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Home My WebLink About205-159Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/14/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230418 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KU 12-17 50133205770000 208089 4/19/2023 YELLOW JACKET PERF MPU C-42 50029231960000 204028 3/22/2023 YELLOW JACKET PERF MPU E-19 50029227460000 197037 4/11/2023 YELLOW JACKET SCBL-CALIPER MPU H-15 50029232840000 205159 3/8/2023 YELLOW JACKET PERF MPU L-12 50029223340000 193011 4/2/2023 YELLOW JACKET CUT PBU 01-31 50029216260000 186132 5/1/2023 YELLOW JACKET SCBL PBU L-117 50029230390000 201167 3/5/2023 YELLOW JACKET SCBL PBU V-02 50029232090000 204077 3/27/2023 YELLOW JACKET SCBL SRU 231-33 50133101630100 223008 3/31/2023 YELLOW JACKET GPT-PERF SRU 231-33 50133101630100 223008 4/14/2023 YELLOW JACKET GPT-PLUG-PERF Please include current contact information if different from above. T37746 T37747 T37748 T37749 T37750 T37751 T37752 T37753 T37754 T37754 MPU H-15 50029232840000 205159 3/8/2023 YELLOW JACKET PERF Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.14 14:53:01 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, May 11, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC H-15 MILNE PT UNIT H-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/11/2023 H-15 50-029-23284-00-00 205-159-0 W SPT 3808 2051590 2000 416 421 416 421 245 260 247 248 OTHER P Brian Bixby 4/5/2023 MIT-IA to 2000 psi as per SUNDRY 322-633 Post RWO 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:MILNE PT UNIT H-15 Inspection Date: Tubing OA Packer Depth 589 2204 2117 2105IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230405162556 BBL Pumped:0.7 BBL Returned:0.8 Thursday, May 11, 2023 Page 1 of 1          1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Tuesday, March 28, 2023 4:25 PM To:Russell Gallen - (C) Cc:Regg, James B (OGC) Subject:RE: H-15 Initial BOPE test Attachments:Hilcorp ASR 1 03-07-23 Revised.xlsx Thanks Russell. Attached is a revised report changing the Number of Failures to 2 based on the 2 “FPs”. Please update your copy. Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Russell Gallen ‐ (C) <Russell.Gallen@hilcorp.com> Sent: Saturday, March 11, 2023 5:34 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: H‐15 Initial BOPE test Thank you, I thought my reports were flawless then I realized Phoebe was on vacation. Thanks, for the assistance & patience. Regards, Russell Gallen ASR DSM, Mobile: 907-529-7202 Office: 907-685-1266 russell.gallen@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Milne Point Unit H-15PTD 2051590 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Re-run Tubing w/ Overshot Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6,800 feet 6,767 feet true vertical 3,973 feet N/A feet Effective Depth measured 6,767 feet feet true vertical 3,974 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)3-1/2' 9.3# / L-80 / EUE 4,427' 4,001' (2) Tripoint DLH Packers and SSSV (type, measured and true vertical depth)(2) Baker Premier N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Operations Manager Contact Phone: 0 435 322-633 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Brian Glasheen Brian.Glasheen@hilcorp.com 907-564-5277 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 112' 0 Size 112' 2,729' 436 6200 0 19 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureWater-BblOil-Bbl N/A MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT H-15 Plugs Junk measured measured TVD 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 205-159 50-029-23284-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025906 1,289' Casing Conductor 3,973'6,800' 5,653' 2,899'Surface Production Liner 20" 9-5/8" 7" 112' 2,899' Length 5,653' 4,022' Burst N/A Collapse N/A 3,090psi 5,410psi 4,126, 4,390, 4,429 & 4,546 3,797, 3,977, 4,002 & 4,068 10,540psi 5,750psi 7,240psi 10,160psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.04.11 14:44:26 -08'00' David Haakinson (3533) DSR-4/13/23 RBDMS JSB 041323 Re-run Tubing w/ Overshot Service 322-633 Pull Tubing WCB 1-3-24 MILNE PT UNIT H-15 205-159 Perforate _____________________________________________________________________________________ Revised By: TDF 4/5/2023 SCHEMATIC Milne Point Unit Well: MP H-15 Last Completed: 3/9/2023 PTD: 205-159 CASING DETAIL Size Type Wt/ Grade/ Conn ID Drift Top Btm BPF 20" Conductor 91.1 / H-40 / N/A 19.124” 18.936” Surface 112' 0.355 9-5/8" Surface 40 / L-80 / BTC 8.835” 8.679” Surface 2,899’ 0.0759 7" Production 26 / L-80 / BTC 6.276” 6.151” Surface 5,653’ 0.0383 3-1/2” Liner 9.2 / L-80 / IBT 2.992” 2.867” 5,511’ 6,800’ 0.0087 TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / TC-II 2.992” 2.867” Surface 5,511’ 0.0087 JEWELRY DETAIL No Depth Item 1 4,024’ Bottom Hole Pressure Gauge –3,714’ TVD 2 4,139’ 7'' x 3.5'' Tri-Point DLH Packer 3 4,159’ X-Nipple 4 4,214’ 3.5'' WFRM w/ Dummy Valve 5 4,309’ 3.5'' WFRM w/ Dummy Valve 6 4,404’ 7'' x 3.5'' Tri-Point DLH Packer 7 4,418’ Tri-Point X-Nipple With RHC Plug 8 4,421’ 3 1/2'' Non Sealing Poor-Boy Overshot –Btm @ 4,427’ 9 4,429’ 7” x 3.5” Baker Premier Packer 10 4,486’Sta #3: Valve *****EMPTY POCKET***** 11 4,546’ 7” x 3.5” Baker Premier Packer 12 4,582’Sta #2: Valve -Dummy 1-1/2" RK latch Set 12/09/12 13 4,620’Sta #1: Valve-*****EMPTY POCKET***** 14 4,659’ 3.5” HES X-Nipple (2.813” Profile) 15 4,689’ 3.5” HES XN-Nipple (2.813” Profile/2.750”/NG)RMX sub left in hole 16 5,511’ Liner Tie Back Sleeve 17 5,520’ 4” Seal Assembly (Landed in Liner Tie Back Sleeve) TREE & WELLHEAD Tree 3-1/8” - 5M FMC Wellhead 11” x 3-1/8” 5M FMC Gen 5 w/ 3.5” TC-II T&B Thread FMC Tubing Hanger 3.0” CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-23284-00-00 Drilled & Cased & Completed by Doyon 14 – 12/19/2005 Perf Add and Recomplete by ASR #1 – 3/9/2023 OPEN HOLE / CEMENT DETAIL 20” 260 sx Arctic Set (Approx.) in a 42” Hole 9-5/8” 344 sx Arctic Set Lite, 411 sx ‘Class G’, in a 12-1/4” Hole 7” 441 sx Class ‘G’ in a 8-3/4” 3-1/2” 237 sx Class ‘G’ in a 6-1/8” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT SPF Size Date Status N 4,254’ 4,326’ 3,891’ 3,937’ 72 6 2-7/8” 3/7/2023 Open N 4,340’ 4,392’ 3,946’ 3,979’ 52 6 2-7/8” 3/7/2023 Open OA 4,493’ 4,535’ 4,040’ 4,062’ 42 5 4.5” 12/16/2005 Open OB 4,605’ 4,645’ 4,097’ 4,116’ 40 5 4.5” 12/16/2005 Open 5,255’ 5,315’ 4,098’ 4,081’ 60 5 4.5” 12/16/2005 Open OA 6,400’ 6,650’ 4,002’ 3,960’ 250 6 2.5” 12/16/2005 Open Ref Log: USIT – 12/15/2005 – TCP Perf Guns 4.5”/ PJ4505 @ 60 Deg (7” Casing) TCP Perf Guns 2.5” / PJ Omega @ 60 Deg (3-1/2” Liner) WELL INCLINATION DETAIL KOP @ 600’ Angle passes 50 deg. at 4,250’ MD Max hole angle in Tbg = 76 deg. at 4,700’ MD Max hole angle in Liner = 107 deg. at 5,108’ MD TD =6,800 (MD) / TD =3,973’(TVD) 13-3/8” Orig.DF Elev.: 70.00’/ GL Elev.: 34.20’ (Doyon 14) 7” 9 13 12 11 16 10 17 9-5/8” 1 7 PBTD =6,767’(MD)/ PBTD =3,974’(TVD) ‘OA’Sands 3-1/2” 14 ‘OA’ Sands ‘OB’ Sands 15 ‘OB’ Sands RA Tag 4,364’ RKB TOC @ 3,307’ RKB USIT 12/15/05 Packer ID= 2.875” @ 7,545’ Packer ID= 2.875” @ 7,545’ Minimum I D= 2.750” @ 4,689’ 3 2 5 6 8 4 PRESSURE DATA Date Sand Pressure 9/04/2016 OA (Upper) 2,130 psi 9/04/2016 OB 2,261 psi 9/04/2016 OA (Lower) 1,409 psi Well Name Rig API Number Well Permit Number Start Date End Date MP H-15 E-Line 50-029-23284-00-00 205-159 1/10/2023 4/5/2023 1/6/2022 - Friday No operations to report. 1/4/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/5/2022 - Thursday No operations to report. WELL S/I ON ARRIVAL. JOB SCOPE: WELLTEC TBG CUT. R/U YJ UNIT. PT PCE 300 PSI L/3000 PSI HIGH. RUN W/WELLTEC 2 3/8 '' MECHANICAL CUTTER,CUT TBG @ 4421' MD CCL TO BLADES 17.9' CCL STOP DEPTH=4403.1' MD. PRE-CUT T/I/O/ 1850/100/220, POST CUT T/IA/OA 900/400/220 psiTOOK ~ 13 MIN TO CUT IN STANDARD PRESSURE MODE, TBG CUT IN COMPRESSION. AT SURFACE TATTLE TAIL SHOWED BLADES WENT OUT TO 3.6". WELL READY FOR RWO. JOB COMPLETE. No operations to report. 1/7/2022 - Saturday No operations to report. 1/10/2023 - Tuesday 1/8/2023 - Sunday No operations to report. 1/9/2023 - Monday WELL READY FOR RWO. JOB COMPLETE MECHANICAL CUTTER,CUT TBG @ 4421' MD Well Name Rig API Number Well Permit Number Start Date End Date MP H-15 ASR 50-029-23284-00-00 205-159 1/10/2023 4/5/2023 RAN 3-1/2" X-LINE W/ 3-1/2" KEYLESS LOCK, XO, SOFT SET, DUAL SPARTEK GAUGES (batt start: 11:05). & LOC X-NIP @ 4,352' SLM (4,377' MD) FOR 25' COR, GOOD DATA ON GAUGES. RAN HES 5' MAX FIRE TUBING PUNCH (21 - .37" holes) & SHOT HOLES FROM 4,380' MD TO 4,385' MD, GOOD INDICATION OF GUN FIRING, SHOT MADE USING 25' COR FROM X-NIP @ 4,377' MD.T/I/O= 210/18/200 (Well Kill) Slickline punched holes in TBG. Pumped 15 bbls of 90* diesel followed by 190 bbls 9.0 ppg brine down TBG up IA taking returns to tank. Unable to set BPV. Freeze protected surface lines with 5 bbls 60/40. Final Whps= vac/vac/200. SET PX-PLUG SET @ 2991' SLM / 3018' MD. SET 96'' X 1-7/8'' PRONG w/ 1-3/4'' F-NECK, SET @ 2984' MD. PRESSURE UP ON TUBING TO 2500#, GOOD TEST ON PLUG, BLEED DOWN TO 0#. WELL S/I ON DEPARTURE. 3/4/2022 - Saturday Install landing joint to isolate the tubing plug. Good shell test. started testing BOPs. Test BOPE as per approve sundry, AOGCC waived witness. Test on 3-1/2" test joint screwed into hanger. Test T/ 250 psi low/ 2500 psi high F/ 5/5 charted mins. Test to test # 7. Suspend testing to R/U SL. SL on location, hold PJSM & rig up. SIMOPS: Con't to pressure test choke manifold offline. XO needed from Slick line's 4 otis to landing joint. Remove landing JT & mobilize side entry joint w/ 4" Otis connection f/ A- pad. Attempt to test, achieve one successful test (#8) on tubing plug with blinds. Degrading tests there after. Equipment on location. P/U 4-1/2" side entry joint & M/U to hanger. P/U SL with retrieveal tool & remove prong f/ PX plug. POOH. Retrieve PX plug. Plug intact. RIH w. new XX plug. & set POOH R/D SL & set off to side. Pull side entry joint f/ stack set aside. SL on standby. Cont. testing BOPE as per approve sundry, AOGCC waived witness. Test T/ 250 psi low/ 2500 psi high F/ 5/5 charted mins. complete tests #9,10,11,12. Perform accumulator drawdown. BOPE test complete. Rig up side entry joint. Rig up S/L with retrieval tool to pull XX plug. 3/5/2023 - Sunday Attempted to set 3'' BPV, did not make up to profile tried another BPV same results. wireline set plug, N/D tree/adapter checked BPV profile still could not get BPV to make up, checked lift threads with sub M/U 8 1/2 turns by hand. S/B for R/U AND BOPE test. Will investigate hanger further once out of well and at shop. 3/6/2023 - Monday 3/3/2022 - Friday T/I/O= 200/6/200 (Well Kill) Pumped a total of 13 bbls diesel down TBG up IA and down IA up TBG to tank in attempt to get circulation. Unable to establish circulation either direction. Bled TBG and IA to tank. Well support on location to finish bleeding TBG/IA. Final Whps=175/0/200 3/1/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 3/2/2022 - Thursday No operations to report. Slickline punched holes in TBG. Pumped 15 bbls of 90* diesel followed by 190 bbls 9.0 ppg brine down TBG up IA taking returns to tank. Unable to set BPV Cont. testing BOPE as per approve sundry, AOGCC waived witness Install landing joint to isolate the tubing plug. Good shell test Test BOPE as per approve sundry, AOGCC waived witness Pumped a total of 13 bbls diesel down TBG up IA and down IA up TBG to tank in attempt to get circulation. Unable to establish circulation either direction. Well Name Rig API Number Well Permit Number Start Date End Date MP H-15 ASR 50-029-23284-00-00 205-159 1/10/2023 4/5/2023 No operations to report. No operations to report. 3/11/2022 - Saturday No operations to report. 3/14/2023 - Tuesday 3/12/2023 - Sunday No operations to report. 3/13/2023 - Monday 3/10/2022 - Friday No operations to report. 3/8/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Cont. M/U E-line 2-7/8" 6 SPF, 60 degree phasing, 15 gram .34" entrance 42.46" pentation Guns, 52' total. RIH on E-line & correlate to previous gamma log. Confirm depth & fire guns. Perf depth 4,340' - 4,392' Minimal loss of fluid from perfs. Monitor well Static POOH, L/D guns. M/U E-line 2-7/8" 6 SPF, 60 degree phasing, 15 gram .34" entrance 42.46" pentation Guns, 72' total. RIH on E-line & correlate to previous gamma log. Confirm depth & fire guns. Perf depth 4,254' - 4,326' Minimal loss of fluid from perfs. Monitor well Static POOH, L/D guns. N/D E-line PCE. N/U flow / spacer spools, & cellar drip pan. Service Rig, Check fluid levels of equip. Complete spool N/U. Prep completion in pipe shed, strap & tally. Set in order injection completion. Clean & clear rig floor. P/U & M/U injection BHA, non-sealing overshot, x nipple, PKR, WFRM x2, X nipple, PKR, & BHPG. Begin to terminate tech line to down hole gauge. Tech line damaged during installation (failed test). Mobilize extra end connectors for gauge reinstall. Test cable (good test). RIH w/ 3-1/2" 9.3# L-80 EUE WF injection completion. F/ 413' T/ 1,931'. Pin on drive cable for skate came loose. Keeper pin sheared. Reinstall & check skate function. RIH w/ 3-1/2" 9.3# L-80 EUE WF injection completion. F/ 1,931' T/ 2,322' Monitor & record displacement. 3/9/2022 - Thursday RIH w/ 3-1/2" 9.3# L-80 EUE WF injection completion. F/ 2,322' T/ 4,338' Monitor & record displacement. Service Rig, check equip fluid levels. Cont. T/ RIH w/ 3-1/2" 9.3# L-80 EUE WF injection completion. T /4,416' Tag tubing stub w/ overshot. Shear first pins cont. dw shear second shear pins. Tag out to NOGO, set 5k dw. Measure for space out. Pull JTs 132, 131. M/U space out pups 3x, & JT#131 M/U hanger & terminate tech line. Final P/U WT = 39k, S/O WT = 26k. Land hanger. RILDS. Rig up to reverse circ, Close blinds & line up IA to pump truck for CI brine & freeze protect. W/ pump truck, reverse circ. 62 bbls of CI brine followed w/ 52 bbls of diesel freeze protect. ICP at 2 BPM = 1,00 psi. FCP at 2 BPM= 1,375 psi. R/D reverse circ lines. Check pressure open blinds. Well having gas breakout. Observe gas breakout increase in frequency. Close blinds let psi build, to 160 psi. open choke to gas buster for 5mins, Close choke for 10 mins, pressure built to 80 psi. Cont. with process for 4 intervals. all decreasing pressure until zero. Probable formation ballooning, due to high pressure circulation for FP. Open blinds. Drop ball & rod. Attempt to pressure up to set Stacked PKRs. Unable to hold high pressure. Determined blind rams leaking. Install landing JT in hanger. Rig up manifold in cellar for pressure testing, Install TIW in landing JT. Pressure up to 3,800 psi & held for 25 mins as per PKR rep. Service rig. perform equip. fluid checks. Pressure test tubing to 2,000 psi, after stabilizing held for 30 charted mins. Bleed tubing to 500 psi. Pressure up IA to 2,000 psi, after stabilizing held for 30 charted mins. Tubing staying consistent during test. (Good MIT). R/D testing equip. & B/D lines. Remove landing joint & L/D. Well static. P/U tee bar & install back pressure valve. Secure well. M/U E-line 2-7/8" 6 SPF, 60 degree phasing, 15 gram .34" entrance 42.46" pentation Guns, 52' total. RIH on E-line & correlate to previous gamma log. Confirm depth & fire guns. Perf depth 4,340' - 4,392' RIH w/ 3-1/2" 9.3# L-80 EUE WF injection completion M/U E-line 2-7/8" 6 SPF, 60 degree phasing, 15 gram .34" entrance 42.46" pentation Guns, 72' total. RIH on E-line & correlate to previous gamma log. Confirm depth & fire guns. Perf depth 4,254' - 4,326' Pressure test tubing to 2,000 psi, after stabilizing held for 30 charted mins. Bleed tubing to 500 psi. Pressure up IA to 2,000 psi, after stabilizing held for 30 charted mins. Tubing staying consistent during test. (Good MIT). Pull JTs 132, 131. M/U space out pups 3x, & JT#131 M/U hanger & terminate tech line. Final P/U WT = 39k, S/O WT = 26k. Land hanger. RILDS. RIH w/ 3-1/2" 9.3# L-80 EUE WF injection completion Cont. T/ RIH w/ 3-1/2" 9.3# L-80 EUE WF injection completion. T /4,416' Tag tubing stub w/ overshot. Shear first pins cont. dw shear second shear pins. Tag out to NOGO, set 5k dw. Measure for space out Drop ball & rod. Attempt to pressure up to set Stacked PKRs. Unable to hold high pressure. Determined blind rams leaking. Install landing JT in hanger. Rig up manifold in cellar for pressure testing, Install TIW in landing JT. Pressure up to 3,800 psi & held for 25 mins as per PKR rep. Well Name Rig API Number Well Permit Number Start Date End Date MP H-15 ASR 50-029-23284-00-00 205-159 1/10/2023 4/5/2023 No operations to report. No operations to report. 4/8/2022 - Saturday No operations to report. 4/11/2023 - Tuesday 4/9/2023 - Sunday No operations to report. 4/10/2023 - Monday 4/7/2022 - Friday No operations to report. 4/5/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary T/I/O=416/589/245 AOGCC MIT-IA to 2105 psi Passed. (Witnessed by Brian Bixby) Pressured up IA to 2204 psi with .70 bbls of 120* diesel. 1st 15 min IA lost 87 psi. 2nd 15 min IA lost 12 psi for a total loss of 99 psi in 30 min. Bled back ~ .80 bbls. Final Whps=415/589/245 4/6/2022 - Thursday No operations to report. AOGCC MIT-IA to 2105 psi Passed. (Witnessed by Brian Bixby) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:ASR 1 DATE:3/7/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2051590 Sundry #322-633 Operation:Drilling:Workover:x Explor.: Test:Initial:x Weekly:Bi-Weekly:Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1288 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2-7/8" x 5" VBR P Flow Indicator P P #2 Rams 1 Blinds FP Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result HCR Valves 1 2 1/16"P System Pressure (psi)3000 P Kill Line Valves 2 2 1/16"FP Pressure After Closure (psi)1800 P Check Valve 0 NA 200 psi Attained (sec)16 P BOP Misc 0 NA Full Pressure Attained (sec)52 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):4 / 2212 PSI P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 20 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:2 Test Time:15.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/5/23 20:00 Waived By Test Start Date/Time:3/6/2023 15:00 (date)(time)Witness Test Finish Date/Time:3/7/2023 6:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Hilcorp Test # 3 High test failed, greased K2 vale (pass). Test # 9 Blinds, High test failed, Tubing plug leaking. Changed out (pass) Precharge psi- 1000psi C.Greub / M. Boord Hilcorp Alaska LLC A.Haberthur / R. Gallen MPU H-15 Test Pressure (psi): askans-asr-toolpushers@hilcorp.co ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022)2023-0307_BOP_Hilcorp_ASR1_MPU_H-15           J. 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^ĂŶĚ WƌĞƐƐƵƌĞ ϵͬϬϰͬϮϬϭϲ K;hƉƉĞƌͿ Ϯ͕ϭϯϬƉƐŝ ϵͬϬϰͬϮϬϭϲ K Ϯ͕ϮϲϭƉƐŝ ϵͬϬϰͬϮϬϭϲ K;>ŽǁĞƌͿ ϭ͕ϰϬϵƉƐŝ DŝůŶĞWŽŝŶƚ ^ZZŝŐϭKW %23( Εϰ͘ϰϴΖ Εϰ͘ϱϰΖ Ϯ͘ϬϬΖ ϱϬϬϬη ϮͲϳͬϴΗǆϱΗsZ ϱϬϬϬη ůŝŶĚ ^͕ϭϭϱDyϳϭͬϭϲϱD;/ĨEĞĞĚĞĚͿ ϮϭͬϭϲϱD<ŝůů>ŝŶĞsĂůǀĞƐ ϮϭͬϭϲϱDŚŽŬĞ>ŝŶĞsĂůǀĞƐ ,ZDĂŶƵĂůDĂŶƵĂůDĂŶƵĂů ^ƚƌŝƉƉŝŶŐ,ĞĂĚ Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/12/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221212 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU H-15 50029232840000 205159 11/28/2022 Halliburton MFC24 Please include current contact information if different from above. By Meredith Guhl at 3:02 pm, Dec 12, 2022 T37369 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.12 15:04:31 -09'00' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVEI) OCT 3 0 2019 1. Operations Abandon LJ Plug Perforations Ll Fracture StimulateLJ Pull Tubing LJ f t wn Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casin 9 ❑ Change Approve Program ❑ Plugfor Redrill ❑ arforate New Pool ❑ Repair Well❑ Re-enter Susp Well ❑ Other: Surface Casing Repair ❑✓ 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Stratigraphic❑ Exploratory ❑ Service E] 205-159 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-23284-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025906 MILNE PT UNIT H-15 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT/ SCHRADER BLUFF OIL 11. Present Well Condition Summary: Total Depth measured 6,800 feet Plugs measured 6,767 feet true vertical 3,973 feet Junk measured N/A feet 5,680, 5,853 & Effective Depth measured 6,767 feet Packer measured 5960 feet 3,875, 4,007 & true vertical 3,974 feet true vertical 4,088 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 2,899' 9-5/8" 2,899' 2,729' 5,750psi 3,090psi Production 5,653' 7" 5,635' 4,022' 7,240psi 5,410psi Liner 1,289' 3-1/2" 6,800' 3,973' 10,160psi 10,540psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.2 / L-80 / TC -II 5,511' 4,032- (2) GT Dual Pkr Packers and SSSV (type, measured and true vertical depth) FH Pkr N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 0 0 0 3 Subsequent to operation: 0 0 542 110 979 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory❑ Development❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. WeII Status after work: Oil LJ Gas WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-356 Authorized Name: Chad Helgeson Contact Name: Wyatt Rivard V`I L Authorized Title: Operations Manager Contact Email: wrlyard(7tilcorp.Cprn Authorized Signature: Date: 10/17/2019 Contact Phone: 777-8547 Form 10-404 Revised 4/2017 /i- J q 'e//01 RBDMSL" NOV 0 12019 Submit Original Only Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP H-15 N/A 50-029-23284-00-00 205-159 8/15/2019 1 10/11/2019 Daily Operations. 8/14/2019- Wednesday No operations to report. 8/15/2019 - Thursday WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE W/LRS 300L/2,500H, DRIFTTBG WITH 2.80" GAUGE RING DOWN TO 4,500' SLM, TOOLS FALL SLOW AFTER 2,600'. HAVE LRS DISPLACE TBG WITH 38bbls OF DIESEL @ .5bpm. SET 3-1/2" XX -PLUG IN X - NIP @ 4377' MD, (oal: 29", 8x1/8" ports). PRESSURE UP ON PLUG TO 2,000psi, MONITOR FOR 15min, PLUG HOLDING, HAVE LRS BLEED BACK TBG TO 0#. 8/16/2019 - Friday No operations to report. 8/17/2019 -Saturday No operations to report. 8/18/2019 -Sunday No operations to report. 8/19/2019 - Monday No operations to report. 8/20/2019 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP H-15 N/A 50-029-23284-00-00 205-159 8/15/2019 10/11/2019 Daily Operations. 9/4/2019- Wednesday No operations to report. 9/5/2019 -Thursday No operations to report. 9/6/2019 - Friday No operations to report. 9/7/2019 - Saturday No operations to report. 9/8/2019 -Sunday Fill out regulated CSE and Hot work permits. Travel to H-15. Sign off permits and hold PJSM. Wellhouse and injection line has been pulled, well secured, and T/I/0 are 0 psi. Begin exposing the 9-5/8" Casing - Cut top 28" of 20" conductor off in 2 separate cuts cleaning out solids between the conductor and casing before, between, and after each cut. Wire wheel casing and find hole. Perform UT profile of the 9-5/8" casing directly below the wellhead - top 5' of the 9-5/8" casing to evaluate extent of corrosion, determine viability of external patch, and determine if more casing needs exposed to find good pipe. 9/9/2019 - Monday No operations to report. 9/10/2019 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP H-15 N/A 50-029-23284-00-00 205-159 8/15/2019 10/11/2019 9/25/2019- Wednesday No operations to report. 9/26/2019 -Thursday No operations to report. 9/27/2019 - Friday No operations to report. 9/28/2019 -Saturday No operations to report. 9/29/2019 -Sunday AYF cut off outer insulated conductor and additional —24" of 20" conductor both in two separate cuts. ATF then removed excess concrete to expose the pipe. 9/30/2019 - Monday ATF buffed the 9-5/8 surface casing, Mistras perfomed UT and find nominal thickness casing at 72" below flutes (27" below leak site). 10/1/2019 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP H-15 N/A 50-029-23284-00-00 205-159 8/15/2019 10/11/2019 10/2/2019- Wednesday After post weld cool down period, Mistras inspected on a grid to ensure competency for welds of the wedding rings. NES began prepping for the installation of the clamshell. 10/3/2019 - Thursday NES welder performed the welding of the clamshell patch, completing the surface casing patch. 10/4/2019 - Friday T/1/0=ssv/vac/vac MIT OA inconclusive(Post Conductor Repair) (PT surface lines 250/1,500 psi) Unable to hold pressure above 270 psi due to likely open OA shoe. Conducted rolling test at 900 psi/2bpm and saw no fluids confirming patch had restored surface casing integrity. FWH Ps=ssv/vac/270. 10/5/2019 -Saturday No operations to report. 10/6/2019 -Sunday No operations to report. 10/7/2019 - Monday No operations to report. 10/8/2019 -Tuesday No operations to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP H-15 N/A 50-029-23284-00-00 205-159 8/15/2019 10/11/2019 10/9/2019 - Wednesday No operations to report. 10/10/2019 - Thursday WELL 5/1 ON ARRIVAL, NOTIFY PAD-OP, PT PCE W/LRS 300L/2,500H. EQUALIZE 3-1/2 XX-PLUG @ 4,377' MD. PULL 3-1/2 XX-PLUG @ 4,377' MD, RECOVER PACKING AND NUBBINS. 10/11/2019 - Friday Conductor ( Top Job ) vac out about 3 ft of water using 1" hose till conductor was dry, Hose was 6 ft down from mud ports when fluid had stop vacing . Conductor was filled within 6 inches of top of conductor with cement . Level all the way around also Mud ports were capped. Took 1/2 yard of cement . 10/12/2019 -Saturday No operations to report. 10/13/2019-Sunday No operations to report. 10/14/2019 - Monday No operations to report. 10/15/2019-Tuesday No operations to report. Q 9/7/19 Begin excavation of concrete and removal of water via Vacuum truck to desired depth for conductor removal. Prep for conductor removal. 9/8/19 Begin exposing the 9-5/8" Casing. Well house and injection line has been pulled, well secured, and T/I/0 are 0 psi. Cut top 28" of 20" conductor off in 2 separate cuts cleaning out solids between the conductors and casing before, between, and after each cut. Perform UT profile of the 9-5/8" casing directly below the wellhead. Hole located. 9/29/19 AYF cut off outer insulated conductor and additional —24" of 20" conductor both in two separate cuts. ATF then removed excess concrete to expose the pipe. 9/30/19 ATF buffed the 9 5/8 surface casing, Mistras will UT the pipe and provide a report of their findings. 10/1/19 NES welders installed the wedding bands at the 12" & 72" marks. 10/2/19 Mistras inspected on a grid to ensure competency for welds of the wedding rings. NES began prepping for the installation of the clamshell. 10/3/19 NES welder continued the welding of the clamshell; completing the surface casing patch. 10/4/19 NES Cut and coped the 20" replacement halves of conductor. Prepped for installation. Performed MIT -OA (inconclusive). Unable to hold pressure above 270 psi due to likely open OA shoe. Conducted rolling test at 900 psi/2bpm and saw no fluids confirming. patch had restored surface casing integrity. 10/5/19 NES welded 20" conductor halves in place. Mistras inspected the welds to ensure competency. 10/11/19 Conductor ( Top Job ) vac out about 3 ft of water using 1" hose till conductor was dry, Hose was 6 ft down from mud ports when fluid had stop vacing . conductor was filled within 6 inches of top of conductor with cement . Level all the way around . also ( Mud ports were capped ). Took 1/2 yard of cement . 10/25/19 MPU Well Support topped off conductor with Black Goo and it took 3.5 gallons to do so. No issues THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, Milne Pt Unit H-15 Permit to Drill Number: 205-159 Sundry Number: 319-356 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Jessiielowski Commissioner DATED this 30 day of July, 2019. RBDMS!)9t✓UL 312019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 JUL 26 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casingg p Q ❑ Other: Surface Casing Repair 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ Stratigraphic ❑ Service 0 - 205-159 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-23284-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No ❑� MILNE PT UNIT H-15 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025906 MILNE POINT / SCHRADER BLUFF OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6,800' 3,973' 6,767' 3,974' 956 6,767' N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 2,899' 9-5/8" 2,899' 2,729' 5,750psi 3,090psi Production 5,653' 7" 5,653' 4,022' 7,240psi 5,410psi Liner 1,289' 3-1/2" - 6,800' 3,973' 10,160psi 10,540psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 3-1/2" 9.2 / L-80 / TC -ll 5,511 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): GT Dual Pkr, GT Dual Pkr & FH Pkr and N/A 5,680(MD)/ 3,875(TVD), 5,853(MD)/ 4,007(TVD) & 5,960(MD)/ 4,088(TVD) and N/A 12. Attachments: Proposal Summary Wellbore schematic LJ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service Q - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/10/2019 OIL ❑ WINJ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: Wyatt Rivard Wk- V7- 2Authorized AuthorizedTitle: Operations Manager Contact Email: wrivard hilcor .Com / '' [[ Contact Phone: 777-8547 , Authorized Signature: Cl•. � n�� Date: 7/26/2019 COMMISSION USE ONLY Conditions of appy : Notify Commission so that a representative may witness Sundry Number: ^ !✓l J S co Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: [� / n L � +F w nG i q,sil , ✓ (I RBDMS�JUL 3 12019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ �/ l / �,,/ Spacing Exception Required? Yes EJL.t7 No Subsequent Form Required: B —W,4 () ,4 APPROVED BY � Approved by: COMMISSIONER THE COMMISSION Date: ')PO )47- ORIGINAL ,k / -7,y./t� Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate U Hiburn Alaska. Lb Surface Casing Leak Repair Well: MPH -15 PTD:2051590 API: 50-029-23284-00-00 Well Name: MPH -15 API Number: 50-029-23284-00-00 Current Status: SI Rig: None Estimated Start Date: 8/10/19 Estimated Duration: 5 Reg.Approval Req'std? Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 2051590 First Call Engineer: Wyatt Rivard (907) 777-8847 (0) (509) 670-8001 (M) Second Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) Current Bottom Hole Pressure: Max Bottom Hole Pressure: Max. Proposed Surface Pressure: Recent SI Surface Pressure: Brief Well Summary: 1,356psi @ 4,000' TVD 1,356psi @ 4,000' TVD 956 psi 250 psi (Based on SBHPS on 9/4/16) (Based on SBHPS on 9/4/16) (Max BHP -(0.1 psi/ft x 10,000 TVD) (Taken on 6/1/19) MPH -15 is a Schrader bluff water injector. The well was SI on 5/30/19 following a confirmed hydrocarbon leak from the conductor. WHPs during the recent leak were T/I/O = 1541/0/200. The leak continued to flow until the OA was bled to — 0 psi. Once SI, the OA would pressure to `200 psi and resume leaking. On 6/1/19 9 ppg low freeze point brine was pumped into the OA followed by 2 bbls diesel and OA remained at 0 psi. Objective: Remove conductor and weld an external surface casing patch to restore OA integrity. Notes On Wellbore Condition: • The well had a passing MIT -IA to 2000 psi on 3/14/18 and has had no indications of TxIA or IAxOA communication since. • Well has an open OA shoe • Surface casing leak is —17" below the Conductor, above the cellar floor, 1 • Surface casing was hung with a fluted mandrel hanger that sits above the landing ring indicating that conductor is not supporting any well weight. • In August 2011, the cement top had been confirmed at .5 ft from the top of conductor and then capped with RG -2401 "Blue Goo". Procedure: Pre -Sundry Work Slickline 1. MIRU SL unit. 2. Pressure test to 300psi low and at least 2000 psi high. 3. RIH and set 3-1/2" XX plug in profile at 4377' MD a. Pressure test to —2000 psi and confirm holding. b. Bleed down the tubing pressure to 0 psi. 4. RDMO Prep Work 5. Disconnect flowline and instrumentation. 6. Verify tubing, IA and OA pressures have been bled to Opsi. 7. Sniff cellar and adjacent area with multi -gas meter for LEL, CO, H2S and 02. Ensure confined space, egress and ventilation is adequate for operations Surface Casing Leak Repair Well: MPH -15 PTD:2051590 llil.m Alaska. Lb API: 50-029-23284-00-00 Vac out gravel from well cellar down to cellar liner to remove residual hydrocarbons. Cut cellar floor and vac out additional 3-4' of fill to provide more space for conductor removal. a. Do not exceed 4' of depth below cellar floor. 8. Install fire blankets around the conductor landing ring to protect surface casing holes from hot machining debris. Sundry Work (Approval required to proceed) Surface Casing Repair 9. Sniff cellar and adjacent area with mutli-gas meter for LEL, CO, H25 and 02. Ensure confined space, egress and ventilation is adequate for operations 10. Drill or cut holes in the conductor roughly 2 ft and 5 ft below the landing rig to ensure adequate space for surface casing patch. Perform UT to confirm adequate surface casing thickness to proceed with heating/welding the SC. 11. Remove cement as needed to confirm weldable, uncorroded surface casing at hole depth before cutting conductor. 12. Flush conductor with water from the landing ring while taking fluid returns from the lower inspection holes. Flush until clean returns are observed. 13. Install N2 purge equipment for the conductor and OA. a. Use of an N2 cap/purge will be determined on site, prior to proceeding, with accurate gas readings and fluid returns observed. b. Prior to cutting conductor, install continuous gas monitoring for LEL's from the conductor. c. Hot work permit to outline if adjacent wells will require shut in as part of safety mitigations. 14. Cut and remove conductor from above the 5 ft inspection holes. a. Primary cutting option is to use an air arc torch but the Hot Work Permit for this portion of the job will dictate if an alternative cutting method will be required. b. Two horizontal cuts (below landing ring and one at bottom of conductor section) and two vertical cuts will be required to remove the conductor. Alternately, if there is not sufficient room to drop the landing ring below the patch area, the vertical cut may be carried all the way up and through the landing ring. 15. Chip away excess cement from the surf!a� ing. Buff and prepare surface casing for inspection and welding. 16. Inspection department to UT the exposed surface casing. a. Inspect for any additional holes below landing ring. b. Areas to patch to be identified marked and inspected on a grid to ensure competency for welds 17. Install 11.125" ID clamshell patch. b. Note that there is a 3.25' pup joint connecting the starting head with a collared connection that may need to be straddled to weld to good metal above and below leak. c. Circumferentially weld band/spacer rings to the surface casing for the upper and lower patch areas I. Band material: A516-70, ID=9.625" thickness=.75". d. Install clamshell patch and weld circumferentially to the machined flutes/ring and vertically to the other patch half. ii. Patch material: A516-70, ID=11.125" thickness=1/2". 18. Inspect the welds to ensure competency. � 19. Conduct an MIT -OA to 1000psi to confirm SC integrity. Q�P, 20. Re -install flowline and instrumentation U flil.m Alaska. M Slickline 21. MIRU SL unit. 22. Pressure test to 300psi low and at least 2000psi high. 23. RIH and pull 3-1/2" XX plug from 4377' md. 24. RDMO 25. Turn well back over to operations Post Repair Work 26. Weld cut conductor halves back onto conductor. 27. Reinstall well house and backfill gravel over cellar liner. 28. Cement SC by Conductor Annulus back to within 1ft of conductor top. 29. Install Corrosion Inhibitor in SC by Conductor Annulus up to the conductor top. Surface Casing Leak Repair Well: MPH -15 PTD:2051590 API: 50-029-23284-00-00 Pr Ata Wallace, Chris D (CED) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, May 30, 2019 4:38 PM To: Wallace, Chris D (CED) Cc: Schwartz, Guy L (CED); Regg, James B (CED); Darci Horner - (C); Chad Helgeson; David Haakinson; Alaska NS - Milne - Wellsite Supervisors; Alaska NS - Wells Foreman Subject: RE: Milne Point Injector MPH -15 (PTD # 2051590) Surface Casing Leak 0 Milne Point Injector MPH -15 (PTD # 2051590), appears to have a surface casing leak. Diesel returns were observed in the conductor when Operations began fluid packing the OA in preparation for the diagnostic MIT. Returns stopped once the OA was bled back to -150 psi. The well will remain shut-in until the surface casing leak can be repaired. Thank You, Wyatt Rivard I Well Integrity Engineer lHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivardRhilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Wyatt Rivard Sent: Thursday, May 30, 2019 10:03 AM To:'Wallace, Chris D (DOA)' <chris.waIlace @a laska.gov> Cc:'Schwartz, Guy L (DOA' <guy.schwartz@alaska.gov>; 'Regg, James B (DOA)' <jim.regg@alaska.gov>; Darci Horner - (C) <dhorner@hilcorp.com>; Chad Helgeson <chelgeson@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com>; Alaska NS - Milne - Wellsite Supervisors <Alaska NS -M ilne-WellsiteSupervisors@hilcorp.com>; Alaska NS - Wells Foreman <Alaska NS-WellsForema n@hilcorp.com> Subject: Milne Point Injector MPH -15 (PTD # 2051590) Shut -In for Hydrocarbons in Conductor Annulus 02 Milne Point water injector MPH -15 was observed this morning with hydrocarbons in the cellar and surface casing by conductor annulus. The well was shut-in and will remain shut-in until diagnostics can determine the cause of the hydrocarbons in the conductor. TIO pressures prior to shut-in were 1320/80/160. A TIO plot is attached for reference. Path Forward - Operations (1) Attempt to MIT -OA to 1000 psi with diesel. Note - the well has not previously had an MIT -OA and may have an open shoe with top of production casing cement -500' below the surface casing. a. Monitor surface casing by conductor annulus for bubbling and discontinue MIT if any observed (2) If MIT -OA cannot be obtained, depress OA fluid level with N2 bottles and evaluate for potential surface casing leak. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-85471 C: (509)670-80011 wrivard(a)hilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 Wallace, Chris D (CED) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, May 30, 2019 10:03 AM To: Wallace, Chris D (CED) Cc: Schwartz, Guy L (CED); Regg, James B (CED); Darci Horner - (C); Chad Helgeson; David Haakinson; Alaska NS - Milne - Wellsite Supervisors; Alaska NS - Wells Foreman Subject: Milne Point Injector MPH -15 (PTD # 2051590) Shut -In for Hydrocarbons in Conductor Annulus Attachments: H-15 TIO.XLSX ZM Milne Point water injector MPH -15 was observed this morning with hydrocarbons in the cellar and surface casing by conductor annulus. The well was shut-in and will remain shut-in until diagnostics can determine the cause of the hydrocarbons in the conductor. TIO pressures prior to shut-in were 1320/80/160. A TIO plot is attached for reference. Path Forward — Operations (1) Attempt to MIT -OA to 1000 psi with diesel. Note - the well has not previously had an MIT -OA and may have an open shoe with top of production casing cement -500' below the surface casing. a. Monitor surface casing by conductor annulus for bubbling and discontinue MIT if any observed (2) If MIT -OA cannot be obtained, depress OA fluid level with N2 bottles and evaluate for potential surface casing leak. Thank You, Wyatt Rivard I Well Integrity Engineer lHilcorp Alaska, LLC 0: (907) 777-8547 1 C: (509)670-80011 wrivard r hilcorp.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,March 20,2018 TO: Jim Regg P.I.Supervisor (I U SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC H-15 FROM: Bob Noble MILNE PT UNIT H-15 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT H-15 API Well Number 50-029-23284-00-00 Inspector Name: Bob Noble Permit Number: 205-159-0 Inspection Date: 3/12/2018 Insp Num: mitRCN180312164910 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well-1 H-15 .11Type Inj W'ITVD 1 4002 Tubing 1040 1040` 1040 1040' PTD 2051590 Type Test SPT Test' psi -- -. ' 1 1500 - IA 156 2026 ` 1948 j 1941 " yp -- — BBL Pumped: 1.1 ` BBL Returned: 12 OA 228 - 380 285 j 255 " Interval 's 4YRTST JP/F P Notes: SCANNED Tuesday,March 20,2018 Page 1 of 1 STATE OF ALASKA AKA OIL AND GAS CONSERVATION COM ISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate❑ Pull Tubing U Operations shutdown ❑ Performed: Suspend Li Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: MBE Treatment ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development ❑ Exploratory ❑ 205-159 3.Address: Stratigraphic❑ Service 0 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-23284-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 MILNE PT UNIT SB H-15 RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNEPOINT/SCHRADERBLUFFOIL OCT 10 2016 11.Present Well Condition Summary: Total Depth measured 6,800 feet Plugs measured 6,767 AOGCC true vertical 3,973 feet Junk measured N/A feet 5,680,5,853& Effective Depth measured 6,767 feet Packer measured 5960 feet 3,875,4,007& true vertical 3,974 feet true vertical 4,088 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' _x.112., __. j �....4II+A. N/A Surface 2,899' 9-5/8" 2,899' 2,729' 5,750psi 3,090psi Production 5,653' 7" 5,635' 4,022' 7,240psi 5,410psi Liner 1,289' 3-1/2" 6,800' 3,973' 10,160psi 10,540psi Perforation depth Measured depth See Attached Schematic SCANNED FEB True Vertical depth See Attached Schematic 2 2IU i7 Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2/L-80/TC-II 5,511' 4,032' (2)GT Dual Pkr Packers and SSSV(type,measured and true vertical depth) FH Pkr N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 20 0 Subsequent to operation: 0 0 480 0 1,054 14.Attachments(required per 20 AAC 25.070,25..071,&25.283) 15.Well Class after work: Daily Report of Well Operations Li Exploratory[1] Development Service ❑✓ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas U WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑✓ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-407 SIP Contact Stan Porhola Email sporholahilcorp.com Printed Name Bo York Title Operations Engineer Signature Phone 777-8345 Date 10/7/2016 /o--lr KBDMS Lt OCT 1 0 2016 711--/K /Form 10-404 Revised 5/2015 Oth Submit Original Only H . • Milne Point Unit Well: MP H-15 • SCHEMATIC Last Completed: 12/19/2005 Hilcora Alaska,LLC PTD: 205-159 TREE&WELLHEAD Orig.DF Elev.:70.00GL Elev.:34.20'(Doyon 14) '/ Tree 3-1/8"- 5M FMC L'3.4 Wellhead 11"x 3-1/8"5M FMC Gen 5 w/3.5"TC-II T&B ThreadFMC Tubing Hanger 3.0"CIW"H"BPV Profile g/g ( OPEN HOLE/CEMENT DETAIL w" 4 20" 260 sx Arctic Set(Approx.)in a 42"Hole ` 9-5/8" 344 sx Arctic Set Lite,411 sx'Class G',in a 12-1/4"Hole s t•o _ 7" 441 sx Class'G'in a 8-3/4" r3, i 3-1/2" 237 sx Class`G'in a 6-1/8" }r J w+ CASING DETAIL '14 Size Type Wt/Grade/Conn ID Drift Top Btm BPF LI 9-5/8' di 20" Conductor 91.1/H-40/N/A 19.124" 18.936" Surface 112' 0.355 9-5/8" Surface 40/L-80/BTC 8.835" 8.679" Surface 2,899' 0.0759 7" Production 26/L-80/BTC 6.276" 6.151" Surface _ 5,653' 0.0383 3-1/2" Liner 9.2/L-80/IBT 2.992" 2.867" 5,511' 6,800' 0.0087 TUBING DETAIL 3-1/2" Tubing 9.2/L-80/TC-Il 2.992" 2.867" Surf 5,511' 0.0087 `' WELL INCLINATION DETAIL TOC©3,307'RKB': USIT 12/15/05 _ ', KOP @ 600' 3. Angle passes 50 deg.at 4,250'MD ,, 5 Max hole angle in Tbg=76 deg.at 4,700'MD Max hole angle in Liner=107 deg.at 5,108'MD f yy RATag 4,364 R, JEWELRY DETAIL ,77 4 16 IA 2 No Depth Item l 4 4 1 3,018' 3.5"HES X-Nipple(2.813"Profile) Packer lt2.875" g 2 4,377' 3.5"HES X-Nipple(2.813"Profile) @7,545' '-" ' 3 3 4,429' 7"x 3.5"Baker Premier Packer a: th 4 GLM DETAIL:3.5"x 1.5"Ca mco MMG w/1.5"RK Latch 'OA'Sands . 4 4,486' Sta#3:Valve-300 bwpd/SET 1-1/2"SINGLE SPARTEK GAUGE IN ST#3 Packer ID 2.875" ,-, e� _'5 5 4,546' 7"x 3.5"Baker Premier Packer @7,545 4 _ 1' 6 4,582' Sta#2:Valve-Dummy/Date-12/09/2012 ., 6 ak 7 4,620' Sta#1:Valve-500 bwpd/SET 1-1/2"SINGLE SPARTEK GAUGE SER#4139 IN ST#1 ' ff Sands - 8 4,659' 3.5"HES X-Nipple(2.813"Profile) 9 4,689' 3.5"HES XN-Nipple(2.813"Profile/2.750 No Go) 7 '04tal 10 5,511' Liner Tie Back Sleeve M 11 5,520' 4"Seal Assembly(Landed in Liner Tie Back Sleeve) 8 4 1w PERFORATION DETAIL NInimum II:: 2.750",° @ass9 M "R Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT SPF Size Date Status v f 3 i 9 P' OA 4,493' 4,535' 4,040' 4,062' 42 5 4.5" 12/16/2005 Open S 5 * 1 OB Sands = OB 4,605' 4,645' 4,097' 4,116' 40 5 4.5" 12/16/2005 Open 5,255' 5,315' 4,098' 4,081' 60 5 4.5" 12/16/2005 Open OA 6,400' 6,650' 4,002' 3,960' 250 6 2.5" 12/16/2005 Open Vj= V 10 Ref Log:USIT-12/15/2005-TCP Perf Guns 4.5"/P.14505 @ 60 Deg(7"Casing) om. 'e 11 TCP Perf Guns 2.5"/PJ Omega @ 60 Deg(3-1/2"Liner) GENERAL WELL INFO API:50-029-23284-00-00 Drilled&Cased&Completed by Doyon 14-12/19/2005 'OA'Sands — 3-1/2"A 0 TD=6,800(MD)/TD=3,973'(TVD) PBTD=6,767'(MD)/PBTD=3,974'(TVD) Revised By:BK 9-9-2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP H-15 Pump Truck 50-029-23284-00-00 205-159 9/16/16 9/23/16 Daily Operations: 9/14/2016 -Wednesday No activity to report. 9/15/2016 -Thursday No activity to report. 9/16/2016- Friday MIRU Cement Pump Unit and Little Red Pump Unit. PT lines to 4,000 psi -test OK. Perform injectivity test at 1.00 bpm @ 900 psi. IMj_and pump 10 bbl of HEC, 15 bbl of 15.8 ppg cement,and 5 bbl of HEC. Drop foam ball. Displace w/27.5 bbl of 1% KCI water. Switch to Little Red Pump Unit and pump 25 bbl of diesel. SD Pumps. Monitor well. Final SITP of 920 psi. RDMO Cement Pump Unit & Little Red Pump Unit. Rig Down. 9/17/2016-Saturday No activity to report. 9/18/2016-Sunday MIRU Cement Pump Unit and Little Red Pump Unit. PT lines to 4,000 psi-test OK. Perform injectivity test at 0.95 bpm @ 1,050 psi. Mix and pump 5 bbl of HEC, 10 bbl of 15.8 ppg cement, and 5 bbl of HEC. Drop foam ball. Displace w/27.5 bbl of 1% KCI water. Switch to Little Red Pump Unit and pump 25 bbl of diesel. SD Pumps. Monitor well. Final SITP of 980 psi. RDMO Cement Pump Unit& Little Red Pump Unit. Rig Down. 9/19/2016- Monday No activity to report. 9/20/2016 -Tuesday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP H-15 CTU 50-029-23284-00-00 205-159 9/16/16 9/23/16 Daily Operations: 9/21/2016-Wednesday No activity to report. 9/22/2016 -Thursday No activity to report. 9/23/2016- Friday MIRU Hal 1.75" CTU. MU cleanout BHA with 1.69' pulsonix nozzle. NU BOPE. Stab on well. BOPE Test. RIH dry with pulsonix nozzle. Soft tag at 5,641' ctmd. Clean out to hard tag at 5,713' ctmd. POOH for motor and mill.Jet across Sta 1, 2, and 3. MU Baker motor and 2.74" OD junk mill.RIH with mill. Tag at 5,088' ctmd. Mill to 6,742' (PBTD). 1.5 bpm/2,000psi CTP/ 90psi WHP/ 10-20 fpm ROP. Green contaminated gel/cement. Pump 2 gel sweeps and BU vol. POOH at 80%. Bullhead down tubing to check injectivity. .55 bpm (792 bpd) at 670 psi WHP 1 bpm (1440 bpd) at 770 psi WHP. FP well with 20 bbls 60/40 meth. Secure Well. Standback injector and BOPE. Return in morning to RDMO. No Activity. Daylight coil operations only. 9/24/2016-Saturday No activity to report. 9/25/2016 -Sunday No activity to report. 9/26/2016- Monday No activity to report. 9/27/2016-Tuesday No activity to report. VOFTy • • Iyy�g. THE STATE Alaska Oil and Gas ofL ASKA Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 VW GOVERNOR BILL WALKER 9 '"° Main: 907.279.1433 4.LA9lP Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Area Operations Manager SCONE JAN 1 32017, Hilcorp Alaska, Inc. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB H-15 Permit to Drill Number: 205-159 Sundry Number: 316-407 Dear Mr. York: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /°- 411t-t4/4. Cathy . Foerster Chair DATED this /S>d of August, 2016. RBDMS I, t/AUii 1 5 2016 , • • AVD STATE OF ALASKA d�i U 2 ALASKA OIL AND GAS CONSERVATION COMMISSION QTS146 V APPLICATION FOR SUNDRY APPROVALS � / 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MBE Treatment❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC Exploratory ❑ Development ❑ 205-159 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service Q 6.API Number. Anchorage Alaska 99503 50-029-23284-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No 2 MILNE PT UNIT SB H-15 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6,800' 3,973' 6,767' 3,974' 3,500 6,767' N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 2,899' 9-5/8" 2,899' 2,729' 5,750psi 3,090psi Production 5,653' 7" 5,653' 4,022' 7,240psi 5,410psi Liner 1,289' 3-1/2" 6,800' 3,973' 10,160psi 10,540psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.2/L-80/TC-II 5,511 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): GT Dual Pkr,GT Dual Pkr&FH Pkr and N/A 5,680(MD)/3,875(TVD),5,853(MD)/4,007(TVD)&5,960(MDy 4,088(TVD)and N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development❑ Service 0 14.Estimated Date for 15.Well Status after proposed work: p 8/20/2016 ❑ ❑ WDSPL ❑ Suspended ❑ CommencingOperations: OIL WINJ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Potholer Email sporholat hilcorD.com Printed Name Bo York Title Operations Manager Signatures Phone 777-8345 Date 8/2/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. �` Plug Integrity ❑ BOP Test Mechanical Integrity Test Li Location Clearance ❑ V Other: x 35 /"45L' i L' Oaf 7:7;(- .1 - 'idiC ,I 1 Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0—'(O'. RBDMS 1,01'12 1 5 2016 ^ APPROVED BY Approved by: / J _ _ COMMISSIONER THE COMMISSION Date: 8—(S-l�p -NI 8 /,‘ 4 D�GAN A Submit Form ane Form 10-403 Revised 11/2015 'r7��v or 12 months from the date Of approval. Attachments in Duplicate . • • Well Prognosis Well: MPU H-15 Hilcorp Alaska,LL Date:8/01/2016 Well Name: MPU H-15 API Number: 50-029-23284-00 Current Status: SI Dual Water Injector Pad: Milne Point H-Pad Estimated Start Date: August 20th, 2016 Rig: N/A Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 205-159 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,167 psi @ 4,000' TVD (Last BHP measured 12/07/2012) Maximum Expected BHP: 1,167 psi @ 4,000' TVD (No new perfs being added, EMW= 5.61 ppg) MPSP: 3,500 psi (Based on maximum surface injection pressure) Brief Well Summary: MPU H-15 was drilled with Doyon #14 in 2005 as a horizontal injector in the Schrader Bluff OA and OB sands.The well provides support in hydraulic unit 3 for the OA sand and the OB sand for offset producers MPU H-16 (PTD 204-190) and MPU 1-15 (PTD 202-152). Notes Regarding Wellbore Condition • Well is a horizontal water injector(max hole angle 107.7° @ 5,108'). • Last MIT-IA to 2,000 psi on 3/14/2014. • Shut-in water injection due to diagnosed MBE (Matrix Bypass Event). • Confirmed MBE between MPU H-16 (ESP Oil Producer) based on water cut. Objective: The purpose of this work/sundry is to pump an MBE tre t and place the well back on water injection. Brief Procedure: Pumping Procedure: 1. Production to SI offset producers up to 5 days prior to treatment(H-16, 1-15). ,-7 2. Production to SI offset injectors up to 2 days prior to treatment(H-04, 1-02, I-16). 3. MIRU Cement Pumping Unit and Little Red Pumping Unit. PT lines to 3,500 psi. [TREATMENT#1] a. Setup fluid manifold to allowing switching over from Cement Unit to Little Red. 4. Perform injectivity test w/8.5 ppg fresh water. a. Inject at 1.0 bpm or a max 1,000 psi for injectivity test. Do not exceed 1,250 psi. 5. Mix and bullhead the following fluids with the Cementing Unit: a. +/-10 bbl of 100 ppt HEC(hydroxy ethyl cellulose) lead spacer pill. b. +/- 15 bbl of 15.8 ppg acid soluble cement. c. +/-5 bbl of 100 ppt HEC(hydroxy ethyl cellulose)tail spacer pill. d. Drop foam ball. 6. Mix and bullhead the following fluids with the Little Red Pumping Unit: • • Well Prognosis Well: MPU H-15 Hilcorp Alaska,Lb Date:8/01/2016 a. +/-32.5 bbl of 1% KCL water. b. +/-20.0 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 1.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 7. SD Pumps. Monitor wellhead pressures for 15 min (T/I/O). 8. RDMO Cement Pumping Unit and Little Red Pumping Unit. 9. WOC 48 hours. 10. MIRU Little Red Pumping Unit. PT lines to 3,500 psi. [INJECTIVITY TEST#1] 11. Mix and bullhead the following fluids: a. +/-5 bbl of 60/40 McOH/Water(to ensure injectivity). b. +/-40 bbl of 8.5 ppg sea water or until injection rate stabilizes (same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 1,250 psi. d. +/-10 bbl of 60/40 McOH/Water(freeze protection; after stable injection achieved). 12. RDMO Little Red Pumping Unit. 13. Contingency: If unable to establish injectivity: a. MIRU Slickline. PT lubricator to 3,500 psi Hi 250 psi Low. b. RIH and tag cement top. POOH [Horizontal well,may not be able to reach PBTD1. c. RIH and bail cement. POOH. d. RIH w/dump bailer and spot 15% HCI acid to dissolve cement in tubing. e. Wait on acid minimum 4 hours (to dissolve calcium carbonate based cement). f. RIH and bail cement. POOH. g. RD Slickline. 14. Contingency: If residual cement exists: a. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg seawater. b. Pressure t- :OPE to 3,500 psi Hi 250 psi Low, 10 min each test. ,✓" o y AOGCC 24 rs. ii. - - : _! - . • or 8.5 ppg seawater. iii. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 psi Low to confirm no leaks. c. RIH w/1.75" coil w/1.75" wash nozzle to cement top.Circulate well w/8.5 ppg seawater. d. Continue to RIH and cleanout cement to PBTD at+/-6,736' MD. e. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 15. Contingency: If unable to cleanout cement w/wash nozzle. a. RIH w/2.75" OD mill, 2-1/8" motor,and oil jars and cleanout cement to PBTD at+/-6,736' MD. b. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 16. Contingency: If able to cleanout cement but unable to establish injectivity. a. RIH w/1.75" wash nozzle to PBTD at+/-6,736' MD. b. RU acid pumping unit. RU lines to pump down coil tubing. PT lines to 3,500 psi. c. Mix and pump 5-10 bbl of 15% HCI acid. Displace acid w/8.5 ppg seawater. POOH. d. RD acid pumping unit. RU return lines to acid returns tank. e. Wait on acid minimum 4 hours(to dissolve calcium carbonate based cement). f. Circulate acid out of well pumping 8.5 ppg seawater. g. RU to test injectivity thru the tubing tail. Do not exceed 3,500 psi. POOH. 17. Contingency: If unable to establish injectivity test after HCI soak, repeat Step#16[a-g]. 18. MIRU Cement Pumping Unit. PT lines to 3,500 psi. [TREATMENT#2] 19. MIRU Little Red Pumping Unit. PT lines to 3,500 psi. 20. Fluid-pack and maintain tubing pressure on offset wells affected by MBE (H-16/I-15). • • Well Prognosis Well: MPU H-15 Ililcorp Alaska,LL Date:8/01/2016 21. Mix and bullhead the following fluids with the Cementing Unit: a. +/-5 bbl of 100 ppt HEC(hydroxy ethyl cellulose) lead spacer pill. b. +/-10 bbl of 15.8 ppg acid soluble cement. c. +/-5 bbl of 100 ppt HEC(hydroxy ethyl cellulose)tail spacer pill. d. Drop foam ball. 22. Mix and bullhead the following fluids with the Little Red Pumping Unit: a. +/-32.5 bbl of 1% KCL water. b. +/-20.0 bbl of diesel (freeze protection). i. Volumes above will over-displace cement into formation by 1.0 bbl. ii. Injection pressure may be increased to prevent leaving cement in tubing. 23. Discontinue maintaining tubing pressure on offset well affected by MBE (H-16/I-15). 24. SD Pumps. Monitor wellhead pressures for 15 min (T/I/O). 25. RDMO Cement Pumping Unit and Little Red Pumping Unit. 26. WOC 48 hours. 27. MIRU Little Red Pumping Unit. PT lines to 3,500 psi. [INJECTIVITY TEST#2] 28. Mix and bullhead the following fluids: a. +/-5 bbl of 60/40 McOH/Water(to ensure injectivity). b. +/-40 bbl of 8.5 ppg sea water or until injection rate stabilizes (same rate as injectivity test). c. ***Contingency*** If unable to establish injectivity. i. Increase injection pressure, do not exceed 1,250 psi. d. +/- 10 bbl of 60/40 McOH/Water(freeze protection; after stable injection achieved). 29. RDMO Little Red Pumping Unit. 30. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Fluid Flow Diagram-Acidizing HO 0 Milne Point Unit Well: MP H-15 • SCHEMATIC Last Completed: 12/19/2005 Mean)Alaska,LLC PTD: 205-159 TREE&WELLHEAD Orig.DF Elev.:70.00'/GL Elev.:34.20'(Doyon 14) Tree 3-1/8"- 5M FMC k Wellhead 11"x 3-1/8"5M FMC Gen 5 w/3.5"TC-II T&B Thread 4 < FMC Tubing Hanger 3.0"CIW"H"BPV Profile 13-3/8.. r'.. OPEN HOLE/CEMENT DETAIL k 20" 260 sx Arctic Set(Approx.)in a 42"Hole i 9-5/8" 344 sx Arctic Set Lite,411 sx'Class G',in a 12-1/4"Hole , 7" 441 sx Class'G'in a 8-3/4" 03-1/2" 237 sx Class'G'in a 6-1/8" c: 1 it 1 CASING DETAIL •k Size Type Wt/Grade/Conn ID Drift Top Btm BPF 9-5/8"°� le . 20" Conductor 91.1/H-40/N/A 19.124" 18.936" Surface 112' 0.355 9-5/8" Surface 40/L-80/BTC 8.835" 8.679" Surface 2,899' 0.0759 7" Production 26/L-80/BTC 6.276" 6.151" Surface 5,653' 0.0383 3-1/2" Liner 9.2/L-80/IBT 2.992" 2.867" 5,511' 6,800' 0.0087 TUBING DETAIL 3-1/2" Tubing 9.2/L-80/TC-II 2.992" 2.867" Surf 5,511' 0.0087 TOC©3,307 RtB= WELL INCLINATION DETAIL USIT 12/15/05 ,w `; ` KOP @ 600' 4 1 Angle passes 50 deg.at 4,250'MD Max hole angle in Tbg=76 deg.at 4,700'MD 0 ; Max hole angle in Liner=107 deg.at 5,108'MD RA Tag 4,364'RB. t ro JEWELRY DETAIL 1 2 No Depth Item Packer ICI2.875" f 1 3,018' 3.5"HES X-Nipple(2.813"Profile) @7545 - �_,; 3 2 4,377' 3.5"HES X-Nipple(2.813"Profile) , _ 3 4,429' 7"x 3.5"Baker Premier Packer 4 GLM DETAIL:3.5"x 1.5"Camco MMG w/1.5"RK Latch 'OA Sands '° 4 4,486' Sta#3:Valve-300 bwpd/Date-10/30/2014 Packer ID=2.875" ' -_. .: °`5 5 4,546' 7"x 3.5"Baker Premier Packer @7,545' tl ti's 6 4,582' Sta#2:Valve-Dummy/Date-12/09/2012 1 Ix 6 7 4,620' Sta#1:Valve-500 bwpd/Date-10/29/2014 'OB'Sands "° 8 4,659' 3.5"HES X-Nipple(2.813"Profile) 9 4,689' 3.5"HES XN-Nipple(2.813"Profile/2.750 No Go)RMX prong(500 bwpd)Set 10/30/14 7 il, 10 5,511' Liner Tie Back Sleeve y8 i 11 5,520' 4"Seal Assembly(Landed in Liner Tie Back Sleeve) ' PERFORATION DETAIL Minimum ID=2.750"`, @4'6s9 t41 9 `s3 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT SPF Size Date Status s * r ' OA 4,493' 4,535' 4,040' 4,062' 42 5 4.5" 12/16/2005 Open '' 4,605' 4,645' 4,097' 4,116' 40 5 4.5" 12/16/2005 Open 'OB'Sands , OB 5,255' 5,315' 4,098' 4,081' 60 5 4.5" 12/16/2005 Open 4 10 OA 6,400' 6,650' 4,002' 3,960' 250 6 2.5" 12/16/2005 Open A ,w 11 Ref Log:USIT-12/15/2005—TCP Perf Guns 4.5"/PJ4505 @ 60 Deg(7"Casing) TCP Perf Guns 2.5"/PJ Omega @ 60 Deg(3-1/2"Liner) GENERAL WELL INFO API:50-029-23284-00-00 Drilled&Cased&Completed by Doyon 14—12/19/2005 OA'Sands 3-1/2" I* TD=6,800(MD)/TD=3,973'(TVD) PBTD=6,767'(MD)/PBTD=3,974'(TVD) Revised By:STP 1/25/2016 • • 111 Milne Point Unit COIL BOPS MPU H-15 8/01/2016 11i1,Y„p ~,i:,.I,.,.J.I . MPU 11-15 20x9% x7x3%2 Coil Tubing BOP To injection head 1 1 1.75'Double Stripper J . [ Lubricator 11111 Blind :NMI 1/16 15 = Blind .L'•il AIMEE ip IIIIIEDEMI 1 MEM VIIIIIIIM tb LIIII:21111111111 •5 046 fi Slip =s Slip .I,'•( .. 1111111 Pipe 11111 NEPipe ®I■'• –MIMI =ma 4i Crossover spool 41/16 15M X41/16 10M ' ' k raw Crossover spool Ws ra 41/16 10M X 4 1/16 5M , • gal Pump-In Sub O> e - cid Le _ I 4 1/16 5M '1fc° :IN III UI 1502 Union eu1 a Manual Gate Manual Gate Crossover spool r 2 1/8 5M 2 1/8 5M 41/16 5M X 3 1/8 5M w, a it i uyl Valve,Swab,WKM-M, „,`*--"-@ 3 1/8 5M FE -- �• \00�, ,. r \fie.44�I��F� i\.— /1 1 Q, , \l'a 3 Ic / , ` Valve, Upper Master,Baker, 3 1/8 5M FE,w/Hydraulic ,, 0 irk Valve,Lower Master,WKM-M, Opt,0`e 3 1/8 5M FE -`• ° a, 1111 Tubing Adapter,3 1/8 5M � i i . • • J H to x 1' to a z C m m Q , II Ca a oto E o C U ro 0 5 H k" •P z z •- > — F K •o='� UJ a m z UJ a z z •• •• [.- cn .°a Uw ¢ 302 302 Il m a m C 7 W W 1.. ., �� ' , XZ L O ---J MI Vf h —,111111.11-- 1111 �_- o. MN 0. a • a • Q fa.' o Q r 7. >. ( t N .a w > 3 a1 U a TO Nilr r v_ I , c Y S u alg c V 0 IIIIIIIIhh •�;z �..� ElmouILII <<• ;� IMr x '11 II;), �� m mi 1111 1111 c OOHO z O O W 2 v W Q R O O O 8- nal m ~ L K a �7 \� Z Q F Y m 8 0 Image Project Weil History Fife Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the fife. Q~,~~- ! ~~ Well History File Identifier Organizing (done) RESCAN ` [XColor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: _ Maria - .®-- Project Proofing BY: Maria Date: ~ j ~ / Q a„~,~~~a,a iuiimuiuiiiii OVERSIZED (Scannable} ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: IIII!IIIIIIIGIIIII ~P r ~ /_ Scanning Preparation _~ x 30 = '~ + ~ =TOTAL PAGES ((J ~' (Count does not include cover shee BY: Maria Date: 5 ~ ~ /s! Production Scanning {l I II II I{VIII { { II Stage 1 Page Count from Scanned File: ~./ 3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~~ ~~ ~' ~ /s/ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I I111I{ { II ({ ({ II{ ReScanned II l II II I{ { I Ill { {III BY: Maria Date: /s/ Comments about this file: o,.o.cea iuiuuuuuiui DIGITAL DATA ~iskettes, No. ^ Other, NolType: Date: ~--~ ~ ~' o~a„~~,~kaa iiumiiiiuuuu 10!612005 We11 History File Cover Page.doc STATE OF ALASKA • AL .(A OIL AND GAS CONSERVATION COMMISoION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well Li Plug Perforations Li Perforate U Other L MBE Treatment 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 ❑ 205-159-0 3.Address: P.O.Box 196612 Stratigraphic Service Q 6.API Number: Anchorage,AK 99519-6612 50-029-23284-00-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 • SBL MPH-15 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): MILNE POINT,SCHRADER BLFF OIL. 11.Present Well Condition Summary: RECEIVED Total Depth measured 6800 feet Plugs measured 4689 feet Dr F: 1 8 2013 true vertical 3973.22 feet Junk measured None feet (� Effective Depth measured 4689 feet Packer measured See Attachment feet ..,, ` true vertical 4133.65 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 78 20"91.5#H-40 36-114 36-114 1490 470 Surface 2864 9-5/8"40#L-80 35-2899 35-2728.43 5750 3090 Intermediate None None None None None None Production 5620 7"26#L-80 33-5653 33-4021.56 7240 5410 Liner 1289 3-1/2"9.2#L-80 5511-6800 4031.05-3973.22 10160 10530 Perforation depth Measured depth 4493-4535 feet 4605-4645 feet 5255-5315 feet 6400-6650 feet True Vertical depth 4040.26-4062.86 feet 4097.72-4116.21 feet 4098.01-4081.1 feet 4002.48-3980.99 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.2#L-80 30-5500 30-4032.93 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): E ,.i.b�' r, '1 Kate 6400'-6650' ., 1 i) .t', ~ Treatment descriptions including volumes used and final pressure: 5 Bbls 100#HEC Gel,10 Bbls 15.8 ppg Acid Soluble Class G Cement,4 Bbls 100#HEC Gel,556 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 352 0 1191 Subsequent to operation: 0 0 253 0 827 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service 0 • Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U Gas U WDSPLU GSTOR ❑ WINJ El, WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-523 . Contact Garry Catron Email Garrv.Catron(a�BP.Com Printed Name Garry Catron Title PDC PE Signature (A,r,,,r 6,417 --- Phone 564-4424 Date 12/18/2013 VLF R°7 ML DEC 2 0 2. Form 10-404 Revised 10/2012 / Submit Original Only Y Packers and SSV's Attachment ADL0025906 SW Name Type MD _ TVD Depscription MPH-15 PACKER 4428 3931.26 3-1/2" Baker Premier Packer MPH-15 PACKER 4546 3998.5 3-1/2" Baker Premier Packer MPH-15 PACKER 5522 3959.45 �3-1/2" Baker ZXP Packer Z c C in U d ° a) = co _ d 3 o Imo * = 0 E o) ' = I _N O — a L U O a) w N O ° YQ � MO � � o a) va') " (6 O a r N (U a (� ._ Q m C �o o ° U < EN- •- o � u) 3 a.- o I oa a� � 0- as aim CO _J a) 2 Nn c � � (D c °o � m cc o . 0 c aa) E M Q >I U) cCa b 0 co ON O N C M ' E' -O - co co c L – U w — c O o) m v -6 J N ! w a) a) Q x V N •~ Q cn w Y O 0_ N O• Q • Q � —° � � I ,C -c E a) a = cow N LLJ a O O 7 a) -p ID EO Oco -a e) o tco a) 1— a) (N a d (0 E E O I a N d (0 (9 N - 0 a 0 Q O C Q _ v' U) D O O O C : ��11 a) u LO CL acn o � � o a) a 7 w V Q E o 0 cm • N O O 03 N d . to - 2 0 73 O) E N E ) a) s ' C Q 6) F- C O C H op E O a O C a C II . O E J n C(p Z W CO CO w O O O (4c � U a�o -' Z � coia 2 o 11) In Q °° -I O io u a w Q d ° _° m ci z : a) o � T� a ° o � � o o 'wOu_ o O �? D ° ° 0 < C � 2 �- U) I– 6 � ° °_Y � 2-0 2Q � E ao � a * � Uw2Q (-)Io o a� N c c Q-. 6 o a) a ENcA a) 2 a) 7:), a) a) io Eo a)•cc O O E .ti Q X Q 0 c 3 U w d C• cn o � ir) � � C� Z ate`) any< l O o a9 ocr o CO Cr � wX � 0 00 ° E > Qa� aa)i w II H U ° � Q > 10 O – a a - O a4 C° > E < � a) ZHO . aU) .� o ° E .° oo -° �° � < up c O W w a X u_ D Q-� • — U) o co 6o n E o c o0 — O cr o 2 w c ` a) 6) o) u) N _ CC_ C N 2 J N J w Q Q J E > = w .o U O N > m(n -° Y • O Lc N 7 a) O O z tf) Q' w (Ni L" w w w> a) . cn I C Q 0 co a a) .0 C O Q a) c=3 ZwJJ > mQ' – o to Qv E c '§ to EO 4, < I D Q * J )) o O N _ - O (n 7 ca 0 ° = o) : cr co a. d + co 2 -0 CD _o f- O : d a U .0 o 1– co co co co co co r 0 o O O O O N N N N N N L[) co co r- N N N N TREE:3-1/8"-5M FMC 15 OI =Elev. =70.00 Doyon 14 MPH- 1 WELLHEAD:11"x 3-1/8"5M .Gen 5 Orig. GL Elev. =34.20 Doyon 14 Tub Hgr.11"x 3-1/8"TC-II T&B 3"CIW-H BPVT j Conductor 112' KOP @ 600' Angle passes 50°@ 4,250' 3.5" HES X-Nipple 2.813" Fo--IT1 Max Angle in Tbg=76°@ 4,700' Angle thru liner=90+° 9-5/8"40#L-80 BTC Csg. 2,899` 1 Valves in SPM/XN: 3.5"9.2#/ft L-80 TC-II Arrangement as of 3/10/13 ( Drift id = .0087 Bpf. ) 7"26 ppf, L-80, BTC-Mod casing (drift ID=6.276", cap. =0.0383 bpf) (cap w/3 1/2"tbg inside=0.0264 bpf) 3.5" HES X-Nipple 2.813" 4,377' "RA"Tag 4,364' 7"x 3.5" Baker Premier pkr. 4,429' Schrader "OA"Perfs SPF MD TVD DV J 3.5"x 1.5"Camco MMG(rk) 4,486' 4,493'-4,535' 4,040'-4,062' J 4.5" HSD 6 spf PJ4505 7"x 3.5" Baker Premier pkr. 4,546' Schrader "OB"Perfs DV , 3.5"x 1.5"Camco MMG(rk) 4,582' SPF MD TVD 4,605'-4,645' 4 097'-4,116' 500 BWPD� 3.5"x 1.5"Camco MMG-W(rk) 4,620' 5,255'-5,315' 4,098'-4,081' RWF 3.5" HES X-Nipple 2.813" 4,659' 4.5" HSD 6 spf PJ4505 300RMX 3.5" HES XN-Nipple 2.750"id. 4,689' (2.813"pkg. bore) 5,511' Baker Tie back slv. Baker 806-40 Seal Assy bottom Baker ZXP Packer 5,522' mom Baker HMC Liner Hgr. 5,528' Baker 80-40 Seal Bore ext. 7"float collar(PBTD) 5,571 5,536' k 7"Weatherford float shoe 5,653' Schrader "OA"Perfs SPF MD TVD 6 6,400'-6,650' 4,002'-3,960' 6,736' 3.5"Baker Landing Collar 2-1/2"HSD 6 SPF.PJ Omega 6,767' Halliburton Float collar 6,800' 3.5"Baker float shoe DATE REV.BY COMMENTS MILNE POINT UNIT 12/19/05 MDO Drilled&Completed Doyon- 14 WELL MPH-15 API NO: 50-029-23284-00 BP EXPLORATION (AK) OF T • • / �, THE STATE I�i�,s� Alaska Oil and Gas f h ts1 Conservation Commission T GOVERNOR SEAN PARNELL F'"�+nr 333 West Seventh Avenue O , p. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Alecia Wood ala NO 3 Pad Engineer BP Exploration (Alaska), Inc. n�',. I P.O. Box 196612 02 Anchorage, AK 99519-6612 Re: Milne Point Field, Schrader Bluff Oil Pool, SBL MPH-15 Sundry Number: 313-523 Dear Ms. Brown: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair, ommissioner DATED this (O" day of October, 2013. Encl. • H u STATE OF ALASKA ti►A i 3l. t0 3 20 1v • ALASKA OIL AND GAS CONSERVATION COMMISSION \‘11 ,t?r'S !v 1 CC (13 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: MBE Treatment [✓( 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 205-159-0- 3.Address: Stratigraphic ❑ Service 0 . 6.API Number P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23284-00-00• 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? SBL MPH-15 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): i ADL0025906• MILNE POINT,SCHRADER BLFF OIL' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 6800 • 3973• 4689 4134 4689 None Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20"91.5#H-40 36-114 36-114 Surface 2864 9-5/8"40#L-80 35-2899 35-2728.43 5750 3090 Intermediate None None None None None None Production 5620 7"26#L-80 33-5653 33-4021.56 7240 5410 Liner 1289 3-1/2"9.2#L-80 5511-6800 4031.05-3973.22 10160 10530 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attachment I See Attachment 3-1/2"9.2#L-80 L-80 30-5500 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths / No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program IS • BOP Sketch ❑ Exploratory ❑ Development ❑ Service IS• 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ El . GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alecia Wood Email Alecia.Wood @BP.Com Printed Name Alecia Wood Title MPU Schrader Pad Engineer Signature ' Phone 564-5492 / f Date Prepared by Garry Cron 564-4424 I 17.; 07t,, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `3 ^5 23 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No u Subsequent Form Required: /0 — 4-0 4 APPROVED BY Approved by: �■t )( 1 -* COMMISSIONER THE COMMISSION Date:/ -f6 — /3 Form 10-403 Revised 10/2 12 Appr d n's NAt d months from the date of approval. Submit Fo m and Attach ants in Duplicate vz )c' /t�/*o /)3 Q R7t I RBDMS OCT 11 ZI -P/A6 to/KJlb %C? - 0 0 Perforation Attachment ADL0025906 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPH-15 3/9/13 STC 4493 4535 4040 4063 MPH-15 3/9/13 STO 4605 4645 4098 4116 MPH-15 3/9/13 STO 5255 5315 4098 4081 MPH-15 4/22/13 STC 6400 6650 4002 3981 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF , • • Packers and SSV's Attachment ADL0025906 Well Facility Type MD Top Description TVD Top MPH-15 PACKER 4428 3-1/2" Baker Premier Packer 4001 MPH-15 PACKER 4546 3-1/2" Baker Premier Packer 4068 MPH-15 PACKER 5522 3-1/2" Baker ZXP Packer 4029 • • bp To: Mark O'Malley/Rob Handy Date: October 1, 2013 MPU Ops Team Leaders From: Alecia Wood, MPU Schrader Pad Engineer 907-564-5492 Subject: MPH-15 MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPH-15 2 F Bullhead treatment down MPH-15 (Toe OA sand). Keep well and offset producers and injectors shut in for the duration of the treatment and flow producers to a tank before returning to production if necessary. 3 C Pending the post cement injectivity tests, perform a fill clean out and possible (Pending) 15bbl HCL acid soak to attempt to regain injectivity. 4 S Align wellbore to the heel OA 2 F Bullhead treatment down MPH-15 (Heel OA sand). Keep well and offset producers and injectors shut in for the duration of the treatment and flow producers to a tank before returning to production if necessary. 3 C Pending the post cement injectivity tests, perform a fill clean out and possible (Pending) 15bbl HCL acid soak to attempt to regain injectivity. Objective: Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. Should the cement or gel lock up the wellbore, a contingent acid job will be performed. This wellbore has two MBE's to two different producers, one located in the toe OA sands and one in the heel OA sands that are separated by -1500 feet. Measure of success: 1. Treatments are displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is observed. Critical Issues: 1. Ensure pumping pressure during gel stage is not above the fracture gradient. 2. Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPH-15 is a produced water injector drilled in December 2005. The well has a single selective completion with an OA lateral. Flow can be regulated into the OA lateral by setting • • a valve in the tubing tail XN nipple @ 4689'. MPH-15 supports MPH-16, MPI-04A and MPI- 15. MPI-15 is a long-term SI awaiting a RWO, and MPI-04A is a plugged ESP producer awaiting a coiled tubing fill clean out. The RMX prong in the XN nipple @ 4689' was sanded in and stuck from 2010 until 2012 failed due to sand/schmoo around the fishing neck. The upper OA and OB were treated with BrightWater ® in October 2011. The SPMG was used for a pre-BW injector falloff in the OB as well as to monitor the injectivity after the Bright Water® was pumped. A second swab valve was installed at the time of the BW 9 p p treatment to allow for freeze protecting without interfering with the pressure falloff. The well was SI to obtain a SBHP in the OA, and pull the SPMG from the OB for a SBHP in preparation for drilling offset injector MPI-20 (Which was taken off the schedule). The SPMG was reset to continue monitoring the BrighWater ® results, and the WFRV's were changed out 3/24/12. When the well was SI to get pressures, an MBE was discovered in an offset producer MPI-04 and the well was kept SI as the suspected MBE culprit. Another injector I- 02 was POI to help support H-16, but it began to see higher water cuts and a rising GOR. The heel OA was confirmed with an MBE to 1-04, and was POI in the toe OA and OB. The toe OA was then confirmed with an MBE to H-16, and was dummied off. The well continued to inject in the OB sands to support H-16 however H-16 has since gone to high GOR without the OA support from this injector. PROCEDURE Stage 1. Injection Test Toe OA 1. MIRU SL 2. Align wellbore toheel-OA. 3. RDMO SL 4. RU, hold pre-job safety meeting, PT surface lines 5. Ensure offset producers are SI. 6. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 7. Contact Engineering to discuss the injection pressure/rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate/pressure continue with remainder of program. Stage 2. Treatment Toe OA 8. Ensure offset producers are offline 9. Pump produced water pre-flush followed by cement acting fluid treatment and diesel or methanol displacement. Allow setup time. 10. Perform injectivity test following cement stage. Should well exhibit zero injectivity, perform CT fill clean out with possible 15bbl HCL acid soak to attempt to regain injectivity into the wellbore. 11. Pump produced water pre-flush followed by a second stage of cement acting fluid treatment, holding pressure on the offset Producer connected by the Matrix Bypass Event. Attempt to squeeze second stage of cement and displace with diesel or methanol. Allow setup time. • • 12. Perform injectivity test following cement stage. Should well exhibit zero injectivity, perform CT fill clean out with possible 15bbl HCL acid soak to attempt to regain injectivity into the wellbore. 13. Pump produced water or KCL pre-flush followed by high volume gel treatment and diesel or methanol over flush. 14. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 15. Forward all post job assessments (w/all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. Stage 3. Injection Test Heel OA 1. MIRU SL 2. Align wellbore to heel OA. 3. RDMO SL 4. Ensure offset producers are SI. 5. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 6. Contact Engineering to discuss the injection pressure/rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate/pressure continue with remainder of program. Stage 4. Treatment .2 OA 7. Ensure offset producers are offline 8. Pump produced water pre-flush followed by cement acting fluid treatment and diesel or methanol displacement. Allow setup time. 9. Perform injectivity test following cement stage. Should well exhibit zero injectivity, perform CT fill clean out with possible 15bbl HCL acid soak to attempt to regain injectivity into the wellbore. 10. Pump produced water pre-flush followed by a second stage of cement acting fluid treatment, holding pressure on the offset Producer connected by the Matrix Bypass Event. Attempt to squeeze second stage of cement and displace with diesel or methanol. Allow setup time. 11. Perform injectivity test following cement stage. Should well exhibit zero injectivity, perform CT fill clean out with possible 15bbl HCL acid soak to attempt to regain injectivity into the wellbore. 12. Pump produced water or KCL pre-flush followed by high volume gel treatment and diesel or methanol over flush. 13. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 14. Rig down all equipment and hold post job assessment meeting to capture learnings to be incorporated into future jobs. 15. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. • • TREE-3-1ff-5M Fli•IC Orig.DF Elev.=70.00 Down 14 WELLHEAD W x 3-1/5"5M FMC Gen 5 MPH-15 Orig.GL Eiev.=34.20 Dawn 14 T ub Ftfr.lr x 3-111' TSB CM-H BFVT Conductor .4, KOP©600' Angle passes 50°G.4,750' 3.5"HES X-Nipple 2.813" 3,018' Max Angle in Tbg=76°©4,700' Angle thru brier=90+" g-ve*404 L-8U sTc Csg_ I 2 899, 11 1 Valves in SPAR I Mt 3.5'9_2 Alt L-80 TC-It Arrangement as of 3110113 (Dnit id=.IX187 Bpt) 7"26 ppf,1-80,BTC-Mod casing (ckift ID=6_276,cap.=0.0383 bpf (cap Jai 311?Sag inside=0.0264 bpf) 3.5"HES X-Nipple 2.813 4.377' 'RA'Tag 4.364' I r x 3_5'Baker Premier pkr. 4,429' SCITa)&TIC Pet SPF IAD ND I 0. 3.5'x 1.5°Cameo MMG(rk) 44136' 4,493-4.535' 4,040'-4,062" 4.5'HSD 6 spf PJ4505 7"x 3_5"Baker Premier pier. 4,546' SdiacMr 06 Perfs ; 3.5'x 1.5*Carnco WIG(irk) 4.587 SPF MD 4,605-4,645' 4.097 -4,116' x 1.5"Camco MMG-W(It) 4,620' 5,255-5,315 4.098'-4,081' 3.5-HES X-kkpple 2.813" 4,659' 4.5"HSD 6 spf PJ4505 3.5•FES XN-fappie 2.75(r id. I 4,689' (2.813"pkg.bore) . ' Baker Tie back sly 5511 Baker 806-40 Seal Assy bottom Baker ZXP Packer 5,527 Baker HMC Liner Hgr. 5,528' 7•float collar(P611)) 5,571' Baker 80-40 Seal Bore et 5,536' A a& 7 Weatherford float shoe 5,653' Schrader'OK Penis MD TVD 6 6,400'-6,650' 4,007-3,960' 6,736' 3.5'Baker Landing Collar 2-UT HSO 5 SPF.PJ Omega 6,767' Halliburtori Float+=Aar 6,800' 35'Baker float shoe DATE REV BY OOMMEtirS MILNE POINT UNIT 12119/05 MDO Drdled&Completed Doyon-14 WELL MPH-15 API NO: 50-029-23284-00 BP EXPLORATION (AK) Ill • • oain ^ ,,.r- ' 'TMs;'"' r. r. - y,u ^vrs ^- m 1 ''''::ft'Y`.-1''''''''',' 'rr.-k''':!'.3.:.:''- ::1:.'-t::..'..: .-A.,.`.',$,..9,i,.:'Aii,.,It--,A,:.,,,,. .7,,,,,,,:',4,-:-' ,-,4'..,;i„,4,,.,,.1,,.yi.•4:„Tv.t.,-..4. ;;?:„,:i,--N.I,A.,::,v,4:4...e.*:41 .,-,:,f,;-.,:. ,,;;:-.:4,,, 5 r s jai ` � r x Fv- i4! i k '� " 3 s R Legal Well Name: MPH-15 Common Well Name: MPH-15 Spud Date: 12/6/2005 Event Name: DRILL+COMPLETE Start: 12/1/2005 End: 12/13/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/19/2005 Rig Name: DOYON 14 Rig Number: 14 0 :i P i, a A : ' e �4 s a % ".t o '!,4:` ,�' � : a 12/15/2005 21:00-00:00 3.00 PERFOB P LOWERI shots per ft. 12/16/2005 00:00-02:00 2.00 PERFOB P LOWER1 PJSM,Finish Picking up Schlumberger 2.5 guns 6 shots per ft, { M 35 jts 2 1/16 CS hydrill pipe,and 4.5 HSD gun 5 shots per ft. 02:00-05:00 3.00 PERFOB P LOWERI Tripping in with guns to 6652.27,space out in place 05:00-06:00 I 1.00 PERFOf3I P LOWER1 I PJSM,Rig up E-line truck 06:00-11:00 5.00 PERFO P LOWERI Made two runs for depth control,guns on depth 11:00-11:30 0.50 PERFO P LOWER1 Rig down wire line truck 11:30-12:00 0.50 PERFO P I LOW ER1 PJSM on firng guns to peforate @ 4493'to 4535',4605'to - 4645',5255i to 5315',6400'to 6650' 12:00-13:00 1.00 PERFO P LOWERI Shut hydrill,pressure up on annulus to 2600 psi,held pressure 'for 3.5 min.,bled of,wait for 18 mins.,one guns fired,waited 13:00-15:00 2.00 PERFO f additional 18 min.for second guns,no indication of second I guns going off,fill hole with 18 bbls brine P LOWER1 Poh with 4'Dp,hole taking 10 bbls brine hr. 15:00-21:00 6.00 PERFO P LOWER1 PJSM,Laying down guns and 2 1/16 CS hydrill,(all guns fired) 21:00 22:00 ! 1.00 PERFO P LOWERI Clear rig floor 22:00-00:00 2.00 PERFO P LOWER1 Mobilize BHA,picking up BHA#4 12/17/2005 00:00-01:30 1.50 PERFO P LOWER1 RIH to 4300',hole taking 2-3 bbls hr. 01:30-03:00 1.50 PERFO P LOWER1 I Wash and ream 4300'to 5500', tag top of liner @ 5510 with 10 i bbls min.1900 psi,hole taking app 4-5 bbl hr. 03:00-05:00 2.00 PERFO P LOWERI- Pump hi vis pill,back reaming 5500 to 4300, 11 bbls min. 2000 psi,hole taking 4-5 bbl hr. 05:00 05:30 ! 0.50 PERFO P LOWER1 Pump hi-vis pill,Circ bottoms up @ 4300 with 11 bbls min. 05:30 07:00 ! 1.50 PERFO P LOWER1 Flow check,POH 07:00-08:30 1.50 PERFO P LOWER1 �Clean out junk subs,small recovery,clear rig floor 08:30-10:30 2.00 PERFO P LOWER1 PJSM with slick line crew„rig up slick line unit 10:30-13:00 2.50 PERFO P LOWER1 Rih with 5.95 gauge ring and junk basket,to 4821,POH,clean out junk basket,gun junk recovery 13:00-15:30 2.50 PERFO P LOWER1 Rerun 5.95 gauge ring and junk basket,to 4835,POH,clean I out junk basket,gun junk recovery,rig down slick line unit 15:30-17:30 2.00 RUNCO RUNCMP I PJSM,Rig up to run 3.5 TCII tubing,install long bales, compensator 17:30-23:30 6.00 RUNCO RUNCMP PJSM,Picking up 3.5 9.2#L-80 TCII tubing,total 65 jts 23:30-00:00 0.50 RUNCO RUNCMP R/u to test tubing to 3500 psi. 12/18/2005 00:00-00:30 0.50 RUNCO RUNCMP Attemp to test tubing to 3500 psi,test failed,65 jts in hole 00:30-01:00 0.50 RUNCO DPRB RUNCMP PJSM,pull and lay down 15 Its of tubing 01:00-02:00 1.00 RUNCO DPRB RUNCMP Rig up and test tubing to 3500 psi and record on chart,good test,checking the 15 its that was layed down c V 02:00-03:00 1.00 RUNCO DPRB RUNCMP Picking up 8 jts of tubing total of 58 jts in hole k"$ 03:00-03:30 0.50 RUNCO DPRB RUNCMP Rig up and test tubing to 3500 psi,good test 03:30-04:00 0.50 RUNCONTI DPRB RUNCMP Picking up 7 jts tubing total of 65 jts in hole -t l 04:00-04:30 0.50 RUNCO DPRB RUNCMP Rig up and test tubing to 3500 psi,test failed 04:30-05:00 0.50 RUNCO DPRB RUNCMP Pull 3 jts,62 jts in hole, -z, 1 2 05:00-05:30 0.50 RUNCO DPRB RUNCMP Pressure up to 3500 psi for 10 min.,record on chart 05:30-06:00 0.50 RUNCO RUNCMP Picking up 3.5 9.2 TCII tubing,change out its 63,64,65 06:00-07:00 1.00 RUNCO RUNCMP Test tubing with 3500 psi for 10 min.good test 07:00-15:30 8.50 RUNCO RUNCMP Picking up tubing 167 jts total,test tubing to 3500 for 10 min. every 20 jts,total jts picked up 167 jts 3.5 TCII 9.2# L-80 15:30-18:00 2.50 RUNCO I RUNCMP Space out,with 3.75 pup one its below hanger,land hanger, I rig up to test landing jt.leaking 18:00-20:00 2.00 RUNCOMP RUNCMP !Pull hanger and back out landing it,service threads,land I hanger,rig up and test tubing to 3500 psi for 10 min.good test Printed: 12/21/2005 1:51:32 PM • • bp BP Exploration (Alaska) Inc. „ _. . Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 5 A ) FEB i i 201 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue ' D5-- 15-9 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPH -Pad M f Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPH -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 extemal corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPH -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPH -01 1900860 50029220610000 Dust Cover NA NA NA 6.8 9/4/2011 MPH-02 1900870 50029220620000 Sealed Conductor NA NA NA NA NA MPH -03 1900880 50029220630000 Sealed Conductor NA NA NA NA NA MPH-04 1900890 50029220640000 Sealed Conductor NA NA NA NA NA MPH -05 1950980 50029225720000 1.3 NA 1.3 NA 11.9 8/17/2011 MPH -06 1951150 50029225800000 0.2 NA 0.2 NA 5.1 10/9/2011 MPH -07A 2020240 50029225970100 6 NA 6 NA 59.5 10/31/2009 MPH -08B 2010470 50029228080200 1.2 NA 1.2 NA 17.0 9/4/2011 MPH -09 1971650 50029228040000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -10 1971490 50029227950000 1.2 NA 1.2 NA 11.9 10/31/2009 MPH -11 1971630 50029228020000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -12 1971700 50029228070000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -13A 2021670 50029228180100 0.8 NA 0.8 NA 8.5 8/17/2011 ->' MPH -15 2051590 50029232840000 0.5 NA 0.5 NA 5.1 8/17/2011 MPH -16 2041900 50029232270000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -17 2070660 50029233580000 1.3 NA 1.3 NA 13.6 8/17/2011 MPH -18 2041740 50029232240000 18.6 NA Need top job MPH -19 2071360 50029233710000 0.1 NA 0.1 NA 2.6 9/4/2011 TE OF ALASKA ALASKA OIL AND S CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other Ei BRIGHTWATER Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ TREATMENT Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ " 205 -1590 3. Address: P.O. Box 196612 Stratigraphic❑ Service 0 6. API Number: Anchorage, AK 99519 -6612 r 50- 029 - 23284 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 025906 MPH -15 10. Field /Pool(s): r MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: I Total Depth measured 6800 feet Plugs (measured) None feet true vertical 3973.22 feet Junk (measured) None feet Effective Depth measured 5571 feet Packer (measured) 4429 4546 5522 feet true vertical 4024.45 feet (true vertical) 4002 4068 4029 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 94# H -40 35 - 114 35 - 114 1530 520 Surface 2865' 9- 5/8 "40# L -80 34 - 2899 34 - 2728 5750 3090 Production 3620' 7" 26# L -80 33 - 3653 33 - 3393 7240 5410 Liner 1289' 3 -1/2" 9.3# L -80 5511 - 6800 4031 - 3973 10160 10530 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - -- - True Vertical depth: _ _ :,'"0', „_:?ill li.,,2 _i h f fi ti ?/ LS 11 - Tubing: (size, grade, measured and true vertical depth) 3 -1/2” 9.2# L -80 30 - 5500 30 - 4033 Packers and SSSV (type, measured and true vertical depth) 3 -1/2" Baker Premier Packer 4429 4002 3 -1/2" Baker Premier Packer 4546 4068 3 -1/2" BakerZXP Packer 5522 4029 12. Stimulation or cement squeeze summary: , .� E Intervals treated (measured): ; ; Treatment descriptions including volumes used and final pressure: . : (.2;i pp fpt�{�t Ct � r M 0 t i3 , lit 'Jt ; i •OPS. ranlsslon 13. Representative Daily Average :PrcAgton or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 814 1159 Subsequent to operation: 734 1112 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory0 Development ❑ Service 0 r Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ 0 • WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Nam- -e Lastu i tilk r Title Petrotechnical Data Technologist Signal - ilillit' \ ----, Phone 564 -4091 Date 11/17/2011 Nir %DMS NOV 2 2 i f. 29.I( Submit Ori final Onl Form 10 -404 Revised 10/2010 g y MPH -15 205 -159 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPH -15 12/16/05 PER 4,493. 4,535. 4,040.26 4,062.86 MPH -15 12/16/05 PER 4,605. 4,645. 4,097.72 4,116.21 MPH -15 12/16/05 PER 5,255. 5,315. 4,098.01 4,081.1 MPH -15 12/16/05 PER 6,400. 6,650. 4,002.48 3,980.99 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • MPH -15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/24/2011 RT /I /0= 1170/820/240 Temp =Hot (Brightwater Reservoir Sweep Mod) Start pumping Brightwater chemicals down TBG while on water injection @ 850 !bwpd. `Pumped 55 gal EC9660A ( Surfactant) Average of 7.8 gph for 7 hrs. Pumped a total of 55 gal since start of project `Pumped 141 gal EC9408A ( Polymer) Average of 20.1 gph for 7 hrs. Pumped a total of 141 gal since start of project 10/25/2011 T /I /0= 2017/800/240 Temp =Hot (Brightwater Reservoir Sweep Mod) Start pumping Brightwater chemicals down TBG while on water injection @ 850 bwpd. Pumped 146 gal EC9660A ( Surfactant) Average of 6.1 gph for 24 hrs. Pumped a total of 201 gal since start of project Pumped 520 gal EC9408A ( Polymer) Average of 21.7 gph for 24 hrs. Pumped a total of 661 gal since start of project 10/26/2011 IT /I /0= 1197/900/200 Temp =Hot (Brightwater Reservoir Sweep Mod) ;Start pumping Brightwater chemicals down TBG while on water injection @ 850 bwpd. Pumped 115 gal EC9660A ( Surfactant) Average of 4.8 gph for 24 hrs. Pumped a :total of 316 gal since start of project Pumped 484 gal EC9408A ( Polymer) Average of 20.2 gph for 24 hrs. Pumped a :total of 1145 gal since start of project 10/27/2011 +T /I /0= 1197/940/200 Temp =Hot (Brightwater Reservoir Sweep Mod) ; Start pumping Brightwater chemicals down TBG while on water injection @ 850 bwpd. Pumped 125 gal EC9660A ( Surfactant) Average of 5.2 gph for 24 hrs. Pumped a :total of 441 gal since start of project Pumped 512 gal EC9408A ( Polymer) Average of 21.3 gph for 24 hrs. Pumped a total of 1657 gal since start of project • 10/28/2011 T/I/0= 1194/1060/240 Temp =Hot (Brightwater Reservoir Sweep Mod) Start pumping pumping Brightwater chemicals down TBG while on water injection @ 850 bwpd. Pumped 152 gal EC9660A ( Surfactant) Average of 7.6 gph for 20 hrs. Pumped a total of 593 gal since start of project Pumped 435 gal EC9408A ( Polymer) Average of 21.75 gph for 20 hrs. Pumped a total of 2092 gal since start of project FLUIDS PUMPED GALS 593 EC9660A (SURFACTANT) 2092 EC9408A (POLYMER) 2685 TOTAL • • TREE: 3 -1/8" - 5M FMC Orig. DF Elev. = 70.00 Doyon 14 WELLHEAD: 11" x 3 -1/8" 5M FMC Gen 5 MPH-15 Orig. GL Elev. = 34.20 Doyon 14 Tub Hgr. 11" x 3-1/8" TC -II T &B 3" CIW -H BPVT Conductor I 112' KOP @ 600' Angle passes 50° @ 4,250' 3.5" HES X- Nipple 2.813" 1 3,018` I Max Angle in Tbg = 76° @ 4,700' Angle thru liner = 90 +° 9 - 5/8" 40# L - 80 BTC Csg. 1 2,899 I Valves in SPM / X■t 3.5" 9.2 #/ft L -80 TC -I I ;;,, Arrangement as of 3/11/10 ( Drift id = .0087 Bpf.) 7 " 26 ppf, L -80, BTC -Mod casing ( drift ID = 6.276 ", cap. = 0.0383 bpf ) (cap w/ 3 1/2" tbg inside = 0.0264 bpf) 3.5" HES X- Nipple 2.813" 1 4,377' I "RA" Tag 4,364'1 7" x 3.5" Baker Premier pkr. 1 4,429` I Schrader "OA" Perfs SPF MD TVD = 1 3.5" x 1.5" Camco MMG (rk) 1 4,486' I 4,493` - 4,535' 4,040'- 4,062' 4.5" HSD 6 spf PJ4505 – A 7" x 3.5" Baker Premier pkr. 4,546` Schrader "OB" Perfs SPF MD TVD 3.5" x 1.5" Camco MMG (rk) 4,582` 4,605`- 4,645' 4,097` - 4,116' ta 5,25T-5,315' 4,098' 4,081' 3.5" x 1.5" Camco MMG -W (rk) ( 4,620' I 3.5" HES X Nipple 2.813" 4,659` I 4.5" HSD 6 spf PJ4505 3.5" HES XN- Nipple 2.750" id. 4,689' I 5,511` — ( 2.813" pkg. bore ) Baker Tie back siv. Baker 806-40 Seal Assy bottom Baker ZXP Packer 5,522` Baker HMC Liner Hgr. 5,528' — 7 " float collar (PBTD) 5,571' Baker 80-40 Seal Bore ext. 5,536` A k 7 " Weatherford float shoe 5,653` Schrader "OA" Perfs SPF MD TVD 6 6,400' - 6,650' 4,002`- 3,960' 1 6,736' I 3.5" Baker Landing Collar 2 - 1/2" HSD 6 SPF. PJ Omega 6,767' I Halliburton Float collar ,I 6,800' I 3.5" Baker float shoe DATE REV. BY COMMENTS MILNE POINT UNIT 12/19/05 MDO Drilled & Completed Doyon - 14 WELL MPH - API NO: 50- 029 - 23284 -00 BP EXPLORATION (AK) ~ ! MEMORANDUM To~ Jim Regg P.I. Supervisor ~~J~9 ~ I i ~ 11 ~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 17, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC H-IS MILNE PT UNIT SB H-Is Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~~r~'~ Comm Well Name: MILNE PT UNIT SB H-ls Insp Num: mitRCN100316135313 Rel Insp Num: API Well Number: 50-029-23284-00-00 Permit Number: 205-159-0 Inspector Name: Bob Noble Inspection Date: 3/13/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Has Type Inj. W TVD ~ 400 12 IA 200 2000 1920 - 1890 P.T.Di zosls9o TypeTest SPT Test psi zooo ~ OA ~ 200 310 2so zzo Interval aYRTST p~ Tubing P ]16s 116s 1166 116s Notes: _ 'jdR - ~,J ~i:51'v ~v~~ ~ ~ t4, .?.' ~~ ~ L1 i tJ Wednesday, March 17, 2010 Page 1 of 1 ~, d fn.. ~ U~ 'b DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051590 Well Name/No. MILNE PT UNIT SB H-15 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23284-00-00 MD 6800. TVD 3973 Completion Date 12!19!2005 Completion Status 1WINJ Current Status 1WINJ UIC Y REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: Gyro, DIR/GR, IFR/CASANDRA, RES, PWD, SCMT, NEUlDEN,USIT, WeII Log Information: Log/ Electr Data Digital Dataset Log Log Run Ty Med/Frmt Number Name Scale Media No og Sonic 5 Col 1 (~ D Asc Directional Surve y i.c S C B~5 13961 Sonic 5 Col 1 ~ 14106 LIS Verification i JJ ~'t? ~H~ g ~•E C Lis 3.k62[J InductionlResistivity Well Gores/Samples Information: (data taken from Logs Portion of Master WeII Data Maint Interval OH / Start Stop CH 3000 5480 Case 0 0 0 0 Received Comments Ultra Sonic Cement log Maxtrac/GR/CCUUSIT 15- Dec-2005 1/17/2006 DEFINITIVE SURVEY 3000 5480 Case Ultra Sonic Cement log I Maxtrac/GR/CCL/USIT 15- 'i Dec-2005 i 78 6721 Open 8/30/2006 Lis Veri, GR, ROP, FET, NPHI, DRHO, RHOS wlGraphics j 78 6721 Open 4!2012007 LIS Veri, GR, ROP, FET, I NCNT, NPHI, DRHO, RHOB wlGraphics EMF, PDF Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORM~jION Well Cored? Y N Chips Received? ~~f-Ids Analysis ~ Received? Comments: Directional Survey ~Yes~~ - ~, Daily History Received? ~° Formation Tops ~/ N r 1 L~ DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051590 Well Name/No. MILNE PT UNIT SB H-15 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23284-00-00 MD 6800 TVD 3973 Completion Date 12(19!2005 Completion Status 1WINJ Current Status 1WINJ UIC Y -- jj --- - ComplianceReviewedBy: __ __ _._-__--_____ Date. _,-J ~ t~~.-~ o~l~`~~--- WELL LOG TRAI'~15i~IITTAL To: State of Alaska April 18, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: MPH-15, AK-MW-4084655 MPH-15: Digital Log Images: 50-029-23284-00 1 CD Rom PLEASE ACI~vOWLEDGE RECEIPT BY SIGNING AlYD RETURNING THE ATTACHED COPIES OF THE TRAi~TS1VIITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Ine. Attn: Rob Kalish Petro-technical Data Center LR2-1 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99548 t' ' ~. i S ~ ? '.~ ,~ ~.~ my ~~t'+ ~` ,, ,~,~ Date: " Signed: ,_. ~,.. », Uzc aa5- IS~i ~ ~SC~~I~i C WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPH-15, • August 18, 2006 AK-MW-4084655 1 LIS formatted CD with verification listing. API#: 50-029-23284-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date ~n ~~ 5'~ ~~~ ~' ~~ "i-~06 ~r~ ~ ~~, ~:.. ,,#~: BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 ,, .> >~ Signed: uxC ~~~ - t~~- ~ ~~ 1 ~~ ~~.J~~ Schium6erger ~k~3~~ z ~ L~1~s Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~~ y~ ~~ CL`'ns• ~4T~Ri.SStCt1 Anchorage, AK 99503-2838 anC~G~~ ATTN: Beth Wnll Inh $ /~ l~~ ~Q~ ~~G ~~ 1 ~~ 1 nn r1a nFin NO. 3854 Company: State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n~~e o~ r..i... rn 06/20/06 07-18 9153238 LDL 01/31/03 C-04A 10649975 SBHP SURVEY 06/26/03 N-11C 10980595 PRODUCTION PROFILE 08!09/05 1 MPF-89 11084328 SCMT 11/24/05 1 D-10 10913021 MULTI-FINGER CALIPER 06/02/05 1 NGI-09 11212860 USIT 05/23/06 1 MPH-09 11211412 USIT 05/28/06 1 MPH-15 11076486 CH EDIT PDC-GR OF USIT 12!15/05 Prints sent earlier 1 MPS-90 11162721 CH EDIT PDC-GR OF USIT 11/27/05 Prints sent earlier 1 AGI-07A 11212865 CH EDIT PDC-GR OF USIT 05/28/06 1 1 15-20C 11075906 MCNL 08/12/05 1 1 18-30 11209593 MCNL 03/25!06 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ,vlasl<a vata ts< consuinng Servces 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • +a MEMORANDUM To: Jim Regg ~~~~ ~~~~~~(v P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, April 07, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC H-15 MILNE PT UART SB H-15 Src: Inspector NON-CONFIDENTIA L 2J°~~ ls~ Reviewed By: P.I. Suprv Comm Well Name: NIILNE PT UNIT SB H-IS Insp Num: mitLG060316110329 Rel Insp Num API Well Number Permit Number: 50-029-23284-00-00 205-159-0 Inspector Name: Lou Grimaldi Inspection Date: 3/1612006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ x-IS {Type Inj, i ~' j TVD p T ; 2oslsso ITypeTest = SPT I Test psi aooz IA + Iooas ~ OA j o I I9so ! Igo ~ zao ~ tsbo ~ Iszo i ~ no ! 2IO I Interval INITAL Pte` P Z'Ubing ~ 1145 ~ 1140 ~ 1130 ~ 1130 ~ Notes Ftiday, April 07, 2006 Page i of 1 IVED ~ ~ STATE OF ALASKA FE8 2 12006 ALASK~IL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LO~laska Oij $ Gas Cons. Corrxnission Revision: 021gl~ Injection 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoanc 2s.,o5 20AAC 25.110 ^ GINJ ®WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 12/16!2005 12. Permit to Drill Number 205-159 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/6/2005 13. API Number 50-029-23284-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12!14/2005 14. Well Name and Number:. MPH-15 2940 FSL, 4011 FEL, SEC. 34, T13N, R10E, UM Top of Productive Horizon: 2501' FSL, 354' FEL, SEC. 33, T13N, R10E, UM g, KB Elevation (ft): 69.96 15. Field /Pool(s): Milne Point Unit !Schrader Bluff Total Depth: 1528' FSL, 2352' FEL, SEC. 33, T13N, R10E, UM 9. Plug Back Depth (MD+TVD} 6767 + 3974 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 556633 y- 6010091 Zone- ASP4 10. Total Depth (MD+TVD) 6800 + 3973 Ft 16. Property Designation: ADL 025906 _ _ TPI: x-_ 555015 y- 6009641 Zone- ASP4 Total Depth: x- 553026 y- 6008653 Zone- ASP4 11. Depth where SSSV set NIA MD 17. Land Use Permit: -~---~-~--~------ --~----------~- -~-~-~--~-~- 18. Directional Survey ^ Yes ®No 19. Water depth, if offshore NIA MSL 20. Thickness of Permafrost 1800' (Approx.) 21. Logs Run: Gyro , DIRJGR , IFR/CASANDRA , RES , PWD , SCMT , NEU/DEN , USIT , CCL 2. ASING, LINER AND EMENTING RECORD CASING ETTINCi EPTH MD ETTINt~ EPTH TVD 1-iOLE UNT SIZE WT. PER FT. _ GRADE OP; TTOM OP TTOM SIZE CEMENTING RECORD '.PULLED.: ; 20" 94# H-40 35' 114' 35' 114' 42" 60 sx Arctic Set A rox. 9-5/8" 40# L-80 35' 2899' 35' 2728' 12-i14" 44 sx AS Lite, 411 sx Class 'G' 7" 26# L-80 33' 5653' 33' 4022' 8-3/4" 1 sx Class 'G' 3-1I2" 9.3# L-80 5511' 6800' 4031' 3973' 6-1I8" 37 sx Class 'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING RrcoRo Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 SPF 4-1/2" Gun Diameter, 6 SPF 3-1l2", 9.2#, L-80 5550' 4428' & 4546' MD TVD MD TVD Schrader'OA' Schrader'OA' Schrader'NB' Schrader'NB' 25. ACID, FRACTURE, CEMENT SQUEEZ€, ETC. 6400' - 6650' 4002' - 3981' 4493' - 4535' 4040' - 4063' DEPTH INTERVAL MD AMOUNT & KIND OF MATER{AL USED Schrader chra er Freeze Protected with 66 Bbls of Diesel 'NCEND' 'NC/ND, 4605' - 4645' 4098' - 4116' 5255' - 5315' 4098' - 4081' 26. PRODUCTION TEST Date First Production: February 1, 2006 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD O{L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary}. Submit core chips; if none, state "none". None ~ ~~~ F~8 `~ 3 206 Form 10-407 Revised 12/2003 ~ ~ ~ ~ ~ ~ C(~TI~JUED ON REVERSE SIDE #-~ 2t3. 29 GEOLOGIC MARKER ' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None", TMA 3970' 3668' None TMBi 3978' 3675' TMB2 4036' 3724' TMC 4204' 3857' TNA 4253' 3891' TNB 4297' 3919' TNC 4342' 3947' THE 4374' 3967' TNF 4439' 4008' TOA 4488' 4037 BOA/TSBC 4540' 4065' TOB 4600' 4095' BOB 4650' 4118' 30. List of Attachments: 31. l hereby certify that the foregoing is true and correct to the best of my knowledge. i Signed Sondra ~ wman Title Technical Assistant Date f ,, Z ' Z~ `- ~~ MPH-15 205-159 Prepared ByName/Number.• Sondra Stewman, 564-4750 Well Number Ori((ing Engineer: John Rose, 564-5271 Permit No. / A royal No. INSTRUCTIONS GeNeRn~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Irera 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). IrEra 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. frets 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Irene 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). trenn 27: If no cores taken, indicate "None". IrewA 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only r-=C:3ANZGAL INTEGRITY Rt., ORT `. ., , ~-_ : _ 1?~~ -~~ OPER ~ FIELD ~~ ~~~~ ~O~~h`T' ~. UD ~.,---~ . _.. G r S ~ ~ ~ ., S . i.~ ~~S-4 '~ h ALL N LIMB F.R ~'~.~ `~ ' l ~' .N ~ LL D~ T e TD : Co~~ .?~.. ~c11~ TVD ; ?BTD : ~~`~ ?'ID 7jal~~ TVD Cas i:-:g ~ f ~ Shae . 5~5 i~iD ~0~~--TVD ; liV . ~ ~ ?~ 'T'~~?i -=:,er . 'JAIL Shoe . ~~y '~ ?j_ ~`~3 T`JD ; :CP . ~(~ ~ t~~ ~0~_~`iD ~uoi='~ ~~(7 Packer :~ TV7; Set at ~ S~.J ~ 5~3 ~ +~d~c~ tiv.e.3 ~t5~ S ole S_~e ~ and (~c~,-; Perks yceoS to ~-t~~ . ~~~ X315 '-'~:.'Cc?.rti?~IC~.I, TNTEGR?"TY _ aA.RT #t Crr~ Co~SC~ r_nnu~us Press Test: ~~ 15 rain ~0 min Consents '-~*'CH~NZC~~, INTEGRITY - PAS,?T # 2 ~~~ ~~~~~~ ~ Cement Volumes :~ A,mt. Liner ~~`Z~~.,c Cs~ ~~ ~S1C DV ~j.A, --~ Cmt Jol to cover oer.s ~ 3~Zo1GS ,~ ~ ~ +~~ GCS ~~,_ ~^ ~~s o~-.<<~~ ~ 4 b b\ cu:~~~-c cc..s~co ~c-~~ -~ec~ ~ ~~ -.e- r ~ i << _ e o r e t i c a 1 T 0 C ~ L ~,R.-r-~-.~~ ~. acl~ ~ cl~fTS 'f ~ c, a~~c...~~ ~ ~. Cement Bond Log (Yes or No)~; ~~ ~, S .~~ In AOGCC File ~~`~ c~b~a~v~~.ZOC,. 33O6t u~~v1~.~~r~ ` -- 3 Soc7 j C9L Evaluation, gone aoove perfs ~ ~ ~\~~. ~~, ~ ~`~ Production Log: Ty-De___ Evaluation CONCL'JS ~ ONS art i 1 : ~ ~-., ?art 12: ~~ 1 ~. S ~ ~c~s: .~ ~ ~ ~ ~ oCp MPH-15 (205-159) USIT Sabject: MPH-15 (205-159) USIT From: Thomas Maunder <tom_maunder cr admin.state.ak.us> D:~te: Tl~u, d2 Feb 20Q6 11:52:38 -0900 "I'~: ~on~~r~i Stewman <_StewmaSU~uBP.con~-, Hi Sondra, I am reviewing the 407 for this well. I just checked and we don't have a copy of the USIT log. I suspect it is not long in coming, but could you check? If an ecopy is available could you or one of the engineers send it over? Thanks, Tom Maunder, PE ~ ~ ~~' AOGCC d OJ--~~~ `~ 1 of 1 2/2/2006 12:06 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~cEivEo JAN 3 0 2006 Alaska Oil & Gas Cons. Commission ee.an~n~ 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ®WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ^ Development. ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: 8P Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. _ 12/6/2005 f Z" /Lt' ` ~ 12. Permit to Drill Number 205-159 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded ~: ,c. 4, ~> 12/6/2005 13. API Number 50-029-23284-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/14/2005 14. Well Name and Number: MPH-15 2940 FSL, 4011 FEL, SEC. 34, T13N, R10E, UM Top of Productive Horizon: 2501' FSL, 354` FEL, SEC. 33, T13N, R10E, UM g. KB Elevation (ft): 69.96 15. Field !Pool(s): Milne Point Unit / Schrader Bluff Total Depth: 1528' FSL, 2352' FEL, SEC. 33, T13N, R10E, UM 9. Plug Back Depth (MD+TVD) 6767 + 3974 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 55 6633 f y- 6010091 'Zone- ASP4 10. Total Depth (MD+TVD} 6800 + 3973 `~ Ft 16. Property Designation: ADL 025906 _ _ TPI: x- 555015 y-`6009641 Zone- ASP4^ Total Depth: x- 553026 Y- 6008653 Zone- ASP4 11 • Depth where SSSV set N/A MD 17. Land Use Permit: ___~-~-~-----~-- -~--~---~---^-~- -~-~-~--~-~-- f Thi f P t 0 k 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL ness o erma ros . 2 c 1800 {Approx.) 21. Logs Run: Gyro , DIR/GR , IFRICASANDRA , RES , PWD , SCMT , NEU/DEN , USIT , CCL 2. ASING, LINER AND EMENTING RECORD ..CASING ETTiNG EPTH MO ET'rINCi EPTH TVD I..1o~ MOUNT .SIZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 35' 1 i 4' 35' 114' 42" 60 sx Arctic Set A rox. 9-518" 40# L-80 35' 2899' 35' 2728' 12-1 /4" 44 sx AS Lite, 411 sx Class 'G' 7" 26# L-80 33' 5653' 33' 4022` 8-314" 41 sx Class 'G' 3-112" 9.3# L-80 5511' 6800' 4031' 3973' 6-1/8" 237 sx Class 'G' 23. Perforations open to Produc tion (MD + N D of To"p and " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-112" Gun Diameter, 6 SPF 4-112" Gun Diameter, 6 SPF 3-112", 9.2#, L-80 5550' 4428' & 4546' MD TVD MD TVD Schrader'OA' Schrader'OA' Schrader'NB' Schrader'NB' 25 ACID,, FRACTURE, CEMENT SQUEEZE, ETC. 6400' - 6650' 4002' - 3981' 4493' - 4535' 4040' - 4063' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED chra er Schrader Freeze Protected with 66 Bbls of Diesel 'N /ND' 'NCMD' 4605' - 4645' 4098' - 4116' , 5255' - 5315' 4098' - 4081' 26. PRODUCTION TEST Date First Production: Not on Injection Method of Operation (Flowing, Gas Lift, etc.): NIA Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-O!L RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary).. Submit core chips; if none, state "none". S ~~ ,`A~ ~ i 10~fi - None ~ I ~ _.L_2 %~~~ -. -,;„ R `a " ` t Form 10-407 Revised 1212003 " ~""'~ ~ ~ ~~~C#JgIT~UED ON REVERSE SIDE f /V.~ ~~ GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". TMA 3970' 3668' None TMBi 3978' 3675' TMB2 4036' 3724' TMC 4204' 3857 TNA 4253' 3891' TNB 4297 3919' TNC 4342' 3947' THE 4374' 3967' TNF 4439' 4008' TOA 4488' 4037' BOA/TSBC 4540' 4065' TOB 4600' 4095' BOB 4650' 4118' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and aLeak-Off Test Summary. 3i. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra wman Title Technical Assistant Date ~ ~ - ~~ -(~~ MPH-15 205-159 Prepared ByWame/Number. Sondra Stewman, 564-4750 Well Number Permit No.1 A royal NO. Drilling Engineer: John ROSe, 564-5271 INSTRUCTIONS GErrEaAL: 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in teet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List alf test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Oniy TREE: 3-118" - SM FMC WELLHEAD: 11" x 3-1l8" 5M en 5 Tub Hgr. bt" x 3-1l8" TC-il T&B 3" CIW-N BPVT ' Conductor 112' KOP @ 600` Angie passes 50° @ 4,250' Max Angie in Tbg = 76° @ 4,700' Angle thru liner = 90+° 9 - 5/8" 40# L-80 BTC Csg. 2,899' "RA" Tag 4,364` Schrader °NB" Perfs SPF MD ND 4,493`-4,535' 4,040`- 4,062' 4.5" HSD 6 spf PJ4505 Schrader "NCIND" Perfs SPF MD ND 4,605`-4,645' 5,255`-5,315' 4,097`- 4,116' 4,098` - 4,081' 4.5" HSD 6 spf PJ4505 Baker Tie back slv. Baker ZXP Packer Baker HMC Liner Hgr. Baker 80-40 Seal Bore ext. 2-1f2" HSD 6 SPF. PJ Omega DATE REV. BY COMMENTS 12/19/05 MDO Drilled & Completed Doyon - 14 Schrader "OA" Perfs SPF MD ND 6 6,400' - 6,650' 4,002'-3,960' Or Elev. = 70.00 Doyon 14'+ O :Elev. = 34.20 Doyon 14 3.5" HES X-Nipple 2.813" 3,018` 3.5" HES X-Nipple 2.813" 4,377` 7" x 3,5" Baker Premier pkr. 4,429' 3.5" x 1.5" Camco MMG (rk) 4,486' 7" x 3.5" Baker Premier pkr. 4,546' 3.5" x 1.5" Camco MMG (rk) 4,582` 3.5" x 1.5" Camco MMG-W (rk) 4,620` 3.5" HES X-Nipple 2.813" 4,659' 3.5" HES XN-Nipple 2.750" id. 4 689` ( 2.813" pkg. bore ) , Baker 806-40 Seal Assy bottom 7 "float collar {PBTD) 5,571' ' 7 "Weatherford float shoe 5,653' 3.5" Baker Landing Callar Halliburton Float collar 3.5" Baker float shoe MILNE POINT UNIT WELL MPN-15 API NQ: 50-029-23284-00 BP EXPL4RATlON BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: MPH-15 MPH-15 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 12/1 /2005 Rig Release: 12/19/2005 Rig Number: 14 Date I~ From - To I Hours ~i Task ~i Code II NPT ~ ' Phase _-_-----I-----~ -_1--- ~ ~ ---~---- ------ 12/3/2005 19:00 - 23:30 4.50 MOB P PRE 23:30 - 00:00 0.50 MOB P PRE i2/4J2005 00:00 - 03:30 3.50 MOB P PRE 03:30 - 15:00 11.50 MOB P PRE 15:00 - 16:00 1.00 MOB P PRE 16:00 - 18:30 2.50 MOB P PRE 18:30 - 22:00 3.50 MOB P PRE 22:00 - 00:00 2.00 MOB P PRE 12!512005 00:00 - 02:30 2.50 MOB P PRE 02:30 - 03:00 0.50 MOB P PRE 03:00 - 05:00 2.00 MOB P PRE 05:00 - 08:30 3.50 RIGU P PRE 08:30 - 09:00 0.50 RIGU P PRE 09:00 - 11:00 2.00 RIGU P PRE 11:00 - 18:30 7.50 DRILL P SURF 18:30 - 21:30 3.00 DRILL P SURF 21:30 - 22:00 0.50 DRILL P SURF 22:00 - 22:30 0.50 DRILL P SURF 22:30 - 23:30 1.00 DRILL P SURF 23:30 - 00:00 0.50 DRILL P SURF 12/6/2005 00:00 - 01:00 1.00 DRILL P SURF 01:00 - 02:30 1.50 DRILL P SURF 02:30 - 03:00 0.50 DRILL P SURF 03:00 - 03:30 0.50 DRILL P SURF 03:30 - 04:30 1.00 DRILL P SURF 04:30 - 06:30 2.00 DRILL P SURF 06:30 - 07:00 0.50 DRILL P SURF 07:00 - 00:00 17.00 DRILL P SURF 12/7/2005 100:00 - 05:00 5.00 ~ DRILL P 1 SURF 05:00 - 06:30 1.50 DRILL P SURF 06:30 - 07:30 1.00 DRILL P SURF 07:30 - 08:30 1.00 DRILL P SURF 08:30 - 09:30 1.00 DRILL P SURF 09:30 - 14:30 5.00 DRILL P SURF 14:30 - 16:00 1.50 DRILL P SURF 16:00 - 18:00 2.00 DRILL P SURF 18:00 - 19:00 1.00 DRILL P SURF 19:00 - 20:30 1.50 DRILL P SURF 20:30 - 22:30 2.00 DRILL P SURF 22:30 - 00:00 1.50 DRILL P SURF 12f8l2005 00:00 - 01:30 1.50 DRILL , P SURF Page 1 of 6 Spud Date: 12/6/2005 End: 12/13/2005 Description of Operations Rig up front booster Skid floor from drlg position to move position Skid rig floor -Move rig off Well S-90 -Install back booster Moving rig from S-Pad to H-Pad Remove front booster's Replace shaker beds in pits Remove back boosters -Install stairs - Celler heaters -Surface bag Prepare rig to move over well H-15i Spot rig over well -Shim rig PJSM -Skid rig floor from move position to drlg position RU floor -Spot rock washer -Berm same -Close celler doors plug gaps to warm up celler -Straighten up pipe shed -Prepare to load 4" DP - 5" HWDP -Steam -water circulating Accept rig C~3 05:00 hrs - NU Diverter system -Load pipe shed with 5" HWDP -Jars -Flex DC's - 4" DP 207 Perform Pre spud derrick inspection Load pipe shed with 4" DP PU 4" DP -Stand back in derrick PU 5" HWDP -Stand back in derrick Function test Accumulator -John Crisp with AOGCC wavied witness of test Pre Spud meeting with Crew -Sperry Sun Directional 1 MW DJGyro -Town engineers -Mud engineer Cut drlg line -Service top drive Moblize BHA to beaver slide Moblize BHA to rig floor MU BHA RU Gyro survey equipment Fill conductor -Stack -Riser -Check for leaks on surface - Diverter system -Circ through surface system Drill from 114' to 248' POH to PU Flex Dc's & orient MWD RIH to 248' & gyro survey Drilling f/ 248' to 1570' with 500 gpm, 60 rpm, 1900 psi, run Gyros to 950' Drilling 1570' to 2241' with 500 gpm, 60 rpm, 1900 psi, Hydrates started @ 1850' to 2100' CBU 2.5 x- R&R DP 40 rpm- 2k tq.- 500 gpm 1950 psi Monitor well- Pump out to HWT. (710') w! full drlg. rate RlH to 2141' Break circ.- Wash last stand down- Encountered heavy "clay balls "- Blanked off shaker screens- Circ. hole clean 170-250 gpm- 400-700 psi. Drilling f/ 2241' to 2914' (12 1/4" TD ).550 gpm, 2380 psi, 80 rpms, Encaur~tered hydrates at 2625' to 2750'. CBU 3X. R&R DP- 550 gems, 2380 psi, 80 rpms Pump out to HWDP with full drilling rate RIH, wash last stand to bottom Circ, Three bottoms up with 550 gpm, 2380 psi, 80 rpms Pump out to HWDP with full drilling rate POH, laying down BHA Laying down BHA, clear floor Printed: 12/21/2005 1:51:32 PM • BP EXPLORATfON Page 2 of 6 Operations Summary Report Legal Well Name: MPH-15 Common Well Name: MPH-15 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 Date I From - To ~ Hours ~ Task j Code I - ~-- --~ ~ 12/8/2005 01:30 - 03:00 1.50 CASE P 03:00 - 07:30 4.50~CASE P Start: 12/1 /2005 Rig Release: 12!19!2005 Rig Number: 14 Spud Date: 12/6/2005 End: 12/13/2005 07:30 - 08:00 0.50 CASE P SURF 08:00 - 09:30 1.50 CASE P SURF 09:30 - 12:30 I 3.001 CEMT I P I I SURF 12:30 - 15:30 I 3.001 CASE I P I I SURF 15:30 - 17:00 1.50 CASE P SURF 17:00 - 18:00 1.00 CASE P SURF 18:00 - 00:00 6.00 CASE P SURF 12/9/2005 00:00 - 03:30 3.50 CASE P SURF 03:30 - 04:30 1.00 CASE P SURF 04:30 - 05:30 1.00 CASE P SURF 05:30 - 06:30 1.00 CASE P SURF 06:30 - 07:00 0.50 CASE P SURF 07:00 - 07:30 0.50 CASE P SURF 07:30 - 09:30 2.00 CASE P SURF 09:30 - 10:30 1.00 CASE P SURF 10:30 - 11:00 0.50 CASE P SURF 11:00 - 12:00 1.00 CASE P SURF 12:00 - 12:30 0.50 CASE P SURF 12:30 - 13:00 0.50 CASE P SURF 13:00 - 14:00 I 1.001 CASE I P I I SURF 14:00 - 14:30 0.50 CASE P SURF 14:30 - 00:00 9.50 DRILL P INT1 12/10/2005 00:00 - 01:00 1.00 DRILL P INT1 01:00 - 02:00 1.00 DRILL P INT1 02:00 - 03:30 1.50 DRILL P INT1 03:30 - 04:00 0.50 DRILL P INT1 04:00 - 04:30 0.50 DRILL P INT1 04:30 - 00:00 19.50 DRILL P lNT1 Description of Operations NPT it Phase Rig up to run csg, PJSM Picking up 9 5/8 40# L-80 BTC Csg.- PU hanger- Land casing at 2899' shoe depth. Final down wt. 125k RD Franks tool - RU cement head & hoses. Condition mud & circ. 2 casing volumes (440 bbls. )- Break circ. w/ 3 bpm 240 psi- Bring up to 8 bpm 300 psi- Good returns throughout. PJSM w/ crew and all involved w/cement operation- Pump cement- 5 bbls H2O-test lines to 3000 psi- 10 bbls H2O- 25 bbls CW 100- 70 bbls 10.0 ppg Mud push wf 1 gal. dye in 1st 5 bbl.-Drop btm plug-Lead, 275 bbls 10.7 ppg ASL w/ 5.5-6 bpm- 285-300 psi- Tail 85 bbls 15.8 ppg class "G" cement w/ 3% BWOC S-001 Accelerator + .25% BWOC w13.7 bpm- 275-390 psi.- Drop top plug- 30 bbls H2O- Displace w/ rig pumps at 7 bpm- Bump plug w/ 1810 stks.- 1800 psi.( 1000 psi over final circ. press. )- Bleed off- Check floats- OK- CIP @ 12:10 hrs, 114 bbls of good cement to surface RD cement head & casing equip.- Clear floor- Flush lines & Diverter system- LD landing joint ND Diverter line & remove Annular dverter. Nipple up speed head and test to 1000 psi for 10 min. Nipple up BOPS, change out choke spool Test Bops and Manifold with 250-3500 psi for 5 min per test, Annular 250-2500 psi 5 min per test, the right to witness was waver by Jeff Jones AOOGC, test was witness by WSL, install wear ring Lay down excess HWDP Picking up BHA #2 Up load MWD- Surface test MWD 475 gpm 800 psi PJSM- Load MWD w/ Nue/Den. Continue MU BHA RIH- Wash last stand down to 2805'- 40 RPM- 3k Tq- 420 gpm 1510 psi Circ. 15 min.- RU for casing test. Test 9 5/8" casing to 2000 psi f/ 30 min.- Record on chart. Drill plugs, FC @ 2812'- Cement- Shoe Q 2899'- Clean out old hole to 2914'. Drill 20' of new hole to 2934'. CBU- PJSM on displacing mud. Pump sweep- Displace well w/ 9.0 ppg LSND mud C~ 400 gpm 1500 psi RU to perform FIT- Attempt FIT to 13.7 EMW- Formation broke over at 13.63 EMW- MW= 9.0- Press= 660 psi. Shoe TVD = 2741'. RD test equip.- Blow down choke & kill lines. Drill 2934' to 4043' with 2500 psi, 500 gpm, 80 rpms, ECD 9.8, TO 5k, AST 1.52, ART 4.43 Drill 4043' to 4139' with 2500 psi, 500 gpm, 80 rpms Circ, three bottoms up with 500gpm. 2500 psi, 80 rpms Pump out to Csg shoe @ 2899 with full drilling rate. Circ bottoms up Q 2899', no Clay balls RIH, wash last stand to bottom Drill 4i 39' to 5481' with 3200 psi, 550 gpm, 80 rpms, AST 9.85 ,ART 2.08, ECD 10.3, Tq 5K ~- SURF SURF Printed: 12/21/2005 1:51:32 PM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 3 of 6 MPH-15 MPH-15 Spud Date: 12/6!2005 DRILL+COMPLETE Start: 12/1!2005 End: 12/13/2005 DOYON DRILLING INC. Rig Release: 12/19/2005 DOYON 14 Rig Number: 14 Date 1 From - To I Hours I Task I Cod -------I--- I~---~-- -- ~ - 12/11/2005 ~ 00:00 - 02:00 ~ 2.00 ~ DRILL ~ P 02:00 - 04:00 I 2.001 DRILL I P 04:00 - 07:00 3.00' DRILL P 07:00 - 08:30 1.50 DRILL P 08:30 - 10:30 2.00 DRILL P 10:30 - 13:00 I 2.501 DRILL I P 13:00 - 15:00 2.00 DRILL P 15:00 - 16:00 1.00 DRILL P 16:00 - 19:00 3.00 DRILL P 19:00 - 20:30 1.50 CASE P 20:30 - 22:00 1.50 CASE P 22:00 - 00:00 2.00 CASE P 12112!2005 00:00 - 05:00 5.00 CASE P 05:00 - 06:30 I 1.501 CASE I P 06:30 - 07:30 1.00 CASE P 07:30 - 08:30 1.00 CASE P 08:30 - 10:00 I 1.501 CEMT I P 10:00 - 11:00 I 1.001 CASE I P 11:00 - 12:00 1.00 CASE P 12:00 - 12:30 0.50 CASE P 12:30 - 14:00 1.50 CASE P 14:00 - 14:30 0.50 CASE P 14:30 - 15:30 1.00 CASE P 15:30 - 16:30 1.00 CASE P 16:30 - 18:30 2.00 CASE P 18:30 - 19:30 1.00 CASE P 19:30 - 20:30 1.00 I CASE P 20:30 - 22:30 2.00 CASE P 22:30 - 00:00 1.50 CASE P i ~ NPT i Phase ~ Description of Operations INT1 Drill 5481' to 5654' TD with 3200 psi, 550 gpm, 80 rpms, ECD 10.2 INT1 Circ four bottoms up with 80 rpms, 550 gpm, 3000 psi ECD 10.0 INT1 Pumping out with full drilling rate to 2899' (9 518" shoe). INT1 Flow check- RIH, wash last stand to bottom. INT1 Circ four bottoms up with 80 rpms, 550 gpm, 3200 psi- Spot "G-seal" casing running pill at bit. INT1 Pumping out (first 5 stds 200 gpm stringing out pill) with full drilling rate to 9 5/S" shoe at 2899'. INT1 Flow check, POH to HWDP INT1 LD HWDP INT1 PJSM- LD DEN/NEU tools.,MWD, Motor INT1 PJSM, Pull wear ring, set test plug,change out top rams to 7", test door seals to 1500 psi INT1 PJSM, Rig up to run 7" Csg INTi Picking up 7' 26# L-80 csg INTi Picking up 7" 26# L~80 btc csg, Circ csg volume @ 2899', get up and down wts. every 10 jts, break circ. every 25 jts., total jts run 137 INT1 Washed last jt to bottom @ 5654'. with 5 bbls min. 500 psi, circ. csg. volume + with franks tool. Wong tt~g ~0 ft. Obtain parameters- PU 150k- SO- 130k INT1 RD Franks fillup tool- RU cmt. head. INTi Break circ. w/ 3 bpm 250 psi- PU & Work pipe 20' strokes- Bring pumps up to 5 bpm 270 psi. PU 150k- SO 130k. Ciracasing volume +. Reciprocate. pipe t(}'-strokes ttrroughout circulation. INTi Pump cement- 5 bbls H2O- test lines to 3000 psi- 25 bbls CW-100- 40 bbls 10.6 ppg mud push spacer 5.5 bpm 325 psi- Drop btm plug- 95 bbls 15.8 ppg class "G" cement w/ 2.0% D600G + .2% D047 + 3.0% D174 + .2% D185 + .1 % D800 retarder- 5.5 bpm, 335 psi, PU 150k- SO 130k- Drop top plug & kick out wf 10 bbls H2O- Displace wf rig pumps- 8 bpm 570 psi wf 9.3 ppg mud- Reciprocate pipe 20' throughout displa~ernent- Bump plug w12019 stks.- 1600 psi (1000 psi over final circ. pressure )- CIP @ 10:00 hrs. Bleed press.- Check floats- OK INT1 Close annular preventer- Pump 45 bbls mud down 9 5/8" X 7" annulus- Bleed off press.- Got 15 bbls back- Pump 25 more bbls.- Bleed off- Got i4 back- Total of mud pumped away = 41 bbls. INT1 RD cement head- Blow down 7" casing for cut. INT1 Clear floor- LD cmt head- casing equip. INT1 ND flowline, fill up line- PU BOP's- INT1 Set emergency slips- PU to 207k (blocks 55k ). INT1 Cut 7" w/ Wachs cutter- LD landing jt. INTi Install packoff- Test to 4500 psi- Hold 10 min. INT1 Nipple up BOPS INT1 Change top rams, test rams and door seals to 250-3500 psi for 5 min. per test, test witness by WSI INT1 Install wear ring, Mobilize BHA INT1 Picking up BHA #3 INT1 e Uploading MWD tool Printed: 12/27/2005 1:51:32 PM BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: MPH-15 Common Welt Name: MPH-15 Spud Date: 12/6/2005 Event Name: DRILL+COMPLETE Start: 12/1/2005 End: 12/13/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 1211912005 Rig Name: DOYON 14 Rig Number: 14 Date li From - To ! Hours j Task i Code j NPT I Phase Description of Operations 12/13/2005 00:00 - 01:00 1.00 CASE P INT1 01:00 - 03:00 2.00 CASE P INT1 03:00 - 04:30 1.50 CASE P INT1 04:30 - 05:00 0.50 CASE P INT1 05:00 - 06:30 1.50 CEMT P INT1 06:30 - 07:30 1.00 CASE P INT1 07:30 - 09:00 1.50 DRILL P PROD1 09:00 - 00:00 15.00 DRILL P PROD1 12/14/2005 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 01:30 1.00 DRILL P PROD1 01:30 - 03:00 1.50 DRILL P PROD1 03:00 - 03:30 0.50 DRILL P PROD1 03:30 - 04:30 1.00 DRILL P PROD1 04:30 - 07:00 2.50 DRILL P PROD1 07:00 - 08:00 1.00 DRILL P PROD1 08:00 - 10:00 2.00 DRILL P PROD1 10:00 - 13:00 3.00 DRILL P PROD1 13:00 - 14:30 1.50 CASE P PROD1 14:30 - 18:00 3.50 CASE P PROD1 18:00 - 21:00 3.00 CASE P PROD1 2.1:00 - 21:30 0.50 CASE P PROD1 21:30 - 22:30 1.00 CASE P PRODi 22:30 - 00:00 1.50 CASE P PROD1 12/15/2005 100:00 - 01:00 I 1.001 CASE I P I I PROD1 01:00 - 01:30 I 0.501 CEMT A P I I RUNPRD 01:30 - 02:00 I 0.501 CEMT I P I I RUNPRD 02:00 - 02:30 I 0.501 CASE I P I I RUNPRD 02:30 - 03:00 0.50 CASE P RUNPRD 03:00 - 05:00 2.00 CASE P RUNPRD 05:00 - 06:00 I 1.001 CASE I P I ~ RUNPRD 06:00 - 08:30 2.50 CASE P RUNPRD 08:30 - 09:00 0.50 CASE P RUNPRD 09:00 - 10:00 1.00 PERFO P LOWERI 10:00 - 19:30 9.50 PERFO P LOWERI 19:30 - 20:00 0.50 PERFOB~ P LOWERI 20:00 - 21:00 1.00 PERFO P LOWERI 21:00 - 00:00 I 3.00 { PERFOS P f I LOW ER1 Pulse test MWD, Load sources RIH to 5331' Slip and cut dril{ line, service top drive wash to 5571' Drill float @ 5571' and shoe track, drill new hole to 5674' Circ bottoms up, displace hole with new 9.3 mud Fit test with 400 psi, 9.3 MW, TVD 4023= 11.2 EMW Drill 5674' to 6770' with 80 rpm, 300 gpm 2380 psi, AST 2.43, ART 5.04 Drill 6770' to 6800 TD with 80 rpm, 300 gpm 2380 psi Circ, three bottoms up with 325 gpm, 2700 psi, 80 rpms Pump out to Csg shoe C~3 5653' with full drilling rate. RIH, Wash last stand to bottom, Circ. three bottoms up with 325 gpm, 2700 psi Pump out to 4200' with full drilling rate. Circ, bottoms up from 4200' Poh to Bha Laying down BHA #3 Clear floor, PJSM, rig up to pick up Liner Picking up 3.5 9.2 L-80 IBT liner total of 40 jts, Baker 80-40 seal bore, HMC hanger and ZXP liner top packer RIH with liner to 5650' Circ bottoms up @ 5650 Rih to bottom ~ 6800' Circ, 6 bbls min. 1200 psi, thin mud for cement job, reciprocate finer 20 ft. Circ, 6 bbls min. 1200 psi, thin mud for cement job, reciprocate liner 20 ft. Cement with Schlumberger, with 5 bbls water,test lines to 4500,20 bbls CW100,25 bbls Mud push mixed @ 10.5, 50.6 bbls, 237 sxs. Class G, mixed ~ 15.8, drop top plug, washed lines, 15 bbls 9.3 brine Displace with rig pumps 54.4 bbls. mud, bump plug with 2800 psi, pressure up to 4000 psi to set packer, release from hanger, pressure to 1000 psi and pickup out of hanger, Circ out cement with 8 bbls min. 1450 psi, 2(Af~bts cement to surface Lay down liner TD head, two jts of pipe Circ work pipe 90 ft., circ with 8 bbls min. 1200 psi, Prepare pits for displacement Displace well with 35 bbl 9.3 hi- vis H2o spacer, 50 bbl Brine, 35 bbls hi vis spacer, 9.3 brine Poh with running tool lay down running tool PJSM, clear floor, Rig up Schlumberger E-line Running in vaith GR1U5-T/CCL with Tractor to 550, k3g to 3000 ft', top of cement 3307 Rig down wire line truck Test csg and liner lap with 2500 psi for 30 min., good test, blow down lines Moblize tools,PJSM, Picking up Schlumberger 2.5 guns 6 shots per ft, 35 jts 2 1116 CS hydrill pipe, and 4.5 HSD gun 5 Printed: 12/21/2005 1:51:32 PAA • BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: MPH-15 Common Well Name: MPH-15 Spud Date: 12/6/2005 Event Name: DRILL+COMPLETE Start: 12/1/2005 End: 12/13!2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/19/2005 Rig Name: DOYON 14 Rig Number: 14 Date I~ From - To j Hours ~~ Task ~ Code I NPT ! Phase 12/15!2005 21:00 - OO:OO I - - 3.00 - l_ - - i - - 12/16/2005 00:00 - 02:00 2.00 PERFO~P LOWERI 02:00 - 05:00 3.00 PERFO P LOWERI 05:00 - 06:00 1.00 PERFO P LOW ER1 06:00 - 11:00 5.00 PERFO P LOWERI 11:00 - 11:30 0.50 PERFO P LOWERI 11:30 - 12:00 0.50 PERFO P LOWERI 12:00-13:00 ~ 1.OO~PERFOB~P ~ ~LOWERI 13:00 - 15:00 2.00 PERFO P LOWERI 15:00 - 21:00 6.00 PERFO P LOWERI 21:00 - 22:00 1.00 PERFO P LOWERI 22:00 - 00:00 2.00 PERFO P LOWERI 12/17/2005 00:00 - 01:30 1.50 PERFO P LOWERI 1 01:30 - 03:00 I 1.50 PERFO P LOWERI 03:00-05:00 { 2.OOfPERFOBIP I ILOWERI 05:00 - 05:30 0.50 PERFO P LOWERI 05:30 - 07:00 1.50 PERFO P LOWERI 07:00 - 08:30 1.50 PERFO P LOWERI 08:30 - 10:30 2.00 PERFO P LOWERI 10:30 - 13:00 2.50 PERFO P LOWERI 13:00-15:301 2.501PERFOBIP I ILOWERI 15:30 - 17:30 I 2.001 RUNCONiP I I RUNCMP 17:30 - 23:30 6.00 BUNCO RUNCMP 23:30 - 00:00 0.50 BUNCO RUNCMP 12/1812005 00:00 - 00:30 0.50 BUNCO RUNCMP OU:30 - 01:00 0.50 BUNCO DPRB RUNCMP 01:00 - 02:00 1.00 BUNCO DPRB RUNCMP 02:00 - 03:00 1.00 BUNCO DPRB RUNCMP 03:00 - 03:30 0.50 BUNCO DPRB RUNCMP 03:30 - 04:00 0.50 BUNCO DPRB RUNCMP 04:00 - 04:30 0.50 BUNCO DPRB RUNCMP 04:30 - 05:00 0.50 BUNCO DPRB RUNCMP 05:00 - 05:30 0.50 BUNCO DPRB RUNCMP 05:30 - 06:00 0.50 BUNCO . RUNCMP 06:00 - 07:00 1.00 BUNCO RUNCMP 07:00 - 15:30 8.50 BUNCO RUNCMP 15:30 - 18:00 I 2.501 RUNCONYIP I I RUNCMP i 8:00 - 20:00 ~ 2.00 ~ RUNC01~1P ~ ~ RUNCMP Description of Operations shots per ft. PJSM, Finish Picking up Schlumberger 2.5 guns 6 shots per ft, 35 jts 2 1116 CS hydrill pipe, and 4.5 HSD gun 5 shots per ft. Tripping in with guns to 6652.27, space out in place PJSM, Rig up E-line truck Made two runs for depth control, guns on depth Rig down wire line truck PJSM on firing guns to peforate @4493' to 4535', 4605' to 4645', 5255' to 5315', 6400' to 6650' Shut hydrill, pressure up on annulus to 2600 psi, held pressure for 3.5 min., bled of, wait for 18 mins. ,one guns fired, waited additional 18 min. for second guns , no indication of second guns going off, fill hole with 18 bbls brine Poh with 4' Dp, hole taking 10 bbls brine hr. PJSM, Laying down guns and 2 1/16 CS hydrill, (all guns fired) Clear rig floor Mobilize BHA, picking up BHA #4 RIH to 4300', hole taking 2-3 bbls hr. Wash and ream 4300' to 5500', tag top of liner « 5510 with 10 bbls min. 1900 psi, hole taking app 4-5 bbl hr. Pump hi- vis pill, back reaming 5500 to 4300, 11 bbls min. 2000 psi, hole taking 4-5 bbl hr. Pump hi- vis pill, Circ bottoms up C~3 4300 with 11 bbls min: Flow check, POH Clean out junk subs, small recovery, clear rig floor PJSM with slick line crew„ rig up slick line unit Rih with 5.95 gauge ring and junk basket, to 4821, POH ,clean out junk basket, gun junk recovery Rerun 5.95 gauge ring and junk basket, to 4835, POH ,clean out junk basket, gun junk recovery, rig down slick line unit PJSM, Rig up to run 3.5 TCII tubing, install long bales, compensator PJSM, Picking up 3.5 9.2# L-80 TCII tubing, total 65 jts R/u to test tubing to 3500 psi. Attemp to test tubing to 3500 psi, test failed, 65 jts in hole PJSM, pull and lay down 15 jts of tubing Rig up and test tubing to 3500 psi and record on chart, good test, checking the 15 jts that was layed down Picking up 8 jts of tubing total of 58 jts in hole Rig up and test tubing to 3500 psi, good test Picking up 7 jts tubing total of 65 jts in hole Rig up and test tubing to 3500 psi,test failed Pull 3 jts, 62 jts in hole, Pressure up to 3500 psi for 10 min., record on chart Picking up 3.5 9.2 TCII tubing, change out jts 63,64,65 Test tubing with 3500 psi for 10 min. good test Picking up tubing 167 jts total, test tubing to 3500 for 10 min. every 20 jts, total jts picked up 167 jts 3.5 TCII 9.2# L-80 Space out, with 3.75 pup one jts below hanger, land hanger, rig up to test landing jt. leaking Pull hanger and back out landing jt, service threads, land hanger, rig up and test tubing to 3500 psi for 10 min. good test Printed: 12/21/2005 1:51:32 PM • BP EXPLORATION Operations Summary Report Page 6 of 6 Legal Well Name: MPH-15 Common Wefl Name: MPH-15 Spud Date: 12/6/2005 Event Name: DRILL+COMPL ETE Start: 12/1/2005 End: 12/13/2005 Contractor Name: DOYON DRILLI NG INC. Rig Release: 12/19/2005 Rig Name: DOYON 14 Rig Number: 14 i Date I From - To j Hours I Task I Code j NPT I Phase I~, Description of Operations 12/18/2005 20:00 - 21:00 1.00 RIGD P RUNCMP PJSM, Rig up slick line truck 21:00 - 22:30 i .50 RIGD P RUNCMP Run slick line and pull D-16 plug 22:30 - 00:00 1.50 RIGD P RUNCMP RIH with Gr/Ccl to RHC-m plug in X nipple C~3 4654' and log up to 4000' ft. 12/19/2005 00:00 - 01:00 1.00 RIGD P RUNCMP RIH with Gr/Ccl to RHC-m plug in X nipple @ 4654' and log up to 4000' ft., Poh 01:00 - 01:30 0.50 RIGD P RUNCMP Reading logs from slick line 01:30 - 02:30 1.00 RIGD P RUNCMP Pump 50 bbls 9.3 with Inhibited brinedown annulus 2 bblsmin., 1350 psi follow by 66 bbls diesel for freeze protect 02:30 - 03:00 0.50 RIGD P RUNCMP Pump 5 bbls brine, down tubing 1 bbl min 850 psi, drop ball and rod 03:00 - 04:00 1.00 RIGD P RUNCMP Set packer with 2500 on tubing, open annulus, raise tubing press to 4200 psi, shut in and test tubing on chart for 30 min. good test, 04:00 - 05:00 1.00 RIGD P RUNCMP Bled tubing to 1500 psi, pressure annulus to 3000 psi with hot oil, recort on chart for 30 min. good test 05:00 - 06:30 1.50 RIGD P RUNCMP Rig up slick line, pull ball and rod 06:30 - 07:30 i.00 RIGD P RUNCMP Install to way check, test to 1500 psi 07:30 - 08:00 0.50 RIGD P RUNCMP Nipple down BOPS 08:00 - 12:00 4.00 RIGD P RUNCMP Install adapter flange, test to 5000 psi 12:00 - 13:30 1.50 RIGD P RUNCMP Install tree and test to 5000 psi, pull TWC and install BPV with lubricator, secure tree, freeze protect tubing with 22 bbls diesel 13:30 - 19:00 5.50 RIGD P RUNCMP Laying down drill pipe out of derrick in mouse hole, Rig release 1900 hrs 12/19/2005 Printed: 12/21/2005 1:51:32 PM Printed: 12/21/2005 1:51:26 PM Halliburton Global I Company: BP Amoco Date: 1/9/2006 Time: 20:04:06 Page: 1 i Field: Milne Point Co-ordinate(NE) Reference: Well: MPH-15, True North , I Site: M Pt H Pad Well: MPH-15 Vertical (TVD) Reference: MPH-15: 69.9 ~ Section (VS) Reference: Well (O.OON,O.OOE,248.69Azi) Wellpath: MPH-15 Survey Calculation M ethod: MinimumGurvature bb: Oracle Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Wel{ Centre Sys Datum: Mean Sea L evel Geomagnetic Model: bggm2005 We1L• MPH-15 Slot Name: Well Position: +N/-S 1110.36 ft Northing: 6010091.32 ft Latitude: 70 26 17.584 N +E/-W 1236.54 ft Easting : 556633.05 ft Longitude: 149 32 17.602 W Position Uncertainty: 0.00 ft Wellpath: MPH-15 Drilled From: Well Ref. Point 500292328400 Tie-on Depth: 34.15 ft Current Datum: MPH -15: Height 69.95 ft Above System Datum: Mean Sea Level Magnetic Data: 12/2/2005 Declination: 24.32 deg Field Strength: 57574 nT Mag Dip Angle: 80.88 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.15 0.00 0.00 248.69 Survey Program for Definitive Wellpath Date: 1/9/2006 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Name ft ft 100.00 913.60 MPH-15 SRO GYRO (100.00-913.60) CB-GYRO-SS Camera based gyro single shots 986.88 6753.43 MPH-15 IIFR +SAG (986. 88-6753.43) MWD+IFR+MS MWD +IFR + Multi Station Survey - _- _ __ -_ - -_ - - - - - - _- _ _- _ - _- - - J9D Incl 1zim TVD SVS TVI) \(S I'./~~~ ~ Ala \ Ala ~E Cooi i L ft deg deg ft ft ft ft ft ft , i 34.15 0.00 0.00 34.15 -35.80 0.00 0.00 6010091.32 556633.05 TIE LINE 100.00 0.47 33.81 100.00 30.05 0.22 0.15 6010091.55 556633.20 CB-GYRO-SS 167.13 0.59 28.70 167.13 97.18 0.76 0.47 6010092.08 556633.51 CB-GYRO-SS 258.47 0.59 355.89 258.46 188.51 1.64 0.66 6010092.96 556633.70 CB-GYRO-SS 347.63 0.90 290.78 347.62 277.67 2.34 -0.03 6010093.66 556633.01 CB-GYRO-SS 439.40 1.48 275.50 439.37 369.42 2.71 -1.88 6010094.02 556631.15 CB-GYRO-SS 532.30 1.42 281.75 532.24 462.29 3.06 -4.20 6010094.35 556628.83 CB-GYRO-SS 622.90 4.73 240.64 622.70 552.75 1.46 -8.56 6010092.71 556624.48 CB-GYRO-SS 722.00 8.11 234.22 721.17 651.22 -4.63 -17.79 6010086.55 556615.30 CB-GYRO-SS 818.30 9.66 238.43 816.31 746.36 -12.83 -30.19 6010078.26 556602.96 CB-GYRO-SS 913.60 11.00 238.27 910.06 840.11 -21.80 -44.73 6010069.18 556588.49 CB-GYRO-SS 986.88 14.59 240.12 981.51 911.56 -30.08 -58.69 6010060.80 556574.60 MWD+IFR+MS 1038.36 17.57 241.16 1030.97 961.02 -37.06 -71.12 6010053.72 556562.22 MWD+IFR+MS 1133.23 21.44 243.58 1120.38 1050.43 -51.69 -99.20 6010038.89 556534.25 MWD+IFR+MS 1229.67 21.43 241.78 1210.15 1140.20 -67.86 -130.51 6010022.48 556503.07 MWD+IFR+MS 1324.61 23.13 239.76 1298.00 1228.05 -85.46 -161.90 6010004.65 556471.81 MWD+IFR+MS 1421.29 23.09 238.41 1386.92 1316.97 -104.95 -194.46 6009984.91 556439.41 MWD+IFR+MS 1518.12 22.24 235.85 1476.28 1406.33 -125.18 -225.80 6009964.44 556408.23 MWD+IFR+MS 1614.28 22.60 234.86 1565.17 1495.22 -146.03 -255.97 6009943.36 556378.22 MWD+IFR+MS 1709.05 22.16 234.52 1652.80 1582.85 -166.89 -285.41 6009922.28 556348.94 MWD+IFR+MS 1805.40 21.73 235.01 1742.17 1672.22 -187.66 -314.82 6009901.29 556319.69 MWD+IFR+MS 1901.87 20.86 234.36 1832.05 1762.10 -207.91 -343.41 6009880.83 556291.26 MWD+IFR+MS 1995.38 21.71 241.59 1919.20 1849.25 -225.85 -372.16 6009862.68 556262.65 MWD+IFR+MS 2092.72 22.00 245.40 2009.55 1939,60 -242.00 -404.57 6009846.28 556230.36 MWD+IFR+MS 2185.58 23.78 248.06 2095.09 2025.14 -256.24 -437.76 6009831.79 556197.29 MWD+IFR+MS 2283.09 28.23 258.86 2182.76 2112.81 -268.05 -478.66 6009819.67 556156.48 MWD+IFR+MS 2378.62 28.39 260.98 2266.86 2196.91 -275.98 -523.26 6009811.40 556111.95 MWD+IFR+MS 2474,47 27.95 261.69 2351.36 2281.41 -282.80 -568.00 6009804.24 556067.27 MWD+IFR+MS 2570.40 27.56 261.48 2436.25 2366.30 -289.34 -612.19 6009797.37 556023.14 MWD+IFR+MS ' ~ Halliburton Global Company: BP Amoco Date: 119(2006 'Cime: 20:04:06 Pale: 2 I j Field: Milne Point Co-ordinate(NE) Reference: Well: MPH-15, True North I Sitc: M Pt H Pad Vertical (TVD) Reference: MPH-15: 69.9 ~, «'ell: MPH-15 Section (VS) Reference: Well (O.OON,O.OOE,248.69Azi) Well ath: P MPH-15 _ _ _ _ _ _ Survey Calculation Method: Minimum Curvature Dh: Oracle J Survey ~ 31D Incl Azim 1'~"D Sys TVD N(S E/W' - ~1ap\ MapE --- ~ ~ - - Tool 1 ft deg deg ft ft ft ft ft ft 2666.87 27.22 261.81 2521.91 2451.96 -295.78 -656.10 6009790.59 555979.28 MWD+IFR+MS 2763.00 26.84 261.06 2607.54 2537.59 -302.29 -699.30 6009783.76 555936.14 MWD+IFR+MS 2859.01 27.64 262.47 2692.90 2622.95 -308.58 -742.79 6009777.14 555892.70 MWD+IFR+MS 2947.33 26.29 262.80 2771.62 2701.67 -313.71 -782.50 6009771.70 555853.03 MWD+IFR+MS 3037.99 26.56 262.44 2852.81 2782.86 -318.90 -822.52 6009766.22 555813.06 MWD+IFR+MS 3139.80 27.28 263.47 2943.58 2873.63 -324.54 -868.26 6009760.22 555767.36 MWD+IFR+MS 3235.13 27.56 262.26 3028.20 2958.25 -330.00 -911.82 6009754.44 555723.85 MWD+IFR+MS 3331.70 28.33 260.36 3113.51 3043.56 -336.84 -956.55 6009747.25 555679.18 MWD+IFR+MS 3428.43 30.29 261.46 3197.86 3127.91 -344.31 -1003.30 6009739.43 555632.49 MWD+IFR+MS 3524.18 29.65 261.12 3280.80 3210.85 -351.55 -1050.58 6009731.83 555585.27 MWD+IFR+MS 3620.29 29.97 260.51 3364.20 3294,25 -359.18 -1097.75 6009723.85 555538.17 MWD+IFR+MS 3716.75 29.80 260.86 3447.83 3377.88 -366.96 -1145.18 6009715.71 555490.80 MWD+IFR+MS 3813.05 29.29 260.86 3531.61 3461.66 -374.50 -1192.06 6009707.81 555443.98 MWD+IFR+MS 3907.19 28.43 260.43 3614.06 3544.11 -381.89 -1236.89 6009700.09 555399.21 MWD+IFR+MS 4004.12 33.06 263.83 3697.35 3627.40 -388.57 -1285.96 6009693.03 555350.20 MWD+IFR+MS 4050.11 34.40 264.36 3735.59 3665.64 -391.19 -1311.36 6009690.22 555324.82 MWD+IFR+MS 4100.06 35.74 264.70 3776.47 3706.52 -393.93 -1339.93 6009687.27 555296.28 MWD+IFR+MS 4146.55 38.59 261.46 3813.52 3743.57 -397.34 -1367.80 6009683.65 555268.44 MWD+IFR+MS 4196.41 43.15 262.47 3851.22 3781.27 -401.88 -1400.10 6009678.86 555236.18 MWD+IFR+MS 4240.41 47.01 260.05 3882.28 3812.33 -406.64 -1430.88 6009673.87 555205.44 MWD+IFR+MS i 4290.97 51.18 260.82 3915.38 3845.43 -412.98 -1468.55 6009667.24 555167.82 MWD+IFR+MS 4337.78 51.34 260.90 3944.67 3874.72 -418.78 -1504.60 6009661.17 555131.82 MWD+IFR+MS 4386.63 51.23 260.57 3975.23 3905.28 -424.91 -1542.22 6009654.75 555094,25 MWD+IFR+MS 4433.12 50.93 260.50 4004.43 3934.48 -430.86 -1577.89 6009648.53 555058.62 MWD+IFR+MS 4482.77 54.74 260.18 4034.42 3964.47 -437.50 -1616.89 6009641.59 555019.68 MWD+IFR+MS 4535.51 59.32 260.63 4063.12 3993.17 -444.87 -1660.51 6009633.90 554976.13 MWD+IFR+MS 4578.55 60.21 260.34 4084.79 4014.84 -451.02 -1697.18 6009627.47 554939.51 MWD+IFR+MS 4623.65 62.02 259.72 4106.57 4036.62 -457.86 -1736.07 6009620.34 554900.67 MWD+IFR+MS 4670.97 67.13 259.89 4126.88 4056.93 -465.42 -1778.12 6009612.46 554858.69 MWD+IFR+MS 4721.45 71.72 260.45 4144.62 4074.67 -473.48 -1824.67 6009604.04 554812.20 MWD+IFR+MS 4770.88 77.21 259.81 4157.85 4087.90 -481.64 -1871.57 6009595.52 554765.37 MWD+IFR+MS 4819.91 81.54 260.38 4166.89 4096.94 -489.93 -1919.03 6009586.88 554717.98 MWD+IFR+MS 4867.11 85.09 259.12 4172.39 4102.44 -498.27 -1965.16 6009578.19 554671.92 MWD+IFR+MS 4915.22 90.42 258.32 4174.27 4104.32 -507.67 -2012.28 6009568.43 554624.87 MWD+IFR+MS 4963.41 96.05 257.18 4171.55 4101.60 -517.87 -2059.28 6009557.87 554577.96 MWD+IFR+MS 5008.50 99.90 256.92 4165.30 4095.35 -527.88 -2102.79 6009547.54 554534.53 MWD+IFR+MS 5058.62 104.25 254.63 4154.81 4084.86 -539.91 -2150.29 6009535.15 554487.13 MWD+IFR+MS 5107.73 107.65 254.53 4141.32 4071.37 -552.46 -2195.80 6009522.25 554441.72 MWD+IFR+MS 5155.09 107.33 255.47 4127.09 4057.14 -564.15 -2239.43 6009510.23 554398.18 MWD+IFR+MS 5208.23 106.74 255.42 4111.52 4041.57 -576.92 -2288.61 6009497.09 554349.11 MWD+IFR+MS 5250.66 106.82 255.02 4099.27 4029.32 -587.29 -2327.89 6009486.43 554309.91 MWD+fFR+MS 5298.31 106.16 254.01 4085.74 4015.79 -599.49 -2371.92 6009473.90 554265.98 MWD+IFR+MS 5346.61 106.17 251.49 4072.29 4002.34 -613.24 -2416.22 6009459.81 554221.79 MWD+IFR+MS 5393.92 106.80 247.18 4058.86 3988.91 -629.24 -2458.65 6009443.48 554179.48 MWD+IFR+MS 5443.09 104.80 243.11 4045.47 3975.52 -649.13 -2501.57 6009423.27 554136.72 MWD+IFR+MS 5491.30 101.33 241.03 4034.57 3964.62 -671.13 -2543.05 6009400.96 554095.42 MWD+IFR+MS 5538.29 96.37 240.20 4027.35 3957.40 -693.91 -2583.49 6009377.88 554055.15 MWD+IFR+MS 5585.34 92.67 238.42 4023.64 3953.69 -717.84 -2623.82 6009353.64 554015.01 MWD+IFR+MS 5614.55 91.50 236.85 4022.58 3952.63 -733.47 -2648.47 6009337.83 553990.48 MWD+IFR+MS 5667.83 91.52 236.81 4021.17 3951.22 -762.61 -2693.05 6009308.36 553946.12 MWD+IFR+MS 5716.55 92.80 236.71 4019.33 3949.38 -789.29 -2733.77 6009281.37 553905.61 MWD+IFR+MS 5761.62 93.31 236.27 4016.93 3946.98 -814.14 -2771,30 6009256.24 553868.28 MWD+IFR+MS ' ~ ~ Halliburton Global Compan}~: BP AmoCO Date: 1!9/2006 Time: 20:04:06 Page: 3 ~ Field: Milne Point Co-ordinate(NE) Reference: Well: MPH-15 True North ~~ Site: M Pt H P2d Vertical (T'VD) Reference: , MPH-15: 69.9 ~~ We1L• MPH-15 Section (VSj Reference: Well (O.OON,O.OOE,248.69Azi) I ~ Wellpath: MPH-15 Sur~e}~ Calculation Method; Minimum Curvature Db: Oracle Sun ev - ~ _-_ -- MD - incl Azim 1'VD SysTVll N/S E/~V MapN b1apF: Tool ft deg deg ft ft ft ft ft ft 5811.29 94.05 235.22 4013.74 3943.79 -842.04 -2812.27 6009228.03 553827.53 MWD+IFR+MS 5858.38 93.93 233.54 4010.47 3940.52 -869.40 -2850.45 6009200.38 553789.56 MWD+IFR+MS 5905.43 93.19 234.96 4007.55 3937.60 -896.83 -2888.56 6009172.66 553751.66 MWD+IFR+MS 5948.57 90.94 235.28 4005.99 3936.04 -921.49 -2923.93 6009147.75 553716.49 MWD+IFR+MS 6002.79 89.73 235.43 4005.68 3935.73 -952.31 -2968.53 6009116.59 553672.12 MWD+IFR+MS 6050.14 89.55 234.30 4005.97 3936.02 -979.56 -3007.25 6009089.05 553633.61 MWD+IFR+MS 6098.00 88.56 235.65 4006.76 3936.81 -1007.02 -3046.44 6009061.29 553594.64 MWD+IFR+MS 6146.25 87.63 234.23 4008.37 3938.42 -1034.72 -3085.91 6009033.29 553555.38 MWD+IFR+MS 6193.35 88.23 233.96 4010.07 3940.12 -1062.32 -3124.04 6009005.41 553517.47 MWD+IFR+MS 6242.38 89.18 233.15 4011.18 3941.23 -1091.44 -3163.47 6008975.99 553478.27 MWD+IFR+MS 6290.35 90.76 233.59 4011.20 3941.25 -1120.06 -3201.96 6008947.08 553440.00 MWD+IFR+MS 6338.93 95.66 235.64 4008.48 3938.53 -1148.14 -3241.49 6008918.71 553400.69 MWD+IFR+MS 6386.39 95.65 235.57 4003.80 3933.85 -1174.82 -3280.46 6008891.74 553361.92 MWD+IFR+MS 6433.23 95.08 235.94 3999.42 3929.47 -1201.06 -3319.01 6008865.20 553323.58 MWD+IFR+MS 6482.43 95.33 235.51 3994.96 3925.01 -1228.66 -3359.50 6008837.31 553283.30 MWD+IFR+MS 6529.25 94.29 234.20 3991.04 3921.09 -1255.51 -3397.65 6008810.16 553245.36 MWD+IFR+MS 6576.49 94.55 233.88 3987.39 3917.44 -1283.17 -3435.77 6008782.22 553207.45 MWD+IFR+MS 6625.54 95.30 234.01 3983.18 3913.23 -1311.93 -3475.28 6008753.16 553168.17 MWD+IFR+MS 6673.23 94.72 234.76 3979.02 3909.07 -1339.60 -3513.90 6008725.21 553129.76 MWD+IFR+MS 6721.95 92.14 235.22 3976.10 3906.15 -1367.50 -3553.73 6008697.01 553090.15 MWD+IFR+MS 6753.43 92.11 235.95 3974:94 3904,99 -1385.28 -3579.68 6008679.03 553064.34 MWD+IFR+MS -• 6800.00 92.11 235.95 3973.22 3903.27 -1411.33 -3618.24 6008652.69 553025.98 PROJECTED to TD a • 11-Jan-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPH-15 a0J~- ~~~ Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 34.15' MD Window /Kickoff Survey: 6,753.43' MD (if applicable) Projected Survey: 6,800.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Car! Ulrich 6900 Arctic B{vd. Anchorage, AK 99518 Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~'~ ~ ~ ~ r`te' „~ ~ 1 ~ FRANK H. MURKOWSK/, GOVERNOR ~ , ~I[1-7~ O~ ~ ~ ~ 333 W. 7T" AVENUE, SUITE 100 C01~5C' RQA7`IO1Q COrII~IISSIOI~T i ANCHORAGE, ALASKA 99501-3539 ~' PHONE (907) 279-tA33 Dan Kara ~+x (so7> 27s-~5a2 Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK Re.; MPH-15 BP Exploration (Alaska), Inc. Permit No: 205-159 Surface Location: 2940' FSL, 4011' FEL, SEC. 34, T13N, R10E, UM Bottomhole Location: 1564' FSL, 2258' FEL, SEC. 33, T 13N, R 1 OE, UM Dear Mr. Kara: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). DATED this ~~ day of November, 2005 cc: Department of Fish 8s Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA AND GAS CONSERVATION COMI~ITSSION PERMIT TO DRILL 20 AAC 25.005 .~~ t '-~~ ~ X005 Ct1ti~ ia. Type of work ®Drill ^ Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ^ Development Oil . e, ~dt~' Zone ^ Stratigraphic Test ®Service ^ Development Gas ~SingZone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 1i. Well Name and Number: MPH-15 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: 3q-jp MD 6701 TVD ,A~488' 12. Field !Pool{s): '~Nlilne Point Unit 1 Schrader Bluff 4a. Location of Well (Governmental Section): Surface: 2940' FSL 4011' FEL UM r SEC 34 T13N R10E 7. Property Designation: ADL 025906 , , , . , , Top of Productive Horizon: 2499' FSL, 435' FEL, SEC. 33, T13N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 11, 2005 Total Depth: 1564' FSL, 2258' FEL, SEC. 33, T13N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 1560' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 556633 ` - 6010091 ° Zone- ASP4 10. KB Elevation Plan (Height above GL): 70.1 feet 15. Distance to Nearest Well Within Pool 320' to MPI-05 16. Deviated Wells: Kickoff Depth: 300 r feet Maximum Hole Angle: 108 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1785 Surface: 1404 18. ng rogram: Size Specifications Setting Depth To Bottom uantrty o ement c.f. or ticks Hole Casio Wei ht Grade Cou lin Len th MD TVD MD ND includin sta a data 42" 20" 92# H-40 Weld 112' Surface Surface 112' 112' 60 sx Arctic Set A rox. 12-114" 9-5/8" 40# L-80 BTC 3397 Surface Surface 9Tr '- 18 sx AS Lite, 392 sx Class 'G' 8-3/4" 7" 26# L-80 BTC-M 5467 Surface Surfac 98 sx Class 'G' 6-1l8" 3-1/2" 9.2# L-80 IBT-M 1Fet3' 6701' 3970' 78 sx Class 'G' ~t>,3 ~ ~ c® 19. PRESENT WELL CONDITION SUMMARY (To be completed for edrill AND Re-entry Operations) Total Depth MD (ft}: Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casio Len th Size Cement Volume MD ND r Pr 'o Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ® Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Rose, 564-5271 Printed Name Dan Kara Title Senior Drilling Engineer Prepared By Name/Number. Si nature `` _ Phone 564-5667 Date 1 ay o Terrie Hubble, 564-4628 Commission Use Onty Permit To Drill_ Number: ~,~-/' API Number: ~/ 50_ (~ Zg- Z~~7 "[~j Permit Approval Date: See cover letter for other requirements Conditions of Approval: Samples R quired ~ Yes ! No Mud Log Required ^ Yes No Hydro S !fide Measures` ^ Yes ~No Directional Survey Required J~'Yes ^ No Other: ~d~ - ~C?S P ~U~~ V ~ ~ ~~ ~`~~ +~ ea.~~~ ~~Q A~ Q cc~~ h\~ p~r~ Af~.C 3~z~3S 1~,'~C.'~~ , C7eccz,.~c~rs ~EC P+~01~ ~"'" ~ ~ APPROVED BY ~! A roved B ~ _ ~ ~ THE COMMISSION Date ~ w 3 Form to-aot Re~edO oa --' ~ SGbmi~ln Duplicate ~~ .~ ;~ , Well Name: MPH-15 Schrader OA & OB Single Selective Horizontal Injector Drilling and Completion Plan Summary T e of Well: Schrader Bluff OA & OB Sand Horizontal In'ector Surface Location: 2,940' FSL and 4,011' FEL ' (As Proposed) Section 34, T13N, R10E UM ' ' E = 556,633 ' N = 6,010,091 % T1 -Top OB 2,500' FSL and 435' FEL Section 33, T13N, R10E UM E = 554,934' N = 6,009,638' Z = 4,090' TVD T2 - up-going near Base OA 2,373' FSL and 1,083` FEL Section 33, T13N, R10E UM E = 554,288' N = 6,009,508' Z = 4,050' TVD T3 - TD 1,564' FSL and 2,258` FEL Section 33, T13N, R10E UM E = 553,120' N =6,008,690' Z = 3,970' TVD Distance to Pro a line 1,560' Distance to nearest well 320' from MPI-05 - AFE Number: Ri Do on 14 Estimated Start Date: 11-Nov-05 Ri da s to com lete: 20 MD: 6701' - TVD: 4,488' ~ Max Inc: 108° KOP: 300' - KBE: 70.1' Well Desi n: USH 3'/z" M 1~w4<a....~E~- Ob'ective: Schrader Bluff OA & OB Horizontal In'ector 10/26!2005 MPH-15 Drilling Permit.doc 9:00:48 AM Page 1 IVlud Program: ~ 12-1/4" Surface Hole (0' - 3,397'): Spud Densi PV YP H AP! Filtrate Chlorides m I 8.6 - 9.8 ~ 10 - 30 30 - 50 8.5 - 9.5 NC-8 < 1500 9-7/8" Intermediate Hole (3,397' - 5,467'): LSND Densi PV YP H API Filtrate Chlorides MBT 8.8-10.0 10-25 20-32 9.0-9.5 6-8 <1500 <25 6-3/4" Production Hole (5,467'- 6,701'): LSND Densi PV YP H API Filtrate Chlorides MBT 9.3-T0.0 ~ 10-20 20-32 9.0-9.5 6-7 <1500 <25 Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposa{ site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. Casing/Tubing Program Hole Csg Diam Wt/Ft Grade Conn Burst Collaps Length Top Bottom Size a MD/ MD/ TVDrkb TVDrkb 42" 20" Casing 92# H-40 Weld 1530 520 112-ft 0 112' / 112' 121/a" 9 5!8"Casing 40# L-80 BTC 5750 3090 3397 0 3397'I 3170' 8 3/a" 7" Casing 26# L-80 BTC-M 7240 5410 5467' 0 5467' / 4030' 6 1!8" 31h" Liner 9.2# L-80 IBT- 10,160 10,530 16$3' S0 6701' / Mod 6' 3970' 31/z" Tubing 9.2# L-80 TC II 10,160 10530 5018' 0 5018' ! 4116' t~ement Program: S31`~~~3 ~~1 5 I~asin Size 9 5/8", 40#, L-80, BTC Surface Casin Tai! cement = 1000' MD above shoe. 40°l° Excess over Gauge Hole 13asis Lead to surface. 40% Excess over Gauge Hole to PF, 150% Excess over Gau a Hole from PF to Surface 1~otal Cement Wash 5 bbl water \folume: 402 bbl 20 bbl CW 100 S acer 75 bbl of MudPush 10.0 Lead 318 bbl, 418 sx of ArcticSet Lite: 10.7 and 4.28 ft /sx Tail 84 bbl, 392 sx "G" mixed at 15.8 Ib/ al & 1.21 ft /sx 10/26/2005 MPH-15 Drilling Permit.doc 9:00:48 AM Page 2 • l Casin Size 7", 26#, L-80, BTC-M Intermediate Casin Basis Tail cement = 500' MD above the TUZC. 40°t° Excess over Gauge Hole Total Cement Wash 5-bbl water Volume: 85 bbl 25 bbl CW 100 S acer 40 bbl of MudPush 10.5 Tail 85 bbl, 398 sx "G" mixed at 15.8 Ibl al & 1.2 ft /sx Tem BHST X80°F from SOR Casin Size 3 i/2", 9.2#, L-80, IBT-M Liner Basis Tail ceme nt = 200' above liner to + 40% Excess over Gau a Hole Total Cement Volume: 60 bbl Wash 5-bbl water 15 bbl CW 100 S acer 25 bbl of MudPush 10.5 Tail 60 bbl, 278 sx "G" mixed at 15.8 Ib/ al & 1.2 ft /sx Tem BHST ~80°F from SOR Evaluation Program: 12-1/4" Section Open Hole: Gyro • DIR/GR • IFR/CASANDRA - • S er InSite 8-3/4" Section • DIRlGR/RES - • Nue/Den • PWD - • lFR/CASANDRA • S er InSite Cased Hole: GR/SCMT 6-1/8" Section Open Hole: . DIR/GRJRES • PWD • IFR/CASANDRA • S er InSite Cased Hole: 10/26/2005 MPH-15 Drilling Permit.doc 9:00:48 AM Page 3 Formation Mark: (7) Formation Tops(TVDss) and Estimated Pore Pressures Formation Estimated Formation Tops (TVDss) Uncertainty (feet) Hydrocarbon Bearing (Yes/No) Est. Pore Press. (Psi) Est. Pore Press. (ppg EMW) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are re aired from surface to TD for all new wells BPRF 1750 +/- I50 ft. -760 8.35 TUZC 3400 +!- 100 ft. Yes - -1476 8.35 U nu-MA 3610 Yes -1567 8.35 U nu-MBl 3617 Yes -1571 8.35 U nu-MB2 3660 Yes -1589 8.35 U u-MC 378.5 No -1643 8.35 SBF2-NA 3815 -1785 9.00 SBFl-NB 3845 +/- 30 ft. Yes -1799 ~ 9.00 SBE4-NC 3872 -1812 9.00 SBE2-NE 3890 Yes -1821 9.00 SBEl-NF 3930 -1839 9.00 TSBD-To OA 3963 +l- 25 ft. Yes -] 855 9.00 TSBC-Base OA 3990 -] 867 9.00 1'SBB-To OB 4030 +/- 25 ft. Yes -1881 9.00 SBAS-Base OB 4040 -1891 9.00 IJ oin SBAS -Base OB 4036 +/- 25 ft. Yes -1889 9.00 U oin TSBB - To OB 4012 -1878 9.00 U oin - TSBC Base OA 3978 +/- 35 ft. Yes -1862 9.00 U oin - TSBD To OA 3900 +/- 25 ft Yes -1825 - 9.00 Well TD Criteria Intermediate Hole TD criteria: 200' MD beyond the Base OA on the upgoing side. (ie ??ft TVD, ??ft Rathole, etc.) TD of lateral at target. Obtain Top OA pick if possible. Comments Ugnu predictions from EV_TWT_12Aug04 and 07Dec04 velocity model. Schrader predictions (NA-SBAS) and OWC's from 02Dec04 EV Schrader Bluff model and 07Dec04 Velocity Model. Assume standard pressure gradient through Ugnu/permafrost (8.35 EMW, 0.4342 psi/ft) Pressures based on MPI-02 and MPI-OS PFO's. Pressure range for SBF is 1350-2200 psi. Recommended Bit Program: BHA Hole Size Depth (MD) Footage Bit Type TFA GPM 1 12 114" 0 - 3,397' 3397' Baker Hughes MX-1 .84 650 2 8 3/a" 3,397' - 5467' 2070' Baker Hughes MX- CS1 .71 550 3 6 1/8" 5467' - 6701' 1234' Hycalog DSX-146 .357 300 Well Control: Intermediate/Production hole: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure; • Integrity tests: Kick tolerance: • Integrity tests: 1,785 psi at 3,815' TVDss (SBF1-NB) 1,404 psi at (Based on a full column of gas at 0.1 psi/ft) ~~ L~~~ 3,000 psi ~ FIT to 12.2 Ib/gal 20' below the 9 5/8" shoe. Infinite with 9.71b/gal mud at below the 9 5/8" shoe. FIT to 10.2 b/gal 20' below the 7" shoe. 10/26/2005 MPH-15 Drilling Permit.doc 9:00:48 AM Page 4 . BPXA requests a vari~ to the provisions of 20 AAC 25.035~10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, exce t when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. • Planned completion fluid: Kill Weight Brine with diesel cap. Drilling Hazards & Contingencies: • Hydrates may be present; previously drilled H-pad wells have encountered hydrate gas cut mud from just below BPRF to approximately 3,000' TVD. ~ • Sticky clays from the lower permafrost on down to the Schrader Bluff. • Potential for packing off/stuck pipe, tight hole, and swabbing from 2,800' to 3,300' TVD. Lost Circulation • Losses are possible in the surface interval if elevated mud weights are required for controlling hydrates. • Losses are also possible when crossing uphole fault prior to reservoir. Expected Pressures Possible overpressure in N- and O-sands.' Pad Data Sheet • Please Read the MPH-Pad Data Sheet thoroughly. Hydrocarbons • Hydrocarbons may be encountered in the Ugnu through the Schrader Bluff sands. Faults Two (2) faults~are mapped in the well. Fault #1 in the SV sands intermediate hole section at 3,150' MD (3,030' TVD). This fault is not expected to cause issues. Fault #2, in the OA sands at 3,996' TVD, is for mapping purposes only; the well will not intersect Fault #2. Hydrogen Sulfide • MPH Pad is not designated as an HZS Pad were all < 2 ppm. Anti-collision Issues H2S levels detected from H-Pad wells on the pad • MPH-15 passes the Major Risk Criteria on all wells. Distance to Nearest Property f • MPH-15 is planned to be 1,560' from the nearest Milne Point property line. Distance to Nearest Well Within Pool • MPH-15 is 320 ft from the nearest sand penetration in MPI-05. 10/26/2005 MPH-15 Drilling Permit.doc 9:00:48 AM Page 5 DRILL & COMP Pre-Rig Operations 1. The 20" conductor will be installed pre-rig. Drillin 1. MIRU and NU Diverter. DURE 2. Function Test Diverter, PU 4" DP and BHA. 3. Drill 12 114" surface hole to 3397' MD / 3170' TVD (top Ugnu). 4. Run and cement 9 5/8" surface casing. 5. ND diverter, install wellhead and NU/Test BOPE. 6. Drill 8 3/4" hole to intermediate casing point AT 5467'~MD 14030' TVD (OA sands). y 7. Run and cement 7" intermediate casing. 8. Drill 6 1/4" horizontal interval to final well TD at 6701' MD J 3970' TVD (OA sands). 9. Run and cement 3 112" liner. 10. Run a 3'/z" completion. 11. ND BOP/NU Tree. 1 12. Freeze Protect With Diesel ~~~~~ ~~~ `~ n 13. RD & MO Doyon 14. ~ov~:c-F~~' ~ o ~ ~~~o~ ~~~~S R~3~~~ / 10!26/2005 MPH-15 Drilling Permit.doc 9:00:48 AM Page 6 ~~! /~ ~! 7-in, 26-Iblft, L-80, BTC-M 5467-ft MD 14030-ft ND - RATag (casing) MPH-15 USH OA/OB Injector w/Mono-Bore Completion Surface Elevation = 35.7' RKB - Doyen #14 = 34.3` RD RKB ELEvation = 70.0' FMC Gen 5 11" USH Wellhead w/Camron 3 1/8" 5000 Carbon Tree 20" x 34" Insulated Conductor t. -114' MD 3.5-in x 1.0-in Camco KBUG-M GLM -3000` TMD / w/DCR-1 Shear Valve pinned to 2500 psi (Freeze protect well to 2200' ND) ~ 3.5-in, 9.3-Iblft, L-80, X NippleBore ID = 2.813dn (4 Joints of tubing below top GLM -3124` TMD') 9-518-in, 40-Iblft, L-80, BTC 3397-$ MD 13170-ft ND 3.5-in,9.3-IbIR, L-80, TC-II Tubing ID = 2.992-in, Drift = 2.867-in Burst =10,160-Ibf, Collapse =10,530-Ibf Capacity = 0.00870-bbllft 3.5-in, 9.2-Iblft, L-80, X Nipple Bore ID = 2.813-in 2,500-fl MD Baker, 7 in x 3.5-in Premier Packer-4400` TMD 3.5-in x 1.5-in Camco MMG GLM wl dummy valve lpjgction perforations: OA sands -4473`--4515' TMD /~ 3.5-in x 1.5-in Camco MMGW GLM wl dummy valve RATag (tubing) / Baker, 7 in x 3.5-in Premier Packer-4520` TMD PKR at +l- 4600` M Inclination < 660 (Minimum Separation = oe I :iection Perforations,/ \ -4592` to -4634`-4634` TMD -~txx~t' to -xxxx` TMD-~ (-55' parts in Tower OB) TOL at -5018 MD 4116` ND ejection Perforations (-2D01: 7" Baker HGR & ZXP Packer OA sands -xxxx` to -xxxx' TMD / SOdO PBR 8 X-0 6 718` Open i ole ~ ~ ~ Well TD = 6701-ft TMD / 3970-ft ND ~ .~ etni ru-rrrr 1 7"Shoe set at 94o OA Sand: 5283' MD to 11701' MD 3.5-in, 9.2-Ib/ft, L-80, IBT-M Liner -4030' ND -5467' TMD DATE ~ REV. BY ~ COMMENTS 3.5-in x 1.5-in Camco MMG GLM wl dummy valve - -4550`TMD 3.5-in, 9.3-Iblft, L-80, X-Nipple Bore 1D 2.813-in + 10` -^4585' TMD (Inclination <66 deg.) Milne Point API NO: 50-029-- 50-029- WELL: H-15 5o-02s- (AMRANY DIiTNI.S ' nr na,~,ro Calculation MGhod: Minimum Curvnlurc terror synem: ISCR'SA Scan Mclhrxl: 'rrav Cylinder Nonh rnorsarrw: Lnlpuem+Lb.iag Warning MGhcd: Rules aasai c 0 0 s A H RfrLRIiNCC INFORMATION Cn-ordinate (N/li) Referrmce: Well Ccolre: Plan MPH-IS,'ITUe Nonh Vcnical (I'VD)RC[6tcrsc: 343+35.8 70.10 Section (VS) Refuencc: Slot - (O.fNIN,O.fNIL) Mea~uccd Depth Rc@xancc'. 14,3+35.8 7U.IU Calculation Method: Minimum Curvalurc tiwn Di ~ ,lull' }il,l ~D gun"I'V'I) ' ti~a~r u... 100' >ul ~II'j, av'i el'n-U Ie~.1 U ,SUO^ oat 1E7. „)''1 P.e. I A'D ;Ijn ,. ~~ I'. x111 :170b'M~lu~ ~.... '_ .... ~r~,42 I ~ U 14'1x1 - ~~t Eon > .. t P11zr - Cni , n { 1 ~n~ ]i ~t Flu, is ~ , n'o ~n11n ,a . 1 t1 Dlr __at Ui' alu, "a~ l9' ~A'D i -lit r I SDRVrY GROGRAM Plan: MPH_IS wp09 (Plan MP1I-I5/Plan MPFI-I S) Depth Fm Dupm Ta swveylPtan Tirol Cleated l?y:Troy lakabosky (akat0@bp.co8}[e: 10/ 14/2005 14.30 1200.10 Plantx:tl: MPI I-IS wp09 V71 CI3-GYRO -SS Cheeked: Data: 1200.10 6701.12 Clanncd: MPFI-IS wp09 V]I MWD+IPR +MS Reviewed: Date: WELL DC7'AILS Nome +N/-S +r/-W Northing P.~wlmg Latitude Longitude Slat Clan MCII-IS 1410,}6 121054 601 U1191.12 35firr33.05 70°26'17.564N 149°32'17.602W N/A TARGET DETAILS Name TVD +N/-S +E1-W Northing Easting Shape a MPH-15 T3 3970.10 -1374.73 -3523.93 6008690.00 553120.00 Point MPH-IS T2 4050.10 -566.00 -2350.00 6009507.55 554287.64 Point MPH-15 T1 4090.10 -440.00 -1702.29 6009638.45 554934.32 Point SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 500.00 3.00 238.00 499.91 -2.77 -4.44 LSO 238.00 5.14 4 600.00 S.QO 238.00 599.66 -6.47 -10.35 2.00 0.00 12.00 5 1100.00 20.00 238.00 1086.42 -63.65 -101.87 3.00 360.00 118.04 6 2020.00 20.00 238.00 1950.93 -230.40 -368.71 0.00 0.00 427.24 7 2346.05 28.71 262.05 2248.39 -270.96 -494.10 4.00 60.16 558.79 8 3982.20 28.71 262.05 3683.38 -379.72 -1272.54 0.00 0.00 1323.53 9 4587.02 65.00 262.00 4090.10 -440.00 -1702.29 6.00 -0.07 1745.80 MPH-IS TI 10 5018.43 107.97 258.07 411.5.94 -513.11 -2116.38 10.00 -5.47 2158.14 ~" 11 5137.16 107.97 258.07 4079.31 -536.45 -2226.89 0.00 0.00 2269.58 12 5267.28 98.00 255.00 4050.10 -566.00 -2350.00 8.00 -162.93 2395.01 MPH-15 T2 13 5467.28 93.62 239.53 4029.74 -642.74 -2532.86 8.00 -105.00 2593.25 l4 5487.28 93.62 239.53 4028.47 -652.86 -2550.06 0.00 0.00 2612.96 IS 5594.07 92.72 233.17 4022.57 -711.92 -2638.78 6.00 -97.92 2717.08 16 6701.12 92.72 233.17 3970.10 ^-1374.73 -3523.93 0.00 0.00 3782.59 MPH-IS T3 CASING DETAILS -._... .._._ __.~ ...... No. TVD MD Natne Size ~ 1 3170.10 3396.97 9 S/8" 9.625 _ ,. ~ ~ ~ -: 2 4029.75 5467.00 7" 7.000 , Slat l) r _ ~~ ~'~' 1 tit >.' ~ 1 ' ~ 3 3970.11 6701.00 3 1/2" 3.500 i tell II I I I ~ 1 /, i .ti 1, .llt I~ lVU J v 0' AIll 1190 I'+\1) ~ _ ._ t 4ui = /~ I IUr:aul~4 ~1L1.J{I )11AI) . / irt]I~I U •1~ J AIU JU~9 IIAU ° •--- ~~ ~ - - - _ . i , _ _ _ _ _ _ ;/ . 1~ 1 11- ~' ~ tits 1 ix e i u aa, alo rr~ 4co ;,un -- [, 4131 >+,~ 7 ~__. '~u j~ / 1 _ _ tt t Il/( '. / / ,1,i irptl 611 i` MU, ny 911' Il'U 1 ` ~ 1 ~ ~ ' S I I...lil-~\111. 1 ~ ,. ~ <i ~ / j ' ?. t j I / I 1-\tl3'_ -~ % ~ t ~ , , t ' auuu ~: ~ ; ~ / 1 ~~ ' , E ~ I -- _ ,t~ ~{t ~ 1 ~ 1 ~~ ~II'~~ ~, ~ 1 ~ ~ ~ f .. - _,_, - tiisr~~~ ~_. _ - - :' ~ = - _.: ,_ _ _ - _._ _..._ ,_ / _ ~~~ r 1 _ue ~ _ _....__. _~.. t _. __ _ { ~.. _ - Srsi r nu ~ } 4 - ,~ ~ ~` - ; . ~ r rc ~a~N1l buUb ~ ~Hr~nc i ~ j 1 ~ ~ , t ~ SBh_ I~PI ~ / ~.i ~ - 6 1 ~ ' ( 411'1 l-I~ ~., poq ` n . CHI 3 vt '.. { / ` 7 3 r ~tid i I~ry,l,a f 1 f 0 1 3200 4000 4800 Vertical Section at 248.69° [800ft/in] COMPANY UcrAILS RP.FFMENCf: INI~ORMA'f10N SURVEY PROGRAM Plan: MPH-IS wp09 (Plan MPH-15/Plan MPH-I $) IiP Amnvo Co-onGnnle (N/I!)ReG:rvnce~. Woll CeMre'. PInn MPII-1 S,Tnc North ' OcPlh Pm DvPih'I'n SurvoylPlnn Thol Created By:Troy lakabosky (jakWO(a76p.eo8pte: 10/14/2005 Cal 1 I MM hnd: Min nmm Cur vmive Vcriical (1 VD)Rc[eron .141+75.871).10 Sacl on (VS) Ref n SI I - (000N',0.00C7 347U 12(q.10 Planned: MPII-IS wrA9 V71 C13-GYRO-SS Chu-kvd: Date: f, Syiem: ISCWSA Scvn Method- 'I'rnv Cylindx North Measumd D.Rih Relvlcnev. l4_i+15.8 70.10 Calculation Method: Minimum CurvnWrv I?00.10 6]041' Planned: MPII-I$rry~09 V71 MWDFIPR~MS WIlLL nLTA1LS l:rnx Sur faur. GIIiPtiu"d+C nsing \Vaming Ma lxxf: Rulee Based Name +N/-5 iP/-W Noshing Palling LatiNdv Longimds Slol P1m MPf 1- 15 IllOlb 1216.54 ({IIIN191.32 S56fi13.05 70°?6'17.584N 149°72'I7lA2W N/A SECTION DETAILS TARGET DETAILS Sac MD [ne Azi TVD +N/-S +EJ-W DLeg TFace VSec Target Name TVD +N/-S +E/-W Northing Easting Shape 1 34.30 0.00 0.00 34.30 0.00 0.00 0.00 0.00 0.00 2 300.00 U.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 MPH-IS Fault l 3030.10 256.01 -566.18 6010343.00 556065.00 Polygon 3 500.00 3.00 238.00 499.91 -2.77 -4.44 1.50 238.00 5,14 MPH-IS T3 3970.10 -1374.73 -3523.93 6008690.00 553120.00 Point 4 600.00 5.00 23ft.00 599.6b -6.47 -10.35 2.00 0.00 12.00 MPH-15 Fault2 3996.10 -882.18 -5037.38 6009171.00 SS 1603.00 Polygon 5 1100.00 20.00 238.00 1086.42 -63.65 -lO1.R7 3.00 360.00 118.04 MPH-15 T2 4050.10 -566.00 -2350.00 6009507.55 554287.64 Point 6 2020.00 20.00 238.00 1950.93 -230.40 -368.71 0.00 0.00 427.24 MPH-15 Tl 4090.10 -440.00 -1702.29 6009638.45 554934.32 Point 7 2346.05 28J1 262.05 2248.39 -270.96 -494.10 4.00 60.16 558.79 MPH-IS Geo Poly 4090.10 -286.73 -1530.42 6009793.00 555105.00 Polygon 8 398220 28.71 262.05 3683:38 -379.72 -1272.54 0.00 0.00 1323.53 9 4587.02 65.00 262.00 4090.10 -440.00 -1702.29 6.00 -0.07 1745.80 MPH-li Tl 10 5018.43 107.97 258.07 4115.94 -513.11 -2116.38 10.00 -5.47 2158.14 I1 5137.1.6 107.97 258.07 4079.31 -536.45 -2226.89 0.00 0.00 2269.58 12 5267.28 98.00 255.00 4050.10 -566.00 -2350,00 8.00 -162.93 2395.01 MPH-IS T2 13 5467.28 93.62 239.53 4029.74 -642.74 -2>32.86 8.00 -105.00 2593.25 14 5487.28 93.b2 239.53 4028.47 -652.86 -2550.06 0.00 0.00 2612.96 IS 5594.07 92.72 233.17 4022.57 -711.92 -2638.78 6.00 -97.92 2717.08 16 6701.12 92.72 233.17 3970.10 -1374.73 -3523.93 0.00 0.00 3782.59 MPH-15 T3 3 CASING DETAILS 1 ~ - - StatYlltrL5rI0U OtMD.300TVp ~ 1 it Ul r 2.IND X00' J1D 99.~1'T~D ~~ No. TVD MD Nama Size # - ~ i ~ Slab Dn ~ 10G buff 1`173, wJ;n6'TVD ~ ~ ~ I 3170.10 3396.97 9 5/8" 9.625 - s _ j ' I ~ v-1PH I ~ I~aull I 2 4029.75 5467.00 7" 7.000 ~ / 3 3970.11 6701.00 3 1/2" 3.500 - ; € NIIJ Dir ~~ ~ 1 : I Iu0 ~IU. Ihk64^I I-VU ~` ' `_ ._ . _ 1 ~ ! Srart Dlr J t0 a ~ ~p o ~1 ~ I) a vl t ~'D D ~~~ 0 _.., . _ ..~_ .._ ~. b _. ~ . _.~ __... -._.. _- _ _ ~~ . .. . _ - . . ~ e.._.. .-_ .____.;..~ _ ~ - i Lild Du : ' ~1G.p5 V1ll '__'-hl.>r) I ~'U. ~ll(1 \ . - ', Jlau ~hrG10U 7Y]" fv1 -__ D (~;?.3 ~~ 1 A'U ~ ~ '~ ___ I(i( ~ )11 ~__ ~ S '. , ~~nt I)ir IO: UIU' 1~3i11~ \{U, 40`>U I TV'D ~~ ~ _______ ISY~O ' - `P Id Dir o 18.41' ~A-11J, ~1 F 1 ~_~/4' l A D ~- - _ __ ~ I 3000 ~~ l _.... r - Slam Dir CIIUU' X13 IG A1U_do-~/ 71 lA7) -__.___ r ,yJU 1. =r ~. tt,~10 -. - '___ End Uir 'l'1p7 _°.ti" t,1D 30_J 7a' I ~ I7 - ~ ', - - ~ j -IODU ~ E -600 ,_. __.-.. 1 ._. , ~ ._..... - _ _,... - - .._.-.. . ...-....-._.~. ~ -i ~ i ~ v- ~- v - - - - __......__ v - .. -.. # .._ ~ a ...~ .. ~ _ P _~ ~~~. ' Malt Dir _ t Illo dft' 7ti VID, 411 C 1, f 4'D - ~ ,. _ ~ ~ r z i i ,d u _ lr ,14.0~~ ~In: 402 ,- 1 ~ D _- ~ i nlPti-i ~ Ti 1 3 [ { .. r ^ s p .. -- MPII € ~ Paull ] ~ ,. ~ 3 1 MPII li I_ ~. i ~ i ~ 1 ~. ~ . ~ ~,. i t s a ~ ' +tlr r, ~ ~ • ~ All H-L vvj OV 1 o ~ -1 200 - __... - .__ _ _.__ _ _.. .. _.~._ ~' . __ - ~._. FORMATTON TOP DETAILS _ ~ ~ ~ ~ _ ~ No. TVDPath MDPath Formation ? I -- ~ ~ _ ~-~= - 7olal ~Jepdi: 67(1L1_' ND 1 )'fI=1''I A'll.. ! j 1 1820.10 1880.77 BPRF ~ ! PInnA,IPIi- - I~ i ~ 2 3470.10 3739.02 TUZC ~1PN-U l3 Y l ~ 3 368QL0 3978.46 Ugttu-MA ~, ~ , ~ ~` i / 4 3687.10 3986.45 Ugnu-MBI _ 5 3730.10 4036.34 Ugnu-MB2 E ~ 6 3855.10 4192.29 Ugnu-MC ~ 7 3885.10 4233.01 SBF2-NA i ` j d - 1800 ___ ~ ..__... ___-_ ._ - - - -_... - .. ,. ,_ ..... _. ,.. _ __ _...-_ ., ..... _.,,_ 9 3942.10 4315.43 SBE4-NC 10 39b0.10 4343.17 SBE2-NE ll 4000.10 4408.64 SBEI-NF '?. ! 12 4033.10 4467.78 TSBD-Top OA 13 4060.10 4520.89 TSBC-Base OA . ? ` 14 4090.10 4587.02 TSBB-Top OB F i J 1 S 41 10.10 4639.55 SBAS-Base OB ~ ~ t i ~ 1 ,, -4800 -4200 -3600 -30 00 -2400 -1800 -12 00 -6 00 0 West(-)/Fast(+) [600ft/in] S err -Sun i p Y BP Planning Report Company: BP Amoco Bate: 10!14/2005 Time: 14:30:09 Page: 1 Field: Milne Point Co-ordinate(NE) Ref erence: WeIC Plan MPH-15, Tru e North Site: M Pt H Pad Vertical (TVD) Refer ence: 34.3+35.8 70.1 WeIL• Plan MPH-15 Section (VS) Reference: Well (O.OON,O.OOE,248.69Azi) ~Vellpath: Pfan MPH-15 Survey Calculation M ethod: Minimum Curvature Db: Oracle - ----------- Plan: MPH-15 wp09 T ~~»,,,, Date Composed: »»~ 7/27/2005 Version: 71 Principal: Yes Tied-to: From Well Ref. Point Field: Milne Point North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: M Pt H Pad TR-13-10 UNITED STATES :North Slope Site Position: Northing: 6008971.91 ft Latitude: 70 26 6.665 N From: Map Easting: .h""55404.91 ft Longitude: 149 32 53.895 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.43 deg Well: Plan MPH-15 Slot Name: Well Position: +N!-S 1110.36 ft Northing: 6010091.32 ft Latitude: 70 26 17.584 N +E/-W 1236.54 ft Easting : 556633.05 ft Longitude: 149 32 17.602 W Position Uncertainty: 0.00 ft Casing Points r- - ---- ---- MD CVD Diameter HoleSizc Namc ~ ft ft in in I 3396.97 3170.10 9.625 12.250 9 518" 5467.00 4029.75 7.000 8.500 7" 6701.00 3970.11 3.500 6.125 31/2" Formations MD TVD fbrmatiuns Lithology Dip Angle Dip Direction ft ft ~ deg ~ deg ~ 1880.77 1820.10 BPRF ~ 0.00 0.00 3739.02 3470.10 TUZC 0.00 0.00 3978.46 3680.10 Ugnu-MA 0.00 0.00 3986.45 3687.10 Ugnu-M61 0.00 0.00 4036.34 3730.10 Ugnu-MB2 0.00 0.00 4192.29 3855.10 Ugnu-MC 0.00 0.00 4233.01 3885.10 SBF2-NA 0.00 0.00 4275.46 3915.10 SBF1-NB 0.00 0.00 4315.43 3942.10 SBE4-NC 0.00 0.00 4343.17 3960.10 SBE2-NE 0.00 0.00 4408.64 4000.10 SBE1-NF 0.00 0.00 4467.78 4033.10 TSBD-Top OA 0.00 0.00 4520.89 4060.10 TSBC-Base OA 0.00 0.00 4587.02 4090.10 TSBB-Top OB 0.00 0.00 4639.55 4110.10 SBA5-Base OB 0.00 0.00 Targets Map Map <--- Latitude ---~ <--- Longitude ---> i Name Description 1'Vp +N'/-S +G/-~V SorthinK N:asting Deg Nlin Scc Dec 11in Sec Dip. Dir'. ft ft ft ft ft ~ MPH-15 Fault 1 3030.10 256.01 -566.18 6010343.00 556065.00 70 26 20.102 N 149 32 34.220 W -Polygon 1 3030.10 256.01 -566.18 6010343.00 556065.00 70 26 20.102 N 149 32 34.220 W -Polygon 2 3030.10 -1045.82 -741.08 6009040.00 555900.00 70 26 7.299 N 149 32 39.350 W MPH-15 T3 3970.10 -1374.73 -3523.93 6008690.00 553120.00 70 26 4.056 N 149 34 1.013 W MPH-15 Fault 2 3996.10 -882.18 -5037.38 6009171.00 551603.00 70 26 8:892 N 149 34 45.435 W -Polygon 1 3996.10 -882.18 -5037.38 6009171.00 551603.00 70 26 8.892 N 149 34 45.435 W -Polygon 2 3996.10 -1194.64 -4585.70 6008862.00 552057.00 70 26 5.821 N 149 34 32.174 W -Polygon 3 3996.10 -2056.76 -3794.14 6008006.00 552855.00 70 25 57.347 N 149 34 8.932 W S er -Sun • P rY BP Planning Report Company: BP Amoco Date: 10!14!2005 Time: 14:30:09 Pxge: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MP H-15, True Nort h Site: M Pt H Pad Vertical (TVD) Reference: 34.3+35.8 70.1 WcIJ: P ian MPH-15 Seetion (VS) Kefcrence: Well (O.OON,O. OOE,248.69Azi) Wellpath: P lan MPH-15 Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <--- Latitude --> <--- Longitude --> Name Description TVD +N/-S +p;/-W Northing Easting Deg Min Scc lleg M11in Sec ~~ Dip. Dir. ft ft ft ft ft ~ -Polygon 4 3996.10 -1194.64 -4585.70 6008862.00 552057.00 70 26 5 .821 N 149 34 32.174 W MPH-15 T2 4050.10 -566.00 -2350.00 6009507.55 554287.64 70 26 12 :014 N 149 33 26.571 W MPH-15 T1 4090.10 -440.00 -1702.29 6009638.45 554934.32 70 26 13 .255 N 149 33 7.562 W MPH-15 Geo Poly 4090.10 -286.73 -1530.42 6009793.00 555105.00 70 26 14 .763 N 149 33 2.519 W -Polygon 1 4090.10 -286.73 -1530.42 6009793.00 555105.00 70 26 14 .763 N 149 33 2.519 W -Polyg on 2 4090.10 -491.38 -2502.10 6009581.00 554135.00 70 26 12 .748 N 149 33 31.035 W -Polyg on 3 4090.10 -1357.74 -3654.82 6008706.00 552989.00 70 26 4 .222 N 149 34 4.854 W -Polygon 4 4090.10 -1487.44 -3563.79 6008577.00 553081.00 70 26 2 .947 N 149 34 2.181 W -Polygon 5 4090.10 -694.96 -2429.63 6009378.00 554209.00 70 26 10 :746 N 149 33 28.907 W -Polygon 6 4090.10 -476.00 -1497.85 6009604.00 555139.00 70 26 12 .901 N 149 33 1.562 W Plan Secfion Information MD Inc! Azim TVll +NI-S +E/-W DLS Bu ild 'Corn TFO "Car„ct ~I ft deg deg ft ft ft d egl100ft deg /100ft deg/100fi deg 34.30 0.00 _ 0.00 _ 34.30 0.00 0.00 0.00 0 .00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0 .00 0.00 0.00 500.00 3.00 238.00 499.91 -2.71 -4.44 1.50 1 .50 0.00 238.00 600.00 5.00 238.00 599.66 -6.47 -10.35 2.00 2 .00 0.00 0.00 1100.00 20.00 238.00 1086.42 -63.65 -101.87 3.00 3 .00 0.00 360.00 2020.00 20.00 238.00 1950.93 -230.4(1 -368.71 0.00 0 .00 0.00 0.00 2346.05 28.71 262.05 2248.39 -270.96 -494.10 4.00 2 .67 7.38 60.16 3982.20 28.71 262.05 3683.38 -379.72 -1272.54 0.00 0 .00 0.00 0.00 4587.02 65.00 262.00 4090.10 -440.00 -1702.29 6.00 6 .00 -0.01 -0.07 MPH-15 T1 5018.43 107.97 258.07 4115.94 -513.11 -2116.38 10.00 9 .96 -0.91 -5.47 5137.16 107.97 258.07 4079.31 -536.45 -2226.89 0.00 0 .00 0.00 0.00 5267.28 98.00 255.00 4050.10 -566.00 -2350.00 8.00 -7 .66 -2.36 -162.93 MPH-15 T2 5467.28 93.62 239.53 4029.74 -642.74 -2532.86 8.00 -2. 19 -7.74 -105.00 5487.28 93.62 239.53 4028.47 -652.86 -2550.06 0.00 0 .00 0.00 0.00 5594.07 92.72 233.17 4022.57 -711.92 -2638.78 6.00 -0 .85 -5.95 -97.92 6701.12 92,72 233.17 3970.10 -1374.73 -3523.93 0.00 0 .00 0.00 0.00 MPH-15 T3 Survey 14D lncl Azim Cy'D Sys TVD VS N/S E/H' llLS hlapN MapE Tool(Commen t ft deg deg ft ft ft ft ft deg/100ft ft ft I 34.30 0.00 0.00 34.30 -35.80 0.00 0.00 0.00 0.00 6010091.32 556633. 05 CB-GYRO-SS 100.00 0.00 0.00 100.00 29.90 0.00 0.00 0.00 0.00 6010091.32 556633. 05 CB-GYRO-SS 200.00 0.00 0.00 200.00 129.90 0.00 0.00 0.00 0.00 6010091.32 556633. 05 CB-GYRO-SS 300.00 0.00 / 0.00 300.00 229.90 0.00 0.00 0.00 0.00 6010091.32 556633. 05 Start Dir 1.511 400.00 1.50 238.00 399.99 329.89 1.29 -0.69 -1.11 1.50 6010090.62 556631. 95 CB-GYRO-SS 500.00 3.00 238.00 499.91 429.81 5.14 -2.77 -4.44 1.50 6010088.51 556628. 63 Start Dir 2/100 600.00 5.00 238.00 599.66 529.56 12.00 -6.47 -10.35 2.00 6010084.77 556622. 75 Start Dir 3/100 700.00 8.00 238.00 699.01 628.91 23.12 -12.47 -19.95 3.00 6010078.70 556613. 19 CB-GYRO-SS 800.00 11.00 238.00 797.62 727.52 39.34 -21.21 -33.95 3.00 6010069.85 556599. 27 CB-GYRO-SS 900.00 14.00 238.00 895.24 825.14 60.60 -32.68 -52.30 3.00 6010058.24 556581. 00 CB-GYRO-SS 1000.00 17.00 238.00 991.59 921.49 86.86 -46.84 -74.96 3.00 6010043.91 556558. 45 CB-GYRO-SS 1100.00 20.00 238.00 1086.42 1016.32 118.04 -63.65 -101.87 3.00 6010026.90 556531. 68 End Dir :1100 1200.00 20.00 238.00 1180.38 1110.28 151.65 -81.78 -130.87 0.00 6010008.56 556502. 81 CB-GYRO-SS 1300.00 20.00 238.00 1274.35 1204.25 185.25 -99.90 -159.88 0.00 6009990.22 556473. 95 MWD+IFR+MS 1400.00 20.00 238.00 1368.32 1298.22 218.86 -118.03 -188.88 0.00 6009971.87 556445. 09 MWD+IFR+MS 1500.00 20.00 238.00 1462.29 1392.19 252.47 -136.15 -217.89 0.00 6009953.53 556416. 22 MWD+IFR+MS 1600.00 20.00 238.00 1556.26 1486.16 286.08 -154.28 -246.89 0.00 6009935.19 556387. 36 MWD+IFR+MS 1700.00 20.00 238.00 1650.23 1580.13 319.69 -172.40 -275.90 0.00 6009916.85 556358. 50 MWD+IFR+MS 1800.00 20.00 238.00 1744.20 1674.10 353.30 -190.52 -304.90 0.00 6009898.50 556329. 63 MWD+IFR+MS 1880.77 20.00 238.00 1820.10 1750.00 380.44 -205.16 -328.33 0.00 6009883.69 556306.32 BPRF Sperry-Sun BP Planning Report Company: BP Amoco Date: 10/14/2005 Time: 14:30:09 Page: 3 Field: Milne Point Co-ordinate(i\F,) Reference: Well: Plan MPH-15, True North Site: M Pt H Pad Vertical (T'VD) Reference: 34.3+35.8 70.1 Wetl: Plan MPH-15 Section (VS) Refcrencr. Wefl (O.OON,O.OOE,248.69Azi) Wetlpath: Plan MPH-15 Survey Calculation Method: Minimum Curvature Db: Oracle - -- -- ----------- ------J Survey MD Inc! Azim TVD Sys TVD VS N/S E/yV DLS MapN MapE "Cool/Comment ft deg deg ft ft ft ft ft deg/100ft ft ft I 1900.00 20.00 238.00 1838.17 1768.07 386.91 -208.65 -333.91 0.00 6009880.16 556300.77 MWD+IFR+MS 2000.00 20.00 238.00 1932.14 1862.04 420.51 -226.77 -362.91 0.00 6009861.82 556271.90 MWD+IFR+MS 2020.00 20.00 238.00 1950.93 1880.83 427.24 -230.40 -368.71 0.00 6009858.15 556266.13 Start Dir 4!100 2100.00 21.76 245.50 2025.69 1955.59 455.49 -243.80 -393.82 4.00 6009844.56 556241.13 MWD+IFR+MS 2200.00 24.36 253.28 2117.71 2047.61 494.58 -257.43 -430.46 4.00 6009830.66 556204.60 MWD+{FR+MS 2300.00 27.28 259.56 2207.73 2137.63 537.66 -267.51 -472.77 4.00 6009820.25 556162.37 MWD+IFR+MS 2346.05 28.71 262.05 2248.39 2178.29 558.79 -270.96 -494.10 4.00 6009816.64 556141.07 End Dir :2346 2400.00 28.71 262.05 2295.71 2225.61 584.01 -274.54 -519.77 0.00 6009812.86 556115.43 MWD+IFR+MS 2500.00 28.71 262.05 2383.41 2313.31 630.75 -281.19 -567.35 0.00 6009805.86 556067.91 MWD+IFR+MS 2600.00 28.71 262.05 2471.12 2401.02 677.49 -287.84 -614.93 0.00 6009798.85 556020.39 MWD+IFR+MS 2700.00 28.71 262.05 2558.82 2488.72 724.23 -294.49 -662.50 0.00 6009791.84 555972.86 MWD+IFR+MS 2800.00 28.71 262.05 2646.53 2576.43 770.97 -301.13 -710.08 0.00 6009784.83 555925.34 MWD+IFR+MS 2900.00 28.71 262.05 2734.24 2664.14 817.71 -307.78 -757.66 0.00 6009777.82 555877.82 MWD+IFR+MS 3000.00 28.71 262.05 2821.94 2751.84 864.45 -314.43 -805.24 0.00 6009770.81 555830.30 MWD+IFR+MS 3100.00 28.71 262.05 2909.65 2839.55 911.19 -321.08 -852.81 0.00 6009763.81 555782.78 MWD+IFR+MS 3200.00 28.71 262.05 2997.35 2927.25 957.93 -327.73 -900.39 0.00 6009756:80 555735.26 MWD+IFR+MS 3237.34 28.71 262.05 3030.10 2960.00 975.38 -330.21 -918.16 0.00 6009754.18 555717.52 MPH-15 Fault 1 3300.00 28.71 262.05 3085.06 3014.96 1004.67 -334.37 -947.97 0.00 6009749.79 555687.74 MWD+IFR+MS 3396.97 28.71 262.05 3170.10 3100.00 1049.99 -340.82 -994.10 0.00 6009742.99 555641.66 9 5/8" 3400.00 28.71 262.05 3172.76 3102.66 1051.41 -341.02 -995.55 0.00 6009742.78 555640.22 MWD+IFR+MS 3500.00 28.71 262.05 3260.47 3190.37 1098.15 -347.67 -1043.12 0.00 6009735.77 555592.70 MWD+IFR+MS 3600.00 28.71 262.05 3348.17 3278.07 1144.89 -354.32 -1090.70 0.00 6009728:77 555545.18 MWD+IFR+MS 3700.00 28.71 262.05 3435.88 3365.78 1191.63 -360.96 -1138.28 0.00 6009721.76 555497.65 MWD+IFR+MS 3739.02 28.71 262.05 3470.10 3400.00 1209.87 -363.56 -1156.84 0.00 6009719.02 555479.11 TUZC 3800.00 28.71 262.05 3523.58 3453.48 1238.37 -367.61 -1185.86 0.00 6009714.75 555450.13 MWD+IFR+MS 3900.00 28.71 262.05 3611.29 3541.19 1285.11 -374.26 -1233.43 0.00 6009707.74 555402.61 MWD+IFR+MS 3978.46 28.71 262.05 3680.10 3610.00 1321.78 -379.47 -1270.76 0.00 6009702.24 555365.33 Ugnu-MA 3982.20 28.71 262.05 3683.38 3613.28 1323.53 -379.72 -1272.54 0.00 6009701.98 555363.55 Start Dir 6/100 3986.45 28.97 262.05 3687.10 3617.00 1325.52 -380.01 -1274.57 6.00 6009701.68 555361.53 Ugnu-M61 4000.00 29.78 262.04 3698.91 3628.81 1331.99 -380.93 -1281.15 6.00 6009700.71 555354.95 MWD+IFR+MS 4036.34 31.96 262.04 3730.10 3660.00 1350.13 -383.51 -1299.62 6.00 6009697.99 555336.51 Ugnu-M62 4100.00 35.78 262.03 3782.95 3712.85 1;184.64 -388.42 -1334.75 6.00 6009692.81 555301.42 MWD+IFR+MS 4192.29 41.32 262.02 3855.10 3785.00 1440.58 -396.40 -1391.68 6.00 6009684.40 555244.55 Ugnu-MC 4200.00 41.78 262.02 3860.87 3790.77 1445.56 -397.11 -1396.75 6.00 6009683.65 555239.49 MWD+IFR+MS 4233.01 43.76 262.02 3885.10 3815.00 1467.37 -400.22 -1418.94 6.00 6009680.38 555217.33 SBF2-NA 4275.46 46.31 262.02 3915.10 3845.00 1496.59 -404.39 -1448.68 6.00 6009675.98 555187.62 SBF1-NB 4300.00 47.78 262.01 3931.82 3861.72 1514.07 -406.88 -1466.47 6.00 6009673.35 555169.85 MWD+IFR+MS 4315.43 48.71 262.01 3942.10 3872.00 1525.27 -408.48 -1477.87 6.00 6009671.66 555158.47 SBE4-NC 4343.17 50.37 262.01 3960.10 3890.00 1545.81 -411.42 -1498.77 6.00 6009668.57 555137.59 SBE2-NE 4400.00 53.78 262.01 3995.02 3924.92 1589.42 -417.65 -1543.15 6.00 6009662.01 555093.26 MWD+IFR+MS 4401.82 53.89 262.01 3996.10 3926.00 1590.85 -417.85 -1544.61 6.00 6009661.79 555091.80 MPH-15 Fauli 2 4408.64 54.30 262.01 4000.10 3930.00 1596.23 -418.62 -1550.08 6.00 6009660.98 555086.34 SBE1-NF 4467.78 57.85 262.01 4033.10 3963.00 1643.96 -425.44 -1598.66 6.00 6009653.79 555037.82 TSBD-Top OA 4500.00 59.78 262.00 4049.79 3979.69 1670.79 -429.27 -1625.96 6.00 6009649.75 555010.55 MWD+{FR+MS 4520.59 61.03 262.00 4060.10 3990.00 16$8.46 -431.80 -1643.94 6.00 6009647.09 554992.59 TSBC-Base OA 4587.02 65.00 262.00 4090.10 4020.00 1745.80 -440.00 -1702.29 6.00 6009638.45 554934.32 MPH-15 T1 4600.00 66.29 261.86 4095.45 4025.35 1757.31 -441.66 -1714.00 10.00 6009636.70 554922.62 MWD+IFR+MS 4639.55 70.23 261.47 4110.10 4040.00 1793.10 -446.98 -1750.34 10.00 6009631.10 554886.32 SBA5-Base OB 4700.00 76.25 260.90 4127.52 4057.42 1849.59 -455.86 -1807.51 10.00 6009621.80 554829.22 MWD+IFR+MS 4800.00 86.21 260.01 4142.75 4072.65 1946.22 -472.23 -1904.85 10.00 6009604.68 554732.02 MWD+IFR+MS 4900.00 96.17 259.14 4140.67 4070.57 2044.28 -490.30 -2003.06 10.00 6009585.88 554633.97 MWD+IFR+MS 5000.00 106.14 258.24 4121.34 4051.24 2140.77 -509.49 -2099.14 10.00 6009565.95 554538.04 MWD+IFR+MS S err -Sun P Y BP Planning Report Companp: BP Amoco Date: 10(1412005 'time: 14:30:09 Page: 4 Field: Milne Point Co-ordinatc(NE) Reference: Well: Plan MPH-15, Tnae North Site: M Pt H Pad Vertical (1'VD) Reference: 34.3+35.8 70.1 Well: Plan MPH-15 Section (VS) Reference: Well (O.OON,O.OOE,248.69Azi) WeBpath: Plan MPH-15 Survey Calculation Method: Minimum Curvature pb: Oracle Survey MU [ncl Azim TVll SVSTVD VS N/S ft deg deg ft ft ft 1t 5018.43 107.97 258.07 4115.94 4045.84 2158.14 -513.11 5100.00 107.97 258.07 4090.77 4020.67 2234.70 -529.14 5137.16 107.97 258.07 4079.31 4009.21 2269.58 -536.45 5200.00 103.16 256.56 4062.45 3992.35 2329.41 -549.75 5267.28 98.00 255.00 4050.10 3980.00 2395.01 -566.00 5300.00 97.31 252.45 4045.74 3975.64 2427.31 -575.09 5400.00 95.14 244.71 4034.88 3964.78 2526.64 -611.38 5467.00 93.63 239.55 4029.75 3959.65 2592.98 -642.60 5467.28 93.62 239.53 4029.74 3959.64 2593.25 -642.74 5487.28 93.62 239.53 4028.47 3958.37 2612.96 -652.86 5500.00 93.51 238.77 4027.68 3957.58 2625.48 -659.37 5594.07 92.72 233.17 4022.57 3952.47 2717.08 -711.92 5600.00 92.72 233.17 4022.28 3952.18 2722.78 -715.47 5700.00 92.72 233.17 4017.55 3947.45 2819.03 -775.34 5800.00 92.72 233.17 4012.81 3942.71 2915.28 -835.21 5900.00 92.72 233.17 4008.07 3937.97 3011.52 -895.08 6000.00 92.72 233.17 4003.33 3933.23 3107.77 -954.96 6100.00 92.72 233.17 3998.59 3928.49 3204.02 -1014.83 6200.00 92.72 233.17 3993.85 3923.75 3300.27 -1074.70 6300.00 92.72 233.17 3989.11 3919.01 3396.52 -1134.57 6400.00 92.72 233.17 3984.37 3914.27 3492.76 -1194.44 6500.00 92.72 233.17 3979.63 3909.53 3589.01 -1254.31 6600.00 92.72 233.17 3974.89 3904.79 3685.26 -1314.19 6700.00 92.72 233.17 3970.15 3900.05 3781.51 -1374.06 6701.00 92.72 233.17 3970.11 3900.01 3782.47 -1374.66 6701.12 92.72 233.17 3970.10 r 3900.00 3782.59 -1374.73 E/W DLS MapN MapE Too(/Commcr Mt ft deg/100ft ft ft -2116.38 10.00 6009562.21 554520.83 End Dir :5018 -2192.30 0.00 6009545.59 554445.04 MWD+IFR+MS -2226.89 0.00 6009538.02 554410.51 Start Dir 8/100 -2285.92 8.00 6009524.28 554351.59 MWD+IFR+MS -2350.00 8.00 6009507.55 554287.64 MPH-15 T2 -2381.13 8.00 6009498.22 554256.58 MWD+IFR+MS -2473.59 8.00 6009461.24 b54164.41 MWD+IFR+MS -2532.62 8.00 6009429.57 554105.63 T' -2532.86 8.00 6009429.43 554105.39 End Dir :5467 -2550.06 0.00 6009419.18 554088.27 .Start Dir 6J100 -2560.96 6.00 6009412.58 554077.41 MWD+IFR+MS -2638.78 6.00 6009359.45 554000.01 End Dir :5594 -2643.52 0.00 6009355.87 553995.29 MWD+IFR+MS -2723.48 0.00 6009295.40 553915.80 MWD+IFR+MS -2803.43 0.00 6009234.92 553836.31 MWD+IFR+MS -2883.39 0.00 6009174.45 553756.82 MWD+IFR+MS -2963.34 0.00 6009113.98 553677.33 ,MWD+IFR+MS -3043.30 0.00 6009053.51 553597.84 MWD+IFR+MS -3123.25 0.00 6008993.04 553518.35 MWD+IFR+MS -3203.21 0.00 6008932.57 553438.86 MWD+IFR+MS -3283.17 0.00 6008872.10 553359.37 MWD+IFR+MS -3363.12 0.00 6008811.62 553279.87 MWD+IFR+MS -3443.08 0.00 6008751.15 553200.38 MWD+IFR+MS -3523.03 0.00 6008690.68 553120.89 MWD+IFR+MS -3523.83 0.00 6008690.08 553120.10 31/2" -3523.93 0.00 6008690.00 553120.00 MPH-15 T3 a'eu uc LMLS AN'rl-('OLLISION SETI'INCiS cuMr,wr ur: r.\as sokvl:v rkouk:,nf hLuuc N. .S ~IL-\\ Nr%tlwlg I'u.iiny I.NUJc Lunginxk Sl.rl Intcrpolaliun MclhuJ:MD Inlcrval: ?i.W III'Ann+„ ucPlh Ym I hPIR Iu Surv y9'lan 'l onl rIn11 nu'u- li I nu ;fi r;h,iy M uxwlh iih(1. 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' ifih lNl i$(I INI XUI 16 41 11 111 A11'll-IC-1' (N ?J it .%fi NIXI III 1 5 1,?i ( N lH1 111X1 4(NI hl .Yh -'I I-) r. %.]N hlNl ' I _71711% . . ~5, I I, h]UI I_ Y - +1 17 I U IU - -I J ] I UINI IXI 1]N_+iy RII'll I< I1 __ ~~ . _ S er -Sun , P rY Anticollision Report Company: BP Amoco Date: 10/14/2005 Time : 14:38:01 Page: 1 Field: Milne Point Reference Site: M Pt H Pad Co-urdinate(nE) Refer ence: Well: Pla n MPH-15, True North Reference Nell: Plan MPH-15 Vertical (TVD) Referen ce: 34.3+35. 8 70.1 Reference Wellpath: Plan MPH-15 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal P-an & PLANNED PROGRAM Interpolation Method : MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 34.30 to 6701.12 ft Scan Method: Trav Cylinder North Maximum Radius: 866.68 ft Error Surface: Ellipse + Casing Survey Program for Definifive Wellpath Date: 7/27/2005 Validated: No Version: 2 Planned From To Survey Toolcode Tool Name ft ft 34.30 1200.10 Planned: MPH-15 wp09 V72 CB-GYRO-SS Camera based gyro single shots 1200.10 6701.12 Planned: MPH-15 wp09 V72 MWD+IFR+MS MWD +IFR + M ulti Station Casing Points Dlll t~'D Diameter Hole Size Name ft ft in in 3396.97 3170.10 9.625 12.250 9 5/8" - 5467.00 4029.75 7.000 8.500 7" 6701.00 3970.11 3.500 6.125 31/2" Summary - --- <-------------------- Offset Wellpath -------------------> Reference Offset Ctr-Ctr \o-Go Vlowable ~ Site «~ell Wellpath D1D DID Distance Area Deviation Warning ft ft ft ft ft M Pt H Pad MPH-01 MPH-01 V1 717.92 700.00 211.89 13.30 198.60 Pass: Major Risk M Pt H Pad MPH-01 Plan MPH-01a V1 Plan: 717.92 700.00 211.89 13.25 198.64 Pass: Major Risk M Pt H Pad MPH-01 Plan MPH-01aL1 V2 Plan 717.92 700.00 211.89 13.30 198.59 Pass: Major Risk M Pt H Pad MPH-02 MPH-02 V1 783.35 775.00 143.71 20.05 123.66 Pass: Major Risk M Pt H Pad MPH-03 MPH-03 V1 826.15 825.00 63.97 18.14 45.82 Pass: Major Risk M Pt H Pad MPH-04 MPH-04 V1 700.86 700.00 21.54 12.81 8.73 Pass: Major Risk M Pt H Pad MPH-05 MPH-05 V1 827.32 825.00 39.51 15.16 24.35 Pass: Major Risk M Pt H Pad MPH-06 MPH-06 V1 910.64 900.00 95.67 16.24 79.43 Pass: Major Risk M Pt H Pad MPH-07 MPH-07 V1 1186.53 1150.00 199.37 23.55 175.82 Pass: Major Risk M Pt H Pad MPH-07 MPH-07A V12 1186.53 1150.00 199.37 23.55 175.82 Pass: Major Risk M Pt H Pad MPH-07 MPH-07AL1 V5 1186.53 1150.00 199.37 23.33 176.03 Pass: Major Risk M Pt H Pad MPH-07 MPH-07AL1 P61 V4 1186.53 1150.00 199.37 23.55 175.82 Pass: Major Risk M Pt H Pad MPH-07 MPH-07AL1 PB2 V6 1186.53 1150.00 199.37 23.55 175.82 Pass: Major Risk M Pt H Pad MPH-07 MPH-07AP61 V25 1186.53 1150.00 199.37 23.44 175.93 Pass: Major Risk M Pt H Pad MPH-08 MPH-08 V2 842.56 825.00 176.88 15.27 161.61 Pass: Major Risk M Pt H Pad MPH-08 MPH-08A V4 842.56 825.00 176.88 15.38 161.50 Pass: Major Risk M Pt H Pad MPH-08 MPH-08APB1 V3 842.56 825.00 176.88 15.38 161.50 Pass: Major Risk M Pt H Pad MPH-08 MPH-08B V5 842.56 825.00 176.88 15.38 161.50 Pass: Major Risk M Pt H Pad MPH-O8 MPH-O8BL1 V16 842.56 825.00 176.88 15.38 161.50 Pass: Major Risk M Pt H Pad MPH-08 MPH-08BP61 V1 842.56 825.00 176.88 15.38 161.50 Pass: Major Risk M Pt H Pad MPH-09 MPH-09 V3 1178.94 1125.00 175.42 22.75 152.67 Pass: Major Risk M Pt H Pad MPH-10 MPH-10 V9 1258.51 1225.00 96.75 25.49 71.26 Pass: Major Risk M Pt H Pad MPH-11 MPH-11 V6 1197.81 1175.00 51.94 23.71 28.23 Pass: Major Risk M Pt H Pad MPH-12 MPH-12 V2 982.09 975.00 38.71 19.81 18.90 Pass: Major Risk M Pt H Pad MPH-13 MPH-13 V4 898.19 900.00 31.67 18.11 13.56 Pass: Major Risk M Pt H Pad MPH-13 MPH-13A V4 898.19 900.00 31.67 18.02 13.65 Pass: Major Risk M Pt H Pad MPH-14 MPH-14 V7 897.88 900.00 52.85 17.94 34.91 Pass: Major Risk M Pt H Pad MPH-16 MPH-16 V5 424.25 425.00 27.95 8.97 18.98 Pass: Major Risk M Pt H Pad MPH-16 MPH-16L1 V4 424.25 425.00 27.95 8.71 19.24 Pass: Major Risk M Pt H Pad MPH-16 MPH-16PB1 V2 424.25 425.00 27.95 9.77 18.18 Pass: Major Risk M Pt H Pad MPH-16 MPH-16P62 V2 424.25 425.00 27.95 9.77 18.18 Pass: Major Risk M Pt H Pad MPH-16 MPH-16PB3 V2 424.25 425.00 27.95 9.77 18.18 Pass: Major Risk M Pt H Pad MPH-18 MPH-18 V6 373.66 375.00 90.06 7.84 82.22 Pass: Major Risk M Pt H Pad MPH-18 MPH-18L1 V3 373.66 375.00 90.06 7.58 82.48 Pass: Major Risk M Pt H Pad MPH-18 MPH-18L2 V2 373.66 375.00 90.06 7.58 82.48 Pass: Major Risk M Pt H Pad Plan Chico Chico V2 Plan: Chico W 1307.75 1300.00 2.85 0.00 2.85 Pass: NOERRORS M Pt H Pad Plan Groucho Groucho V1 Plan: Grouc 732.47 725.00 111.18 0.00 111.18 Pass: NOERRORS M Pt H Pad Plan Harpo Harpo V1 Plan: Harpo W 903.41 900.00 107.47 0.00 107.47 Pass: NOERRORS M Pt H Pad Plan Helix Helix L1 V1 Plan: Heli 5495.91 9725.00 76.68 No Reference Casings M Pt H Pad Plan Helix Helix L2 Vi Plan: Heli 5468.21 14100.00 23.78 No Reference Casings M Pt H Pad Plan Helix Helix L3 V1 Plan: Heli 5507.50 Z¢25.00 76.07 No Reference Casings M Pt H Pad Plan Helix Helix L4 V1 Plan: Heli 5459.23 1 75.00 23.10 No Reference Casings i S err -Sun i P Y Anticollision Report Company: BP Amoco Date: 10/14/2005 Time: 14:38:01 Page: 2 Field: Milne Point Reference Si te: M Pt H Pad Co-ordinate(1\E) Refer ence: Well: Pla n MPH-15, T rue North Reference W eil: Plan MPH-15 Vertical ('I'VD) Reference: 34.3+35.8 70.1 Reference W ellpath: Plan MPH-15 Db: Oracle Summary <------------------ O ffset Wellpath ---------------> Reference Offset Ctr-Ctr No-Go Allowable Site Nell Wellpath Nlll R1D Distance Arca Deviation Warning ft ft ft ft ft M Pt H Pad Plan Helix Helix V1 Plan: Helix w 3849.74 3800.00 210.19 0.00 210.19 Pass: NOERRORS M Pt H Pad Plan MPH-17 MPH-17 wp01 V1 Plan: M 5364.82 4950.00 28.65 0.00 28.65 Pass: NOERRORS M Pt H Pad Plan Smith Smith 8 VO Plan: Smit 874.23 875.00 77.55 No Reference Casings M Pt H Pad Plan Smith Smith 10 VO Plan: Smit 658.39 650.00 119.65 No Reference Casings M Pt H Pad Plan Smith Smith 2 VO Plan: Smith 735.95 725.00 118.91 No Reference Casings M Pt H Pad Plan Smith Smith 3 VO Plan: Smith 1443.37 1425.00 62.87 No Reference Casings M Pt H Pad Plan Smith Smith 4 VO Plan: Smith 898.27 900.00 68.27 No Reference Casings M Pt H Pad Plan Smith Smith 5 V0 Plan: Smith 897.91 900.00 70.61 No Reference Casings M Pt H Pad Plan Smith Smith 6 VO Plan: Smith 897.57 900.00 73.01 No Reference Casings M Pt H Pad Plan Smith Smith 7 VO Plan: Smith 874.46 875.00 75.39 No Reference Casings M Pt H Pad Plan Smith Smith 9 VO Plan: Smith 275.00 275.00 119.81 No Reference Casings M Pt H Pad Plan Smith Smith V2 Plan: Smith W 710.10 700.00 119.35 0.00 119.35 Pass: NOERRORS M Pt I Pad MPI-01 Plan MPI-01A VO Plan: 6701.06 4500.00 494.46 117.16 377.30 Pass: Major Risk M Pt I Pad MPI-01 Plan MPI-01AL1 VO Plan 6701.06 4500.00 494.46 116.95 377.51 Pass: Major Risk M Pt I Pad MPI-05 MPI-05 V1 5646.25 4975.00 192.24 148.43 43.80 Pass: Major Risk M Pt I Pad MPI-07 Plan MPI-07A VO Plan: 5366.71 5983.36 27.18 0.00 27.18 Pass: NOERRORS M Pt I Pad MPI-15 MPI-15 V6 6693.47 4525.00 527.57 107.44 420.13 Pass: Major Risk M Pt I Pad MPI-15 MPI-15L1 V2 6693.47 4525.00 527.57 107.34 420.23 Pass: Major Risk M Pt I Pad MPI-15 MPI-15PB1 V5 6693.47 4525.00 527.57 107.30 420.27 Pass: Major Risk Site: M Pt H Pad Well: MPH-01 Rule Assigned: Major Risk Wellpath: MPH-01 V1 Inter-Site Error: 0.00 ft ~ Reference Offset Semi-Rlajor axis Ctr-Ch~ ,Ao-Co Allowable RTD I'VD RID 1'VD Ref Offset TFt}+A %1 3~F0-HS Casin};/H SDistancc :1rea Ucviation y'1'arning ~ ft ft ft ft ft ft deg deg in ft ft ft 50.00 50.00 50.00 50.00 _ _ _ 0.04 0.01 196.11 196.11 210.46 1.21 209.25 Pass 75.00 75.00 75.00 75.00 0.09 0.02 196.11 196.11 210.47 1.67 208.80 Pass 100.00 100.00 100.00 100.00 0.15 0.04 196.11 196.11 210.49 2.13 208.35 Pass 125.00 125.00 125.00 125.00 0.24 0.05 196.10 196.10 210.51 2.69 207.83 Pass 150.00 150.00 150.00 150.00 0.32 0.07 196.10 196.10 210.55 3.24 207.31 Pass 175.00 175.00 175.00 175.00 0.41 0.08 196.10 196.10 210.59 3.79 206.80 Pass 200.00 200.00 200.00 200.00 0.50 0.09 196.09 196.09 210.64 4.34 206.30 Pass 225.00 225.00 225.00 225.00 0.55 0.11 196.08 196.08 210.70 4.80 205.90 Pass 250.00 250.00 250.00 250.00 0.61 0.12 196.08 196.08 210.77 5.26 205.51 Pass 275.00 275.00 275.00 275.00 0.66 0.14 196.07 196.07 210.85 5.71 205.13 Pass 300.00 300.00 300.00 300.00 0.72 0.16 196.05 196.05 210.95 6.21 204.74 Pass 326.07 326.07 325.00 325.00 0.73 0.19 195.99 317.99 211.02 6.58 204.44 Pass 352.13 352.13 350.00 350.00 0.74 0.21 195.88 317.88 211.00 6.96 204.05 Pass 378.19 378.19 375.00 374.99 0.76 0.24 195.73 317.73 210.90 7.33 203.57 Pass 404.24 404.23 400.00 399.99 0.77 0.27 195.52 317.52 210.71 7.72 203.00 Pass 430.28 430.25 425.00 424.98 0.80 0.30 195.24 317.24 210.47 8.14 202.33 Pass 456.29 456.24 450.00 449.97 0.83 0.33 194.86 316.86 210.26 8.56 201.70 Pass 482.26 482.19 475.00 474.94 0.85 0.36 194.37 316.37 210.11 8.99 201.12 Pass 508.30 508.20 500.00 499.89 0.88 0.39 193.76 315.76 210.02 9.42 200.61 Pass 534.53 534.38 525.00 524.81 0.92 0.42 193.04 315.04 209.99 9.86 200.13 Pass 560.68 560.47 550.00 549.71 0.95 0.46 192.19 314.19 210.01 10.32 199.69 Pass 586.74 586.44 575.00 574.57 0.98 0.51 191.20 313.20 210.11 10.79 199.32 Pass 613.02 612.62 600.00 599.38 1.02 0.55 190.07 312.07 210.31 11.27 199.04 Pass 639.50 638.97 625.00 624.15 1.07 0.60 188.79 310.79 210.58 11.76 198.83 Pass 665.79 665.09 650.00 648.85 1.11 0.65 187.35 309.35 210.96 12.25 198.72 Pass 691.93 691.01 675.00 673.52 1.15 0.70 185.80 307.80 211.41 12.76 198.64 Pass 717.92 716.73 700.00 698.17 1.20 0.76 184.16 306.16 211.89 13.30 198.60 Pass 743.75 742.25 725.00 722.81 1,26 0.83 182.45 304.45 212.45 13.84 198.61 Pass 769,42 767.56 750.00 747.43 1.32 0.89 180.65 302.65 213.11 14.38 198.73 Pass 794.91 792.63 775.00 772.02 1.37 0.95 178.78 300.78 213.90 14.92 198.98 Pass , , v i ' ~ J 9 I 75'40'59' i ~----------------------------------~ ~ 27 28 i I F I ; Q ~ -N- A Z a ' ~ I i I PAD ~, THIS sul~ I I i H PAD _N_ I , I , H-18 ~; ~ z I I -~ H-17 raH ~ H-1s i VICINITY MAP ~ 30'(TYP)~ H-15 i N.T.S. H-14^ ^ H-4 H-13 ^ ~ ^ H-5 I H-12 ^ ^ H-3 LEGEND H-11 ^ ^ H-6 -~- AS-BUILT WELL CONDUCTOR H-10^ i ^ H-2 ~ ^ EXISTING WELL CONDUCTOR , H-9 ^ ^ H-8 I ^ H-1 ' , ~' ^ H-7 I q~.~ ~ ,`~ °OF ° ACS / ~ °q ' P°° ° ° °S ' ~ °°or ;~ ;' I °°°°°°°°°°°°°°°°°°°° °°°°°° °°°°° ~ ~______-________ J ° ~ ~ _____ -------------------------' Richard F. Allison / , c~° 10608 '~ ' MPU H-PAD ~I~~-~ SURVEYOR'S CERTIFICATE NOTES I HEREBY CERTIFY THAT I AM 1. DATE OF SURVEY: JULY 24, 2004. PROPERLY REGISTERED AND LICENSED 2. REFERENCE FIELD BOOK MP04-02 pp.17-21. TO PRACTICE LAND SURVEYING IN 1. ALASKA STATE PLANE COORDINATES THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY (A. S.P.) ARE ZONE 4 ALASKA, NAD 27. MADE BY ME OR UNDER MY DIRECT 2. PAD SCALE FACTOR IS 0.99990364 SUPERVISION AND THAT ALL 3. HORIZONTAL CONTROL IS BASED ON DIMENSIONS AND OTHER DETAILS ARE MPU H-PAD MONUMENTS H-1 AND H-2 CORRECT AS OF JULY 24, 2004. 6' LOCATED WITHIN PROTRACTED SECTION 34, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITfON(D.DD) BOX ELEV. OFFSETS H-15 Y= 6,010,091.32 N= 1,409.85 70°26'17.584" ' 70.4382178° 35 8 2 940' FSL ' X- 556,633.05 E= 879.91 149'32 17.602" 149.5382228° . 4,011 FEL H 16 Y= 6,010,120.38 N= 1,440.03 70'26'17.869" 70.4382969' 36 2 2,969' FSL - X= 556,641.19 E= 879.89 149°32'17.356" 149.5381544' ' 4,003' FEL H-17 Y= 6,010,149.22 N= 1,470.03 70°26'18.153" 70.4383758° 35 7 2,997' FSL ' X= 556,649.44 E= 880.04 149'32'17.108" 149.5380856' ' 3,995 FEL H-18 Y= 6,010,178.19 N= 1,500.11 70'26'18.437" 70.4384547' 35 6 3,026' FSL ' X= 556,657.51 E= 879.97 149'32'16.865" 149.5380181° . FEL 3,986 (~---- ~. °"EDKE° ~A~oBSm~~~ ~° by BP EXPLORATION 0 I ' I DATE: I~l~ll^JnJI „~ ~ 7-27-04 ' DRAWING: FRB04 MPH Ot-00 MILNE POINT UNIT H-PAD SNEET: JOB NO: ® ~~ ~ ~a AS-BUILT CONDUCTORS 0 7-27-04 ISSUED FOR INFORMA710N KWH JJ "s u'D SCALE: 1 OF i i~ = i5o• WELLS MP H-15, H-16, H-17, H-18 N0. DAIE REVLON BY CNK ~ ¢ °vzr ivirn-i~ rCruu~ w Lrui • • Subject: 1~IPH-IS Permit to Drill From: "Rose, John G (FAIRWEATHER)" <rosel l@BP.com> Date: GV"rd, 09 \'~ov ?Ot)5 1~2~:34-0400 To: tom tna~fnder~a:~;adrnin.state.ak.us CC: "Kara, Danny T" <KaraDT~a?~BP.com=>, "Hubble, Tercie L" ~ ~[ubbleTL!u-BP.com~ Tom, As we have discussed, please note a few changes to the above referenced Permit To Drill application: 1. The 3 1/2" Liner Length The Permit request currently reads liner top at 5018' MD/4116' TVD which gives us a 449' liner lap. It should read liner top at 5317' MD/4038' TVD which gives us our targeted -150' lap. 2. Page 6 of the Wellplan (Drill & Complete Procedure) has been modified to show the cement bond log work and perforating work that will be done on the well. 3. The 1/4 mile AOR for MPH-15 is attached for your review. If you have any concerns or require additional information, please advise. Thanks for your help - JR «MPH-15 AOR.doc» __ ___ _ __ ~; ' Content-Description: MPH-15 AOR.doc '! :MPH-15 AOR.doc ' Content-Type: application/msword Content-Encoding: base64 1 of 1 11/9/2005 2:36 PM • • MPH-15i '/4 Mile Area of Review (11/09/2005): Five wells penetrate the Schrader Bluff OA/OB sands within a 1/4-mile of the MPH-15 OA/OB injection intervals, and based upon this review, it is our conclusion that the off-set wells have sufficient mechanical integrity to be within the proposed injection patter of this well. Included in this AOR is the following listed data: I. Cementing Data - No unusual issues were note in the well to well review of the associated cement jobs. II. Injector Well Data -Both injection wells within this AOR have bond logs indicating good mechanical isolation capabilities. III. MPH-15 Injector Planning Data -TIFF files detailing the planned injector objectives. A diagram showing the locations of these wellbores is included in this packet. The following table(s) provides information on the production/injection casing cement jobs and FIT's (if available) for each proximate well. Cementin Data: Csg Shoe Well Type Size Depth Cement FIT TVDss Ibl at EMW MPI-02 injector 7" 4213 391 sxs Class "G" - MPI-03 producer 7~~ 4192 307 sxs Class "G" - MPI-05 injector 768 sxs Permafrost "E", 314 sxs Trinity " " _ 5-1/2" 4338 E Lite-Water, 250 sxs Permafrost MPI-15* producer 7" 3975 84 sxs Class "E", 189 sxs Class "G" 11.8 MPH-16* producer 7.5/8" 3993 598 sxs Class "G" 12.5 "have laterals through OA and OB sands; cased with 4.5" slotted liners r 1 ~J Injector Well Data: MPI-02 Hole Size Csg OD Shoe Depth (MD) Length 30" 13-3/8" 106' 71' 12-1/4" 9-5/8" 2800' 2765' _ ~ ~ 022'. '~ 6186' Formation Tops MD TVD Top"N" Sand 5710 3903 Top"O" Sand 5898 _ 4046 • MPI-05 Hole Size Csg OD Shoe Depth Length 24" 20" 142' 110' 8.5" 5-1/2" 5688' 5657' Formation Tops MD TVD BPRF 1919 1884 Top NA Sand 4928 3829 Top NB Sand 4955 3849 Top NC Sand 4987 3874 Top ND Sand 5013 3894 Top NE Sand 5046 3919 Top OA Sand 5124 3979 Top OB Sand 5203 4039 Base OB Sand 5235 4064 MPI-05 Cement Bond Log Review: A review of the 04/08/1996 cement bond log indicates that the cement job on this well provide sufficient isolation characteristics with at least 250' of good cement above the top set of perforations as the bond log terminated at 5460' MD. This log is on file and available for additional review if desired. MPI-02 Cement Bond Log Review: A review of the 10/16/2002 cement bond log indicates that the cement job on this well provide sufficient isolation characteristics with good 130' of good cement above the top set of perforations. This log is on file and available for additional review if desired. III. MPH-15i Planning Data MWI-16 SBIi S~bsP.i Rn l~rl r~-~~ ~ul OA ~. " OB MPI-16 ~c-o r OA Cohoroncy Mop - proposod odditionel ir~joction support h bolhr support MPH-16 and M/I-SS • • ,~„L° vJ MPH-7 5i Planned Location ~~ FIL4APtl7 f~ _ ---- ` , ~i61P1-O4 _+IM -0 ~, 1~\ .. - ~INP - 1... -'. _. _. 33 . `6,1 00 x`,400 ~MPI-1 ~.-.:..:~ r~*- 0.25 Mlle Buffer r (Schratler BIU1f OAfOB SectiorU o iooo Zooo F®et 1:'12.000 ASP Zone 4 NAD 27 TSBB OB M~rKOrs X TSBD OA Marxono y Well Status / Abandoned :- Gas Injector Injecting Miscible Injector Operating Miscible Injector Shut-M o Not Yet Completed / Td Not YeL Reached. O Null/Unknown • ON Producer Flowing G ON Producer Gas Lilt • OII Producer Hydraulic Pump ~ OII Producer Shut-In r OII Producer Submersible • OII Suspended • OII Well cJ Plugged Back For Redrill b Suspended t7 Water Injector f3 Water Injector Injecting O Water Injector ar Water Producer Shut-In • Water Producer Flawing ~ • TERRIE L RUBBLE ss-s~,z52 231 BP EXPLORATION-AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99 5 1 9-661 2 ~ ~.~~-~S DATE _ PAY TO THE ~~+ ~ -~~ ~ `~ ~ ,. OR ER OF (~~__ RS First Nationa ank A aska Anchor(ag~e,, AK 99501 I MEMO ~: L Z5 200060~:9914~~~6 2 2?~~~ 1556~~' 0 23-1 a • • ~~J `~'- E TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSiVIITTAL,~L, E/TTER WELL NAME / /~~C~ ' ( ~~~ PTD# Zf~ S- "` ~~~ CHECK WHAT ADD-ONS "CLUE" APPLIES ~ (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (Z} digits a function of .the original API number stated 4 are between 60-69) above. ~ I ~ PILOT HOLE In accordance with 20 AAC 25.005(f), all ~ , (p);~ records, data and logs acquired for the pilot ~ hole must be clearly differentiated in both ` ~ name (name on permit plus PH) f ~ and API number (50 - 70/80) from records, data and logs acquired for well (name on permit}. SPACING The permit is approved subject to full ~ EXCEPTION compliance with 20 AAC 25.055. Approval to a ~ perforate and produce/infect is contingent ' upon issuance of a conservation order ~ approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' ~ sample intervals from below the permafrost i or from where samples are first caught and 1 10' sample intervals through target zones. ~ f Rev: Q4lO1/OS Cljody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 Well Name: MILNE PT UNIT SB H-15 Program SER Well bore seg ^ PTD#:2051590 Company BP EXPLORATION A( LASKA) INC Initial ClasslType SER ! PEND GeoArea 890 Unit 1~~ OnlOff Shore On Annular Disposal Administration 1 Permit_fee attached- - - - - - Yes - 2 Lease number appropriate - Yes - - - - 3 Uniquewell_nameandnumber__..__-__---------------------------- Yes_ _,__.-_--,_-___-_-....... ------------------------------------------------- 4 Well located in a-definedpool___________________ __________________ Yes_ __-.MPUSchrader Bluff-525140_,______ 5 Well located proper distance-from drilling unit_boundary_ _ - . _ _ - - _ Yes _ , . _ More than 500' frpm external property_boundary where ownership or landownership changes. 6 Well located proper distance-f[o_m other wells- - - - - - - - - - - - - - - - - -- - - - - - - - - - - - Yes _ _ - _ - - _ CO 477.05-governs spacing: -n_o res_trictions exeepi 500' from_e_xfe[iorproperty_line._ - _ _ - _ _ _ _ _ _ - , _ - _ - _ - 7 Sufficient acreage available in_drilling unit- , _ - - - - .... Yes _ _ - - . No restrictions. - 8 If deviated,is_wellboreplat_included.-_-_____________ ________________ Yes_ ____._--__-__-__-.-- 9 Operator only affected party_ - - Yes - - 10 OpQratorhasappropriaie_bondinforce___________________--__-.--.-.. Yes_ -_-....-.._-.-_.-__. 11 Permitcanbeissuedwithoutconservationorder__-__.__.______-_-__-___ Yes- __-_---------------_--__--_____-_--._--_._-_-____.-.--_-__- --. __ Appr Date 12 Permitcan be issued without administrative-appr_oya_I - Yes _ - SFD 10!27!2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata authorized by_ Injection Order # (put1O# in_comments)_(For_ Yes _ _ _ _ _ - AIO.10B_ , - _ _ . _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , - _ - _ - - 15 All wells within 114_mile area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . - MPU I-01, I-02, I-03, I-05,1-15, H-16.. _ - .. _ . _ , _ - - _ _ - .. _ _ _ . _ _ .. _ _ - _ 16 Pre-produced injector; duration of pre production l_ess_than3months(Forservicewellcnly)_ No_- _-_ __________________________-__._-____-____-_- -__-_--_-_--_- ___-_ 17 ACMP_Finding of Consistency-h_as been issued forthis proiect - _ - , _ - NA_ _ - _ _ . -Well drilled from existing pad, _ _ _ _ - Engineering 18 Conductorstring provided - - - - - Yes - - - - - - - - - 19 SurfacecasingprotectsallknownUSDWs-__-___-___- -_--___,__-__- NA__ __-_-All aquifers exempted,40CFR_147.1Q2(b)_(3)andAEO2_____________________ _-____.___ - 20 CMT_voladeguate_tocirculate_onconductor-&surf_csg-.-_ __- _------------- Yes_ ___-._-- __.-__-___--,--_--.-,_-_--_- __-.__-____--__----,_.___. -_. 21 CMT_vol adequate.to tie-in long string to surf csg- No_ - All h drocarbon zones will be_covered. - y 22 CMT-will coverall known-productive horizons- _ _ _ - Y_es - _ Cemented linerpl_anned, . - 23 Casing designs adequate forC,_T,B&_permaf[ost_____-__-_-_ ,_-___--__. Yes_ _.--_.__--.-.._.-_._.--_-.__._-_-_-_.._-__-.-_-.._--.__.__-.-.-. 24 Adequate iankage_or reserve pit _ - - Yes - .. - -Rig is_equipped with steeLpits.. No reserve_pitplanned, All waste to approved disposal-wells._ - _ _ - 25 Ifa-re-drill,has.a_10-40$forabandonment been approved-__-_--__-_______-, NA__ _______________-_____-_--_--___-__-__-__-_________.-_--._------_._--.- 26 Adequate wellbore.separation-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . _ - - _ - .Proximity analysis perf_ormed_ Traveling cylinder path calculated, Gyros passible: , _ _ _ _ _ _ _ _ _ _ _ , _ _ . _ _ 27 Ifdiverterrequired,doesitmeetregulations_-_--__-__-___________________ Yes_ -___-__-_--_-__.-______--_______-__-_-_____-__-_----__-_-___.__... Appr Date 28 Drilling fluid_program schematic & equip list adequate- - Yes - - - _ - Maximum expected f_ormatipn pressure 9,Q EMW._ MW planned up to 10.Oppg.. - - - _ - TEM 11/10!2005 29 BO_PES,_dotheymeetregulation------------------------------------- Yes- ---------------------------------------------- ------------------ M,~ /~ 30 BOPE_press rating appropriate; test to_(put prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - , - _ _ - MA$P calculated at 1404 psi. 3000-psi_BOP testplanned. _ - _ - _ _ . _ - - _ _ - _ . _ _ - _ _ - _ , , _ _ - - _ _ v ~ 31 Choke-man'rfold complies wIAPI-RP-53 GMay 84) Yes - - - - - - 32 Work will occur without operation shutdown_-----------------------. Yes- ----.-- ----------------.--------- -----------------------------_-- 33 IspresenceofH2Sgas_probable______________________--_-._------ No_. _____-H2SisnotleportedinSB-production on MPH pad._-,______._.----.--._-._.--_.-_-.- 34 Mechanical_condition of wells within AOR verified (For-service well only) - - - - - - - - - - - - - - Yes - _ _ - _ _ - Wells_within AOR_examined. -4 OH sidetracks_in OB ig 1-15&-H-16. _ No issues identified, _ - , _ . _ _ _ _ _ Geology 35 Permit_can be issued w/o hydrogen-sulfide measures - - -- - - - - - -- - - - - - - - - - - - Yes . _ - _ .Schrader Bluff sands have NOT produced H2$ from th_e Schrader Blutfreservoi[s_at H-Pad._ - - - _ 36 Data_presented on potential overpressure zones- - - Yes , - _ - -Expected resrevoirp[essure is 9,0-ppg; will be_drilled with 9,3-10,0_ppg mud._ Some potential far- - _ _ - _ . - Appr Date 37 Seismic analysis of shallow gas_zones- - - - - - - - - - - - - - - - - - - - - - -- - - - NA, _ - overpressure in NA-OB interval.. -Hydrates possible dawn to_3000' TVp._ Mentioned-in Drilling Hazards section. - SFD 10!27/2005 38 Seabed conditionsurvey_(ifoff_-shore)_-._.____-__-_-__-___-__----- - NA_. _- 39 Contact name/phgne for weekly progress-reports ]exploratory only]- _ - - _ _ - _ - , NA_ , Geologic Engineering P Date Date • Date: Commissioner: m n Commissioner: ~l !~~ • 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 intor~iation, information of this nature is accumulated at the end of the file under APPENDIX. No special eftorl has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Aug 17 15:00:39 2006 Reel Header Service name .............LISTPE Date .....................06/08/17 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/08/17 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 W-0004084655 R. FRENCH J. HABERTHUR SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: F5L: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 12.250 2ND STRING 8.750 3RD STRING 6.125 PRODUCTION STRING • RECEIVED auG 3 0 coos Alaska Oil & Gas Cons. Commission AnChOra9a Scientific Technical Services Scientific Technical Services MPH-15 500292328400 BP Exploration (Alaska), Inc. Sperry Drilling Services 17-AUG-06 MWD RUN 2 MWD RUN 3 W-0004084655 W-0004084655 C. ZAWADZKI C. ZAWADZKI J. HABERTHUR E. VAUGHN 34 13N l0E 2940 4011 69.95 35.80 CASING DRILLERS SIZE (IN) DEPTH (FT) 20.000 114.0 9.625 2900.0 7.000 5652.0 (l~C ~~r_ X59 ~ 1~1POCo REMARKS: • • 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. 4. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE. RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON (CTN), STABILIZED LITHO-DENSITY (SLD), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 2 ALSO INCLUDED ACOUSTIC CALIPER (ACAL) MWD RUN 3 ALSO INCLUDED AT-BIT INCLINATION (ABI) RUN 2 CTN DATA WERE REPROCESSED USING ACAL DATA, INSTEAD OF A FIXED HOLE SIZE. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL DATED 8/11/2006 FROM DOUG DORTCH (SAIL/BP) TO BUSTER BRYANT (SDS), QUOTING AUTHORIZATION FROM MICAELA WEEKS (BP GEOSCIENTIST) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3 REPRESENT WELL MPH-15 WITH API#: 50-029-23284-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6800'MD/3973'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (ACAL-DERIVED & FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR-TO-BIT DISTANCE. PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.75" BIT); 6.125" BIT MUD WEIGHT: 9.2-9.4 PPG MUD SALINITY: 400 PPM CHLORIDES FORMATION WATER SALINITY: 21,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: ~ SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/17 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 STOP DEPTH GR 78.0 6734.0 ROP 118.5 6800.0 RPS 2880.0 6741.0 FET 2880.0 6741.0 RPD 2880.0 6741.0 RPX 2880.0 6741.0 RPM 2880.0 6741.0 NCNT 2885.0 6705.5 FCNT 2885.0 6705.5 NPHI 2885.0 6705.5 PEF 2900.5 6721.0 CALA 2901.0 5564.0 DRHO 2903.0 6721.0 RHOB 2903.0 6721.0 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 1 78.0 2914.0 2 2914.0 5654.0 3 5654.0 6800.0 REMARKS: 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 GALA MWD INCH 4 1 68 4 2 FCNT MWD CNTS 4 1 68 8 3 ~ • NCNT MWD CNTS 1 68 12 4 RHOB MWD G/CM 4 1 68 16 5 DRHO MWD G/CM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 FET MWD HOUR 4 1 68 40 11 GR MWD API 4 1 68 44 12 PEF MWD BARN 4 1 68 48 13 ROP MWD FT/H 4 1 68 52 14 NPHI MWD PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 78 6800 3439 13445 78 6800 GALA MWD INCH 8.52 15.24 9.43116 5295 2901 5564 FCNT MWD CNTS 126.02 2545.29 685.421 7642 2885 6705.5 NCNT MWD CNTS 15634.8 189452 97809 7642 2885 6705.5 RHOB MWD G/CM 1.154 2.989 2.1991 7483 2903 6721 DRHO MWD G/CM -0.252 0.672 0.102752 7483 2903 6721 RPD MWD OHMM 0.07 2000 34.5012 7723 2880 6741 RPM MWD OHMM 0.7 2000 40.2582 7723 2880 6741 RPS MWD OHMM 0.61 2000 11.0676 7723 2880 6741 RPX MWD OHMM 0.53 2000 11.7414 7723 2880 6741 FET MWD HOUR 0.16 55.73 1.95699 7723 2880 6741 GR MWD API 17.45 123.59 71.5413 13313 78 6734 PEF MWD BARN 0.19 9.03 2.30429 7488 2900.5 6721 ROP MWD FT/H 0.78 2394.45 187.133 13364 118.5 6800 NPHI MWD PU-S 13.76 83.5 37.2906 7642 2885 6705.5 First Reading For Entire File..........78 Last Reading For Entire File...........6800 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/17 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.......06/08/17 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: 1 DEPTH INCREMENT: .5000 FILE SUMMARY • VENDOR TOOL CODE START DEPTH GR 78.0 ROP 118.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 2872.5 2914.0 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 r L J 07-DEC-05 Insite 66.37 Memory 2914.0 114.0 2914.0 .0 28.4 TOOL NUMBER 132478 12.250 114.0 Native/Spud Mud 9.80 95.0 8.0 500 8.2 000 .0 000 64.4 000 .0 000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ~ • ROP MWDO10 FT/H 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 78 2914 1496 5673 78 2914 GR MWDO10 API 17.45 123.59 65.503 5590 78 2872.5 ROP MWDO10 FT/H 17.46 2394.45 209.351 5592 118.5 2914 First Reading For Entire File..........78 Last Reading For Entire File...........2914 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/17 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.......06/08/17 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2873.0 5609.0 FET 2880.0 5601.0 RPX 2880.0 5601.0 RPS 2880.0 5601.0 RPM 2880.0 5601.0 RPD 2880.0 5601.0 NPHI 2885.0 5561.0 FCNT 2885.0 5561.0 NCNT 2885.0 5561.0 PEF 2900.5 5574.5 CALA 2901.0 5564.0 RHOB 2903.0 5574.5 DRHO 2903.0 5574.5 ROP 2914.5 5654.0 LOG HEADER DATA DATE LOGGED: 11-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REA~IME) Memory TD DRILLER (FT) 5654.0 TOP LOG INTERVAL (FT) 2914.0 BOTTOM LOG INTERVAL (FT): 5654.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 26.3 MAXIMUM ANGLE: 107.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 134745 EWR4 ELECTROMAG. RESIS. 4 145654 SLD STABILIZED LITHO DEN 78609 CTN COMP THERMAL NEUTRON 1844674407370955 ACAL Acoustic Caliper 727424 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT) 2900.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S) 55.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 4.250 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.060 106.7 MUD FILTRATE AT MT: 6.500 75.0 MUD CAKE AT MT: 3.100 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GALA MWD020 INCH 4 1 68 4 2 FONT MWD020 CNTS 4 1 68 8 3 NCNT MWD020 CNTS 4 1 68 12 4 RHOB MWD020 G/CM 4 1 68 16 5 DRHO MWD020 G/CM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 RPM MWD020 OHMM 4 1 68 28 8 RPS MWD020 OHMM 4 1 68 32 9 ~ RPX MWD020 OHMM 1 68 36 10 FET MWD020 HOUR 4 1 68 40 11 GR MWD020 API 4 1 68 44 12 PEF MWD020 BARN 4 1 68 48 13 ROP MWD020 FT/H 4 1 68 52 14 NPHI MWD020 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2873 5654 4263.5 5563 2873 5654 GALA MWD020 INCH 8.52 15.24 9.43116 5295 2901 5564 FCNT MWD020 CNTS 452.57 2545.29 854.352 5353 2885 5561 NCNT MWD020 CNTS 104880 189452 130138 5353 2885 5561 RHOB MWD020 G/CM 1.154 2.989 2.19219 5344 2903 5574.5 DRHO MWD020 G/CM -0.129 0.672 0.128861 5344 2903 5574.5 RPD MWD020 OHMM 0.37 2000 20.6211 5443 2880 5601 RPM MWD020 OHMM 0.7 2000 12.8592 5443 2880 5601 RPS MWD020 OHMM 0.61 2000 9.05719 5443 2880 5601 RPX MWD020 OHMM 0.53 2000 8.17815 5443 2880 5601 FET MWD020 HOUR 0.16 48.3 1.35102 5443 2880 5601 GR MWD020 API 20.94 118.33 76.7904 5473 2873 5609 PEF MWD020 BARN 0.19 7.35 2.39919 5349 2900.5 5574.5 ROP MWD020 FT/H 5.71 438.21 172.387 5480 2914.5 5654 NPHI MWD020 PU-S 13.76 83.5 37.6641 5353 2885 5561 First Reading For Entire File..........2873 Last Reading For Entire File...........5654 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/17 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.......06/08j17 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 5561.5 6705.5 NCNT 5561.5 6705.5 FCNT 5561.5 6705.5 RPD 5601.5 6741.0 RPX 5601 . FET 5601.5 RPM 5601.5 RPS 5601.5 GR 5609.5 DRHO 5652.0 RHOB 5652.0 PEF 5652.0 ROP 5654.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 6741.0 6741.0 6741.0 6741.0 6734.0 6721.0 6721.0 6721.0 6800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON EWR4 Electromag Resis. 4 ACAL Acoustic Caliper BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY {HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined • 14-DEC-05 Insite 66.37 Memory 6800.0 5654.0 6800.0 87.6 95.7 TOOL NUMBER 156436 188894 1844674407370955 73634 78908 6.125 5652.0 Polymer 9.30 54.0 8.5 300 5.4 4.200 70.0 3.230 93.2 5.500 71.0 3.500 70.0 Frame Spacing...........~.......60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 BARN 4 1 68 44 12 ROP MWD030 FT/H 4 1 68 48 13 NPHI MWD030 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5561.5 6800 6180.75 2478 5561.5 6800 FCNT MWD030 CNTS 126.02 942.57 290.364 2289 5561.5 6705.5 NCNT MWD030 CNTS 15634.8 36657.7 22205.2 2289 5561.5 6705.5 RHOB MWD030 G/CM 2.039 2.743 2.21637 2139 5652 6721 DRHO MWD030 G/CM -0.252 0.269 0.0375245 2139 5652 6721 RPD MWD030 OHMM 0.07 2000 67.6371 2280 5601.5 6741 RPM MWD030 OHMM 5.4 2000 105.667 2280 5601.5 6741 RPS MWD030 OHMM 3.16 1714.65 15.8669 2280 5601.5 6741 RPX MWD030 OHMM 3.22 2000 20.2479 2280 5601.5 6741 FET MWD030 HOUR 0.42 55.73 3.40363 2280 5601.5 6741 GR MWD030 API 37.85 106.74 73.7751 2250 5609.5 6734 PEF MWD030 BARN 1.26 9.03 2.06698 2139 5652 6721 ROP MWD030 FT/H 0.78 669.35 168.18 2292 5654.5 6800 NPHI MWD030 PU-S 18.3 57.73 36.4174 2289 5561.5 6705.5 First Reading For Entire File..........5561.5 Last Reading For Entire File...........6800 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/17 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/08/17 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ....... ......LISTPE Date ............... ......06/08/17 Origin ............. ......STS Reel Name .......... ......UNKNOWN Continuation Number ......01 Next Reel Name..... ......UNKNOWN Comments ........... ......STS LIS Physical EOF Physical EOF • Writing Library. Scientific Technical Services End Of LIS File