 2-7/8" 8.6 # L-80 10275 - 10310 8700.8 - 8730.9 15000 15300 Production 9997 9-5/8" 47# L-80 25 - 10022 25.0 - 8479.9 6870 4760 Surface 81 13-3/8" 72# K-55 28 109 28.0 - 109.0 3700 2230 Surface 2393 13-3/8" 72# L-80 109 - 2502 109.0 - 2501.9 4930 2670 Perforation deDth: Measured depth: 10284 - 10294, 10295 - 10300, 10396 - 10400, 10446 - 10458 True vertical depth: 8708.62 - 8717.23,8718.09 - 8722.37,8804.71 - 8808.2,8848.69 - 8859.31 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 24 9870 Packers & SSSV (type & measured depth): 2-7/8" Eclipse Patch Packer 2-7/8" Eclipse Patch Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Liner Top Packer @ 10275 @ 10310 @ 9812 @ 9855 MAR 1 5 20H¡1 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ReDresentative Daily Average Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 16.7 4991 1075 13 497 25.9 7574 1250 Tubing Pressure 1212 712 Prior to well operation: Subsequent to operation: Oil-Bbl 336 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ) ServiceD Copies of Logs and Surveys run- 16. Well Status after proposed work: Operational Shutdown D OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or NIA if C.O. Exempt: N/A Daily Report of Well Operations - ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron JJ~C~ Title Production Technical Assistant Signature Phone 564-4657 Date 3/11/04 Form 1 0-404 Revised 12/2003 ORiGiNAL RØJtIS BfL MAl 16 lU\1~ (" 11-17A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/30103 PULL 4-1/211 ECLIPSE PATCH AND SETTING SLEEVE @10263' SLM. BRUSH & FLUSH WI LRS TO 10,285' SLM WI 4-1/211 BRUSH, 3.7011 GUAGE RING. DRIFT WI 3.705 CENT, 3.7" GAUGE RING TO 102901.(6311 OAL AS DUMMY PATCH) ***WELL LEFT SHUT IN*** 12/20103 T/I/O=2250/110010. PUMP 175BBLS 190*F CRUDE TO WARM UP TBG. FINAL WHP; T 11/0= 1501125010. 12121/03 SET 4.5" WEATHERFORD ECLIPSE PATCH AND UPPER PACKER ASSEMBLY INTO BOTTOM PACKER @ 175 FPM. LATCH CONFIRMED BY PULLING 800 LBS OVER NORMAL UP WEIGHT. UPPER PACKER SET WITH MID OF ELEMENT AT 102751. TOP OF PATCH AT 10271'. PULLED TIGHT AT 86201 WHILE POOH. OAL UPPER & LOWER SECTION = 39'. UPPER SECTION ONLY = 36.2'. MIN ID = 2.2511 *******WELL LEFT SHUT -IN****** FLUIDS PUMPED BBLS 267 267 Crude TOTAL Page 1 " ~ \ ( TREE = W8...LHEAD = 'ÄCTUA TOR';;; KB.. 8...EV..;;;;..m.... m BF. 8...EV = KOP= Max Angle = Datum MD = """"". . "" ."..."... DatumlVD= 6"FMC FMC GEN 4 . AXELSON .. "" ""..... 54' 27.4' - ^ 10022' . 44 @ i997~ 11-17 A . . 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" 1--1 2505' ~ L Minimum ID = 2.25" @ 10272' ECLIPSE PATCH . . g ~ 14-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 1--1 9868' ~r ~ 8 ~ PERFORATION SUMMARY REF LOG: MWD DEN/NEU ON 07/31/02 ANGLEATTOPPERF: 31 @ 10284' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 6 10284 - 10294 0 10/07/02 2-7/8" 6 10295 - 10300 0 08/22/02 2-7/8" 6 10295 - 10300 0 09/02/02 2-7/8" 6 10396 -10400 0 08/22/02 ~ 2-7/8" 6 10446 - 10458 0 08/22/02 TOPOFWHPSTOCK H 10022' ~ ICIBP(02/2/3/02) 1--1 10125' ~ n IFISH - CA-R-20-RK - 06/07/961-1 10640' I PBTD 1--1 10857' : .~ JR 19-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 10871' ( SAFTEY NOTES: 4.1/2" CHROME TBG. 2200' 1-14-1/2" HES X NIP, ID = 3.813" 1 ST MD lVD ~ 8 3014 3000 7 4133 4000 6 6093 5500 5 6751 6000 4 7409 6500 3 8068 7000 2 8768 7521 1 9721 8234 GAS LIFT MANDR8...S DEV TYÆ VLV LATCH 10 MMGM DMY RK 35 MMGM DOME RK 41 MMGM SO RK 40 MMGM DMY RK 36 MMGM DMY RK 44 MMGM DMY RK 44 MMGM DMY RK 37 MMGM DMY RK PORT DATE 0 08/14/02 16 08/14/02 20 08/14/02 0 08/09/02 0 08/09/02 0 08/09/02 0 08/09/02 0 08/09/02 9791' 1-14-1/2" HES X NIP, ID = 3.813" 1 9812' 1-19-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 1 9836' 1-14-112" HES X NIP, ID = 3.813" 1 9857' 1-14-1/2" HES XN NIP, ID = 3.725" 1 9868' 1-14-1/2" WLEG, ID = 3.958" 1 9855' 1-19-5/8" X 4-1/2" BKRZXPPKR, ID= 6.280"1 9868' I-1ELMD TT LOGGED (08/22/02) 1 110272'.10310'1-14-112" ECLIPSE PATCH (10/13/03), ID= 2.25" I I PBTD 1-1 10655' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 10737' 1 DATE 06/12/86 08/09/02 08/22/02 08/31/02 09/02/02 1 0/07/02 REV BY COMMENTS ORIGINAL COM PLETION DAV/KK RIG SIDETRACK (11-17A) TMN/KK IPERFS DTRfTP GL V C/O CWS/KK REPERF CWS/KK REPERF DA TE REV BY COMMENTS 10/13/03 CJS/TLH SET ECLIPSE PATCH PRUDHOE BA Y UNIT W8...L: 11-17A ÆRMIT No: 2020320 API No: 50-029-21598-01 SEe 34, T11 N, R15E, 770' FNL & 666' FWL BP Exploration (Alaska) ... ..,'6 ( STATE OF ALASKA { ALASKP. ùlL AND GAS CONSERVATION corv""IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Suspend D Repair WellŒJ Pull TubingD Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate D WaiverD Stimulate D Time ExtensionO Re-enter Suspended WellO 5. Permit to Drill Number: 202-0320 OtherO Name: BP Exploration (Alaska), Inc. 53.85 8. Property Designation: ADL-0028328 11. Present Well Condition Summary: Development Œ] Stratigraphic D 9. Well Name and Number: 11-17A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Exploratory D Service D 6. API Number 50-029-21598-01-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 10740 feet true vertical 9114.8 feet Plugs (measured) None Effective Depth measured 10655 feet Junk (measured) None true vertical 9036.6 feet Casing Length Size MD TVD Burst Collapse Conductor 72 20" 91.5# H-40 29 101 29.0 101.0 1490 470 Liner 891 4-1/2" 12.6# L-80 9848 - 10739 8336.7 - 9113.9 8430 7500 Liner 35 2-7/8" 8.6 # L-80 10275 - 10310 8700.8 - 8730.9 15000 15300 Production 9997 9-5/8" 47# L-80 25 - 10022 25.0 - 8479.9 6870 4760 Surface 81 13-3/8" 72# K-55 28 109 28.0 109.0 3700 2230 Surface 2393 13-3/8" 72# L-80 109 2502 109.0 - 2501.9 4930 2670 Perforation depth: Measured depth: 10284 - 10294, 10295 - 10300, 10396 - 10400, 10446 - 10458 True vertical depth: 8708.62 - 8717.23,8718.09 - 8722.37,8804.71 - 8808.2,8848.69 - 8859.31 Tubing (size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 24 9870 RECEIVED FEe 1 9 AlaSka I'\h 2004 'VII & GasG Anch';; ~ Packers & SSSV (type & measured depth): 2-7/8" Eclipse Patch Packer 2-7/8" Eclipse Patch Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Liner Top Packer @ 10275 @ 10310 @ 9812 @ 9855 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 16.7 4991 1000 13 Prior to well operation: Subsequent to operation: Oil-Bbl 336 497 25.9 7574 1150 Tubing Pressure 1212 712 14. Attachments: 15. Well Class after proposed work: ExploratoryD Developmentl!l ServiceD Copies of Logs and Surveys run- 16. Well Status after proposed work: Operational Shutdown D OilŒ] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564~4657. Sundry Number or NIA if C.O. Exempt: N/A Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron }J~~ Title Production Technical Assistant Signature Phone 564-4657 Date 2/16/04 "tit.. ttB 20.' Form 1 0-404 Revised 12/2003 ( 11-17A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10104/03 T/I/O=2300/100010 Well SI on arrival Assist Slickline with Brush & Flush. Pumped 120 bbls crude down the tubing @ 180* 10104/03 UNABLE TO GET PASSED 6775' SLM. DUE TO THICK PARAFIN. BRUSH & FLUSH TUBING TO 10550 SLM.( 4.5 B.L.BRUSH WI 3.25 GUAGE RING) LRS USED A TOTAL OF 120 BBL. OF CRUDE. DRIFT TO 10500 WI 3.72 BARBELL SET UP 10/13/03 T10=2400/100010 WELL KILL FOR E-LlNE, LINER PATCH. PUMPED 6 BBLS METH, & 195 BBLS CRUDE TO SECURE WELL. FINAL T10=100/100010 10/13/03 A 4.5" ECLIPSE PATCH WAS SET @ 10275-10310.. LOG WAS CORRELATED TO SCHLUMBERGER JEWELRY LOG DATED 22-AUGUST-2002. ADAPTER FROM SETTING TOOL TO UPPER PATCH DID NOT COME BACK WITH TOOL. 10/17103 T/I/O= 2300/115010. PUMP 7BBLS METH AND 48CRUDE TO FREEZE PROTECT THE FLOWLINE. PUMP 5BBLS METH AND 58BBLS CRUDE DOWN TBG. FINAL WHP; T 11/0=1100/115010. FLUIDS PUMPED BBLS 421 12 6 439 Crude Methenal Neat Methenal TOTAL Page 1 TREE = 6" FMC WELLHEA D = FMC GEN 4 ,....~....~.... .~. ... .~~~n..........n..~~.n~n ...n~ .. . . ACTUA TOR = AXELSON .. " -...'.. "" ".m.m................. KB. ELEV = 54' sT ELEV-;;----------- 27 Ai' Kop;------_w___._-_m-i 0022' 'Max A n9.i~-;----'''---~4-@-i997-; Datum MD = Datum ND = ( 11-17 A . 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2505' ~ L Minimum ID = 2.25" @ 10272' ECLIPSE PATCH . g 14-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 1-1 9868' ~r 'J g ~ ÆRFORATION SUMMARY REF LOG: MWD DEN/NEU ON 07/31/02 ANGLEAT TOP PERF: 31 @ 10284' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 6 10284 - 10294 0 10/07/02 2-7/8" 6 10295 - 10300 0 08/22/02 2-7/8" 6 10295 - 10300 0 09/02/02 2-7/8" 6 10396-10400 0 08122/02 ~. 2-7/8" 6 10446 - 10458 0 08122/02 TOPOFWHPSTOCK H 10022' ~ ICIBP (02/2/3/02) 1-1 10125' 1 n FISH - CA-R-20-RK - 06/07/961~ 10640' I PBTD 1-1 10857' 1 .'.." ~ 19-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 10871' . . g ( SAFTEY NOTES: 4-1/2" CHROME TBG. 2200' 1-14-1/2" HES X NIP, ID = 3.813" I ST MD ND ~ 8 3014 3000 7 4133 4000 6 6093 5500 5 6751 6000 4 7409 6500 3 8068 7000 2 8768 7521 1 9721 8234 GAS LIFT MANDRELS DEV TYÆ VLV LATCH 10 MMGM DMY RK 35 MMGM DOME RK 41 MMGM SO RK 40 MMGM DMY RK 36 MMGM DMY RK 44 MMGM DMY RK 44 MMGM DMY RK 37 MMGM DMY RK 9791' 1-14-1/2" HES X NIP, ID = 3.813" I PORT DATE 0 08/14/02 16 08/14/02 20 08/14/02 0 08/09/02 0 08/09/02 0 08/09/02 0 08/09/02 0 08/09/02 9812' 1-19-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 1 9836' 1-14-1/2" HES X NIP, ID = 3.813" I 9857' 1~4-1/2" HES XN NIP, ID = 3.725" 1 9868' 1~4-1/2" WLEG, ID = 3.958" 1 9855' I~ 9-5/8" X 4-1/2" BKR ZXP PKR, ID = 6.280" 1 9868' 1-1 ELMD TT LOGGED (08/22/02) 1 110272'-10310' 1~4-1/2" ECLIPSE PATCH (10/13/03),ID= 2.25" 1 I PBTD 1-1 10655' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 10737' I DATE 06/12/86 08/09/02 08/22/02 08/31/02 09/02/02 1 0/07/02 COMMENTS ORIGINAL COM PLETION DAV/KK RIG SIDETRACK (11-17A) TMN/KK IPERFS DTRfTP GL V C/O CWS/KK REPERF CWS/KK REPERF REV BY DA TE REV BY COMMENTS 10/13/03 CJS/TLH SET ECLIPSE PATCH PRUDHOE BA Y UNIT WELL: 11-17A ÆRMIT No: 2020320 API No: 50-029-21598-01 SEC 34, T11 N, R15E, 770' FNL & 666' FWL BP Exploration (Alaska) a~-D3cl . 1/ 5yS WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska February 27, 2003 RE: MWD Fonnation Evaluation Logs 11-17 ^ AK-MW-22126 1 LDWG fonnatted Disc with verification listing. API#: 50-029-21598-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Si~IJbo~ RECEIVED FEB 28 2003 AIufœ Oil & Gas Cons. CollJlnitJtfo Anctl~ n Scblumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 11/26/02 NO. 2567 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK. 99501 Field: Prudhoe Bay Color Well Job# Log Description Date Blueline Sepia Prints J-10B Ol~~"d.O I 22494 USIT 10/25/02 2 MPI-02 I o-~y 22495 USIT 10/16/02 2 D.S.1-12 I 7;- )( 22460 RST 09/02/02 1 H-23A J ~5-0R'S 22488 MCNL 10/12/02 1 D.S.11-33 J I../..oql) 22441 RST 09/13/02 1 H-OS ~ 71-~ '!> 22479 RST 10/15/02 1 E-31A ~-J 16 22409 MCNL 08/08/02 1 H-20 I - -00 -1 22478 RST 10/09/02 1 N-15 I -D1C 22507 RST 11/13/02 1 C-31A ~ ~ "'0°" 22335 MCNL 07/13/02 1 D.S.11-17A~-o..~ 22418 PERF/JEWELRY (PDC) 08/22/02 1-01/J-19 I ~. DfL~ '1 22504 RST 11/02/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED Date Delivered: NOV 29 2002 Alaska O~ & Gas Cons. Ccmmi88ion Al1chorage CD 1 1 1 1 1 1 1 1 1 1 Schlumberger GeoQuest 3940 Arctic Blvd. Suite 300 Anchorage, AK 99503-5711 A TTN Betil Received ~ (. Onqf'" J ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: IBPI ACIDI ADD & RE-PERF 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - 771'FNL,4614'FEL,Sec.34, T11N, R15E,UM At top of productive interval 5206'FNL,4954'FEL, Sec. 34,T11N, R15E, UM At effective depth 5241' FNL,4983'FEL, Sec. 34,T1N, R15E,UM At total depth 102'FNL,5085'FEL,Sec.03,T10N, R15E,UM 12. Present well condition summary Total depth: measured true vertical Stimulate _X Alter casing - 5. Type of Well: Development _X Exploratory- Stratigraphic- Service- (asp's 708241, 5950973) (asp's 708033, 5946530) (asp's 708005, 5946494) (asp's 707907, 5946351) Plugging - Perforate _X Repair well - Other _X IBP 6. Datum elevation (DF or KB feet) RKB 54 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 11-17A 9. Permit number I approval number 202-032 10. API number 50-029-21598-01 11. Field I Pool Prudhoe Bay Field / Prudhoe Bay Pool 10740 feet 9115 feet Plugs (measured) IBP set @ 10348' (09/25/2002) Effective depth: measured 1 0348 feet Junk (measured) true vertical 8764 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 104' 20" 1840# Poleset 134' 134' Surface 2475' 13-3/8" 2700 sx CS III, 400 sx 2505' 2505' CS II Production 9993' 9-5/8" 800 sx Class 'G', 300 sx 10023' 8481' ASI Scab Liner 891' 4-1/2" 200 sx Class 'G' 9848' - 10739' 8337' - 9114' Perforation depth: measured Open Perfs 10284'-10294',10295'-10300', Perfs below BIP 10396'-10400',10446'-10458' true vertical Open Perfs 8708'-8716',8718'-8722', Perfs below BIP 8805'-8808',8849'-8859' Tubing (size, grade, and measured depth) 4-1/2",12.6#, 13-CR-80 @ 9868' MD. RE€EIVED Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" BKR S-3 Packer @ 9812'; 9-5/8" x 4-1/2" BKR ZXP Packer @ 9855' 4-1/2" HES X Nipple @ 2200' MD. NOV 0 6?OO? 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Alaslèa 01.& Gas Gons. Commission Treatment description including volumes used and final pressure Anchorage 14. Representative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Met Water-Bbl 654 1005 1699 Prior to well operation 10103/2002 Subsequent to operation 10/21/2002 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations - Oil _X Gas - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. D~~~ 597 Form 10-404 Rev 06/15/88 . Casing Pressure Tubing Pressure 174 176 1942 16. Status of well classification as: Title: Technical Assistant 1798 Suspended - Service Date October 22.2002 P'e,,,e' by DeW.yne R. Sohoon 564'~ SUBMIT IN DUPLICATE 08/22/2002 09/02/2002 09/25/2002 09/26/2002 09/29/2002 1 % 1/2002 10/01/2002 10/07/2002 10/07/2002 10/08/2002 10/08/2002 10/09/2002 10/13/2002 10/13/2002 10/14/2002 10/14/2002 10/15/2002 10/19/2002 11-17A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS RWO CAPITAL: JEWELRY LOG--DEPTH CONTROL; PERFORATING PERFORATING: PERFORATING RWO CAPITAL: PROFILE MODIFICATION RWO CAPITAL: ACID TREATMENT ANNCOMM TESTEVENT RWO CAPITAL: PRODUCTION PROFILE RWO CAPITAL: PERFORATING PERFORATING: PERFORATING PERFORATING: PERFORATING RWO CAPITAL: PERFORATING PERFORATING: LOAD WELL TO SECURE PPROF: FISH PERFORATING: FISH; LOAD WELL TO SECURE PERFORATING: FISH; LOAD WELL TO SECURE PERFORATING: FISH PERFORATING: DRIFT/TAG TESTEVENT --- BOPD: 621, BWPD: 1,792, MCFPD: 5,709, AL Rate: 3,505 EVENT SUMMARY 08/22/02 LOG JEWELRY FROM 10639"(TD) TO 96801 (1ST GLM) . PERFORATE 104461- 104581,103961-10400' & 102951-10300 IN THREE RUNS WITH 2-7/8I1PJ (2906 HMX), 6 SPF, 60 DEG PHASING. ALL SHOTS FIRED. WHP REMAINED 0 PSI. NOTIFY DSO OF STATUS - WELL READY TO BOL. 09/02/02 COMPLETED REPERF. PERFORATED FROM 10295'-10300' MD. SHOT GUN UNDERBALANCED WITH WELL FLOWING AT 38 DEGREE CHOKE. AFTER OPEN WING BEFORE SHOT, PRESSURE DROPPED FROM 1600-1200 PSI. WELL LEFT FLOWING. PAD OPERATOR NOTIFIED OF WELL STATUS. 09/25/02 MIRU DS CTU #8. LOAD WELL WITH 10/0 KCL. RIH WITH BAKER INFLATABLE PACKER. SET PACKER @ 10348' CTMD, SET 5K DOWN WEIGHT ON PACKER AND MAINTAINED THROUGHOUT ACID TREATMENT. ATTEMPTING TO BLEED DOWN IA THROUGH 1/211 HOSE. 09/26/02 CTU #8 ACID TREATMENT. PUMPED 51 BBLS 7.5°10 HCL, 52 BBLS 2°1o KCL AND 33 BBLS MEOH. PRE ACID TREATMENT INJECTIVITY 1050 PSI AT 2 BPM. CLIMBED TO 1175 PSI THEN STABLlZED AT 900 PSI WHEN HCL AT PERFS. PRESSURE STARTED TO CLIMB AS SOON AS OVER FLUSH HIT PERFS, 1075 PSI AT END OF 2°1o KCL OVER FLUSH. (IRON PPM = 1000) (ACID TRITATIONS = 7.6). Page 1 ( ( 11-17A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/29/02 ANNCOMM --- T/I/O = 690/1300/350, MONITOR TROUBLE WELL WHP's. HAS SIGN. 10/01/02 TESTEVENT --- BOPO: 591, BWPO: 1,857, MCFPO: 4,870, AL Rate: 3,505 10/01/02 COMPLETED PRODUCTION PROFILE. PERF INTERVAL CONTRIBUTIONS: 490/0 FROM 102951 - 103001, 19% FROM 103961 - 10400' AND 32% FROM 10446' - 10458'. LEFT WELL FLOWING. 10/07/02 PUMP 286 BBLS OF WATER AT 4.5 BPM AND 40 BBLS OF 180 DEG DIESEL AT 1.5 BPM DOWN THE TUBING. ASSISTING E-LlNE, PERF. 10/07/02 COMPLETED ADD PERF. PERFORATED FROM 10284'-10294'. SHOT UNDERBALANCE WITH WELL FLOWING AT 200 PSI WHP. WELL SHUT IN TO POOH AND GET STUCK At 650 FT. 10/08/02 SPENT PERF GUN (17' OAL) STILL STUCK IN TBG, DROPPED KINLEY CUTTER, RECOVERED 15' OF 0.223" CABLE. CLOSED BOP's, RD LUBRICATOR AND CAPPED BOPS. BLED IA TO 1700 PSI, PUMPED SEAWATER KILL, FINAL WHP = 150 PSI. COULD NOT CLOSE SWAB OR MASTER VALVES. SECURED WELL WITH BOP1s AND WATCH. 10/08/02 PUMPED 300 BBLS OF WATER AND 50 BBLS 50/50 METHANOL DOWN THE TUBING. 10/09/02 «< LOAD & KILL / SECURE WELL.... (WIRELlNE TOOLS ACROSS MASTER & SWAB VALVES) »> NOTIFY PAD OPERATOR. MI/RU DOWELL AND LITTLE RED PUMP UNITS. FREEZE PROTECT FLOWLINE. CONFIGURE VALVES ON TREE TO ACCOMODATE PUMP UNIT ... , (BLEED & BLIND AIL LINE, ADD SECOND I/A VALVE). PUMPED 5 BBLS METHANOL, 525 BBLS FLUID, 84 BBLS 50/50 METHANOL, 27 BBLS CRUDE, AND 6 BBLS METHANOL DOWN IA TO KILL WELL. 10/13/02 PUMP 13.5 BBLS 50/50 METH-WATER DOWN TUBING TO FILL VOID, DETERMINED WELL IS ON VACUM****STANDBY WHILE HES FISHES TOOLSTRING. 10/13/02 RUN 2 -1/2" SB. PULL KINLEY CUTTER @ -11' SLM. RUN BAITED 2.63" WIRE GRAB. GRAB WIRE @ -121. JAR UP. GAIN 4'. USE CRANE TO PULL WIRE OPEN HOLE. FISHING JOB CONTINUED ON NEXT DAY. 10/14/02 PULL ALL OF E-LlNE WIRE W/CRANE OPEN HOLE; FISHED OUT E-LlNE TOOLS; SECURE WELL. «< WELL LEFT SHUT-IN »> Page 2 . ( 11-17A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 10/15/02 DRIFTED DOWN TO XN NIPPLE W/ 4 1/2 GR AND BAIT SUB W/ BOWEN WIRE FINDER ( 3.75 ), WIRE SCRATCHER, AND WIRE GRAB. NO OBSTRUCTIONS TAGGED XN @ 9840' SLM. «< PAD OPERATOR TO PUT ON PRODUCTION »> 10/19/02 TESTEVENT --- BOPD: 621, BWPD: 1,792, MCFPD: 5,709, AL Rate: 3,505 BBLS 4 11 242 50 40 570 70 1689 61 61 51 2849 Fluids Pumped PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 3 TESTS) NEAT METHANOL 50/50 METHANOL WATER 60/40 METHANOL WATER DIESEL 10/0 KCL WATER 20/0 KCL WATER SEAWATER CRUDE FLOPRO 7.5% HCL ACID TOTAL ADD & RE PERFS THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2-7/811 PJ (2906 HMX), 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 08/22/2002 09/02/2002 10/07/2002 102951 - 103001 10396' - 10400. 10446' - 10458' 102951 - 10300' 10284' - 10294' Page 3 Scblumbepgel' Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job# PSI-10 c:6lf\~-l,C\9 D.S.1-22A I Q4...Jh6 D.S. 11-17A ~~-lk~ TEMP & PRESS LOG PRODUCTION PROFILE PRODUCTION PROFILE Log Description Date 10/14/02 10/07/02 10/01/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: ~=t~:~~:no~:~:~t:\R2-1 RECE\VED 900 E. Benson Blvd. Anchorage, Alaska 99508 NOV 0 1 2002 Date Delivered: fda8R Q~ & ~AA ConS. eommis8ÏOO And\orage Blueline NO. 2513 Company: 10/24/02 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia 1 1 1 Color Prints CD Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Received~~ ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well a Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface ",,''''''''''.'''.''''-'''''''''--¡ 770' SNL, 666' EWL, SEC. 34, T11 N, R15E, UM ¡ GOVPU::nON ~ At top of productive interval I DÞTE. i 5206' SNL, 326' EWL, SEC. 34, T11 N, R15E, UM i-I> ¡.. ~~~ì At total depth J \!~:JS' 1 102' SNL, 194' EWL, SEC. 03, T10N, R15E, UM ~ -~_._,_.~... Ì "': ' . ~ 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Dèšígrïätlon and Serial No. KBE = 53.85' ADL 028328 12. Datej3l.e . pUdded. 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. ~002 ,;§p 8/6/2002 8/22/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10740 9115 FT 10655 9037 FT a Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, DEN, NEW, RES 23. CASING SIZE 20" 13-3/8" 9-5/8" 4-1/2" Classification of Service Well 7. Permit Number 202-032 8. API Number 50- 029-21598-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 11-17A 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2200' MD 1900' (Approx.) -r/¿J4£6-w /oc:>,¿z"~'þ Vyf"ø '>?'YÞ WT. PER FT. 91.5# 68# /72# 47# 12.6# GRADE H-40 K-55/ L-80 L-80 13Cr80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 104' 30" 1840# Poleset Surface 2505' 17-1/2" ;2.700 sx CS III, 400 sx CS II Surface 10023' 12-1/4" 800 sx Class 'G', 300 sx AS I 9848' 10739' 6-1/8" 200 sx Class 'G' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-7/8" Gun Diameter, 6 spf MD TVD 10295' - 10300' 8718' - 8722' 10396' - 10400' 8805' - 8808' 10446' - 10458' 8849' - 8859' 25. SIZE 4-1/2", 12.6#, L-80 MD TVD AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 9870' PACKER SET (MD) 9812' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 150 Bbls of Diesel Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA '; Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core c*f (" t I V t 0 26. 27. Date First Production August 23, 2002 Date of Test Hours Tested 9/24/2002 10 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL-BBL TEST PERIOD 699 GAs-McF 1,132 GAs-McF WATER-BBL 1,896 WATER-BBL OIL-BBL No core samples were taken. OCT 1 0 RBOMS 8Fl Form 10-407 Rev. 07-01-80 0 I G I CHOKE SIZE 84.17 OIL GRAVITY-API (CORR) GAS-OIL RATIO 1,620 SEP 21 2002 Alaska Oil & Gas Qons. Commission Anchorage 0F ,- Submit In Duplicate ( ( 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GaR, and time of each phase. Sadlerochit / Zone 4 10102' 85481 Zone 3 10257' 8685' Zone 2 103381 8755' Zone 1 B 105941 89811 RI€&IVED SEP 2 7 2002 AlasRa 01& Gas GorIs. Commission Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the fO~Oi~9 is true and correct to the best of my knowledge Signed Terrie Hubble /'f~ ~ Title Technical Assistant Date eft. 'J.-.. 7". O:l.. 11-17 A 202-032 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Dave Wesley, 564-5773 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: 11-17 Common Name: 11-17 Test Dêtte 8/4/2002 Test Type FIT BP Leak-Off TesfSu_mmary Test Depth (TMD) 10,023.0 (ft) Test Depth (TVD) 8,505.0 (ft) AMW 9.00 (ppg) Surface Pressure 710 (psi) Leak Off Pressure (BHP) 4,686 (psi) Page 1 of 1 EMW 10.61 (ppg) ~ ....-.." Printed: 8/12/2002 2:45:55 PM (' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-17 11-17 REENTER+COMPLETE Start: Rig Release: Rig Number: 8/10/2002 Spud Date: 5/26/1986 End: 7/28/2002 00:00 - 18:00 18.00 RIGU P DECOMP Trouble shoot Top Drive. Repair welds in pits. Gave rig 3 hours credit for well operations simlumtaneously completed during weld repair of pits. Accepted rig at 1500 hpours. 18:00 -18:30 0.50 RIGU P DECOMP Pre Spud safety meeting. 18:30 - 19:00 0.50 RIGU P DECOMP Pressure test surface lines to 3000 psi. 19:00 - 23:30 4.50 RIGU P DECOMP Displaced freeze protection with 50 bbl Condit pill and seawater. Circulated 75 bbl over calculated. Well out of balance. Reverse circulate annular volume to tubing cut at 3025'. Monitor well. Static. 23:30 - 00:00 0.50 RIGU P DECOMP Set BPV in FMC gen 4 hanger. 7/29/2002 00:00 - 02:00 2.00 RIGU P DECOMP ND tree and check and dress threads on the tubing hanger. 02:00 - 05:30 3.50 RIGU P DECOMP NU BOP's 05:30 - 10:30 5.00 RIGU P DECOMP Test BOP 10:30 - 11 :30 1.00 PULL P DECOMP Pull Blanking Plug. RD test equipment. 11 :30 - 12:30 1.00 PULL P DECOMP Pull BPV with lubricator. 12:30- 13:30 1.00 PULL P DECOMP Make Up landing joint. Engage tubing hanger. Back out lock down bolts. 13:30 - 14:00 0.50 PULL P DECOMP PJSM. Pull 160K to unseat hanger. Increase to 250K fell back to 175K continued to pull to 250K. Tubing parted. String WT 73K 14:00 - 15:00 1.00 PULL P DECOMP Inspect derrick. 15:00 - 15:30 0.50 PULL P DECOMP Pull tubing hanger to rig floor and lay down same. 15:30 - 16:30 1.00 PULL P DECOMP RU tubing handling equipment and control line spooler. 16:30 - 19:00 2.50 PULL P DECOMP Laydown 5-1/2" tubing to SSSV. 19:00 - 20:00 1.00 PULL P DECOMP Laydown SSSV and RD Camco spooler. 20:00 - 21 :00 1.00 PULL P DECOMP Laydown 5-1/2" tubing to cut-off. 21 :00 - 22:00 1.00 PULL P DECOMP Set test plug. Test bottom variables. Pull test plug. 22:00 - 23:30 1.50 PULL P DECOMP PU Fishing BHA #1 23:30 - 00:00 0.50 PULL P DECOMP PU 5-1/2" work string and RIH to fish tubing. 7/30/2002 00:00 - 03:30 3.50 PULL P DECOMP Continue picking up 5-1/2" tubing and RIH to top of fish. 03:30 - 04:00 0.50 PULL P DECOMP UP 74K dn74K. Tag top of fish at 3037'. Swallow 8' to 3045. Set down 10K. PU to 255K. Pull free. UP wt 175K. 04:00 - 06:00 2.00 PULL P DECOMP Circulate 45 bbl Condit pill 215 SPM @ 180 psi. 06:00 - 06:30 0.50 PULL P DECOMP Pump dry job. 06:30 - 10:00 3.50 PULL P DECOMP POH lay down 5-1/2" work string. 10:00 - 10:30 0.50 PULL P DECOMP LD over shot 10:30 - 19:30 9.00 PULL P DECOMP LD 5-1/2' tubing and Seal stem. 19:30 - 20:00 0.50 PULL P DECOMP Install wear ring. 20:00 - 22:30 2.50 PULL P DECOMP PU BHA #2 Packer Milling Assy. 22:30 - 23:30 1.00 PULL P DECOMP General maintenance on top drive. 23:30 - 00:00 0.50 PULL N RREP DECOMP Top drive downtime to change out electrical pin board for backup wrench. 7/31/2002 00:00 - 07:30 7.50 PULL P DECOMP PU drill pipe while RIH. 07:30 - 08:30 1.00 PULL P DECOMP Break circulation 115 psi at 3BPM. Tag top of packer @ 9883'. Shut down pump and slack off 14'. Set down 10-15K. PU 15K to verify packer is latched. 08:00 - 21:00 13.00 PULL P DECOMP Mill packer. 115 psi @ 3 bpm. 90 rpm. Made 1.5 feet. Spinning on junk. Tried various RPM's, with and without pumps, Spudding etc. After much persistance got some torquing and drill-off. PU and Pulled free. 21 :00 - 22:30 1.50 PULL P DECOMP CBU 12 bpm @ 1950 psi. Circulate out packer gas. Monitor well. " Static." 22:30 - 00:00 1.50 PULL P DECOMP POH from 9860' to 8425'. Printed: 8/1212002 2:46:07 PM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8/1/2002 8/2/2002 8/3/2002 11-17 11-17 REENTER+COMPLETE From -To Hours Task Code NPT Phase 00:00 - 04:30 4.50 PULL P 04:30 - 05:00 0.50 PULL P 05:00 - 07:00 2.00 PULL P 07:00 - 08:00 1.00 PULL P 08:00 - 10:00 2.00 PULL P 10:00 -11 :00 1.00 PULL P 11 :00 -12:30 1.50 PULL N 12:30 - 13:00 0.50 PULL N 13:00 -15:30 2.50 PULL N 15:30 - 16:30 1.00 PULL P 16:30 - 17:30 1.00 PULL P 17:30 - 18:00 0.50 PULL P 18:00 - 20:00 2.00 PULL P 20:00 - 22:00 2.00 PULL P 22:00 - 00:00 2.00 PULL P 00:00 - 02:00 2.00 PULL P 02:00 - 03:30 1.50 PULL P 03:30 - 04:00 0.50 PULL P 04:00 - 08:30 4.50 PULL P 08:30 - 09:30 1.00 PULL P 09:30 - 10:00 0.50 PULL P 10:00 - 10:30 0.50 PULL P 10:30 - 11 :00 0.50 PULL P 11 :00 - 11 :30 0.50 PULL P 11 :30 - 12:30 1.00 PULL P 12:30 - 13:00 0.50 PULL P 13:00 -14:30 1.50 PULL P 14:30 - 15:00 0.50 PULL P 15:00 - 16:00 1.00 PULL P 16:00 - 16:30 0.50 PULL P 16:30 - 17:30 1.00 PULL P 17:30 - 19:00 1.50 PULL P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DFAL DECOMP DFAL DECOMP DFAL DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 19:00 - 20:00 1.00 PULL P DECOMP 20:00 - 00:00 00:00 - 01 :30 01 :30 - 03:30 03:30 - 08:30 4.00 PULL P 1.50 PULL P 2.00 STWHIP P 5.00 STWHIP P DECOMP DECOMP WEXIT WEXIT 08:30 - 10:00 1.50 STWHIP P WEXIT 10:00 - 16:00 16:00 - 18:00 6.00 STWHIP N 2.00 STWHIP N DFAL WEXIT DFAL WEXIT Start: Rig Release: Rig Number: Spud Date: 5/26/1986 End: 8/10/2002 Description of Operations POH with packer milling assembly and packer tailpipe assembly. Stand back collars. LD overshot packer milling assembly and packer. Clear rig floor MU and RIH with milling assembly to 950'. Shallow hole test MWD. 12bpm at 1450 psi. Failed to operate. POH. Change out MWD pulser. RIH and shallow hole test MWD. Continue to RIH to 9740' Slip and cut drill line. Service top drive. MAD pass 9740' to 10019', Tag liner stub @ 10019'. Change over to mud 8.4 ppg Quick Driln MiII3-1/213 CR liner from 10,019' to 10,034'. UP 190K, DN 160K, RT 175K, TQ Off 7, TQ ON 11-12 Mill to 10045' planned milling depth = 24' below top of Shublik as picked by MWD. Circulate hole clean. Pump dry job, POH. LD BHA. Pressure test well bore. Lost 400 psi in 15 min. Service wear ring. Flush stack and function test rams. PU RTTS. RIH to 2515'. Test casing from 2515 to surface to 3000 psi for 15 minutes. OK. RIH to 5040'. Test casing from 5040' to surface to 3000 psi for 15 minutes. OK. RIH to 7558'. Test casing from 7558' to surface to 3000 psi for 15 minutes. OK. RIH to 9987'. Test casing from 9987' to surface to 3000 psi for 30 minutes, Lost 200 psi. Tested below packer to 3000 psi for 15 minutes OK. PU to 9870' and Test casing from 9870' to surface to 3000 psi for 30 minutes. OK. POH. LD milling BHA. MU whipstock and whipstock milling assembly. RIH. Surface check MWN @ 916', OK, RIH to 9,994' filling pipe at 4,000' and 6,950'. Break circulation at 2 bpm. MWD OK. Increased rate 3.5 bpm. Pressure suddenly ¡ncleased from 400 psi to 3000 psi. Attempt to surge pipe to regain circulation. No Luck. Reverse circulate at minimum rate. Attempt to establish circulation. No Luck. POH. Stand back HWDP and DC's. Break and check MWD OK , Printed: 8/12/2002 2:46:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-17 11-17 REENTER+COMPLETE Start: Rig Release: Rig Number: 8/10/2002 Spud Date: 5/26/1986 End: 8/312002 16:00 - 18:00 2.00 SlWHIP N DFAL WEXIT Floats OK, Unpin whipstock. Break out starter mill. Mill packed with 1.5' of fine metal shavings. Clean out mill and flush. 18:00 - 20:00 2.00 SlWHIP N DFAL WEXIT MU Whipstock BHA. 20:00 - 20:30 0.50 SlWHIP N DFAL WEXIT Surface check MWD at 940' OK. 20:30 - 00:00 3.50 SlWHIP N DFAL WEXIT RIH filling every 20 stands to 8000' and then every10 stands. Wash last 5 stands to bottom. 8/4/2002 00:00 - 02:00 2.00 SlWHIP N DFAL WEXIT RIH to 9622 breaking circulation every 20 stands. Wash from 9,622' to 9,994', @ 7bpm 900 psi. 02:00 - 03:00 1.00 STWHIP P WEXIT Orient Whipstock..UP 190K, DN 160K, Set Whipstock at 74R. Set down 20K to shear slips. PU to 170K to confirm the slips were set. Set down 45 K to shear off whipstock. TOW @ 10,023'. 03:00 - 11 :00 8.00 SlWHIP P WEXIT Milling window with 2-3ZK on bit 200 psi 103 SPM each pump. TO 12000 ft-Ibs. Mill window from 10023' to 10039' + 13 ' of open hole to 10052'. Work window with pumps off OK. Recovered 104 # of metal. UP 190, DN 160, ROT 170, TO off 8/9K, TO on 10/12K. 11 :00 - 12:30 1.50 SlWHIP P WEXIT Circulate sweeps @ 12 bpm 2030psi @ 9970'. A total of two sweeps pumped. 12:30 - 13:00 0.50 SlWHIP P WEXIT Perform FIT test 700 psi with 8.4 ppg mud = EMW of 10.0 ppg. Bleed off 50 psi in 5 min. 13:00 - 13:30 0.50 SlWHIP P WEXIT Pump dry job. 13:30 - 14:30 1.00 SlWHIP P WEXIT Cut and slip drilling line. 14:30 - 15:00 0.50 SlWHIP P WEXIT Service top drive replace RPM sensor. 15:00 - 15:30 0.50 SlWHIP N RREP WEXIT Repair hydraulic leaks on top drive. 15:30 - 21 :00 5.50 STWHIP P WEXIT POH. LD BHA. Upper string mill in gauge. 21 :00 - 22:00 1.00 SlWHIP P WEXIT Clear floor and flush stack. 22:00 - 22:30 0.50 SlWHIP P WEXIT RU test joint and testing tools. 22:30 - 00:00 1.50 SlWHIP P WEXIT Test BOP. Witnessing waived by John Crisp AOGCC. 8/5/2002 00:00 - 01 :30 1.50 SlWHIP P WEXIT Complete BOP test. 01 :30 - 04:30 3.00 STWHIP P PROD1 MU BHA #6 for drilling 6-1/8" hole. Load 04:30 - 08:30 4.00 STWHIP P PROD1 RIH to 10052'. Filled pipe at 2790',4647',6525',8390', & 9887'. Orient 80 deg R @ 9981'. No problems going thru window. 08:30 - 00:00 15.50 STWHIP P PROD1 Directionally drill 6-1/8" hole to 10610'.190 UP, 150 DN, 170 ROT, TQ 6 off and 8 on bottom. Total ART = 7.4 and Total AST = 5.3. Kavik drilling at 20 FtlHr no hole problems. 8/6/2002 00:00 - 06:30 6.50 DRILL P PROD1 Directionally drill 6-1/8" hole to 10,740' TD, with 1.15 deg motor. ART = 6.5 hr, AST = 0 hr. UWT= 200K, DWT= 145K, ROT= 170K, Torque offl on = 9K ft-Ib. 06:30 - 07:00 0.50 DRILL P PROD1 Sweep hole, monitor well. POOH to 9,981', inside casing. No over pull, 'no problems. 07:00 - 07:30 0.50 DRILL P PROD1 Service Top Drive. 07:30 - 08:00 0.50 DRILL P PROD1 RIH to 10,740', no problems. 08:00 - 10:30 2.50 DRILL P PROD1 Sweep hole at 6 BPM and 1800 psi. Spot liner pill in open hole with 4% lubricants. 10:30 - 11 :00 0.50 DRILL P PROD1 Drop ESS (set up to be a 1-7/8" rabbit also). 11 :00 - 12:00 1.00 DRILL P PROD 1 POOH to 9,981'. Slug pipe. Continue POOH to 9,300'. 12:00 - 15:30 3.50 DRILL P PROD 1 POOH to BHA, change out handling tools. 15:30 - 17:00 1.50 DRILL P PROD1 LD BHA. PJSM. 17:00 -19:00 2.00 DRILL P PROD1 Remove RA sources from MWD. Download data. 19:00 - 20:30 1.50 DRILL P PROD1 Clear rig floor, RU casing handling equipment. PJSM. 20:30 - 21 :00 0.50 DRILL P PROD1 MU and thread lock shoe track. Test float equipment - okay. 21 :00 - 22:00 1.00 DRILL P PROD 1 RIH with 21 jts of 4-1/2", 12.6 Ib/ft, L-80, IBT-M liner. Average Printed: 8/1212002 2:46:07 PM ( ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-17 11-17 REENTER+COMPLETE Start: Rig Release: Rig Number: 8/10/2002 Spud Date: 5/26/1986 End: From- To Hours Task .Code NPT Phase 8/6/2002 21 :00 - 22:00 1.00 DRILL P PROD1 MU of 4,000 ft-Ib using Best-O-Life 2000 thread compound. MU HMC hanger and ZXP liner top packer. C/O handling equipment. 22:00 - 22:30 0.50 DRILL P PROD1 RU and circulate liner volume. 22:30 - 00:00 1.50 DRILL P PROD1 RIH with 4" DP filling every 10 stands. 817/2002 00:00 - 03:30 3.50 CASE P PROD1 Continue to RIH with 4" DP, to 10,023', filling every 10 stands. 03:30 - 04:00 0.50 CASE P PROD1 Circulate liner plus drillpipe volume at 6 BPM, 640 psi. UWT= 180K, OWT= 135K. 04:00 - 04:30 0.50 CASE P PROD1 RIH in open hole to 10,740'. 04:30 - 05:00 0.50 CASE P PROD1 MU cement head. 05:00 - 07:00 2.00 CASE P PROD 1 Break circulation slowly, increase to 7 BPM and 1,510 psi. Circulate hole and reciprocate pipe. UWT= 190K, DWT= 145K. RU cementing equipment, hold PJSM, batch mix cement. 07:00 - 08:00 1.00 CASE P PROD1 Pump 5 bbls of fresh water and test lines to 4500 psi. Pump 5 bbl of water and 30 bbl Alpha spacer weighted to 9.7 ppg. Pump 39 bbl (184 sx) class "G" LATEX cement at 15.9 ppg, yielding 1.15 ft3/sx, with 0% FW and 50 WL. Drop wiper Dart and displace using cementing unit, with 32 bbl perf pill plus 78 bbl of mud, at 6 BPM. Bump plug. Cement in palce at 07:50 hrs. Pressure up to 4,000 psi and set liner hanger. Bleed pressure off, check floats - okay. Release from liner, pick up, circulate to clear cement from liner top. 08:00 - 09:00 1.00 CASE P PROD1 Displace excess cement from above liner at 12.5 BPM and 2,440 psi. Trace of cement in returns. 09:00 - 09:30 0.50 CASE P PROD1 Set down with 70K Ibs to set ZXP liner top packer. Repeat set down of 70K while rotating. UWT= 170K, DWT= 135K. 09:30 - 11:30 2.00 CASE P PROD1 Displace well to clean seawater at 12 BPM and 2,820 psi. 11 :30 - 12:00 0.50 CASE P PROD1 Lay down cement head. 12:00 - 16:00 4.00 CASE P PROD1 POOH to 5,000', laying down 4" drillpipe. 16:00 - 17:30 1.50 CASE P PROD1 Cut and slip 102' of drill line. (Repair hydraulic leak on iron roughneck). 17:30 - 21 :00 3.50 CASE P PROD1 Continue POOH laying down DP. 21 :00 - 22:00 1.00 CASE P PROD1 Lay down and inspect C-2 running tool- okay. 22:00 - 22:30 0.50 CASE P PROD1 PuIlWB. 22:30 - 23:00 0.50 CASE P PROD1 Pressure test 4-1/2" x 9-5/8" casing to 3,000 psi - okay. 23:00 - 00:00 1.00 CASE P PROD1 RU casing equipment. 8/8/2002 00:00 - 00:30 0.50 RUNCO~ P COMP Continue to RU casing equipment. 00:30 - 01 :00 0.50 RUNCO~rp COMP MU and thread lock all tailpipe connections, below the packer. 01 :00 - 04:00 3.00 RUNCOIVP COMP Run 24 jts of 4-1/2" 12.6Ib/ft, 13CR, VAM-ACE tubing, with 3,620 ft-Ib average MU. Laid down GLM #2 and sent in for a replacment pup joint. Changeout GLM and tbg collar. 04:00 - 07:00 3.00 RUNCO~ J..J SFAL COMP Trouble shoot Torque-Turn equipment. Change out Mode Box, Wire and computer. 07:00 - 20:00 13.00 RUNCO~P COMP Continue to run 4-112" 12.6Ib/ft, 13CR, VAM-ACE tubing, with 3,620 ft-Ib average MU. Laid down and replaced 8 joints of tubing, changeout 8 tubing collars. Several connections had to be backed. out and re-made up. (Rough areas were seen on the last 3-4 threads on most tbg pin connections, and also several shoulders of the box connections). 20:00 - 20:30 0.50 RUNCO~ J..J SFAL COMP Trouble shoot Torque..Turn equipment. Change out Mode Box on the casing tongs. 20:30 - 23:00 2.50 RUNCO~P COMP Continue to run 226 jts (total) of 4-1/2" 12.6 Ib/ft, 13CR, VAM-ACE tubing, with 3,620 ft-Ib average MU. Printed: 8/1212002 2:46:07 PM ( ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11-17 11-17 REENTER+COMPLETE Date From - To. Hours Task.Code NPT Phase 8/8/2002 23:00 - 00:00 1.00 RUNCO"P COMP 8/9/2002 00:00 - 01 :00 1.00 RUNCO"P COMP 01 :30 - 05:00 3.50 RUNCO" P COMP 05:00 - 07:00 2.00 RUNCO" P COMP 07:00 - 07:30 0.50 BOPSUR P COMP 07:30 - 08:00 0.50 BOPSUR P COMP 08:00 - 11 :00 3.00 BOPSURP COMP 11 :00 - 11 :30 0.50 WHSUR P COMP 11 :30 - 12:00 0.50 WHSUR P COMP 12:00 - 12:30 0.50 WHSUR P COMP 12:30 - 14:30 2.00 WHSUR N SFAL COMP 14:30 - 15:00 0.50 WHSUR P COMP 15:00 - 17:30 2.50 WHSUR P COMP 17:30 - 18:00 0.50 WHSUR P COMP 18:00 - 19:00 1.00 WHSUR P COMP Start: Rig Release: Rig Number: Spud Date: 5/26/1986 End: 8/10/2002 Description of Operations Space out with 3.76' + 10.22' + 10.29' pup jts. DWT= 10aK, UWT= 130K. Make up tbg hanger and landing joint. Land tubing and run in LDS. Displace well with clean seawater + corrosion inhibitor, circulating at 3 BPM. Drop Bar + Rod, set packer and pressure test tubing to 3,000 psi for 30 minutes. Bleed off tbg pressure to 1 ,500 psi and pressure test annulus to 3,000 psi. Pressure communicated with tbg. Bleed down pressure on casing and tubing. Pressure tubing to 3,500 psi and set packer. Pressure up tbg to 1,500 psi and casing to 3,000 psi and test annulus + packer for 30 min. Bleed down tbg pressure and shear RP valve. Install BPV and test from below to 2,000 psi. Blow down surface equipment. ND BOPE, NU Tree Test adaptor void to 5,000 psi for 10 min. RU lubricator and pull BPV. Set Test plug and attempt to test tree to 5,000 psi. Test plug leaking. RU lubricator and attempt testing. Pull Test plug and change out. Test tree to 5,000 psi for 10 minutes- okay. Pull test plug with lubricator. LD lubricator. RU hoses from Hot Oil unit, test to 3,000 psi for 10 minutes. Reverse circulate 150 bbl of diesel freeze protect at 3 BPM and 700 psi. U-tube diesel. Install BPV and test from below to 2,000 psi for 10 min. Secure tree, Install secondary annulus valve. RELEASE RIG: 19:00 hrs, AUG 09,2002 Printed: 8/1212002 2:46:07 PM ( ( Well: Field: API: Permit: 11-17A Prudhoe Bay Unit 50-029-21598-01 202-132 Rig Accept: 07/28/02 Rig Spud: 08/05/02 Rig Release: 08/09/02 Drilling Rig: Nabors 2ES POST RIG WORK 08/14/02 PULL BALL AND ROD FROM RHC PLUG @ 9849' WLM. PULL RP SHEAR VALVE FROM ST# 8 @ 3004' WLM. PULL DGLV'S FROM ST# 6 AND 7. SET DGLV IN ST # 8, SET LGLV(1500# PRESSI 1/4 PORT)IN ST# 7 AND S/OGLV(5/16) IN ST# 6. 08/15/02 PULL RHC PLUG BODY. RUN 33/8 DUMMY GUNISAMPLE BAILER. SET DOWN @ 10156' WLM. COULD NOT MAKE ANY FURTHER HOLE. SAMPLE BAILER CONTAINED 1/2 CUP SEMI CURED CEMENT AND THE REST SOFT SLURRY CEMENT. WELL LEFTSHUT IN. 08/17/02 BOP TEST. RIH WI 3" DJN. DRY TAG AT 10176. CLEAN OUT TO 10650'. PUMP 30 BBL BIO SWEEP OFF BTM. CHASE TO SURFACE AT 80%. FP WI METH/WTR TO 2000'. RDMO. 08/18/02 VECO INSTALLS TREECAP FLANGE ON TREE; PIT TREE CAP FLANGE 300/3000, GOOD TEST; DRIFT TBG & TAG FILL WI 2.83 DMY GN TO 10,618' WLM; SAMPLE OF FINE SAND. WELL TO REMAIN SHUT IN. 08/22/02 LOG JEWELRY FROM 10639'(TD) TO 9680' (1ST GLM). PERFORATE 10446'-10458',10396'-10400' & 10295'- 10300 IN THREE RUNS WITH 2-7/8"PJ (2906 HMX), 6 SPF, 60 DEG PHASE. ALL SHOTS FIRED. WHP REMAINED 0 PSI. NOTIFY DSO OF STATUS - WELL READY TO BOL. 09/02/02 COMPLETED HEPERF. PERFORATED FROM 10295'-10300' MD. SHOT GUN UNDERBALANCED WITH WELL FLOWING AT 38 DEGREE CHOKE. AFTER OPEN WING BEFORE SHOT, PRESSURE DROPPED FROM 1600- 1200 PSI. WELL LEFT FLOWING. PAD OPERATOR NOTIFIED OF WELL STATUS. 09/25/02 LOAD WELL WITH 1% KCL. RIH WITH BAKER INFLATABLE PACKER. SET PKR AT 10348' CTMD, SET 5K DOWN WEIGHT ON PACKER AND MAINTAINED THROUGHOUT TREATMENT. ATTEMPTING TO BLEED DOWN IA THROUGH 1/2" HOSE. 09/26/02 ACID TREAT. PUMPED 51 BBLS 7.5% HCL, 52 BBLS 2% KCL AND 33 BBLS MEOH. PRE ACID TREATMENT INJECTIVITY 1050 PSI AT 2 BPM. CLIMBED TO 1175 PSI THEN STABLlZED AT 900 PSI WHEN HCL AT PERFS. PRESSURE STARTED TO CLIMB AS SOON AS OVER FLUSH HIT PERFS, 1075 PSI AT END OF 2% KCL OVER FLUSH. (IRON PPM=1000) (ACID TRITATIONS=7.6). aoa-o~ 19-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 11-17 A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,996.85' MD Window / Kickoff Survey 10,022.00' MD (if applicable) Projected Survey: 10,740.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment( s) f,,! ¡ ,"" f"I ""7'1"\'00'> ¡)-. j.:) L \) L . '" Alaska Oil & Gas Cons. Commission Ancborage North Slope Alaska BPXA PBU_EOA DS 11, Slot 11-17 11-17A Job No. AKMW22126, Surveyed: 6 August, 2002 SURVEY REPORT 14 August, 2002 Your Ref: API 500292159801 Surface Coordinates: 5950973.91 N, 708240.76 E (700 16' 09.8898" N, 1480 18' 56.9095" W) Kelly Bushing: 53. 85ft above Mean Sea Level Sp&r'r'y-sUl1 DRILLING SERVices A Halliburton Company DEFINr-IVE '-'"c ~'" 5U1vey Ref: svy11281 Sperry-Sun Drilling Services . Survey Report for 11-17A Your Ref: API 500292159801 Job No. AKMW22126, Surveyed: 6 August, 2002 BPXA North Slope Alaska PBU_EOA DS 11 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) I 9996.85 34.050 190.600 8405.23 8459.08 4320.81 S 279.65 W 5946647.01 N 708080.76 E 4328.02 Tie On Point .~ MWD Magnetic 10022.00 34.040 190.680 8426.07 8479.92"" 4334.65 S 282.25 W 5946633.11 N 708078.54 E 0.182 4342.04 Window Point 10071.86 32.530 196.520 8467.76 8521.61 4361.23 S 288.65 W 5946606.37 N 708072.88 E 7.103 4369.10 10103.19 29.300 200.550 8494.64 8548.49 4376.49 S 293.74 W 5946590.97 N 708068.22 E 12.241 4384.77 10135.20 27.350 204.950 8522.82 8576.67 4390.49 S 299.59 W 5946576.81 N 708062.75 E 8.921 4399.26 10167.64 26.150 209.710 8551.79 8605.64 4403.46 S 306.28 W 5946563.67 N 708056.43 E 7.567 4412.79 10227.42 27.320 219.150 8605.21 8659.06 4425.55 S 321.47 W 5946541.16 N 708041.85 E 7.361 4436.21 10320.66 32.270 220.500 8686.10 8739.95 4461.09 S 351.17 W 5946504.81 N 708013.15 E 5.357 4474.38 10413.50 28.470 216.680 8766.19 8820.04 4497.70 S 380.49 W 5946467.41 N 707984.85 E 4.590 4513.57 10506.66 26.720 215.090 8848.75 8902.60 4532.65 S 405.80 W 5946431.77 N 707960.52 E 2.038 4550.73 10599.84 25.200 215.410 8932.53 8986.38 4565.96 S 429.34 W 5946397.82 N 707937.91 E 1.638 4586.10 10693.94 22.840 215.520 9018.47 9072.32 4597.15 S 451.56 W 5946366.02 N 707916.56 E 2.508 4619.24 10740.00 22.840 215.520 9060.92 9114.77 4611.71 S 461.95 W 5946351.19 N 707906.58 E 0.000 4634.70 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 185.370° (True). - Based upon Minimum Curvature type calculations, at a Measured Depth of 10740.00ft., The Bottom Hole Displacement is 4634. 78ft. , in the Direction of 185.720° (True). 14 August, 2002 - 11:15 Page 2 of 3 DrillQlIest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 11-17A Your Ref: API 500292159801 Job No. AKMW22126, Surveyed: 6 August, 2002 ." North Slope Alaska BPXA PBU EOA DS 11 Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment ~ 9996.85 10022.00 10740.00 8459.08 8479.92 9114.77 4320.81 S 4334.65 S 4611.71 S 279.65 W 282.25 W 461.95 W Tie On Point Window Point Projected Survey Survey tool program for 11-17A From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 9996.85 0.00 9996.85 8459.08 10740.00 8459.08 AK-1 BP _HG - BP High Accuracy Gyro (11-17) 9114.77 MWD Magnetic (11-17A) ~" 14 August, 2002 - 11:15 Page 3 of 3 DrillQuest 2.00.08.005 ( ~~!Æ~E ':} !Æ~!Æ~~~!Æ A.T1A.~1iA. OIL A.lVD GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Robertson . Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchroage AK 99519 Re: Prudhoe Bay Unit 11-17 A BP Exploration (Alaska), Inc. Pennit No: 202-032 Sur Loc: 770' SNL, 666', EWL, Sec. 34, TIIN, RI5E, UM Btmhole Loc. 123' SNL, 191' EWL, Sec. 03, TI0N, R15, UM Dear Mr. Robertson: Enclosed is the approved application for pennit to redrill the above referenced well. The pennit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit 11-17A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ( ~~. ~ ,~tv£ cJæ-t-/ C~Ÿ&echsli Tayloi) Chair BY ORDER OF THE COMMISSION DATED this 15th of February, 2002 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( STATE OF ALASKA ALASKA Ol~. ,ND GAS CONSERVATION COMMIS~.< PERMIT TO DRILL ' 20 AAC 25.005 1;JC~ 'L{ I S¡D2 Ii ? (1,\ JM¡J- .;;-/t5-/DL \J 1 a. Type of work 0 Drill 181 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 770' SNL, 666' EWL, SEC. 34, T11 N, R15E, UM At top of productive interval 5104' SNL, 374' EWL, SEC. 34, T11N, R15E, UM At total depth 123' SNL, 191' EWL, SEC. 03, T10N, R15E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028325, 123' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10021' MD Maximum Hole Angle 18. Casinf) Program Specifications Size Casino Weioht Grade CouplinQ 4-1/2" 12.6# L-80 IBTC Hole 6-1/8" 1b. Type of well 0 Exploratory 0 §tratigraphic Test 181 Development Oil 0 Service 0 Development Gas ErSingle Zone..6Þ 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 52.65' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ~32Ç ~DL 028328. "'¿Ò 7. Unit or Property Namè 11. Type Bond (See 20 AAC 25.025) Prudhoe Bay Unit 8. Well Number 11-17A 9. Approximate spud date 03/01/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10737' MD / 9101' TVD 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 34.3 Maximum surface 2510 psig, At total depth (TVD) 8903' / 3400 psig Setting Depth Top Bottom Quantity of Cement Lenath MD TVD MD TVD (include staQe data) 867' 9870' 8355' 10737' 9101' 180 sx Class 'G' Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Alaska Oil & Gas Cons. Commission 181 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Dfftna~ram 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requi rements Contact Engineer Name/Number: Brian Robertson, 564-4192 Prepared By Name/Number: Terrie Hubble, 564-4628 21.~~:~;~Yc~~~~;;~efO,r~~~i~i~~?:C~;~,~£$i~~~~;":::;... .. Date.. .t Iz~/oz-, Permit Number . API Number Ap~roval Ea~ See cover letter :2-02.,-D32- 50- 029-21598-01 ~J 1'5/0c1\ for otherrequírements Conditions of Approval: Samples Required 0 Yes ,J!(1 No Mud Log Required 0 Yes SfN° Hydrogen Sulfide Measures .Yes 0 No Directional Survey Required ~es 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: n 'Þt- BDt'ii R, š 2J 0 f ~. wGt\- Original Signed By by order of Cemmy Oichsli Commissioner the commission Casing Structural Conductor Surface Intermediate n Production ~¥"~ ~ Ch(St~ Scab Liner Perforation depth: measured true vertical 20. Attachments Approved By Form 10-401 Rev. 12-01-85 10871 feet 9137 feet 9940 feet 8413 feet Length Cemented MD TVD 1840# Poleset 104' 104' 2700 sx CS III, 400 sx CS II 2505' 2505' 800 sx Class 'G', 300 sx AS I 10857' 9127' 33 Bbls LARC Plugs (measured) Set IBP at 9940' (03/97) Junk (measured) Size 104' 20" 2505' 13-3/8" 10857' 9-5/8" 518' 3-1/2" Below IBP: 10292' - 10720' 2 5 Below IBP: 8702' - 9028' Date ~mk fÞ~ate (' \Well Name: 111-17A Drill and Complete Plan Summary I Type of Well (service 1 producer 1 injector): I Producer Surface Location: x = 708,240.8 E Y = 5,950,973.9 770' FNL, 666' FWL, S 34, T-11-N, R-15-E, UM KOP Location: 10,021' MD X = 708,078.2 E Y = 5,946,633.2 N 8479' TVD 5104' FNL, 374' FWL, SEC 34, T-11-N, R-15-E, UM X = 707,904.3 E Y = 5,946,328.8 N 9101' TVD 123' FNL, 191' FWL, SEC 3, T-10-N, R-15-E, UM I AFE Number: 4P1862 I 1 Rig: 1 Doyon 16 -/ I Estimated Start Date: 13/01/2002 I I Operating days to complete: 116 Bottom Hole Location: MD: 10,737' TVD: 9,101' Top Edge Cellar/MSL: 27' KB: 52.65' 1 Well Design (conventional, slim hole, etc.): I Conventional Sidetrack from 9-5/8" Casing 1 1 Objective: 1 Ivishak Zone 1: Romeo / Victor (This is a replacement wellbore) Mud Program: 6-1/8" Production hole: Interval Density Viscosity (ppg) (seconds) 8.3 - 8.5 50 - 70 QuickDril N YP PV Tauo pH (lb/100ft2) 35 5-8 4-8 8.5- 9.0 Production 8.3- 8.5 45 - 60 20 - 25 5-8 4-8 8.5- 9.0 Milling Directional: KOP: I ~ 10,021' MD Maximum Hole Angle: Close Approach Wells: 34.30 None 2 5 Z002 11-17 A Drilling Perm it Application Page 1 ( ( Logging Program: Production Hole Drilling: MWD / GR / DEN / NEU / RES (memory mode) Open Hole: None Cased Hole: None Formation Markers: Formation Tops MD KOP 10,021' SHB 10,021 ' TSAD 10,097' Zone 4 10,097' Zone 3 10,268' Zone 2A 10,511' B/SAD 10,650' Kavik 10,650' TD 10,737' TVDss -8,479' -8,425' -8,498' -8,489' -8,637' -8,850' -8,972' -8,972' -9,048' LinerITubing Program: LnrlTbg WtlFt Grade Conn Comments Based on Schlumberger Jewelry Log 11/93 7.43 ppg EMW, 1 0' vertical uncertainty 7.43 ppg EMW, 1 0' vertical uncertainty 7.43 ppg EMW, 10' vertical uncertainty 7.43 ppg EMW, 10' vertical uncertainty 7.43 ppg EMW, 10' vertical uncertainty / 7.43 ppg EMW, 10' vertical uncertainty, 3400 psi Drill +/- 80' of Kavik for E-Line rat hole. Length Top Btm MDITVD MDITVD 9,870' / 8,355' 10,737' / 9,101' Surface 9,870' / 8,355' 4-1/2" 12.6# L-80 IBTC 867' 4-1/2" 12.6# 13Cr-80 Vam Ace 9,870' Cement Calculations: Casing Size 14-1/2" Liner I Basis: Tail Slurry Based on a fully cemented liner with 500/0 excess, 82' shoe track, 150' of 4-1/2" x 9-518" liner lap, and 200' of cement in the 5" DP x 9-5/8" annulus. TOC: 9,670' MD. I Total Cement Volume: Lead N/A /' Tail 37 bbls 1 207 fe 1 180 sks of Halliburton Premium 'G' + .5% UCS + .5% Super CBL + HR-5 as needed. Mixed at 15.9 ppg and 1.15 cf/sk./ Integrity TestinQ Test Point Test Depth Window 20' MD minimum from the top of the window 11-17 A Drilling Permit Application Test Type FIT EMW 10.5 ppg ,/' Page 2 ( Well Control: For production hole drilling, well control equipment consisting of 5000 psi working pressure variable bore rams (2), blind/shear rams, and an annular preventer will be installed and be capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3,500 psi. BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Max. anticipated BHP (SAD): . Max. surface pressure (SAD): . Planned BOP test pressure: . Planned completion fluid: 3,400 psi (7.4 ppg) in Z9ne 2A 2,510 psi @ surface y/ (Based on eHP and a full column of gas from TO @ 0.10 psi/ft) 3,500 psi / seawater I 2,200' of 7.0 ppg Diesel Drilling Hazards/Contingencies: jiYDROGEN SULFIDE - H2S . Drillsite 11 is designated as an H2S site and Standard Operating Procedures for H2S precautions should be followed at all times. Highest level of H28 recently measured on 08 11: Adjacent wells measured recently: Recent data from nearest BHL: 650 ppm from 11-36, 4/24/01. 169 ppm from 11-16, 4/23/01. 45 ppm from 11-18,3/26/01. DRilliNG CLOSE APPROACH: . There are no close approach issues for this sidetrack. Disposal: ¡ . No annular injection in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at 08-04. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to 08-04 for injection. Haul all Class I wastes to Pad 3 for disposal. 11-17A Drilling Permit Application Page 3 (' DRILL AND COMPLETE PROCEDURE SUMMARY Pre-RiQ Work: * Notify the field AOGCC representative with intent to plug and abandon * 1. Retrieve the 5-1/2" x 3" "Alpha" tubing patch at 2980'. 2. Bail the sand/sluggits off the IBP at 9933'. 3. Retrieve the IBP from the 3.5" liner at 9933' MD. 4. Drift the 3.5" liner to +/- 10,300' with 2.75" tools. 5. Flush the tubing with seawater and bullhead +/- 100 bbls into the perforations. Freeze protect. 6. Run an SCMT in the 3.5" liner: 10300' - 9700'. Find TOC in 3.5" x 9.625" annulus. Notify ODE. 7. Set a CIBP in the 3.5" liner at j: 10125' MD (at least 50' below TOC). 8. Dump 25' of cement on the plug at 10125' MD. PBTD = 10,100'. 9. Jet cut the 3-1/2" liner as follows: 1) must be below the 5-1/2" tubing tail at 10004' (Schlumberger), 2) no deeper than 10043' and 3) at the TOC if the TOC is between 10004' & 10043' (most likely). The idea is to cut and pull as much of the 3-1/2" liner as possible down to 10043'. The liner above the cut will be pulled with the packer and 5-1/2" tubing tail during the de-completion phase. Any of the 3-1/2" liner left in the hole above 10043' must be milled up. 10. Jet cut the 5-1/2" IPC tubing j: 30' above the packer at +/- 9852' (Schlumberger). 11. Circulate the well with seawater. CMIT: Tbg x I_A to 3000 psi. Freeze protect to 2200'. 12. PPPOT the 9-5/8" packoffs to 3000 psi and the 5-1/2" túbing hanger to 4000 psi. Check the LOS for free movement. Set a BPV. 13. Remove the wellhouse and flow lines. Clear and level pad in preparation of the rig move. RiQ Operations: 1. MIRU. Circulate out freeze protection flui~and circulate well to clean seawater. 2. NO tree. NU and test BOPE to 250/3500 psi. 3. Pull and LD 5-1/2" tubing string from the cut at j: 8952'. 4. RIH with a spear on 5" DP. Catch and retrieve the locator seal nipple. POOH. 5. RIH and mill the SB-3 packer with Baker's PRT. Displace with QuikDrill mud while milling the packer. Catch the PKR, tail pipe and upper part of the 3-1/2" scab liner. POOH. Lay down the fish and PRT. ./" 6. RIH with a mill and scraper. Dress off the 3-1/2" stub and cement to 10043'. POOH. 7. Optional: set a CIBP at 10043' if the 3-1/2" liner is not cemented this high up. 8. RIH and orient the whipstock high-side right 80°. 9. Set the Baker bottom trip whipstock on the stub or CIBP (if set). Mill the window. /' 10. Drill the 6-1/8", "build and hold" open hole section as directed to the PTD of 10737' MD. 11. At TO, set & cement a 4-1/2" liner from TO to +/- 9875' MD. /' 12. Run the 4-1/2", 13Chrome completion with S-3 packer. 13. Set BPV. NO BOPE. NU and test the tree. Freeze protect. RDMO. Post-Ria Work: 1. Pull the ball and rod / RHC plug from 'X' nipple below the new production packer. 2. Install gas lift valves as required. 3. Perforate the 4-1/2" liner as directed using E-line. 11-17 A Drilling Permit Application Page 4 ( Job 1: MIRU Hazards and Contingencies ~ W ell 11-18 and 11-16 are located 60' and 59' away from 11-17 A respectively. These wells should not require the well houses to be removed and therefore will not need to be shut in. / ~ HYDROGEN SULFIDE - H2S Drillsite 11 is designated as an H2S site and Standard Operating Procedures for H2S precautions should be followed at all times. Highest level of H2S recently measured on OS 11: Adjacent wells measured recently: Recent data from nearest BHL: 650 ppm from 11-36, 4/24/01. 169 ppm from 11-16, 4/23/01. 45 ppm from 11-18, 3/26/01. Reference RPs .:. "Drilling/Work over Close Proximity Surface and Subsurface Wells Procedure" III.' ....~ , .1 Job 2: Decomplete Well Hazards and Contingencies ~ As always, there is a potential for trapped gas under the production packer. Monitor closely while retrieving or milling the packer. ~ There is a possible casing leak in the 9-5/8" casing. The well failed a CMIT in 1997 although the leak is probably through the sand plug on bottom. ~ A tapered drill string will be used to sidetrack this well. Ensure the 3-1/2" x 5" DP X-O has been inspected, that VBR's are installed in both pipe rams and that TIW valves are ready for both sizes of drill pipe. Reference RPs .:. "De-Completions" RP Job 3: Run Whipstock Hazards and Contingencies ~. Cement is expected behind the casing at the window depth. ~ The top of the Whipstock should be set at ~ 10021' (Schlumberger). Reference RPs .:. "Whipstock Sidetracks" RP .:. "Leak Off and Formation Integrity Tests" SOP Job 4: Drillina Production Hole Hazards and Contingencies ~ No mapped faults exist along the 11-17A well path. ~ Hole cleaning is important in the 3-1/2" x 9-5/8" annulus above the window. Inclinations in this section range from 34° to 42°. Sweep the hole often with Hi-Vis. Rotate at maximum RPM as much as possible while holding the target line. Make a wiper trips to the window as dictated by hole conditions. ~ Differential sticking can be a problem if the drill string or casing is left stationary for an extended period of time across the Ivishak Sands. ~ The kick tolerance for the 6-1/8" production section would be infinite assuming an influx from the Ivishak formation at TO of the 6-1/8" hole. This is a ''worst case" scenario based on an 8.3 ppg formation gradient, a 9.5 ppg frac gradient at the window, and an 8.5 ppg mud in the hole. 11-17A Drilling Permit Application Page 5 ( Reference RPs .:. "Leak Off and Formation Integrity Tests" SOP Job 5: Install 4 %" Production Liner Hazards and Contingencies ~ Differential sticking could be a problem in the Ivishak sands. Minimize the time the pipe is left stationary while running the liner. ~ It is planned to drill 80' of Kavik shale for rat hole. Sticking or swelling may occur in the Kavik. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight to set the packer. Check with Baker for the maximum down weight. If the stinger is pulled out of the liner top prior to setting the packer, POOH to remove the stinger prior to setting the packer. ~ Recent wells have encountered fill / cement contaminated perf pill during post rig work that resulted in a CTU cleanout. Review the procedure for releasing from the liner under pressure and circulating out excess cement to ensure no access problems for post rig perforating. Reference RPs .:. "Modified Conventional Liner Cementing" RP Job 6: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect: Flash point = 100° F. Vapor pressure.:t 0.1 psia at 100° F. Reference RPs .:. "Completion Design and Running" RP Job 7: ND/NU/Release Ria Hazards and Contingencies ~ See hazards related to the MIRU and adjacent well spacing in Job 1. Reference RPs .:. "Freeze Protecting an Inner Annulus" RP 11-17 A Drilling Permit Application Page 6 -:~-'+..t., BPXA ,lRt.~.þ~..:;:.~~Z. North Slope Alaska ~~~7:C:P?~ 11 Drillflu6st' Eastings (Well Reference) Scale: 1 inch = 150ft -675 I -525 I -375 I -225 I -75 I End Dir, Start Sail @ 28.698° : 10240.11ftMD,8665.65ftTVD - -4125 8000 - --------------- - -4275 8250 - KOP Begin Dir @ 12.0000/100ft: 10021.00ft MD, 8478.94ft TVD Decrease in Dir Rate @ 6.0000/100ft : 10041.00ft MD, 8495.49ft TVD Q) () c: ~ .! Q) - -4425 ~ ã) 3: - Q) () c: ~ 8500- Q) - Q) a: ã) 3: - OP Begin Dir @ 12.oooo/1ooft: 10021.00ft MD, 8478.94ft TVD Decrease in Dir Rate @ 6.0000/100ft: 10041.00ft MD, 8495.49ftTVD .c. ë. 8750- Q) 0 ãš () :e Q) > 11-17A Tl 9032.95 TVD, End Dir, Start Sail @ 28.698° : 10240.11 ftMD,8665.65ftTVD 4603.41 S, 443.29 W -.,...-------'!'°8~9~----- 4112"Uner "M).m) 00. "'.'D 10736.85 9101.37 en C) c: :E ~ 0 - -4575 Z ~ .,.. ------------------ II .c (,) - -4725 ~ ~~~ ( (J, Š LO N II .c (,) .E 9250- Q) (ij (,) Cf) 11-17A T1 9032.95 TVD, 4603.41 S, 44.U9 W. 9000 - ..."'~...., a,on.on Bsad / Kavik ------------------ --- -§lj24.9S------ 4 1/2" Uner 0700.00 1 0736.85 ~ 9101.37 ~\... Total Depth: /" 10736.85ftMD 9101.37ftTVD I I 3875 4125 Scale: 1 inch = 250ft I I I 4625 4875 5125 Section Azimuth: 184.480° (True North) Vertical ~ection (Well Reference) , 4375 _..!II''''Io... - _L " ^^ "'^ ^^^ laska Ing & Wells ~~-- OS 11, Slot 11-17a 1;7- 11-17A Wp-04 Revised: 18 January, 2002 PROPOSAL REPORT 18 January, 2002 Surface Coordinates: 5950973.91 N, 708240.76 E (700 16' 09.8898" N, 1480 18' 56.9095" W) Surface Coordinates relative to Project H Reference: 950973.91 N, 208240.76 E (Grid) Surface Coordinates relative to Structure Reference: 1428.09 N, 691.66 E (True) Kelly BushIng: 52.95ft above Mean Sea Level . ..i.Y:-~.lIl ""'PlJJLINPf-'. ."YI'-" A~-.'.~~f.'1t' ,.-. Proposal Ref: pro11072 Sperry-Sun Drilling Services Proposal Report for 11-1TA Wp-04 Revised: 18 January, 2002 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordina; Depth Inc I. Azim. Depth Depth Northlngs Eastlngs Northings (ft) (ft) (ft) (ft) (ft) (ft) 10021.00 34.045 190.678 8425.99 8478.94 4334.57 S 282.62 W 10041.00 34.327 194.920 8442.54 8495.49 4345.52 S 10096.64 32.446 199.934 8489.00 8541.95 708067.67 E 10100.00 32.339 200.253 8491.84 8544.79 708067.10 E 10200.00 29.561 210.615 8577.65 8630.60 708046.55 E 10240.11 28.698 215.231 8612.70 8665.65 5946527.39 N 708036.41 E 10267.82 28.698 215.231 5946516.32 N 708029.04 E 10300.00 28.698 215.231 5946503.45 N 708020.47 E 10400.00 28.698 215.231 5946463.48 N 707993.87 E 10500.00 28.698 215.231 5946423.50 N 707967.26 E 10510.65 28.698 4545.28 S 402.23 W 5946419.24 N 707964.43 E 10600.00 28.698 4580.32 S 426.99 W 5946383.53 N 707940.66 E 10649.73 28.698 4599.83 S 440.76 W 5946363.65 N 707927.43 E 10658.85 28.698 4603.41 S 443.29 W 5946360.00 N 707925.00 E 10700.00 28. 4619.55 S 454.69 W 5946343.55 N 707914.05 E 10736.85 2 9048.42 9101.37 4634.00 S 464.90 W 5946328.82 N 707904.25 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference . Magnetic DecHnation at Surface is 26.635° (18-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 184.480° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10736.85ft., The Bottom Hole Displacement is 4657.26ft.,in the Direction of 185.729° (True). 18 January, 2002 - 11 :35 Page2of4 Alaska Drilling &: Wells PBU_EOADS 11 Comment 4343.40 KOP Begin Dir @ 12.000°/1000: 10021.00ft MD, 8478.94ft TVD 12.000 4354.52 Decrease in Dir Rate @ 6.000°/1000: 10041.00ft MD, 8495.400 TVD 6.000 4384.34 Zone 4 6.000 4386.07 ~ 6.000 4434.00 6.000 4451.16 End Dir, Start Sail @ 28.698° : 10240.11 ftMD,8665.65ftTVD 0.000 4462.60 Zone 3 0.000 4475.88 0.000 4517.15 0.000 4558.41 0.000 4562.81 Zone 2A 0.000 4599.68 0.000 4620.20 Bsad / Kavik 0.000 4623.97 Target .11-17A T1, Current Target 0.000 4640.95 0.000 4656.16 Total Depth: 1 0736.85ftMD,91 01.37ftTVD 4 1/2" Liner ~ DrlllQuest 2.00.09.008 North Slope Alaska Comments Measured Depth (It) Sperry-Sun Drilling Services Proposal Report for 11-17A Wp-04 Revised: 18 January, 2002 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10021.00 10041.00 10240.11 10736.85 8478.94 8495.49 8665.65 9101.37 Formation Tops Formali on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. 8489.00 8637.00 8850.00 8972.00 Casing detsls From Measured Vertical Depth Depth (It) (ft) <Surface> <Surface> 18 January, 2002 - 11:35 4334.57 S 4345.52 S 4439.16 S 4634.00 S 282.62 W 285.11 W 327.29 W 464.90 W KOP Begin Dir @ 12 Decrease in Dir Rate End Dir. Start 51 . Total D, 8489.00 8637.00 8850.00 8972.00 4374.72 S 4450.03 S 4545.28 S 4599.83 S To Measured Vertical Depth Depth (ft) (ft) Casing Detail 10736.85 9101.37 4 1/2" liner Alaska Drilling & Wells PBU_EOA DS 11 : 1oo21.08J1MD. 8478.94ft TVD : 10041.000 MD. 8495.49ft TVD 1.11ftMD.8665.65ftTVD ':37ftTVD ~, Eastings (ft) Formation Name 294.24 W Zone 4 334.97 W Zone 3 402.23 W Zone 2A 440.76 W Bsad I Kavik Page30f4 DrlllQuest 2.00.09.008 North Slope Alaska Survey tool program for 11-17A Wp-04 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 10736.85 Targets associated with this wellpath Target Name 11-17A T1 18 January, 2002 - 11:35 To Measured Vertical Depth Depth (ft) (ft) 9101.37 Sperry-Sun Drilling Services Proposal Report for 11-17A Wp-04 Revised: 18 January, 2002 Survey Tool Description Target Entry Coordinates TVD Northings Eastlngs (ft) (ft) (ft) Sea Level/Global Coordinates: Geographical Coordinates: 9032.95 8980.00 4603.41 S 443.29 W 5946360.00 N 707925.00 E 70° 15'24.6130" N 148° 19' 09.8061- W Page 4 of4 Alaska Drilling & Wells PBU_EOA DS 11 ~~, Target Target Shape Type Point Current Target ,~ Dril/Ouest 2.00.09.008 SfJØrrf7~l-!Tt;.p!I~ltt)R~êi:i~"éS PrøpøsaIDJIa-.I'-17A -1'-17A W"..04 .';; '-" t. t~, ¡ ::;~; ,,'~';~;; c .,~!.. ,.~~~~~ ~. ~ I);:,,;,¡ :, ~~~~ ~ ~"~:"è:,~ 2505' Î Alpha Tubing Patch at 2980' T /Shublik 10021' MD 8479' TVD 3-1/2",9.3#, Chrome ScabLiner:9989'M 10507' MD 9-5/8", 47#, L-80, BTC 11-17A (Current) .; ;~,::. ~~¡ :~:),.~:":. z--"".':./ ""\:> :~)~.~ ~ ~~'~~;. ~ ~ 13-3/8", 72#, L-80 BTC BAL-O SSSV at 2186' . 5-1/2", 17#, L-80, IPC Tubing 9880' I -. ~ SB-3 PKR at 9897' wI SBE & MOE Retrievable IBP at 9933' MD 5-1/2" Tail Pipe assembly EOT at 10020' MD (8479' TVD) """'" >-Perforations: 10292' -10720' ::tF./ ::i~ 10857' MD " ~ ""/:. '; , \'"'" ~ C> ~ ;":.::. II ~ :; ;~:.~ , ~~\,~ I'~ "t!j 2505' i Jet Cut 5-1/2" Tubing :t 30' above the packer Jet Cut 3-1/2" Liner between 10004' - 10043' 3-1/2",9.3# Scab Liner 9989'-10507'MD ~~ ~'"'''.'''' 9-5/8",47#, L-80, BTC ..:'i;::):'::ï:; (' ( 11-17A (Pre-Rig Condition) ,;;:" ".~ ,I; .. .. <: ;~, ...~ ~!,,' ~~j ~~ ~~ ~~ 1'':':., i~~~ ~(..~~ _~13_3/8'" 72#, L-80 BTC BAL-O SSSV at 2186' . 5-1/2", 17#, L-80, IPC Tubing ad ba~ SB-3 PKR at 9897' w/ SBE & MOE (Locator Seal Assembly) 5-1/2" Tail Pipe assembly EOT at 10004' MD (Schlumberger) .~ r.. ".::,.~.:~,: 'fk¡ ~!¡~!~ CIBP at + 10120' w/25' Cement ~ >-Perforations: 10292' -10720' ~Z.:"~}~f ~ :,':,.:.:"",;::::,;;:i~,'. 10857' MD M;~'\,~! :~;~~. .\:"'",: :.~~:~: :~':.:~~ ~x' ,f';!II ;~;. ~~~ ;;(.~:~ :,.,:).(1,..= ;:~~:"; 2505' i Jet Cut 3-1/2" Liner at 2: 10020' MD 3-1/2", 9.3# Scab Liner 9989'-10507'MD ~,::;:" ~:; J ~)IIII~", 9-5/8", 47#, L-80, BTC ~:!;::~:::¡;:.: (' 1m IBI~ . ,~.~ Jil ~~mj ~~l::::~::,:,,;~il::;I,.~Jj:II::: r... ;~¡~:¡"::;~i,:~;!:;:.,I:;~:;: ..../ ,- '~11.:.~r lii~II' ,11::11 :r:::~II' ~;"1 ~.,.1 ..:;""0:' :~:~:' :~.':~:,~~ :ð.'~~ ~~¡ .';01'\;0; ::p"'Z;tr i ( :.~.~; :;:",<,,;-.. rf':.;.>!:-;' 11-17A (De-Complete I) 13-3/8", 72#, L-80 BTC . Lay down the 5-1/2" tubing . Fish the locator seal assembly. . Estimated string weight = 161,000# . Maximum allowed pull = 260,000# SB-3 PKR at 9897' wI SBE & MOE 5-1/2" Tail Pipe assembly EOT at 10020' MD (8479' TVD) CIBP at:!: 10250' w/25' Cement ~ >-Perforations: 10292' - 10720' 10857' MD ~:a~ ',¡:~:} ::~~~ , ~ 1":.1 <~:'~ 2505' ;i 3-1/2",9.3# Scab Liner 9989' -10507' MD 9-5/8", 47#, L-80, BTC ~.J",. ~~~ ,~~,~: ..j(., ~:, :,;f' :~'fJ t~¡ !i~r.~~ Î ~J~~t :=~ ; :d:" ,,~: ,,';-' ,:~;"""... ;::~:::i~;~:";::":~:;:'iF ::,i:':;:: "",on,', ,:,::;,,:::,,~:::',,::::!:~ " ~~¡;iI ~~ ~¡.IU~ l:Ii II~~ 11-17A (De-Complete II) 13-3/8", 72#, L-80 BTC . Mill the packer with a PRT. . Displace with QuikDrill while milling the packer. . POOH and lay down the packer, tail pipe and upper section of the 3-1/2" scab liner to the pre-rig cut. CIBP at + 10250' w/25' Cement >-Perforations: 10292' -10720' ~~?~~~m~ ./ :j::::';;::J:::f~~ 10857' MD ::~;::~;:::,~¡, ~:~iWf,:¡~~1 ~"::;'''.:i~''::.':. .::¡:::;i~"::i:: ~:-.:::~: ~~< >:'! ~ ;,1'\:..1 ~,\":~t!:.'~ ~~~~ .':~~~ ~::~g ~ '~.:~ 2505' Î Dress off Stub to 2: 10043' MD 9-5/8", 47#, L-80, BTC ( ~,,' ~~:~;il :il::;II::~;~I~ ~:":;::: ,~ 3~~~~¡ ~~~~l ( ~i "'.)~' ,:ð,Z';: ~~:~ r::~.:~ ~¡~,~~ ~: ~~~ $~;J ~ 11-17A (Whipstock) 13-3/8", 72#, L-80 BTC . Dress offPBTD with a mill & scraper. . Set a CIBP if necessary. . Set the bottom trip whipstock. . Mill the window. . Perfonn FIT. ~ Top of the Window at 2: 10021' (Schlumberger) 9-5/8" Casing Collars: :t 10051' :t 10010' 10857'MD ( r~~~ :-;;s:¡;:;¡e:¡;¡ ~ r;.~ $IS.~: *~~::;:; i:~'l;i::;:;::: r~:::;:;;. ~::;:;.~~ ~~1'Æf1.t ;:s:~~« ~,i*$f* ;::¡:~:;:¡U:: ~'*~::;:;~ ~~:;:¡:¡.1i: ~"*,':f.::;:; ::: ;'j:~:;:¡:¡;¡' ~~:Æ::;:;t. """", 2505' Î ::;:;~'*>it: ~$~'è ~%-:::~ ,%':<$:::è ;/J,j ::;:;;<::~~ :~:'J ::;:;-s::::::,;g; 'JÆ'!§'~i «~'g~ \:~Y'~ ~l*:::/ ::;:;:;¡;~* 'f!Æ.~ :::'*~ i~ Ii 11-17A (Sidetrack) 13-3/8", 72#, L-80 BTC . Drill the 6-1/8" production hole into the Kavik shale. TD = 10737' MD. . Drill deep enough to log the B/SAG. Top of the Window at , ~ ~ 10021' (Schlumberger) ~ ", . ," , -.., " " " , " -.., ", " " " " " " , " " " , , , " , , , -- ::ss: 9-5/8", 47#, L-80, BTC 10737' MD 10857' MD ::t:;:'<~~ ~ ~'iI> ¡:¡¡; ~ ~$$~ ~ ",~:<Æ~ 1;i'.~~-;.s, ~;~~ ~;;f$.~", ~?~~~~ :t.~$~ <i'J:$'$; *:<Æ,$$" ~/*$'J:: ~"*¡:¡¡;~ ¡.:'¡*$'$; ::0;:;:.<$:=*" ~,?~$x 2505' Î . .. ,t :ES: ~ -~;~~ t:(ß*ri 'iI>~):',*, ff.$z~~ :;s~* $~»~~ $~~ f.!:1!'<~) ..". $S§1':'$~ $}$»;& tlø~~ $$~* t:(1'Æ~i $~~ $'Sf:!:';:g~ $$'$"::t $$ ':11 ?i t~ Ii 11-17A (Proposed Completion) 13-3/8", 72#, L-80 BTC . Set and cement a 4-1/2", L-80 liner . Run 4-1/2", 13Chrome tubing & PKR 4-1/2", 12.6#, 13Chrome Vam-Ace 4-1/2" Liner 9875' -10808' MD Top of the Window at ~ 10021' MD 10857' MD H 20L1434 DATE 01/17/02 CHECK NO. 00204434 DATE INVOICE I CREDIT MEMO 011602 CK011602A PYMT :OMMENTS: HANDLING INST: DESCRIPTION GROSS 100.00 VENDOR DISCOUNT ALASKAûILA NET 00 100.00 Pernit to Drill ~ee S/H - Terrie Hub)le X4628 \ ~- ) 7~ HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ,:":,,...,0 :,,:' '~:~"',. 'I::,:,:' "'/"":',':,':,:';" Y;;''':::' TOTAL..'~\ 100.00 100.00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519.6612 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 204434 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00204434 PAY ONE HUNDRED to( OO/100***i:f********************************* US DOLLAR DATE 01/17/02 AMOUNT $100..00 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOTVALlD AFTER 120. DAYS AK 99501 \1~~_ßð~ III 2 0 ... ... ~ ... III 8: 0'" ¡. 2 0 ~ éPì 5 I: 00 B ...... ¡. q III ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME fAt) //~ /7 /T CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRlLL ~.. EXPLORATION INJECTION WELL INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) PILOT HOLE (PH) ANNUL~R D~.. R D P~SAL JDNO ANNULAR DISPOSAL L--> YES ANNULAR DISPOSAL THIS WELL' "CLUE" Tbe permit is for a Dew wellbore segment of existing. weD ----' Permit No, ,API No. - " Production should continue to be reported as a function of tbe original API number stated above. ' In accordance with 20 AAC 25.005(1), all records, data and logs acquired for' the pilot bole must be dearly , differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved,.. . DISPOSAL INTO OTHER Please note tbat an disposal of fluids generated. '. . ANNULUS L--> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved . subJect to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuan'ce of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to tbe spacing exception that may occur. {/ð«. WELL PERMIT CHECKLIST COMPANY ßP;C WELL NAME /1-- 17 r:::? PROGRAM: Exp - Dev ~Redrll /" Serv - Wellbore seg ~ Ann. disposal para req- FIELD & POOL (0 tltJ ¡Ç"D INITCLASS:Þ-£V I' 0/1.- GEOLAREA ~() UNIT# d?//~&Ó ON/OFFSHORE On ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . iN.; /- ~ . . ,4 - / . , ~. ~ .... ~~-:/J' 2. Le~se number appropriate:*: . . . . . . . . . . . . . . . . . N~~Ur,lfT{.~ ~ ¿:;CÇ¿ ~\. ~e tlA:;;¿vC; ~ ~ vP"f!..(" VÄ..-o 3. Umquewellnameandnumber....... ......... .. N :t9z:>t"- OZc>.3~/ . , ~ ~ /lPL- t)2-7r3?g..4'; 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N ~ 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N A. _P.,:>¡ÐF DATE. 12. Permit can be issued without administrative approval.. . . . . ... N .- ~j) z' (; .Õv 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . .¥"-t:t tJ/A ¿J / /1. '. /.' .-. ~ J/- . J2À 15. Surface casing protects all known USDWs. . . . . . . . . . . N"A ¥ N tC-c-cCYf',¡ ð/ ~/sr-':f ~(~ "tY 16. CMT vol adequate to circulate on conductor & surf csg. . . . . ¥---N- t-J/A () 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . .~ ¡...iIA . ../.... 18. CMT will cover all known productive horizons. . . . . . . . . . r:i! N A-de<1r (,UL.-ÍR e('CL~ s: CtvvLe.t-vG' 19. Casing designs adequate for C, T, B & permafrost. . . . . . . TiJ N U 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . fi) NDo~v-- l (g . 21. If a re-drill, has a 10-403 for abandonment been approved. . . fj) N AtJr.lrtJ \.ftR d 2-/ fi/ {) '- 22. Adequate wellbore separation proposed.. . . . . . . . . . . . fS) N 23. If diverter required, does it meet regulations. . . . . . . . . . *-N JIA 24. Drilling fluid program schematic & equip list adequate. . . . . N ,) - {(P 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . .' . N f-~ . / ? APPR DATE 26. BOPE press rating appropriate; test to 3500 psig. N MI\;'S P ~ 2..C; lOp c.;. Ú;c.-l ~7t 3~()D f K . NvA- zlt7!aL 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N '011w\ '--I 28. Work will occur without operation shutdown. .. . . . . . . . . . N h"i:"( 1'-( 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . . . . ycR) I () 31. Data presented on potential overpressure zones . . . . . . . Y~ i::.>t~~ ~VCIr- ~~ ~ '73cr'ifð" 87nw.. .~ 32. Seismic analysis of shallow gas zones. . . . . . . .~. . . . ~N APi~ DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . Y N ~. 2. i'5,oz-...- 34. Contact name/phone for weekly progress reports [ex I ory only] Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . Y N. I J r. t -I-.j (B) will not contaminate freshwater; or cause drilling waste. .. Y N f\.LD c£'.£..'\..¥lU1úV GtS po<;~ '('eß¡ ¿¿{ç ~ . to surface; U (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: TE429f1)~1~~ WGA ÍIJ4t\- . '\ ) / ) APPR DATE Commentsllnstructions: RPC SF~" COT DTSO?f/4-joz- JMH :?{ t S) ~'?-- G:\geology\permits\checklist.doc Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process. but is part of the history file. To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPEN.DIX. No special 'effort has been made to chronologically",: organize this category of information. ( c?fB. ã3~ 1/5LJ5 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Feb 27 13:56:37 2003 Reel Header Service name........... ..LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/02/27 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name......... ...... . UNKNOWN Continuation Number.... ..01 Previous Reel Name...... . UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/02/27 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name..... ..UNKNOWN Comments... ...... ...... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 11-17A 500292159801 BP Exploration Sperry Sun 27-FEB-03 (Alaska) Inc. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 2 AK-MW-22126 R. MCNEILL J. RALL MWDRUN 5 AK-MW-22126 R. MCNEILL J. RALL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 34 11N 15E 770 666 MSL 0) 53.85 25.35 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 13.375 2505.0 6.125 9.625 10125.0 ( (' 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS A FAILED SHALLOW PULSE TEST. NO DATA WERE ACQUIRED. 4. MWD RUN 2 COMPRISED (DGR) UTILIZING GEIGER-MUELLER TUBE RUN WAS TO TIE IN THE UPHOLE SECTION. DIRECTIONAL WITH DUAL GAMMA RAY DETECTORS. THE PURPOSE OF THIS 5. MWD RUNS 3 & 4 COMPRISED DIRECTIONAL AND DGR, AND INVOLVED POSITIONING THE WHIPSTOCK. NO DATA ARE PRESENTED. 6. MWD RUN 5 COMPRISED ELECTROMAGNETIC WAVE RESISTIVITY - PHASE LITHO-DENSITY (SLD)¡ COMPENSATED THERMAL DIRECTIONAL WITH DGR¡ 4 (EWR4)¡ STABILIZED AND NEUTRON (CTN). 7. LOG AND MERGED DIGITAL DATA ONLY ARE SHIFTED TO THE SCHLUMBERGER CASED-HOLE WIRELINE GAMMA RAY LOG RUN IN 11-17A ON 22 AUGUST 2002. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 2 & 5 REPRESENT WELL 11-17A WITH API# 50-029-21598-01. THIS WELL REACHED A TOTAL DEPTH OF 10740'MD/9115'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) SLIDE = NON-ROTATED INTERVALS SLDSLIDE = NON-ROTATED INTERVALS ACCOUNTING FOR SENSOR-TO-BIT DISTANCE (" PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.7 - 9.0 PPG MUD SALINITY: 1200 PPM CHLORIDES FORMATION WATER SALINITY: 101990 PPM CHLORIDES FLUID DENSITY: 1.0 GICC MATRIX DENSITY: 2.65 GICC LITHOLOGY: SANDSTONE $ File Header Service name. ........... .STSLIB.001 Service Sub Level Name. . . Version Number... ...... ..1.0.0 Date of Generation. ..... .03/02/27 Maximum Physical Record. .65535 File Type..... .......... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FCNT NCNT NPHI DRHO RHOB PEF FET RPD RPM RPS RPX $ 1 clipped curves¡ all bit runs merged. .5000 START DEPTH 9721.5 9738.5 9974.5 9975.5 9975.5 9990.0 9990.0 9990.0 10010.5 10010.5 10010.5 10010.5 10010.5 STOP DEPTH 10688.0 10739.0 10659.5 10659.5 10659.5 10675.0 10675.0 10675.0 10695.0 10695.0 10695.0 10695.0 10695.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE 9721.5 9724.0 9732.5 9759.5 9773.5 9817.0 9830.0 9836.5 9841.5 9846.5 9854.0 9856.5 9867.5 9892.0 9897.0 9904.0 DEPTH GR 9723.0 9725.5 9734.0 9760.0 9773.0 9816.5 9829.5 9835.0 9839.5 9845.0 9853.0 9855.0 9866.0 9892.5 9898.0 9904.0 ( ( 9925.5 9924.0 9954.0 9954.5 9982.5 9981.0 9984.0 9983.0 9991.5 9990.5 10007.0 10007.0 10017.5 10017.0 10024.5 10024.0 10029.0 10030.5 10033.0 10036.0 10040.5 10042.5 10046.0 10049.0 10048.0 10051.0 10054.5 10056.0 10064.0 10065.5 10067.0 10069.0 10071.0 10072.5 10077.5 10079.5 10085.5 10087.5 10088.5 10090.0 10095.0 10096.5 10097.5 10100.0 10102.0 10104.0 10103.0 10105.5 10105.5 10108.0 10117.0 10117.5 10131.0 10132.0 10139.5 10141.0 10154.0 10156.5 10159.0 10162.0 10169.0 10171.0 10178.0 10179.5 10192.0 10193.5 10197.5 10199.0 10201.0 10202.5 10208.0 10209.0 10211.5 10213.5 10217.0 10218.5 10233.5 10235.5 10238.5 10239.5 10246.0 10248.0 10258.0 10259.0 10268.5 10269.0 10271.5 10271.5 10292.0 10292.0 10298.5 10299.5 10323.0 10324.0 10342.0 10343.5 10358.0 10359.0 10393.0 10393.5 10401.0 10401.0 10422.0 10422.5 10427.0 10428.0 10435.5 10436.5 10437.5 10438.5 10442.0 10442.5 10451.5 10452.5 10463.0 10463.5 10469.0 10469.5 10474.5 10474.5 10477.0 10476.5 10483.5 10484.5 10486.0 10486.5 10512.0 10513.0 10519.5 10520.0 ( ( 10526.5 10541.5 10544.5 10555.0 10567.5 10570.0 10579.5 10588.5 10591.0 10596.0 10602.0 10608.5 10739.0 $ 10528.0 10541.5 10544.5 10555.5 10568.0 10571.0 10580.5 10589.5 10591.5 10596.5 10603.0 10609.5 10740.0 # MERGED DATA PBU TOOL MWD MWD $ SOURCE CODE BIT RUN NO MERGE TOP 2 9723.0 5 10049.5 MERGE BASE 10049.5 10740.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction.. .............. . Down Optical log depth units.......... .Feet Data Reference Point..... ....... ..Undefined Frame Spacing..... ............... .60 .1IN Max frames per record............ . Undefined Absent value.... . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9721.5 10739 10230.3 2036 9721.5 10739 ROP MWD FT/H 0.28 727.72 96.151 1996 9738.5 10739 GR MWD API 14.36 330.32 71.8891 1934 9721.5 10688 RPX MWD OHMM 0.81 1094.28 22.6196 1370 10010.5 10695 RPS MWD OHMM 1.1 665.63 29.6788 1370 10010.5 10695 RPM MWD OHMM 1.83 2000 62.0238 1370 10010.5 10695 RPD MWD OHMM 0.37 2000 51.0189 1370 10010.5 10695 FET MWD HOUR 0.46 85.11 5.88895 1370 10010.5 10695 NPHI MWD PU-S 7.29 75.85 25.2564 1369 9975.5 10659.5 ( FCNT MWD CNTS 72.95 2507.08 610.252 1371 9974.5 10659.5 NCNT MWD CNTS 12064.7 46976.8 25958.8 1369 9975.5 10659.5 RHOB MWD G/CM 1.128 3.114 2.35108 1371 9990 10675 DRHO MWD G/CM -1.218 0.823 0.058671 1371 9990 10675 PEF MWD BARN 1.27 15.06 2.69194 1371 9990 10675 First Reading For Entire File........ ..9721.5 Last Reading For Entire File......... ..10739 File Trailer Service name....... ..... .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/02/27 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name... ......... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/02/27 Maximum Physical Record. .65535 F i 1 e Type.. . . . . . . . . . . . . . . LO Previous File Name.. .... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9723.0 ROP 9740.0 $ 2 header data for each bit run in separate files. 2 .5000 STOP DEPTH 10032.0 10049.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 02-AUG-02 Insite 4.3 Memory 10050.0 9721.0 10050.0 .0 .0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 69706 (' # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction...... ......... ..Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record........ ... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ( 8.500 2505.0 Quickdril-N 8.40 50.0 8.5 900 15.0 .000 .000 .000 .000 .0 147.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9723 10049.5 9886.25 654 9723 10049.5 ROP MWD020 FT/H 0.28 727.72 181.424 620 9740 10049.5 GR MWD020 API 29.97 177.84 97.0541 619 9723 10032 First Reading For Entire File......... .9723 Last Reading For Entire File.......... .10049.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/02/27 Maximum Physical Record. .65535 File Type...... ...... ... .LO Next File Name...... .... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation.. .... .03/02/27 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI DRHO RHOB PEF FET RPD RPM RPS RPX GR ROP $ 3 ( header data for each bit run in separate files. 5 .5000 START DEPTH 9973.5 9974.5 9974.5 9989.0 9989.0 9989.0 10010.5 10010.5 10010.5 10010.5 10010.5 10032.5 10052.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ # STOP DEPTH 10660.5 10660.5 10660.5 10676.0 10676.0 10676.0 10696.0 10696.0 10696.0 10696.0 10696.0 10689.0 10740.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 06-AUG-02 Insite 4.3 Memory 10740.0 10050.0 10740.0 22.8 32.5 TOOL NUMBER 156435 112439 100983 167218 6.125 ( DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O (' 2505.0 Qucikdrill-N 8.40 51.0 8.5 1400 12.0 .100 .050 .180 .160 68.0 135.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9973.5 10740 10356.8 1534 9973.5 10740 ROP MWD050 FT/H 0.36 188.51 57.4011 1376 10052.5 10740 GR MWD050 API 14.36 330.32 59.9198 1314 10032.5 10689 RPX MWD050 OHMM 0.51 1094.28 22.4538 1372 10010.5 10696 RPS MWD050 OHMM 1.07 886.68 29.8619 1372 10010.5 10696 RPM MWD050 OHMM 1.83 2000 60.4646 1372 10010.5 10696 RPD MWD050 OHMM 0.37 2000 50.5128 1372 10010.5 10696 FET MWD050 HOUR 0.46 85.11 6.23456 1372 10010.5 10696 NPHI MWD050 PU-S 7.29 75.85 25.4109 1373 9974.5 10660.5 FCNT MWD050 CNTS 72.95 2507.08 607.137 1375 9973.5 10660.5 NCNT MWD050 CNTS 12064.7 46976.8 25891.5 1373 9974.5 10660.5 RHOB MWD050 G/CM 1.128 3.114 2.35039 1375 9989 10676 DRHO MWD050 G/CM -1.218 0.823 0.0582611 1375 9989 10676 PEF MWD050 BARN 1.27 15.06 2.71095 1375 9989 10676 First Reading For Entire File.... ..... .9973.5 Last Reading For Entire File.. ........ .10740 File Trailer Service name......... ... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/02/27 Maximum Physical Record. .65535 File Type. .............. .LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name.... ........ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 1 02 / 2 7 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. .............. . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments... .......... ... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name......... ... .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 02 127 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name...... ......... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments... ............. .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File