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Home My WebLink About199-036MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 4, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC R-15A PRUDHOE BAY UNIT R-15A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/04/2023 R-15A 50-029-20917-01-00 199-036-0 W SPT 8507 1990360 2127 1500 1500 1500 1500 19 15 18 21 4YRTST P Brian Bixby 2/17/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT R-15A Inspection Date: Tubing OA Packer Depth 104 2425 2364 2355IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230217115946 BBL Pumped:2 BBL Returned:2 Tuesday, April 4, 2023 Page 1 of 1           7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU R-15A Pull LTP Assembly Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 199-036 50-029-20917-01-00 11986 Conductor Surface Intermediate Tieback Liner Liner 8813 80 2636 8377 9022 2639 9170 20" 13-3/8" 9-5/8" 7" 4-1/2" 8784 26 - 106 26 - 2669 25 - 8402 24 - 9046 8902 - 11541 26 - 106 26 - 2669 25 - 8094 24 - 8683 8552 - 8824 None 470 2670 4760 5410 7500 9170 1490 5380 6870 7240 8430 9054 - 11986 4-1/2" 12.6# L-80 22 - 8909 8690 - 8813 Structural 4-1/2" Baker S3 Packer 8853, 8507 8710, 8853 8378, 8507 Stan Golis Sr. Area Operations Manager Josh Stephens Josh.Stephens@hilcorp.com 907.777.8420 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028279 22 - 8558 N/A N/A 7657 1761 250 50 1499 1634 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker SB3 Packer 8710, 8378 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 t to the best of my know March 14, 2023 By Samantha Carlisle at 3:04 pm, Mar 14, 2023 DSR-3/14/23 PRUDHOE BAY, PRUDHOE OIL RBDMS JSB 031423 Sundry Number Plug Perforations PBU R-15A N/A 199-036 Pull LTP Assembly WCB 11-27-2023 ACTIVITY DATE SUMMARY 2/20/2023 (Assist SL with FL Freeze Protect) TFS U-3, Pumped 1 BBL of 60/40 down WI line to FP. Flags and tags hung. Well left in control of SL upon departure 2/20/2023 (Assist SL with FL Freeze protect) TFS U3. Refresh earlier FP ( Broken Containment). Pumped 1 BBL of 60/40 down WI line for freeze protect. Well left in control of SL upon departure. 2/20/2023 *** WELL FLOWING ON ARRIVAL *** DRIFT TO MCX W/ 3.84" GAUGE RING TO 2,129' MD PULL 4-1/2" MCX (sn# =M-05) FROM 2,129' MD RAN SHEARABLE EQ PRONG TO 9,148' SLM PULL 2-7/8" CHOKE FROM @9,144' MD SET 2 -7/8" PX-PLUG BODY, FILL EXT (44.5" OAL 5 x 3/16 eq ports) @ 9,146' SLM (9,144' MD) (BRASS PIN. 1.30" x 5/16 LIH) RUN CHECK SET, PIN SHEARED *** CONTINUE ON 2/21/2023 *** 2/21/2023 T/I/O= 525/100/0 Temp= S/I (TFS Unit 4 Freeze Protect TBG Post SL) Pumped 38 bbls Crude down TBG for Freeze Protect. Final WHPS= 400/100/0 2/21/2023 *** CONTINUE FROM 2/20/2023 *** SET PX PRONG @9,146' SLM RECOVERED TOOLSTRING @9,343' SLM PULLED PX PRONG @9,371' SLM PULLED 2-7/8" PX PLUG BODY @9,372' SLM PULLED 45KB PKR @9,356' SLM (all elements intact, f/n damaged) ***WELL S/I ON DEPARTURE*** 3/2/2023 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(cibp) SET NORTHERN SOLUTIONS ALPHA 4.5 CIBP MID-ELEMENT AT 9170'. CCL TO MID-ELEMENT OFFSET: 12.5'. CCL STOP DEPTH: 9157.5'. TIE INTO SLB PERFORATION RECORD DATED 20-DEC-2018. Daily Report of Well Operations PBU R-15A @ PULLED 45KB PKR @9,356' SLM (all elements intact, f/n damaged) () SET NORTHERN SOLUTIONS ALPHA 4.5 CIBP MID-ELEMENT AT 9170'. The new WBS, below, correctly shows no KB packer in place as well as the new CIBP. -WCB MEMORANDUM State of Alaska Permit Number: 199-036-0 Inspection Date: 2/17/2019 Alaska Oil and Gas Conservation Commission TO: Jim Regg q � � J� III DATE: Thursday, March 7, 2019 P.I. Supervisor SUBJECT: Mechanical Integrity Tests 15 Min 30 Min 45 Min 60 Min BP EXPLORATION (ALASKA) INC. 9507 R -15A FROM: Jeff Jones PRUDHOE BAY UNIT R -15A Petroleum Inspector Sre; Inspector 2127 - Reviewed B- 1 2496 �y�: P.I. Supry + NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT R -1 5A API Well Number 50-029-20917-01-00 Inspector Name: Jeff Jones Permit Number: 199-036-0 Inspection Date: 2/17/2019 Insp Num: miUJ190218102750 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well R-15nType Inj w TVD 9507 Tubing' 1700 1692 - 1694 1688 " PTD 1990360 Type Test SPT Test psi 2127 - IA 87 1 2496 2457 2446 BBL Pumped: 2 ,BBL Returned: 2 OA 30 - 22 28 32 Interval 4YRTST IP/Ii P Notes: OA is cemented to surface. One well inspected, no exceptions noted. - Thursday, March 7, 2019 Page 1 of 1 STATE OF ALASKA 1 `1t �--L) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT F r O SUNDRY WELL OPERATIONS �, , 1. Operations Performed Burst: Collapse: Structural Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown -, e-%❑ feet Suspend ❑ Perforate IIZ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ' 7❑ feet Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Set 45KB Packer 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 11Exploratory ❑ 5. Permit to Dnll Number: 199-036 3. Address: P.O. Box 196612 Anchorage, 11986 feet Packer AK 99519-6612 Stretigraphic ❑ ServiceRI 1 6. API Number: 50-029-20917-01-00 7. Property Designation (Lease Number): ADL 028279 8. Well Name and Number: PBU R -15A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: Liner 2639 4-1/2' 8902-11541 PRUDHOE BAY, PRUDHOE OIL 8430 11. Present Well Condition Summary: Size: MD: TVD: Burst: Collapse: Structural Total Depth: measured 11986 feet Plugs measured None feet 20" We vertical 8813 feet Junk measured None feet Effective Depth: measured 11986 feet Packer measured 8712, 8853 feet 31-8094 true vertical 8813 feet Packer true vertical 8380, 8507 feet Casing: Length. Size: MD: TVD: Burst: Collapse: Structural Prior to well operation: 7452 150 660 Conductor 80 20" 33-113 33-113 1490 470 Surface 2636 13-3/8" 33-2669 33-2669 4930 2670 Intermediate 8371 9-5/8" 31-8402 31-8094 6870 4780 Intermediate 9017 T' 29-9046 29-8683 7240 5410 Liner 2639 4-1/2' 8902-11541 8552-8824 8430 7500 Perforation Depth: Measured depth: 9054-11986 feet True vertical depth: 8690-8813 feel 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): 4-1/2" 12.6# L-80 27-8909 4-1/2" Baker S-3 Perm Packer 8712 4-1/2" Baker S133 Packer 8853 Treatment descriptions including volumes used and final pressure: 27-8558 8380 8507 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 7452 150 660 Subsequent to operation: 1127 50 1800 14. Attachments: (required per 4 MC 25.070, 25.071, s 25 2M) Daily Report of Well Operations 0 Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 15. Well Class after work: Exploratory ❑ Development ❑ Service 0 Straligrephic ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑ Sun 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. WA dry Number or N/A if C.O. Exempt: WA Authorized Name: Draughon, Austin Contact Name: Dreughon, Austin Authorized Title: Petroleuin EV m Contact Email: Austin.Draughonpbp.com Authonzed Signature:r-IA24Q�A�Date: /3 2(}1 Contact Phone: +1 9075644033 Form 10-404 Revised 04/2017 e U 1 k&JttZn*&"6BDM93&B 2 0 2019 Submit Onginal Only Daily Report of Well Operations PBU R -15A ACTIVITYDATE SUMMARY "'WELL INJECTING UPON ARRIVAL"" (perforating) R/U SWCP 4516 SLICKLINE UNIT 12/6/2018 "`CONT WSR ON 12!7/18'" -CONT WSR FROM 12/6/18"' (perforating) DRIFTED W/ 15'x 3.70" DRIFT TO 9,222' SUM (possible dogleg) DRIFTED W/ 36'x 2 7/8" DUMMY GUNS (3.16" max od) TO DEVIATION @ 9,400' SLM 12/7/2018 "'WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS"" "'JOB STARTED ON 20 -DECEMBER -2018"' (SLB ELINE: ADPERF) WELL FLOWING ON ARRIVAL. LRS FP FLOWLINE AND TBG W/ DIESEL. INITIAL SHUT IN TWO = 50/50/0. RU. PT TO 3700 PSI, RUN 1: PERFORATE 9067'- 9093'W/ 2.875" POWERJET NOVA, 6 SPF, 60 DEG PHASED, 151 SHOTS. RUN 2: PERFORATE 9057'- 9067'W/ 2.875" POWERJET NOVA, 6 SPF, 60 DEG PHASED, 151 SHOTS. RUN 3: ATTEMPT TO SET BAKER HUGHES KB PACKER AT 9113'. NOT MAKE IT PAST 9069'. POOH AND PUT WELL ON INJECTION TO CLEAN UP WELLBORE. 12/20/2018 "'JOB CONTINUED ON 21 -DECEMBER -2018`" '"`JOB CONTINUED FROM 20 -DECEMBER -2018'" (SLB ELINE: SET BAKER PACKER) CONTINUE POOH RUN 3, BAKER HUGHES KB PACKER. RDMO. PAD OP NOTIFIED ON DEPARTURE. WELL SHUT IN ON DEPARTURE. FINAL TWO = 0/50/0. 12/21/2018 "'JOB COMPLETE ON 21 -DECEMBER -2018"• "'WELL INJECTING ON ARRIVAL" (Perforating) CURRENTLY RIH W/ 3.70" x 10' DUMMY WHIPSTOCK, 3.70" DUMMY WRP 12/27/2018 "'JOB IN PROGRESS, CONTINUED ON 12/28/18 WSR' —CONTINUED FROM 12/27/18 WSR (Perforating) RAN 15' x 3.70" DRIFT TO RESTRICTION @ 9,065'SUM (Unable to pass) RAN 4-1/2" BRUSH, 3.70" GAUGE RING TO DEVIATION AT 9361' SLM WHILE PUMPING CRUDE (No issues) RE -RAN 15'x 3.70" DRIFT TO RESTRICTION @ 9,065'SUM (Unable to pass) RAN 4-1/2" BRUSH, 3.70" GAUGE RING TO DEVIATION AT 9361' SLM WHILE PUMPING CRUDE (No issues) RAN 10'x 3.70" DRIFT W/ 3.70" SWAGE TO 9192' SLM (Able to pass thru restriction at 9065' while pumping 3bpm) RAN 2.78" x 10' DUMMY GUN, DUMMY 45KB PKR /X -NIPPLE DRIFT TO 9160' SUM (No issues) RAN 4-1/2" XN LOCATOR TO XN NIPPLE AT 8881' SLM (8897' MD), CONT IN HOLE AND FLAG WIRE AT 9133' MD. RIH W/ HES DPU & BAKER 45 KB PACKER W/ 2.313 NIPPLE (2.31 XX PLUG INSTALLED) 12/28/2018 "'JOB IN PROGRESS, CONTINUED ON 12/29/18 WSR"' "'CONTINUED FROM 12/28/18 WSR"*(perforating) SET BAKER 45 KS PACKER W/ 2.31 NIPPLE & XX PLUG (2 3/16" eq ports), ME @ 9,134' MD, (oal = 12.34') 12/29/2018 ""WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS" T/I/O= 1600/100/0 Temp= Inj Freeze protect / HPBD (PERFORATING) Pumped 2 bbls 60/40 down PWI line for FP, Pumped 5 bbls of 60/40 Meoh and 155 bbls of 1 % KCI to displace the TBG. Perform Step rate test with 88 bbls of I% KCI. 3.5 bpm @ 1856 psi. 4 bpm @ 1862 psi. 4.5 bpm @ 1874 psi Pumped 200 bbls of 1 % KCI breakdown test. Max of 5 bpm @ 1965 psi. Pumped step down injection test with 142 bbls of 1 % KCI. 4.5 bpm @ 1933 psi 4 bpm @ 1887 psi 3.5 bpm @ 1846 psi 3 bbpm @ 1816 psi 2.5 bpm @ 1764 psi Freeze protected surface equipment with 5 bbls of 60/40 Meoh. Final T/I/O= 1547/42/0. WFO agreed to POI well post rig down. 1/19/2019 TREE= 4-1/16"CAMRON WELLWAD= 11" FMC ACTUATOR= BAKER --- KB. UEV = _ 53.39' RffELE V = 48.96' BF. E LEV _ 20.02' KOP= 4496' Max Angle 107' @ 9673' Datum 9054 - 9090 DatumN 12/20/18 = 47#, L-80, TC-IL MD= 9287' D = 8.861" D= 8800'SS 13-3/8" CSG, 72#, L-80, D = 12.347' { 7' LP 28#. L-80, VAM TOP, { .0383 bpf, D = 6.276' Minimum ID = 3.725" @ 8897' 4-112" HES XN NIPPLE 3279' BRK TACK SEAL ASSBVBLY, D=6.200' —j 824W 7• SCAB LNR, 26#, L-80, $245' BTC -K .0383 bpf, D = 6.276' 14-1/2' TBG STUB (01/10/07) 88113' 4-i/2' TBG, 12.6#, L-80, TC -k$$25' .0152 bpf, D = 3.958' 1TOP OF4-1/2•LNRI- 8902 4-1/2' TBG, 12.6#, L -8O, .0152 bpf, D = 3.958' $909' 7' LW 26#, L-80, .0383 bpf, D = 6276' 9046' SAFETY NOTES: H2S READINGS AVERAGE 125 ppm R -15A WHEN ON Mi. WELL REQUIRES ASSSVWHEN 0N ML PARENT WELLBORE R -16A) NOT SHOWN BELOW MILLOUT WINDOW @ 8402'."'WELL ANGLE> 70' 15H.— 2129' 4-]4 E•S HCESEMX3NYPIH, D2 = 3- 2&210 Fs-s/e w HCR .0152 bpf, D = 3.953' 11498' 4-1/2" SLTD LNR 12.6#, L-80, .0152 bpf, D = 3.953' I MLLOUT WNDOW (R -15A) 8402' - 8417' I 8240' 9-5/8• X 7' BKR ZXP RCR w / FLEX -LC LNR HGR ) = 6250' 8679' 4-1/2" HES X NP, D = 3.813' $710' 7'X4-1/2'BKR S-3 PKR D=3.875" $743' 4-1(2• HES X NP, D = 3.813• 8842- 4-1/2• HES X NP, D = 3.813' $$53' 7• X 4-1/2' BKR SB -3 PKR D= 3.875• $$76' 4-1/2' HES X NP, D = 3.813' $$97' 4-1/2' HES XN NP, D = 3.725' $902' 7'X5"BKR ZXP LTPw/FMC HGR D=4.405' 8909' 4-1/2'WLEG, D=3.958' $923' S• X 4-1/2• XO, D = 3.958• 45KB LTPw /2-7/8' X -NP, D = 2.313' (12/29/18) 2-7/8' XX RUG (12/29/18) 11458' HEs Es CEM3NI132 11470' BKR -CTC- PAYZONE PKR 119$6' TD(OPEN HOLE) 1 11541' 1 (OPBJHOLE) 1-1 11993' PERFORATION SUk MRY FEF LOG: PRUDFDE BAY UNIT VALL: R15A PERMT No: 1990360 API No: 50-029-20917-01 SEC 32, T12K RI 3E ANGLE AT TOP PEW: 26" @ 9054' Note: Refer to Production DB for historical perf data SIZE SPF MHZVAL OpNSgz DATE 2-7/8" 6 9054 - 9090 O 12/20/18 4-112" SLTD 11498 - 11541 O 05/16/99 6" OH 11541 - 11986 07 05/11/99 SAFETY NOTES: H2S READINGS AVERAGE 125 ppm R -15A WHEN ON Mi. WELL REQUIRES ASSSVWHEN 0N ML PARENT WELLBORE R -16A) NOT SHOWN BELOW MILLOUT WINDOW @ 8402'."'WELL ANGLE> 70' 15H.— 2129' 4-]4 E•S HCESEMX3NYPIH, D2 = 3- 2&210 Fs-s/e w HCR .0152 bpf, D = 3.953' 11498' 4-1/2" SLTD LNR 12.6#, L-80, .0152 bpf, D = 3.953' I MLLOUT WNDOW (R -15A) 8402' - 8417' I 8240' 9-5/8• X 7' BKR ZXP RCR w / FLEX -LC LNR HGR ) = 6250' 8679' 4-1/2" HES X NP, D = 3.813' $710' 7'X4-1/2'BKR S-3 PKR D=3.875" $743' 4-1(2• HES X NP, D = 3.813• 8842- 4-1/2• HES X NP, D = 3.813' $$53' 7• X 4-1/2' BKR SB -3 PKR D= 3.875• $$76' 4-1/2' HES X NP, D = 3.813' $$97' 4-1/2' HES XN NP, D = 3.725' $902' 7'X5"BKR ZXP LTPw/FMC HGR D=4.405' 8909' 4-1/2'WLEG, D=3.958' $923' S• X 4-1/2• XO, D = 3.958• 45KB LTPw /2-7/8' X -NP, D = 2.313' (12/29/18) 2-7/8' XX RUG (12/29/18) 11458' HEs Es CEM3NI132 11470' BKR -CTC- PAYZONE PKR 119$6' TD(OPEN HOLE) 1 11541' 1 (OPBJHOLE) 1-1 11993' PRUDFDE BAY UNIT VALL: R15A PERMT No: 1990360 API No: 50-029-20917-01 SEC 32, T12K RI 3E DATE REV BY COM ENTS DATE REV BY COMMENTS 7 02/28/83 ORIGINAL COMPLETION 01/10/19 CJNVJMD SET45KBPKPJPLUG&ADPERFS 05/16/99 SIDETRACK(R 15A) 02/12/19 DD'JIVD ADD®OKB, FfF, & BF E -EV 01/30/07 DIS RWO 03/05/07 MNS/PJC DR -G DRAFT CORRECTIONS 02/15/11 M3/JM) ADDE)SSSV SAFETY NOTE BP Exploration (Alaska) 01/18/12 TK"JM) ADDED IQS SAFETY NOTE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,March 05,2015 TO: Jim Regg �1"' ))) SUBJECT: Mechanical Integrity Tests P.I.Supervisor �C 3)��t 7 BP EXPLORATION(ALASKA)INC lll/ I R-I 5A FROM: Bob Noble PRUDHOE BAY UNIT R-15A Petroleum Inspector Src: Inspector Reviewed By: J&—'P.I.Supry J �- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT R-15A API Well Number 50-029-20917-01-00 Inspector Name: Bob Noble Permit Number: 199-036-0 Inspection Date: 2/3/2015 Insp Num: mitRCN150203125940 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 'Type i99o360 J 1 455 455 TVD 8503 Tubing 456 456 --- PTeIn� D'i Type TestsPT;- a -- — - — --- �- {-- -- (Test psi 2126 " IA 220 2505 - 1 2478. 2477 Interval 4YRTST IPF P ‘/ OA 27 15 26 32 - - 1-- - --- --` ---- — — Notes: S�14ED lvikl' 2 2 t015 Thursday,March 05,2015 Page 1 of 1 · . Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. . J 0f1- C> 3(ç File Number of Well History File PAGES TO DELETE Complete RESCAN o Color items - Pages: o Grayscale, halftones, pictures, graphs, charts - Pages: o Poor Quality Original - Pages: o Other - Pages: DIGITAL DATA ~ Diskettes, No. o Other, NolType OVERSIZED o Logs of various kinds o Other COMMENTS: 5 I r~ Scanned by: Beverly Mildred Daretha~owell Date: d.. /7 Isl N o TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Isl STATE OF ALASKA AL,..,KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other L BrightWater Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development Exploratory ❑ 199-036-0 ' 3.Address: P.O.Box 196612 StratigraphiC Service El 6.API Number: Anchorage,AK 99519-6612 50-029-20917-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028279 . PBU R-15A ' 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: RECEF',.:' :...'- Total Depth measured 11986 feet Plugs measured None feet NOV �3 true vertical 8812.67 feet Junk measured None feet N 19 20 t Effective Depth measured 11986 feet Packer measured See Attachment feet AOGCC' true vertical 8812.67 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 27-107 27-107 1490 470 Surface 2643 13-3/8"72#L-80 26-2669 26-2668.98 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production 8221 7"26#L-80 24-8245 24-7945.23 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11498-11539 feet 11541-11986 feet True Vertical depth 8828.3-8824.39 feet 8824.2-8812.67 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4-1/2"MCX I-SSV 2129 2128.98 SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11,498'-11,539',11,541'-11,986'. Treatment descriptions including volumes used and final pressure: 4,065 Gallons EC9360A Surfactant, 17,806 Gallons EC9378A Polymer,430 psi. 13. Representative ttittiNEOro0Aiiii iinTcjEc14ata Oil-Bbl Gas-Mcf ater-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 3056 0 300 Subsequent to operation: 0 0 3739 0 368 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run ExploratorL Development❑ Service 0 • Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG El . 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.Corn Printed Name Garry Catron Title PDC PE Signature .14 G i Phone 564-4424 Date 11/19/2013 VGr IA TM RBDMS NOV 204 ,_,Form 10-404 Revised 10/2012 � �/y Submit Original Only Packers and SSV's Attachment ADL0028279 SW Name Type MD TVD Depscription R-15A SSSV 2129 2080.02 4-1/2" MCX I-SSV R-15A PACKER 8240 7891.55 7" Baker ZXP Packer R-15A PACKER 8710 8328.69 4-1/2" Baker S-3 Perm Packer R-15A PACKER 8853 8458.28 4-1/2" Baker SB3 Packer R-15A PACKER 8902 8502.72 5" Baker ZXP Top Packer R-15A PACKER 11470 8781.88 4.5" Baker CTC Packer 0000000000 ( (O (O (O — O — r- 00 r� r� r� vUnvmUIUn C V tt Tr 0 to N r� U .. C) 0 0 Or M Tr M M M o a• ) co (0N- cNTr 00000000 O) Q) NN M00 (OM O O) r- ti N N O) 00 O p Tr Tr M N N 0 00 Y- 00 0000000 t (000 �f) 00 00 O (O 00 0) (O �C) ✓ '- 0000 r- N00O lllll O Y- CO N O (O to N N N N ij N N N 000tf) , r- co co ( 48 2toN (0i • C) I ) 0 0 0 0 CO N O op co O N (O CO CO 00 O) 00 N 00 00 N 00 r- C� OTr (0 ('4 CO ON NNNWNCDNNNO0 C F 0000 000 000000 C' 1" 00 00 00 O J O J J - J J J CO 00 •N N * * * u J (O J N (wO 0 CO - y- y- • 0 00 00 6 N _ N 0\0 N0) ma) 4 .- 44 t C) r (v) (Y) O)O N- r� O O M N ct O C 00 00 00 0 0 (O N (0 00 0) J - - CO O N 00 N CO H H H Z "51, QQQ O 01555 H W C 0 W W W U U to W W Wc' cou_ zz V Z W W W W W O w m m OFZ- F' ZZceDDD UZZ � Jd (/) HH co Q N- C 0) N CO • 4- 6) 4- c) CO N 0 N- 0 r 4_ `- o O• T3 U) O (7 O O O (B o O To O (L6 Ts . � O co O O O O cr, as (D co a) c as a Cu Cu O a) E .N -6 a E -0 a a) N 0- -0 E 0- s E 0- * ID c 0 CI_ * E D Cl- * a. V2 W Qa Cr YO- c Y0. ui L .0 to L 3 o O u. 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Q� ( N � — Q co � Q C -0 7 a) (B " < 0) 0 (0 < 0) (0 < 0) (n U < CO C CO 'E 0 < CO C CO 0 < CO C CD E c U Q co a) Q C a) CO a7 .O Q L a) (0 Q co .O O M Q co .O ct Ti O E O N- o E o , - 0) o ' °-'T N C O O 0 0-6 .0 c) U p Q >+ a a) co co _ U _° LU W Quo LU W Qc LU W QE � c' -c 0)° 0 .Ow 0 - o E ALL! °) 0 3 _ a) w m 0 3 ow 0 0 0 cu F 3 a) W ° o Cu 0 .o C)t U) o 6 2 mt V) E C0 a3 .o ( )t v) Q� as a) * 4- . 0) 0 c6 a) - -0 0) Q �p aim .i0) Q co o 00 2 m o m E 0)N o co h w L_ -0 -0 a)a) o (0 - N aa) 0 v ca m N O oo L ° C 0)N- U * C _ I t N U c co N co U , , .Q co -t N U m Q c n ( - C C CU C - C N ,_ N CO I- (n U) �O C "C V) '� C V) 0 -p V) '� C to '� o m U -O (). 0 Q 0 Q Q U Q = 0 0 Q U Q 0 Q Q U Li) i _c) ..4.? Cu a c a) c a) m Q a) E E c E m co� Ei E „.0_ c r_0_°) m RS E E c E m as O c EE (7,. Ecc) o .o - as � aow o c as `� 0 ° as � aLw * * BCD as rna � a 0_ 0) °v * C.D a) (Q3 * 0) rn * CO CO co co N- O r r r 0 0 c) N N N N N IC) CO N- CO r r r N- 6 O O O r r r r N 4- co to co co co Co V 9 a) 0) t0 4- O O N 0 N O C co _O O O O O N o 0 0 O 0_ (0 O CO 0 (0 AC O (0 2 • D CO w c0 a) § (0 a c0 Q Q C1 CL E Q Q Q Q Q Q a) fl E a- * E a ° 3 E a- 3 E a a L Y ° (n Y (n Y a c LL L a_ CC o 4 _c �' o V C V N O V _c g o r , N ?) o 2 0 v cL co 2 0 N 2 0 N co 2 !mil(r) o co Q N r Q N 0 C1 N �O .— Q N `— ,— Q a) C L . a) C L a) C L ' a) c L -c , a) a) 0 O Q N a) O O c W a) O O Q N a) o 0 Q N O C O Cl) o , o) O (A U (n 0 O (� U O (A N C 0) L C CA l L C CY) L C CT N '',7-Z: 0- a) co O L co `_ o 0 L co O L co o M N 0 0)10 N -a 2 a) N .� 2 a) N ,� 2 a) N ,_ -O � Cr (0 cO N a) (0 .- O Q) (0 0 (0 O N co 0 a) N O C• Et C a) 0) a) a) a)c++ L o Cr) C L O a) 2 L O cm 2 C L O a C O G a i � a) (2D > o t a) co a) a) 0 ca > O a) > O a) O co _E > Q (° E Q Q > Q n 1E > < _ D O a O� � � Q o O C� a * m (D ¢ -) c co ,- CO co i_� L 'K CO 03 �_- L N ML 03 i_� L 3 L co —_- L * j O II ai /�, W L.� C C� }_ C a) (/) C H C a CO LJ C > (O * c -, E r V�, r c O - a 4- Q CY o ' o a' o 't O a' O 't O .�-, a' O `t o ct .C 0 C O J w 'a ° 0- 0 co a ° a 0 m a. o -0 ° a o co rn a) o U O) Q U) (f) `� c • � � 0_> (nom — ° °� o0 CU < o, (0 Q co < (T> co < o) 'L >a O Q co U Q CO tJ .0 U < 00 0 O co U < Co C) .0 � U < CO U .0 CO a) U > C. o > o r o > o > CD o:S E M ,O o E ° (r) .a) O , O M , o M (,) a) O C II m O M CA O L O O M O O +� O O co A co .- O M O) O L N o O (1 o O Q N . a) O Q °_c� c o U Q Cz C• c U) Y • O LU W cO O +' W a) co LO W LO LO ; W _c p 0 t!7 W U O W U O W U O W U . O U C 4 ca E co - o c0 tm u) E i0 0 C t .- E i0 0 3 i0 o c0 3 E ai Q Q O C6 L (0 O • (0 L0 C O (0 L o) (0 (n O (0 L o) (0 N O L 2 � Q a) L CnQ L 40) 0_ a) L ., C) a mu) (0 L ► N .1- to N L ,— C) to (6 4- C2 11 0 -O CT N 0 CO a) L a CT N 0 CO a) -0 CT N 0 CO o L -o CA 0) 0 ,— a) L -O E >> ' D _ I tN 0 CTD _a• Lo N C 0 7 .° t() -EN C o) 0 N C O > a) C +0 •- .0 C 0 '- C '� C C CO '� C C U O C1 C1 a) C1=.. — o a C1 a) C2 (0 O Q C2 a o. (0 — 0 Q a) a Q — 0 'C U O U U o)ID U U CT 0 U o1 U O ° U Q[n _ E E c E E E c E E E c E E E c E o as � a � W �o a. a � aNO u) 0 a. a � a. C) W 0- 0 _. d , W � 0_ 5 *k c0 N : *k (0 t(7 0 .*k (0 N- .*k (0 0 ** .*k 3 CT '— 3 3 o) r 0_* CT — * 3 co N * 3 CO co co co co O o O O O N N N (NJ N 0) O <- N co N N N N O O O O O r r TREE= 4-1/16"CAMERON WELLHEAD= 11"FMC S, !NOTES:H2S READINGS AVERAGE 125 ppm ACTUATOR= BAKER R-1 5 A WHEN ON MI.WELL REQUIRES A SSSV WHEN ON Ml. PARENT WELLBORE(PRE-R-15A)NOT SHOWN KB ELEV= 48.6' BELOW MILLOUT WINDOW @ 8402'."4-WELL ANGLE> BF ELEV= 21.81' ►�� ►.►�4 70°@ 9315'""" KOP= 4496' ►M ►.�� Max Angle= 107° !.� 9673' 9-5/8"CSG, --1 1895' ,: �� !% 1885' IH HES ES CEMENTER Datum MD= 9287 47#,L-80,TGII, %��i �• Datum TV D= 8800'SS ♦4 • 2129' -14-1/2"HES X NIP,ID=3.813" ID=8.861" ►_�i �•►.! .4 • 62 21' -I9-5/8"DV PKR •13-3/8"CSG,72#, L-80, ID=12.347' --1 •2673' I ,• ►! 7"LNR,26#,L-80,VAM TOP, -1 3279' �� ∎, .0383 bpf,ID=6.276" .4 0 •- • ■9-5/8"CSG,47#,L-80,ID=8.681" -1 8402' �4 �•, • Minimum ID = 3.726" 8897' .4 :j MILLOUT WINDOW(R-15A)8402'-8417' 4-1/2" HES XN NIPPLE • •4• i P• VOA.iii •i ► v '; 8240' I 9-518"X 7"BKR ZXP PKR w/FLEX-LOC BRK TIEBACK SEAL ASSEMBLY, ID=6.200" -1 8240' gi IN LNR HGR,ID=6.250" 8679' I-14-1/2"HES X NIP,ID=3.813" I 7"SCAB LNR,26#,L-80, -I 8245' BTC-M,.0383 bpf, ID=6.276" .. Z 8710' 7"X4-1/2"BKR S-3 PKR, ID=3.875" I I , ( 8743' H4-1/2"HES X NIP,ID=3.813" 14-1/2"TBG STUB(01/10/07) H 8818' I I 8825' H 7"X 4-1/2"UNIQUE OVERSHOT 4-1/7'TBG,12.6#, L-80,TGII, -I 8825' 17 I ' I 8842' H4-1/2"HES X NIP, ID=3.813" .0152 bpf, ID=3.958" 1E S 8853' H7"X 4-1/2°BKR SB-3 PKR,ID=3.875" ' , 1 8876' H4-1/2"HES X NIP,ID=3.813" I ' 8897' H4-1/2"HES XN NIP,ID=3.725" I TOP OF 4-1/7'LNR -I 8902' 4-1/2"TBG, 12.6#,L-80, .0152 bpf,ID=3.958" -1 8909' 8902' -17"X 5"BKR ZXP LTP w/HMC HGR, ID=4.405" PERFORATION SUMMARY 8909' 1-14-1/2"WLEG,ID=3.958" I REF LOG: 8923' I-15"X 4-1/2"XO,ID=3.958" I ANGLE AT TOP PERF.96°@ 11498' Note Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" SLTD 11498- 11541 0 05/16/99 1145$' I-1 HES ES CEMENTER 1 6" OH 11541 - 11986 0 05/11/99 11470' I-1 BKR"CTC'PAYZONE PKR, ID=3.958" I ■ 11986' -ITO(OPEN HOLE) PLUGBACK 7"LNR,26#,L-80, .0383 bpf, ID=6.276" -I 9046' - - • 4-1/2"LNR,12.6#, L-80, .0152 bpf,ID=3.953" 11498' 4-1/2"SLID LNR, 12.6#,L-80, .0152 bpf,ID=3.953" --I 11541' TDD(OPEN HOLE) 11993' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02128183 ORIGINAL COMPLETION WELL R-15A 05/16/99 SIDETRACK(R-15A) PERMT No '1990360 01/30107 D16 RWO AR No 50-029-20917-01 03/05/07 MWS/PJC DRLG DRAFT CORRECTIONS SEC 32,T12N, R13E 02/15/11 NE/JMD ADDED SSSV SAFETY NOTE 01/18/12 TMWJMD ADDED I-QS SAFETY NOTE BP Exploration(Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg l' i C /tI1 41 DATE: Wednesday, April 13, 2011 P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC R -15A FROM: Bob Noble PRUDHOE BAY UNIT R -15A Petroleum Inspector Src: Inspector Reviewed By..::�j� P.I. Supry :J— NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT R - 15A API Well Number: 50 029 - 20917 - 01 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110305152524 Permit Number: 199 - 036 - Inspection Date: 3/5/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. R -15A W -� 837 ' I Well Type Inj. TV IA 1 340 2600 - 2570 2570 - 1 - P.T.D 1990360 1 TypeTest SPT Test psi 2095 ' OA 20 20 20 20 Interval 4YRTST P/F P . Tubing l 200 200 200 200 Notes: Wednesday, April 13, 2011 Page 1 of 1 ID 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission !'-) DATE: Friday, March 11, 2011 TO: Jim Regg P.I. Supervisor 2 /1 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC R -15A FROM: Bob Noble PRUDHOE BAY UNIT R -15A Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprvg-- NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT R - I5A API Well Number: 50 029 - 20917 - 01 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110305152524 Permit Number: 199 - 036 - Inspection Date: 3/5/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well R-15A • Type Inj. w 1 TVD 8507 ' IA 1 340 2600 • 2570 I 2570 - P. T.D 1990360' TypeTest SPT Test psi 2600 ' OA 20 20 20 20 Interval P/F P Tubing zoo 200 200 200 Notes: ivk111. fee -1 21Z(, ; 4'` APR 1 Friday, March 11, 2011 Page 1 of 1 ~ JIJL ~ ~ ~9~~ Afaska OiB ~S ~~~ ~~~s, ~ommwssia~ bp BP Exploration (Alaska) Inc. A~~har~~~ ~u Attn: Well Integrity Coordinator, PRB-20 '~ Post Office Box 196612 Anchorage, Alaska 99519-6612 " 20~~ -~~~'}U~i~~`~ JUL .~ 4:~ July 10, 2009 } R-03( Mr. Tom Maunder ` ~ ` Alaska Oil and Gas Conservation Commission ~~- ~~~ 333 West 7ih Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB R-Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB R- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my altemate, Torin Roschinger, at 659-5102. Sincerely, Anna Dube, P.E. BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) R-pad natp RPVisPd 7/10/2009 Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al R-02 50029203540000 1781000 125 NA 125 NA 6.8 5/11/2009 R-03A 50029203640100 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 50029203740000 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 50029203800100 1972500 0 NA 0 NA 3 5/13/2009 R-06A 50029203880100 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 50029205230100 2000i00 2.25 NA 2.25 NA 43 5/11/2009 R-08 50029205480000 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 50029206090100 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 50029206180000 1810930 2 NA 2 NA 14.5 6/22/2009 R-11A 50029208930100 1982060 0.25 NA 0.25 NA 1.7 6/11/2009 R-12 50029209210000 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 50029209290000 1830440 24 NA 24 NA 96.9 6/23/2009 R-14 50029209090100 2021560 0 NA 0 NA 0.04 5/18l2009 R-15A 50029209170100 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 50029206860000 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 50029206770100 1981380 4 NA 4 NA 27.2 5/15/2009 R-186 50029206330200 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 50029206370100 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 50029209970000 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 50029210050000 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 50029210130100 1972020 2.25 NA 2.25 NA 16.2 6/12/2009 R-24 50029212320000 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 50029222780100 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 50029215470000 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 50029215570000 1860510 0.25 NA 0.25 NA 1.7 6/11/2009 R-29 50029222750100 1971070 20 3.9 1.25 NA 11.05 5/14/2009 R-31 A 50029222770100 2021500 1.5 NA 1.5 NA 8.5 5/11 /2009 R-32A 50029224130100 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 50029224080000 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 50029224240000 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 50029225220000 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 50029225260100 1960840 2 NA 2 NA 22.1 5/11/2009 R-40 50029229260000 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 50029233990000 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 r~ ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 26, 2009 (~ ~ (~ 3 ~ ~"1~ ,~~ Mr. Tom Maunder ~.~ Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of R-Pad Dear Mr. Maunder, ~~ ~ ~~ ~ ~ .a ~ , JUL ~ ~ Z00~ ~~~~~~ ~A~ Ga~ Conse ~orn~i~~ia~ Anchor~ , Enclosed please find a spreadsheet with a list of wells from R-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, 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, Anna Dube, at 659-5102. Sincerely, .. , ~~~c~. ~~~`~~~~~~.: ,~ ~ { ~ R . ~~ Torin Roschinger BPXA, Well Integrity Coordinator ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~'' Date R-pad • 6/25/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al R-02 1781000 1.25 NA 125 NA 6.8 5/11 /2009 R-03A 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 1972500 0 NA 0 NA 3 5/13/2009 R-06A 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 2000100 2.25 NA 2.25 NA 43 5l11 /2009 R-08 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 1810930 2 NA 2 NA 14.5 6/22/2009 R-11 A 1982060 0.25 NA 0.25 NA 1.7 6/11 /2009 R-12 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 1830440 3.75 NA 3.75 NA 76.5 6/22/2009 R-14 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 1981380 4 NA 4 NA 27.2 5/15/2009 R-18B 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 1972020 2.25 NA 225 NA 16.2 6/12/2009 R-24 1842160 9.5 NA 9.5 NA 37.4 6/12l2009 R-25A 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 1860510 0.25 NA 0.25 NA 1.7 6/11/2009 R-29 1971070 20 3.9 1.25 NA 11.05 5/14/2009 R-31A 2021500 1.5 NA 1.5 NA 8.5 5/11l2009 R-32A 1980090 0.75 NA 0.75 NA 8.5 6/11 /2009 R-34 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 1941440 3.25 NA 325 NA 44.2 5/14/2009 R-39A 1960840 2 NA 2 NA 22.1 5/11 /2009 R-40 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 lVIEMORANDUlVI . TO: T<ef1 ~'SDl Jim Regg P.I. Supcrvisor FROM: Chuck Scheve Petroleum Inspector Well Name: PRUDHOE BAY UNIT R-15A Insp Num: mitCS070307072932 Rei Insp Num Packer . .-.._~.~-~--------- --~,._------ Well P.T. R-15A Type Inj. W TVD -----.._-------~--------. -.------------ 1990360 TypeTest SPT' Test psi ---------------- -;7----- -------- State of Alaska . Alaska Oil and Gas Conservation Commission DATE: Mondav. \Iarch 12.2007 SL BJECT: \kchanicallntêgnty rests 8? EXPLORATiON -~LÄ.SK.~) I'\C R-!SA PRUDHOE SA Y UNIT R-! 5A Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-20917-01-00 Permit Number: 199-036-0 Depth Pretest Initial 8376 , IA 320 2600 2094 .OA 0 0 Tubing 550 550 .ll!terYªL.':'RKo\¡"~_~P/F______ __ __________________. Notes Pretest pressures observed and fOlll1d stable Well demonstrated good mechanical Integrity. Monday, March 12,2007 c;('I~\\\NE.D MpJ{ 2. 1 7..007 \;,,')'(~)r ,. Reviewed By: P.I. Suprv 'St3f2-- Comm Inspector Name: Chuck Scheve Inspection Date: 3/611007 2560 2550 15 Min. 30 Min. 45 Min. 60 Min. o 0 -------- 550 550 v' - ---- Page 1 of 1 ~ ~ I STATE OF ALASKA ~'P? ALAS Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS A RECEIVED FEB 2 0 2007 laska Oil & Gas Cons. ^ 1. Operations Performed: Anchorage D Abandon 181 Repair Well D Plug Perforations D Stimulate D Re-Enter Suspended Well D Alter Casing 181 Pull Tubing' D Perforate New Pool D Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. o Development D Exploratory 199-036 .¡ 3. Address: D Stratigraphic 181 Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20917-01-00 / 7. KB Elevation (ft): 48.96' / 9. Well Name and Number: PBU R-15A ¡ 8. Property Designation: 10. Field / Pool(s): ADL 028279 ¡- Prudhoe Bay Field / Prudhoe Bay Pool ' 11. Present well condition summary Total depth: measured 11986 feet true vertical 8813 feet Plugs (measured) None Effective depth: measured 11986 feet Junk (measured) None true vertical 8813 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2673' 13-3/8" 2673' 2673' 4930 2670 Intermediate 8402' 9-518" 8402' 8094' 6870 4760 Production Liner 806' 7" 8240' - 9046' 7941' - 8683' 7240 5410 Liner 2639' 4-1/2" 8902' -11541' 8552' - 8824' 8430 7500 Tieback 8221' 7" 24' - 8245' 24' - 7945' 7240 5410 ~~ FES 2 7 2007 Perforation Depth MD (ft): 11498' - 11986' Perforation Depth TVD (ft): 8828' - 8813' 4-1/2", 12.6# L-80 8909' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker 'SB-3' packer 8853' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut & pulled tubing from 8818'. Cut & pulled 9-5/8" Casing from 1895'. Run new 9-5/8" casing to 1895', cement w/160 Bbls of LiteCrete (Yield 1.87). Run 7" Tieback, cement w/83 Bbls Class 'G' and 150 Bbls Class 'G' (both Yield 1.17). Run new tubinQ. 13. ReDresentative Dailv Averaoe Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory o Development 181 Service 16. Well Status after proposed work: 181 Well Schematic Diagram DOil o Gas 181 WAG oGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 306-364 Printed Name Terrie Hubble Title Technical Assistant Signature /fÔ ^L 0 't-L J Q,ß,(J n Pl]pne 564-4628 o z.~ ~ h Prepared By Name/Number: Date 1 ~ 0'7 Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 t'H:'h)M~ tsrt fTH; Submit Original Only OR\G\NAL i ~J-{}-\ . Well Events for SurfaceWell - R-15 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC2 -> R -> R-15 Date Range: 11/Nov/2006 to 18/Dec/2006 Data Source(s): DIMS, AWGRS Digital Wellfile . Events Source Well AWGRS R-15A AWGRS R-15A AWGRS R-15A AWGRS R-15A AWGRS R-15A AWGRS R-15A AWS;;RS R-15A AWGRS R-15A Date 12/18/2006 12/14/2006 12/12/2006 12/11/2006 12/07/2006 12/05/2006 12/04/2006 12/03/2006 AWGRS R-15A 12/02/2006 AWGRS R-15A 11/21/2006 AWGRS R-15A Awc;,RS R-15A AWGRS R-15A 11/19/2006 11/18/2006 11/17/2006 AWGRS R-15A 11/14/2006 AWGRS R-15A 11/13/2006 AWGRS R-15A 11/13/2006 AWGRS R-15A AwGBS R-15A 11/12/2006 11/12/2006 . Page 1 of 2 Description SET BPV PRE RIG API VALVE SHOP T/IA/OA=SI/O/O PRE-RIG WELLHEAD MIT PPPOT-T Passed PPPOT-IC Passed Cycle all LDS on tubing spool [backed out to clear bowl] all ok no signs of any bent or broken LDS Cycle all LDS on casing spool **** note [1] LDS from previous well work is painted red [old records show nose to be ground off ]**** NOTE: 2) 1 5/8" studs need changed or adjusted on casing head to tubing head flanges. T/I/O=100/275/0 ( Circ-Out ) Awgers continued from 12-11-06 ( U-Tube Tx IA ) FWHP=O/O/O T/I/O=100/275/0 ( Circ-Out) Pump 5 bbl meth spear followed by 1548 bbls water down TBG @ 4.7 bpm. Swap to IA and Pump 151 bbls diesel. U-Tube IA x TBG for 1 Hr. Bleed WHP Back to 0 Psi. Awgers continued on 12-12-06 T/I/O= 120/200/0+ Supersuck cellar, install spray in liner (pre-rig). Cellar is 8' x 10' metal type. Used Super Sucker to remove gravel from cellar and around conductor. Conductor is sealed type insulated 30" x 20". Dug down 3' on the outside of 30" to try and locate cement nipples. No cement nipples were found. Leveled out cellar to 3.5' from top to bottom. Gravel is now 2' below top of conductor. Cellar is prep'd for rhino liner. Final WHPs=120/200/0+ T/I/O=120/200/0+. Temp=SI. Supersuck cellar, install spray-in liner (pre-rig). No change in psi overnight. Supersucked 24" down to the frost line inside the cellar box and pulled out 5.9 cubic yards of gravel. Installed herculite over open cellar & placed heater trunk under the herculite cover. Will return @ later date to continue job. Final WHP's= 120/200/0+. T/I/O= 120/200/0. Temp= SI. Supersuck cellar, install spray-in liner (pre-rig). No change in pressures overnight. Heater ran out of fuel. Ground still frozen. Ordered new heater for well. Continue at a later date. T/I/O= 120/200/0. Temp= SI. Supersuck cellar, install spray-in liner (pre-rig). No change in pressures overnight. Supersucked 10" down into cellar box about a yard of gravel. Put heater on gravel with herculite over the top to thaw. Will continue at a later date. T/I/O= 110/200/0. Temp= SI. Supersuck cellar, install spray-in liner (pre-rig). Installed heater inside of wellhouse to thaw gravel for removal. ***WELL SHUT IN ON ARRIVAL. SSV OPEN*** INITIAL T/I/O=50/250/0 CHEM CUT AT 8813FT IN MIDDLE OF JOINT. 4.5" L-80 TBG CUT WITH 2"x80" AND 14" OF 9/16 GAS GRAIN. **** WELL LEFT SHUTIN WITH DSO, SSV OPEN **** **** WELL SHUTIN ON ARRIVAL **** SSV OPEN SMALL TUBING PUNCH, 2FT LONG, SHOT OVER INTERVAL 8754 - 8756. 12' STRING SHOT WITH 2 STRANDS SHOT OVER INTERVAL 8803-8815'. ***WELL SHUT IN ON DEPARTURE***. SSV OPEN ***JOB NOT COMPLETE*** T/I/O= 200/340/0. Temp.= SI. WHP's. (Pre Cam). TP no change overnight. lAP increased 20 psi overnight. OAP no change overnight. T/I/O= 1600/1600/0. Temp.= 51. Bleed WHP's to 0 psi. (pre Cam). TBG FL @ surface, IA & OA FL's near surface. Bleed TBGP to production from 1600 psi to 200 psi in 1 hour. lAP came down to 300 psi during TBG bleed. Shut-in and monitored WHP's for 1 hour. After 1 hour monitor there was no change in TP. lAP increased 20 psi. OAP no change. TBG FL @ surface, IA & OA FL's are near surface. Could not get bleed tank to get WHP's down to 0 psi. Will continue at a later date. Final WHP's= 200/320/0. ***CONTINUED FROM WSR 11/13/06***(PRE RWO) CMIT TUBING / lA, W/ 60 BBL'S DIESEL, TO 3450PSI, (PASSED) ***LEFT WELL S/I, SSV DUMPED NOTIFIED DSO ON DEPARTURE*** ***WSR continued from 11/12/06*** ASSIST SLICKLINE; Brush and Flush the TBG with 153 bbls of 190* diesel into the TBG. Final WHP= 400/350/0. ***CONTINUED FROM WSR 11/12/06*** (pre rwo) BRUSHED FROM 8200'SLM TO 8881'SLM (XN NIPPLE) W/ 4.5 BLB, 3.805 G-RING WHILE LRS PUMPING (HOT DIESEL BRUSHED FROM 8200'SLM TO 9000'SLM W/ 4.5 BLB (STIFF) 3.625 G-RING, WHILE LRS PUMPING, MADE SEVERAL PASSES FROM 8800' SLM TO 9000'SLM TOTAL 150 BBL'S HOT DIESEL AWAY. SET 4.5 XXN PLUG W/ 8, 1/8" PORTS, 13" FILL EXT,@8881'SLM SET TOP OF 4.5" JUNK CATCHER @ 8872' SLM (JUNK CATCHER = (O.D.3.75" F.N, 3.50" O.D. BODY, 3.75" O.D. BASE) OAL 115") USE 4.5" GS TO PULL. ATTEMPT TO DO CMIT ***CONTINUED ON WSR 11/14/06*** T/I/O= 0/100/0. ASSIST SLICKLINE; Brush and flush the TBG. ***WSR continues on 11/13/06*** ***CONTINUED FROM WSR 11/11/06*** CO NT LOG TBG FROM 9300'SLM TO 6463'SLM BRUSH TBG TIGHT SPOT 7877' SLM TO 8008'SLM ***CONTINUED ON WSR 11/13/06*** http://digitalwellfile.bpweb.bp.comIW ellEvents/HomelDefault.aspx 2/15/2007 Digital Wellfile . AwGRS R-15A 11/11/2006 . Page 2of2 ***WELL S/I ON ARRIVAL *** DRIFT TUBING W/ 3.70.T TO 9316' SLM STOP DUE TO DEV. CALIPER TBG FROM 9300' SLM TO SURFACE RE-CALIPER TBG FROM 9300' SLM TO 670S'SLM (BAD DATA) RE-CALIPER TBG FROM 9300' SLM TO 670S' SLM ( BAD DATA) CHANGE CALIPER. ***CONTINUED ON WSR 11/12/06*** http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 2/15/2007 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-15 R-15 WORKOVER DOYON DRilLING INC. DOYON 16 Start: 12/27/2006 Rig Release: Rig Number: 16 Spud Date: 2/14/1983 End: 1/412007 14:00 - 19:00 5.00 MOB P PRE Move off DS 12-14, Spot Rig To Lay Down Derrick, UD Derrick, Remove BOPs to Traveling Stand. Install Booster Wheels 19:00 - 00:00 5.00 MOB P PRE Move Rig Off DS 12 to R-Pad. 1/5/2007 00:00 - 00:30 0.50 MOB PRE Continue to Move Rig to R-Pad, Blew ODS Rear Tire in Route to R-Pad on Spine Road. 00:30 - 00:00 23.50 MOB PRE Replace ODS Rear Tire. Decission made to Change Out Both Tires. This will eliminate all the older Firestone Tires from the rear of the rig. 1/6/2007 00:00 - 01 :00 1.00 MOB PRE Continue to Replace Rear ODS Tires on Rig Move to R-Pad. 01 :00 - 04:00 3.00 MOB PRE Both Tires Replaced and Back of Rig Put Back together. Rig moving in route to R-Pad. 04:00 - 08:00 4.00 MOB PRE DS Drive Motor Failure. Rig Dead in the Road. Made 4-1/2 miles since tire failure. Replacing Drive Motor. 08:00 - 14:00 6.00 MOB PRE Continue to Move to R-Pad. 14:00 - 21 :00 7.00 MOB PRE Rimove Booster Wheels, Install Heaters in Cellar, Install BOPs to Cellar, R/U Choke and Kill Lines. 21 :00 - 22:30 1.50 MOB PRE PJSM Prep and Raise Derrick, R/U Rig Floor. 22:30 - 00:00 1.50 MOB PRE Lay Herculite around Well, Set Rig Mats. 1/7/2007 00:00 - 05:30 5.50 MOB P PRE Spot Rig over Well R-15, R/U Generator Complex, and #2 Pump Room, R/U Secondary Annulus Valve, and Circulating Lines, Spot Slop Tank, Un-Bridle Blocks, R/U Rig Floor. 05:30 - 06:00 0.50 WHSUR P DECOMP Taking on Sea Water, R/U DSM to Pull BPV. 06:00 - 07:00 1.00 WHSUR P DECOMP Pull BPV. Tbg = Vac, IA and OA = psi. Laydown BPV Lubricator. 07:00 - 08:00 1.00 KILL P DECOMP R I U Circulating Manifold, Lines and Hoses to circ out well. 08:00 - 08:30 0.50 KILL P DECOMP PJSM on Circ Out. PT Lines to 3500 psi. 08:30 - 10:30 2.00 KILL P DECOMP Circulate Well to Clean Seawater. Pump 40 bbl High Visc Sweep and Chase with 675 bbls of 120 deg F Sw. Circulate well at 9 bpm and 1800 psi. 10:30 - 11 :00 0.50 WHSUR P DECOMP Blow Down Lines and Hoses. Cameron Install TWC. 11 :00 - 12:30 1.50 WHSUR P DECOMP Pressure Test TWC from below to 1000 psi - Good Test. Pressure Test TWC from above to 3500 psi - Leaking - 150 psi in 5 mins. Call Out DSM for Lubricator to Pull and Replace TWC. 12:30 - 14:30 2.00 WHSUR N WAIT DECOMP Wait on DSM and Lubricator. 14:30 - 16:30 2.00 WHSUR N SFAL DECOMP PIU DSM Lubricator and Pull TWC. Visual inspection shows no problems. Stand Back Lubricator and Set 2nd TWC wI Cameron. Pressure Test TWC again to 1000 psi from below- Good Test. Pressure Test TWC from above to 4000 psi. - Good Test. All Tests Charted. 16:30 - 17:00 0.50 WHSUR P DECOMP Rig Down Circulating Manifold, Test Lines and Hoses. UD DSM Lubricator. 17:00 - 18:30 1.50 WHSUR P DECOMP Bleed Down Void, Nipple Down Tree and Nipple Down Adapter. 18:30 - 19:30 1.00 WHSUR P DECOMP Function Lock Down Screws, Check XO to Hanger, 9 Rounds to Make Up. 19:30 - 21 :30 2.00 WHSUR P DECOMP NIU Double Valve to OA, Nipple Up BOPE. 21 :30 - 22:00 0.50 WHSUR P DECOMP R/U to Test BOPE. 22:00 - 00:00 2.00 WHSUR P DECOMP Test BOPs (Tighten Choke Hose Flange and Trouble Shoot Test Pump). 1/8/2007 00:00 - 05:00 5.00 WHSUR P DECOMP Test BOPE to 250 psi Low Pressure and 4,000 psi High Pressure.The Hydril was tested to 3,500 psi. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Printed: 1/30/2007 11 :43:46 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-15 R-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/27/2006 Rig Release: Rig Number: 16 Spud Date: 2/14/1983 End: 1/812007 00:00 - 05:00 5.00 WHSUR P DECOMP John Crisp. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- Choke Valves, #12,13,14, Kill HCR, Upper IBOP, Blind Rams. Test #2- Choke Valves #9, 11, Manual Kill, Lower IBOP. Test #3- Choke Valves #5,8, 10, TIW Valve. Test #4-Choke Valves, #4, 6, 7, Dart Valve. Test #5- Choke Valve #2 and Lower VBRs 4". Test #6- Choke Valve #1, 3. Test #7-Manual Choke Test #8- Lower VBRs 4.5" Test #9- Annular Preventer Accumulater Test- 3,000 psi Starting Pressure, 1850 psi After Actuation, First 200 psi in 14 seconds, Full Pressure in 1 Minute 12 Seconds. 5 Nitrogen Bottles at 2,100 psi. 05:00 - 05:30 0.50 WHSUR P DECOMP RID BID Surface Lines, RID Test Equipment. 05:30 - 06:30 1.00 WHSUR P DECOMP RlU DSM Lubricator to Pull Two Way Check. 06:30 - 07:30 1.00 PULL P DECOMP P/U Baker Double Spear and M/U to Joint of DP. RIH wI Spear and Engage Tbg. 07:30 - 08:30 1.00 PULL P DECOMP BOLDS and Check for Flow I Pressure on Annulus. 08:30 - 09:30 1.00 PULL P DECOMP Attempt to Pull Hanger to Floor. Hanger Pop Free at 160,000 Ibs. Continue to Pull Up to 80% of 4-1/2" Tbg String. Work Up to 230,000 Ibs. Tbg Not Cut will Not Pull Free. Work Pipe from 100,000 to 230,000 Ibs several times. 09:30 - 10:30 1.00 PULL P DECOMP Circulate bottoms up at 8 bbls I min and 2100 psi. 10:30 - 11 :30 1.00 PULL P DECOMP Attempt to work pipe again while waiting on E-Line for Chem Cutter. 11 :30 - 12:30 1.00 PULL P DECOMP Set Hanger Back on Seat. RILDS. Release Spear and UD. 12:30 - 13:30 1.00 PULL P DECOMP Nipple Down Flow Riser and Nipple Up Shooting Flange. 13:30 - 14:30 1.00 PULL P DECOMP Move in and Spot E-Line. Load Riser, BOPE, Lubricator, and Pack Off to Rig Floor. PJSM wI E-Line Crew and Rig Crew on Chem Cutter Operations. 14:30 - 16:00 1.50 PULL P DECOMP Rig Up E-Line Sheeves and Tools. Chem Cutter for 4-1/2" 12.6# Tubing. Pressure Test Riser and BOP Equipment. 16:00 - 17:00 1.00 PULL P DECOMP RIH wI E-Line Chem Cutter. Tie In Log to Last Chem Cut Run on 11/19/06 and to Tubing Tally. Cut Tubing at 8818', five feet deeper than last cut. 17:00 - 18:00 1.00 PULL P DECOMP POOH wI Chem Cutter. 18:00 - 18:30 0.50 PULL P DECOMP RID SWS E-line Crew. 18:30 - 19:00 0.50 PULL P DECOMP N/D Shooting Flange, N/U Flow Riser. 19:00 - 19:30 0.50 PULL P DECOMP P/U Spear Change out Grapple, Spear Tubing B/O Lock Down Screws. Hanger Pulled Free w/96,000 Ibs Up Weight. Pull Hanger to Floor. 19:30 - 20:30 1.00 PULL P DECOMP CBU at 10 bpm at 2060 psi. 20:30 - 21 :00 0.50 PULL P DECOMP Back Out Spear and Hanger - UD Same. 21 :00 - 22:30 1.50 PULL N HMAN DECOMP Casing Crew delivered Wrong Size Heads with Casing Equipment. Changed out Heads on Power Tongs When Proper Size was Delivered. 22:30 - 00:00 1.50 PULL N DECOMP POOH w/4.5",12.6#,L-80, NSCT. 1/9/2007 00:00 - 06:00 6.00 PULL P DECOMP Pulling and UD 4.5",12.6#, L-80, NSCT Completion. Tubing in Generally Good Condition jt #71 had Pin Holes just under Tool Printed: 1/30/2007 11 :43:46 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-15 R-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/27/2006 Rig Release: Rig Number: 16 Spud Date: 2/14/1983 End: 1/912007 00:00 - 06:00 6.00 PULL P DECOMP jt, 3 jts had Split Collars, 1 X nipple, 215 jts, and cut jt, Clean Cut No Flaring, Length = 24.15'. 06:00 - 07:00 1.00 PULL P DECOMP Clear and Clean Rig Floor. 07:00 - 07:30 0.50 PULL P DECOMP Service Top Drive, Blocks, Draworks, and Iron Roughneck. 07:30 - 08:00 0.50 PULL P DECOMP Install Wear Ring. 08:00 - 12:00 4.00 PULL P DECOMP Load and Tally 18 jts HT-38 Drill pipe for BHA, P/U Dress Off BHA and 9 - 6.25" Drill Collars. 12:00 - 18:30 6.50 PULL P DECOMP RIH PIU 4" HT-38 Drill Pipe from Pipe Shed 1x1 to 8,252' 18:30 - 19:30 1.00 PULL P DECOMP Attempt to Work Through Tight Spot with Parameter of, 90 RPM, 5,000 to 10,000 ftIlbs of Torque, 5.5 bpm w/680 psi, 170,000 # Up Weight, 162,000# Down Weight, 170,000# Rotating Weight, Mill Depth 8,252',(12' inside Liner top), 7"CSG Scraper at 8,228' (12' above Liner Top), 95/8" CSG Scraper at 7,646' (594' above Liner Top). 19:30 - 22:00 2.50 PULL P DECOMP POOH w/4" Drill Pipe. 22:00 - 00:00 2.00 PULL P DECOMP POOH with Drill Collars, UD 9 5/8" CSG Scraper, NO Indication of Wear on 9 5/8" Scraper. UD Junk Baskets. UD 18 jts of HT-38 DP. 1/10/2007 00:00 - 00:30 0.50 CLEAN P CLEAN UD 7" Scraper and Boot Baskets, No Indication of Wear on 7" Scraper or Boot Baskets, Dress Off Mill Over Shot Showed Signs of Wear and Scaring on the Outside of the Overshot Barrel. The face of the Mill Showed No Signs of Wear. 00:30 - 01 :00 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 01 :00 - 01 :30 0.50 CLEAN P CLEAN Load and Tally 12-4.75" Drill Collars, Prepared BHA #2, 01 :30 - 03:00 1.50 CLEAN P CLEAN P/U and M/U 6 1/8" Bit, 7" CSG Scraper, 2 - 4.75"Junk Baskets, X0,4.75" LBS, 4.75"Jar, XO, 12 - 4.75" Drill Collars, BHA Lenght = 403.10'. 03:00 - 05:00 2.00 CLEAN P CLEAN RIH w/4" HT-38 Drill Pipe to 7,783' 05:00 - 06:00 1.00 CLEAN P CLEAN Picked up Singles from Pipe Shed 1x1 to 8240' Top of 7" Liner. Bottom of Tie Back Receptical at 8,246' Ran Bit through liner Top and Tie Back Receptical Took 5,000 Ibs. M/U Top Drive Worked Through This Area and Rotated and Reciprocated Through This Area with no Torque or Drag. 06:00 - 07:30 1.50 CLEAN P CLEAN CBU @ 10 bpm w/2,500 psi. Monitor Well, BID Top Drive. 07:30 - 10:30 3.00 CLEAN P CLEAN POOH f/8,813'. 10:30 - 12:00 1 .50 CLEAN P CLEAN Stand Back 4 stds 4 3/4" Drill Collars, UD 7"CSG Scraper, Clean Boot Baskets No Recoverey in Boot Baskets. 12:00 - 13:00 1.00 CLEAN P CLEAN M/U Dress Off Assembly, RIH wlDrill Collars. 13:00 - 15:00 2.00 CLEAN P CLEAN RIH tI 8,751 '. 15:00 - 15:30 0.50 CLEAN P CLEAN Obtain Parameters, 80 rpm, 5,000 ftIlbsTorque, 5,000# wob, 5.5 bpm, 740 psi, Tag Tubing Stub at 8,818'. Mill 2" off Stub. 15:30 - 16:30 1.00 CLEAN P CLEAN Pump 20 bbl Sweep @ 10 bpm w/2,230 psi, Pump Dry Job. 16:30 - 09:00 16.50 CLEAN P CLEAN POOH 19:30 - 21 :00 1.50 CLEAN P CLEAN UD 12 - 4 3/4" Drill Collars and Dress Off Assembly. 21 :00 - 00:00 3.00 CLEAN P CLEAN M/U 7" RBP Assembly and RIH to 5,955'. 1/11/2007 00:00 - 01 :00 1.00 CLEAN P CLEAN Continue to RIH f/5,955' to 8,340' Parameters 152,000 Ibs Up Weight, 152,000 Ibs Down Weight. 01 :00 - 02:00 1.00 CLEAN P CLEAN Set RBP, Center of Element at 8,340' Top of Assembly at 8,336'. Set Down 15,000# to Confirm Set. Rack Back One Stand. RIU and Pressure Tested RBP to 2,500 psi for 15 Minutes on Chart, Good Test. 02:00 - 03:00 1.00 CLEAN P CLEAN Dumped 1,200 Ibs of 20 - 40 River Sand Through Drill Pipe on RBP. Printed: 1/30/2007 11 :43:46 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-15 R-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/27/2006 Rig Release: Rig Number: 16 Spud Date: 2/14/1983 End: 1/11/2007 03:00 - 03:30 0.50 CLEAN P CLEAN Pump 44 bbls at 2 bpm to Clear Drill Pipe. RID BID Circulating Lines. 03:30 - 04:00 0.50 CLEAN P CLEAN P/U Std Drill Pipe, and Tagged Top of Sand at 8,282' 04:00 - 07:00 3.00 CLEAN P CLEAN POOH f/8,282' with Running Tool to Surface, UD RBP Running Tool. 07:00 - 10:30 3.50 CLEAN P CLEAN P/U Pressure Control Equipment to Rig Floor, RlU SWS Tools to Run USIT and Corrosion Logs. 10:30 - 16:30 6.00 CLEAN P CLEAN RIH w/USIT Logging Tools to 8,160'. Logged Up in Cement Evaluation I Corrosion Mode to 2,673'. Logged up from 2,673 to Surface to determine Top of Cement. Top of Cement at 1,980' 16:30 - 17:30 1.00 CLEAN P CLEAN RID Usit Logging Tools. 17:30 - 18:00 0.50 CLEAN P CLEAN NID Riser, N/U Shooting Flange. 18:00 - 20:30 2.50 CLEAN P CLEAN RlU Lubricator Extendsion, BOPs Pump in Sub and Pack Off. Test SWS Surface Equipment to 1,000 psi. 20:30 - 22:00 1.50 CLEAN P CLEAN MIU String Shot RIH and Fire Shot Between 1,895' and 1,907'. 22:00 - 23:30 1.50 CLEAN P CLEAN RID SWS E-Line Equipment. 23:30 - 00:00 0.50 CLEAN P CLEAN NID Shooting Flange, NIU Flow Riser. 1/12/2007 00:00 - 00:30 0.50 CLEAN P CLEAN Continue to NIU Flow Riser and Clear Rig Floor of SWS Equipment. 00:30 - 01 :00 0.50 CLEAN P CLEAN MIU 95/8" RBP and Running Tool, RIH wlOne Stand of DP and Test Set RBP and Release. 01 :00 - 02:30 1.50 CLEAN P CLEAN Continue to RIH w/RBP to 2,500', Up Weight = 70,000 Ibs, Down Weight = 75,000 Ibs, RBP Set at 2,498'Center of Element, Top of RBP Assembly at 2,493. 02:30 - 03:00 0.50 CLEAN P CLEAN RlU Test Equipment. Pressure Test RBP to 1,000 Psi for 10 Charted Minutes. Good Test. 03:00 - 03:30 0.50 CLEAN P CLEAN Pump Drill Pipe Volume to Balance Well at 7 bpm w/700 psi. 03:30 - 04:30 1.00 CLEAN P CLEAN Dump 2,200 Ibs Sand down Drill Pipe on RBP. 04:30 - 05:00 0.50 CLEAN P CLEAN Pump 13 bbls@ 2 bpm, 60 psi, To Clear Drill Pipe of Sand, RID Circulating Lines. 05:00 - 05:30 0.50 CLEAN P CLEAN P/U std DP Tagged Sand @2,449'. 05:30 - 06:30 1.00 CLEAN P CLEAN Displace Well to 9.8 ppg Brine, 20 bbl Hi-Vis Sweep Followed by 177 bbls 9.8 ppg Brine. 06:30 - 07:30 1.00 CLEAN P CLEAN POOH w/RBP Setting Tool UD Same. 07:30 - 09:00 1.50 CLEAN P CLEAN PIU Multi String Cutter BHA and 3 Stands Drill Collars. 09:00 - 10:00 1.00 CLEAN P CLEAN RIH with Multi String Cutter. 10:00 - 11 :00 1.00 CLEAN P CLEAN Cut and Slip Drilling Line. 11 :00 - 12:00 1.00 CLEAN P CLEAN Service Rig, Top Drive and Iron Roughneck. 12:00 - 14:00 2.00 CLEAN P CLEAN Waiting on Brine, Remove Gravel from Cellar. Build Herculite Top for Flow Back Tank. 14:00 - 15:00 1.00 CLEAN P CLEAN Locate Collar @ 1,895' Cut 9 5/8" Casing at 1,882'. Cutting Parameters are 85 rpm, 5 bpm with 1,000 psi. Lost 32 bbls 9.8 ppg Brine during Cutting Operations. 15:00 - 16:30 1.50 CLEAN P CLEAN RlU Little Red, Test Lines to 2,800 psi, Displace Drill Pipe w/19 bbls Diesel, Close Annular Preventer, Pumped 6 bbls Diesel wlLittle Red at 2.5 bpm at 800 psi and 10 bbls at 2.5 bpm with 600 psi. With No Returns. 16:30 - 17:00 0.50 CLEAN P CLEAN Discuss Options 17:00 - 17:30 0.50 CLEAN P CLEAN RID Little Red RlU Little Red, Clear Line to Flow Back Tank w/4 bbls Diesel at 250 psi. 17:30 - 18:00 0.50 CLEAN P CLEAN Bull Headed 25 bbls Down Drill Pipe, and 15 bbls Down 9 518"Annulus at 4 bpm w/450 psi. Printed: 1/30/2007 11 :43:46 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-15 R-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/27/2006 Rig Release: Rig Number: 16 Spud Date: 2/14/1983 End: 1/12/2007 18:00 - 18:30 0.50 CLEAN P CLEAN Circulate at 4 bpm with 600 psi, Lost 32 bbls at a rate of 60 bph. 18:30 - 20:00 1.50 CLEAN P CLEAN Monitor Well, Fluid Level Dropped to Well Head Level. 20:00 - 00:00 4.00 CLEAN P CLEAN Dropped Ball and Rod Opening Circ Sub at 1,200 psi, Circulated at 4 bpm. Fluid Temp 80 deg going In and 61 deg Coming Out at Beginning of Circulation. At Midnight Temp Going in 98 deg and 80 deg Coming Out. Losses Reduced to 48 bph. Total Losses for Tour 213 bbls 1/13/2007 00:00 - 03:30 3.50 CLEAN P CLEAN Continue to Circulate IA at 2 bpm with Average Losses of 46 bph, 9.8 Brine Temp 100 deg Going in and 84 deg Coming Out, Mixing 80 bbl LCM Pill, 20 ppb MI Seal Medium, 20 ppb MI Fine, 20 ppb MI Mix 2 Coarse, and 2 pales of Flow Vis. 03:30 - 04:30 1.00 CLEAN P CLEAN Pump 30 bbls HI-Vis LCM Pill Down Drill Pipe, Cleared Drill Pipe Volume with 20 bbl 9.8 ppg Brine,Closed Annular Preventer, Opened 133/8" Annulus to Flow Back Tank and Pumped Down Kill Line to Clear 9 518" x 4" Annulus. Attempt to Spot LCM through Casing Cut. Approx 1 bbl of Arctic Pack Returns to Flow Back Tank, Closed 133/8" Annulus line, Allowed LCM to Soak for 20 Minutes, Pressured up to 1,000 Psi. Reconfirm Process 2 Times With Same Results. 04:30 - 05:30 1.00 CLEAN P CLEAN Continue to Circulate 100 deg 9.8 brine Down Drill Pipe Taking Returns up 9 518" Casing. To Heat 133/8" Annulus and Arctic Pack in Preparation to Circulate Out Arctic Pack. 05:30 - 08:00 2.50 CLEAN P CLEAN Pressure Up to 2,000 psi, Establish Circulation in 13 3/8" Annulus at 2 bpm at 40 psi Taking Arctic Pack Returns to Flow Back Tank. Approx 15 bbls of Arctic Pack to Surface Followed by 9.8 brine. Suspected Partial loss of Returns to Well Bore. 08:00 - 09:00 1.00 CLEAN P CLEAN Pump 30 bbl Hi-Vis LCM Pill Down Drill Pipe and Closed Annular Preventer Pumped Down 9 5/8"x4"Annulus and Squeezed LCM into 13 3/8" Annulus. Pumped Second 25 bbl Hi-Vis LCM Pill with Annular Preventer Closed and Squeezed Pill into 133/8" Annulus. 09:00 - 12:00 3.00 CLEAN P CLEAN Mix 50 bbl Hi-Vis LCM Pill. 12:00 - 13:00 1.00 CLEAN P CLEAN Pumped 52 bbl Hi-Vis LCM Pill Down Drill Pipe Close Annular Preventer and Bull Headed Pill Through Cut Into Formation. Pumped at 3 bpm w/280 to 690 psi. 13:00 - 15:30 2.50 CLEAN P CLEAN Monitor Well, Formation is Holding 150 psi. While Mixing LCM Pill Pump 1 bbl every 15 min, Pressure Increase to 110 psi and Bleds to 60 psi. 15:30 - 17:30 2.00 CLEAN P CLEAN Pumping 60 bbl LCM, Close Annular Preventer, Pumped at 5 bpm 300 psi Bull Heading to Formation. Pump 30 bbls #1 Pump Plugged Off, Pulled Screens on #2 Pump. Began Pumping at 2.5 bpm with 400 psi. LCM Pill Difficult to Pump, Added 15 bbls Hi-Vis Sweep to LCM Pill. Followed LCM Pill with 9.8 PPG Brine and Cleared Drill Pipe. 17:30 - 22:00 4.50 CLEAN P CLEAN Monitor Well, Shut in w/260 psi Bled Down to 60 psi, While Mixing LCM Pill. 22:00 - 23:00 1.00 CLEAN P CLEAN Establish Loss Rate Circulating Down Drill Pipe Taking Returns up 9 5/8" Annulus for 15 Minutes at 5 bpm and 250 psi with No Losses. Temp 120 deg Going In and 80 deg Coming Out. 23:00 - 00:00 1.00 CLEAN P CLEAN Pump 60 bbl LCM Pill Down Drill Pipe to 9 5/8" Annulus, at 5 bpm w/850 psi. Closed Annular Preventer and Pump Down 9 5/8" Annulus With Kill Line, Pumped to 250 psi and Let Printed: 1/30/2007 11 :43:46 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-15 R-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/27/2006 Rig Release: Rig Number: 16 Spud Date: 2/14/1983 End: 1/13/2007 23:00 - 00:00 1/14/2007 00:00 - 01 :30 01 :30 - 02:30 1.00 CLEAN P CLEAN 1.50 CLEAN P CLEAN 1.00 CLEAN P CLEAN 02:30 - 03:00 0.50 CLEAN P CLEAN 03:00 - 03:30 0.50 CLEAN P CLEAN 03:30 - 05:30 2.00 CLEAN P CLEAN 05:30 - 11 :30 6.00 CLEAN P CLEAN 11 :30 - 12:00 0.50 CLEAN P CLEAN 12:00 - 13:00 1.00 CLEAN P CLEAN 13:00 - 20:00 7.00 CLEAN P CLEAN 20:00 - 21 :30 1.50 CLEAN P CLEAN 21 :30 - 22:00 0.50 CLEAN P CLEAN 22:00 - 23:30 1.50 CLEAN P CLEAN 23:30 - 00:00 0.50 CLEAN P CLEAN 1/15/2007 00:00 - 01 :00 1.00 CLEAN CLEAN 01 :00 - 06:30 5.50 CLEAN P CLEAN Pressure Bled to 150 psi, Increased Pressure to 250 psi and let bled to 150 psi. Continued to Hold Hesitation Squeeze on LCM Pill to Spot LCM into Loss Zone. Spotted LCM Pill in 9 5/8"x 4" Annulus, Well Bore Stable While Static, Closed Annular Preventer Hesitation Squeezed LCM Increased Pump Pressure to 250 psi and let Pressure Bled Back to 150 psi, Increased Pressure to 250 psi and let bled back to 150 psi Continued Process until Squeezed 40 of 50 bbl LCM Pill into Loss Zone, Soaked Pill for 30 minutes. Opened Well, CBU, At Bottom Up Several Barrels of LCM at Shakers, Circulated 9.8 ppg Brine at 4 bpm w/240 psi at 120 deg going in and 85 deg Coming Out. NO Losses While Circulating Close Annular Preventer, Pressured Up to 250 psi at 3 bpm w/5 bbl Losses. Bled Back to 150 psi in Ten Minutes. Pumped 70 bbl of 80 ppb LCM Pill. Followed by 20 bbl 9.8 brine at 4 bpm w/1 ,250 psi to Clear Drill Pipe. Spot LCM Pill Let It Soak While Clearing Kill Line. Hesitation Squeeze LCM Pill. Pressure Up to 250 psi let it Bled to 150 psi, in Approx 10 minutes. Pressure up to 250 psi, Let Bled Back to 150 psi And Squeeze LCM Pill into Loss Zone. Shut Down Pumping, Blow Down Kill Line CBU at 5 bpm w/290 psi. Pumped 43 bbl LCM Pill Cleared Drill Pipe w/20 bbls 9.8 ppg Brine at 5 bpm w/450 psi. Squeeze LCM at 1/2 bpm Up to 860 psi Let it Bled to 560 psi and Maintained Pressure Between 860 and 560 psi. At Approx 5 minute Intervals. Maximum Squeeze Pressure Achieved 875 psi. BID Kill Line, Circulate in 120 deg 9.8 ppg Brine, RD Surface Lines. POOH POOH Stand Back Collars and Lay Down Cutter Assembly. Pump Stack Out.Pulll Wear Ring. RIU Test Equipment, Set Test Plug. Test BOPE to 250 psi Low Pressure and 4,000 psi High. Pressure for Annular Preventer was 250 psi Low Test and 3,500 psi High. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by John Crisp. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- Annular Preventer Test #2- 4" VBRs Test #3- Blinds, Manual Kill, Floor Valve, Choke Valves 12, 13, 14. Test #4- Lower IBOP, Choke Valves 9, 11. Test #5- ManuallBOP, Choke Valves 5,8, 10. Test #6- HCR Kill, Choke Valves 4,6,7. Test #7- Dart Valve, Choke Valve 2. Test #8- Choke Valves 3, 1. Test #9- HCR Choke. Test #10- Manual Choke Test #11- 4.5" VBRs. Accumulater Test- 3,000 psi Starting Pressure, 1,850 psi After Actuation, First 200 psi in 16 seconds, Full Pressure in 1 Printed: 1/30/2007 11 :43:46 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-15 R-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/27/2006 Rig Release: Rig Number: 16 Spud Date: 2/14/1983 End: 1/15/2007 01 :00 - 06:30 5.50 CLEAN P CLEAN Minute 17 Seconds. 5 Nitrogen Bottles at 2,200 psi. 06:30 - 07:00 0.50 CLEAN P CLEAN Rig Down Test Equipment. 07:00 - 08:30 1.50 CLEAN P CLEAN RlU and Spear 9 5/8" Casing. BOLDs 08:30 - 09:30 1.00 PULL P DECOMP Pull Hanger to Rig Floor, 140,000 Ibs to Free Hanger, 110,000 Ibs String Weight, Lay Down Hanger. Connection Broke out at 45,000 ft-Ibs Torque. 09:30 - 10:00 0.50 PULL P DECOMP Change From Short Bail to Long Bails to Accomodate Reciprocation of 9 5/8" Casing. 10:00 - 10:30 0.50 PULL P DECOMP RlU 95/8" Casing. Install XO and Safety Valve and Circulating Line 10:30 - 12:00 1.50 PULL P DECOMP Establish Circulation, Pump 20 bbl Hi-Vis Sweep. Followed by 20 bbl Safe Surf-O Pill. Inital Circulation Rate at 5.5 bpm w/400 to 450 psi, Take Returns to Flow Back Tank. Total Displacement 323 bbls. Appear to Have Good Arctic Pack Recovery. 12:00 - 12:30 0.50 PULL P DECOMP BID and RID Circulating Lines. 12:30 - 19:30 7.00 PULL P DECOMP UD 9 5/8" CSG, 45 Total Jts, Cut Jt Lenght=27.50'. Clean Cut, Casing in Generally Good Condition. No Corrosion, No Pitting. 19:30 - 20:30 1.00 PULL P DECOMP RID Casing Equipment, Clear and Clean Rig Floor. 20:30 - 21 :00 0.50 CLEAN P CLEAN Change Bails on Top Drive to Accomodate Normal Drilling Operations. 21 :00 - 22:30 1.50 CLEAN P CLEAN M/U BHA, 12 1/8" Shoe, 11 3/4" Wash Pipe, Wash Pipe Boot Basket, Bumper Sub, Jar, 3- 6 1/4" Drill Collars, BHA Lenght=131'. 22:30 - 23:00 0.50 CLEAN P CLEAN RIH with Drill Collars to 115' Started Taking Weight. Continued in to 130' Unable to Go Deeper. 23:00 - 00:00 1.00 CLEAN P CLEAN UD 1 Drill Collar, PIU 1jt Drill Pipe, Circulate out Arctic Pack, Attempt to Work Through Parted or Damaged 133/8" CSG. Rotated, Erratic Torque of 5,000 to 8,000 ft-Ibs. 1/16/2007 00:00 - 01 :00 1.00 CLEAN P CLEAN POOH, Inspect Drag Shoe, Vertical Scaring, Lay Down 133/8" Scraper and Upper Boot Basket. No Recovery in Boot Basket. 01 :00 - 01 :30 0.50 CLEAN P CLEAN RIH With 12 1/8" Shoe and 11 3/4" Wash Pipe to 158' Taking 5,000 Ibs Down Weight, POOH w/5-15,000 Ibs Over, RIH Tagged Up at 130' Unable to Work Past 130'. 01 :30 - 03:00 1 .50 CLEAN P CLEAN POOH wlDrag Tooth, Wash Pipe Assembly and Inspect BHA. 03:00 - 03:30 0.50 CLEAN P CLEAN Clear and Clean Rig Floor. 03:30 - 05:00 1.50 CLEAN P CLEAN UD BHA, Clear Floor of Excess Equipment. Notified Engineer of Parted or Damaged 13 3/8" Casing and Discussed Options. 05:00 - 06:30 1 .50 CLEAN P CLEAN PIU Jars, Bumper Sub, 12.19" and 12.25" String Mill, RIH to 125'. Hit obstruction. Attempt to work through. Unable to get through obstruction. 06:30 - 08:00 1.50 CLEAN N CLEAN POOH with String Mills, UD String Mills. A pull back rubber was inadvertently dropped down the hole. Rubber is 1 1/16" OD and 4' long. Each end has a 1 5/8" knob with a 2" brass eye. 08:00 - 09:00 1.00 CLEAN N CLEAN Pump out BOP Stack, Examine BOP Stack for lost pull back rubber. Pull back rubber was not in BOP Stack. 09:00 - 12:30 3.50 CLEAN N CLEAN M/U 4" Mule Shoe and RIH to 580'. Circulate bottoms up at 12 bpm with 300 psi, in an attempt to circulate out the rubber pull back. RIH to 40' inside the 9 5/8" casing to 1,920' and circulate bottoms up at 12 bpm. Printed: 1/30/2007 11 :43:46 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-15 R-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/27/2006 Rig Release: Rig Number: 16 Spud Date: 2/14/1983 End: 1/16/2007 12:30 - 13:00 0.50 CLEAN P CLEAN POOH from 1,920', UD 4" Mule Shoe. 13:00 - 14:00 1.00 CLEAN P CLEAN Make drift run with 11.75" WP Overshot assembly and RIH to 210'. Work through obstruction at 125" two times. No drag. 14:00 - 14:30 0.50 CLEAN P CLEAN POOH and UD 11.75" Overshot assembly. 14:30 - 15:00 0.50 CLEAN P CLEAN Clear and Clean Rig Floor. 15:00 - 16:00 1.00 CLEAN P CLEAN MIU 6.25" DC's and 9.625" Back Off Assembly. Mule Shoe, XO, 9 x 6.25" DC's, XO, Blanking Sub, Lower Slip Unit, Power Section, Upper Slip Section, XO, Circulating Sub, XO. Total BHA Lenght = 323.79' 16:00 - 18:00 2.00 CLEAN P CLEAN RIH with Back Off Assembly to 2,205'. Fill pipe with water every third stand. Set Back Off Tool at 1,895'. 18:00 - 18:30 0.50 CLEAN P CLEAN Back Off 9.625" Casing Stub. Make 4 complete turns using back off tool. 18:30 - 19:30 1.00 CLEAN P CLEAN Drop opening dart and shear open Circulating Sub with 1,500 psi. Circulate out water, 7 bpm with 290 psi pump pressure. Monitor well. 19:30 - 20:00 0.50 CLEAN P CLEAN POOH with Back Off Assembly. 20:00 - 21 :00 1.00 CLEAN P CLEAN Break down and UD Back Off Tool, Stand back 6.25" DC's. 21 :00 - 21 :30 0.50 CLEAN P CLEAN Clear and Clean Rig Floor. 21 :30 - 22:30 1.00 CLEAN P CLEAN MIU Spear Assembly. 5" Mule Shoe, 9.625" Pack Off Assembly, Spear Assembly with 8.681" Grapple, Spear Extension, Stop Sub with 10.75" Ring, Bumper Sub, Fishing Jars, XO, 9 x 6.25" DC's, XO. Total BHA Lenght = 316.23' 22:30 - 23:00 0.50 CLEAN P CLEAN RIH with Spear Assembly to 1,882' 23:00 - 23:30 0.50 CLEAN P CLEAN Establish parameters. Up weight 85,000#, Down weight 85,000#. Set Spear and back out 9.625" casing stub. Top of 9 5/8" collar to be screwed into is at 1,895' 23:30 - 00:00 0.50 CLEAN P CLEAN Circulate bottoms up at 7 bpm with 290 psi. 1/17/2007 00:00 - 01 :00 1.00 CLEAN N CLEAN Grabber on Top Drive not operational, Break down stand of drill pipe and lower Top Drive to floor. Repair Top Drive Grabber. 01 :00 - 03:00 2.00 CLEAN P CLEAN POOH with spear and 9.625" Casing Stub. 03:00 - 04:30 1.50 CLEAN P CLEAN Stand back 6.25" DC's, Release and UD 13.32' long 9.625 cut joint. Break and UD Spear Assembly. Threads on cut joint looked good with no galling or damage. 04:30 - 07:00 2.50 CASE P TIEB1 RIU 9.625" Casing Handling Equipment. 07:00 - 08:00 1.00 CASE P TIEB1 PJSM with all personnel involved. PIU 9.626" Triple Connect, HES Cementer, and BTC x TC II Crossover, Bakerloc all connections. 08:00 - 13:30 5.50 CASE P TIEB1 Run 9.625", 47#, L-80, TC II Casing to 1,895'. Use Jet Lube Seal Guard on all connections. Torque Turn all connections. Average make up torque 17,500 ftllbs. Fill pipe every 5 joints. Ran 50 joints of casing with centralizers on joints 48 and 49. 13:30 - 18:30 5.00 CASE P TIEB1 Change out elevators and MIU Screw in Assembly, Attempt to screw into 9.625" collar. No indication of making up. UD three joints of 9.625" casing and remove centralizers. One centralizer was missing and second joint of casing had wear marks where centralizer had hung up at 55' while trying to make up triple connect. 18:30 - 20:00 1.50 CASE P TIEB1 Space Out and tag at 1,895'. Change out elevators and MIU Screw in Assembly. Up weight 112,000#, Down weight 117,000#, Screw into 9.625" collar, Work 13,000 ftllbs down hole to connection. Pull test 9.625" casing string to 250,000#. Good test. Printed: 1/30/2007 11 :43:46 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-15 R-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/27/2006 Rig Release: Rig Number: 16 Spud Date: 2/14/1983 End: 1/17/2007 20:00 - 21 :00 1.00 CASE P TIEB1 Break out Screw in Assembly. M/U TC II x BTC XO and HES Cement head. 21 :00 - 22:00 1.00 CASE P TIEB1 Pressure test 9.625" casing to 2,000 psi for 15 minutes, Good test. Pressure up and shear open ES Cementer. Cementer sheared open at 3,000 psi. Good surface indication of shear. 22:00 - 00:00 2.00 CASE P TIEB1 Circulate 20 bbl high vis Safe Surf sweep and pump 100 degree 9.8 ppg brine down hole 75 degrees coming back. 7 bpm at 500 psi. 1/18/2007 00:00 - 01 :00 1.00 CASE P TIEB1 Circulate 100 degree 9.8 brine around till returns were 80 degrees. 7 bpm at 500 psi. Hold PJSM with all personnel involved with cement job. 01 :00 - 03:30 2.50 CEMT P TIEB1 Pump 5 bbls, Pressure test lines to 4,000 psi, pump 30 bbls of 10 ppg mud push followed by 160 bbls of 11 ppg Lite Crete Cement. Initial Circulating Pressure 5 bpm at 400 psi, Final Circulating Pressure 3 bpm at 255 psi. Drop HES Closing Plug and kick out with 5 bbls of water. Displace with 133 bbls of 9.8 brine. Initial Circulating Pressure 6 bpm at 300 psi, Final Circulating Pressure 2 bpm at 350 psi. Bump plug. Close ES Cementer with 1,000 psi. Good surface indication of ES Cementer closing. Hold 1,200 psi for 5 minutes. Bleed off pressure and check for flow. No flow. CIP at 2:50 am. 50 bbls of Cement back to surface. 03:30 - 04:30 1.00 CEMT P TIEB1 Flush BOP stack and annulus valves with two 40 bbl SAPPICitric pills. Center casing in hole. 04:30 - 06:00 1.50 CEMT P TIEB1 Blow down and RID all cement lines, blow down kill and choke lines, pump out BOP stack. Clear rig floor. 06:00 - 18:30 12.50 CEMT P TIEB1 Wait on Cement, Clean pits 3 and 4. Clean rig and perform general rig maintenance. Inspect drawworks. Nipple down BOPE as for as possible in preparation for wellhead work. Remove annulus valves. Install rebuilt adjustable choke in manifold and test. Good test. 18:30 - 23:00 4.50 CEMT P TIEB1 Break and lift BOP Stack, obtain cement sample for Schlumberger. Cement not setting up, compressive strenght still 0 psi on sample at Schlumberger lab. Take measurements to fab up supports for 9.625" casing. 23:00 - 00:00 1.00 WHSUR P TIEB1 Slack off casing, RID HES cement head and RlU to cut 9.625" casing with Wachs cutter. 1/19/2007 00:00 - 01 :30 1.50 WHSUR P TIEB1 Pump out 9.625" landing joint. Cut 9.625" landing joint with Wach's cutter, lay down landing joint. 01 :30 - 02:30 1.00 WHSUR P TIEB1 Pull Riser, NID tubing spool from BOP stack and remove. Set back BOP stack. 02:30 - 04:30 2.00 WHSUR P TIEB1 RlU Wach's cutter and make cut on 13.375" casing and remove McEvoy 13.375" wellhead. 04:30 - 06:30 2.00 WHSUR P TIEB1 RlU Wach's cutter and make final cut on 9.625" casing. Prep 9.625" casing and install FMC 9.625" Slip-Lac casing head assembly. Torque metal to metal seal nuts to 400 ftllbs and test to 1,425 psi, Torque slip segment nuts to 200 ftllbs. Retorque metal to metal seal nuts to 400 ftllbs and retest to 1,425 psi as per FMC procedure. New wellhead height +1- 1" of old wellhead height. 06:30 - 13:30 7.00 WHSUR P TIEB1 Install support brackets and braces for 9.625" to cellar box with Peak Oilfield Services. 13:30 - 16:30 3.00 BOPSU P TIEB1 NIU BOPE, install riser and turnbuckles. Secure cellar area. Printed: 1/30/2007 11:43:46 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-15 R-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/27/2006 Rig Release: Rig Number: 16 Spud Date: 2/14/1983 End: RIU and test connections, wellhead and 9.625" casing to 250 psi low for 5 minutes and 4,000 psi high for 30 minutes. Good test. 19:00 - 19:30 0.50 DRILL P TIEB1 Install wear bushing. 19:30 - 21 :00 1.50 DRILL P TIEB1 M/U Clean out BHA #12. 8.5" bit, 2 x 7" boot baskets, XO, 6.25" bumper sub, 6.25" fishing jar, XO, 9 x 6.25" DC's, XO. Total BHA lenght = 310.20' 21 :00 - 21 :30 0.50 DRILL P TIEB1 RIH with BHA #12 on 4" DP from 310' to 1,840' 21 :30 - 00:00 2.50 DRILL P TIEB1 Establish parameters, Up weight 81 ,000#, Down weight 85,000#, Rotating weight 81,000#. 3,500 ftllbs of torque at 85 rpm, 8 bpm with 320 psi pump pressure. Wash down and tag cement at 1,866'. Drill cement and ES Cementer. 2,000 - 5,000# WOB, 3,000 - 4,000 ftllbs torque at 80 rpm, 8 bpm with 320 psi pump pressure. Initial bottoms up returns contained green cement. 1/20/2007 00:00 - 01 :00 1.00 DRILL P TIEB1 Drill out HES 9.625" Baffle plate. 2,000 - 4,000# WOB. 3,000- 4,000 ftllbs of torque at 80 rpm. 8 bpm with 380 psi pump pressure. 01 :00 - 02:00 1.00 DRILL P TIEB1 RIH to 2,295'. Tag LCM. Attempt to circulate out LCM. Pump screens plugged off. Clean out pump screens and displace well to 100 degree seawater. 02:00 - 03:00 1.00 DRILL P TIEB1 Wash LCM out of hole at 14 bpm with 1,090 psi. Tag sand at 2,439'. Recovered 8" section of rubber pull back tool (fish that was dropped during previous operation). 03:00 - 03:30 0.50 DRILL P TIEB1 Circulate hole clean with 18 bpm with 1,630 psi. 03:30 - 04:30 1.00 DRILL P TIEB1 POOH standing back 4" DP from 2,439' 04:30 - 06:00 1.50 DRILL P TIEB1 Stand back 6.25" DC's, Break 8.5" bit and clean out boot baskets. M/U RCJB BHA #13 run #1 with RCJB. 8.5" RCJB, 2 x Boot Baskets, 9.625" Casing Scraper, XO, Bumper Sub, Fishing Jar, XO, 9 x 6.25" DC's, XO. Total BHA Lenght = 325.19' 06:00 - 08:00 2.00 CLEAN P CLEAN RIH to 2,430' filling pipe every 5 stands so debris from well bore doesn't plug ports in RCJB. 08:00 - 09:00 1.00 CLEAN P CLEAN Establish parameters. Up weight 90,000#, Down weight 95,000#, Rotating weight 95,000#. 2,000 ftllbs of torque at 20 rpm. Drop ball. Wash sand and debris to 2,444' with RCJB. 5.5 bpm at 1,630 psi. 09:00 - 10:00 1.00 CLEAN P CLEAN POOH standing back 4" DP from 2,444'. 10:00 - 11 :30 1.50 CLEAN P CLEAN Stand back 6.25" DC's, empty RCJB and boot baskets. Recovered pieces of the ES Cementer and Baffle Plate, also recovered pieces of brass shear pins and rubber chunks from rubber pull back tool. 11 :30 - 12:00 0.50 CLEAN P CLEAN Rerun BHA #13. RCJB run #2. 12:00 - 13:00 1.00 CLEAN P CLEAN RIH to 2,429' filling pipe every 5 stands so debris from wellbore doesn't plug ports in RCJB. 13:00 - 14:00 1.00 CLEAN P CLEAN Establish parameters. Up weight 90,000#, Down weight 95,000#, Rotating weight 95,000#. 2,000 ftllbs of torque at 25 rpm.Drop ball. Wash sand and debris to 2,456' with RCJB. 5.5 bpm at 1,630 psi. RCJB hanging up, Work RCJB free. 14:00 - 15:00 1.00 CLEAN P CLEAN Circulate 20 bbl high vis sweep around at 5 bpm with 1,370 psi. Sand and some LCM came back with sweep. 15:00 - 16:00 1.00 CLEAN P CLEAN POOH standing back 4" DP from 2,456'. 16:00 - 17:30 1.50 CLEAN P CLEAN Stand back 6.25" DC's, empty RCJB and boot baskets. Printed: 1/30/2007 11 :43:46 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-15 R-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/27/2006 Rig Release: Rig Number: 16 Spud Date: 2/14/1983 End: 1/20/2007 16:00 - 17:30 1.50 CLEAN P CLEAN Recovered pieces of the ES Cementer and Baffle Plate and rubber chunks from rubber pull back tool. 17:30 - 18:00 0.50 CLEAN P CLEAN Pull wear bushing and install test plug. 18:00 - 23:00 5.00 CLEAN P CLEAN RlU BOP test equipment and perform weekly BOPE test. Test choke manifold, annular, pipe rams, blind rams, upper and lower IBOP's, kill and choke line valves, dart valve and full opening floor valve to 250 psi low and 4,000 psi high. Test was witnessed by Chuck Scheve with AOGCC, Doyon Toolpusher and BP WSL. Full opening floor valve failed, valve was replaced and tested. Good test. 23:00 - 00:00 1.00 CLEAN P CLEAN RID BOP test equipment, Blow down lines. 1/21/2007 00:00 - 02:00 2.00 WHSUR N CLEAN Test plug hung up in wellhead, attempt to work test plug free, RlU and flush through annulus valves. Attempt to work test plug loose, 3 inches of free movement. Discuss options with FMC and Well engineer. 02:00 - 03:30 1.50 WHSUR N CLEAN Split BOP stack between tubing spool and casing head. Debris from 9.625" ES Cementer, Baffle Plate and rubber chunks were around test plug. Remove debris and pull test plug. 03:30 - 04:30 1.00 WHSUR N CLEAN FMC wellhead tech cleaned and inspected casing head and tubing spool. No damage or marks in casing head or tubing spool. Install new test plug in casing head. 04:30 - 05:30 1.00 WHSUR N CLEAN N/U tubing spool and BOP stack, Install riser and turn buckles. Secure cellar work area. 05:30 - 06:30 1.00 WHSUR N CLEAN Test connection on wellhead to 250 psi low and 4,000 psi high. Hold each test for 5 minutes. Good test. 06:30 - 07:00 0.50 CLEAN P CLEAN Inspect and service Top Drive and Drawworks. 07:00 - 07:30 0.50 CLEAN P CLEAN Install wear bushing. 07:30 - 08:00 0.50 CLEAN P CLEAN M/U HES 9.625 RBP retrieving tool onto 4" DP. 08:00 - 09:00 1.00 CLEAN P CLEAN RIH with 4" DP to 2,430'. Establish parameters, Up weight 75,000#, Down weight 75,000#. 09:00 - 10:00 1.00 CLEAN P CLEAN Wash down and tag sand at 2,461', wash sand to 2,490'. Pump 20 bbl high-vis sweep around at 10 bpm with 470 psi. Sand returns with sweep. 10:00 - 10:30 0.50 CLEAN P CLEAN Reverse circulate a 20 bbl high-vis sweep around at 10 bpm with 650 psi. Sand returns with sweep. 10:30 - 11 :30 1.00 CLEAN P CLEAN Latch onto HES 9.625" RBP and release plug. Allow RBP pack off rubbers to relax. RID reversing lines, blow down kill line. 11 :30 - 12:30 1.00 CLEAN P CLEAN POOH from 2,490' standing back 4" DP. 12:30 - 13:00 0.50 CLEAN P CLEAN UD HES 9.625" RBP and RBP running tool. Clear rig floor. 13:00 - 13:30 0.50 CLEAN P CLEAN M/U Baker polishing mill for 7" tieback. Polishing Mill, XO, 9 x 6.25" DC's, XO. Total BHA lenght = 290.13' 13:30 - 16:00 2.50 CLEAN P CLEAN RIH with 4" DP to 8,151'. 16:00 - 17:00 1.00 CLEAN P CLEAN Establish parameters, Up weight 170,000#, Down weight 165,000#, Rotating weight 170.000#. 3,000 ftllbs torque at 30 rpm, 3 bpm with 150 psi. Wash down and tag 7" liner top at 8,240'. Polish 7" liner, 30 rpm with 3,000 - 3,500 ftllbs of torque o - 2,000 weight on polishing mill. 17:00 - 18:30 1 .50 CLEAN P CLEAN Pump 20 bbl high-vis sweep around at 12 bpm with 2,120 psi. 18:30 - 21 :00 2.50 CLEAN P CLEAN POOH from 8,240' to 290' standing back 4" DP. 21 :00 - 22:00 1.00 CLEAN P CLEAN UD 6.25" DC's. Break down polishing mill. Good indication on polish mill that liner was dressed. 22:00 - 22:30 0.50 CLEAN P CLEAN Clear rig floor and pull wear bushing. 22:30 - 00:00 1.50 CASE P TIEB2 RlU floor and 7" casing handling equipment. Printed: 1/30/2007 11 :43:46 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-15 R-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/27/2006 Rig Release: Rig Number: 16 Spud Date: 2/14/1983 End: 1/22/2007 00:00 - 05:30 5.50 CASE P TIEB2 PJSM with all personnel involved. Run ported tie back stem and 7",26#, L-80, BTC-M casing. Use Best-O-Life 2000 pipe dope. Make up connections to mark. Average M/U torque 8,800 ftllbs of torque. Run free floating centralizer on each joint. 05:30 - 06:00 0.50 CASE P TIEB2 R/U torque turn equipment. 06:00 - 10:30 4.50 CASE P TIEB2 Run 7", 26#, L-80, Vam Top casing. Torque Turn all Vam Top connections, Average M/U torque 11,950 ftllbs. Used Jet Lube Seal Guard pipe dope. Ran free floating centralizer on each joint. 10:30 - 11 :30 1.00 CASE P TIEB2 Tag up, bottom of seal assembly at 8,245' No/Go at 8,240'. Space out to insure no casing collars across wellhead. Up weight 232,000#, Down weight 225,000#. 11 :30 - 12:30 1.00 CEMT P TIEB2 R/U Schlumberger cement head and lines. 12:30 - 14:00 1.50 CEMT P TIEB2 Pressure up to 500 psi and pick up on casing string to expose ports in seal stem. Mark pipe at No/Go depth and circulating depth. Circulate at 5 bpm with 290 psi. Hold cementing PJSM with all personnel involved. 14:00 - 16:30 2.50 CEMT P TIEB2 Pump 5 bbls of water and test lines to 4,500 psi, divert water to flowline, Pump 83.2 bbls of 15.8 ppg GasBlok Class G cement, Pump 147 bbls of 15.8 ppg Class G cement at 5 bpm with 250 psi. Drop plug and kick out with 5 bbls of water, positive indication of plug leaving head. Line rig pump and displace with seawater at 5.4 bpm. Catch cement at 158 bbls of displacement, 5.4 bpm with 450 psi. Cement to surface with 295 bbls of displacement pumped. Slow to 1 bpm with 3,200 psi. Bump plug with 3,700 psi, 500 psi over displacement rate. CIP @ 16:30 hours. 16:30 - 17:00 0.50 CEMT P TIEB2 Bleed off pressure and slack off to No/Go on casing string. Check floats, floats holding. 17:00 - 17:30 0.50 CEMT P TIEB2 RD cement head and lines. Flush annulus valves. 17:30 - 18:30 1.00 WHSUR P TIEB2 NID BOPE stack between tubing spool and casing head. 18:30 - 19:00 0.50 WHSUR P TIEB2 Install 7" FMC emerency slips in casing head. Set 150,000# in slips. 19:00 - 20:30 1.50 WHSUR P TIEB2 R/U Wach's cutter and cut 7" casing. UD cut joint. 20:30 - 22:30 2.00 WHSUR P TIEB2 Prep 7" stub and install 7" pack off and run in lock down screws. 22:30 - 23:30 1.00 WHSUR P TIEB2 NIU BOP stack and test Pack off and connection to 4,300 psi ( 80% of collapse) for 15 minutes as per FMC procedure. Good test. 23:30 - 00:00 0.50 BOPSU P TIEB2 Install riser and turnbuckles on BOP stack. 1/23/2007 00:00 - 01 :00 1.00 BOPSU P TIEB2 NIU BOP stack after landing emergency slips, Air up riser boots, move secondary annuls vave to tubing spool. Install wear bushing. 01 :00 - 02:00 1.00 CLEAN P CLEAN Break down and UD 6.25" Fishing jars and 6.25" bumper sub from previous run. 02:00 - 02:30 0.50 CLEAN CLEAN Service Top Drive. 02:30 - 03:30 1.00 CLEAN P CLEAN M/U BHA #14, 6.125" Clean out BHA. 6.125" Bit, 2 x Boot Baskets, XO, Bumper Sub, Fishing Jar, XO, 12 x 4.75" DC's. Total BHA lenght = 399.84' 03:30 - 06:30 3.00 CLEAN P CLEAN RIH with 4" DP from 399' to 8,160'. Establish parameters, Up weight 168,000#, Down weight 155,000#, Rotating weight 162,000#. 4,000 ftllbs of torque at 80 rpm. 6 bpm with 830 psi. Printed: 1/30/2007 11 :43:46 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-15 R-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/27/2006 Rig Release: Rig Number: 16 Spud Date: 2/14/1983 End: 1/23/2007 06:30 - 08:30 2.00 CLEAN P CLEAN Tag cement at 8,186'. Drill out cement with 80 rpm with 4,000 - 4,500 ftIlbs of torque, 1,000 -5,000# WOB and 6 bpm with 830 psi. Drilled through plug and float collar at 8,229' 08:30 - 09:30 1.00 CLEAN P CLEAN Pump around a 20 bbl SAPP pill followed by 20 bbl high - vis sweep. 14 bpm at 3,650 psi. Cement cuttings and some rubber with sweep. 09:30 - 10:30 1.00 CLEAN P CLEAN Wash to 8,296',10' of sand, pump 20 bbl high - vis sweep around at 14 bpm with 3,650 psi. Sweep brought up sand retu rns. 10:30 - 11 :30 1.00 CLEAN P CLEAN POOH to 8,163', R/U and test 7" casing to 4,000 psi for 30 minutes on chart. Good test. 11 :30 - 14:00 2.50 CLEAN P CLEAN POOH standing back 4" DP. 14:00 - 14:30 0.50 CLEAN P CLEAN Break off 6.125" bit, Break and clean out boot baskets, recovered 1 gallon of cement cuttings and sand. 14:30 - 15:30 1.00 CLEAN P CLEAN M/U BHA #15, RCJB assembly. 6.125" RCJB, XO, 2 x Boot Basket, 7" Casing Scraper, XO, Bumper Sub, Fishing Jar, XO, 12 x DC's. Total BHA lenght = 412.09' 15:30 - 19:30 4.00 CLEAN P CLEAN RIH with 4" DP from 412' to 8,272' filling pipe every 20 stands to insure ports on RCJB don't plug. 19:30 - 21 :00 1.50 CLEAN P CLEAN Establish parameters, Up weight 174,000#, Down weight 152,000#, Rotating weight 165,000#. 4,000 ftIlbs of torque at 20 rpm. Drop ball, wash to 8,312' working RCJB, Pump 20 bbl high - vis sweep while working RCJB. 5 bpm with 960 psi. 21 :00 - 23:30 2.50 CLEAN P CLEAN POOH standing back 4" DP. 23:30 - 00:00 0.50 CLEAN P CLEAN Stand back 4.75" DC's 1/24/2007 00:00 - 01 :00 1.00 CLEAN P CLEAN UD 6.125" RCJB, clean out boot baskets, recovered several small pieces of pot metal. No recovery in RCJB. 01 :00 - 03:30 2.50 CLEAN P CLEAN M/U HES RBP retrieval tool and RIH with 4" DP to 8,275'. 03:30 - 05:00 1.50 CLEAN P CLEAN Establish parameters, Up weight 158,000#, Down weight 145,000#. Pump 20 bbl high - vis sweep and wash sand from 8,312' off top of HES RBP. Latch RBP at 8,336' and release. Slack off below setting depth to insure RBP latched and released. 05:00 - 05:30 0.50 CLEAN P CLEAN Circulate bottoms up at 10 bpm with 1,720 psi. 05:30 - 09:00 3.50 CLEAN P CLEAN POOH standing back 4" DP. 09:00 - 09:30 0.50 CLEAN P CLEAN UD 7" HES RBP and RBP retrieval tool. Packer element had a small 1 " chunk missing. 09:30 - 12:00 2.50 CLEAN P CLEAN M/U BHA #16,3.625" RCJB Assembly. 3.625" RCJB, XO, 4 x 2.875" PAC DP, XO, XO, 2 x Boot Baskets, XO, Bumper Sub, Fishing Jars, XO, 12 x DC's. Total BHA lenght = 535.64' 12:00 - 15:00 3.00 CLEAN P CLEAN RIH with 4" DP to 8,779', fill pipe every 20 stands to keep RCJB ports from plugging. 15:00 - 16:30 1 .50 CLEAN P CLEAN Establish parameters, Up weight 174,000#, Down weight 158,000#, Rotating weight 170,000#, 4,000 ftIlbs torque at 20 rpm, 2.5 bpm with 300 psi. Tag top of tubing stub at 8,815', drop ball and wash to top of junk catcher at 8,884'. 16:30 - 18:30 2.00 CLEAN P CLEAN Pump around a 20 bbl high - vis sweep, 8.5 bpm with 2,270 psi. Pull out of 4.5" tubing stub at 8,815'. Wait 10 minutes and work RCJB back to top of junk catcher at 8,884'. 18:30 - 21 :30 3.00 CLEAN P CLEAN POOH standing back 4" DP. 21 :30 - 23:30 2.00 CLEAN P CLEAN Break and UD 3.625" RCJB assembly.Clean out boot baskets and RCJB. Recovered 1/2 gallon of parafin and one small 1 " Printed: 1/30/2007 11 :43:46 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-15 R-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/27/2006 Rig Release: Rig Number: 16 Spud Date: 2/14/1983 End: 1/24/2007 21 :30 - 23:30 2.00 CLEAN P CLEAN chunk of rubber. 23:30 - 00:00 0.50 CLEAN P CLEAN M/U BHA #17, GS spear assembly. 1/25/2007 00:00 - 00:30 0.50 CLEAN P CLEAN Continue M/U BHA #17, GS spear assembly. GS Spear, XO, Circulating Sub, 4 x 2.875" PAC DP, XO, XO, 2 x Boot Baskets, XO, Bumper Sub, Fishing Jars, XO, 12 x DC's Total BHA lenght = 532.50' 00:30 - 04:00 3.50 CLEAN P CLEAN RIH with 4" DP to 8,807' 04:00 - 05:00 1.00 CLEAN P CLEAN Slip and Cut 110' of Drilling Line. Inspect Drawworks. 05:00 - 06:00 1.00 CLEAN P CLEAN Establish Parameters, Up weight 174,000#, Down weight 160,000#. Wash down to 8,882' at 3 bpm and 1,050 psi. Shut off pump and set down 5,000# on Junk Catcher. Latch onto Junk Catcher with GS spear. 06:00 - 12:00 6.00 CLEAN P CLEAN POOH standing back 4" DP to 532'. 12:00 - 13:00 1.00 CLEAN P CLEAN Stand back 4.75" DC's, UD 2.875" PAC DP, UD Junk Catcher, 1 quart of parafin and several small pieces of rubber were in junk catcher. 13:00 - 14:00 1.00 CLEAN P CLEAN M/U GS spear assembly and re-run BHA #17 to retrieve XXN plug at 8,892' 14:00 - 17:30 3.50 CLEAN P CLEAN RIH with 4" DP to 8,807' 17:30 - 19:00 1.50 CLEAN P CLEAN Establish Parameters, Up weight 174,000#, Down weight 160,000#. Wash down to 8,892' at 2.5 bpm and 730 psi. Shut off pump and set down 5,000# on XXN plug. Latch onto XXN plug with GS spear. Work several times. Was able to slack off to 8,898', 6' below XXN plug setting depth. Hole taking fluid. Drop ball and open pump out sub. Pull out of 4.5" tubing stub. Get static loss rate of 60 bph. Monitor well. Static loss rate of 45 bph. 19:00 - 00:00 5.00 CLEAN P CLEAN POOH laying down 4" DP to 4,326'. Loss rate down to 5 bph. 1/26/2007 00:00 - 02:30 2.50 CLEAN P CLEAN POOH laying down 4" DP from 4,326' to 532' 02:30 - 04:30 2.00 CLEAN P CLEAN UD BHA #17, GS spear assembly and XXN plug. 04:30 - 05:00 0.50 RUNCO RUNCMP Pull wear bushing. 05:00 - 06:00 1.00 RUNCO RUNCMP RIU to run 4.5",12.6#, L-80, TC II, tubing. 06:00 - 19:30 13.50 RUNCO RUNCMP PJSM with all personnel involved. Run 4.5",12.6#, L-80, TC II tubing. Torque Turn all connectons. Used Jet Lube Seal Guard pipe dope. Average M/U torque 3,850 ftIlbs. Run tubing to 8,791'. Up weight 135,000#, Down weight 130,000# 19:30 - 22:00 2.50 RUNCO RUNCMP M/U circulating equipment, tag top of 4.5" tubing stub at 8,820', Wash over stub 3 bpm with 180 psi, shear pins sheared out at 6,000# down weight. No/Go out at 8,828', pressured up from 180 psi to 420 psi. Shut pump down, PIU to neutral weight plus 2'. Take measuement and space out to land at 8,825', PIU space out pup, tubing hanger and landing joint. 22:00 - 00:00 2.00 RUNCO RUNCMP Clear and clean rig floor while waiting on vac trucks. All trucks busy. 1/27/2007 00:00 - 00:30 0.50 RUNCO RUNCMP Wait on Seawater trucks. 00:30 - 04:00 3.50 RUNCO RUNCMP Reverse in 200 bbls of 140 degree seawater and 160 bbls of corrosion inhibited seawater at 3 bpm with 200 psi. Follow with 75 bbls of diesel freeze protect pumped with Little Red Services. 04:00 - 05:30 1.50 RUNCO RUNCMP U-tube freeze protect from annulus to tubing. 05:30 - 06:00 0.50 RUNCO RUNCMP Land tubing hanger and run in lock down screws. 06:00 - 07:30 1.50 RUNCO RUNCMP Pressure Up to 4000 psi on Tbg and Pressure Test for 30 mins. Bleed down pressure on Tbg to 1500 psi and pressure Printed: 1/30/2007 11 :43:46 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-15 R-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 12/27/2006 Rig Release: Rig Number: 16 Spud Date: 2/14/1983 End: 07:30 - 08:30 1.00 RUNCMP up IA to 4000 psi. Hold Pressure for 30 mins. Both pressure test good. Bleed down pressure. ¡I Set TWC wI FMC and Pressure Test from above to 3500 psi for 10 mins. Good test. PJSM; N/D BOP's and 13-5/8" x 11" Spacer Spool. N/U Adapter and test to 5000 psi for 30 mins. N/U Tree and test to 5,000 psi for30 mins. RIU DSM lubricator and pull TWC, Install BPV. Remove secondary annulus valve and secure well and cellar. 08:30 - 10:30 10:30 - 12:00 12:00 - 14:00 14:00 - 16:30 2.00 1.50 WHSUR P 2.00 WHSUR P 2.50 WHSUR P RUNCMP RUNCMP RUNCMP RUNCMP Printed: 1/30/2007 11 :43:46 AM pI DRAFT TREE = 4-1/16" CAMERON WELLHEA D = 11" FMC ACTUA TOR = ? KB. ELEV = 48.6' BF.ELEV= 21.81' KOP = 4496' Max Angle = 107 @ 9673' Datum MD = DatumTVD= 9-5/8" CSG, 47#, L-80, TC-II, 8800' SS ID= 8.861" 113-3/8" CSG, 72#, L-80, ID = 12.347" I 7" LNR. 26#, L-80, VAMTOP, .0383 bpf, ID = 6.276" 19-5/8" CSG. 47#, L-80, ID = 8.681" I Minimum ID = 3.725" @ 8897' 4-1/2" HES XN NIPPLE I BRK TIEBACK SEAL ASSEMBLY, ID = 6.200" 1 7" LNR. 26#, L-80, BTC-M, .0383 bpf, ID = 6.276" 14-1/2" TBG STUB (01110107) I 4-1/2" TBG, 12.6#, L-80, TC-II, .0152 bpf, ID = 3.958" TOPOF 4-1/2" LNR I 14-1/2" TBG, 12.6#, L-80. .0152 bpf. ID = 3.958" I R-15A SAFETY NOTES: PARENTWELLBORE(PRE- R-15A) NOT saN BELOW MILLOUT WINDOW @ 8402'. ***WE.o@9314'*** 1895' ÆRFORA TION SUMMARY REF LOG: ANGLEATTOPÆRF: 96 @ 11498' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4-1/2" SL TO 11498 - 11541 0 05/16/99 6" OH 11541 - 11986 0 05/11/99 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 14-112" LNR. 12.6#, L-80, .0152 bpf, ID = 3.953" 1885' H HES ES CEMENTER I 2129' -i4-1/2" HES X NIP, ID = 3.813" 2621' -19-5/8" DV PKR 8679' 8710' 8743' 8825' 8842' 8853' 8876' MILLOUT WINDOW (R-15A) 8402' - 8417' 9-5/8" X 7" BKR ZXP PKR w I FLEX-LOC LNR HGR, ID = 6.250" -I4-1/2" HES X NIP, ID = 3.813" 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" -4-1/2" HES X NIP, ID = 3.813" I -17" X 4-1/2" UNIQUE OVERSHOT I -4-1/2" HES X NIP, ID = 3.813" -17" X 4-1/2" BKR SB-3 PKR, ID = 3.875" I -4-1/2"HESXNIP,ID=3.813" I 8897' - 4-112" HES XN NIP, ID = 3.725" I 8902' -17" X 5" BKR ZXP L TP w I HMC HGR, ID = 4.405" 8909' '14-1/2" WLEG, ID = 3.958" I 14-1/2" SL TD LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" DATE REV BY COMMENTS DATE REV BY COMMENTS 02/28/83 ORIGINAL COM PLETION 05/16/99 SIDETRACK (R-15A) 01/30/07 D16 RWO 02/13/04 ?/ PJC DRLG DRAFT CORRECTIONS - - - - - - - - ITOD (OÆN HOLE) I PRUDHOE BAY UNrr WELL: R-15A ÆRMrr No: "1990360 API No: 50-029-20917-01 SEC 32, T12N, R13E BP Exploration (Alaska) 02/12/2007 Schlumberge.r NO. 4131 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth UIC- /C1~-03G Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Lo!! Description Date BL Color CD L5-25 11538589 LDL 12/28/06 1 Y-16 11626467 LDL 01/19/07 1 L-04 11603118 MEM LDL 12/30/06 1 11-24A 11638611 USIT 01/24/07 1 1·33 11631645 USIT 01/09/07 1 A-05A 11533393 USIT 01/04/07 1 DS 05-10B 11626469 SCMT 01/22/07 1 W-29 11536193 USIT 01/05/07 1 R-15A 11626266 USIT (CEMENT EVALUATION) 01/11/07 1 R-15A 11626266 USIT (CORROSION) 01/11/07 1 MPF-99 11637306 CEMENT EVALUATION/CBL 01/14/07 1 R-12 11414757 RST 09/01/06 1 1 NK-38A 40011271 OH EDIT MWD/LWD 03/11/05 3 1 NK-38A PB1 40011271 OH EDIT MWD/LWD 02/26/05 2 1 MPC-28A 11649937 MEM INJECTION PROFILE 01/05/07 1 DS 07 -04A 11533394 LDL 01/05/07 1 F-23A 11626066 LDL 01/08/07 1 P2-19 11630449 LDL 01/14/07 1 Y -09A 11630450 LDL 01/16/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 SCANNED FEB 2 1 2007 CEI\/E Alaska Data & Cons 2525 Gambell Street, Anchorage, AK 99503-2838 ATTN: Beth rEB 2 0 Z007 Date Delivered: Received by: 1\!Æ!k~ Oil & Gæ Cons. Commi~sioo Anr.horage JCJ . . . . FRANK H. MURKOWSKI, GOVERNOR ALASIiA OIL AND GAS CONSERVATION COmnSSION 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, Well Name R-15A Sundry Number: 306-364 Dear Mr. Reem: (¡ , Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thiSday of November, 2006 Enc!. IQQ-03(... · úff ~;;~~O~F ALASKA flt,:,->- -,;rðr- (Hl{VPD 11{\.0 "'JJbJ·)J~ ALASKA OIL AND GAS CONSERVATION COM~ON ~ ow - r" V APPLICATION FOR SUNDRY APPROV AL< 20 AAC 25.280 o Perforate o Stimulate o Waiver 1. Type of Request: 0 Abandon o Alter Casing o Change Approved Program o Suspend 181 Repair Well 181 Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Time Extension o Re-Enter Suspended Well o Other 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? 0 Yes ~ No 9. Property Designation: 10. KB Elevation (ft): ADL 028279 48.96' 4. Current Well Class: / o Development 0 Exploratory o Stratigraphic 181 Service 5. Permit To ~iII Number 199-036 6. API Number: . 50-029-20917-01-00 /' 8. Well Name and Number: W6Jt- PBU R-fS- ! - t S' A- 11. Field / Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Plugs (measured): None Bur t Junk (measured): None Colla s 11 ' 2673' 4930 2670 8094' 6870 4760 806' 7" 8240' - 046' 7941' - 8683' 7240 5410 Liner 2 3 ' 4-112" 8902' - 11541' 8552' - 8824' 8430 7 00 Perforation Depth MD (ft): Perforation Depth TVD (ft): 11498' - 11986' 8828' - 8813' Packers and SSSV Type: 7" x 4-1/2" Baker 'SB-3' packer Tubing Size: 4-1/2",12.6# Tubing Grade: L-80 Packers and SSSV MD (ft): 8853' Tubing MD (ft): 8909' 13. Attachments: ~ Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 15. Estimated Date for Commencin 0 erations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Nam vid Reem Title Drilling Engineer 14. Well Class after proposed work: / o Exploratory 0 Development 181 Service December 15, 2006 Date: 16. Well Status after proposed work: o Oil 0 Gas 181 WAG 0 GINJ o Plugged OWINJ o Abandoned o WDSPL Contact Taylor Wellman, 564-5620 Signature Phone 564-5743 Date It 7 Db Prepared By Name/Number: Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test 0 Mechanical Integrity Test 0 Location Clearance Other: T.ec...t gorE to 4000 ft.../, pL(Ir , L{ ~ f- to 'to PrÆ (. '2 ') . 0 ~:;- ( 0.) l ¡} ) Sundry Number: 3/)(p_ Subsequent Form Required: L 0 - 4- 0 4 rMn~.J~:~ EO PIE- / ~ '1)frOl/6J. O....F·1. De it f 5 2006 APPROVED BY THE COMMISSION Date INAL Submit In Duplicate ........., '".,..,c"_""'_. ",,_"~'____,~''''''_''''-''''''._._'''' ~ . . -.-...............- ".-._"_.._<'. -- R-15A Rig Workover Scope of Work: Pull 4-1/2" completion, cut and pull 9-5/8" casing above the surface casing shoe, run premium threaded 9-5/8" tieback and cement 9-5/8" x 13-3/8" annulus to surface, run 7" tie-back to surface (premium threaded from 3300' to surface) and cement 7" x 9-5/8" annulus to 2800', run 4-W' premium threaded completion. / // MASP: 2250 psi Well Type: Injector Estimated Start Date: December 15, 2006 Pre-Ri F 1 S 2 F 3 E 3 o 4 o 5 o 6 kr 5/10/99 Tb tall Level the ad as needed for the ri Install flow line and re-set well house & retrieve SPV. Retrieve ball & rod /Install MXC Fla er Valve / Pull RHC bod ProDosed Procedure: 1. MIRU Work Over Rig. Pull SPV, set and test TWC in tubing hanger. ND tree and adapter flan~. NU SOPE. Test SOPE per SP and AOGCC regulations to 250 psi (low)/4000 psi (high). ,;' 2. Circulate out freeze protection fluid to clean seawater. 3. Pull 4-1/2" tubing down to the cut @ -8812' MD. 4. Run 9-5/8" )J81l) to locate top of cement in 9-5/8" x 13-3/8" annulus. 5. Set 9-5/8" ~3600' MD and pressure test to 2000 psi for 15 min. 6. Cut and pull the 9-5/8" casing. Note: Pipe rams will not be changed to 9-5/8" as the well has / two tested barriers (XXN plug and RBP) to the reservoir. 7. RIH with new 9-5/8" premium thread casing and fully cement to surface. 8. Drain and ND SOP and remove the casing spool. 9. Cut the 13 3/8" at the surface below the slips. 10. Replace existing wellhead equipment with FMC Gen. 5 wellhead configuration. NOTE: New wellhead configuration uses the 4-1/2" tubing, 7" tieback liner, and the 9-5/8" casing as pressure containing barriers. Under the new configuration the IA will be the 4-1/2" / x 7" annulus and the OA will be the 7" x 9-5/8" annulus. The 13-3/8" casing will be fully ~"~.':'¢'~:i.· . . \..,;. cemented in place but will not be attached to the wellhead and will not be considered a /' pressure containing barrier. 11. NU and test BOPs, as per step #1. 12. Test casing to 3000 psi f/30-min. 13. Run 7" tie-back liner from -8240' MD to surface. Cement liner to 2800' MD. 14. PT liner/casing to 4000 psi for 30 charted minutes. 15. Run new 4.5" premium threaded completion. Set and test 4-1/2" x 7" stacker packer to 4000 psi / (tubing and inner annulus). 16. RDMO. 17. Weld base plate on 30" x 20" x 13 3/8" stubs after top jobs on all exposed annuli. TREE '= 4-1/16" CAMERON r I W8..LHEAD = 13-5/.8" MCEVOY R-15A SAÆTY NOTES: 70° @ 9330' & 90° @ 9451' ACTUATOR = ? KB. ELEV = 48.6' BF. ELEV = 21.81' KOP= 4496' I 2215' -f4-112"HESXNIP,D=3.813" I Max Angle = 107 @ 9673' Datum MD = 9633' Datum TVD = 8800' SS = 1= --I 2621' 1-19-518" rN PKR I 113-3/8" CSG, 72#, L-80, 10 = 12.347" I W ~ GAS LFT MANDRELS 2673' ST MD TVD DEV TYPE VLV LATCH PORT DATE TOPOF7" LNR I 8240' ~ IðI 8240' 9-5/8" X 7" BKR ZXP PKRlFlEX LOC LNR HGR I Minimum ID = 3.725" @ 8897' MILLOUT WINOOW 8402' - 8417' 4·1/2" HES XN NIPPLE · 8842' 1--14-112" HES X NIP, 10 = 3.813" I ~ ~ I 8853' /-17" X4-1/2" BKR 5B-3 PROD PKR, 10 = 3.875" I · . 8876' 1-j4-112" HES X NIP, 10= 3.813" I TOPOF 4-1/2" LNR I 8902' · 8897' 4-112" HES XN NIP, ID = 3.725" I 14-112" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 8908' r-- L 8902' /-17" X 5" BKR ZXP PKRlHMC HGR I ~ 8908' /-14-1/2" VVLEG, ID = 3.958" I PERFORA TON SlJtJMARY I 8925' H ELMD TT LOGGED 06/14199 I REF LOG: A NGLE AT TOP PERF: 96 @ 11498' Note: Refer to Production DB for historical perf data SIZE 5PF INTERVAL OpnlSqz DATE 4-1/2" 11498 - 11539 SLID 05/16199 6" 11541 - 11986 OH 05111199 19-5/8" CSG, 47#, L-80, 10 = 8.681" I 8402' 11986' I ID (OPEN HOLE) PLUGBACK .. .. .. .. I TOP OF CEMENT I 881T .. ...- .. '\ .. .. .. I 7" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" 9044' r .. .. 14-112" LNR, 12.6#, L-80, .0152 bpf,lD= 3.953" H 11498' I I TOP OF 4-112" SLID LNR 11498' I ~ 14-112" SLIDLNR, 12.6#, L-80, .0152 bpf, Ð= 3.953" H 11541' I lIDO (OPEN HOLE) I tttI8' DATE REV BY COWMENTS DATE REV BY COM\1ENTS PRUDHOE BAY UNIT 02128/83 ORIGINAL COMPLETION WElL: R-15A 05116/99 SIDETRACK (R-15A) PERMIT No: 1990360 03/28102 RtIVTP CORRECTIONS API No: 50-029-20917-01 03/24/04 KNCITlH OPSII HOLE CORRECTK)N SEC 32, T12N, R13E 04/30104 PJPlKAK CORRECTK)NS BP exploration (Alaska) . . - TREE,,: 4-1/16" CAMERON WB.LHEAD= 13-!il8" MCEVOY R-1 SA ProposeCl ACTUA TOR = ? KB. B.EV = 48.6' BF. aEV = 21.81' KOP= 4496' I · 2100' -f4-112" HES X NIP, Ð= 3.813" I Max Angle = 107 @ 9673' Datum MD = 9633' DatumlVD= 8800' S5 .......¡ 2621' -f 9-518" rN PKR I 113-3/8" CSG. 72#, L-80, Ð= 12.347" I 2673' µ/ ~ I SAÆTYNOTES: 70° @ 9330' & 90° @ 9451' I TOPOFCMT I 2800' I I 7" CSG, 26#, L-80 TC2, .0383 bpf, ID = 6.276" I 3300' Minimum ID = 3.725" @ 8897' 4-1/2" HES XN NIPPLE TOPOF7" LNR I 8240' I 8240' 9-5/8" X 7" BKR ZXP PKRlFLEX LOC LNR HGR ~. Iii::: 1111 H4-112" HES X NIP, Ð- 3.813" I 111 H7" X 4-1/2" BKR SB-3 PROD PKR, ID = 3.875" I 14-1/2" TBG, 12.6#, L-BO TC2, .0152 bpf, ID = 3.958" · · 11 Ji4-112" HES X NIP, Ð= 3.813" I I 111 I · I~ 8842' H4-1/2" HES X NIP, Ð = 3.813" I 8853' 1-\7" X 4-1/2" BKR SB-3 PROD PKR, ID = 3.875" I · · 8876' 1-14-1/2" HES X NIP, Ð = 3.813" 1 I · · 8897' 1'14-1/2" HES XN NIP, ID = 3.725" I .- ITOP OF 4-1/2" LNR I 8902' I I 14-1/2" TBG, 12.6#, L-80. .0152 bpf,lD= 3.958" 1 8908' J H 7" X 5" BKR ZXP PKRIHMC HGR I L. 8902' PERFORA TION SlMJIARY r----.¡ 8908' 1-14-1/2" WLEG, Ð = 3.958" REF LOG: I 8925' H aMD TT LOGGED 06/14/99 I ANGLE AT TOP PERF: 96@ 11498' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE MUOUT ININOOW 4-112" 11498 -11539 SLTD 05116/99 8402' - 8417' 6" 11541 - 11986 OH 05/11199 I 11986' I TD (OPEN HOLE) PLUGBACK 19-518" CSG, 47#, L-80, ID = 8.681" I 8402' I , , , I TOP OF CEMENT 8817' I , , -\ , , , , , I 7" LNR. 26#, L-80, .0383 bpf, Ð = 6.276" 9044' r '\' 14-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" H 11498' I TOPOF'-II2"SLTDLNR 11498' ~ 14-112" 5L TD LNR, 12.6#, L-80, .0152 bpf, Ð = 3.953" 1- 11541' r I TOO (OPEN HOLE) DATE REV BY COWAENT5 DATE REV BY COM\I3IITS PRUDHOE BAY UNIT 02128183 ORIGINAL COMPLETION WB.L: R-15A 05116199 SIDETRACK (R-15A) PERMfT No: 1990360 03/28/02 RNITP CORRECTIONS API No: 50-029-20917-01 03/24104 KNClTLH OPEN HOLE CORRECTION see 32, T12N, R13E 04130/04 PJPlKAK CORRECTK>NS BP Exploration (Alaska) . . TRæ= 4-1/16" CAMERON WB.LHEAD= 13-518" MCEVOY ACTUA TOR = ? KB. aEV = 48.6' BF. aEV = 21.81' KOP= 4496' Max Angle = 107 @ 9673' Datum MD = 9633' Datum lVD = 8800' SS Wellhead R-15A 13-3/8" Csg 14-112" TBG, 12.6#, L-BO TC2, .0152 bpf, ID = 3.958" I 111 TOPOF 4-1/2" LNR I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" PERFORA TION Sut..lMRY REF LOG: A NGLE AT TOP PERF: 96 @ 11498' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 11498 -11539 SL10 05/16/99 6" 11541-11986 OH 05/11/99 19-518" CSG, 47', L-80, 10 = 8.681" I TOP OF CEMENT Proposld / 2100' 4-1n" HES X NIP, 10= 3.813" SAFETY NOTES: 70° @ 9330' & 90° @ 9451' Minimum ID = 3.725" @ 8897' 4·112" HES XN NIPPLE 8240' 9-5/8" X 7" BKR ZXP PKRlFLEX LOC LNR HGR 1111 111 11 .,4-1n" HES X NIP, 10 = 3.813" I "7" X 4-1/2" BKRSB-3 PRODPKR, Ð= 3.875" .,4-1n" HES X NIP, 10 = 3.813" I 8842' 8853' 8876' 8897' 4-1n" HES X NIP, 10 = 3.813" 7" X 4-1/2" BKR SB-3 PROD PKR, 10 = 3.875" ,,4-1/2" HES X NIP, ID = 3.813" I ,,4-1/2" HES XN NIP, 10 = 3.725" I 8902' -17" X 5" BKR ZXP PKRlHMC HGR ,,4-1/2" WLEG, 10= 3.958" I H aMD TT LOGGED 06/14199 I MUOUT WINDOW 8402' - 8417' I 10 (OPEN HOLE) PLUGBACK 7" LNR, 26#, L-80, .0383 bpf, II) = 6.276" DATE 02128/83 05118199 03/28/02 03n4/04 04130104 REV BY COt.tM:NTS ORIGINAL COMPLETION SIDETRACK R-15A) RNITP CORRECTIONS KNClTLH OPEN HOLE CORRECTION PJPlKAK CORRECTIONS DATE REV BY PRUDHOE BA Y UNIT WB.L: R-15A PERMIT No: 1990360 API No: 50-029-20917-01 SEe 32, T12N, R13E COM'ÆNTS BP exploration (Alaska) MEM ORAND UM State of Alaska Alaska Oil and Gas Conservation Commission TO: ~~ S~:;;isor ~~q 7('lI{!CW FROM: Jeff Jones Petroleum Inspector DATE: Wednesday, July 28, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORA TJON (ALASKA) INC R-15A PRUDHOE BAY UNIT R-15A Src: Inspector Reviewed By: P.I. Suprv 51?#-- Comm NON-CONFIDENTIAL Well Name: PRUDHOEBAYUNlTR-lSA API Well Number: 50-029-20917-01-00 Inspector Name: Jeff Jones Insp Num: mitJJ0407281041 05 Permit Number: 199-036-0 Inspection Date: 7123/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well R-I5A Type Inj. S TVD 8813 IA 950 2500 2320 2210 P.T. 1990360 TypeTest SPT Test psi 2126.75 OA 10 10 10 10 Interval OTHER P/F F Tubing 860 840 840 840 Notes: MITIA to evaluate high IA pressure. MITIA failed; pressure loss exceeded 10% of test pressure. 3.5 BBLS 50/50 methanol pumped. I well house inspected; no exceptions noted. ' vJ ill- 'S Iw:h ~ ' / 5(:e. ~chd Wednesday, July 28, 2004 Page I of I R:-15A (PTD #1990360) Confmned TxIA Comm Hello Jim & Winton. Well R-15 (PTD #1990360) failed an MITIA and has been SI. The IA pressure was noted to increase at the end of the pit dewatering usage. An AOGCC witnessed MITIA on 7/23/04 failed, loosing 180/110 psi in 15/30 minutes. We repeated the MITIA on 7/26/03 and established a LLR of .3 BPM @ 3000 psi. The well currently has a sundry for a surface casing leak. Current plans are for the well to remain SI and evaluate for a RWO. A 10-404 will be suþmitted to cancel Sundry #304-242 for the surface casing leak. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, x1154 Email: NSUADWWellIntegrityEngineer@bp.com -----Original Message~---- From: NSU, ADW Well Integrity Engineer Sent: Saturday, July 17, 2004 6:53 PM To: 'AOGCC - Winton Aubert (E-mail)' Cc: NSU, ADW Well Integrity Engineer¡ GPB, Wells Opt Eng¡ GPB, Optimization Engr¡ Reeves, Donald F Subject: R-15A (PTD 1990360) Possible TxIA Comm Winton, R-15A appears to have TxIA communication. Current WHPs are 750/750/0. was recently sundried for a SC leak. Our plan forward is to: 1. Shut-in injection 2. DHD: MITIA 3. WIE: Eval for possible TxIA comm This well The AOGCC inspector will be notified prior to conducting the MITIA. I've included a wellbore schematic for reference. Please let me know if you have Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 any questions. 1 of 1 7/29/2004 1 :08 PM July 27, 2004 0..'.'" bp i' ..;, .... ,.,. ','" .i . < .~" ¡Q1-o3b BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage. Alaska 99519-6612 Mr. Winton Aubert, P. E. Alaska Oil & Gas Conservation Commission 333 W. ¡th Ave. Anchorage, Alaska 99501 Subject: R-15A (PTD 1990360) Application for Cancellation of Sundry #304-242 Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 304-242 for well R-15A (PTD 1990360). The well failed an MITIA and has been SI. If you require any additional information or clarification, please contact Anna Dube or Joe Anders at (907) 659-5102. Sincerely, 'oe C~ ..oe Anders, P.E. Well Integrity Coordinator Attachments Application for Sundry Cancellation form 10-404 ~ 'I .. _1,,-- . . I Ii) :! ORIGINAL 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 2. Operator STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair WellD Plug PerforationsD Pull Tubing 0 Perforate New POOIO Operation Shutdown 0 Perforate 0 4. Current Well Class: Stimulate D OtherŒ) WaiverD Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: 199-0360 Cancel Sundry Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 48.96 8. Property Designation: ADL-028279 11. Present Well Condition Summary: Total Depth Development 0 StratigraphicO 9. Well Name and Number: R-15A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD ServiceŒ] 6. API Number 50-029-20917 -01-00 measured 11986 feet Plugs (measured) None Effective Depth true vertical 8812.7 feet Junk (measured) None measured 11986 feet true vertical 8812.7 feet Casing Conductor Liner Liner Production Surface Length 80 806 2639 8377 2643 Perforation depth: Measured depth: 11498 -11539 Size 20" 91.5# H-40 7" 26# L-80 4-1/2" 12.6# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 MD TVD Burst Collapse 27 107 27.0 107.0 1490 470 8240 - 9046 7940.5 - 8682.7 7240 5410 8902 - 11541 8551.7 - 8824.2 8430 7500 25 - 8402 25.0 - 8093.7 6870 4760 26 - 2669 26.0 - 2669.0 4930 2670 True vertical depth: 8828.3 - 8824.39 8909 Tubing ( size. grade, and measured depth): 4-1/2" 12.6# L-80 @ 25 ... ; i ~ ..;, Packers & SSSV (type & measured depth): 4-1/2" Baker SB3 Packer 5" Baker ZXP Liner Top Packer 7" Baker ZXP Packer @ @ @ 8853 8902 8240 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Daily Report of Well Operations - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Anders/Anna Dube Printed Name Joe Anders, :J.E. Signature luP !)~ Form 1 0-4¿ Revised 4/2004 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - IQØ)MS BfiL AUf; 4) ?, 1.~~~)~ Qd-Bbl Representative Dailv AveraQe Production or Injection Data Gas-Mef Water-Bbl Casing Pressure Tubing Pressure 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ) 16. Well Status after proposed work: OilO GasD WAG 0 GINJD WINJŒ WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 304-242 Title Well Integrity Coordinator Phone 659-5102 Date 7/27/04 O~I{jINAL { BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 bp June 18, 2004 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 R E C E ~ \. it?:: :-", 'liIJ. ,....../: t ,.o-or,";~ .,' I' JUN 2 3 2004 A.!aska Oil t, I{"" Subject: R-15A (PTD 1990360) Application for Sundry Approval to Continue Injection with Surface Casing Leak Dear Mr. Aubert: Attached is Application for Sundry Approval form 10-403 for well R-15A (PTD 1990360). The purpose of this request is to continue water injection into R-15A with a surface casing leak. If you require any additional information or clarification, please contact Anna Dube or Joe Anders at (907) 659-5102. sincerl Iì IJ " 0f /tMÆ£,v UuJvV- Anna Dube Well Integrity Coordinator Attachments Application for Sundry form 10-403 Description Summary of Proposal Wellbore Schematic ('n,\ r"".' .". \ ø ~ ,~' 1'1-"" ("") ~ (J >" , '" It:" ..... ¡, /, ¡IÌo..,.. U (' \ f~~~~","CE_\~\1 Lm '. Ý STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 3 LOO~k ~ft~ APPLICATION FOR SUNDRY APPRQV~L':$ Comm\ss\C~, 20 AAC 25.280 1. Type of Request: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: Suspend 0 Repair Well D Pull Tubing D Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: PerforateD WaiverŒ} Annular DisposalD StimulateD Time ExtensionD OtherD Re-enter Suspended WellD 5. Permit to Drill Number: 199-0360 StratigraphicD Service Œ] 9. Well Name and Number: R-15A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY I Effective Depth MD (ft): I Effective Depth TVD (ft): 11986 8763.7 S~ MD WD BP Exploration (Alaska), Inc. Development D Exploratory D 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 48.96 KB 8. Property Designation: ADL-0028279 11. Total Depth MD (ft): ITotal Depth TVD (ft): 11986 8812.7 Casing Length Conductor 80 Liner 806 Liner 2639 Production 8377 Surlace 2643 Perforation Depth MD (ft): 11498 - 11539 Packers and SSSV Type: 4-1/2" Baker SB3 Packer 5" Baker ZXP Liner Top Packer 7" Baker ZXP Packer 12. Attachments: Description Summary of Proposal 0 top 27 8240 8902 25 26 27.0 7940.5 8551.7 25.0 26.0 bottom top 107 9046 11541 8402 2669 Tubing Size: 4.5 II 12.6 # Packers and SSSV MD (ft): 20" 91.5# H-40 7" 26# L-80 4-1/2" 12.6# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 Perforation Depth TVD (ft): 8828.3 - 8824.4 13. Well Class after proposed work: Detailed Operations Program ŒJ BOP Sketch 0 Exploratory 0 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. July 2, 2004 15. Well Status after proposed work: Oil D GasD WAG D GINJD Date: Contact Printed Name Signature - ~a Dube /) 11.- (~ ..~~~. Title Phone Well Integrity Coordinator 659-5102 6/18/04 Commission Use Only 0 that a representative may witness 6. API Number 50-029-20917 -01-00 Plugs (md): Junk (md): None None Burst Collapse bottom 107.0 8682.7 8824.2 8093.7 2669.0 Tubing Grade: L-80 1490 7240 8430 6870 4930 Tubing MD (ft): 25 470 5410 7500 4760 2670 8909 8853 8902 8240 DevelopmentD ServiceŒ} PluggedD AbandonedD WINJŒ WDSPLD Prepared by Garry Catron 564-4657. Joe Anders/Anna Dube ber' I Sundry Num .3~ c¡. d l(d- Bap TrstD ~ ~Mecha,nciallntegrity Test D I Locatior Clear,ance D I "L ,J, " J -llv] - I ~vl~~:ft ~ IA.-Litl (A.;1 Pel Ve-,.r I ì ~ l. r;~t, .¿..(..>( Lt.' CL.{ 12'1,/ ~.ty )1\ e:v {!;,~lll f- CAA.~t? "1 (2.4'1/ s, It,) P)'l9 \I CLl ¿y.þi tV ç; , & /2 /3/l0 0 ((:> I ' Þ BY ORDER OF ~~,(/v ' " THE COMMISSION Date: t::1,~. 'v, :/", _8ft J' ~ "'tlf~J.'~ nln'f(-'~rr 1,f¡ 1 Form 10-403 Revised 12/2003 " SUBMIT IN DUPLICATE ( R-15A Description Summary of Proposal 06/18/04 Problem: Injector with Suñace Casing leak Well History and Status Well R-15A (PTD 1990360) is a water injector with a surface casing leak. Summary of recent events: > 07/23/03: MITOA Failed wi N2, won't pressure over 450 psi > 12/23/03: AOGCC MITIA Passed to 2500 psi. > 06/06/04: AOGCC MITIA Passed to 3000 psi This sundry request is to allow for continued water injection. The following supports the request: - A MITIA Passed to 3000 psi on 06/06/04, demonstrating competent tubing and production casing. Pressures, temperature and injection rate are monitored and recorded daily. Proposed Action Plan 1. Allow well to continue water injection. 2. Record wellhead pressures, temperature, and injection rate daily. 3. Submit a monthly report of daily pressures, temperatures, and injection rates. 4. Perform an MITIA once every 2 years. 5. Notify the AOGCC of any indication of leaks or sustained fluids leaking from around the well. ~' TREE = 4-1/16" CAMERON WB..LI-EAD = 13-5/8" I\tCEVOY A CfUA TOR = --_? KB. ELEV = 48.6' BF. ELEV = 21.81' KOP = 4496' Max Angle = 107 @ 9673' Datum MD = 9633' Datum lVD = 8800' SS R-15A I ~ ~ SAFETY NOTES: 70° @ 9330' & 90° @ 9451' 2215' H4-1/2" HESX NIP, ID= 3.813" 1 - :::::>---I 2621' H9-5I8" DV PKRI ~ GAS LIFT MANDRELS ST MD lV D DEV lY PE VL V LA Ta-I PORT DATE 113-318" CSG, 72#, L-80, ID= 12.347" H 2673' r-JI ITOPOF7" LNR H 8240' 1 ~ ~ 8240' H9-5I8" X 7' BKR ZXPPKRlFLEX LOC LNR HGR 1 Minimum ID = 3.725" @ 8897' 4-112" HES XN NIPPLE MLLOUTWNDOW 8402' - 8417 ~ 8842' H4-1/2" HES X NIP, JD = 3.813" 1 8853' H 7" X 4-1/2" BKR SB-3 PROD PKR, ID = 3.875" 1 I 8 I ITOPOF 4-112" LNR 1-1 8902' 1 8876' H4-1/2" HES X NIP, ID = 3.813" 1 889T I~ 4-1/2" HES XN NP, ID = 3.725" 1 PERFORATION SUMMA.RY REF LOG: ANGLEA TTOP PERF: 96 @ 11498' f\bte: Refer to A"oduction DB for historical perf data SIZE SFf INTERVAL Opn/Sqz DATE 4-112" 1149B - 11539 SLID 05/16/99 6" 11541-11986 OH 05/11/99 8902' 1-17" X 5" BKR ZXPPKRlHWC HGR I 8908' H4-1/2" WLEG,ID = 3.958" I 8925' j-i ELMO TT LOGGED 06/14/99 1 1 4-1/2" TBG, 12.6#, L-BO, .0152 bpf, ID = 3.958" I~ 8908' i ~ " I T' UR,26#, L-80, .0383 bpI, ID = 6.27~' H 9044' i( , , , , 14-112" LNR, 12.6#, L-80, .0152 bpf, ID =3.953" 1-1 11498' 1 ~ ITOPOF 4-112" SLID LNR I~ 11498' 14-112" SLTDLNR, 12.6#, L-BO, .0152 bpf, ID= 3.953" 1-1 11541' I I TOO (OPS\J H:>LE) H 11993' t I-IID (OPS\J H:>LE) A..UGBACK I 1 9-5/8" CSG, 47#, L-80, D = 8.681" l-i 8402' 1 1 TOP OF CEMS\JT 1-1 8817' I , , , , , J [),L\TE 02128/83 05116/99 03128/02 03124/04 04/30/04 REV BY COMMENTS ORIGINAL COMPLETION SIŒTRACK(R-15A) RN/lP CORRECllONS KNC/TLH OÆN HOLE OORRECfION PJP/KAK CORRECllONS DATE REV BY OOfvfv1ENTS PRUDHOE BAY ll'Jrr WELL: R-15A ÆRMT f\b: 1990360 API f\b: 50-029-20917-01 SEe 32, T12N, R13E 8P Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor K~ b(ltbl04 DATE: Tuesday, June 15,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC R-15A PRUDHOE BAY UNIT R-15A FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ,J8e- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT R-15A Insp Num: mitJCr040612214620 Rei Insp Num: API Well Number: 50-029-20917-01-00 Permit Number: 199-036-0 Inspector Name: John Crisp Inspection Date: 6/6/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well R-15A Type Inj. F TVD 8813 IA 500 3000 2990 2990 P.T. 1990360 TypeTest SPT Test psi 2126.75 OA 0 0 0 0 Interval OTHER P/F P Tubing 1000 1000 1000 1000 Notes: MITIA to 3000 psi prep for waiver request. Tuesday, June 15,2004 Page 1 of 1 ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ::J.K~Cj I D{Zb( 03. Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us ({ OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / R Pad 12/23/03 Anna Dube Witnessing declined by John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Well R-15A Type Inj. F TVD 8,507' Tubing 700 700 700 700 Interval 4 P.T.D. 1990360 Type test P Test psi 2,127 Casing 475 2,500 2,440 2,440 P/F P Notes: 4 year required test. AOGCC representative declined witnessing test. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P TO. , Type test Test psi Casing P/F Notes: Well Typelni. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) ~Cl~NNEt) DEC :J 1 200] MIT Report Form Revised: 06{19/02 MIT PBU R-15A 12-23-03.xls 199-036-0 PRUDHOE BAY UNIT R-15A 50- 029-20917-01 BP EXPLORATION (ALASKA) ~c Roll #1: Start: Stop Roll/42: _~grt Stop MD 11986- TVD 08813- Completion ~a .t0~/11/99 Completed Status: WAGIN Current: T Name Interval Sent Received T/C/D c 9478 ~ 1 SCHLUM MCNL CH 3/20/00 3/28/00 C 9479b-'~ 1 SCHLUM USIT CH 3/20/00 3/28/00 D 9512 ~ SPERRY MPT/GR/EWR OH 3/21/00 3/21/00 L DGR/EWR-MD ~'f~AL 8100-11986 OH 2/5 3/28/00 3/28/00 L DGR/EWR-TVD ~"F"~AL 7800-8880 OH 2/5 3/28/00 3/28/00 L MCNL ~,~AL 8325-11496 CH 5 3/20/00 3/28/00 C ~-FINAL BL(C) 8800-9040 CH 5 5/5/99 5/13/99 L USIT L USIT ~IAL BL(C) 8250-8975 CH 5 5/5/99 5/13/99 R SRVY RPT ~..~EI(RY 8395.57-11986. OH 7/6/99 7/8/99 D Tuesday, May 01,2001 Page 1 of 1 I~RILLIIM !~ C~ER~/Ir-Ec; To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs' R-15A, AK-MM-90110 March 28, 2000 R-15A: 2" x 5" MD Resistivity & Gamma Ray Logs' 50-029-20917-01 2" x 5" TVD Resistivity & Gamma Ray Logs' 50-029-20917-01 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNO~DGE RECEIPT BY SIGNING AND RETURNING A COPY OF Tll]g TRANSMITTAL LETrER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date:2.8 2000 Alaska Oil & Gas Cons. Commission Anchorage BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 ~. Signed:. ~\ ~>~.~ . /~~Y~ ~ .-,.~., 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 ° Fax: 907-273-3535 a Halliburton company GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 121291 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 3/20/00 Well Job # Log Description Date Blueline Sepia Color CD Prints R-15A [,',.kc_ ~ ct ~ '"1, ~ 20113 USlT PDC/GR 990428 1 R-15A 99273 MCNL ! ~ CI~ q % 990614 1 i 1 S-25A ~c[q~'"-I 20030 RST 990929 1 1 1 ., PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Schlumberger GeoQuest Petrotectnical Data Center MB3-3 3940 Arctic Blvd, Suite 300 900 E. Benson BIvd. Anchorage, AK 99503-5711 Anchorage, Alaska 99519-6612 RECEIVED Alq'N: Date Delivered: MAI:J ~8 ~000 Received b '.~__..)/~,0x~ '-~ / Alaska 0il & Gas Cons. Commission (, .) Anchorage WELL LOG TRANSMI'ITAL To.' State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs March 2 l, 2000 1 LDWG formatted Disc with verification listing. APl#: 50-029-20917-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITrAL LE'ITER TO THE ATrENTION OF: Sperry-Sun Drilling Services Attn: Jun Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date: MAR 2] 2.000 .~lasKa i)il ,s u;.~, L;aas. tommission Anchora§~ BP Exploration (Alaska) Inc. Petro-Technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Signed: 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company -- STATE OF ALASKA .-~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~] Oil [] Gas [] Suspended []Abandoned [~ Service Water & Gas Injector 2. Name of Operator ~, 7. Permit Number BP Exploration (Alaska)Inc .......~ 99-036 3. Address . _~~ . 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612~ 50-029-20917-01 4. Location of well at surface ! ~lli~- _-'~?/'J~_. i 9. Unit or Lease Name 1551' NSL, 1734' EWL, SEC. 32, T12N, R13E, UM ~:~?.--'~~ Prudhoe Bay Unit At top of productive interval i~..~.'/?/_¢~,~ ,10. Well Number 1826' NSL, 120' WEL, SEC. 31, T12N, R13E, UM ~i R-15Ai At total depth ![ '- -':~'~- '-~ ~ i11. Field and Pool 3272' NSL, 2300' WEL, SEC. 31 T12N, R13E, UM ~""~'~'-- ~-~ ' ; ~'~-~'-- --~ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designatio~-~a¥~8 Serial No. Pool KBE = 48.96' AMSLI ADL 028279 12. Date Spudded4/25/99 I 13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'll 5' Water depth' if °ffsh°re I 16' N°' °f C°mpleti°ns5/4/99 5/11/99 N/A MSL One 17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121 . Thickness of Permafrost 11986 8813 FTI 11986 8813 FTI [~Yes ~-]No (Nipple) 2215' MD 1900' (Approx.) 22. Type Electric or Other Logs Run Mw ,, us,Y, 23. CASING, LINER AND CEMENTING RECORD~,.,} I '~ ~ ~,) ~ ~ ~ /~ CASING SETTING DEPTH HOLE 20"x 30" Insulated Conductor Surface 110' 36" [8 cu yds concrete ~. 13-3/8" 72# L-80 Surface 2673' 17-1/2" 3720 cuft Permafrost II 9-5/8" 47# L-80 Surface 8402' 12-1/4" 11615 cu ft Class 'G', 130 cu ft Permafrost 7" 26# L-80 8254' 9046' 8-1/2" 202 cuft Class 'G' 4-1/2" 12.6# L-80 8916' 11541' 6" 371 cuft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Arii~fl°'rage Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 6" Open Hole 4-1/2", 12.6#, L-80 8909' 8853' MD TVD MD TVD 11498'- 11539' 8828' - 8824' 11541'- 11986' 8824'- 8813' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 151 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) June 24, 1999 I Water & Gas Injector Date of Test !Hours Tested PRODUCTION FOR OIL-BBL :GAS-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAViTY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 9048' 8685' Shublik 9098' 8728' Sadlerochit / Zone 4 9175' 8787' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the forepoing is true an~d _correct to the best of my knowledge Signed TerrieHubble ""~,~~__j .--/~ Title Technical Assistant III Date OI~'' ~ '~ R-15Ai 99-036 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. ,,, INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1.' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 20 Apr 99 21 Apr 99 22 Apr 99 23 Apr 99 24 Apr 99 PB R Pad 01:00-06:00 06:00-08:00 08:00-12:00 12:00-06:00 06:00-08:00 08:00-10:00 10:00-11:00 11:00-15:00 15:00-18:30 18:30-19:30 19:30-20:30 20:30-21:30 21:30-23:30 23:30-00:30 00:30-03:00 03:00-06:00 06:00-08:00 08:00-09:30 09:30-12:00 12:00-13:30 13:30-14:00 14:00-14:30 14:30-15:30 15:30-16:30 16:30-19:00 19:00-19:30 19:30-22:00 22:00-22:30 22:30-23:30 23:30-00:30 00:30-06:00 06:00-07:30 07:30-08:00 08:00-11:30 11:30-14:00 14:00-16:00 16:00-16:30 16:30-00:00 00:00-01:00 01:00-01:30 01:30-04:30 04:30-06:00 06:00-11:00 11:00-12:30 12:30-13:00 13:00-13:30 13:30-16:00 16:00-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-21:30 21:30-22:00 22:00-03:00 Progress Report Well R- 15A Page 1 Rig Nabors 7ES Date 20 May 99 Duration 5 hr 2 hr 4 hr 18hr 2 hr 2 hr 1 hr 4 hr 3-1/2 hr 1 hr 1 hr 1 hr 2 hr 1 hr 2-1/2 hr 3 hr 2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1 hr 1 hr 2-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1 hr 1 hr 5-1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 2-1/2 hr 2 hr 1/2 hr 7-1/2 hr lhr 1/2 hr 3hr 1-1/2 hr 5 hr 1-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 2hr 1/2 hr 1 hr 1/2 hr 1-1/2 hr 1/2 hr 5 hr Activity Rig moved 5.00 % Rig waited: Service personnel Rig moved 20.00 % Rig moved 80.00 % Rig moved 95.00 % Rig moved 100.00 % Rigged up Drillfloor / Derrick Rigged up Fluid system Rigged up High pressure lines Retrieved Hanger plug Held safety meeting Held safety meeting Circulated at 8423.2 ft Installed Hanger plug Removed Xmas tree Rigged up BOP stack Rigged up BOP stack Tested Well control Removed Hanger plug Rigged down Lubricator Pulled Tubing on retrieval string to 8393.2 ft Circulated at 8393.2 ft Pulled Tubing on retrieval string to 8343.2 ft Rigged up Sub sea tools Installed Seal assembly Held safety meeting Tested BOP stack Installed Wear bushing Retrieved Retrievable packer Rigged up Completion string handling equipment Laid down Tubing of 7000.0 ft Laid down 8430.0 ft of Tubing (cont...) Rigged down Tubing handling equipment Conducted slickline operations on Slickline equipment - Tool run Made up BHA no. 1 Made up BHA no. 1 Took MWD survey at 958.2 ft Singled in drill pipe to 8413.2 ft Functioned downhole tools at 8425.2 ft Tested Casing Circulated at 8393.2 ft Milled Casing at 8395.2 ft Milled Casing at 8437.0 ft (cont...) Circulated at 8437.0 ft Performed formation integrity test Cleared Kelly/top drive hose Pulled out of hole to 960.0 ft Pulled BHA Removed Sub sea tools Serviced BOP stack Serviced Top drive Made up BHA no. 2 Made up BHA no. 2 R.I.H. to 8310.0 ft Facility Date/Time 25 Apr 99 26 Apr 99 27 Apr 99 28 Apr 99 PB R Pad 03:00-03:30 03:30-04:30 04:30-06:00 06:00-22:00 22:00-22:30 22:30-04:30 04:30-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-09:00 09:00-09:30 09:30-10:00 10:00-14:00 14:00-15:00 15:00-16:30 16:30-17:00 17:00-19:00 19:00-19:30 19:30-20:00 20:00-00:00 00:00-01:30 01:30-02:00 02:00-03:30 03:30-04:00 04:00-04:30 04:30-05:30 05:30-06:00 06:00-07:00 07:00-08:00 08:00-09:30 09:30-13:30 13:30-14:30 14:30-15:00 15:00-21:00 21:00-23:00 23:00-01:00 01:00-05:00 05:00-05:45 05:45-06:00 06:00-06:15 06:15-09:00 09:00-09:15 09:15-09:30 09:30-10:15 10:15-13:15 13:15-14:00 14:00-14:45 14:45-15:45 15:45-17:00 17:00-18:00 18:00-19:30 Duration 1/2 hr 1 hr 1-1/2 hr 16hr 1/2 hr 6 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 4 hr 1 hr I- 1/2 hr 1/2 hr 2 hr 1/2 hr 1/2 hr 4 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1 hr 1/2 hr 1 hr lhr 1-1/2 hr 4 hr lhr 1/2 hr 6 hr 2 hr 2 hr 4 hr 3/4 hr 1/4 hr 1/4 hr 2-3/4 hr 1/4 hr 1/4 hr 3/4 hr 3 hr 3/4 hr 3/4 hr 1 hr 1-1/4 hr 1 hr 1-1/2 hr Progress Report Well R- 15A Rig Nabors 7ES Page Date Activity Serviced Block line Circulated at 8310.0 ft Drilled to 8450.0 ft _Drilled to 8872.0 ft Serviced Mud pumps Drilled to 9039.0 ft Circulated at 9039.0 ft Drilled to 9046.0 ft Circulated at 9046.0 ft Circulated at 9046.0 ft (cont...) Pulled out of hole to 8370.0 ft R.I.H. to 9046.0 ft Circulated at 9046.0 ft Circulated at 9046.0 ft Took EMS survey at 8938.0 ft Pulled out of hole to 756.0 ft Pulled BHA Pulled BHA Rigged up Casing handling equipment Ran Liner to 807.0 ft (7in OD) Ran Liner on landing string to 1361.0 ft Circulated at 1361.0 ft Ran Liner on landing string to 8400.0 ft Circulated at 8400.0 ft Ran Liner on landing string to 9015.0 ft Circulated at 9046.0 ft Mixed and pumped slurry - 36.000 bbl Displaced slurry - 107.000 bbl Functioned Liner hanger Pulled Drillpipe in stands to 8284.0 ft Circulated at 8200.0 ft Washed to 8238.0 ft Circulated at 8238.0 ft Pulled out of hole to 0.0 ft Laid down 555.0 ft of 5in OD drill pipe Serviced Top drive Made up BHA no. 3 Reamed to 8964.0 ft Circulated at 8964.0 ft Pulled out of hole to 1200.0 ft Pulled BHA Retrieved Wear bushing Installed BOP test plug assembly Tested BOP stack Retrieved BOP test plug assembly Installed Wear bushing Rigged up Logging/braided cable equipment Conducted electric cable operations Rigged down Logging/braided cable equipment Tested Liner Made up BHA no. 4 R.I.H. to 4400.0 ft Serviced Block line R.I.H. to 8964.0 ft 2 20 May 99 Facility PB R Pad Date/Time 19:30-00:00 29 Apr 99 00:00-02:00 02:00-04:30 04:30-05:00 05:00-06:00 06:00-06:15 06:15-09:15 09:15-10:00 10:00-11:30 11:30-12:00 12:00-13:00 13:00-15:30 15:30-19:30 19:30-21:30 21:30-22:00 22:00-22:30 22:30-23:30 23:30-00:30 30 Apr 99 00:30-04:30 04:30-06:00 06:00-06:00 01 May 99 06:00-06:00 02 May 99 06:00-17:00 17:00-19:30 19:30-21:00 21:00-21:30 21:30-22:00 22:00-02:00 03 May 99 02:00-03:30 03:30-05:30 05:30-06:00 06:00-10:30 10:30-11:00 11:00-06:00 04 May 99 06:00-13:30 13:30-16:30 16:30-18:00 18:00-19:30 19:30-23:30 23:30-06:00 05 May 99 06:00-08:30 08:30-09:30 09:30-14:00 14:00-14:30 14:30-18:00 18:00-18:30 18:30-22:00 22:00-00:00 06 May 99 00:00-01:30 01:30-02:30 02:30-03:00 03:00-03:30 03:30-04:00 04:00-04:30 Progress Report Well R-15A Page 3 Rig Nabors 7ES Date 20 May 99 Duration Activity 4-1/2 hr 2 hr 2-1/2 hr 1/2 hr 1 hr 1/4 hr 3 hr 3/4 hr 1-1/2 hr 1/2 hr 1 hr 2-1/2 hr 4 hr 2 hr 1/2 hr 1/2 hr 1 hr 1 hr 4 hr 1-1/2 hr 24 hr 24 hr llhr 2-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 4 hr 1-1/2 hr 2 hr 1/2 hr 4-1/2 hr 1/2 hr 19hr 7-1/2 hr 3 hr 1-1/2 hr 1-1/2 hr 4 hr 6-1/2 hr 2-1/2 hr 1 hr 4-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 3-1/2 hr 2 hr 1-1/2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr Drilled installed equipment - Landing collar Circulated at 9040.0 ft Pulled out of hole to 780.0 ft Pulled BHA Rigged up Logging/braided cable equipment Rigged up Logging/braided cable equipment (cont...) Conducted electric cable operations Rigged down Logging/braided cable equipment Laid out HWDP from derrick Made up BHA no. 5 Held safety meeting Made up BHA no. 5 R.I.H. to 8115.0 ft Logged hole with LWD: DIR/FE from 8115.0 fl to 8484.0 ft R.I.H. to 9044.0 ft Drilled installed equipment - Float shoe Circulated at 9048.0 ft Drilled to 9066.0 ft Circulated at 9046.0 ft Drilled to 9136.0 fl Drilled to 9840.0 fl (cont...) Drilled to 10670.0 ft (cont...) Drilled to 11023.0 ft (cont...) Circulated at 11023.0 ft Pulled out of hole to 9042.0 ft Serviced Block line Serviced Top drive pipe handler Pulled out of hole to 212.0 ft Pulled BHA Made up BHA no. 6 R.I.H. to 600.0 ft R.I.H. to 11023.0 ft Circulated at 11023.0 ft Drilled to 11740.0 fl Drilled to 11986.0 ft Circulated at 11986.0 fl Pulled out of hole to 9039.0 fl R.I.H. to 11986.0 ft Circulated at 11986.0 ft Pulled out of hole to 1000.0 ft Pulled BHA Installed Casing handling equipment Ran Liner to 2643.0 ft (4-1/2in OD) Circulated at 2643.0 ft Ran Liner on landing string to 9000.0 ft Circulated at 9000.0 ft Ran Liner on landing string to 11540.0 ft Circulated at 11540.0 ft Set Liner hanger at 11470.0 ft with 2300.0 psi Circulated at 11540.0 ft Held safety meeting Batch mixed slurry - 66.000 bbl Displaced slurry - 123.000 bbl Functioned Permanent packer Facility Date/Time 07 May 99 08 May 99 09 May 99 10 May 99 PB R Pad Progress Report Well R- 15A Page 4 Rig Nabors 7ES Date 20 May 99 Duration Activity 04:30-06:00 06:00-07:00 07:00-10:30 10:30-11:00 11:00-16:00 16:00-20:00 20:00-20:30 20:30-00:00 00:00-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-10:00 10:00-12:00 12:00-13:30 13:30-15:00 15:00-16:30 16:30-17:30 17:30-23:00 23:00-00:00 00:00-01:00 O1:00-03:00 03:00-05:00 05:00-06:00 06:00-08:00 08:00-14:00 14:00-14:30 14:30-16:00 16:00-16:30 16:30-17:00 17:00-18:00 18:00-18:30 18:30-22:00 22:00-22:30 22:30-00:00 00:00-03:30 03:30-04:00 04:00-04:30 04:30-06:00 06:00-06:15 06:15-08:00 08:00-08:15 08:15-11:00 11:00-15:30 15:30-15:45 15:45-21:00 21:00-00:00 00:00-01:00 01:00-01:30 01:30-03:00 03:00-06:00 06:00-12:30 12:30-15:30 15:30-17:30 1-1/2 hr 1 hr 3-1/2 hr 1/2 hr 5 hr 4 hr 1/2 hr 3-1/2 hr 3 hr 1 hr 1 hr 1 hr 4 hr 2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 5-1/2 hr 1 hr 1 hr 2 hr 2 hr 1 hr 2 hr 6 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1 hr 1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/4 hr 1-3/4 hr 1/4 hr 2-3/4 hr 4-1/2 hr 1/4 hr 5-1/4 hr 3 hr 1 hr 1/2 hr 1-1/2 hr 3 hr 6-1/2 hr 3 hr 2 hr Reverse circulated at 8897.0 ft Cleared Cement head Rigged down Fluid system Held safety meeting Rigged down Fluid system Tested BOP stack Installed Drillstring handling equipment Made up BHA no. 7 R.I.H. to 3510.0 ft Serviced Draw works Circulated at 3510.0 ft Pulled out of hole to 2775.0 ft Pulled out of hole to 29.0 ft Pulled BHA R.I.H. to 3777.0 ft Circulated at 3777.0 ft Pulled out of hole to 0.0 ft Made up BHA no. 8 R.I.H. to 11150.0 ft Installed High pressure lines Tested Liner - Via string Washed to 11463.0 ft Drilled installed equipment - DV collar Drilled installed equipment - Landing collar Drilled installed equipment - Landing collar (cont...) Pulled out of hole to 3719.0 ft Rigged up Drillstring handling equipment Pulled out of hole to 29.0 ft Pulled BHA Made up BHA no. 9 R.I.H. to 3719.0 ft Rigged down Drillstring handling equipment R.I.H. to 11459.0 ft Washed to 11539.0 ft Drilled installed equipment - Float shoe Reamed to 11988.0 ft Circulated at 11988.0 ft Pulled out of hole to 11540.0 ft Washed to 11986.0 ft Functioned Circulating sub Circulated at 11968.0 ft Functioned Circulating sub Circulated at 8267.0 ft Circulated at 8267.0 ft Pulled out of hole to 11521.0 ft Laid down 8022.0 ft of 4in OD drill pipe Pulled out of hole to 28.9 ft Pulled BHA Rigged down Drillstring handling equipment Rigged up Completion string handling equipment Ran Tubing to 4-1/2in (2600.0 ft OD) Ran Tubing to 8909.0 ft (4-1/2in OD) (cont...) Reverse circulated at 8909.0 ft Freeze protect well - 151.000 bbl of Diesel Facility PB R Pad Date/Time 17:30-18:00 18:00-19:00 19:00-20:00 20:00-20:30 20:30-00:00 11 May 99 00:00-02:00 02:00-03:00 03:00-04:00 Progress Report Well R- 15A Rig Nabors 7ES Page Date Duration 1/2 hr 1 hr 1 hr 1/2 hr 3-1/2 hr 2 hr 1 hr 1 hr Activity Functioned Production packer Tested Tubing Tested Casing Installed Hanger plug Rigged down BOP stack Rigged up Xmas tree Retrieved Hanger plug Functioned Xmas tree primary components 5 20 May 99 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_ WOA R Pad, Slot R- 15 R-15A Job No. AKMM90110, Surveyed: 4 May, 1999 SURVEY REPORT 17 May, 1999 ORiGiNAL Your Ref: AP1-500292091701 Surface Coordinates: 5978035.08 N, 635366.41 E (70° 20' 52.3748" N, Kelly Bushing: 48.96ft above Mean Sea Level 148 o 54' 03. 8550" W) D.R,I L L, I N..~ S. E~ R V I. cZ ~, s Survey Ref: svy8560 A HAI,LIBt~TO~ CO~PAF;Y · Sperry-Sun Drilling Services Survey Report for R- 15A Your Ref: API-500292091701 Job No. AKMM90110, Surveyed: 4 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 8395,57 18,5o0 280,594 8038.66 8087.62 84Ol.00 18.49o 280,610 8043.81 8092.77 8437.41 19.24o 276.320 8078.27 8127.23 8472.50 20.660 272.580 8111.25 8160.21 8504.89 22.090 269.520 8141.41 8190.37 8534.0o 23.380 267,050 8168.26 8217.22 8564.71 24.160 264.660 8196.37 8245.33 8596.26 24,410 264.610 8225.13 8274.09 8625.80 24.420 266.000 8252.02 8300.98 8718,00 24,530 275,240 8335.97 8384.93 8748.77 25.180 281,950 8363.90 8412.86 8780.64 25,120 285,240 8392,75 8441.71 8811.76 25,220 289.760 8420.91 8469,87 8845.78 24,890 291.860 8451.73 8500.69 8877.16 24,970 295.360 8480.19 8529.15 8907.82 24,860 296.780 8508.00 8556.96 8938.37 24.600 296.550 8535.75 8584.71 8969.38 24,350 297,580 8563.97 8612.93 8991.62 24,210 297.610 8584.24 8633.20 9017,07 24.350 296.390 8607.44 8656.40 9048.75 24.800 294,990 8636.25 8685.21 9080,56 29,290 293,770 8664.58 8713.54 9112.22 35.470 289.390 8691.31 8740.27 9143.38 40.870 287.470 8715.79 8764.75 9174.72 46.250 287.980 8738.50 8787.46 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 198.80 N 1534.52W 5978206.13 N 633828.55 E 199.12 N 1536.21W 5978206.42 N 633826.85 E 200.84 N 1547.85W 5978207.93 N 633815.19 E 201.76 N 1559.78W 5978208.63 N 633803.24 E 201.96 N 1571.58W 5978208.62 N 633791.44 E 201.62 N 1582.82W 5978208.08 N 633780.21 E 200.72 N 1595.16W 5978206.95 N 633767.88 E 199.51 N 1608.08W 5978205.51 N 633754.99 E 198.51 N 1620.25W 5978204.29 N 633742.84 E 198.93 N 1658.34W 5978204.02 N 633704.75 E 200.87 N 1671.10W 5978205.73 N 633691.95 E 204,05 N 1684,26W 5978208.67 N 633678.74 E 208.03 N 1696.88W 5978212.42 N 633666.05 E 213.14 N 1710.34W 5978217.29 N 633652.50 E 218.44 N 1722.46W 5978222.37 N 633640.29 E 224.11N 1734.06W 5978227.84 N 633628.58 E 229.85 N 1745.48W 5978233.36 N 633617,06 E 235.70 N 1756.92W 5978239.00 N 633605,52 E 239.93 N 1765.03W 5978243.09 N 633597,34 E 244,68 N 1774.35W 5978247.67 N 633587.93 E 250.39 N 1786.22W 5978253.17 N 633575.96 E 256,35 N 1799.40W 5978258.88 N 633562.68 E 262.53 N 1815.17W 5978264.78 N 633546.80 E 268.59 N 1833.43W 5978270.51 N 633528.42 E 275.17 N 1854.00W 5978276.72 N 633507.75 E Alaska State Plane Zone 4 PBU_WOA R Pad Dogleg Rate (°/100ft) Vertical Section (ft) Comment 0.205 4.330 5,439 5.598 5.512 4.036 0.795 1.945 4.150 9.4Ol 4,391 6,184 2,788 4,708 1.984 0,907 1.595 0.632 2.046 2.323 14.222 20.867 17.742 17.203. 1434.59 1436.22 1447.20 1458.05 1468.43 1478.06 1488.37 1499.03 1509.14 1542.53 1554.61 1567.64 1580.58 1594.82 1607.98 1620.87 1633.64 1646.47 1655.61 1666.07 1679.22 1693.62 1710.39 1729.28 1750.43 TIE-ON SURVEY WINDOW POINT Continued... 17 May, 1999 - 15:26 - 2- DrlllQuest Sperry-Sun Drilling Services Survey Report for R-15A Your Ref: API-500292091701 Job No, AKMM90110, Surveyed: 4 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9205.77 51.700 288.400 8758.87 8807.83 9237.20 57.540 290.500 8777.06 8826.02 9264.92 62.900 293.530 8790.83 8839.79 9299.34 67.910 296.290 8805.15 8854.11 9329.62 71.790 294.990 8815.58 8864.54 9356.00 75.600 294.060 8822.98 8871.94 9390.39 81.640 292.860 8829.77 8878.73 9421.53 87.910 291.040 8832.60 8881.56 9450.86 91.320 288.400 8832.80 8881.76 9482.30 95.330 285.650 8830.98 8879.94 9513,47 99.390 283.100 8826.98 8875.94 9545.05 103.880 283.420 8820.61 8869.57 9576.71 104.480 287.300 8812.86 8861.82 9610.03 105.550 290.540 8804.22 8853.18 9642.68 106.610 292.660 8795.18 8844.14 9673.16 106.930 293.360 8786.38 8835.34 9705.30 106.070 292.360 8777.26 8826.22 9736.39 103.080 292.070 8769.43 8818.39 9767.32 100.230 293.830 8763.18 8812.14 9794.00 98.610 293.750 8758.82 8807.78 9823.84 96.460 294.700 8754.90 8803.86 9856.45 95.030 294.340 8751.64 8800.60 9885.71 94.070 294.200 8749.32 8798.28 9918.21 90,680 291.060 8747.97 8796.93 9949.13 89,320 290.580 8747.97 8796.93 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 282.48 N 1876.24W 5978283.63 N 633485.37 E 291.03 N 1900.39W 5978291.73 N 633461.08 E 300.06 N 1922.67W 5978300.36 N 633438.63 E 313.25 N 1951.04W 5978313.04 N 633410.03 E 325.54 N 1976.66W 5978324.86 N 633384.19 E 336.05 N 1999.69W 5978334.95 N 633360.97 E 349.46 N 2030.61W 5978347.80 N 633329.82 E 361.04 N 2059.36W 5978358.87 N 633300.87 E 370.94 N 2086.96W 5978368.26 N 633273.09 E 380.13 N 2116.96W 5978376.91 N 633242.93 E 387.80 N 2146.90W 5978384,04 N 633212.86 E 394.89 N 2176.99W 5978390.59 N 633182.64 E 403.02 N 2206.59W 5978398.18 N 633152.90 E 413.45 N 2237.03W 5978408.06 N 633122,28 E 425.00 N 2266,19W 5978419.08 N 633092,91 E 436.41N 2293.06W 5978430.00 N 633065.85 E 448.38 N 2321.45W 5978441.45 N 633037.24 E 459.75 N 2349.30W 5978452.32 N 633009.18 E 471.56 N 2377.19W 5978463.63 N 632981.09 E 482.18 N 2401.28W 5978473.81N 632956.82 E 494.32 N 2428.25W 5978485.46 N 632929.63 E 507.78 N 2457.77W 5978498.39 N 632899.87 E 519.77 N 2484.36W 5978509.89 N 632873.07 E 532.26 N 2514.33W 5978521.84 N 632842.88 E 543.25 N 2543.23W 5978532.31 N 632813.79 E Alaska State Plane Zone 4 PBU_WOA R Pad Dogleg Rate (°/100ft) Vertical Section (ft) Comment 17.582 19.361 21.535 16.278 13.432 14.834 17.893 20.958 14.702 15.456 15.345 14.252 12.032 9.925 7.033 2.437 4.007 9.660 10.768 6.079 7.866 4.521 3.315 14.211 4.664 1773.40 1798.63 1822.48 1853.67 1882.03 1907.25 1940.77 1971.50 200O.40 2031.05 2O60.90 2090.61 2120.38 2152.02 2183.10 2212.11 2242.72 2272.57 2302.67 2328.86 2358.32 2390.65 2419.70 2451.94 2482.51 Continued... 17 May, 1999 o 15:26 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for R-15A Your Ref: API-500292091701 Job No. AKMM90110, Surveyed: 4 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 9980,67 1 oo 1 o,93 1 oo42.o5 10o72.92 1 Ol o3.85 1 Ol 39.52 1 Ol 71 .Ol 1 Ol 98.63 10228.17 I o258.68 10290.29 10323.06 10353.98 10385.14 1 o416.67 10446.76 10478.80 10511.86 1 o543.51 10574.91 10605.80 10638.17 I o668.69 10696.82 10727.83 86.420 83,950 8o.19o 79.640 79.620 81.39o 82.12o 82.o7o 83.41o 84.71o 84.640 84.670 84.290 84.280 84.330 84.12o 85.12o 86.850 87,320 89.880 91.91o 93.11o 92.430 91.69o 89.260 Azim. 287.540 286,99o 283.74o 283.30o 284.630 282.350 28o.19o 280.420 278.040 277.820 276,740 276,680 277,670 276,670 277.1oo 277.600 278.15o 282.490 283.1oo 288.560 290.890 294.370 298.630 3Ol.89o 3o2.18o Sub-Sea Depth (ft) 8749.14 8751,68 8755.98 8761.38 8766.95 8772.84 8777.35 8781.15 8784.88 8788.04 8790.98 8794.03 8797.00 8800.11 8803.23 8806.26 8809.27 8811.58 8813.19 8813.96 8813.48 8812.06 8810.58 8809.57 8809.31 Vertical Depth (ft) 8798.10 8800.64 8804.94 8810.34 8815.91 8821.80 8826.31 8830.11 8833.84 8837.00 8839.94 8842.99 8845.96 8849.07 8852.19 8855.22 8858.23 8860.54 8862.15 8862.92 8862.44 8861.02 8859.54 8858.53 8858.27 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (fi) (ft) (fi) (fi) 553.54 N 2573.01W 5978542.06 N 632783.82 E 562.49 N 2601,80W 5978550,48 N 632754.87 E 570.66 N 2631.51W 5978558.11 N 632725.02 E 577.77 N 2661.06W 5978564.69 N 632695.35 E 585.11 N 2690.59W 5978571.49 N 632665.69 E 593.31 N 2724.79W 5978579.08 N 632631.34 E 599.40 N 2755.36W 5978584.61 N 632600.68 E 604.30 N 2782.27W 5978589.02 N 632573.68 E 609.00 N 2811.19W 5978593.20 N 632544.68 E 613.18 N 2841.25W 5978596.84 N 632514.55 E 617.17 N 2872.47W 5978600.26 N 632483.26 E 620.98 N 2904.87W 5978603.49 N 632450.80 E 624.83 N 2935.41W 5978606.78 N 632420.20 E 628.70 N 2966.17W 5978610.10 N 632389,37 E 632.46 N 2997.32W 5978613.29 N 632358,16 E 636.29 N 3027.01W 5978616.59 N 632328,40 E 640.66 N 3058.61W 5978620.39 N 632296.73 E 646.57 N 3091.04W 5978625.71 N 632264.19 E 653.57 N 3121.87W 5978632.15 N 632233.25 E 662.13 N 3152.05W 5978640.16 N 632202.91 E 672.55 N 3181.12W 5978650.06 N 632173.66 E 684.99 N 3210.97W 5978661.96 N 632143.59 E 698.59 N 3238.24W 5978675.06 N 632116.08 E 712.75 N 3262.52W 5978688.79 N 632091.55 E 729.20 N 3288.80W 5978704.76 N 632064.97 E Alaska State Plane Zone 4 PBU_WOA R Pad Dogleg Rate (°/100fi) Vertical Section (ft) Comment 13.315 8,361 15.9o4 2.268 4.230 8.o23 7.173 0.844 9.19o 4.321 3.409 0.204 3,416 3.193 1.366 1.795 3.558 14.1o2 2.431 19.199 lO.OO3 11.362 14.119 11.876 7.892 2513.51 2542,99 2572.89 26o2.12 2631.45 2665.28 2694.90 2720.75 2748.26 2776.50 2805.66 2835.76 2864.25 2892.96 2921.94 2949.69 2979.37 3OLO.53 3040.82 3o71.32 31Ol.76 3133.87 3164.31 3192.42 3223.39 Continued... 17 May, 1999 - 15:26 - 4 - DrlllQuest Sperry-Sun Drilling Services Survey Report for R-15A Your Ref: API-500292091701 Job No. AKMM90110, Surveyed: 4 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 10758,95 lO787,14 10817,97 10848.97 10882.29 10911.78 10943.41 10976,57 11006.31 11035.65 11068.13 11097.34 11128.27 11157.04 11191 .o6 11220.56 11250.49 11281.12 11313.98 11344.77 11374.09 11406.35 11437.35 11466.05 11498.63 87.660 86.61o 86.21o 85.960 86.12o 86.490 90.340 91,110 91.39o 91.29o 91.91o 92.280 92.370 92.990 94.630 95.870 97.820 98.21o 97.990 96.760 95,890 94.370 94.350 94.800 95.520 Azim. 305.120 3O5.47O 3O5.87O 305.840 308.270 311.450 314,040 314,700 315.510 318.730 322.980 324.980 325.280 324,940 326.040 326.09O 330.080 329.950 331.560 332.590 334.190 334.920 334.210 334.820 334.230 Sub-Sea Depth (ft) 8810.15 8811.56 8813.49 8815.61 8817.91 8819.81 8820.68 8820.26 8819.62 8818.93 8818.02 8816.95 8815.70 8814.35 8812.09 8809.39 8805.83 8801.56 8796.93 8792.97 8789.74 8786.86 8784.50 8782.21 8779.28 Vertical Depth (ft) 8859.11 8860.52 8862.45 8864.57 8866,87 8868.77 8869.64 8869,22 8868.58 8867.89 8866.98 8865.91 8864.66 8863,31 8861.05 8858.35 8854.79 8850.52 8845.89 8841.93 8838.70 8835.82 8833.46 8831.17 8828.24 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 746.43 N 3314,70W 5978721.52 N 632038.77 E 762.70 N 3337.68W 5978737.37 N 632015.50 E 780.64 N 3362,67W 5978754.86 N 631990.19 E 798.76 N 3387.74W 5978772.52 N 631964.80 E 818.79 N 3414.27W 5978792.06 N 631937.91 E 837.65 N 3436.85W 5978810.51N 631914.99 E 859.10 N 3460.07W 5978831.54 N 631891.39 E 882.29 N 3483,77W 5978854,30 N 631867.27 E 903.35 N 3504.75W 5978874.98 N 631845.91 E 924.84 N 3524.71W 5978896.10 N 631825.57 E 950.02 N 3545.20W 5978920.90 N 631804.63 E 973.62 N 3562.37W 5978944.20 N 631787.04 E 998.98 N 3580.04W 5978969.23 N 631768.92 E 1022.55 N 3596.47W 5978992.50 N 631752.05 E 1050.52 N 3615.70W 5979020.12 N 631732.32 E 1074.89 N 3632.10W 5979044.19 N 631715.48 E 1100.11 N 3647.81W 5979069.12 N 631699.32 E 1126.38 N 3662.97W 5979095.12 N 631683.69 E 1154.77 N 3678.86W 5979123.21 N 631667.29 E 1181.75 N 3693.16W 5979149.92 N 631652.51 E 1207.80 N 3706.21W 5979175.74 N 631638,99 E 1236.81N 3720.02W 5979204.50 N 631624,66 E 1264.73 N 3733.29W 5979232.17 N 631610.88 E 1290.55 N 3745.60W 5979257.77 N 631598.11 E 1319.84 N 3759.56W 5979286.80 N 631583.63 E Alaska State Plane Zone 4 PBU_WOA R Pad Dogleg Rate (°/lOOft) Vertical Section (ft) Comment 10.752 3.926 1.833 0.812 7.291 10.834 14.667 3.058 2.881 10.977 13.218 6.959 1.o12 2.457 5.8Ol 4.207 14.752 1.341 4,897 5.193 6.182 5.223 2.285 2.636 2.852 3254.41 3282.41 3313.oo 3343.73 3376.67 3405.60 3436.36 3468.39 3497.Ol 3524.95 3555.15 3581.7o 3609.53 3635.42 3665.91 3692.16 3718.22 3744.32 3772.09 3797.79 3821.95 3848.22 3873.48 3896.88 3923.42 Continued... 17 May, 1999 - 15:26 - 5 - DrlllQuest Sperry-Sun Drilling Services Survey Report for R-15A Your Ref: API-500292091701 Job No. AKMM90110, Surveyed: 4 May, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11533.08 95.450 332.480 8775.99 8824.95 1350.49 N 3774.94W 5979317.17 N 631567.70 E 11565.36 95.300 330.500 8772.96 8821.92 1378.73 N 3790.28W 5979345.13 N 631551.85 E 11598.03 93.170 327.940 8770.55 8819.51 1406.72 N 3806.95W 5979372.81 N 631534.68 E 11628.90 91.110 325.090 8769.40 8818.36 1432.44 N 3823.97W 5979398.22 N 631517.20 E 11660.38 91.110 324.450 8768.79 8817.75 1458.15 N 3842.1'2W 5979423.60 N 631498.58 E 11688.57 91.910 324.510 8768.05 8817.01 1481.09 N 3858.49W 5979446.23 N 631481.79 E 11722.25 92.340 324.840 8766.80 8815.76 1508.55 N 3877.95W 5979473.34 N 631461.84 E 11753.28 91,730 322.280 8765.70 8814.66 1533.49 N 3896.37W 5979497.95 N 631442.98 E 11784.76 89,570 324,030 8765,34 8814,30 1558.68 N 3915,25W 5979522.79 N 631423.65 E 11815.80 89.010 323.230 8765.72 8814.68 1583.67 N 3933.65W 5979547.44 N 631404.80 E 11845.39 89.450 323.860 8766.12 8815.08 1607.47 N 3951.23W 5979570.92 N 631386.79 E 11874.27 89.780 323.920 8766.31 8815.27 1630.80 N 3968.25W 5979593.94 N 631369.35 E 11908.51 91.350 323.170 8765.98 8814.94 1658.34 N 3988.59W 5979621.11N 631348.51E 11930.75 91.730 323.890 8765.38 8814.34 1676.22 N 4001.81W 5979638.74 N 631334.98 E 11986.00 91.730 323.890 8763.71 8812.67 1720.83 N 4034.36W 5979682.76 N 631301.63 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 27.605° (04-May-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 299.390° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11986.00ft., The Bottom Hole Displacement is 4386.03ft., in the Direction of 293.100° (True). Alaska State Plane Zone 4 PBU_WOA R Pad Dogleg Rate (°/100ft) Vertical Section (ft) Comment 5.061 6.125 10.177 11.386 2.033 2.846 1.609 8.476 8.830 3.146 2.597 1.161 5.082 3.660 0.000 3951.86 3979.08 4007.34 4034.79 4063.23 4088.75 4119.18 4147.47 4176.28 4204.58 4231.58 4257.85 4289.09 4309.38 4359.63 PROJECTED SURVEY Continued... 17 May, 1999 - 15:26 - 6- DrillQuest Sperry-Sun Drilling Services Survey Report for R-15A Your Ref: API-500292091701 Job No. AKMM90110, Surveyed: 4 May, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_WOA R Pad Comments Measured Depth (ft) 8395.57 8401.00 11986.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8087.62 198.80 N 1534.52 W 8092.77 199.12 N 1536.21 W 8812.67 1720.83 N 4034.36 W Comment TIE-ON SURVEY WINDOW POINT PROJECTED SURVEY 17 May, 1999- 15:26 - 7- DrillQuest 5/5/99 ___ GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12547 Company Alaska Oil & Gas Cons Comm Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Color Well Job # Log Description Date Blueline Print Sepia CD-R Y-01A ~ G~.~_ ~ 99186 MCNL 990405 i 1 ..... 1 R- 15A 99204 USIT 990428 1 R-15A 99205 usIT 990429 ! A-24 pROD. PROFILE 990420 1 1 - A'-24 PROD. PROFILE W/DEFT 990420 "i 1 ,, , A-43 PRODUCTION LOG 990412 1 1 =l R-27 PROD. PROFILE 990426 1 1 ,i, ,, l,, , , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrotectnlcal Data Center MB3-3 900 E, Benson Blvd, Anchorage, Alaska 99519-6612 Date Delivered: REC,[EiIVED Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Received ~ .,./ ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson, ~ DATE: May 6, 1999 Chairman THRU: Blair Wondzell, ~1~~ FILE NO: ajrlefgf. DOC P. I. Supervisor z'/¢~'/~ FROM: John H. Spaulding0r"~ SUBJECT: Petroleum Inspecto¢ BOP Test, Nabors #7ES BPX/A R-15a Prudhoe Bay Field PTD #99~-~-5., ~ Non-Confidential May 6, 1999; I witnessed the weekly BOP test on Nabors rig #7ES drilling BPX / A well #DS R-15a in the Prudhoe Bay field. I arrived to find the rig ready and testing was started immediately. The test went very well with all BOPE components functioning properly and holding their pressure test with no leakage observed. The crew seemed well versed in their procedure, which indicated to me familiarity with this procedure. A tour around the rig showed much attention to housekeeping and preventative maintenance is standard for this rig, all in all a good looking rig. SUMMARY: I witnessed the weekly BOP test on Nabors 7ES, Test time 3.5 hours, No failures. Attachments: ajrlefgf. XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 4.5" Test: Initial Workover: X NABORS Rig No. 7ES PTD # 99-36 BPY,/A Re p.: R-15a Rig Rep.: Set @ 11,541'rnd Location: Sec. Weekly X Other DATE: 5/6/99 Rig Ph.# 659-4831 Torn Anglen Bill Bixby 32 T. 12N R. 13E Meridian Urniat MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location ok Standing Order Posted ok , BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve NA Well Sign Drl. Rig Hazard Sec. ok ok ok , Test Press. 25O/25OO P/F P I 250/5, 000 P I 25O/5, O0O P I 25O/5, O0O P I 25O/5, O0O P 2 250/5, 000 P 1 250/5, 000 P 250/5,000 MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok . H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 250/5, O0O P I 250/5, 000 P I 250/5,000 P "I 250/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 14 250/5,000 P 32 250/5,000 P I P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 @ 2200 avg, 2,800 P 1,600 p minutes 31 sec. minutes 27 sec. X Remote: X' Psig. Number of Failures: 0 ,Test Time: 3.5 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spauiding FI-021L (Rev.12/94) ajdefgf, xls TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 13, 1999 Anthonv S. Bunch Drilling Supcrintcndcnt BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit R- 15A BP Exploration (Alaska), Inc. Permit No: 99-36 Sur. Loc. 1551'NSL, 1734'EWL, Sec. 32. T12N, R13E, UM Btmhole Loc. 2085'SNL 2360%VEL, Sec. 31, T12N, RI3E, UM Dear Mr. Bunch: Enclosed is thc approved application for permit to rcdrill thc above referenced well. Thc permit to rcdrill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations arc made. Thc bloxvout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of thc injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission mav witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~nstcnson, P. E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosurc cc: Department of Fish & Game, Habitat Section xv/o cncl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALASKA ,.;~.~ AND GAS CONSERVATION CON;..r~ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill J lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single.Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field an~l Pool BP Exploration (Alaska) Inc. Plan RKB -- 48.6' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028279 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1551' NSL, 1734' EWL, SEC. 32, T12N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 1892' NSL, 325' WEL, SEC. 31, T12N, R13E, UM R-15A At total depth 9. Approximate spud date Amount $200,000.00 2085' SNL, 2360' WEL, SEC. 31, T12N, R13E, UM 04/15/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028257, 2509'I R-02, 156' away at 10678' MD 2560 11911' MD / 8791' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8400' MD Maximum Hole Angle 105° Maximum surface 2725 psig, At total depth (TVD) 8739' / 3600 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-M 771' 8250' 7950' 9021' 8672' 161 sx Class 'G' ...... 6" 4-1/2" 12.6# L-80 IBT-M 3121' 8870' 8532' 11991' 8791' 319 sx Class 'G' ,,, 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: truemeasuredvertical 92399600 feetfeet Plugs(measured) cement plug at 9196 (5/96) 0 R I Gl NA j~ Effective depth: measured 9300 feet Junk (measured) fill at 9300' MD BKB (12/89) - true vertical 8950 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20 x 30 8 cu yds 142' 142' Surface 2641' 13-3/8" 3720 cuft 2673' 2673' Intermediate 8966' 9-5/8" 1745 cu ft 8998' 8660' Production Liner 863' 7" 330 cu ft 8733' - 9596' 8408' - 9235' ' ;-' ~" '"i Perforation depth: measured 9016' - 9056' (Sag River) 9146' - 9196', 9206' - 9250' (Ivishak) true vertical subsea 8624' - 8662' (Sag River) ,:-.-::-'~-.~- 8749' - 8849' (two Ivishak intervals) !20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements iContact Engineer Name/Number: Biff Is~acson, 564-5521 Prepared By Name/Number: Terrie Hubble, 564-4628 !21. I hereby certify that the fore.(~oina~ is true and correct to the best of my knowledge Signed /~ '-~ ....... ~') A~ho,y S. Bu,oh ~.. · .'%~.._~'-'~-'=q~ Title Drilling Superintendent Date · . =. , Commission Use Only Permit Number I APl Number ApProval Dat_e,- I See cover letter . ./,O~-,_~¢~ 50-029-20917-01 "~-/-/7/'~' ¢'¢¢ for other requirements Conditions of Approval: Samples Required []Yes l~No Mud Log Required []Yes ~No Hydrogen Sulfide Measures ,~Yes []No Directional Survey Required J~Yes FINe Required Working Pressure for BOPE []2K; []3K; J~'4K; [] 5K; [] 10K; [] 15K Other: by order of Approved By ORIGINAL SIGNED-BY Commissioner the commission Date Form 10-401 Rev. 12-01-85 ~ N. Christenson Submit In Triplicate R-15Ai Permit to Drill J Well Name: I R-15Ai Sidetrack Plan Summary I Type of Redrill (producer or injector)' I Injector ISurface Location: 1551' FSL 1734' FWL S32 T12N R13E Umiat Target Location' 1892' FSL 325' FEL S31 T12N R13E Umiat Bottom Hole Location' 2085' FNL 2360' FEL S31 T12N R13E Umiat I AFENumber: 14P1273 I I Estimated Start Date: 14/15/99 I MD: I ~,991' I ITVD: 1879~' I Rig: I Nabors7ES I Operating days to complete: 123 J BF/MSL: 121.81'I I RKB: 148.6' I Well Design (conventional, slimhole, etc.): I Extended Horizontal Sidetrack I Obiective: I Restore injection into upper Zone 4 sands, targeting bypassed oil in the area. Mud Program: Intermediate Mud Properties: LSND 8.5" hole section J Density (ppg) Funnel vis Yield Point 10 sec gel 10 min gel pH Fluid Loss 10.5-10.7 45-50 18-29 4-8 8-12 9-10 6-9 Production Mud Properties: Quickdril-n 16" hole section Density (ppg) Funnel vis LSRV LSR YP pH 8.6 - 8.8 40-55 <20,000 cP 10-20 8.5-9.0 Directional: KOP: I 8400' MD Maximum Hole Angle: Close Approach Well: 105° @ 9,600' (8863' TVD) R-02 (in horizontal section, well will be shut-in 7 days prior to R-15Ai spud) Logging Program: Intermediate Production Hole(Horizontal) IDrilling: Open Hole: Cased Hole: Drilling: Open Hole: MWD / G R None Cement Bond Log in 7" Liner MWD / GR / Resistivity None R-15Ai Permit to Drill ..... Formation Markers: Formation Tops MD TVDss Comments Top Kingak Kingak - TJE 7851' Not Penetrated TJ D 8020' Kick-off Point 8400' 8043' Kick-off with-in Kingak Zone D TJC 8685' 8310' Sa~l (LCU) 9021' 8623' Shublik 9068' 8663' Top Sadlerochit 9171' 8739' Est. pore pressure 3500 psi (7.6 ppg EMW) TZ4 9171' 8739' TZ3 9424' 8835' Maximum TVDss Planned Maximum TVDss 9424' 8835' TZ2 8893' Not Penetrated HOT 8956' Not Penetrated OOWC 9023' Not Penetrated TZ1 9161' Not Penetrated Casin¢l/Tubing Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/'rVD MD/TVD 8.5" 7" 26# L-80 BTC-M 771' 8250'/7950' 9021 '/8672' 6" 4 1/2" 12.6# L-80 IBT-M 3121' 8870'/8532' 11,991'/8791' Tubing 4 1/2" 12.6# L-80 NSCT 8837' ~33'/33' 8870'/8532' NOTE: The 4 1/~,, production liner will be a Bonzai style completion with the solid cemented section covering all but the end 350 to 400' of hole section, which will be uncemented slotted liner. Cement Calculations: Liner Size 17" Intermediate I Basis: Lead: None Tail: Based on 80' shoe track, 620' of open hole with 30% excess, 150' of 9-5/8" x 7" liner lap, and 150' of 9-5/8" x 5" HWDP annulus volume. Tail TOC: At liner top - 8250' MD (7950' TVD). I Total Cement Volume: Lead I None Tail 133 bbl/185 f¢ / 161 sk of Halliburton Premium 'G' at 1 15.8 ppg and 1.15 cf/sk. Liner Size 14 1/2" Production I Basis: Tail: Based on 2570' of open hole over solid cemented portion of the liner with 50% excess, 150' of 7" x 4.5" liner lap, and 200' of 7" x 4" DP annulus volume. Tail TOC: At liner top - 8870' MD (8532' TVD). T°tal Cement V°lume: I Tail 1 67 bbl / 376 f¢ / 319 sk °f acid resistant Halliburt°npremium 'G' at 15.8 ppg and 1.18 cf/sk. R-15Ai Permit to Drill Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. · Maximum anticipated BHP: 3600 psi @ 8739' TVDss - Zone 4 · Maximum surface pressure: 2725 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/fi) · Planned completion fluid: 8.5 ppg Seawater / 6.8 ppg Diesel Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S R Pad is designated as an H2S drill site. The highest level of H2S measured on R Pad has been 400 ppm from R-12. Recent measurements taken on the drill-site were as high as 204 ppm on 6/25/98. Standard Operating Procedures for H2S precautions should be followed at all times. DRILLING CLOSE APPROACH: Well R-02 is 156' center-to-center to the planned R-15Ai on directional plan Wp3 at 10,678' MD. R-02 is planned to be shut-in for approximately 7 days prior to spud of R- 15Ai. INTERMEDIATE SECTION: · The well will kick-off in the Kingak shale and drill approximately 600' of Kingak to the top of Sag River. · Tight hole conditions have been encountered in the Kingak shales at 8000' to 8600' TVD. Mud weights as high as 11.0 ppg and the addition of shale stabilizers may be required. · The kick tolerance for the 8.5" open hole section would be 89 bbls assuming an influx at section TD of 9021'. This is a worst case scenario based on an 8.0 ppg pore pressure gradient, a fracture gradient of 12.0 ppg at the surface casing shoe, and 10.5 ppg mud in the hole. PRODUCTION SECTION: · Differential sticking will be a problem if loss circulation is occurring or if the drill string is left stationary for an extended period or time. · The kick tolerance for the 7" shoe would be an infinite influx (annular volume) assuming an influx at section TD of 11,991'. This is a worst case scenario based on a 8.0 ppg pore pressure, a minimum fracture gradient of 10.0 ppg at the 7" casing shoe, and 8.5 ppg mud in the hole. R-15Ai Permit to Drill ~ ~ ~r Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to CC- 2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal, except any metal cuttings which will be sent to the North Slope Borough. SUMMARY SIDETRACK PROCEDURES Pre-Riq Work: * Notify the field AOGCC representative with intent to plug and abandon * RIH with CTU and clean-out any fill to PBTD (top of cement plug) at 9,196' MD. Perform a cement P&A of 15.8 ppg class 'G' cement with adequate cement volume to fill the 7" liner from PBTD at 9,196' to a minimum of 100' above the top perforation at 9016' MD, plus squeeze 5 bbls to the perforations. Estimated minimum cement volume needed is 16 barrels. Note: Top of cement must be at a minimum of 89~ AOGCC compliance. Top of cement may extend up to the tubing tail as long as it ~ot interfere with the tubing cuffing operations. . Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut. Test the integrity of the cement plug and 9-5/8" casing by simultaneously pressure testing both the tubing and 9-5/8" annulus to 3500 psi for 30 minutes (tubing has two identified leaks at 6985' and 7284'). Increase tubing pressure prior to the 9-5/8" annulus to avoid possibility of tubing collapse, Note: This step should be done prior to the tubing cut to allow additional trouble-shooting if either the cement plug or 9-5/8" casing is leaking. 4. Cut the 5 Y2" L-80 tubing at 8430' MD (based upon 9/15/96 Tubing Summary). This is in the middle of the 10' pup directly on top of the 'X' nipple at 8435' MD. This cut will not be fished and is at the discretion of the Wells Group as to chemical or jet cut. Verify tubing cut with communication between tubing and annulus and freeze protect top 2200' MD with diesel, as needed. 5. Test the McEvoy 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. 6. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. Secure well. 7. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. Ri.q Operations: 1. MIRU Nabors7ES. 2. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. 4. Pull and lay down 5-1/2" tubing from E-line cut and above. 5. RU slickline and make GR/JB run to top of tubing cut. 6. RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock as desired and set on tubing stub. Mill window in 9-5/8" casing at 8400' MD. POOH. R-15Ai Permit to Drill 7. Kick-off and drill the 8-1/2" intermediate section to Top Sag @ _+9020' MD (8672' TVD). 8. Run and cement a 7", 26# intermediate drilling liner, fully cemented into the 9-5/8" casing. 9. Make up and RIH with a 6" directional assembly to the landing collar. 10. Test the 7" casing from the landing collar to surface to 3500 psi for 30 minutes. 11. Drill the 6" production section building 14°/100, to horizontal, targeting the Zone 4 sands. Drill ahead to an estimated total depth of 11,991' MD (8791' TVD). 12. Run and cement a 4 ~", 12.6# Bonzai production liner (solid liner cemented above ECP with slotted liner below) throughout the 6" wellbore. 13. Test the 4 Y2", 7", and 9-5/8" casing from the 4-1/2" landing collar to surface to 3500 psi for 30 minutes. 14. Pick up 4 ½" clean-out assembly. RIH and drill out 4-1/2" ES cementer. Displace well to clean seawater. 15. Run a USlT / CBT on e-line as deep as possible, logging the 4 ½" and 7" cement bond to the 7" liner top. 16. Run 4 ½", 12.6# L-80 NSCT completion tying into the 4 ½" liner top. 17. Test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes with 2000 psi on the tubing. 18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 19. Freeze protect the well to -2200' and secure the well. 20. Rig down and move off. Estimated Pre-rig Start Date: 04/05/99 Estimated Spud Date: 04/15/99 William Isaacson Operations Drilling Engineer 564-5521 TREE: 6" McEVOY WELLHEAD: McEVOY ACTUATOR: AXELSON R-15i Current Conditron KB. ELEV = 53.39' BF. ELEV = 21.81' I 13-3/8", 72 #/ft, 2673' L-80, BTRS SHOE DV 2621' KOP: 3900' I MAX ANGLE: 26o/5700' NOTE: TUBING LEAKS AT 6985' AND 7284' ELMD 5 1/2" 17# L-80 NSCC * ( RAN USED TBG. FOR RWO) TBG. I.D.: 4.892" CAPACITY: .0232 BBL / FT BAKER SLIDING SLEEVE J 8569' J TYPE "L"( 4.313" ID) B OT SBR W/3.813" X - PROFILE 9 5/8" BOT 3-H PKR [ 8655' I (3.956",D) 8733' 9-5/8", 47#/ft, L-80, BTRS J 8998' 5 1/2" HES X-NIPPLE I (4.562" ID) I 2201' NU I ~: I HI~ WI-EL I'IA~ NO CONTROL LINES. ALL HANGER PORTS ARE PLUGGED. 5 1/2" HES X - NIPPLE (4.562" ID) @ 8435' 9 5/8" X 5 1/2" TIW HB-BPT ~ PACKER ( 4.854" ID ) @ 8447' 5 1/2" HES X-NIPPLE (4.562" ID) @ 8482' 5 1/2" HES XN-NIPPLE (4.455" ID) @ 8505' 5 1/2" PERF. PUP (4 EA. 1/2" HOLES) @ 8506' 5 1/2" OVERSHOT ASSEMBLY @ 8518' ( MULESHOE SWALLOWS +/- 4 1/2' OF OLD 5 1/2" TaG. STUB) (4.892" ID) PERFORATION SUMMARY REF LOG: SWS- BHCS- 2-24-83 ELO~ 4 . INTERVAL OPEN SQZ'D 9016-9056' 9146-9166' 9166-9196' CEMENT/SAND PLU( 9206-9250' 9250-9266' OPEN/10-9-89 OPEN/11-23-89 OPEN/11-19-89 OPEN/Il-19-89 SQZD/9-28-89 7" , 26 #Iff, L-80, IJ4S PBTD 19550' I9596' 4 1/2 ", 12.6 #/ft, L-80 .TAILPIPE (OTIS) ( 3.813" ID) 4 1/2 ....XN" NIPPLE (OTIS) ( 3.725" ID) 4 1/2" TBG TAIL ( BOT- SOS) (ELMD) 7" MARKER JOINT FILL AT 9300' WLM. 18706' J8738' 18774' 18757' 9148' DATE 2-28-83 --LV. BY COMMENTS INITIAL COMPLETION 7/25/92 PAB CORRECTED PERFS 5/6/96 KIORPES SAND PLUG & CEMENT CAP 9/16/96 CHH RWO ( DOYON 16 ) 12/16/98 KDK LEAK DETECT - ELINE PRUDHOEBAYUNIT WELL: R-15 (13-32-12-13) BP Exploration (Alaska) TREE: 6" McEVOY WELLHEAD: McEVOY ACTUATOR: AXELSON .... R-15i Post Pre-Rig Work KB. ELEV -- 53.39' BF. ELEV: 21.81' I 13-3/8", 72 Cf/fi, 2673' L-80, BTRS SHOE IKOP: 3900' MAX ANGLE: 26o/5700' DV 2621' 5 1/2" HES X-NIPPLE ( 4.562" ID ) 2201' JNOTE: THIS WELL HAS NO CONTROL LINES. ALL HANGER PORTS ARE PLUGGED. Tubing Cut at 8430' 5 1/2" 17Cf L-80 NSCC TBG. I.D.: 4.892" CAPACITY: .0232 BBL / FT NOTE: TUBING LEAKS AT 6985' & 7284' ELMD 8569' I BAKER SLIDING SLEEVE TYPE "L" ( 4.313" ID) B OT SBR W/3.813" X - PROFILE 9 5/8" BOT 3-H PKR 8655' I (3.958" ID) 8733' 9-5/8", 47Cf/ft, L-80, BTRS I 8998' Minimum Top of Cement at 8916' MD 5 1/2" HES X - NIPPLE ( 4.562" ID) @ 8435' 9 5/8" X 5 1/2" TIW HB-BPT @ 8447' PACKER (4.854" ID ) 5 1/2" HES X-NIPPLE (4.562" ID) @ 8482' __ 5 1/2" HES XN-NIPPLE (4.455" ID) @ 8505' 5 1/2" PERF. PUP (4 EA. 1/2" HOLES) @ 8506' ' 5 1/2" OVERSHOT ASSEMBLY @ 8518' ( MULESHOE SWALLOWS +/- 4 1/2' OF OLD 5 1/2" TBG. STUB) (4.892" ID) 4 1/2" 12.6Cf/ft, L-80 TAILPIPE 4 1/2 ....X" NIPPLE I (OTIS) ( 3.813" ID) 8706' 4 1/2 ....XN" NIPPLE I (OTIS) ( 3.725" ID) 8738' 4 1/2" TBG TAIL ( BOT- SOS) I 8774' (ELMD) 18757, PERFORATION SUMMARY REF LOG: SWS - BHCS - 2-24-83 SIZE R )F INTERVAl_ OPEN R(37'1-) 3 3/8" 4 9016 - 9056' OPEN/10-9-89 .... 9146 - 9166' OPEN/Il-23-89 .... 9166 - 9196' OPEN/11-19-89 B =LOV 'CEMENT/SAND PLUI i: 3 3/8" 4 9206 - 9250' OPEN/11-19-89 2 7/8 .... 9250 - 9266' SQZD/9-28-89 PBTD 19550' 7", 26 Cf/fi, L-80, IJ4S I 9596' DATE R -_-V. BY COMMENTS 2-28-83 INITIAL COMPLETION 7/25/92 PAB CORRECTED PERFS 5/6/96 KIORPES SAND PLUG & CEMENT CAP 9/16/96 CHH RWO ( DOYON 16 ) 12/16/98 KDK LEAK DETECT - ELINE MARKER JOINT I 9148' CEMENT PLUG 5/6/96 PBTD @ 9196' ELMD FISH: 43' x 3 3/8" PERF GUN w/AUX TOOLS LOST ON 11-20-89. TOP OF FISH IS BELOW SAND FILL AT 9300' WLM. PRUDHOE BAY UNIT WELL: R-15 (13-32-12-13) BP Exploration (Alaska) TREE: 4-1/16" - 5M CIW Chrome WELLHEAD: 13 5/8" - 5M McEvoy SSH 13-3/8", 72 #/ft, L80, BTC R-15Ai Proposed Completion 4-1/2" 'X' Landing Nipple with 3.813" seal bore. I 2200' 4-1/2" 12.6# L-80, NSCT Tubing Cellar Elevation = 20.1' Base Flange = 21.81' Nabors 7ES RKB: 48.6' +fi8250' [ BAKER 7" x 9-5/8" Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger Window milled from Whipstock Top of window at +/-8400' MD Estimated top of tubing stub at +/-8430' MD 9-5/8", 47 #/ft, L80, BTC 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go ID. 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. +~-8870' I BAKER 5" x 7" Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger +/-11,591' I +/'9021' I 7", 26 #/ft, L-80, BTC-Mod 4-1/2" 12.6 #/ft, L-80, BTC-Mod w/Baker CTC ECP 4-1/2" 12.6 #/ft, L-80, BTC-Mod Slotted Liner to I +/-11,991' 7", 26 #/ft, L80, IJ4S I 9'596' ' I Date 3/31/99 Rev By WSI Comments Proposed Completion PRUDHOE BAY UNIT WELL: R-15Ai APl NO: 50-029-20917-01 Shared Services Drilling IIII II IIII I I Il I I 11111 IIiiiii i ii i iii R-15A Wp3 Prelim Plan DriHQuestTM 'PRELIMINARY 800O 8500 9000 Scale: linch = 500ff 1500 2O90 o 00 k~ . ~' I , . ~%~o~°" Vertical Section 3000 3500 I ! i I i 1500 Scale: linch = 500ft 25OO 4OOO I 3000 3500 Vertical Section , ,~o~'~; . ¢,,q-" .~.1'¢" ,. ,~o~"- -8500 ,- ~'.~ ............ ,oj~[-~ ............ ,~ ........................................ ;; ............ ..~-. ........... ;,1~ .............. .~.- ................................. ~a, 1r7.4 - ~78Z00 TVD )i:~'~i'~,~. '~' ...................... CZ~'-'~ ~'f~ o ~-~sn .w~.s. 33 Dg~;~'fff~ ........................ fC/:'g~/£~'f+~ to ....................................... ;Lr~6r.37.~,'STO0;I0'W ............. )/b~r-.-~4;~-f~- 9000 ~' ' ;,~¢¢gN,' 3'$6Z.5'5' ~ ............................................................ '6 ~-;v~: '~f'/Z?~'f~ o TZI- I i I 400o 4500 5000 Section Azimuth: 299.390° (True North) R-15A Wp3 Prelim _P. lan l..'t~C~: ' ' ..... I DrillQuest' 1200 - 800 - Scale: linch = 40Oft I -3600 I Eastings -3200 -2800 -2400 I I I R-15A Wp3 T4 ~TVD 1643.3717, 4100.10 W Sail @ 94.103° Inclination on 323.005° Azimuth DRAFT COPY PLANNING PURPOSES ONLY 8861.73ft TVD R-15A Wp3 T3 8875.60 TVD 725.88 N, 3361.55 W : I061726ft MD, 8867.98ft 1-VD Inclination on 281.291 ° Azimuth 10084.56ft MD, 8787.40ft TVD i~ 12.000°/100ft: 9859.02ft MD, MD, 8871.12ft ~t-zsa w~ 341.32 Iv, 2060.28 w I -4000 Scale: linch = 400ft I -3600 I -3200 I -2800 East~ngs I -2400 I I -2000 -1600 Reference is True North 1600 120O 800 Z 'TVD ) 8420.35fl N'~), 8110.99ff 'Ir'vD : b-"~t Dir CI, lO.O00'/lOOft :8400.001t MD, 8091.~ Sperry-Sun Drilling Services Proposal Report for R-15A WPS - R-15~ Wp3 Prudhoe Bay Unit Measured Sub-Sea Vertical Local Coordinates Global Co~rc~l~'nates Dogleg Vertical Depth incl. Azim. Depth Depth Northings Easflngs Northings Easflngs Rate Section Comment (fi) Alaska State Plane Zone 4 PBU_WOA R Pad 199.07 N 1536.01 W 5978205~.4 N 633826.75 E 1436.02 KOP: St~t Dtr ¢~ 10.000°/100ft: 8400.00ff MD, 8091.80ff TVD 20~22 N 1542.70 W 5978206~7 N ~0.05 E 10.000 1442.41 End Dtr: 8420.35ft MD, 8110.99ft TVD 204.56 N 1570.19 W 5978210.11 N 6~3792.48 E 0.000 1468.49 210.00 N 1604.71 W 5978214.93 N 633757.87 E 0.000 1501.24 214.90 N 1635.72 W 5978219,?.7 N 633726.78 E 0.000 1530.66 Sail O 20.453° Inc~inaUon o~ 278.967* Aztmulh 215.45 N 1639~2 W 5978219.76 N 633723~6 E 0.000 1533.99 220.90 N 1573.74 W 5978224.58 N 633688.65 E 0.000 1566.73 226.34 N 1708~.6 W 5978229.40 N 633654.04 E 0.000 1539.48 229.57 N 1728.74 W 5978232.26 N 633633.51 E 0.000 1618.91 Start DIr O 14.000°/100ft: 8959.34ft MD, 8~16.00ft TVD 232.56 N 1744.48 W 5978234.97 N 633617.71 E 14,~00 1634.10,. 240.93 N 1778.00 W 5978242.73 N 033584.05 E 261.31 N 1844.65 W 5978261.90 N 633517.04 E 14.000 297.71 N 1948.03 W 5978296.43 N 633413.05 E 14`003 1~A° '~ ~ 841.32 N 2060.28 W 5978338.00 N 633300.00 E 14`030 - ogicai 368.94 N 2130.49 W 5978364.35 N 633229,30 E 14`000 . 392.36 N 2193~1 W 5978386.63 N 633166.17 E 14.000 2103,49 End Dir: 9568.11ft MD,~iiiil~1.121t TVD 402.88 N ~>'~_~_-16 W 5978396.63 N 633137.04 E 0.000 2133,88 435.88 N 2312-93 W 597842796 N 033045.~ E 0.0~0 2229,16 468.87 N 2403.70 W 5978459~33 N 632954,33 E 0.000 232445 488.35 N. 245-7.28 W 5978477.84 N 632900.41E 0.000 2380.69 Start Dir O 12.000o/100ff: 9859.02ft MD, 8795.761t'I'VD 501.91 N 2494.90 W 5978490.72 N 63286255 E 12.000 2420.12 533.84 N 2&85,89 W 5978521.00 N 632771.03 E 12.000 2515.07 Target - R-15A Wp3 T2, Geological 53485 N 2588.85 W 5978521.96 N 632768.02 E 12.000 2518.14 556.66 N 2670.07 W 5978542.30 N 632686.42 E 12.000 2599.61 End DIr: 10084.56fl MD, 8787.40ft TVD 559.65 N 2685.04 W 5978545.01 N 632671.40 E 0.000 2614.12 579.00 N 2781.97 W 5978562.61 N 632574.13 E 0.000 2708.08 Continued_. 19 March, 1999 - 9'.19 - 2 - DrillQue~ Prudhoe Bay Unit 10300.00 81.299 281.291 8771.39 8819.99 103.50.91 61.299 281.291 8779.09 8827.69 10400.00 81.299 281.291 8786.52 8835.12 10500.00 81.299 281.291 8801.65 8850.25 10600.00 81.299 281.291 8816.77 8865.37 10617.26 81-299 281.291 8819.38 8867.98 Sperry-Sun Drilling Services Proposal Report for R- 15A WPS - R- 15~lW.~ p3 Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 10700.00 86.884 289..548 8827.91 8876.51 10800.04) 93.708 299.424 8827.40 8876.00 Global Coor s Dogleg Vertical Northings Eastings Rate Section Comment (ft) (ft) (o/10oft) (ft) Alaska State Plane Zone 4 PBU_WOA R Pad 598.36 N 2878.91 W 5978580.21 N 632476.86 E 0.0OO 2802.04 608.21 N 2928.26 W 5978589.17 N 632427.34 E 0.000 2849.B7 Sa~q O 81.299° Inclination o~ 281.291 ° Azimuth 617.71 N 2975.84 W 5978597.81 N 632379.59 E 0.000 2895.99 637.07 N 3072.78 W 5978615.41 N 632282.32 E 0.000 2989.95 656.42 N 3169.72 W 5978633.01 N 632165.06 E 0.000 3083.91 659.76 N 3186.45 W 5978636.05 N 632168.27 E 0.000 3100.13 Start Dir @ 12.000°/100ft: 10617.26ff MD, 8867.98ff TVD 681.64 N 3265.68 W 5978656.50 N 632088.66 E 1~.~ 3179.9~ 723.0t N 3356.52W 5978696.22N 631997.08E ~249gl~"j 3279.;~ ~ . 10805.81 94.103 300.000 8827.00 8875.60 725.88 N 3361.55 W 5978699.00 N 631992.03 E 12.~r ,~5.14/~~r~_~ R-15A Wp3 T3, Geoiocjical 10900.05 94.187 311.333 8820.17 8868.77 780.57 N 3437.75 W 5978752.30, 6319~4.83 E 12.000 ~Tai~,~ --, ~ 10997.02 94.103 323.0~}5 8813.13 8861.73 851.41 N 3503.42 W 5978821.94 N 631947.89 E 12.0003~73.~. ~Dir~ MD. 8861.73fl TVD 11300.00 94.103 1092.78 N 3685.27 W 5979059.99 N 631661.71 E 1172.44 N 3745.29 W 5979138.55 N 631600.26 E 0.000 3838.64 11400.0311494.0i394.10394.103 1247.39 N 3801.76 W 5979212.47 N 631542.44 E 0.000 3<J24.63 Stol @ 94.103' Inca 323.005° Azimuth 11500.05 94.103 1252.11 N 3805.31 W 5979217.12 N 631538.81 E 0.000 3930.04 11600.05 94.~03 1331.77 N 3865.33 W 5979295.69 N 631477.36 E 0.000 4021.43 11700.00 94.103 1411.43 N 3925.35 W 597937425 N 631415.91 E 0.050 4112-82 323.005 8791.45 ~840.05 323.005 8784.30 323.005 8777.57~.~8~.17 323.0~5 87~ 9818.59 323.005 87i~ ' 8811.43 323.005 ~5~.68 8804~28 323.005 '~,~. ;~18-52 8797.12 ~.o<~.~:~7~oo 87~o.~o 1491.10 N 3965.37 W 5979452.82 N 631354.46 E 0.000 4204.21 1570.76 N 4045.39 W 5979531.39 N 631293.01 E 0.000 4295.60 1643.37N 4100.10W 5979603.00N 631237.00E 0.000 4378.90 Total Depth :11991.15ft MD 8790.60ftTVD Target - R-15A Wp3 T4, ~..~logical 11800.00 94.103 11900.00 94.103 11991.15 94.103 19 March, 1999 - 9:19 - 3- DrlllQU~ Alaska hare. d w~[[ NAME ] R-15Ai ervlces riiling DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET IThe attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) DRILLING PERMIT Permit Documentation Prepared: ODE: '~._).JL. [. ~,,_____.~ Date: Pe~t A~~R~wed: SDE~~ nate'~/~ Per~A~~on~y~tted: ' PRE-RIG WORK Pre-Rig Memo Reviewed: SDE/ES: Date: Pre-Rig Memo Sent to Slope: ODE: Date: Pre-Rig Sundry Documentation Prepared: ODE: Date: Pre-Rig Sundry Application Reviewed: SDE/ES: Date: Pre-Rig Sundry Application Submitted: TA: D ate: [~] SUNDRY NOTICE ---]Sundry Documentation Prepared: ODE: Date: r~] Sundry Application Reviewed: SDE/ES: Date: I--] Sundry Application Submitted: TA: D ate: NOTE: IF SUNDRY IS FOR PRE-RIG WORK, USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW Reason for Sundry (Check all that apply) Abandon Change Approved Program Alter Casing Operation Shutdown Suspend Re-enter Suspended Well Repair Well Time Extension Plugging Perforate Pull Tubing Stimulate Variance ~ ?-f ii' ~'il ~./!~ i-" Other(Explain): APPROVAL TO PROCEED Approved AOGCC PermiffSundry Received TA: Date: Approval to Commence Operations SDE/ES: Date: DATE INVOICE ! cREDIT MEMO DESCRIPTION GROSS DIscOUNT NET 032699 CK032699 100. O0 100. O0 HANDLIINO INST' S/H TERRI HUBBLE X4628 ~.,: ^.^c.,:o c.,:c~ ~s ~..^~.£~ ~o. ~,4s ~sc.,.E~ ^.ov,:. ~ 100. O0 100. O0 :BP EXPLORATION (ALASKA)i:JNC~. ,I;'~':':~, ] ' ~ ' : ..... ' ;I' ::,~ 1 No., :.H :'...1...5 0:2 8:~7. I ',,:::.'oo 1:~:~.~:!,!,,:~ 'i:::, ?' :: ::, :.:.' ANCHoRAGE~ALASK~i~ 99519-6612 PAY ::,TO: Th:~' ,:::"ALASKA STATE,::,:[)EPT::,I]F REVENUE Or d ~.T' ::!i:,.:' ?300 liiii:PORCUP I:~E ;!~,":]:)~::'. ,:'.',:,:::"!. ,..,.':~'.':!,. :':: :~!: ANCHORAOE AK 99501-3120 412 ii" 3. 50 2~ ?11" m.'O I., & 20 ~,~ c~ Sm: 00~ I., I., 1. c3,, COMPANY _/~/g~ WELL NAME/~?Z~ ,~-/' ,~. -.//..~',~z' PROGRAM: exp __ dev __ WELL PERMIT CHECKLIST FIELD & POOL ~ .~/'('._~"'~) INIT CLASS ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. . 5. 6. 7. 8. 9. 10. 11. 13. ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. APPR DATE 26. 28. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to Z-~ ~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... OL AREA __ ¥ N GEOLOGY A~NUL~R DISPOSAL APPR DATE redrll .~' serv ~ wellboreseg__ UNIT# ///~/'~. ~'~"'~::~ Comments/Instructions: ann. disposal para req_ ON/OFF SHORE ~ iL,) 29. Is presence of H2S gas probable ................. i~ N 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... Y Seismic of gas zones. 32. analysis shallow ............ N 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratory/Snly] Y N 35. With proper cementing r,.gee~s, this plan (A) will contain was~ a suitable receiving zone; . ...., .... Y N (B) will not con,tarh~ate freshwater; or cause drill~aste... Y U to S U rfa,~, (C) will ~anical integrit~e well used for disposal; Y N (D) ~ f r~.p:~ffion or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N : ENGINEERING: ~ COMMISSION: JDH ~ c:\msoffice\wordian\diana\checklist Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Mar 17 15:05:14 2000 Reel Header Service name ............. LISTPE Date ..................... 00/03/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... IINKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/03/17 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 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: RUN 1 AK-MM-90110 P. SMITH M. JACKSON MAR 2 000 R-15A ~aska 0il &._~Gas Cons. 5002 92 0917 01 a~c~rage BP Exploration' (Alaska), Inc. Sperry Sun 17-MAR-00 MWD RUN 2 AK-MM-90110 P. SMITH M. JACKSON MWD RUN 3 AK-MM-90110 A. WEAVER T. ANGLEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 4 AK-MM-90110 A. WEAVER T. ANGLEN OPEN HOLE 32 12N 13E 1551 1734 .00 48.96 21.81 CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT'SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 8418.0 8.500 7.000 9046.0 6.000 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. 4. MWD RUNS 3 AND 4 ARE DIRECTIONAL WITH DUAL GAMMA R_AY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. A MADPASS WAS PERFORMED AFTER RUN 400 TO FILL IN A GAP IN THE GAMMA RAY FROM 10930' TO 10985' MD, 8870' TO 8869' TVD AND IS INCORPORATED INTO RUN 400. 6. DIGITAL AND LOG MWD DATA ARE DEPTH-CORRECTED TO THE PDC GR LOG OF 4/28/99 WITH KBE = 53.3' A.M.S.L. THIS WELL KICKS OFF FROM R-15 AT 8406' MD, 8097' TVD. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUN 2, 3, AArD 4 REPRESENT WELL R-15A WITH API# 50-029-20917-01. THIS WELL REACHED A TOTAL DEPTH OF 11986' MD, 8812' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 8095 0 ROP 8433 0 FET 9037 5 RPD 9037 5 RPM 9037 5 RPS 9037 5 RPX 9037 5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 8095 8230 8240 8245 8252 8263 8271 8279 8291 8302 8319 8334 8339 8342 8344 8360 8371 8374 8387 8415 8421 8425 8433 8436 8442 8444 8450 8456 8458 8462 8467 8471 8493 8514 8519 8530 8535 8544 8546 8549 8551 8568 8570 8574 8577 8589 8594 8604 8610 8618 8625 8631 GR 0 8100 0 8235 5 8245 0 8250 0 8256 0 8268 5 8276 0 8285 5 8295 0 8305 5 8323 5 8339 0 8341 0 8344 5 8346 5 8364 5 8374 5 8376 0 8388. 5 8419. 5 8425. 0 8427 5 8437 5 8441 5 8447 0 8448 5 8455 0 8459 0 8462 0 8466 0 8472 0 8475 0 8497 0 8518 5 8523 0 8533 5 8539 5 8548 0 8549 5 8553 5 8555 0 8571 0 8573 0 8576 5 8579 5 8592 5 8598 0 8608 5 8615 5 8622 5 8629. 0 8635. STOP DEPTH 11944.0 11983.0 11951.0 11951.0 11951.0 11951.0 11951.0 EQUIVALENT UNSHIFTED DEPTH 8641 8650 8652 8654 8665 8667 8673 8677 8683 8688 8692 8694 8698 8703 8705 8707 8712 8713 8716 8720 8730 8737 8743 8747 8755 8761 8764 8781 8782 8786 8791 8798 8824 8830 8832 8837 8843 8848 8869 8881 8885 8888 8894 8900 8902 8905 8918 8920 11983 $ 5 5 0 5 5 0 5 0 0 0 5 0 5 0 5 5 0 5 0 5 0 5 5 5 5 5 0 0 0 5 5 0 5 0 0 5 0 0 5 0 0 0 .5 0 5 0 5 5 0 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: 8645 0 8653 5 8655 5 8658 5 8668 5 8670 5 8677 5 8681 5 8687 5 8693 0 8697 5 8699 0 8702 0 8706 5 8709 5 8711 0 8716 5 8718 0 8721 0 8724 0 8734 5 8743 0 8746.0 8752 0 8758 5 8763 0 8765 0 8783 0 8784 5 8788 5 8793 5 8801 0 8827 5 8833.0 8834.5 8842.0 8847.0 8851.0 8872 0 8882 5 8887 0 8889 0 8895 5 8902 0 8906 0 8909 0 8921.0 8923.5 11986.0 BIT RUN NO MERGE TOP MERGE BASE 2 8100.0 9049.0 3 9009.5 11023.0 4 10929.5 11986.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHM- 4 1 68 12 4 RPS MWD OHM- 4 1 68 16 5 RPM MWD OHM- 4 1 68 20 6 RPD MWD OHM- 4 1 68 24 7 FET MWD HRS 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHM- RPS MWD OHM- RPM MWD OHM- RPD MWD OHM- FET MWD HRS Min 8095 0.43 9 29 0 88 1 14 0 26 0 34 0 26 Max Mean Nsam 11983 10039 7777 452.08 66.0875 7101 591.03 48.2352 7699 1950.22 12.0505 5828 1946.69 11.674 5828 2000 15.0478 5828 2000 14.3497 5828 96.32 1.65511 5828 First Reading 8095 8433 8095 9037.5 9037.5 9037.5 9037.5 9037.5 Last Reading 11983 11983 11944 11951 11951 11951 11951 11951 First Reading For Entire File .......... 8095 Last Reading For Entire File ........... 11983 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/17 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 ....... 00/03/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8100.0 9009.0 ROP 8437.0 9049.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWA~RE 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 MINIMI/M Ai~GLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY $ BOREHOLE A1W-D CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 26-APR-99 Insite 630.909973144531 Memory 9049.0 18.5 85.2 TOOL NUMBER P1298HVGW6 8.500 8418.0 KCL/Polymer 10.40 39.0 9.0 28000 10.2 .000 .000 .000 .000 .0 139.7 .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 N~me Service Unit Min Max DEPT FT 8100 9049 ROP MWD020 FT/H 2.17 363.95 GR MWD020 API 21.99 172.2~ Mean Nsam .--~Reading 8574.5 1899 8100 40.7626 1225 8437 95.2367 1819 8100 Readin9 9049 9049 9009 First Reading For Entire File .......... 8100 Last Reading For Entire File ........... 9049 File Trailer Sez-vice name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/17 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 ....... 00/03/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9009.5 10929.0 FET 9040.5 10987.5 RPD 9040.5 10987.5 RPM 9040.5 10987.5 RPX 9040.5 10987.5 RPS 9040.5 10987.5 ROP 9049.5 11023.0 $ LOG HEADER DATA DATE LOGGED: 02-MAY-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 11023.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM AlqGLE: 29.3 MAXIMUM ANGLE: 106.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P1287GRV4 EWR4 $ ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MLrD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block subotype...0 P1287GRV4 .... ~ 6.000 9046.0 Quik Drill N 8.40 40.0 9.4 1000 10.6 1.400 .800 1.050 1.950 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHM- 4 1 68 12 4 RPS MWD030 OHM- 4 1 68 16 5 RPM MWD030 OHM- 4 1 68 20 6 RPD MWD030 OHM- 4 1 68 24 7 FET MWD030 HRS 4 1 68 28 8 72.0 127.0 72.0 72.0 Name Service Unit Min Max Mean Nsam DEPT FT 9009.5 11023 10016.3 4028 ROP MWD030 FT/H 0.57 251.29 68.7567 3948 GR MWD030 API 9.29 591.03 37.601 3840 RPX MWD030 OHM- 0.88 1950.22 12.6628 3895 RPS MWD030 OHM- 1.14 1946.69 11.6614 3895 RPM MWD030 OHM- 0.26 2000 16.631 3895 RPD MWD030 OHM- 0.34 2000 15.4305 3895 FET MWD030 HRS 0.5 96.32 1.68785 3895 First Reading 9009.5 9049.5 9009.5 9040.5 9040.5 9040.5 9040.5 9040.5 Last Reading 11023 11023 10929 10987.5 10987.5 10987.5 10987.5 10987.5 First Reading For Entire File .......... 9009.5 L~st Reading For Entire Fii~ ........... 11023 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPD RPM RPS RPX FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 10929.5 10988 0 10988 0 10988 0 10988 0 10988 0 11025 5 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: STOP DEPTH 11947.0 11954.0 11954.0 11954.0 11954.0 11954.0 11986.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 04-MAY-99 Insite 0 Memory 11986.0 89.0 98.2 TOOL NUMBER P1301GRV4 P1301GRV4 6.000 9046.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : Quik Drill N 8.50 39.0 9.5 8OO 9.7 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPEP~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 2.300 1.300 1.600 3.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHM- 4 1 68 12 4 RPS MWD040 OHM- 4 1 68 16 5 RPM MWD040 OHM- 4 1 68 20 6 RPD MWD040 OHM- 4 1 68 24 7 FET MWD040 HRS 4 1 68 28 8 70.0 132.0 70.0 70.0 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHM- RPS MWD040 OHM- RPM MWD040 OHM- RPD MWD040 OHM- FET MWD040 HRS Min Max 10929.5 11986 0.43 452.08 10.36 125.69 4.92 32.09 5.04 33.74 5.05 36.41 5.7 34 0.26 19.63 Mean Nsam 11457.8 2114 76 8631 1922 26 3485 2036 10 8167 1933 11 6994 1933 11 8577 1933 12 1719 1933 1.58913 1933 First Reading 10929.5 11025.5 10929.5 10988 10988 10988 10988 10988 Last Reading 11986 11986 11947 11954 11954 11954 11954 11954 First Reading For Entire File .......... 10929.5 Last Reading For Entire File ........... 11986 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation .....- - - -".'00/03/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/03/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/03/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File