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Home My WebLink About201-163Nolan Vlahovich Hilcorp Alaska, LLC Geotech 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: 3/6/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240306 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-19RD 50133205790100 219188 12/9/2023 AK E-LINE CBL BRU 232-09 50283200750000 184136 10/30/2023 AK E-Line PT/CALIPER MPU B-19A 50029214510100 223123 2/26/2024 HALLIBURTON Jewelry Log MPU I-12 50029230380000 201163 1/30/2024 HALLIBURTON Coilflag MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON Coilflag PBU N-11D 50029213750300 223083 2/13/2024 HALLIBURTON RBT Please include current contact information if different from above. T38597 T38598 T38599 T38600 T38601 T38602 MPU I-12 50029230380000 201163 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.06 12:00:22 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 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: 2/8/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240208 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 13-08 50133203040000 177029 10/11/2023 AK E-LINE TUBING CUT KBU 14-6Y 50133205720000 207149 10/24/2023 AK E-Line PLUG/PERF MPU B-28 50029235660000 216027 1/10/2024 HALLIBURTON MFC40 MPU F-65 50029227520000 197049 1/19/2024 HALLIBURTON MFC40 MPU I-12 50029230380000 201163 1/30/2024 HALLIBURTON Coilflag MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON Coilflag Please include current contact information if different from above. T38488 T38489 T38490 T38491 T38492 T38493 2/8/2024 MPU I-12 50029230380000 201163 1/30/2024 HALLIBURTON Coilflag Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.08 10:05:37 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, December 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC I-12 MILNE PT UNIT I-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/22/2022 I-12 50-029-23038-00-00 201-163-0 W SPT 3572 2011630 1500 548 549 549 549 252 314 321 320 INITAL P Bob Noble 11/5/2022 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: MILNE PT UNIT I-12 Inspection Date: Tubing OA Packer Depth 1402 2216 2188 2187IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN221110155404 BBL Pumped:1 BBL Returned:1 Thursday, December 22, 2022 Page 1 of 1 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. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: MPU I-12 (PTD# 201163) Return to Injection Date:Wednesday, November 2, 2022 9:17:37 AM From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Monday, October 31, 2022 8:58 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com> Subject: OPERABLE: MPU I-12 (PTD# 201163) Return to Injection Mr. Regg, MPU I-12 (PTD# 201163) was made NOT OPERABLE due to being shut in and missing the 4 year MIT- IA. The well is now ready to be returned to injection. It is now classified as OPERABLE and will be placed on injection. A witnessed MIT-IA will be scheduled once the well has stabilized injection. Please respond with any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 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 above, then promptly and permanently delete this message. 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. OF ALAS E AL/IIA OIL AND G ST CONSERVATION COMSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS FEB 0 8 2018 1.Operations Abandon U Plug Perforations U Fracture StimulateU Pull Tubing U •, rttwn Li Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter Casing ❑ Ch.n.-WO ram ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well❑ Re-enter Susp Well❑ Other:Convert to Injector Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑✓ Exploratory ❑ 201-163 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-029-23038-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025517 MILNE PT UNIT 1-12 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 12,470 feet Plugs measured N/A feet true vertical 3,712 feet Junk measured N/A feet Effective Depth measured 12,470 feet Packer measured 9,504 feet true vertical 3,712 feet true vertical 3,572 feet Casing Length Size MD TVD Burst Collapse Conductor 108' 20" 108' 108' N/A N/A Surface 2,906' 10-3/4" 2,906' 2,408' 3,580psi 2,090psi Intermediate 10,228' 7" 10,228' 3,706' 7,240psi 5,410psi Liner"A" 2,457' 4-1/2" 12,393' 3,716' 8,430psi 7,500psi Liner"B" 2,232' 4-1/2" 12,396' 3,715' 8,430psi 7,500psi Perforation depth Measured depth See Schematic feet SCANNED FEB 1 6 2013 True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80/EUE MOD 9,644' 3,597' 7"x 3-1/2"TNT 9,504'(MD) Packers and SSSV(type,measured and true vertical depth) Perm.Hyd. N/A 3,572'(TVD) 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 0 711 1,160 699 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Service ❑✓ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q 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: 317-595 Authorized Name: Bo York �-' �� Contact Name: Stan Porhofola sP Authorized Title: Operations Manager Contact Email: sporhola@hilcorp.corn Authorized Signature: 90Date: 2/6/2018 Contact Phone: 777-8412 cL .2—/I-4 Form 10-404 Revised 4/2017 j,/,/31 C[' " LF`' - f: 'l 18 Submit Original Only • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-12 Pumper 50-029-23038-00-00 201-163 1/11/18 1/13/18 Daily Operations: 1/10/2017-Wednesday No activity to report. 1/11/2017 -Thursday MIRU Little Red Pumping Unit. PT lines to 3,500 psi. Pump 4 bbl diesel and pressure test 7" casing to 2,846 psi, bled to 2,793 psi in 30 min (lost 53 psi; passed). Bled off to 0 psi, returned 4 bbl diesel. RDMO. $4 1 T LI 1/12/2017 - Friday No activity to report. 1/13/2017-Saturday MIRU Little Red Pumping Unit. PT lines to 3,500 psi. Pump 0.05 bbl 60/40 McOH and pressure test surface lines from injection header to 2,731 psi, bled to 2,708 psi in 5 min (lost 23 psi; passed). Bled off to 0 psi, returned 0.05 bbl 60/40 McOH. Perform injectivity test w/ produced water. Pump a total of 53 bbl @ 1 m. Max injection pressure of 505 psi. Displace w/3 bbl 60/40 McOH.;Turn well over to operators and place on injection @ 300 bwpd. RD Little Red. 1/14/2017 -Sunday No activity to report. 1/15/2017- Monday No activity to report. 1/16/2017-Tuesday No activity to report. . • Milne Point Unit Well: MPU 1-12 SCHEMATIC Last Completed: 11/08/2016 Hilcorp Alaska,LLC PTD: 201-163 WELLHEAD LWellhead FMC Tubing Hanger,11"x 3-1/2"TC-II Top&Bottom Orig.KB Elev.:64.7'/Orig.GL Elev.:34.7' OPEN HOLE/CEMENT DETAIL RKB-Hanger:15.20'(ASR) 20" Cmt w/650 sx of Arcticset I in 30"Hole "t k 10-3/4" Cmt w/585 sx AS Lite,502 sx Class"G"in 13-1/2"Hole 20', ` 7" Cmt w/1,172 sx Class"G"in 9-7/8"Hole CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm ' 20" Conductor 92/H-40/Welded N/A Surf 108' "'k 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 2,906' 7" Intermediate 26/L-80/Btc-Mod 6.151 Surface 10,228' eJ 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 9,936' 12,393' 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 10,164' 12,396' 10-3/4"„l 44 TUBING DETAIL 3-1/2" Tubing 9.3/L-80/EUE-MOD 2.867 Surf 9,644' LINER DETAIL 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 9,936' 9,980' 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 9,980' 12,393' 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 10,164' 10,373' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 10,373' 12,396' WELL INCLINATION DETAIL KOP@300'MD Max Wellbore Angle=85.5 deg @ 8,102'MD 63.74 deg @ 2,550'MD JEWELRY DETAIL No Depth Item 1 2,345' GLM 3-1/2"x 1-1/2"Patco GLM(DGLV Set 11/08/16) 2 9,339' 3-1/2"XD Sliding Sleeve(2.813"Packing Bore Min ID;Closed 11/17/17) 3 9,427' 3-1/2"NDPG-C Single-drop Intake Gauge(2.913"ID) 4 9,485' 3-1/2"X Profile(2.813"Packing Bore Min ID) 5 9,504' 7"x 3-1/2"TNT Permanent Hydraulic Set Packer(2.949"ID) 6 9,558' 3-1/2"Autofill Sub(2.88"ID) 7 9,643' Wireline Entry Guide(Btm at 9,644') Nin ID=2.813 i.i i r 2 8 9,906' Baker Hook Wall,Hanger above 7"Window Ib „ 9 9,928' Baker Hook Wall,Hanger below 7"Window 3 10 9,930' Baker Tension Lock Swivel y' .• 11 10,116' Baker Tie Back Sleeve 1 w 12 10,128' Baker ZXP Liner Top Packer Mn ID=2.813" '' ft 413 10,147' Baker 7"x 5"HMC Liner Hanger 14 12,395' Btm 4-1/2"Pack-off Bushing 5 15 12,435' Btm 4-1/2"Guide Shoe 16 12,396' Btm Baker Pack-off Bushing 17 12,439' Btm Baker 4-1/2"Guide Shoe fE s LATERAL WINDOW DETAIL Top of"OA"Window @ 9,916'MD;Bottom @ 9,928'MD;Angle @ top of window is 80 deg Top of"OB"Window @ 10,228'MD;Bottom @ 10,240'MD;Angle @ top of window is 87 deg Ill 7 GENERAL WELL INFO 6, API:50-029-23038-00-00 4^ 8. i: 9 Drilled and Cased by Nabors 4ES-12/08/2001 r 10 14 ESP Completion by Nabors 4ES-12/15/2001 0 FISH-3-1/2"X- Convert to ESPCP by Nabors 4ES-6/30/2010 OA'Latera15 Lock,3"RCOM Jet Convert to TTC-ESPCP by Doyon 16-12/05/2014 11 ", ' Pump(Serial BP- Convert to ESPCP by ASR 1-1/17/2016 12,° k..13 1078),Bottom Convert to Jet Pump by ASR 1-11/08/2016 1screen.Fish Length= Convert to Injector by Pump Truck-1/13/2018 06"Lateral 17 5.83'.Could be in 7" either lateral. TD=12,470'(MD)/TD=3,712'(TVD) PBTD=12,470'(MD)/PBTD=3,712'(TVD) Revised By:TDF 2/6/2018 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,January 26,2018 TO: Jim Regg 'Wert �Z((1 eg SUBJECT:Mechanical Integrity Tests P.I.Supervisor Y 1 HILCORP ALASKA LLC I-12 FROM: Matt Herrera MILNE PT UNIT I-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT 1-12 API Well Number 50-029-23038-00-00 Inspector Name: Matt Herrera Permit Number: 201-163-0 Inspection Date: 1/23/2018 Insp Num: mitMFH180125141316 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-12 Type Inj W TVD 3572 Tubing 330 -1 331 331- 331 PTD 2011630 Type Test SPT Test psi 1500 IA 753 2922 - 2871 - 2868 - BBL Pumped: 2.5 'BBL Returned: 3 OA 236 377 372 371 Interval INITAL P/F / P Notes: Newly converted to Injector per Sundry 317-595. "fest pressure 2900 PSI per Operator.Operator bled IA pressure back to approx.450 PSI.Note the larger volume fluid bled back. SCANNED • Friday,January 26,2018 Page 1 of 1 • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday,January 12, 2018 10:50 AM To: Wallace, Chris D (DOA);Alaska NS - Milne -Wellsite Supervisors;Alaska NS - Milne - Field Foreman Cc: Darci Horner- (C); Regg,James B (DOA); Stan Porhola; Brooks, Phoebe L(DOA) Subject: Milne Point Injectors MPF-90 and MPI-12 Ready for Injection Attachments: MIT MPU 1-12 1-11-18.xlsx; MIT MPU F-90 1-11-18.xlsx All, Milne point well MPI-12 (PTD#2011630) is being converted to water injection under sundry#317595.The well had a passing Pre-Injection MIT-IA(attached) on 1/11/18.The well is ready for an injectivity test followed by compliance testing once on stable injection. Milne point WAG injector MPF-90(PTD#2012110) has been shut-in since 2/6/2012 for reservoir management and is out of its 4 year MIT cycle.The well has no know integrity issues and had a passing Pre-Injection MIT-IA (attached)on 1/11/18. The well is ready to return to injection for stabilization and compliance testing. Plan Forward-Operations 1) Place wells on injection. Use caution, annuli are fluid packed. 2) AOGCC MIT-IA when wells are on injection and thermally stable. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 1 • • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.resct alaska.gov AOGCC.Insoectorsaalaska.gov phoebe.brooks(caalaska.ciov •chris.wallace(Qalaska.dov OPERATOR: Hilcorp Alaska LLC • FIELD/UNIT/PAD: Milne Point/Milne Point Unit/I Pad /,j Al_ tl,ZA+e DATE: 01/11/18 J /� OPERATOR REP: Matthew Linder AOGCC REP: Well I.12 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011630 Type Inj N Tubing 201 205 204 203 Type Test P Packer TVD 3.903 BBL Pump 4.0 IA 0 2846 ,- 2804 2793 - Interval 0 Test psi 2700 BBL Return 4.0 OA 163 371 372 368 Result P Notes: Witness waived by Brian Bixby.Pre-Injection MIT on newly converted injector to 2700 psi per Sundry 317-595 ../ • Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj W Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing _ Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test • Packer TVD BBL Pump IA Interval • Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result • Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. • PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA _ Interval Test psi BBL Return OA Result • Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) - 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT MPU I-12 1-11-1e - or T� • wP THE STATE Alaska Oil and Gas � of Lj\ S Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 leXtmn_AOFMa Main: 907.279.1433 LA91°ts- Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SCANNED ,.: 7 r)/1 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU I-12 Permit to Drill Number: 201-163 Sundry Number: 317-595 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, dC011 - Hollis S. French Chair 1.44J DATED this 1, day of January, 2018. EE-7.1:73 • • RECEIVED o R I G I N AOF ALASKA L l 9E ALASKA OIL AND GASTCONSERVATION COMMISSION SEC ? APPLICATION FOR SUNDRY APPROVALS X & '67 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: Convert to Injector Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development D. 201-163 • 3.Address: 3800 Centerpoint Dr,Suite 14000 6.API Number: Stratigraphic ❑ Service Anchorage Alaska 99503 50-029-23038-00-00 , 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 ❑ 1 MILNE PT UNIT Sfti 1-12 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517 ' 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): 12,470' . 3,712' • 12,470' . . 3,712' 1,255 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 108' 20" 108' 109' N/A N/A Surface 2,906' 10-3/4" 2,906' 2,408' 3,580psi 2,090psi Intermediate 10,228' 7" 10,228' 3,706' 7,240psi 5,410psi Liner"A" 2,457' 4-1/2" 12,393' 3,716' 8,430psi 7,500psi Liner"B" 2,232' 4-1/2" 12,396' 3,715' 8,430psi 7,500psi Perforation Depth MD(ft): 'Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 3-1/2" 9.3#/L-80/EUE MOD 9,644' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"x 3-1/2"TNT Perm.Hyd.and N/A ' 9,504'(MD)/3,572'(TVD)and N/A 12.Attachments: Proposal Summary 0 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑ , 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1/1/2018 OIL ❑ WINJ 0 WDSPL ❑ Suspended ❑ 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. Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Oper tions Manager Contact Email: sporhola[l hilcorp.com Contact Phone: 777-8412 Authorized Signature: Date: 12/18/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Nt f T- rte 3 -5q S-- Plug Integrity ❑ BOP Test El Mechanical Integrity Test D Location Clearance ❑ Other: It P f j�1/42v^n c fi-.,ca r pIe.;,,c.-e-4-,—........A"' —»,., ` ,0,"i^ r ....f, r.....„.„ z,., -'�-,_- zJ • 'iii (i-) Post Initial Injection MIT Req'd? Yes "No ❑ Spacing Exception Required? Yes El No Subsequent Form Required: �^" ,. , APPROVED BY Approved by: ( COMMISSIONER THE COMMISSION Date: j I Li 11 , �(��1� 43 42,0- ,� /3647 y ye /z -- 2`i—17 tal► Submit Form and �/ De Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: MPU 1-12 Ililcorp Alaska,LLI Date:12/18/2017 Well Name: MPU 1-12 API Number: 50-029-23038-00 Current Status: SI Oil Well [Jet Pump] Pad: I-Pad Estimated Start Date: January 1st, 2018 Rig: N/A Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-163 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: 1724074 Job Type: Convert to,Injector Current Bottom Hole Pressure: 1,655 psi @ 4,000' TVD (Last BHP measured 11/15/2017) Maximum Expected BHP: 1,655 psi @ 4,000' TVD (No new perfs added, EMW= 7.96 ppg) ✓' MPSP: 1,255 psi (0.10 psi/ft gas gradient) Brief Well Summary: MPU 1-12 was drilled in 2001 using Nabors 22E and completed as a multi-lateral in the Schrader Bluff OA and OB sands with an ESP pump. ESP changeouts took place in 2010 and 2014, the most recent was an ESP changeout in 2014 using Doyon #16 to replace the conventional ESP with a TTC-ESPCP (Thru-tubing conveyed electric submersible progressive cavity pump). In September 2015, the failed TTC-ESPCP was replaced using coil tubing. However, the new pump failed to work. A rig workover pulled the completion and ran an ESPCP pump in January 2016 but the pump failed in June 2016 due to solids production. The well was converted to a reverse circulating jet pump in November 2016, but multiple attempts to set a jet pump in the sliding sleeve profile and establish consistent production have been unsuccessful. Notes Regarding Wellbore Condition • Deviation down to sliding sleeve section (max angle 85.5° @ 8,110'). • Casing last tested to 2,500 psi for 30 min down to 9,504'on 11/08/2016. • Cleaned out fill to 11,593'with coil tubing on 11/13/2016. • Jet pump lost in hole (unknown which lateral) at 11,303' CTM on 5/30/2017. AOR(status of wells within 1/4 mile radius of injection zone): Current° . t t � } API Well No Permit Well Status` Zonal isolation(method) 50-029-23038-00-00 201-163 MPU 1-12 Idle Estimated TOC (calculated) at 6,880'MD Producer —2,370' above Schrader NB sand Active CBL run on 26 Aug 2001 indicates TOC at 50-029-23012-00-00 201-075 MPU 1-13 —7,150'MD, —2,586' above Schrader NB •"_.. Injector sand. 71+ Objective: The purpose of this work/sundry is to convert this well from a SI Schrader Bluff producer to a Schrader Bluff injector to provide waterflood support for offset producer MPU I-11 (PTD 201-137). . 14 • • Well Prognosis Well: MPU I-12 LU Date:12/18/2017 Surface Procedure: 1. MIRU Little Red Pumping Unit. PT lines to 3,000 psi. 2. Test 7" casing to 2,700 psi for 30 min (charted). a. Notify AOGCC Inspector at least 24 hours prior to conducting pre-injection MIT-IA. b. Record on 10-426 form. c. Email to wrivard@hilcorp.com for submission to AOGCC. 3. Perform injectivity test w/8.5 ppg produced water. a. Inject at 1.0 bpm (1,440 bwpd) or a max 1,250 psi for injectivity test. Do not exceed 1,500 psi. 4. RD Little Red Pumping Unit. 5. MU surface lines from injection header to existing tree. PT lines to 2,700 psi. a. Pressure test lines at existing water header pressure (2,700 psi). 6. Turn well over to injection. 7. After stabilized injection, conduct an MIT-IA to 2,700 psi. a. Notify AOGCC Inspector at least 24 hours prior to conducting MIT-IA. i b. Record on 10-426 form. c. Email to wrivard@hilcorp.com for submission to AOGCC. AOGCC Regulation Variance Requests: • 20AAC25.412(b) "The packer must be placed within 200 feet measured depth above the top of the perforations..." Requesting a variance to set the packer more than 200 feet measured depth above the dual slotted liner. The packer is set at 9,504' MD/3,572' TVD at approximately 79° hole angle. The packer is 476' MD to the top of the OA sand slotted liner, which is 90'TVD from the packer to the OA sand. The packer is 869' MD to the top of the OB sand slotted liner,which is 150'TVD from the packer to the OB sand. Attachments: ( 14-__ 1. Current Schematic yet l L 1'i-( 2. Area of Review(AOR)Summary ©©© 3. Area of Review Map 4. Surface Owner Affidavit H . • Milrill!Well: Point MPU 1-12Unit SCHEMATIC Last Completed: 11/08/2016 Hileorp Alaska,LLC PTD: 201-163 WELLHEAD Wellhead FMC Tubing Hanger,11"x 3-1/2"TC-II Top&Bottom Orig.KB Elev.:64.7'/Orig.GL Elev.:34.7' OPEN HOLE/CEMENT DETAIL RKB-Hanger:15.20'(ASR) 20" Cmt w/650 sx of Arcticset 1 in 30"Hole A AA j 10-3/4" Cmt w/585 sx AS Lite,502 sx Class"G"in 13-1/2"Hole 1eill ";0 20' 7" Cmt w/1,172 sx Class"G"in 9-7/8"Hole 04 4! CASING DETAIL ,, i1 Size Type Wt/Grade/Conn Drift ID Top Btm .4 20" Conductor 92/H-40/Welded N/A Surf 108' ; 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 2,906' 7" Intermediate 26/L-80/Btc-Mod 6.151 Surface 10,228' 1 il 1 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 9,936' 12,393' ii, 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 10,164' 12,396' 10-3/4" .,/1V4: TUBING DETAIL 3-1/2" Tubing 9.3/L-80/EUE-MOD 2.867 Surf 9,644' LINER DETAIL 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 9,936' 9,980' 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 9,980' 12,393' 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 10,164' 10,373' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 10,373' 12,396' WELL INCLINATION DETAIL KOP@300'MD Max Wellbore Angle=85.5 deg @ 8,102'MD 63.74 deg @ 2,550'MD JEWELRY DETAIL No Depth Item 1 2,345' GLM 3-1/2"x 1-1/2"Patco GLM(DGLV Set 11/08/16) 2 9,339' 3-1/2"XD Sliding Sleeve(2.813"Packing Bore Min ID;Closed 11/17/17) 3 9,427' 3-1/2"NDPG-C Single-drop Intake Gauge(2.913"ID) 4 9,485' 3-1/2"X Profile(2.813"Packing Bore Min ID) 5 9,504' 7"x 3-1/2"TNT Permanent Hydraulic Set Packer(2.949"ID) + 6 9,558' 3-1/2"Autofill Sub(2.88"ID) .,� &)1.6 7 9,643' Wireline Entry Guide(Btm at 9,644') Mn ID=2.813"ID $o I 2 C- 8 9,906' Baker Hook Wall,Hanger above 7"Window � , 4° 9 9,928' Baker Hook Wall,Hanger below 7"Window 3 10 9,930' Baker Tension Lock Swivel 11 10,116' Baker Tie Back Sleeve a . 12 10,128' Baker ZXP Liner Top Packer Mn ID=2813 ID ii... 4 13 10,147' Baker 7"x 5"HMC Liner Hanger r k 14 12,395' Btm 4-1/2"Pack-off Bushing 5 `'1Sct� 15 12,435' Btm 4-1/2"Guide Shoe AI I 16 12,396' Btm Baker Pack-off Bushing 17 12,439' Btm Baker 4-1/2"Guide Shoe " ) 6 0 LATERAL WINDOW DETAIL I ( 14 2(o Top of"OA"Window @ 9,916'MD;Bottom @ 9,928'MD;Angle @ top of window is 80 deg Top of"OB"Window @ 10,228'MD;Bottom @ 10,240'MD;Angle @ top of window is 87 deg 7 GENERAL WELL INFO API:50-029-23038-00-00 fe "r 8 3`" Drilled and Cased by Nabors 4ES-12/08/2001 a 3. 10 14 ESP Completion by Nabors 4ES-12/15/2001 « . FISH-3 1/2"X- Convert to ESPCP by Nabors 4ES-6/30/2010 `4' "OA"Lateral ° 15 Lock,3"RCOM Jet Convert to TTC-ESPCP by Doyon 16-12/05/2014 11.• 'irairiArt Pump(Serial BP Convert to ESPCP by ASR 1-1/17/2016 121, 13 16 1078),Bottom Convert to Jet Pump by ASR 1-11/08/2016 screen.Fish Length= "OF Lateral 17 5.83'.Could be in 7" either lateral. TD=12,470'(MD)/TD=3,712'(TVD) PBTD=12,470'(MD)/PBTD=3,712'(TVD) Revised By:STP 11/27/2017 i • Area of Review Summary — Milne Point Unit I-12 (PTD 201-163) This Area of Review is required prior to the conversion of well MPU I-12 from a producer to a water injector. This AOR discusses wells with 1/4 mile of the well's entry point into the Schrader Bluff Formation OA sand (top of the injection zone) to the bottom of MPU I-12 well bore completion. I- ---_ "/ I 1-12 \ l i a!__ _ i-14L1 �\ -12L1 ---..�. -11 --— `-- 1-06 ——---: _ 1-111_1 MILNE POINT UNIT KUPARUK RIVER UNIT Figure 1:Map showing wells within X mile radius from MPU 1-12. The list of all operators and surface owners within 1/4 mile of MPU I-12 is below: # Operators # Surface Owners 1 Hilcorp Alaska,LLC 1 Alaska Department of Natural Resources(ADNR) Table 1:List of operators and surface owners • • An affidavit has been submitted to the following operators and surface owners: # Operators # Surface Owners 1 N/A 1 Alaska Department of Natural Resources(ADNR) Table 2:List of operators and surface owners receiving an affidavit One other wellbore, MPU I-13 (PTD 201-075), enters the Schrader Bluff formation just outside this area of review. The tables below illustrate the wells within the AOR, distance from MPU I- 12, completion details, and annulus integrity/cement conditions based on in-depth review of each well: Well Name PTD Distance Annulus Integrity (Feet) MPU 1-12 201-163 0 TOC estimated at 6,880' MD based on volume pumped MPU 1-13 201-075 1,460 TOC estimated at 7,150' MD—based on CBL dated 8/26/01 Table 3:Distance and annulus integrity of wells within AOR Well Casing Hole Vol. of Cement Schrader Bluff Schrader Bluff Name Size depth (MD) depth (TVDss) MPU 1-12 7" 9-7/8" 240 bbls 9,156' 3,438' MPU 1-13 7" 8-1/2" 296 bbls tail/358 bbls lead 9,700' 3,433' Table 4:Completion Detail Well MPU I-12 was completed in December 2001. The completion enters the Schrader Bluff at 9,156' MD. A 10-3/4" surface casing was run to 2,905' MD and cemented to surface using 432 bbl of Permafrost Type "L" cement and 103 bbl of Class"G". Returns of 250 bbls of lead cement were seen at surface after the plug was bumped. The 10-3/4" casing was tested to 1,900 psi for 5 V..1"' minutes after bumping the plug. Before drilling out the float collar and shoe track, the casing was tested to 1,500 psi for 30 minutes. A 7"production casing string was run from surface to 10,347' MD. The production casing string was cemented with 240 bbls of 15.8 ppg Class "G" cement. Plugs bumped with floats holding, and the estimated top of cement at 6,880' MD. The 7" casing was tested to 2,900 psi for 5 minutes. The 7" production casing was`tested,500 psi for 30 minutes prior to drilling out the float collar and shoe track.A lower lateral was drilled and a 4-1/2" slotted liner ran in the OB sand. An upper lateral was drilled and a 4-1/2" slotted liner ran in the OA sand. Well MPU I-13 was completed in August 2001.The completion enters the Schrader Bluff at 9,700' MD. A 7" production casing (monobore) was run to 11,397' MD and cemented to surface using 29 6 bbls of Class"G"cement at the shoe, and 358 bbls of Permafrost Type"L"thru the DV collar at 1,416' MD. Returns of 10 bbls of lead cement were seen at surface after the plug was bumped during the job thru the TAM port collar. The 7" production casing was tested to 4,500 psi for 30 minutes after drilling out the TAM port collar. The well is a cased and perforated dual string completion, with one string in the OA sand and one string in the OB sand. TC 7I a ' f • • The injection zone is bracketed by a north-south fault to the east and a east-west fault to the north, isolating this pattern from the rest of the field. No faults are known to exist in the injection zone. ,.7,,_ ..„______„_______ ,, .....,.. -yam —~ 4111•11 , al . - 4' ,„,t_i 2r4'14-04,-,,..,==r,,,, ., / .. I-1 2 i - N. ® r f A/ c7 - L f i 0 --\\ 1, 7 ..8.,uceaas f ,.-J. ,..,7 , „,„ ,,,,, „ , c.,7 0, 01 o•mss a ,, ..,.....2„.„ \\, is° Irx, . Figure 2:Map showing faulting near MPU 1-12. Withdrawal and injection volumes and reservoir pressures indicate this area is hydraulically isolated. This hydraulic unit is referred to as HU-13. While drilling the OB lateral for MPU I-12 at 13,243' MD (MPU I-12PB1, API 50-029-23038- 70), the well took a kick with 9.2 ppg mud in the hole. The lateral was eventually killed with a k)V 11.9 ppg mud, but experienced lost circulation and the BHA became stuck and was not able to be fished out of the hole. The lateral and fish was plugged back and redrilled to 12,470' MD with 9.2 ppg mud and the 4-1/2” liner ran to bottom(MPU 1-12, API 50-029-23038-00). Offset injector MPU 1-13 was drilled before MPU I-12 and encountered a pressure anomaly after it had TD'd the well,but this well had a large open hole section and this salt water kick was likely due to the North-South fault that separates MPU I-13 and MPU I-10 (see Figure 2 above). Offset producer MPU I-11 (PTD 201-137) was drilled after MPU 1-12 and did not encounter any pressure anomalies in the Schrader Bluff drilling dual laterals with 9.2 ppg mud in the same OA and OB sands as MPU 1-12. Offset Kuparuk River well KRU 3K-108 (PTD 208-130)was drilled in 2008 in the Schrader Bluff equivalent sands (West Sak) and did not encounter any pressure anomalies within the interval, • • completing their liner with a 9.2 ppg brine. This well is immediately due west of the toe of the MPU I-12 well. Based on the immediate offset well information, it appears to be a small isolated anomaly that is isolated from the other wellbores in the area and not likely to impact the waterflooding of the reservoir from MPU I-12 south to MPU I-11. Outside of the MPU I-12PB1 anomaly, the original reservoir pressure in this hydraulic unit was 8.6 ppg EMW as of 2001. The current reservoir in 2017 is approximately 8.0 ppg EMW, based on the active downhole gauge on MPU I-12. Injection conformance of other offset injectors in adjacent patterns only applies to MPU I-13 in this case. This well currently injects down dual strings, one injecting in the Schrader Bluff OA sand and one injecting in the Schrader Bluff OB sand. Injection rates and pressures indicate that there is limited conductivity to offset producers MPU I-11 and MPU 1-12. This is likely caused by near-wellbore damage in the MPU I-13 completion that is preventing an effective water flood sweep to the offset producers. • • � I ' I 1 Q i I T. .......--.......--_,--7....N4‘- ......=-_ _ _- ! ! 11 S 1 l ; 1 o _ 11 i 1 z 1 I 1 o � .._.. a 1 J ' 11 \N e I :MI- a- N<'''' I/ \I i I / I- 2 ceW Y I, f N CL 11 1 I li 4 i/ CDi f rII I1} II /7 .... 11 1 II I 1 I I r 1.I o Kt B 1 M I \at ,I 1 I \\ c 1 \ _ 1 \ N 11 \ _a \ i N M § r 0 Y J eg < \\ M \ \M M \LO 0 a z JIi O w -$ w d3g A 8 3�eai ,1-e% / 8 ._ 'N O Cl • • / i Q \ \ 1 / / / o \ \ I /I/ _a,. � \ \ 1 J J1 � 1 1 ZCCI ap44! im/ n o OG a. m m a� m O TTT o ra � w rl x�5 O o 0 2 c N Lo i a` _\ n m m O C� e Nr � J c s_ t_ a g 0 _ = I *;,,,,-----.4 I A n 1 \\ p_ �-�' }IV 7 � . , I / I I� �� l 'r i — z / 1i'Y \I\ / / 1 / \ c / 1 1 A y S 7 D7 II / I ` r '7 I 111 1 ` ,� d ( ICC al 11 / I 1 ` ' / �' a III I cn CO > N I I I I // / 1 I I I I 1 \ N N V • . -O CD C 1 ,/ I I 11 '/ `\‹ N 1 11 11 \ I \ a. d d a co 2 II I '/ o// \\m 1 i�I1 111 I1 11 \, d 2 2 2 20 I I ��I W IIS 11 I CD f 11 I } ,' I/I I 11 11 1. I I1 J I ! III .� :Z 1�1I I I 1--'!- I 1/�,' ,�`M I�' 111 I� 1 1 1 I 1,' K rm q,I 1 1 1 1 C a_ N 1 //, � '0 1 1 Cl) � X I/ N 1 a) 11 I I , I �,...m � SII co 11 1 / 1 cy cL - W 1 11 JH �I I I 1 1 0 N I/1 ,-� , I I I w- s °. '� I 1 II i Z / — r Ln a 1 1 I r" I / J , I 4) I .-1 I D I _ I 1 I I I c _- — N w 1 1 i O 1 1 1 I 11 I I I LJ — 1 I I ) L-- I' �' _z } 1 1 11 :s' II „\\, 1 1I 1 1 I -- III I I II I li o N ,- I 1 M� _;E ' CD 6' �i 01-^ I I m aI mi`"° 1 ,1 u01 I , I I ) ♦ y" Q. I 1jII r�� 1 M I N 111 I 5 I I j 1 + \ ty CO 00 1I CNI / 1 I11 I o w, —I \ A_ N f 1 11 �' 0 ,) cJ p J Y � �. �. . -z' ._...._�t M N O / O) W' o Y / m m Lo O M .} 1 ;200,:27 I N 1 CO I co / o a� N Z lei CD N , I o / z 0 O 'm I I M / € d a ;� I, 1 '1 / t/ �, I )I / e • • Landowner Notification Letter MPI-12 Page 2 of 2 VERIFIATION OF NOTICE PER 20 AAC 25.402(c)(3) MILNE POINT UNIT MPU I-12 I, Bo York, Operations Manager do hereby verify the following: I am acquainted with Hilcorp Alaska, LLC's application for sundry approval to the Alaska Oil and Gas Conservation Commission to convert well MPU I-12 to an injector. Pursuant to pending regulation 20 AAC 25.402(c)(3), I assert that all owners, landowners, surface owners, and operators within a one-quarter mile radius of the current wellbore trajectory have been provided notice of Hilcorp Alaska, LLC's proposed operations. DATED at Anchorage, Alaska this day of December, 2017. Bo ork, Operations Manager Hilcorp Alaska, LLC STATE OF ALAKSA ) ) ss THIRD JUDICIAL DISTRICT ) SUBSCRIBED TO AND SWORN before me this 1Cday of December, 2017 IA, 6. gkI)AJA/e,C OTA PUBLIC IN AND FOR THE STATE OF ALSKA My Commission expires: OI. if I c),20)/ STATE OF ALASKA : ,. NOTARY PUBLIC t "'i Alicia G.Showalter My Commission -,. Oct.4,2021 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, December 21, 2017 9:29 AM To: 'Stan Porhola' Subject: MPU 1-12 (PTD 201-163) Sundry Application Good morning Stan, The AOGCC treats wells/motherbores and laterals as individual wells for recording purposes. Please submit a sundry application to convert MPU I-12L1 (PTD 201-164)from a producer to an injector. The commission will hold the sundry application for MPU 1-12 until the application for MPU I-12L1 is received. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Thursday, December 21, 2017 9:31 AM To: Bettis, Patricia K (DOA) Subject: Automatic reply: MPU 1-12 (PTD 201-163) Sundry Application I will be out of the office on PTO, returning Friday, Dec 29th. I will have limited immediate access to my email and cell phone. If urgent, please contact Paul Chan or Taylor Wellman in my absense. • • ECEIVED STATE OF ALASKA NOV 2a ?017 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC 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 a Re-enter Susp Well a Alter Casing ❑ Other: Convert to Injector ❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory a Development Q 201-163 - 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic a Service a 6.API Num'-r: Anchorage Alaska 99503 50-029-23038-00-00 '- 7.If perforating: 8.We . e d 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 a ` MILNE PT UNIT SB 1-12 - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517 MILNE PONT/.- HRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(p-' : • Plugs(MD): Junk(MD): 12,470' 3,712' 12,470' 3,712' k 55 N/A N/A Casing Length Size MD % TVD Burst Collapse Conductor 108' 20" 108' \ 109' N/A N/A Surface 2,906' 10-3/4" 2,906' `,,' 2,408' 3,580psi 2,090psi Intermediate 10,228' 7" 10,228' . 3,706' 7,240psi 5,410psi Liner"A" 2,457' 4-1/2" 12,393' 3,716' 8,430psi 7,500psi Liner"B" 2,232' 4-1/2" 12,3•.' '\ 3,715' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: i1` Tubing Grade: Tubing MD(ft): See Schematic See Schematic 3- " 9.3#/L-80/EUE MOD 3,597' Packers and SSSV Type: •ac r nd SSSV MD(ft)and TVD(ft): 7"x 3-1/2"TNT Perm.Hyd.and N/A IL 9,504'(MD)/3,572'(TVD)and N/A 12.Attachments: Proposal Summary Q Wellbore sche -if. Well lass after proposed work: Detailed Operations Program ❑ BOP Sketch ip M E for ory ❑ Stratigraphic❑ Development❑ Service 0 14.Estimated Date for \Nor' \, ,15. II Status after proposed work: 12/11/201 + Commencing Operations: l OIL 0 WINJ Q WDSPL ❑ Suspended a 16.Verbal Approval: Date: l GAS a WAG ❑ GSTOR a SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown a Abandoned a 17. I hereby certify that the foregoing is true and th- .rocedure approved herein will not be deviated from without prior written approval. Sri' Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola anhilcorp.com Contact Phone: 777-8412 Authorized Signature. C Date: --2-d\\bu '11?, ii, COMMISSION USE ONLY Conditions of approval: N. ify Commiss'4 n so that a representative may witness Sundry Number: I-1` Plug Integrity ❑ Bc•Test ❑ Mechanical Integrity Test a pp��ggLocation Clearance ❑ Other: Sl1b6�9I'fli ED71 ; i' z.„H) Post Initial Injection MIT ''eq'd? Yes a No ❑ Spacing Exception Req(iired? Yes a No a Subsequent Form Required: r..S 3 r" 18 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • S Well Prognosis Well: MPU 1-12 Hilcorp Alaska,LLI Date:11/15/2017 Well Name: MPU 1-12 API Number: 50-029-23038-00 Current Status: SI Oil Well [Jet Pump] Pad: I-Pad Estimated Start Date: December 11th, 2017 Rig: N/A Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-163 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 Numbe'r:� Job Type: Convert to Injector Current Bottom Hole Pressure: 1,655 psi @ 4,000' TVD (Last BHP measured 11/15/2017) Maximum Expected BHP: 1,655 psi @ 4,000' TVD (No new perfs added, EMW= 7.96 ppg) MPSP: 1,255 psi (0.10 psi/ft gas gradient) Brief Well Summary: MPU 1-12 was drilled in 2001 using Nabors 22E and completed as a multi-lateral in the Schrader Bluff OA and OB sands with an ESP pump. ESP changeouts took place in 2010 and 2014, the most recent was an ESP changeout in 2014 using Doyon #16 to replace the conventional ESP with a TTC-ESPCP (Thru-tubing conveyed electric submersible progressive cavity pump). In September 2015, the failed TTC-ESPCP was replaced using coil tubing. However, the new pump failed to work. A rig workover pulled the completion and ran an ESPCP pump in January 2016 but the pump failed in June 2016 due to solids production.The well was converted to a reverse circulating jet pump in November 2016, but multiple attempts to set a jet pump in the sliding sleeve profile and establish consistent production have been unsuccessful. Notes Regarding Wellbore Condition • Deviation down to sliding sleeve section (max angle 85.5° @ 8,110'). • Casing last tested to 2,500 psi for 30 min down to 9,504'on 11/08/2016. • Cleaned out fill to 11,593'with coil tubing on 11/13/2016. • Jet pump lost in hole (unknown which lateral) at 11,303' CTM on 5/30/2017. AOR(status of wells within 1/4 mile radius of injection zone): Current API Well No Permit Well Zonal isolation(method) Status 50-029-23038-00-00 201-163 MPI 12 Idle Estimated TOC (calculated) at 6,880'MD Producer —2,370' above Schrader NB sand Active CBL run on 26 Aug 2001 indicates TOC at 50-029-23012-00-00 201-075 MPI-13 Injector -7,150'MD, 2,586' above Schrader NB sand. Objective: The purpose of this work/sundry is to convert this well from a SI Schrader Bluff producer to a Schrader Bluff injector to provide waterflood support for offset producer MPU I-11 (PTD 201-137). Well Prognosis Well: MPU 1-12 IIilcora Alaska,LL) Date: 11/15/2017 Surface Procedure: 1. MIRU Little Red Pumping Unit. PT lines to 3,000 psi. 2. Test 7" casing to 2,700 psi for 30 min (charted). 3. Perform injectivity test w/8.5 ppg produced water. a. Inject at 1.0 bpm (1,440 bwpd) or a max 1,250 psi for injectivity test. Do not exceed 1,500 psi. 4. RD Little Red Pumping Unit. 5. MU surface lines from injection header to existing tree. PT lines to 2,700 psi. a. Pressure test lines at existing water header pressure (2,700 psi). 6. Turn well over to injection. 7. Notify AOGCC Inspector for witnessed MIT-IA after stabilized injection. Attachments: 1. Current Schematic 2. Area of Review(AOR) Map II • • Milne Well: MPUPoint 1-12 Unit SCHEMATIC Last Completed: 11/08/2016 Hiker!)Alaska,t 1,c PTD: 201-163 WELLHEAD Wellhead FMC Tubing Hanger,11"x 3-1/2"TC-II Top&Bottom Orig.KB Elev.:64.7'/Orig.GL Elev.:34.7' OPEN HOLE/CEMENT DETAIL RKB-Hanger:15.20'(ASR) 20" Cmt w/650 sx of Arcticset I in 30"Hole 10-3/4" Cmt w/585 sx AS Lite,502 sx Class"G"in 13-1/2"Hole 20; I 7" Cmt w/1,172 sx Class"G"in 9-7/8"Hole CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 92/H-40/Welded N/A Surf 108' 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 2,906' 1 ". 7" Intermediate 26/L-80/Btc-Mod 6.151 Surface 10,228' 12 l f 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 9,936' 12,393' 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 10,164' 12,396' 10-3/4" liA TUBING DETAIL 3-1/2" Tubing 9.3/L-80/EUE-MOD 2.867 Surf 9,644' LINER DETAIL 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 9,936' 9,980' 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 9,980' 12,393' 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 10,164' 10,373' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 10,373' 12,396' WELL INCLINATION DETAIL 1'. KOP @ 300'MD Max Wellbore Angle=85.5 deg @ 8,102'MD 63.74 deg @ 2,550'MD JEWELRY DETAIL No Depth Item 1 2,345' GLM 2.875"x 1"Patco GLM(DGLV Set 11/08/16) 2 9,339' 3-1/2"XD Sliding Sleeve(2.813"Packing Bore Min ID;Closed 11/17/17) 3 9,427' 3-1/2"NDPG-C Single-drop Intake Gauge(2.913"ID) 4 9,485' 3-1/2"X Profile(2.813"Packing Bore Min ID) 5 9,504' 7"x 3-1/2"TNT Permanent Hydraulic Set Packer(2.949"ID) 6 9,558' 3-1/2"Autofill Sub(2.88"ID) 7 9,643' Wireline Entry Guide(Btm at 9,644') Mn I0=2.813'ID ,p 2 8 9,906' Baker Hook Wall,Hanger above 7"Window I'i 9 9,928' Baker Hook Wall,Hanger below 7"Window 3 10 9,930' Baker Tension Lock Swivel 11 10,116' Baker Tie Back Sleeve 12 10,128' Baker ZXP Liner Top Packer Y W10=2.813'10 ° VI 4 '+ 13 10,147' Baker 7"x 5"HMC Liner Hanger 14 12,395' Btm 4-1/2"Pack-off Bushing ;fi' S 15 12,435' Btm 4-1/2"Guide Shoe 16 12,396' Btm Baker Pack-off Bushing 17 12,439' Btm Baker 4-1/2"Guide Shoe 6 LATERAL WINDOW DETAIL t9` �� Top of"OA"Window @ 9,916'MD;Bottom @ 9,928'MD;Angle @ top of window is 80 deg Top of"OB"Window @ 10,228'MD;Bottom @ 10,240'MD;Angle @ top of window is 87 deg GENERAL WELL INFO 8 API:50-029-23038-00-00 g Drilled and Cased by Nabors 4ES-12/08/2001 10 14 ESP Completion by Nabors 4ES-12/15/2001 Nr., FISH-3 1/2"X Convert to ESPCP by Nabors 4ES-6/30/2010 11'OA"Lateral OA _15 Lock,3"RCOM Jet Convert to TTC-ESPCP by Doyon 16-12/05/2014 12 1s .. Pump(Serial BP- Convert to ESPCP by ASR 1-1/17/2016 1078),Bottom Convert to Jet Pump by ASR 1-11/08/2016 A. screen.Fish Length= ` "Ce'Lateral diV3 17 5.83'.Could be in 7' ` either lateral. TD=12,470'(MD)/TD=3,712'(TVD) PBTD=12,470'(MD)/PBTD=3,712'(TVD) Revised By:STP 11/17/2017 • • • ` 1 } ,,„,,. f' ' .1... • :000'''...-.' I 1 i I ammo... .-..........,.----- 1 I , 0 0 , I 7 E 1— I 1 v 5 ...... ....... I 't Ii' w / \1 \ _.., I \ \ I\ , ,... , • \ t— \I E \ / m w w •,..... ...... cl" 0 1 1 I i n / 1 ! I 1 / I , , I i /14 I r I 4 II (0 i I ii 11 1 i CV) id I t / , // /1 1 i I/ q I 11' # 1 II t I II I I I T . i 1 H n 1 4 r- di : , II -..- co 0 1 , 4 i I , , . i \ \ c L,- I. N 0 4 c., \, c., C')vc2 , 10‘' i , , N \ i . \ , \- ' ' ' 01 ce g! .,3 LL :-.,C3 ti 0141-'' 0 . 7 .,t 3,., 2„ z , '•N 'N ' ! 0 Z i 0 iL2 OA 1 I ; 3-'w: , = .E •+1.* 11.1.s `, t\ N oE.A1 \ /0 V Mit \ \ el ,..- i 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent Tuesday,January 16,2018 10:10 AM To: 'Tom Fouts' Cc Stan Porhola; Bettis, Patricia K(DOA);samantha.carlisle@alaska.gov Subject: RE: MP I-12 Sundry Submittal Withdrawal Request- PTD:201-163 Tom, The AOGCC with withdraw the initial sundry(317-553) for 1-12 conversion to injector as requested.The updated ones for 1-12 and 1-12L1(317-595/598)should be in your office. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Tom Fouts [mailto:tfouts@hilcorp.com] Sent:Wednesday,January 10,2018 11:07 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Stan Porhola<sporhola@hilcorp.com> Subject: MP 1-12 Sundry Submittal Withdrawal Request- PTD: 201-163 Guy, Hilcorp Alaska LLC is officially requesting the withdrawal of the sundry submitted for MP 1-12 on 11/20/2017(see attachment)due to additional information request by the AOGCC. The previous sundry was replaced by the sundry submittal on 12/19/2017. Please feel free to contact me with any questions you may have. Thanks, Tom Fouts I Senior Ops/Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907)777-8398 Mobile: (907) 351-5749 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Friday, November 24, 2017 10:03 AM To: 'Stan Porhola' Subject: MPU 1-12 (PTD 201-163) Sundry Application Attachments: AOR guidance Doc.pdf;AOR go-by.pdf Good morning Stan, We appreciate Hilcorp providing the plat for the AOR; however for an AOR for an injector, more information is required. I attached a guidance document for Hilcorps' use as an AOR"go-by" that includes a table that includes distance from proposed injection well, completion details, and annulus integrity/cement conditions and discussion of other wells within the AOR. All wells within the AOR include plugged and abandoned wells, e.g., N-01A and N-01B and laterals. Submittal of this type of form with the Permit to Drill Application for an injector or for a request to convert a producer to injector would greatly aid the AOGCC's review of Hilcorps' application. Please submit a detailed discussion of the AOR for MPU I-12 that includes an evaluation of the integrity/cement conditions of all wells within the AOR. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 STATE OF ALASKA A ALOA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS .A 1.Operations Abandon Plug Perforations LI Fracture Stimulate Li Pull Tubing CT FCO 4 Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Convert to Jet Pump ❑ Plug for Redrill ❑ ?rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Coil-Jet Pump Changeout [ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development 0 Exploratory ❑ 201-163 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 COVED g D 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025517 MILNE PT UNIT SB 1-12 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): DEC 0 1 2016 N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: AOGCC Total Depth measured 12,470 feet Plugs measured N/A feet true vertical 3,712 feet Junk measured N/A feet Effective Depth measured 12,470 feet Packer measured N/A feet true vertical 3,712 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 108' 20" 108' 108' N/A N/A Surface 2,906' 10-3/4" 2,906' 2,408' 3,580psi 2,090psi Intermediate 10,228' 7" 10,228' 3,706' 7,240psi 5,410psi Liner"A" 2,457' 4-1/2" 12,393' 3,716' 8,430psi 7,500psi Liner"B" 2,232' 4-1/2" 12,396' 3,715' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80/EUE MOD 9,644' 3,597' 9,504'(MD) Packers and SSSV(type,measured and true vertical depth) 7"x 3-1/2"TNT Perm.Hyd. N/A 3,572'(TVD) 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 SCANt4ED 6,PP f? 1 3?1.117 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 40 895 Subsequent to operation: 0 4 0 430 934 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory Developments Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil s Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-528&316-573 Contact Stan Porhola Email sporholaahilcoro.com Printed Name Bo York Title Operations Manager Signature /-27Phone 777-8345 Date 11/6/2016 /- /2---/Y--/&" Form 10-404 Revised 5/2015 RBDMS �� DEC - 8 2010 Submit Original Only H . • Milne Point Unit Well: MPU 1-12 SC H E M ATI C Last Completed: 11/08/2016 Ilticorp Alaska.LLC PTD: 201-163 WELLHEAD Wellhead FMC Tubing Hanger,11"x 3-1/2"TC-Il Top&Bottom Orig.KB Elev.:64.7/Orig.GL Elev.:34.7' OPEN HOLE/CEMENT DETAIL RKB-Hanger:15.20'(ASR)31 k 20" Cmt w/650 sx of Arcticset I in 30"Hole ;; ,„ 10-3/4" Cmt w/585 sx AS Lite,502 sx Class"G"in 13-1/2"Hole 20 7" Cmt w/1,172 sx Class"G"in 9-7/8"Hole E CASING DETAIL a' Size Type Wt/Grade/Conn Drift ID Top Btm " 20" Conductor 92/H-40/Welded N/A Surf 108' S' 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 2,906' IIII 1 r- 7" Intermediate 26/L-80/Btc-Mod 6.151 Surface 10,228' i 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 9,936' 12,393' 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 10,164' 12,396' 10-3/4" ° 0i' TUBING DETAIL 3-1/2" Tubing 9.3/L-80/EUE-MOD 2.867 Surf 9,644' LINER DETAIL 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 9,936' 9,980' 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 9,980' 12,393' 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 _ 10,164' 10,373' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 10,373' 12,396' WELL INCLINATION DETAIL KOP@300'MD Max Wellbore Angle=85.5 deg @ 8,102'MD 63.74 deg @ 2,550'MD F' JEWELRY DETAIL No Depth Item 1 2,345' GLM 2.875"x 1"Patco GLM(DGLV Set 11/08/16) 2 9,339' 3-1/2"XD Sliding Sleeve(2.813"Packing Bore Min ID;7C JP set 11/14/16) 3 9,427' 3-1/2"NDPG-C Single-drop Intake Gauge(2.913"ID) 4 9,485' 3-1/2"X Profile(2.813"Packing Bore Min ID) 5 9,504' 7"x 3-1/2"TNT Permanent Hydraulic Set Packer(2.949"ID) 6 9,558' 3-1/2"Autofill Sub(2.88"ID) 7 9,643' Wireline Entry Guide(Btm at 9,644') Ivan ID=2.813"ID i i i 2 8 9,906' Baker Hook Wall,Hanger above 7"Window ry '1 lilt9 9,928' Baker Hook Wall,Hanger below 7"Window 3 1 10 9,930' Baker Tension Lock Swivel 11 10,116' Baker Tie Back Sleeve 11„ 12 10,128' Baker ZXP Liner Top Packer Nin ID=2.813 ID " _E 4 13 10,147' Baker7"x 5"HMC Liner Hanger Gel .Lei= i 14 12,395' Btm 4-1/2"Pack-off Bushing * 5 15 12,435' Btm 4-1/2"Guide Shoe 16 12,396' Btm Baker Pack-off Bushing i : 17 12,439' Btm Baker 4-1/2"Guide Shoe �?'. 6 ' LATERAL WINDOW DETAIL Y-1 . Top of"OA"Window @ 9,916'MD;Bottom @ 9,928'MD;Angle @ top of window is 80 deg Top of"OB"Window @ 10,228'MD;Bottom @ 10,240'MD;Angle @ top of window is 87 deg y GENERAL WELL INFO Pe, 8 API:50-029-23038-00-00 v" ' 9 Drilled and Cased by Nabors 4ES-12/08/2001 2i 10 14 ESP Completion by Nabors 4ES-12/15/2001 u -_ Convert to ESPCP by Nabors 4E5-6/30/2010 "Q4"Lateral 15 Convert to TTC-ESPCP by Doyon 16-12/05/2014 12 16 11' Convert to ESPCP by ASR 1-1/17/2016 13 Convert to Jet Pump by ASR 1-11/08/2016 A "06"Lateral 17 7" TD=12,470'(MD)/TD=3,712'(TVD) PBTD=12,470'(MD)/PBTD=3,712'(TVD) Revised By:TDF 12/6/2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP MP 1-12 ASR#1 50-029-23038-00-00 201-163 11/4/16 11/14/16 Daily Operations: 11/2/26/2016 Wednesday No activity to report. 11/3/2016-Thursday No activity to report. 11/4/2016- Friday Spot equipment on MPI-12, Set well cover, Nipple Down Tree, Nipple up BOP, set rig floor with crane. Move rig unit on to Mud boat, Raise Derrick& pin. Set Catwalk, rig up Certek system. Connect gas alarms & calibrate &test. Continue to rig up, install circulating lines, install heat trace on circulating lines & Koomey lines. Pull BPV, install TWC, Held Sundry review with day crew. Continue to Heat trace and insulating lines. Shell Test Bop and all Connection to 250/,1,500psi ( Good Test) Spot ESP Spooling unit, Hang ESP Sheave in Derrick.Test Bop all Rams and Valves to 250/2,500psi 5Min Each,Tested 2-7/8" and 3-1/2"Test Joints, Annular 250/ 1,500psi 5Min Each,Test Accumulator and Chart Pressures ( AOGCC Chuck Scheve Waived Witness Bop Test on 11-4-16 @ 7:12AM). Held Sundry review with day crew. Well head rep Tee Bar Removed TWC Valve. R/U to Pump Down the Tubing Take Returns to the Flow Back Tank, Circulate 290 bbl. 140 Degree Sea Water, ICP w/ Pump Rate of 3 bpm at 1,450psi, FCP w/ Pump Rate of 3bpm at 1,014psi,Total bbls. Pump 290bbls. 20 bbls pump away Have Returns to the Flow Tank. M/U landing joint RIH Screw into Hanger BOLDS open IA Valvepsi=0 Pull Hanger to the Rig Floor at 48k Free Pull 44k flfi 11/5/2016-Saturday D Service Rig, Check fluid on equipment.TOOH, Lay down 2-7/8" Tubing[Total Joints 303),Break Down Lay Down Old ESP Pump Assembly, Centrilift Rep Meg Pump Motor at Surface Motor was Grounded out. Remove Pup Joint f/top of Pump, Pump is Sanded up Solid and Locked up Solid Main Shaft will not Rotate, Pump was Transported to Centrilift Shop for Further Inspection, Did not Observe no Corrosion on exterior Pump, Recovered Cross Collar Clamps=247/ Mid Joint Clamps=2/ Protectorlizers=3/ Flat Guards=2. Clear and Clean Rig Floor and Cellar Area. Load and Tally 322 joints 3.5 WS on Pipe Racks.Trip in the hole 7' #26 Casing Scraper and 3.5 WS to 3,575'. 11/6/2016-Sunday Continue to Trip in the hole 7'#26 Casing Scraper and 3.5 WS F/3,575'.T/9,627' 322 Joints. Rig up &Circulate wellbore @ 3.5 bpm @ 600psi.Total pumped 300 bbls.TOOH with 3.5" work string F/9,627'to Surface Lay Down 7'#26 Casing Scraper. Load and Tally 305 Joints of 3.5 9.3/L-80/EUE Tubing and Completion Assembly on Pipe racks, Hang Cap line Sheave in Derrick and Spot Control Line Spooler and Air Compressor. 11/7/2016- Monday J Service Rig, Check fluid in all equipment. Load completion equipment on Catwalk. Make up completion assembly per /..1 program, Install I wire to Intake gauge &test.TIH with Completion assembly on 3.5" L-80 9.2# EUE Modified tubing, to 3,624'.Test cable each 2,000'. Service Rig, Check fluid in all Equipment.TIH with Completion Assembly on 3.5"/9.3#/ L-80/ 44.6 EUE Mod Tubing F/3,624'.to 9,608'. (Total jts Ran 302) Pick up weight= 63K Slack off Wt. =5 k • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP MP 1-12 ASR#1 50-029-23038-00-00 201-163 11/4/16 11/14/16 Daily Operations: 11/8/2016-Tuesday Service Rig, Check fluids in all equipment. Make up landing joint& Hanger, Install I wire in tubing hanger, Land tubing hanger& run in lock down screws. Rig up Little red services, pressure test lines, reverse circulate with 53 bbls of diesel l` down 3.5" x 7" for freeze protect. Pressure up on tubing to 3,200psi. set Halliburton packer, held 10 min. charted, bleed down to 1,000psi,Test 3.5" x 7" IA to2,500psi charted for 30 minutes bleed annulus to 500psi &tubing down to Opsi. Pressure up on tubing to shear out Mirage plug to 4,300psi. Install BPV with Tee bar, bullhead 10 bbls of diesel down tubing. rig down little red services. (Release rig @ 13:00hrs.). Prepare for rig move, blow all lines down, Rig down Koomey lines, break BOP connections down to 4 bolt. Move misc. rig equipment to E pad, Prep Rig floor and Cellar, Unpin top section of Derrick and Lower. Move ASR Rig to MPE-14, Load mud boat and Rig Equipment on Trailer Haul to MPE-14 Alaska Crane Hoisted Rig Floor and Well House on Flat Bed Truck, Assisted in Removal of Bop Stack, nipple up Tree,Test Hanger Void to 5,000psi. Pull BPV and Install TWC Valve, Fill Tree with Diesel Test Tree Connections to 5,000psi. Rig Down and move Company Man and Change House Trailer and Pit Module to MPE-14, • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP MP 1-12 ASR 50-029-23038-00-00 201-163 11/4/16 11/14/16 Daily Operato.ns 11/9/26/2016-Wednesday, No activity to report. 11/10/2016-Thursday No activity to report. 11/11/2016-Friday No activity to report. ' - ` 11/12/2016-Saturday Arrive on location. Fire equipment. Hold safety meeting. Discuss job procedures and review JSA. Pick injector head. Make up MHA consisting of all 1.75" OD tools as follows, CC, DFCV, HYD disco (1/2'ball) Stinger, Pulsonics nozzle. 8.3' tool Ienght. Stab on well. Start BOPE test.Test all rams and valves to 250/4,500psi. Draw down test completed. BOPE test finished. Passed. BOPE test report will be loaded to 0 drive. Online with 1% KCL. Circulate out 60/40 to meth holding tank. Close choke pressure up WH to 500psi. Open master and swab SSV Blocked and capped. Opsi whp, RIH after 1,200' WHP started increasing indicating fluid level close to surface. N2 cooled down primed. PT N2 lines to 250/7,500psi. NO leaks. Bleed down. 2,000' Online with N2 @ 350 scf/min Foam rate at .2 bbls/min. Crack choke and attempt to leave 50psi back pressure at 3,500' increase N2 rate to 800 scf/min at .2 bbls/min. Continue in hole and park at 5,500' wait for N2 to lift hydrostatic. N2 at surface. No luck at getting good atomization of Foam. Double the mixture from 1.36 gallons per 10 bbls to 2.5 gallons per 10 bbls. Pinch in block for better mix. WT check 7,500' clean. 9,500' wt check prior to exiting tubing tail 12,000 lbs clean. Continue IH at 1,200 scf/min and .8 bbls/min.take 100' bites and pick up 100'. Made it down to 10,600'. Looks like after pick up we are snubbing more when attempting to RIH. Could be building sand dunes. Chase fluid OOH to tubing tail at 60 ft/min. Drop spped to 35 ft/min in 7" casing interval of 250'.Attempt to RIH from 9,500' Stacking weight. Pick up another 200'. Looks like well is getting to dry with N2 creating friction. Drop N2 rate to 350psi add FR to fluid increase fluid rate to 1.1 bbls/min.While circluaiting FR to nozzle continue OOH to 9,000'. 4 bbls of FR turn corner.Start RIH. Broke friction. Returns milky no indcation of foam. 30%solids in return sample. fine formation sands. Continue in hole. Made it to 9,590' and sweeping welded 90 on tank washed out. Closed choke. POOH to surface. Report incident to MP front desk, MP wellsite supervisor, and MP enviro. swap to 60/40 to freeze protect reel. 35 bbls pumped.Tagged up at surface. Bull head 5 bbls of 60/40 into well for freeze protect. Well secure. Stack back inj.40 bbls of 60/40 used. 210 bbls of 1% KCL used. During job tank straps indicated we had 1:1. Location secure. Crews off location. • . Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP MP 1-12 A #1 50-029-23038-00-00 201-163 11/4/16 11/14/16 OatyOperation ', - °' do 11/13/2016 Sunday ' Fire equipment. Hold safety meeting. 2x tanks were delilvered previous night. Inspect tanks and plumbing. Pick injector. BHA all 1.75" OD . CC, DFCV, HYD DISCO, weight bar, Pulsonics nozzle. Stab on well. Fluid pack to return tank. Close choke. PT stack to 250/4,SOOpsi. Bleed down to 1,000psi. Open master swab. 994psi initial WHP. migrating N2 created WHP. Bleed down to zeropsi. RIH. Foam online fluid pump .5 bbls/min N2 450 scf/min. 4,692' increase N2 rate to 800 scf/min. Good N2 and fluid returns hold 150psi back pressure. Continue RIH. weight check 7,076' , Pump schedule while FCO is 10 bbls foam, 10 bbls gel and FR alternating to save on foam usage. Contiue in hole . @ 10,207' -6k rih wt. Start dropping N2 rate for less metal friction 1.1 bbls/min and 600 scf/min. Back to deepest depth from pevious day 10,600'. Pick up hole 100' . CIH 10,955' pick up 10,600' wiper trip. 15%solids in returns WHP still 180-200psi . CIH, 11,525' snubbing weight-18k. Drop N2 rate to 600 scf/min pump rate 1.1 bbls min. Circ pressure 4,682psi. mixing FR in each batch of pump schedule. POOH to tubing tail 11,593' locking up. Gel sweep at nozzle. pump bottoms up. chase up to tubing tail. Contiue washing to tubing tail slow down to 30 ft/min at 7" casing. @ tubing tail gel at nozzle chase up hole to 9,916'. slow down to 20 ft/min at 9,350'- 9,310'. Continue chasing fluid OOH. Shut down N2 while POOH at 4,800'. swap to 60/40 for 35 bbls. tagged up at surface. Master swab close. Blow down stack. Pop off well. Break down nozzle. install 1.75" od knuckle swivel and SR BO42 sleeve shifting tool. Stab on well. Fluid pack. Pt stack 250/4,500psi. Bleed down. Open master swab. 320psi tubing pressure. RIH. RIH 100' per min. Slow down to 50' pm at GLM stacked 5k at GLM. Pick up .Attempt to pass by pumping down ct with choke closed. No luck. Pump down CTxtubing annuli at 2 bbls/min no luck injection pressure 450-463psi. POOH to surface. master swab closed. Break down and remove knuckle . stab on well. Pt stack 250/4,SOOpsi. Coil crew rigging up IA pump line for sleeve test in AM. Stack weight at 2,347'. 1,200 lbs down. Push to-5k and tool pops through.TIH, stacked wieght at XD sliding sleeve 9,353', 1,600 lbs down and weight pop back. IA dropped from 360psi to zero. Pick up 50' above GLM.TIH, slight bobble again at 9,353'. Pooh to surface. 4 bbls of 60/40 bullheaded in well. POOH.Tagged up master swab closed. Blow down stack. pop off well. Stack back injector head. Install night cap.SDFN. • ! Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP MP 1-12 AS .1 ,t.50-029-23038-00-00 201-163 11/4/16 11/14/16 Daily Operations: .70 11/14/2016- Monday Pick inj. 20' lubricator. Hold safety meeting. Discuss job procedure, making up tools. Pull test coil connector 2,5000 lbs. Make up MHA and jars and disconnect. PT 250/3,500psi. Good test. Bleed down. Make up the rest of BHa incluidng sidi hip tripper x over to sucker rod and Weatherford 7C jet pump. BHA as follows. CC 2.25"ODx 1.38'. DFCV 2.13" OD x 1.38', G Force Jars 2.13" OD x 5.84',TJ disonnect 5/8" ball x 1.57', accelerator 2.13" OD x 4.52', Si-Di Hipp-Tripper 2.13" OD x 4,52', Ported x over 2.0" OD x .66' x line setting tool and jet pump 7.12' 7C Nozzles.total bha length 22.91'. Low pt 250/high 4,500psi good test . Pump down IA. Returns to surface at 1 bbl/min Pump pressure 120psi. 70psi IA pressure. Normal flow rate of power fluid is 750 BOPD. or .53 bbls/min. NO indication that sleeve is partially closed. Close choke. freeze protect IA line with 60/40 meth. RIH. wt check 5,000' 8k lbs. wt check 9,291', 13,500 lbs. RIH at 40 ft/min while pupming .5 bbls/min. Stall hip tripper Pick up to 13k weight with out moving JP. Cotinue attempting to set jet pump with hip tripper.Trying to find sweet spot. Attempt over pull to see if mandrel closed and dogs are engaged. No over pull indicated ct weight 16. Continue with attempting to see hip tripper working.Trying different rates from .3, .5, .7, 1.1 bbls/'min. Only time we saw hip tripper working at surface was at .3-.5 bbls/min. Attempt 5 jar licks down. Only time jar lick were seen would be when we come off a hip tripper stall nad wait for pressure to bleed down and jars would fire. 3 attempts to snumb down 30k. No over pull throughout job. Decided to POOH to surface to check shear pins and overall condition of jet pump.Tagged up. Close master swab.Trolly back .Jet pump not on setting tool. Looks to be set. Previous IA test with sleeve open was at .56 bbls/min. 75psi seen on pump pressure. Returns up tubing to choke and return tank. Good indication sleeve fully open. Line up down IA with jet pump jet. come online with .56 bbls/min pressure increasing on IA and returns at open top tank. IA pressure 2,500psi. Good indication pump is set. Pinch in choke to simulate header pressure 250psi on choke.Jet pump is set Circulate 5 bbls of freeze protect down back side. Bull head 3 bbls of 60/40 down tubing. Night cap installed on BOPE . RDMO CTU. 11/15/2016-Tuesday No activity to report. V of rit, • • • gwP\1//7,'s. THE STATE Alaska Oil and Gas �, of Conservation Commission r•-1) --- ..,,, AIJAS��:A } ii 333 West Seventh Avenue l.1sr!- C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 w� ' Main: 907.279.1433 of ALA *P Fax: 907.276.7542 www.aogcc.alaska.gov n�i3 Bo York `r'' t.'�`> Operations Manager s ati Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB I-12 Permit to Drill Number: 201-163 Sundry Number: 316-573 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, Daniel T. Seamount, Jr. Commissioner DATED this b day of November, 2016. RBDMS (L- NOV 1 6 2016 RECEIVE . • STATE • OF ALASKA NOV 0 3 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGGC .,,z- 20 AAC 25.280 N 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑., " CT FCO❑✓ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Coil-Jet Pump Change CI 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ a 201-163 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23038-00-00 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 Q / MILNE PT UNIT SB 1-12 1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517 ' MILNE POINT/SCHRADER BLUFF OIL 1 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): 12,470' , 3,712' - - 12,470' • 3,712' 1,282 N/A N/A — Casing Length Size MD TVD Burst Collapse Conductor 108' 20" 108' 109' N/A N/A Surface 2,906' 10-3/4" 2,906' 2,408' 3,580psi 2,090psi Intermediate 10,228' 7" 10,228' 3,706' 7,240psi 5,410psi Liner"A" 2,457' 4-1/2" 12,393' 3,716' 8,430psi 7,500psi Liner"B" 2,232' 4-1/2" 12,396' 3,715' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic • See Attached Schematic 2-7/8" 6.5#/L-80/8rd 9,583 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑., Exploratory ❑ Stratigraphic❑ Development Q • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 11/9/2016 Commencing Operations: OIL ❑., . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A 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 Porhola Email sporhola@hilcorp.com Printed Name Bo York Title Operations Manager Signature / �,�. A KY Phone 777-8345 Date 11/3/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \L4 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ / NOV19 Spacing ExceptiopRequired? Yes ❑ No Subsequent Form Required: ` C.)'''''‘Y 0 l RBDMS LL NV 1 6 ?t7 f6 APPROVED BY /1 /f/// Approved by: 0-0/ LL COMMISSIONER THE COMMISSION Date: `/ Q` (� -PM I'1//7 Submit Form and Form 10-403 Revised 11/2015 pI a oalid for 12 nths from the date of approval. Attachments in Duplicate OrcibilNAl ,.` �� ,� 111"/'g S • Well Prognosis Well: MPU 1-12 Hilcarn Alaska,LI) Date:11/03/2016 Well Name: MPU 1-12 API Number: 50-029-23038-00 Current Status: SI Oil Well [ESPCP] Pad: I-Pad Estimated Start Date: November 9th, 2016 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-163 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) Current Bottom Hole Pressure: 1,682 psi @ 4,000'TVDss (Last BHP measured 12/19/2015) Maximum Expected BHP: 1,682 psi @ 4,000' TVDss (No new perfs added, EMW= 8.09 ppg) MPSP: 1,282 psi (0.10 psi/ft gas gradient) Brief Well Summary: MPU 1-12 was drilled in 2001 using Nabors 22E and completed as a multi-lateral in the Schrader Bluff OA and OB sands with an ESP pump. ESP changeouts took place in 2010 and 2014, the most recent was an ESP changeout in 2014 using Doyon #16 to replace the conventional ESP with a TTC-ESPCP (Thru-tubing conveyed electric submersible progressive cavity pump). In September 2015,the failed TTC-ESPCP was replaced using coil tubing. However, the new pump failed to work. A rig workover pulled the completion and ran an ESPCP pump in January 2016 but failed in June 2016 due to solids production. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 85.5° @ 8,110'). • Casing last tested to 250/2,000 psi for 5 min down to 6,014' on 11/29/2014. • Cleaned out fill from 9,855'to 12,045'with Doyon#16 in 2014. • ESPCP Pump failed in June 2016. Objective: SKThe purpose of this work/sundry is to perform a foam cleanout of the lateral and run a new Jet Pump (all after the well is recompleted using the ASR rig under sundry 316-528). Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. ✓7 a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. Notifyrs prior o esting . Vit, v�=� c. Submit 10-424 form within 5 days. 3. RIH w/2.00" coil w/2.0"to 2.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/- 12,395' MD(in OB lateral). POOH. a. This multi-lateral is a Baker Hughes Level 3 Hook Hanger with no Lateral Entry Modules (LEM)so selective entry into the OA lateral is not possible. b. Circulate out fill using 8.5 ppg 1% KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the liner. r • Well Prognosis Well: MPU 1-12 Hilcor)Alaska,LLI Date: 11/03/2016 c. Contingency: If unable to wash down with nozzle, RIH w/2.0" to 2.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/-12,395' MD(in OB lateral). POOH. 4. RIH w/2.00" coil w/2.0"to 2.5" max OD wash nozzle and extended reach cleanout BHA and cleanout to PBTD at+/- 12,395' MD(in OB lateral). POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. b. Contingency: If unable to wash down with nozzle, RIH w/2.0"to 2.5" mill and extended reach cleanout BHA and cleanout to PBTD at+/-12,395' MD(in OB lateral) using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen. POOH. 5. RIH and shift sliding sleeve open at+/-9,400' MD. 6. Pump 8.5 ppg 1% KCI or 8.4 ppg power fluid to confirm open. POOH. 7. RIH and set jet pump in sliding sleeve profile at+/-9,400' MD. 8. PU to 2,500' and freeze protect well. POOH w/coil. 9. RD Coiled Tubing and ancillary equipment. 10. Turn well over to production. Attachments: 1. Proposed Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen &Foam Flow Diagram • Milne • II • Well: Point MPU 1-12 Unit PROPOSED Last Completed: Proposed Ilileori Aluska,LLC PTD: 201-163 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm Orig.KB Elev.:63.4'/Orig.GL Elev.:34.7' 20" Conductor 92/H-40/Welded N/A Surf 108' RKB-Hanger:18.00'(ASR) 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 2,906' 7" Intermediate 26/L-80/Btc-Mod 6.151 Surface 10,228' 20,x+ .s 1 „ 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 9,936' 12,393' i' «' 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 10,164' 12,396' i" i ,* TUBING DETAIL pax 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.833 Surf 9,637' , LINER DETAIL a; '* 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 9,936' 9,980' 1 ,_+ 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 9,980' 12,393' n 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 10,164' 10,373' v �' �, 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 10,373' 12,396' 10-3/4"4 JEWELRY DETAIL : No Depth Item 1 2,500' GLM 2.875"x 1"KBMM GLM(Dummy Valve Set Proposed) 2 9,400' 3-1/2"XD Sliding Sleeve(88 Jet Pump installed Proposed) 3 9,410' 3-1/2"NDPG-C Single-drop Intake Gauge(2.958"ID) s 4 9,475' 3-1/2"X Profile(2.833"Packing Bore ID) 5 9,500' 7"x 3-1/2"Permanent Packer 6 9,600' 3-1/2"XN Profile(2.75"No-Go ID) 7 9,636' Wireline Entry Guide(Btm at 9,637) 8 9,627 Baker Hook Wall,Hanger above 7"Window 1 ) 9 9,642' Baker Hook Wall,Hanger below 7"Window 10 9,650' Baker Tension Lock Swivel 11 9,906' Baker Tie Back Sleeve 12 9,928' Baker ZXP Liner Top Packer 13 9,930' Baker 7"x 5"HMC Liner Hanger 14 10,116' Btm 4-1/2"Pack-off Bushing e 15 10,128' Btm 4-1/2"Guide Shoe 16 10,147' Btm Baker Pack-off Bushing Q 17 12,395' Btm Baker 4-1/2"Guide Shoe I �' tv 1 �� LATERAL WINDOW DETAIL ,'1 � 2 �� Top of"OA"Window @ 9,916'MD;Bottom @ 9,928'MD;Angle @ top of window is 80 deg A: a i Top of"OB"Window @ 10,228'MD;Bottom @ 10,240'MD;Angle @ top of window is 87 deg 3 WELL INCLINATION DETAIL a KOP @ 300'MD "; fir 4 Max Wellbore Angle=85.5 deg @ 8,102'MD 63.74 deg @ 2,550'MD i' 7 IF i .$ OPEN HOLE CEMENT DETAIL e 20" Cmt w/650 sx of Arcticset I in 30"Hole ' 10-3/4' Cmt w/585 sx AS Lite,502 sx Class"G"in 13-1/2"Hole ''. 7" Cmt w/1,172 sx Class"G"in 9-7/8"Hole 04 6 { WELLHEAD ,� ' IWellhead FMC Tubing Hanger,11"x 4-1/2"TC-II Top&Bottom '' (1.(71"'*"$ GENERAL WELL INFO 10 14 API:50-029-23038 00 00 !^!'° Drilled and Cased by Nabors 4ES-12/08/2001 "OA"Lateral 15 ESP Completion by Nabors 4ES-12/15/2001 12 11 Convert to ESPCP by Nabors 4ES-6/30/2010 13 Convert to TTC-ESPCP by Doyon 16-12/05/2014 16 Convert to ESPCP by ASR 1-1/17/2016 I "06't�eg 17 7" TD=12,470'(MD)/TD=3,712'(TVD) PBTD=12,470'(MD)/PBTD=3,712'(TVD) Downhole Revised:Proposed Revised By:STP 8/31/2016 • Mine Point Unit . 1111 COIL BOPE MPU I-12 ,.p.idn.,.m,LLC 11/03/2016 itis MPU I-12 20x10% x7x3''A Coil Tubing BOP To injection head i I 2.00"Double Stripper i1 4i Lubricator 1 o 1 -4 1/16 15 — .. 1'1 1.IaIi Blind �_ Blind IMI'J ...111.0017. MilkMOBIIIII AIMa � M 0® is •',I■ Slip �= = Slip .I.1II.(1 iii imIIIII.4 J Iii. Pipe 111111 _ Pipe 111111 1411=1 Crossover spool 4 1/16 15M X 4 1/16 10M 11 1o1 1o1 Crossover spool 1 4 1/16 10M X 4 1/16 5M 1 1 embilf. Pump-In SubRP • �� o � o 4 1/16 5M }• i.{ • I I 1502 Union 1rz1 z Crossover spool 1 1 Manual Gate Manual Gate 4 1/16 SM X 3 1/8 5M 1 1o1 2 1/8 5M 2 1/8 5M f 1 Valve,Swab,WKM-M, u� 3 1/8 5M FE .* \L��' IA •'4'SO F III — �a\1e,31\2 . ■ Valve,Upper Master,Baker, 3 1/8 5M FE,w/Hydraulic Valve,Lower Master,WKM-M, L " 3 1/8 5M FE "• 111111ail Tubing Adapter,3 1/8 5M 1111 • STANDARD WELL PROCEDURE Ilileorp.n1a4ka. NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 0 • D011 lil S DM • : •• :::::"..... •• • 7 0 0 ', 11 .8.,-3-••••o2<u_ occ i=,2,,, ,0Lcu, ,,0-.5-.; 1D.i ,rt, L- — :..:.:....,..••: •: '.. '5S"..IT>IIo X7co ,oJ Z4,e o. • . O. .. 0 0 O. •CI > 0) :.•.1 7 2 t.) bt '1;2 C 1:19 09 a2 —** , • • t., ,_, 7't = .., = 2 0 0' .. in Z i•••• ,_ u., > c. ca (-) a, •"" = .:,•• cl• •O• c.) •G.T. C.J '4 . - 1— 1— _ O z 1 i 1 c m r 4. .4 _. ., ."3 ,' .•,4 li 0 1; --00*{>T4-IXX1— ii 41111i; ;, ; .•.. 104. 0114 1.111.11 Z Al. i V LA g -Patticitoi— ".: 1 i<5'2 :1° • • • • 0 . . . . o ....t... ...,„4,...,.. 11111 II 1111 1111 i.-- . i''.-"'''Ilrr'7•""f"1, L'i* -'' ' 14441,014 -mmoidi 111 i 4) lli-E14000,Viii." '1:,,IPtiro'7414411°, MI)ill! III lin , 1 „,..., . I' litrii { i N Z O 1 < 0 0 0 8. W 0 0 Ce L.r. ._ V Ill Z 01' cc ce LY LY 1—• 2 g5 21+1 Z < 2— O ell.' Fe g Da- LO —i COW 00 Tr ... , II OF Tit, • evio I/7:4. THE STATE Alaska Oil and Gas N ;IN 'a� ALASKA Conservation Commissiontt } x 333 West Seventh Avenue ^ti GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 `• Main: 907.279.1433 OF ALAS.0* Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager scANNED MAR 0 22017 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB I-12 Permit to Drill Number: 201-163 Sundry Number: 316-528 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, 2V- /0.a:R. tr_fix_______ Cathy . Foerster Chair DATED this day of October, 2016. RBDMS ,L- OCT 2 4 2016 STATE OF ALASKA 0 Ci 1 4 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations p Fracture Stimulate ❑ Repair Well p Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other Convert to Jet Pump El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Hilcorp Alaska LLC t Exploratory 0 Development 0, 201-163 3.Address: Stratigraphic ❑ Service ❑ 6.API Number 3800 Centerpoint Dr,Suite 1400 50-029-23038-00-00 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 0 No Q I MILNE PT UNIT SB 1-12 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517 ' 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): ' 12,470' • 3,712' . 12,470' • 3,712' 1,282 N/A N(A Casing Length Size MD TVD Burst Collapse Conductor 108' 20" 108' 109' N/A N/A Surface 2,906' 10-3/4" 2,906' 2,408' 3,580psi 2,090psi Intermediate 10,228' 7" 10,228' 3,706' 7,240psi 5,410psi Liner"A" 2,457' 4-1/2" 12,393' 3,716' 8,430psi 7,500psi Liner"B" 2,232' 4-1/2" 12,396' 3,715' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(it): See Attached Schematic I See Attached Schematic 2-7/8" 6.5#/L-80/8rd 9,583 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ay N/A 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 Q. Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/26/2016 ❑ Suspended 0 Commencing Operations: OIL Q . WINJ 0 WDSPL 16.Verbal Approval: Date: N/A GAS ❑ WAG 0 GSTOR El SPLUG 0 Commission Representative: N/A GINJ 0 Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved 1 herein will not be deviated from without prior written approval. Contact Stan Pothole Email sporhola(cthilcorp.com Printed Name "/,/� Bo York Title Operations Manager Signature 'rte/ Phone 777-8345 Date 10/12/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\L-625s- Plug Integrity ❑ BOP Test Mechanical Integrity Test 0 Location Clearance 0 Other: Q Z, v.,,.. 1 -i:: T--ST -ac 102-41t. Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No El Subsequent Form Required: k° -'404 RBDNIS LC OCT 2 4 2016 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:IQ 1"� ?►i3 T J ti �� _ __ w,` SubmitlForm and Form 10-403 Revised 11/2015 ORIGIIINAv6 for 12 months from the date fapproval. `v, Attachments in Duplicate A(eitt((( �fzo , • • Well Prognosis Well• MPU I-12 Ililcora Alaska,I.LI Date:10/12/2016 Well Name: MPU 1-12 API Number: 50-029-23038-00 Current Status: SI Oil Well [ESPCP] Pad: I-Pad Estimated Start Date: October 26th, 2016 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-163 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) Current Bottom Hole Pressure: 1,682 psi @ 4,000' TVDss (Last BHP measured 12/19/2015) Maximum Expected BHP: 1,682 psi @ 4,000' TVDss (No new perfs added, EMW= 8.09 ppg) / MPSP: 1,282 psi (0.10 psi/ft gas gradient) Brief Well Summary: MPU 1-12 was drilled in 2001 using Nabors 22E and completed as a multi-lateral in the Schrader Bluff OA and OB sands with an ESP pump. ESP changeouts took place in 2010 and 2014, the most recent was an ESP changeout in 2014 using Doyon #16 to replace the conventional ESP with a TTC-ESPCP (Thru-tubing conveyed electric submersible progressive cavity pump). In September 2015, the failed TTC-ESPCP was replaced using coil tubing. However, the new pump failed to work. A rig workover pulled the completion and ran an ESPCP pump in January 2016 but failed in June 2016 due to solids production. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 85.5° @ 8,110'). • Casing last tested to 250/2,000 psi for 5 min down to 6,014' on 11/29/2014. • Cleaned out fill from 9,855' to 12,045' with Doyon #16 in 2014. • ESPCP Pump failed in June 2016. Objective: Pull failed ESPCP (failed June 2016), and convert the well to a 3-1/2"Jet Pump completion. Brief RWO Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing, taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. • ! Well Prognosis Well: MPU I-12 Hileorp Alaska,LLQ Date: 10/12/2016 WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg sea water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/2,500 psi High, annular to 250 psi Low/ 1,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-7/8" and 3-1/2" test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg sea wate, as needed. 15. MU landing joint or spear and recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 16. POOH and lay down the 2-7/8" tubing. Salvage the entire tubing string for cleaning and inspection. 17. Lay down failed ESPCP. Collect samples of any solids and test for scale. 18. RIH with 7" 26#scraper assembly to 9,627' MD (Hook Wall) on 3-1/2" tubing. Circulate the well clean. 19. If needed, spot sized salt pill to control losses. POOH and LD tubing. 20. PU 3-1/2"jet pump completion and RIH on 3-1/2" tubing. Set tubing tail at±9,637' MD (inside upper hook wall hanger). 21. Land tubing hanger. RILDS. Note PU (Pick Up) and SO (Slack Off)weights on tally. 22. Drop setting ball. Pressure up tubing to 3,000 psi to set packer. Hold pressure and test tubing for 10 min and chart. Bleed down to 1,000 psi. • • Well Prognosis Well: MPU 1-12 Hileorn Alaska,LLQ Date: 10/12/2016 23. Pressure test annulus to 2,500 psi for 30 min and chart. Bleed annulus to 0 psi. Bleed tubing to 0 psi. 24. Lay down landing joint. 25. Set BPV. 26. Rig down ASR#1. Post-Rig Procedure: 27. RD mud boat. RD BOPE house. Move to next well location. 28. RU crane. ND BOPE. 29. NU new 3-1/8" 5,000#tree/adapter flange. Pull BPV. Set TWC. Test tree to 500 psi low/5,000 psi high. Test tubing hanger void to 500 psi low/5,000 psi high. Pull TWC. 30. RD crane. Move 500 bbl returns tank and rig mats to next well location. 31. Replace gauge(s) if removed. 32. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Proposed Tree/Wellhead 5. FWD Circ to Kill Tank Flow Diagram 6. REV Circ to Kill Tank Flow Diagram 7. Bleed to Pits Flow Diagram 8. Blank RWO MOC Form • Milne Point Unit Well: MPU 1-12 • int SCHEMATIC Last Completed: 1/17/2016 ftileorp Alaska,LLC PTD: 201-163 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm RKB Elev 64.7' 20" Conductor 92/H-40/Welded N/A Surf 108' 10-3/4" Surface 45.5/L-80/BTC 9.794 Surf 2,906' 7" Intermediate 26/L-80/BTC-Mod 6.151 Surface 10,228' 20 4 a ' 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 9,936' 12,393' 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 10,164' 12,396' 1 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 9,583' LINER DETAIL 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 9,936' 9,980' 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 9,980' 12,393' 2 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 10,164' 10,373' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 10,373' 12,396' 10-3/4"-A JEWELRY DETAIL No Depth Item 1 202' GLM 2.875"x 1"KBMM GLM(Dummy Valve Set 1/17/16) 2 2,490' GLM 2.875"x 1"KBMM GLM(Shear Valve 2,000 psi Set 1/17/16) 3 9,521' WellLift Discharge Gauge Unit 4 9,525' Centrilift ESP:PCP 200D2600 and Flex Shaft Assembly 5 9,556' Tandem Seal Section 6 9,570' Gear Reduction Unit 7 9,571' Motor MSP1 60 HP 8 9,580' WeIILift MGU w 6 fin Centralizer-Bottom @ 9,583' 9 9,627' Baker Hook Wall,Hanger above 7"Window 10 9,642' Baker Hook Wall,Hanger below 7"Window 11 9,650' Baker Tension Lock Swivel 12 9,906' Baker Tie Back Sleeve 13 9,928' Baker ZXP Liner Top Packer 14 9,930' Baker 7"x 5"HMC Liner Hanger 15 10,116' Btm 4-1/2"Pack-off Bushing 16 10,128' Btm 4-1/2"Guide Shoe 17 10,147' Btm Baker Pack-off Bushing 18 12,395' Btm Baker 4-1/2"Guide Shoe $ 1 LATERAL WINDOW DETAIL Top of"OA"Window @ 9,916'MD;Bottom @ 9,928'MD;Angle @ top of window is 80 deg Top of"OB"Window @ 10,228'MD;Bottom @ 10,240'MD;Angle @ top of window is 87 deg WELL INCLINATION DETAIL KOP @ 300'MD I 3 Max Wellbore Angle=85.5 deg @ 8,102'MD 4 63.74 deg @ 2,550'MD 5 OPEN HOLE/CEMENT DETAIL 1 20" Cmt w/650 sx of Arcticset I in 30"Hole 6 10-3/4" Cmt w/585 sx AS Lite,502 sx Class"G"in 13-1/2"Hole 7" Cmt w/1,172 sx Class"G"in 9-7/8"Hole 7 WELLHEAD a.(](�11A 8 Wellhead I FMC Tubing Hanger,11"x 4-1/2"TC-II Top&Bottom 9 GENERAL WELL INFO 10 11 15 API:50-029-23038-00-00 :rs.,• Drilled and Cased by Nabors 4ES-12/08/2001 "OA'Lateral 16 ESP Completion by Nabors 4ES-12/15/2001 13 127 Convert to ESPCP by Nabors 4ES-6/30/2010 Convert to TTC-ESPCP by Doyon 16-12/05/2014 /K...., 17 Convert to ESPCP by ASR 1-1/17/2016 A 18 7 OB"Lateral TD=12,470'(MD)/TD=3,712'(TVD) PBTD=12,470'(MD)/PBTD=3,712'(TVD) Revised By:STP 8/31/2016 IIIMilne Point Unit Well: MPU 1-12 14 • PROPOSED Last Completed: Proposed Harp Alaska,LLC PTD: 201-163 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm Orig.KB Elev.:63.4'/Orig.GL Elev.:34.7' 20" Conductor 92/H-40/Welded N/A Surf 108' RKB-Hanger:18.00'(ASR) 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 2,906' E ,. ) , - - 7" Intermediate 26/L-80/Btc-Mod 6.151 Surface 10,228' 20' + . ( p, 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 9,936' 12,393' ', " 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 10,164' 12,396' TUBING DETAIL 041 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.833 Surf 9,637' . 4 LINER DETAIL 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 9,936' 9,980' 1 4-1/2" 0A Slotted Lnr 12.6/L-80/IBT 3.833 9,980' 12,393' I 1 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 10,164' 10,373' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 10,373' 12,396' 10-3/4" JEWELRY DETAIL No Depth Item 1 2,500' GLM 2.875"x 1"KBMM GLM(Dummy Valve Set Proposed) 2 9,400' 3-1/2"XD Sliding Sleeve(8B Jet Pump installed Proposed) 3 9,410' 3-1/2"NDPG-C Single-drop Intake Gauge(2.958"ID) 4 9,475' 3-1/2"X Profile(2.833"Packing Bore ID) 5 9,500' 7"x 3-1/2"Permanent Packer 6 9,600' 3-1/2"XN Profile(2.75"No-Go ID) 7 9,636' Wireline Entry Guide(Btm at 9,637') 8 9,627' Baker Hook Wall,Hanger above 7"Window 9 9,642' Baker Hook Wall,Hanger below 7"Window 10 9,650' Baker Tension Lock Swivel 11 9,906' Baker Tie Back Sleeve 12 9,928' Baker ZXP Liner Top Packer 13 9,930' Baker 7"x 5"HMC Liner Hanger 14 10,116' Btm 4-1/2"Pack-off Bushing 15 10,128' Btm 4-1/2"Guide Shoe 16 10,147' Btm Baker Pack-off Bushing 17 12,395' Btm Baker 4-1/2"Guide Shoe LATERAL WINDOW DETAIL s 6 2 Top of"OA"Window @ 9,916'MD;Bottom @ 9,928'MD;Angle @ top of window is 80 deg - Top of"OB"Window @ 10,228'MD;Bottom @ 10,240'MD;Angle @ top of window is 87 deg w S ' WELL INCLINATION DETAIL KOP @ 300'MD r Max Wellbore Angle=85.5 deg @ 8,102'MD 63.74 deg @ 2,550'MD r. :i iii '„ a OPEN HOLE/CEMENT DETAIL "" 20" Cmt w/650 sx of Arcticset I in 30"Hole 11 10-3/4" Cmt w/585 sx AS Lite,502 sx Class"G"in 13-1/2"Hole b+ 7" Cmt w/1,172 sx Class"G"in 9-7/8"Hole wI$ ', WELLHEAD , a Wellhead FMC Tubing Hanger,11"x 4-1/2"TC-II Top&Bottom 41 '.,,' i j7 8 GENERAL WELL INFO 1 1014 API:50-029-23038-00-00 t & " Drilled and Cased by Nabors 4ES-12/08/2001 % "OA'Lateral 15 ESP Completion by Nabors 4ES-12/15/2001 12 11 Convert to ESPCP by Nabors 4ES-6/30/2010 13 Convert to TTC-ESPCP by Doyon 16-12/05/2014 16 Convert to ESPCP by ASR 1-1/17/2016 I d\s„..... '06'WWI 17 7 TD=12,470'(MD)/TD=3,712'(TVD) PBTD=12,470'(MD)/PBTD=3,712'(TVD) Downhole Revised:Proposed Revised By:STP 8/31/2016 • II Milne Point ASR Rig 1 BOPS Raw?41•460„rad: 11" BOPE Stripping Head i riv 3.98' 1r i ' p Shaffer 4 1.1"_ 5000 91i Iii di lit iii UUP nd CI -U raLai 4.54 I _� / ® , �= VBR or Pipe Rams � PIIr .�(MO � 11"V5000 11-nu10 _ ©a Blind ,[11 main fai 21/16 5M Kill Line Valves 21/16 5M Choke Line Valves 4.1 el a • ° �' € ') _ I'i�I-i�ir` I-i� 2.00' ai , c „ 0 � o) C H I iE i� 1 w Manual Manual Manual HCR Updated 8/19/2015 11 • ! MPU I-12 PROPOSED TREE/WELLHEAD Wellhd/T Hile rp 1a ka..U.i c Milne PointeaUnit VO ' 3 1/8" CIW 5M Swab Valve o o o 0s. e. 1 }. iy tlt\ / o @V" ,d N. III ,,.,I II" •.. 3 1/8"CIW 5M Wing Valve ' 3 1/8" CIW 5M SSV with Baker actuator IR 'tit B It I MI ILI C p ' ' �., 3 1/8" CIW 5M Master Valve co +4 ' IRI _. 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I've attached the proposed P&IDs for MPI-12 and the I-pad water injection header. Please note the alarm settings for the annular flow meter and pressure transmitter will likely be updated once piping is operational and under steady state conditions. Thank You. Wyatt Rivard I Well Integrity Engineer D: (907) 777-8547 I C: (509)670-8001 (wrivard@hilcorp.com SCANNED JUN 2 1 2016 3800 Centerpoint Drive,Suite 1400 j Anchorage,AK 99503 IIt1=•nrir 41444, 1 1 {. From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, May 06, 2016 10:37 AM To: Wyatt Rivard Subject: RE: Milne Point ESP Annular Water Circulation Wyatt, The AOGCC has appoved this in the past. I don't see any reason why not to again based on the low rates you are proposing. Could you forward a simple piping diagram for our files. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent: Wednesday, May 04, 2016 10:26 AM To: Schwartz, Guy L(DOA) Subject: Milne Point ESP Annular Water Circulation Hello Guy, • • Milne Point well MPI-12 (PTD#201163) is a Schrader Bluff packerless ESPCP producer with a history of production problems due to viscous oil and solids plugging the pump. Prior to conversion from an ESP to an ESPCP in 2010,the well benefited from the circulation of produced water down the inner annulus. Circulating water increases pump efficiency by heating the wellbore fluids and adding fluid volume. Recently,the well was again shut-in for low BHP and solids inflow problems. A backside flush was performed and a temporary, manned,water line was installed to allow roughly 70 bwpd to be slipstreamed down the IA.The well has responded positively to the water circulation, producing at roughly 230 bpfd with consistent BHP. Moving forward, Hilcorp is planning to reinstall a permanent tie-in for water circulation through the IA as needed.The hardline tie-in would include metering and an automated valve to shut-in water circulation in the event the well's SVS is tripped.There are no velocity or erosion concerns at the low circulation rates planned. In March of 2002 BP contacted the AOGCC with a request for approval to circulate water in MPI-12 and two other Milne Point wells, a scan of the emails from the well file is attached.The determination at that time appeared to be that,while unusual,the annular water circulation would not require additional permitting or approvals. Since this is a nonstandard well configuration for a packerless ESP, Hilcorp would like to confirm that no additional AOGCC approval is required for MPI-12 or future packerless ESPs at Milne Point that could benefit from this type of annular water circulation. Please give me a call if you would like to discuss this in more detail or have any questions. Thank You, Wyatt Rivard ; vVell Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivardPhilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 2 • • Cu I U 1 Cu I 6 n n ��yyO- 8 811 SOb 111 alig ; 1 Z s-I, sem$ =1- o s 0 � ,N .. W 81..!!: Er- a - lig "--- Wri wig WW ai Oil ! o oz jr. m 1 C:21 i 4 k lgt I5ry 5_ ME $.]g a n cu �NiF dori d 1 1 i 1a i 1 J .2 * 14_ 0%-@-13 a- Q~ 0o- m � >n I ii d MI, i 1 ,C)? ! . tea I $t e$ A 5 a + IFl E .41 �� !his i — LE , b. i . .. ♦ 461titt 1 L I J • `- '--- i 4 1---allgiE - I Y �A El ;; Gs • - ig i'i /4, � II � $gii} �E — 'N:F –fl 11 � g II st 14 . ,.., ..! ,.Bi !. NI @p r--- 3 ®14 ,---- yisErrap s >PO-p 1 > .i. , ca • NE--e--1-- -Ek-'J-1-9"-- cr- - Kro-ffli ,r Es &I mom la -i!! 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IA,5AMBMdN sn 4 414 , i 1,, h lk gi i 10 r"' 1 rh t ilE i 8 Y Z Y8' kit te '1 - 4 `��' - 0---L 4-1.0=, L 1, PI 11---y g 19 21I ! ! 5 .-;.,i R1 41 ® 1.3 Il t i < s g a_ v } I 0 t 1 Q i STATE OF ALASKA AKA OIL AND GAS CONSERVATION CON.SSION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon [J Plug Perforations u Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well Q Re-enter Susp Well❑ Other: Esp Changeout 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development ❑, Exploratory❑ 201-163 3.Address: Stratigraphic❑ Service❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23038-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: �y, ADL0025517 MILNE PT UNIT SB 1-12 RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): FEB 1 0 2016 N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: AOGCC Total Depth measured 12,470 feet Plugs measured N/A feet true vertical 3,712 feet Junk measured N/A feet Effective Depth measured 12,470 feet Packer measured N/A feet true vertical 3,712 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 108' 20" 108' 108' N/A N/A Surface 2,906' 10-3/4" 2,906' 2,408' 3,580psi 2,090psi Intermediate 10,228' 7" 10,228' 3,706' 7,240psi 5,410psi Liner"A" 2,457' 4-1/2" 12,393' 3,716' 8,430psi 7,500psi Liner"B" 2,232' 4-1/2" 12,396' 3,715' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic SCOW jvi True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/8rd 9,583' 3,586' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A 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 0 140 0 Subsequent to operation: 230 20 36 260 220 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑., Exploratory Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas U WDSPL Li 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: 315-464 F Contact Stan Porhola Email sporhola(a,hilcorp.com Printed Name Bo York Title Operations Manager Signature .yam "" - iat.` , irj.-' Phone 777-8345 Date 2/10/2016 3_ _/69 , 14 Form 10-404 Revised 5/2015 Submit Original Only RBDMS w FF9 1 1 2016 • • Milne Point Unit Well: MPU 1-12 SCHEMATIC Last Completed: 1/17/2016 nilcorp Alaska,LLC PTD: 201-163 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm RKB Elev=64.7' 20" Conductor 92/H-40/Welded N/A Surf 108' 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 2,906' tj t I 7" Intermediate 26/L-80/Btc-Mod 6.151 Surface 10,228' 20 A' o 0 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 9,936' 12,393' 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 10,164' 12,396' 1 ;t TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 9,583' LINER DETAIL + 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 9,936' 9,980' 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 9,980' 12,393' 2 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 10,164' 10,373' a 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 10,373' 12,396' 10-3/4"> r JEWELRY DETAIL No Depth Item 1 202' GLM 2.875"x 1"KBMM GLM(Dummy Valve Set 1/17/16) 2 2,490' GLM 2.875"x 1"KBMM GLM(Shear Valve 2,000 psi Set 1/17/16) 3 9,521' WeIILift Discharge Gauge Unit 4 9,525' Centrilift ESP:PCP 200D2600 and Flex Shaft Assembly 5 9,556' Tandem Seal Section 6 9,570' Gear Reduction Unit 7 9,571' Motor MSP1 60 HP 8 9,580' WeIILift MGU w 6 fin Centralizer-Bottom @ 9,583' 9 9,627' Baker Hook Wall,Hanger above 7"Window 10 9,642' Baker Hook Wall,Hanger below 7"Window 11 9,650' Baker Tension Lock Swivel 12 9,906' Baker Tie Back Sleeve 13 9,928' Baker ZXP Liner Top Packer 14 9,930' Baker 7"x 5"HMC Liner Hanger 15 10,116' Btm 4-1/2"Pack-off Bushing 16 10,128' Btm 4-1/2"Guide Shoe 17 10,147' Btm Baker Pack-off Bushing 18 12,395' Btm Baker 4-1/2"Guide Shoe LATERAL WINDOW DETAIL Top of"OA"Window @ 9,916'MD;Bottom @ 9,928'MD;Angle @ top of window is 80 deg ' Top of"OB"Window @ 10,228'MD;Bottom @ 10,240'MD;Angle @ top of window is 87 deg WELL INCLINATION DETAIL KOP@300'MD 3 Max Wellbore Angle=85.5 deg @ 8,102'MD b 4 63.74 deg @ 2,550'MD E OPEN HOLE/CEMENT DETAIL 20" Cmt w/650 sx of Arcticset I in 30"Hole 1 7 10-4/4" Cmt w/585 sx AS Lite,502 sx Class"G"in 13-1/2"Hole 7" Cmt w/1,172 sx Class"G"in 9-7/8"Hole • WELLHEAD 4 9 Wellhead FMC Tubing Hanger,11"x 4-1/2"TC-II Top&Bottom 10 GENERAL WELL INFO ., ; 1 +11 12 16 API:50-029-23038-00-00 f" Drilled and Cased by Nabors 4ES-12/08/2001 E13"OA"Lateral 17 ESP Completion by Nabors 4ES-12/15/2001 ' 14� Convert to ESPCP by Nabors 4ES-6/30/2010 15 Convert to TTC-ESPCP by Doyon 16-12/05/2014 18 Convert to ESPCP by ASR 1-1/17/2016 J Tr Laoll 19 NOTES: 7" Need Cementing Report to Establish Tops TD=12,470'(MD)/TD=3,712'(1VD) PBTD=12,470'(MD)/PBTD=3,712'(TVD) Need Casing&Tubing Tallies Revised By:STP 1/19/2016 • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP1-12 ASR#1 / 50-029-23038-00-00 201-163 1/8/16 1/17/16 Daily Operations: 1/6/2015-Wednesday No activity to report. 1/7/2015 -Thursday No activity to report. 1/8/2015 - Friday Review Well Plan. Well Support rigging up hard lines and 500 bbl return tank on well 1-12. Cummins Mechanic (Allen Lawson) working on Truck Mounted Rig Motor. Peak dispatch was called for 400 bbls of 120 degree sea water. On location at 23:00 hrs for well kill. Little Red Services will be on Location at 00:00 Hrs. Matting boards are placed around well. Rig crew loading and hauling rig equipment to location. Little Red Service kill well with seawater. Circulated through GLM mandrel @ 2,485' to flow back tank. Closed tbg in. Rigged up on IA. Bullhead 380 bbl down back side. 1/9/2015-Saturday Monitor wellbore. Backside &tubing.Tubing flowing crude back. Flow back to open flow back tank. Continue moving ASR Equipment to I Pad. Rig up Little Red Services. Circulate additional 90 bbls down tubing taking returns to flow back tank. Monitor well. Both sides were 0 pressure. Install BPV. Nipple down production tree. Inspect lifting threads on hanger. Inspect lock down screws. Safety meeting with ASR Rig crews and review upcoming 1-12 RWO. Roads and Pads crane operator assisted in nipple up Bop Stack. Spot well house, mud boat. Back rig over well. Raise Derrick. Center over well. Roads and Pads hauled pit module. 1/10/2015 -Sunday Roads and Pads hauled change house to MP 1-12. Continue torquing up flanges on BOP stack. Install X-box and power tongs on rig floor. Rigging up hydraulic hoses to BOP stack and Koomy Unit. Pumping and thawing running and wrapping glycol lines around hydraulic lines. Continue rigging up. Set up pipe racks. Hang ESP cable sheave in Derrick.Well head Rep (Dean Norris ) pull BPV and install TWC in well head for testing.AOGCC Jeff Jones on location to witness BOP test. Little Red Services to assist in testing BOP and chart test. LRS had 60/40 glycol fluid on truck.ASR Rig has 8.5 PPG Sea water in pits. Jeff Jones addressed that these two types of fluids are not acceptable for testing BOP.Test fluids are not addressed in Application for Sundry Approvals. Fresh water will be used for testing. Peak trucks are dispatched to off load sea water in pits and to haul in fresh water for testing. Hang up tarp on the inside of well house on Derrick side. Cold air coming in freezing up BOP Stack. Conduct testing with ASR test pump. Checking for leaks and drips on connections on test pump. 250 Low/4,000 High testing on Choke Manifold valves. Relocate test chart recorder due to too much vibration while charting test. Adjust belts on test pump motor. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP 1-12 ASR#1 50-029-23038-00-00 201-163 1/8/16 1/17/16 Daily Operations: 1/11/2015 - Monday Continue winterizing Rig. Test BOPs as per AOGCC requirements. Test all Rams and Valves to 250psi Low pressure and 3,000psi High pressure.Test H2S & Methane gas alarms.Test was witnessed by AOGCC,Jeff Jones. Had to switch to Little Red Services halfway through testing operations due to test pump failure. Rig down BOP Test equipment. Wellhead Rep (Dean Norris) pull TWC. Rigged up return line from IA to flow back tank. Closed blind rams. Pump 80 bbl down tbg with a pump rate of 4 BPM @ 290psi. Got returns to tank with 13 bbl pumped. Shut down pump with 80 bbl pumped away. Blow line down. Make up landing joint &TIW valve. RIH screw into Tbg Hanger. BOLDS. Pull Tbg Hanger to rig floor @ 60k free pull @ 67k. Break down lay down hanger and landing joint.Trip out of the hole with 3-1/2 Tbg and ESP cable to 2,485 ft. Total joints pulled (74). Pumping double displacement cleaning oil from tbg and cable as being pulled. ESP cable was cut and strapped to Tbg. Picked up Tbg Hanger and made up. Ran back into the hole and landed. RILDS. 1/12/2015-Tuesday Waiting on Halliburton Wireline to arrive on location. Circulate 65 bbls down Tubing @ 3 BPM at 700 psi. Wait on Wireline. Held PJSM. Rig up Halliburton Wireline with Lubricator and Pressure control.Test Lubricator to 250/1500 psi. RIH with Perf Tools as follows: 3 Weight bars, Decentralizing magnet, 2" OD Tbg punch with 4 SPF, Decentralizing magnet. Locate Tbg Collar at 3,050 ft. Pull up 15 ft to 3.035 ft. Shoot holes in Tbg. Pooh with Wireline. Break out Lubricator. Stand off to the side of the Rig Floor. Break out pup joints in hanger. Close Pipe Rams. Conduct injection rate test through Punch Holes in Tbg with a total 20 bbl pumped away. Pump rate of 3 bpm @ 220 Psi. Taking returns to Flow Back Tank. Blow down return line. Continue rigging down Halliburton Wireline. Lubricator off Rig Floor. Make up landing joint. Pull hanger to Rig Floor @ 52k. Continue tripping out of the hole 3-1/2"Tbg and ESP Cable. Pumping double displacement cleaning oil from Tbg and Cable.Total joints pulled to punch joint (93 ).Total joints pulled and laid down from well (167). ESP cable was cut and strapped to Tbg. Picked up Tbg Hanger and made up. Ran back into the hole and landed. RILDS. D/N=21K P/U=33K. Held PJSM. Rig up Halliburton Wireline with Lubricator and Pressure control.Test Lubricator to 250/1500 psi. RIH, locate collar and punch holes in tubing at 2,845'. Pull out of the hole. • • fif Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP1-12 ASR#1 50-029-23038-00-00 201-163 1/8/16 1/17/16 Daily Operations: 1/13/2015 -Wednesday Lay down Tubing Hanger.TOOH with 3.5"Tubing& ESP cable to 2.700'. Change out ESP spools in Spooling unit. Continue to POOH to top of TTC-ESPCP. PJSM. Rig down Halliburton Wireline. PJSM. Rig up Halliburton Slickline. Pull TTC-ESPCP. Recovered all pieces. Rig down Halliburton. Continue to POOH laying down ESP housing assembly. Clear and clean rig floor insde well house walls, BOP stack. Hoisted BHA to rig floor and steam connections.Torque and make up BHA.Trip in the hole with 7" casing scraper, boot baskets on 3-1/2" tubing to 4,600'. 1/14/2015 -Thursday Service Rig. Check fluids in generators. Continue to TIH with BHA. Bit, 2 Boot Baskets, 7" Casing scraper and 2-4.75" DCs on 3.5" tubing to 9,627'. Rig up & reverse circulate 1 tubing volume 3.5 BPM 450 psi. Monitor wellbore. Prepare to TOOH with 3.5" tubing. TOOH laying down 3.5"Tubing. Pumping Double Displacement. Break down lay down 2-Boot Baskets 7" Casing Scraper& Bit. Boot baskets are Empty. Clear and Clean Rig floor. Change out Rig floor handling Equipment back to 2- 7/8". Load 2-7/8"Tbg on Pipe Racks. 1/15/2015- Friday Service Rig. Check all fluids. Load ESP Assy on racks. Load & strap 2 7/8" Completion Tubing.;Make up &service ESP ASSY and continue loading and tallying 2 7/8" Completion Tubing.;Trip in the hole with ESP Assy and 2 7/8" Tubing to check cable continuity each 1,200 ft. Reel to reel ESP Cable Splice on joint#92, depth 2,933 ft. Fill hole 9 bbls. Continue tripping in the hole from 2,933 ft to 6,513 ft. Check cable continuity every 1,200 ft. (Note ESP Cable Splice is on the btm of joint#99). Fill hole 5 bbls at 5,361 ft. 1/16/2015 -Saturday Continue to TIH with ESP Assy on 2-7/8"Tubing. Checking cable continuity every 1200'. Run 303 joints total.;Pick up anding joint. Make up Tubing Hanger and install Penetrators.;Make up Connector to ESP cable and install on hanger. Install final clamps. Meg test cable. P/U 42K, S/O 5K. (Total 303 joints of 2-7/8 6.5# EUE tbg ran, 267 cross collar clamps, 2 mid joint clamps, 3 protectolizers, 2 flat guards ).;Land Tubing Hanger. Run in lock down screws. Close annular and test Hanger to 500 psi for 5 min. Lay down landing joint. Blow down lines. Install BPV.;Electrician disconnected alarm system on rig. Nipple down BOP stack to four bolts. Remove ESP Sheave from Derrick. Load out Pipe Racks on Flat Bed Truck. Remove 2-7/8" handling equipment from Rig Floor and Power Tongs. Roads and Pads unload 220 bbls unused seawater from Active System. Hauled over to ORT. Rig down Pit Module. Rig up Generater to Change house and Company Man Shack.;Removed X-Box and Stairs from Rig Floor. Lower Derrick. Move Rig and Pit Module. Mud Boat to A-Pad. Remove Well House. Nipple Down BOP. Nipple up Production Tree. 1/17/2015 -Sunday Nipple up Tree. Test Hanger void to 5000 psi. Pull BPV. Install TWC. Test Tree to 250 psi 5000 psi. Freeze Protect well with 30 bbl of 60/40 methanol down annulus with Little Red Pumping Services.;RDMO. Continue moving Rig equipment to MP A-Pad. Remove Herculite and Matting boards. Clean location.;Continue moving misc Rig equipment to MP A-Pad. Spot units and install shore power to units. Move change house and Company Man Trailer to A-Pad. Spot and set up. Move well house, matting boards. Heater to MPE-21 Warm up BOP Stack. 1/18/2015- Monday No activity to report. 1/19/2015 -Tuesday ,,®F r� • • yw\.,1//7�:sv THE STATE Alaska Oil and Gas ��Z�� of LASK A. Conservation Commission rte- ?® _ 'itri.t_ 333 West Seventh Avenue = :--= ' �*h,,, I� GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 1Main: 907.279.1433 OFALA`14 ' Fax: 907.276.7542 www.aogcc.alaska.gov Bo York a + ';'Q FEB 0 3 n16 Area Operations Manager201 -,,- -1 ° Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB I-12 Sundry Number: 315-764 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, ' 164 7e-- ._. Cathy P. Foerster Chair �{�-- DATED this 3o day of December, 2015 Encl. RBDMS.tDEC 312015 • • RECEIVED • STATE OF ALASKA DEC 2 3 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION 2o-S 12130 I is APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0. Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC . Exploratory ❑ Development 0. 201-163 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23038-00-00 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 0 ✓ MILNE PT UNIT SB 1-12 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0025517, 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): 12,470' . 3,712' -• 12,470' . 3,712' 1,282 ' N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 108' 20" 108' 109' N/A N/A Surface 2,906' 10-3/4" 2,906' 2,408' 3,580psi 2,090p si Intermediate 10,228' 7" 10,228' 3,706' 7,240psi 5,410psi Liner"A" 2,457' 4-1/2" 12,393' 3,716' 8,430psi 7,500psi Liner"B" 2,232' 4-1/2" 12,396' 3,715' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attached Schematic. See Attached Schematic 3-1/2" 9.3#/L-80/8RD 9,582 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0. Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 1/8/2016 Commencing Operations: OIL 0. WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A 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 Porhola Email sporhola a(�hilcorp.com Printed Name (` Bo York Title Operations Manager Signature 4 �-(�t) Yd f k Phone 777-8345 Date 12/23/2015 COMMISSION USE ONLY Condition f approval: Notify Commission so that a representative may witness Sundry Number. 3(5'762q Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance ❑ Other: '--71-9,5-f--- Post ' 3cx�f�p s� Lop / 9-sem Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ©/ Subsequent Form Required: 1b '.. 1°fI APPROVED BY Approved by: �7�1)t 47 4, 12_2.3..1,5 COMMISSIONER THE COMMISSION /914 RI l Z - 3o - 5_ I1a�f l� , (2/ �� (.jRicotiSubmit Form and Form 10-403 Revised'1/2015 i nA v lid for 12 months from the date of approval. Attachments in Duplicate RBDMgu JEC 3 12015 • Well Prognosis Well: MPU 1-12 !carp Alaska, Date: 12/22/2015 Well Name: MPU 1-12 API Number: 50-029-23038-00 Current Status: SI Oil Well [TTC-ESPCP] Pad: I-P Estimated Start Date: January 8th, 2016 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-163 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: 1650013 Current Bottom Hole Pressure: 1,682 psi @ 4,000' TVD (BHP 12/19/2015/8.09 ppg EMW) Maximum Expected BHP: 1,682 psi @ 4,000' TVD (No new perfs being added) ✓ MPSP: 1,282 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU 1-12 was drilled in 2001 using Nabors 22E and completed as a multi-lateral in the Schrader Bluff OA and OB sands with an ESP pump. ESP changeouts took place in 2010 and 2014, the most recent was an ESP changeout in 2014 using Doyon #16 to replace the conventional ESP with a TTC-ESPCP (Thru-tubing conveyed electric submersible progressive cavity pump). In September 2015, the failed TTC-ESPCP was replaced using coil tubing. However,the new pump failed to work. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 85.5° @ 8,110'). • Casing last tested to 250/2,000 psi for 5 min down to 6,014' on 11/29/2014-, • Cleaned out fill from 9,855'to 12,045' with Doyon #16 in 2014. • TTC-ESPCP Pump failed in September 2015. L.,/ 3V " 46 Objective: The purpose of this work is to pull the existing failed TTC-ESPCP and run a new conventional ESPCP. Brief Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services and 500 bbl returns tank with choke manifold. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.5 ppg sea water down tubing,taking returns up casing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services. 8. Set BPV. RU crane. ND Tree. NU 11" BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. • • . firWell Prognosis . Well: MPU I-12 IIilcorn Alaska,LL) Date: 12/22/2015 WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/8.5 ppg seawater prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8" and 3-1/2" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure cre5 c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor �l the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking xgi anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment - and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/8.5 ppg seawater as needed. 15. If able to circulate well, mix and pump caustic soda pill (-5 lb/bbl) ahead of Baraklean pill (^'4 gal/bbl)to clean oil of tubulars. Displace with 8.5 ppg seawater. I �4 16. MU 4-1/2" landing joint (TC-II) and BOLDS. '1 s,L.: lb. 17. Pull over string weight on tubing hanger to confirm free (est. 109 klbs). LD tubing hanger. a. Contingency: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 18. POOH to +/- 100' MD to TTC-ESPCP. Lay 3-1/2" tubing on the pipe rack. a. Look for over-torqued connections from previous Doyon#16 tubing runs. y,/ 19. MU 3" GS pulling tool and recover tubing stop. V::} 20. MU 3" GS pulling tool and recover packoff. 21. MU 3" GS pulling tool and recover TTC-ESPCP (33.2' long). a. Tubing stop, packoff, and TTC-ESPCP all have 3" GS fishing neck. b. Utilize 2.75" ID dog collar to recover TTC-ESPCP from inside 3-1/2" tubing. 1/1 • • Well Prognosis Well: MPU 1-12 HIilcarp Alaska,LI) Date: 12J22J2015 22. Contingency: (If pipe is pulling wet and unable to circulate while pulling TTC-ESPCP). a. Land tubing hanger. RILDS (Run in lock-down screws). Lay down landing joint. b. MIRU Slickline and PCE (Press Control Equip) PT lubricator to 1,500 psi Hi 250 Low. i. Install 11" x 7-1/16" adapter on top of annular for lubricator connection. ‘�Y.r. • RIH w/equalizing tool and run thru KOBE adapter below packoff. ri i. Min ID is 1.50" thru tubing stop. d. Contingency: (If still unable to equalize). MU tubing punch and punch above TTC-ESPCP. e. RIH w/GS pulling tool and recover tubing stop (1.56' long). f. RIH w/GS pulling tool and recover packoff(8.22' long). g. RD Slickline and PCE. h. MU landing joint. BOLDS (Back-out lock-down screws). Lay down tubing hanger. i. Continue to POOH to+/- 100' MD to TTC-ESPCP. j. MU 3" GS pulling tool and recover TTC-ESPCP (33.2' long). 23. Continue to POOH and lay down TTC receiver, seals,gear reduction unit and motor. a. Inspect TTC-ESPCP components and redress to place back into inventory as needed. I, 24. MU 6" or 6-1/8" mill/bit and casing scraper for 7" 26#casing. (-G'C 25. RIH with 3-1/2"tubing and scrape casing down to+/-9,627' MD. Forward or reverse circulate well clean with 8.5 ppg sea water. 26. POOH. Lay 3-1/2"tubing on the pipe rack. LD mill/bit and casing scraper. a. Store used 3-1/2" tubing at Milne. Send out 10%for inspection. No recent caliper available. 27. PU new 375 series ESPCP and RIH with new 2-7/8" 8RD EUE L-80 tubing. a. Run Upper GLM @ ±200' w/valve. b. Run lower GLM @ ±2,500' w/valve. 28. Set base of ESP at+/-9,575' MD. 29. Land tubing hanger. RILDS. Close annular and test tubing hanger to 500 psi for 5 minutes. 30. Lay down landing joint. a. Note PU (Pick Up) and SO (Slack Off)weights on tally. 31. Set BPV. 32. RD Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. 2. RU crane. ND BOPE. Pull BPV. Set TWC. 3. NU new 2-9/16" 5,000#tree and adapter flange and test to 500 psi low/5,000 psi high. 4. Test tubing hanger void to 500 psi low/5,000 psi high. 5. Pull TWC. RD crane. 6. Move 500 bbl returns tank and rig mats. 7. Replace IA x OA pressure gauge if removed (7" x 10-3/4"). 8. Turn well over to production. RU well house and flowlines. Attachments: . fir • • Well Prognosis Well: MPU 1-12 Ililcorp Alaska.LL Date: 12/22/2015 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic 5. Existing Tree/Wellhead 6. FWD Circ to Kill Tank Flow Diagram 7. REV Circ to Kill Tank Flow Diagram 8. Bleed to Pits Flow Diagram 9. Blank RWO Changes Form • 11 • � Milne Point Unit Well: MPU 1-12 SCHEMATIC Last Completed: 12/5/2014 Hilcorp Alaska,LLC PTD: 201-163 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm RKB Elev=64.7' 20" Conductor 92/H-40/Welded N/A Surf 108' 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 2,906' 9 ( i 7" Intermediate 26/L-80/Btc-Mod 6.151 Surface 10,228' 20' 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 9,936' 12,393' 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 10,164' 12,396' 1 TUBING DETAIL I : 3.5 Tubing 9.3/L-80/EUE 8rd 2.867 Surf 9,582' LINER DETAIL 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 9,936' 9,980' y 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 9,980' 12,393' 2 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 10,164' 10,373' (" 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 10,373' 12,396' 10-3/4"N �< JEWELRY DETAIL No Depth Item 1 201' GLM 3.5"x 1"Camco KBMG w/Orifice Valve&BK Latch 2 2,485' GLM 3.5"x 1"Camco KBMG w/Open/Empty Pocket 3 9,493' 3.5"Well Lift Discharge Gauge Unit 4 9,510' TTC-ESPCP(Stop/Packoff/Pump) 5 9,550' TTC Receiving Assembly 6 9,555' Tandem Seal Section 7 9,570' Motor 562MSP1,84hp,2,210 v/23 amp 8 9,579' Well lift MGU Gauge 9 9,581' Centralizer-Bottom @ 9,582' 10 9,627' Baker Hook Wall,Hanger above 7"Window 11 9,642' Baker Hook Wall,Hanger below 7"Window lr 3 12 9,650' Baker Tension Lock Swivel we 4 13 9,906' Baker Tie Back Sleeve 14 9,928' Baker ZXP Liner Top Packer 15 9,930' Baker 7"x 5"HMC Liner Hanger 16 10,116' Btm 4-1/2"Pack-off Bushing tip 17 10,128' Btm 4-1/2"Guide Shoe i .e 18 10,147' Btm Baker Pack-off Bushing / 19 12,395' Btm Baker 4-1/2"Guide Shoe '\ 'C/ Illi LATERAL WINDOW DETAIL 6 Top of"OA"Window @ 9,916'MD;Bottom @ 9,928'MD;Angle @ top of window is 8odeg Top of"OB"Window @ 10,228'MD;Bottom @ 10,240'MD;Angle @ top of window is 87 deg WELL INCLINATION DETAIL 7 KOP @ 300'MD $ Max Wellbore Angle=85.5 deg @ 8,102'MD 9 63.74 deg @ 2,550'MD OPEN HOLE/CEMENT DETAIL 20" Cmt w/650 sx of Arcticset I in 30"Hole 10-4/4" Cmt w/585 sx AS Lite,502 sx Class"G"in 13-1/2"Hole 7" Cmt w/1,172 sx Class"G"in 9-7/8"Hole , WELLHEAD 10 Wellhead FMC Tubing Hanger,11"x 4-1/2"TC-Il Top&Bottom ` 11 12 16 GENERAL WELL INFO "OA"Lateral 17 API:50-029-23038-00-00 13 Drilled and Cased by Nabors 4-ES -12/8/2001 14 /K..... 15 18 NOTES: 4 Need Cementing Report to Establish Tops Leteral 19 Need Casing&Tubing Tallies 7" TD=12,470'(MD)/TD=3,712'(TVD) PBTD=12,470'(MD)/PBTD=3,712'(TVD) Revised By:TDF 12/17/2015 iii . Milne Point Unit Well: MPU 1-12 PROPOSED SCHEMATIC Last Completed: Proposed Ililcorp Alaska,LLC PTD: 201-163 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm RKB Elev=64.7' 20" Conductor 92/H-40/Welded N/A Surf 108' 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 2,906' A201i7" Intermediate 26/1-80/Btc-Mod 6.151 Surface 10,228' 20 ' 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 9,936' 12,393' l''4 c: Liner"B" 12.6/L-80/IBT 3.833 10,164' 12,396' 1 e TUBING DETAIL 2.875 Tubing 6.5/L-80/EUE 8rd 2.441 Surf 9,575' r ir LINER DETAIL !, 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 9,936' 9,980' 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 9,980' 12,393' 2 i, 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 10,164' 10,373' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 10,373' 12,396' 10-3/4"4 JEWELRY DETAIL No Depth Item 1 ±200' GLM 2.875"x 1"KBMM GLM 2 ±2,500' GLM 2.875"x 1"KBMM GLM 3 ±9,500' WellLift Discharge Gauge Unit 4 ±9,505' Centrilift ESP:PCP 5 ±9,535' Flex Shaft Assembly EUE 8rd Box 6 ±9,540' Single Seal Section 7 ±9,545' Gear Reduction Unit 8 ±9,550' Motor MSP1 9 ±9,570' WeIILift MGU w 6fin Centralizer-Bottom @ 9,575' 10 9,627' Baker Hook Wall,Hanger above 7"Window 11 9,642' Baker Hook Wall,Hanger below 7"Window 12 9,650' Baker Tension Lock Swivel 13 9,906' Baker Tie Back Sleeve 14 9,928' Baker ZXP Liner Top Packer 15 9,930' Baker 7"x 5"HMC Liner Hanger 16 10,116' Btm 4-1/2"Pack-off Bushing 17 10,128' Btm 4-1/2"Guide Shoe 18 10,147' Btm Baker Pack-off Bushing 19 12,395' Btm Baker 4-1/2"Guide Shoe Fi, s4 LATERAL WINDOW DETAIL Top of"OA"Window @ 9,916'MD;Bottom @ 9,928'MD;Angle @ top of window is 80 deg "fir Top of"OB"Window @ 10,228'MD;Bottom @ 10,240'MD;Angle @ top of window is 87 deg Y" i e WELL INCLINATION DETAIL 3 C�� 0 KOP@300'MD y: 4 G'/ k Max Wellbore Angle=85.5 deg @ 8,102'MD MD4, I '�/ 63.74 deg @ 2,550'MD at II OPEN HOLE/CEMENT DETAIL 20" Cmt w/650 sx of Arcticset I in 30"Hole 10-4/4" Cmt w/585 sx AS Lite,502 sx Class"G"in 13-1/2"Hole G 7" Cmt w/1,172 sx Class"G"in 9-7/8"Hole • WELLHEAD 10 Wellhead FMC Tubing Hanger,11"x 4-1/2"TC-II Top&Bottom # 11 12 16 L J GENERAL WELL INFO "OA"Lateral 17 API:50-029-23038-00-00 14 M 1311,!15. - Drilled and Cased by Nabors 4-ES 12/8/2001 18vs 19 NOTES: Need Cementing Report to Establish Tops ` "Oe'Wind 7" \ Need Casing&Tubing Tallies TD=12,470'(MD)/TD=3,712'(11/D) PBTD=12,470'(MD)/PBTD=3,712'(TVD) Revised By:STP 12/18/2015 • Milne Point 2015 ASR Rig 1 rf;4..,,�, t1:,.►.,.t.tr: Knight Oil Tools BOP Stripping Head ti\\ mimow IIPIPI N. ° Shaffer ' 11" - 5000 It 111 1 4 ' I lIl [Iilllli IJI 1 iii [iii is 27/8" —5" VBR ,.. iffEloon :� `■`■ 11"+-�® 000 Mme` Blind 2" Kill Line 111111111111111111, 1 2" Choke Line tens fin III 111111111 Lii r441)._ 111 .T A ,I,.1 11,,,}1 6 — — — — cic. ii-' (:-.6;,,,,,,, ri_JI ----- il1 ; N , I E1 Manual Manual Manual HCR Updated 11/03/15 • • Choke Manifold ASR#1 11/01/2015 Digital Reverse line back to Kill Manifold Pressure Readout . f Pt C2 ' I. C3 1 II Digital Pressure Transmitter �� I - . From Choke Line Manual Choketp 11 " B ,,l til -... Remote A a Choke C4 C5 C6 C7 eighamov 11 I, ; fir ail III I#r 111 1r , 4111 II] asion ,Iti _ 1�t. 1i1 C9 =110 t All Valves 211 Piper Series PB Ball Valves 6,170 psi Working 10,000 psi Tested C8-0 - C11 -(:) I C � ` C13 C15 10 : L)1:111.. .0 I 4141 O , i ' O III III C12 ow O C14 -O. C16 Olit 1 asle, To Panic Line 1502 Union Outside End CappedIli To Gas Buster • • • H EXISTING TREE/WELLHEAD MPU I-12 Wellhead/Tree Hilerorp Alaska.LLC Milne Point Unit 4"Otis tree cap MPI-12 (P1\:Siiic Ja\ie `4 Q1`O5 o f i 4 1/16 CIW 5M Wing Q`0)o L Valve �!11 1 SS a 1'\,6'�0 a a O Nov AI NI 4 1/16 CIW 5M t-. . - HWO master valve IIL 1!i lMl a1`16 c s:1\ 50i-aaac 11 IN iii 11"5MX11"5M "s mu Attachment Spool 1� I 1 " I ...-ti 2 1/16 3M HWO 13 5/8 3M X 115M FMC Gen 1p1 _ 1.1 valve 5 tubing spool I �� i I . -1,1q. . 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C-- a a 1 tr,2_, ri _ = 23 f.. • • a) £ 3 6 = c \ / 2a) .o0 a) .> Eo � m0 E � > J2 E• 7 U - 0 O 0 > E / $ �ct. � � f ?� - « a \ / 0 7 / � 2 �f e e a. — 0.k.% « CO• .C° ■ a) � � \ a CI CI O 0 f 0.03 F c0 a / .- e % %... ke a) .0 / k co O & _ 0 A/ k a » \ 100CIS RQ = E) L. % < Q � E § t k g• -k ) O e c 2 i 2 = .. a_ ._ / / g a) »> 0 a) O 7 / . 7 8p c W CD § 73 0 7. / o si kG 2 «Ci‘ floiLe o O 0_ x 2 r c Q ■ x 2 * a R (a 7 2 = al 0 .g o 2 � 0 / � « E § .. / g 0 2 V E O A \ k 2 o a 0 Cl) C \ / < / 0 < U) STATE OF ALASKA AIL OIL AND GAS CONSERVATION COIABSION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations ❑ Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 3rforate New Pool El Repair Well 0 Re-enter Susp Well ❑ Other: TTC-Esp Changeout 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: iti f c..-rt, Hilcorp Alaska LLC Development 0 Exploratory ❑ 201-163 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23038-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025517 MILNE PT UNIT SB 1-12 RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL DEC 2 3 2015 11.Present Well Condition Summary: OGCC Total Depth measured 12,470 feet Plugs measured N/A feet true vertical 3,712 feet Junk measured N/A feet Effective Depth measured 12,470 feet Packer measured N/A feet true vertical 3,712 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Conductor 108' 20" 108' 108' N/A N/A Surface 2,906' 10-3/4" 2,906' 2,408' 3,580psi 2,090psi Intermediate 10,228' 7" 10,228' 3,706' 7,240psi 5,410psi Liner"A" 2,457' 4-1/2" 12,393' 3,716' 8,430psi 7,500psi Liner"B" 2,232' 4-1/2" 12,396' 3,715' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80/8rd 9,582' 3,586' Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A 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 %ANNE t,,/,',A, _ J 2 ',, ,I, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 240 216 Subsequent to operation: 0 0 0 220 223 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas U WDSPL U 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: 315-464 Contact Stan Porhola Email sporholat7a hilcorp.com Printed Name Bo York Title Operations Manager Signature -•' 7f Phone 777-8345 Date 12/17/2015 / /..-c—iteRBDMSi4EC 282015 Form 10-404 Revised 5/2015 ,%r'`� (7.9--:‘ Submit Original Only • • Milne Point Unit Well: MPU 1-12 • SCHEMATIC Last Completed: 12/5/2014 Hilcorp Alaska,LLC PTD: 201-163 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm RKB Elev 64.7' 20" Conductor 92/H-40/Welded N/A Surf 108' 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 2,906' 7" Intermediate 26/L-80/Btc-Mod 6.151 Surface 10,228' 20'S 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 9,936' 12,393' 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 10,164' 12,396' 1 TUBING DETAIL 3.5 Tubing 9.3/L-80/EUE 8rd 2.867 Surf 9,582' LINER DETAIL 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 9,936' 9,980' 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 9,980' 12,393' 2 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 10,164' 10,373' N 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 10,373' 12,396' 103/4",A l JEWELRY DETAIL No Depth Item 1 201' GLM 3.5"x 1"Camco KBMG w/Orifice Valve&BK Latch 2 2,485' GLM 3.5"x 1"Camco KBMG w/Open/Empty Pocket 3 9,493' 3.5"Well Lift Discharge Gauge Unit 4 9,510' TTC-ESPCP(Stop/Packoff/Pump) 5 9,550' TTC Receiving Assembly 6 9,555' Tandem Seal Section 7 9,570' Motor 562MSP1,84hp,2,210 v/23 amp 8 9,579' Well lift MGU Gauge 9 9,581' Centralizer-Bottom @ 9,582' 10 9,627' Baker Hook Wall,Hanger above 7"Window 11 9,642' Baker Hook Wall,Hanger below 7"Window k. 3 12 9,650' Baker Tension Lock Swivel 4 13 9,906' Baker Tie Back Sleeve el b 14 9,928' Baker ZXP Liner Top Packer 15 9,930' Baker 7"x 5"HMC Liner Hanger ..,---- rA � 16 10,116' Btm 4-1/2"Pack-off Bushing �)(V' 17 10,128' Btm 4-1/2"Guide Shoe 5 18 10,147' Btm Baker Pack-off Bushing 19 12,395' Btm Baker 4-1/2"Guide Shoe dr: t LATERAL WINDOW DETAIL 6 Top of"OA"Window @ 9,916'MD;Bottom @ 9,928'MD;Angle @ top of window is 80deg Top of"OB"Window @ 10,228'MD;Bottom @ 10,240'MD;Angle @ top of window is 87 deg WELL INCLINATION DETAIL KOP@300'MD 8 Max Wellbore Angle=85.5 deg @ 8,102'MD , 9 ,> 63.74 deg @ 2,550'MD OPEN HOLE/CEMENT DETAIL It it 20" Cmt w/650 sx of Arcticset I in 30"Hole to lo 10-4/4" Cmt w/585 sx AS Lite,502 sx Class"G"in 13-1/2"Hole * 7" Cmt w/1,172 sx Class"G"in 9-7/8"Hole i el WELLHEAD 910 Wellhead FMC Tubing Hanger,11"x 4-1/2"TC-II Top&Bottom +11 12 16 GENERAL WELL INFO 1 "OA"Lateral 17 API:50-029-23038-00-00 14 13 Drilled and Cased by Nabors 4-ES -12/8/2001 !MD 18 NOTES: Need Cementing Report to Establish Tops 19 Need Casing&Tubing Tallies 7" TD=12,470'(MD)/TD=3,712'(TVD) PBTD=12,470'(MD)/PBTD=3,712'(TVD) Revised By:TDF 12/17/2015 • • Hilcorp Alaska, LLC I- IikurpAlusku,LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP 1-12 201-163 50-029-23038-00-00 9/17/2015 9/30/2015 ion. t- ax 777 9/16/15-Wednesday rdN _ 11111111 = No operations to report. 9I P/15Thursday, i ' I° s ul�i�. Held PJSM, laid containment, MIRU Halliburton Coil Unit#1 and associated equipment.Set tanks connected hoses and hardline. SDFN Held PJSM. Finshed MIRU, MU/PU Injectorhead lubricator and BOP's. Performed full body test 250psi to 4,500psi,test BOPE as follows:Valves 250-4,500psi, Rams 250-4.500psi, Blinds 250-4,500psi. Function and drawdown test. No failures �. recorded. 24 hr notice was giving,AOGCC witness waived by Bob Noble. LD injector and lubricator. MU Night Cap and (- SDFN. 9/19/15'-Saturday ,'I' } 11 Held JSA. MU and tallied cleanout BHA. MU injector and riser to wellhead.Tested 250-4,500psi-test ok.Circulated 35 bbls of 60/40 out of the coil to freeze protect tank. Opened well, RIH 50 fpm. Kicked pump in @ 1 bpm.Started losing weight at 8,350',fighting friction, increased rate to 1.5 bpm.Worked coil down to 8,800'weight check every 100'. PU and short trip to 8,250'. Bottoms up was oil/PW no solids. RIH and tagged top of pump @ 9,900'ctm. Parked coil and washed TOP, circulated bottoms up. Returns clean. POOH,SI well. Flushed riser and lines with 10bbls of hot clean fluid. Circulated 35bbls of 60/40 freeze protection.SD pump and blow lines down with air. RD riser and injector, MU night cap changed out the injector head rubber,secured well and SDFN. € 15- tifida U i I III j I II I III� _ €gym '� �I ii II IG. ;wt�i�D4� Held PJSM and discussed daily operations. PU/MU the fishing BHA as follows: Ext Connector,Check Valve,Jar, Disconnect, XO,GS Pulling Tool, Equalizing Prong. Pull tested connector to 20k. PU/MU Riser and Injector Head to the well head and tested 250-4,500psi-Test ok.Circulated 35bbls of freeze protect out of the coil to the 50bbl open top tank.SITP Opsi IA 400psi OA 190psi.Opened well and RIH tagged Tbg Stop at 9,498'ctm. PU 10'and Choked back well to maintain 500psi. Increased rate to 1.5 bpm.Washed back down to top of plug and knocked out the Equilizer Prong.Set down 20k on Tbg Stop and latched pulled 18k over to unseat. POOH. Flushed and blew down the Riser. Broke the Riser connection and LD the Tbg Stop and Prong. MU Riser and Injector.Test to 250-4,500psi. RIH w/GS Spear to 9,400'. PU weight check.Started pumping 1 bpm. RIH and tagged Packoff @ 9,500'ctm.Set down 20k and latched. PU 20k over and unseated Packoff. POOH.Circulated 60/40 freeze protect into coil. Flushed and blew down Riser. Broke Riser Connection and LD Packoff. LD Riser and Injector.SDFN. „4/;j:t 1 cinday i G i'i 8 Held PJSM and discussed daily operations. PU/MU the Fishing BHA as follows: Ext Connector,Check Valve,Jar, Disconnect, XO,GS Spear. PU/MU Riser and Injector Head to the well head and tested 250-4,500psi-Test ok. Circulated 35bbls of freeze protect out of the coil to the 50bbl open top tank.Opened Well and RIH to 9,500 started pumping 1.5 bpm, washed down and tagged TTC-ESP 9,510'CTM,SD pump. Pushed 20k over, repeated attempt. POOH Broke Riser Connection, LD Pump Section in cellar. MU Riser to wellhead and circulated freeze protection into coil. RD Riser and Injector head to free crane. LD Pump with crane. 9/ `- 'ue a Held PJSA. Off loaded new ESP and staged in cellar. Loaded exsiting ESP and sent back to Shop on A pad. MU BHA. CT connector,check valve,disconnect and venturi basket. PU/MU Riser and Injector to wellhead. Circulated freeze protection to 50 bbls holding tank.Tested 250-4,500psi-test ok.Opened well and RIH to 9,536'ctm, parked within 3'of the ESP receiver. Kicked pump on 1.25bpm caught fluid and pumped for 5 mins. PU 20'at minium speed RIH to 9,536' and parked for 5 mins.SD pump. POOH.Crew Changeout, Held PJSM dissuuss work to performed. Broke Riser connection L/D Venturi Basket recovered roughly 1/4 piece of a teflon seal. PU/MU Rotational Test Tool. MU Riser to wellhead and Tested 250-4,500psi-Test ok. RIH and tagged reciever @ 9,539',Set 10k down and PU to neutral weight, started downhole motor and waited 1 min,SD motor. POOH, Circulated freeze protection into coil. Broke Riser connection and1D_Rotatipnal Test Tool. Good test-Pin was sheared in tool. MU Riser to wellhead.Secured and SDFN. Night crane operator on duty. • • Hilcorp Alaska, LLC fr,t,,,rp.ska,LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP1-12 201-163 50-029-23038-00-00 9/17/2015 9/30/2015 , Nti 4U f ititieratlonsCA PId 9/23/15 y Wednesday = " '" Held PJSM.Lines valves to freeze protect tank,pumped 35bbls of seawater and returned 35bbls of 60/40 to freeze protect tank.Blow line dry.MU/PU Jars,GS spear and ESP.Connect Riser to tree and test to 250-4,500psi-Test ok.RIH to ESP receiver 9,521'ctm,set down neutral weight.Started pump 1.25bpm @ 3,400psi.PU 20'observed a decrease of 250psi circulating pressure,good indication GS released.SD pump.POOH,blew riser dry and broke connection.Pump gone.PU Packoff,MU Riser to wellhead.Tested 250- 4,500psi.Open well and RIH.Set down at 1,679'.Tried working down no luck tools set.POOH.Flushed and broke riser connection. Didn't recover Pack-off.Dressed GS in latched position.MU Riser connected and Tested 250-4,500psi-Test Ok.Opened well and RIH lightly tagged packoff @ 1,679'setdown to latch and packoff started giving up weight, pushed packoff down hole to top of ESP @ 9,510'ctm.Set 10k down on packoff and kicked pump on at 1.25 PU 10'observed a decrease of 250psi circulating pressure,good indication packoff set.Flushed and blew down riser,Broke riser connection to make sure Packoff was set in hole.MU connection and circulated freeze protection. SDFN. 924/3.5-�"��i`St�, h ' •� Held PJSM.Off loaded 150bbls of hot seawater in upright.Circulated 60/40 methanol to freeze protect tank.Flushed riser with 5 bbls of hot seawater and blew dry.Broke riser connection.PU/MU ported sub,3"JUC and Packoff Test Tool.MU Riser and tested 250- 4,500psi-test ok.Opened well and RIH,Tagged packoff and set down 5k over,Circulated 90 bbls of seawater,broke cir at 16bbls.With circulations clean SD Pump.Closed choke and pressured up to 250psi.Bled off in 4 mins.Set down 12k over and pressure back up to 250psi.Bled off 50psi/min with no leaks at surface.NO TEST.POOH,Broke connection LD test tool and JUC and ported sub.MU 3"GS Spear.Freeze protect coil. 9/25/15^Friday tlP 4"Il��r; V4ItlIIhV # ti T Held PJSM.Circulated 60/40 methanol to freeze protect tank.Test Riser 250-4,500psi-Test ok.Opened well and RIH w/GS Spear to 8,054'ctm.Parked Coil,SD OPERATION FIELD WIDE SAFETY STAND DOWN.Stand down lifted,Held JSA, continued RIH and tagged Packoff at 9,500'ctm,PU 10'and started pump at 1.25BPM.Established circulating pressure.RIH tagged Packoff and latched circulation pressure increased and packoff pulled free.SD Pump.POOH,SI well flushed and blew riser down.BO/LD Packoff,sent to shop for redress.BO/LD BHA and CT connecter.Cut off 100'of CT and MU new Ext C/C and pull tested to 20k.RU riser and prep for BOPE Test.Performed Weekly BOPE Test;Valve 250-4,500psi,Rams 250-4,500psi,Blinds 250-4,500psi.Function and Drawdown Test. No failures recorded.24 hr notice was giving,AOGCC didn't respond to notice.Instructed to proceed with test if no responce was given.Circulated 60/40 methanol into coil,secured well and SDFN. 9 /35-Sat€trdey*° Held PJSM.Circulated 60/40 Methanol to open top freeze protect tank,broke connection and MU BHA.Ext C/C,CV,Accelerator, Weigh Bar,Jars,Disconnect and GS Spear,MU Riser and Tested 250-4,500psi-Test Ok.Opened Well,RIH 30fpm stopped at 9,400'for weight ck,kick pump in @ 1.25bpm and established circulation pressure and opened Jars.SD Pump and RIH @ 75fpm Tagged Top of Pump @ 9,500'set down 20k over and waited 10mins.No Jar action.PU 2k over PU weight and opened jars.Set down 20k over for 15 mins.No Jar action.PU 5k over and packoff pulled free.PU 60'and RIH 80fpm set down 20k over.No Jar action.Kicked Pump in to 1.25bpm and released packoff.PU 60'and RIH at 125fpm and set down 20k.Repeated and held 20k down for held for 20mins.PU with no over pull stop and couldn't go down.PU 10'and could not go down.POOH,flushed and blew down Riser and RD,LD Packoff and sent to A pad for redress.MU BHA and Riser connection.Circulated free protection and SDFN. • • 9/27/15-Sunday °' y Held PJSM.Circulated 35bbls 60/40 metanol to open top tank,Broke riser connection and changed BHA,PU Hammer,GS spear and Packoff.MU riser and tested to 250-4,500psi-test ok.Opened well and RIH at 40fpm,set down at 4,330',PU 30'and RIH,couldn't work past 4,330'.POOH w/packoff slight over pull.Broke riser connection and LD packoff and BHA.GS tool had small amount of coil shaving in it.MU/PU Venturi Basket and RU riser.Tested 250-4,500psi and RIH at 60fpm pumping lbpm to 9,495'(5'above Pump)parked coil. Lined up valves and Bullhead 120bbbls of seawater down the backside at 3bpm to sweep coil annulus.Lined valve back to coil and pump 1.5bpm made three 20'passes while surging pump.SD Pump.POOH,Freeze Protected Coil,Broke connection and LD Venturi Basket.Removed pieces of rubber and coil shaving.MU Hammer and Packoff,RU Riser.Secured well and SDFN. 048/15-Mdndc y r 4 ,l;yo; , is i i ili�� i Held PJSM.Circulated 35bbls of 60/40 Methanol out of the coil to open top freeze protect tank,broke connection and MU BHA.Ext C/C,CV,Disconnect,Weight bar,Hammer, GS Spear and Packoff.MU Riser and Tested 250-4,500psi-Test Ok.Opened well and RIH 40fpm, stop at 9,450'PU for weight check.Rolled pump over at 1.25bpm and RIH at 5fpm.Tagged top of pump @ 9,510'.Set down on packoff with hammer 20k at.5fpm.PU to neutral weight and repeated. With returns at surface presured up on the backside to 250psi lost 4opsi in 5 mins,pressured up to 1,000psi and lost 70psi in 5mins.Bled off.Rolled pump over at 1.25bpm and and made several attemps to release off GS,POOH.Flushed and blew riser dry,Broke connection and LD Packoff and BHA,MU riser and circulated freezel� protection into coil.Secured well and SDFN. 9/29/IS-Tuesday''. "''Hu"Vi Hold safety meeting.2.125in Tools coil connector,check valves,Hydraulic disconnect,2 weight bars,x over,GS spear baited with DD pack off assembly. Crews RIH and Stack weight at 25 ft.Pick up and upon attempt of RIH kept stacking weight.Believed to have sheared pins on Top Pack off element.POOH.Break off and confirm sleeve shifted and sheared pin.Upon inspection noticed one shear(rubber/nylon)pin was used.Wellsite leader shift change.Dispactched BOT with Hip tripper.Obtained Slick line 3.5in GS spear pinned with .25 inch Brass shear pin.Brought DD pack off to A pad to have redressed.Installed one brass shear pin and 2 nylon shear pins.While redressing tools had CTU RIH to 4,000 ft with wash nozzle to confirm no obstructions. POOH to surface.BOT on location. Breaking down BHA and installing new BHA consisting of the following.EXT CC,DFCV,FA Disconnect,Hiptripper accel,Hipptripper, xover/drain sub,3in mechanical GS pinned with 1/4in brass.D&D pack off assembly.Stab on well.PT 250/4500 psi.Open well and RIH. Noticed 1,5001b weight stack at 25 ft.Weight broke back.Continue to RIH, @ 9300 ft 45 ft/min stacked 8k down.Pick up 11.5k clean, online down back side at 2 bbls min to clean sand/debris.Shut down pump and RIH from 9,200'.Made it past 9,300'without seeing weight stack.Parked coil at 9,400'.Online at 1 bbl/min down back side.Injection pressure 800psi.Shut down pump.Online down ct with Sea water at 1 bbl/min to catch fluid in coil.5 bbls pumped. down on pump.Perform weight check from 9,400'.Up weight clean at 13K.RIH to find top of pump.Started stacking weight at 9,514'.Stacking 2,5001bs down.Online down CT to activated hip tripper at 1 bbl/min.Attempting to find sweet spot of hip tripper.Trying different pump rates and Slack weights.Found sweet spot at 9,513.4'- 4031bs Ct weight and 1.2 bbls minute.Felt good rocking at surface indicating tools was working.Once obtained good hip tripping pumped 28 bbls while slacking off on pack off in 5001b increments. Spent 30 minutes.Down on pump.Picked up 2k below PU weight to 10K.RIH without pumping.Stack 15k down.Pick up and repeat same.POOH at 5 ft/min looking for indication of overpull.PU weight while pulling out of GS profile was 12k lbs 1,000 lbs less than pick up weight with D&D baited on GS.Good indication of pack off set.Attempt Pt down back side at.5 bbls min.Pressure increased to 650psi and bleed down.POOH to surface.At surface.Freeze protect coil with 60/40 meth.Secure well. Blow down stack.Break flange.RIH no D&D pack off.GS sheared.Break down tools.Install next BHA.CC,DFCV,DISCON,2x weight bars,JDC,Pack off test assembly,stab on well.Blow back suction hose to upright tank.Walked around performed with roustabout and crane operator. Discussed custodial plans for the evening. Location secure. Pad operator notified. Crews off location. • A Hilcorp Alaska, LLC Icor,,Alaska,LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP 1-12 201-163 50-029-23038-00-00 9/17/2015 9/30/2015 Ipti661'''''inkC , IbD1!":� 9/30/ .5 ;Wednesday . r !NW ?iI t Arrive on location.Hold safety meeting.Discuss job procedures and review Halliburton JSA.Fire equipment.Previously stabbed on well with Pack off test tool from previous night.Break flange.Pop off and Break down weight bars and PT tool.BOT on location with SIDI hip tripper.Pinned Slick line GS with 1/4 in Brass shear pin.Tool consists of CC,DFCV,HYD DISC,Hip tripper accelerator,hip tripper,xover ported sub,and 3in Gs spear baited with A stop tubing stop.Circulate 60/40 into holding tank with sea water.Rlh at 40 ft/min until 2,500'.Increase RIH speed to 50 ft/min(small aluminum shear pin on A stop).Weight check at 9,400'.12,700 lbs RIH weight-4,200lbs.Stacked 3k down at 9,495'.Online with sea water at 1 bbl/min.Pressure increase to 4,000psi.Hip tripper stalled.Pick up to 6k.Online 1 bbl/min no indication of tool working.Increase rate to 1.2 bbls/min slack of to 5k.2,500-2,650psi coil pressure. Continue slack off in 1,000Ibs increments.-400Ibs.Tool working great.Hammerd down for 15 minutes.Saw weight break back and stacked 1,000Ibs.Pressure increased but didn't stall hip tripper.3,800psi.Tool is still working.Down on pump.Pick up to 2,000Ibs under wt check(12,700).RIH 30 ft/min not pumping.Stack 7k at surface.Estimated 1,5001bs weight on bit.Pick up off A stop and watch for overpulls.Weight broke over at 11k,1,700Ibs under previous weight check with a stop on GS.Clean pick up.29 bbls pumped for run.ESP Rep on location.Attempt to turn on motor.8.6 amps seen and then slowly dropping.Increased Hertz or speed from 30/40/45.Still no incease in Amperage.Attempt to set down on top of a stop with CT.Estimated 1,500 lbs WOB.Fire pump back up. Doesn't look like pump and motor are engaged.No visual indication of fluid at tank.Circulated fluid down coil and established returns to tank prior to turning on ESP pump.Looks like pump not engaged with motor.POOH to Rig down.2,000'from surface come online down CT string with 60/40 methanol water.At surface master swab shut in.Continue to circulate 40 bbls of 60/40 into coil.Freeze protect complete.Flow down stack and down corner to tank.Pop off well. GS sheared.No A-stop at surface.Break down tools.Set BOPS and riser in mast.Set injector head on CTU trailer.Walk around location.Location secure.Crews off location. 10/1/15-Thursday '21't � l i i ilaimi .1 i• -mrret02L No operations to report. 10/2/15-Friday No operations to report. 10/3/15- Saturday °' � No ooperations to report. 10/4 "Sun�l'I(i � Oli Biba"` d iiI'i��7t' i - I P aq 41 int Imo' i�`i0, No operations to report. No operations to report. �y/��.t '" No operations to report. � F �� w\� s THE STATE Alaska Oil and Gas F7,0,11 ofA LAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main. 907 279.1433 OF ALAS' Fax. 907.276 7542 www.aogcc.alaska.gov Stan Porhola / Operations Engineer 0 — 6i) Hilcorp Alaska, LLC ` 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB I-12 Sundry Number: 315-464 Dear Mr. Porhola: 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, /4°)Q4)Z— — Cathy P Foerster Chair DATED this ay of August, 2015 Encl. • RECEIVED STATE OF ALASKA J U L 2 9 015 ALASKA OIL AND GAS CONSERVATION COMMISSION b'j 3v a/S APPLICATION FOR SUNDRY APPROVALS ,AOG 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate 0 _ „n,,, Alter Casing 0 Change Appro - gram ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair WeN -enter Susp WeN 0 Other:SI(Pump change❑✓ 2.Operator Name: 4.Current WeN Class: 5.Permit to WI Number. TR Esq Hilcorp Alaska,LLC Exploratory ❑ Development Q , 201-163 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23038-00-00 • 7.If perforating: 8.WeN 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 SB 1-12 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025517• MILNE POINT/SCHRADER BLUFF OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 12,470. 3,712 • 12,470 . 3,712 - N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 108' 20" 108' 109' N/A N/A Surface 2,906' 10-3/4" 2,906' 2,408' 3,580psi 2,090psi Intermediate 10,228' 7" 10,228' 3,706' 7,240psi 5,410psi Liner"A" 2,457' 4-1/2" 12,393' 3,716' 8,430psi 7,500psi Liner"B" 2,232' 4-1/2" 12,396' 3,715' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic I See Attached Schematic 3-1/2" 9.3#/L-80/IBT 9,582 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development Q. Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Operations: 8/12/2015 CommencingOIL WDSPL ❑' WINJ ❑ ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email sporhola(ahilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature ..� "`'76:7 L— Phone 777-8412 Date �/2.q/c--- COMMISSION USE ONLY l Conditions of approval: Notify Commission so that a representative may witness Sundry Number: X15 - yQL Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No G Subsequent Form Required: /Cj _c,n y 1 / APPROVED BY � Approved by: -/ COMMISSIONER THE COMMISSION Date: a-'(t.—! it Forrn and Form 10-403 Revised 5/2015 Approved application is II 1 jr o�tlls r ,A Q�of approval. /Attach f n Dup cate i `` RBDMS AUG 1 4 2015 Well Prognosis Well: MPU 1-12 llih+orp Alaska.LL Date:7/29/2015 Well Name: MPU 1-12 API Number: 50-029-23038-00 Current Status: SI Oil Well [TTC-ESPCP] Pad: I-Pad Estimated Start Date: August 12th, 2015 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-163 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: 1,878 psi @ 4,000' TVD (Last BHP measured 11/13/2014) Maximum Expected BHP: 1,878 psi @ 4,000' TVD (No new perfs being added) Max.Allowable Surf Pressure: 393 psi (Based on SBHP taken 11/13/2014 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000'TVD of oil cap) Brief Well Summary: MPU 1-12 was drilled in 2001 using Nabors 22E and completed as a multi-lateral in the Schrader Bluff OA and OB sands with an ESP pump. ESP changeouts took place in 2010 and 2014, the most recent was an ESP changeout in 2014 using Doyon #16 to replace the conventional ESP with a TTC-ESPCP (Thru-tubing conveyed electric submersible progressive cavity pump). Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 85.5° @ 8,110'). • Casing last tested to 250/2,000 psi for 5 min down to 6,014'on 11/29/2014. • Cleaned out fill from 9,855'to 12,045'with Doyon#16 in 2014. • TTC-ESPCP Pump failed in January 2015. Objective: The purpose of this work/sundry is to pull the existing failed TTC-ESPCP and run a new TTC-ESPCP. Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. - 2. RIH w/2.00" coil w/2.75"wash nozzle and cleanout to top of TTC-ESPCP+/-9,510' MD. POOH. a. Min ID is 2.920"thru GLMs(2.813" drift). 3. RIH w/2.00"coil w/GS pulling tool and pull tubing stop+/-9,510' MD. POOH. 4. RIH w/2.00"coil w/GS pulling tool and pull packoff+/-9,511' MD. POOH. 5. RIH w/2.00" coil w/GS pulling tool and pull TTC-ESPCP pump+/-9,517' MD. POOH. 6. RIH w/2.00" coil w/2.75"wash nozzle and cleanout to top of TTC receiver at+/-9,550' MD. POOH. 7. RIH w/2.00" coil w/GS running tool and run TTC-ESPCP pump+/-9,517' MD. POOH. 8. RIH w/2.00" coil w/GS running tool and run packoff+/-9,511' MD. POOH. 9. RIH w/2.00" coil w/Test tool to+/-9,500' MD.Test packoff to 250/1,000 psi for 15 min. POOH. 10. RIH w/2.00" coil w/GS running tool and run tubing stop+/-9,510' MD. 11. PU to+/-9,500' MD. Displace well over to 8.4 ppg produced water. Well Prognosis Well: MPU 1-12 Ililcorp Alaska.LLQ Date:7/29/2015 a. Estimated volume (w/o coil in hole) is 84 bbl. 12. POOH w/coil. LD GS running tool. 13. RD Coiled Tubing. 14. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic Milne Point Unit • Well: MPU 1-12 II SCHEMATIC Last Completed: 12/5/2014 llilcorp Alaska,LLC PTD: 201-163 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm RKB Elev 64.7' 20" Conductor 92/H-40/Welded N/A Surf 108' 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 2,906' 7" Intermediate 26/L-80/Btc-Mod 6.151 Surface 10,228' 20''A 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 9,936' 12,393' 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 10,164' 12,396' `" ; TUBING DETAIL . 3-1/2" Tubing 9.3/L-80/EUE 8rd 2.867 Surf 9,582' LINER DETAIL 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 9,936' 9,980' f 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.833 9,980' 12,393' I 2 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 10,164' 10,373' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 10,373' 12,396' 10-3/4".• • JEWELRY DETAIL No Depth Item 1 201' GLM 3.5"x 1"Camco KBMG w/Orifice Valve&BK Latch 2 2,485' GLM 3.5"x 1"Camco KBMG w/Open/Empty Pocket 3 9,493' 3.5"Well Lift Discharge Gauge Unit 4 9,510' TTC-ESPCP(Stop/Packoff/Pump) 5 9,550' TTC Receiving Assembly 6 9,555' Tandem Seal Section 7 9,570' Motor 562MSP1,84hp,2,210 v/23 amp 8 9,579' Well lift MGU Gauge 9 9,581' Centralizer-Bottom @ 9,582' 10 9,627' Baker Hook Wall,Hanger above 7"Window 11 9,642' Baker Hook Wall,Hanger below 7"Window frp ci 12 9,650' Baker Tension Lock Swivel 3 13 9,906' Baker Tie Back Sleeve s , 14 9,928' Baker ZXP Liner Top Packer 4 15 9,930' Baker 7"x 5"HMC Liner Hanger 16 10,116' Btm 4-1/2"Pack-off Bushing 17 10,128' Btm 4-1/2"Guide Shoe 18 10,147' Btm Baker Pack-off Bushing 19 12,395' Btm Baker 4-1/2"Guide Shoe 5 LATERAL WINDOW DETAIL II 1 Top of"OA"Window @ 9,916'MD;Bottom @ 9,928'MD;Angle @ top of window is 80deg I_III Top of"OB"Window @ 10,228'MD;Bottom @ 10,240'MD;Angle @ top of window is 87 deg • • 6 WELL INCLINATION DETAIL KOP@300'MD a 7 Max Wellbore Angle=85.5 deg @ 8,102'MD 63.74 deg @ 2,550'MD 8 09 OPEN HOLE/CEMENT DETAIL , 20" Cmt w/650 sx of Arcticset I in 30"Hole • 10-4/4" _ Cmt w/585 sx AS Lite,502 sx Class"G"in 13-1/2"Hole 7" Cmt w/1,172 sx Class"G"in 9-7/8"Hole WELLHEAD '; Wellhead FMC Tubing Hanger,11"x 4-1/2"TC-II Top& ' t, Bottom 1� GENERAL WELL INFO '.� �� 12 16 API:50-029-23038-60-00 Ii ,' Drilled and Cased by Nabors 4-ES -12/8/2001 "CA"Lateral 17 13 t-"•w NOTES: 14 I5 Need Cementing Report to Establish Tops 18 Need Casing&Tubing Tallies ` "OB"Lateral 19 7" TD=12,470'(MD)/TD=3,712'(1VD) PBTD=12,470'(MD)/PBTD=3,712'(TVD) Created By:STP 7/29/2015 r 11 Milne Point Unit COIL BOPE MPU I-12 Ilile rp %Ia.ka.IJ.(. 07/28/2015 MPU 1-12 20X10' X7X3% Coil Tubing BOP 1. Lubricator to injection head . o III Illi 1.75"Tandem Stripper i� �L I�•I,I, Blind/Shea.=' 1/16 10 =.Blind/Shear .1.11 LI 0.1111111Blind/Shear = • .Blind/Shearl,I,'•��] -_-__ _— c T _—� fill`"`,\\\ Slip MI114 •I1I, PiI I Pipe Mill Mud Cross Jpe A =■ 4 1/16 10M X 4 1/16 10M _ Outlet I w/2-2 1/16 10M full opening FMC valves IIII( a 1 18 lil_I. ' oli a hi Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M `U 2 1/16 10M 2 1/16 10M Crossover spool r' 4 1/16 10M X 2 9/16 5M L. Valve,Swab,WKM-M, `.'o•`'+� �`�go 2 9/16 5M FE �a\i ,—,\ 6 immin. 1-9 Valve, Upper Master,Baker, 2 9/16 SM FE,w/Hydraulic (5)� Lur Valve,Lower Master,WKM-M, dirk, � 2 9/16 5M FE ...tile rrT1 Adapter,2 9/16 5M FE x j 4 1/16 5M FE I4it- ui nTui s. Tubing Adapter,4 1/16 5M ��' Tl _1 STATE OF ALASKA RECEIVED A, CA OIL AND GAS CONSERVATION CC SSION REPORT OF SUNDRY WELL OPERATIONS DEC 2 2 2014 1. Operations Performed. AOGCC ❑Abandon 0 Repair Well 0 Plug Perforations 0 Perforate 0 Re-Enter Suspended Well ❑Alter Casing ®Pull Tubing 0 Stimulate-Frac 0 Waiver ®Other ❑Change Approved Program 0 Operation Shutdown 0 Stimulate-Other 0 Time Extension Changeout ESP 2. Operator Name. 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 201-163 3. Address: ®Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-23038-00-00 7. Property Designation(Lease Number): 8. Well Name and Number: ADL#025906&025517 MPI-12 9 Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Milne Point Unit/Schrader Bluff 11. Present well condition summary: Total depth. measured 12470' feet Plugs:(measured) None feet true vertical 3712' feet Junk:(measured) None feet Effective depth: measured 12470' feet Packer: (measured) None feet true vertical 3712' feet Packer: (true vertical) None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 29'- 108' 29'- 108' 1490 470 Surface 2877' 10-3/4" 29'-2906' 29'-2408' 5210 2480 Intermediate 10201' 7" 27'- 10228' 27'-3706' 7240 5410 Production Liner 2313' 4-1/2" 10128'- 12441' 3691'-3714' 8430 7500 Perforation Depth Measured Depth: 10374'- 12397' feet SCANNED RANI ,i 0 _,... 1 :, True Vertical Depth: 3710'-3715' feet Tubing(size,grade,measured and true vertical depth): 3-1/2",9.3# L-80 9582' 3586' Packers and SSSV(type,measured and true vertical depth): None None None 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1020 0 Subsequent to operation. 0 0 0 0 0 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: 0 Exploratory 0 Stratigraphic ®Development 0 Service ®Daily Report of Well Operations 16. Well Status after work: ®Oil 0 Gas 0 WDSPL 0 Well Schematic Diagram 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 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: Contact: J.E.B.Bolen,564-5110 Email: J.E.B.Bolen@bp.com N/A Printed Name: Joe Lastu t........,812.o.ne: Title: Drilling Technologist /�Signature• t 564-4091 Date: Iy/I"lIIF rm 10-404 R vised 10/2012 \ Submit Original Only 0e � /' e 1 `i s✓� /7q/y RBDMS�JANg- 4 CZ North America-ALASKA-BP Page 1 of 15 Operation Summary Report Common Well Name:MPI-12 AFE No Event Type:WORKOVER(WO) Start Date:11/24/2014 End Date:12/5/2014 X4-010Q5-E:(1,200,000.00) Project:Milne Point Site:M Pt I Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/7/2001 12:00:00AM Rig Release:12/5/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292303800 Active datum:MPI-12:@63.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/24/2014 21:00 - 23:00 2.00 MOB P PRE PJSM,PREP TO MOVE TO OFF OF MPF-54 -LAY DERRICK OVER AND SECURE ON DERRICK STAND -FUNCTION TEST MOVING SYSTEM HYDRAULICS AND ESD -RAISE RIG AND MOVE OFF OF MPF-54 -POSITION IN CENTER OF PAD -REMOVE BOP FORM CELLAR AND INSTALL REAR BOOSTER WHEELS 23:00 - 00:00 1.00 MOB N WAIT PRE RIG MOVE AROUND THE END OF THE PAD IS OBSTRUCTED BY INOPERABLE CRANE THAT IS RIGGED TO THE WSL OFFICE WAIT ON MECHANIC CALLED OUT FROM DEADHORSE -SEE TRACTION REPORT#IR-4871512 11/25/2014 00:00 - 02:00 2.00 MOB N WAIT PRE RIG MOVE AROUND THE END OF THE PAD IS OBSTRUCTED BY INOPERABLE CRANE THAT IS RIGGED TO THE WSL OFFICE -WAIT ON MECHANIC CALLED OUT FROM DEADHORSE. 02:00 - 06:00 4.00 MOB P PRE PJSM,BEGIN RIG MOVE. MOVE AROUND MPF PAD TO ENTRANCE. '-CONTINUE MOVE DOWN ACCESS ROAD TO MPL PAD. -MOVE RIG THRU MPL-PAD DOWN ACCESS ROAD TO MILNE PT SPINE ROAD. 06:00 - 12:00 6.00 MOB P PRE 'CONTINUE TO MOVE RIG FROM MPF-54 TO MPI PAD. -ON LOCATION AT 11:00 HRS.INSPECT WELL HEAD,1000 PSI ON I/A,200 PSI ON 0/A. -VALVES AND WELLHEAD DRESSED OUT ACCORDING TO WELL PROGRAM. -SPOT TREE AND WELLHEAD EQUIPMENT BEHIND WELL. -CALL DRILL SITE OPERATOR FOR OPPORTUNITY TO WITNESS MOVING RIG OVER WELL. 12:00 - 16:00 ' 4.00 MOB P PRE PJSM.SPOT RIG OVER WELL. DOUBLE MATT UNDER RIG AND EXTENSIVE SHIMMING REQUIRED AS DRILLER'S SIDE HAS A LOW SPOT. -TAKE ON WATER AND FUEL.SPOT WSL SHACK. 16:00 - 17:00 1.00 RIGU P PRE PJSM.RAISE AND PIN DERRICK. -BRIDLE DOWN. -R/U FLOOR.SPOT FUEL TRAILER. RIG ACCEPTED @ 17:00 HRS, 11/25/2014. 17:00 - 18:30 1.50 KILLW P DECOMP PJSM.R/U SURFACE LINES. -R/U KILL MANIFOLD. -SPOT SLOP TANK. 18:30 - 22:30 4.00 KILLW P DECOMP TAKE ON 9.8 PPG BRINE. -SPOT TIGER TANK,R/U HARD LINES. Printed 12/15/2014 3:02:10PM North America-ALASKA-BP Page 2 of 15 Operation Summary Report Common Well Name:MPI-12 AFE No Event Type:WORKOVER(WO) Start Date: 11/24/2014 End Date:12/5/2014 X4-010Q5-E:(1,200,000.00) Project:Milne Point Site:M Pt I Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/7/2001 12:00:00AM 1Rig Release:12/5/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292303800 Active datum:MPI-12:©63.40usft(above Mean Sea Level) Date From-To 1 Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 23:00 0.50 KILLW P DECOMP RIG EVACUATION DRILL. -WELL BLOW OUT DRILL. -ALL CREWAND THIRD PARTY MEMBERS REPORTED TO THE PRIMARY MUSTER AREA IN A TIMELY MANNER. -MR WITH RIG CREW,WSL AND ALL PERSONAL ON SITE. 23:00 - 00:00 1.00 KILLW P DECOMP PJSM.PRESSURE TEST SURFACE LINES. -PRESSURE TEST TO 250 PSI LOW,3,500 PSI HIGH FOR 5 CHARTED MINUTES. 11/26/2014 00:00 - 00:30 0.50 KILLW P DECOMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS -CHECK CROWN-O-MATIC.GOOD. 00:30 - 04:00 3.50 KILLW P DECOMP PJSM.PRESSURE TEST SURFACE LINES. CONTINUE PRESSURE TEST TO 250 PSI LOW,3,500 PSI HIGH FOR 5 CHARTED MINUTES. 04:00 - 06:00 2.00 WHSUR P DECOMP PJSM.PULL BPV. -R/U WELL SUPPORT LUBRICATOR. -PRESSURE TEST LUBRICATOR TO 250 PSI LOW,3,500 PSI HIGH FOR 5 MINUTES.GOOD TEST. -PULL BPV. -L/D LUBRICATOR.1,000 PSI SHUT IN TUBING PRESSURE. Printed 12/15/2014 3:02:10PM v North America-ALASKA-BP Page 3 of 15 Operation Summary Report Common Well Name:MPI-12 AFE No Event Type:WORKOVER(WO) Start Date:11/24/2014 End Date:12/5/2014 X4-010Q5-E:(1,200,000.00) Project:Milne Point Site:M Pt I Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/7/2001 12:00:00AM Rig Release:12/5/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292303800 Active datum:MPI-12:©63.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 12:30 6.50 KILLW P DECOMP PJSM.PERFORM WELL KILL. -EMPHASIZE GOOD COMMUNICATION AND STOPPING THE JOB IF SOMETHING IS NOT RIGHT. I-REVIEW PRESSURE CROSS CHECK LIST. PRV ON PUMP SET FOR 4,200 PSI. -NOTIFY MILNE PT AND DRILL SITE OPERATOR OF GAS VENTING OPERATIONS. -BLEED GAS OFF TO FLOW BACK TANK BLEED FOR APPROXIMATELY 25 MINUTES, NO FLUID BACK. -TUBING SHUT IN PRESSURE 700 PSI.LINE UP TO PUMP 9.8 PPG KWF DOWN TUBING. -PUMP DOWN TUBING AT 3 BPM,ICP=700 PSI,FCP=100 PSI,PUMPED 25 BBLS,TAKING RETURNS THROUGH CHOKE TO FLOWBACK TANK. '-CLOSE IN CHOKE AND BULLHEAD 441 BBLS AT 7 BPM/1400 PSI.MONITOR 0/A THROUGHOUT OPERATION.325 PSI MAX. -MONITOR WELL FOR 10 MINUTES,SITP= 625 PSI,SICP=925 PSI. -CIRCULATE DOWN TUBING 40 BBLS DEEP CLEAN PILL FOLLOWED BY 214 BBLS 9.8 PPG BRINE AT 5 BPM. -TAKING RETURNS THROUGH CHOKE AND TO FLOW BACK TANK.ICP=700 PSI,FCP= 125 PSI ON TUBING. -INTERMITTENT GAS IN RETURNS, PROBABLY FROM TUBING BELOW GLM AT 2,508' -I/A=900 PSI INITIALLY AND 100 PSI AFTER 214 BBLS CIRCULATED. -RECOVERED 120 BBLS FROM FLOW BACK TANK.SITP=200 PSI,I/A=475 PSI. -CIRCULATE 171 BBLS DOWN TUBING, TAKING RETURNS THROUGH CHOKE TO FLOW BACK TANK. -SHUT IN AND EMPTY FLOW BACK TANK,72 BBLS RECOVERED. (12)HOUR FLUID LOSS=121 BBLS 9.8 PPG BRINE. FLUID LOSS FROM BULLHEAD=441 BBLS 9.8 PPG BRINE. NO PUMP OPERATIONS WITH SLOW CIRCULATING RATES. 12:30 - 14:00 1.50 KILLW P DECOMP PTSM.LINE UP AND PUMP DOWN TUBING AT 5 BPM=690 PSI TAKING RETURNS THROUGH CHOKE TO FLOW BACK TANK -PUMP 85 BBLS.RETURNS ARE CLEAN AND GAS FREE.25 BBLS RETURNED TO FLOW BACK TANK.LOST 60 BBLS. -I/A AND TUBING ARE ON A VACUUM.BLOW DOWN LINES AND RIG UP TO FILL WELL, STATIC LOSS RATE=72 BPH. -CONSULT ODE AND DIRECTED TO FILL HOLE AT 30 BPH AS PER PROGRAM. Printed 12/15/2014 3:02:10PM • North America-ALASKA-BP Page 4 of 15 Operation Summary Report Common Well Name:MPI-12 AFE No Event Type:WORKOVER(WO) Start Date:11/24/2014 End Date:12/5/2014 X4-010Q5-E:(1,200,000.00) Project:Milne Point Site:M Pt I Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/7/2001 12:00:OOAM Rig Release:12/5/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292303800 Active datum:MPI-12:@63.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 16:00 2.00 WHSUR P DECOMP PJSM.SET TWC._.J -P/U WELL SUPPORT LUBRICATOR AND TEST TO 250 PSI LOW,3,500 PSI HIGH FOR 5 MINUTES.GOOD TEST. -SET TWC. -L/D LUBRICATOR. 16:00 - 17:00 1.00 WHSUR P DECOMP PJSM.PRESSURE TEST TWC. -PERFORM ROLLING TEST FROM BELOW TWC,PUMP AT 5 BPM=300 PSI FOR 5 MINUTES. -PRESSURE TEST TWC FROM ABOVE TO 250 PSI LOW,3,500 PSI HIGH FOR 5 MINUTES. GOOD TEST. -DRAIN STACK,BLOW DOWN LINES. 17-00 - 19:30 2.50 WHSUR P DECOMP PJSM.N/D 2-9/16"TREE AND ADAPTER FLANGE. -DRAIN TREE OF FLUIDS. -FMC REPRESENTATIVE BLEED VOID. -N/D ADAPTER FLANGE AND TREE. -CHECK THREADS ON HANGER 19:30 - 22:00 2.50 BOPSUR P DECOMP PJSM.N/U 13-5/8"FOUR PREVENTER BOPE. -R/U TURN BUCKLES AND RISER. -CONNECT ACCUMULATOR LINES,HOLE FILL LINE AND KILL LINE. 22:00 - 00:00 2.00 BOPSUR P DECOMP PJSM.TEST FOUR PREVENTER 13-5/8"BOPE ` AND RELATED EQUIPMENT. -TEST BOPE ACCORDING TO AOGCC REGULATIONS,DOYON AND BP PROCEDURES. -TEST ANNULAR WITH 2-7/8"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST UPPER 2-7/8"X 5"VARIABLE RAMS WITH 2-7/8"AND 4"TEST JOINT TO 250 PSI, 3,500 PSI HIGH FOR 5 CHARTED MINUTES. (24)HOUR FLUID LOSS=370 BBLS 9.8 PPG BRINE. FLUID LOSS FROM BULLHEAD=441 BBLS 9.8 PPG BRINE. OA=200 PSI. NO PUMP OPERATIONS WITH SLOW CIRCULATING RATES. 11/27/2014 00:00 - 03-00 3.00 BOPSUR P DECOMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS -CHECK CROWN-O-MATIC.OK. PJSM.CONTINUE TEST FOUR PREVENTER 13-5/8"BOPE AND RELATED EQUIPMENT. -TEST LOWER 2-7/8"X 5"VARIABLE RAMS WITH 2-7/8"AND 4"TEST JOINT TO 250 PSI, 3,500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3,500 PSI HIGH FOR 5 CHARTED MINUTES. -PERFORM ACCUMULATOR DRAW DOWN TEST WITH WSL PRESENT. -NO FAILURES,JOHNNIE HILL OF AOGCC WAIVED WITNESSING. 03:00 - 04:00 1.00 BOPSUR P DECOMP BLOW DOWN ALL SURFACE LINES. -DRAIN STACK AND GAS BUSTER. -R/D TEST EQUIPMENT. Printed 12/15/2014 3:02:10PM North America-ALASKA-BP Page 5 of 15 Operation Summary Report Common Well Name:MPI-12 AFE No Event Type:WORKOVER(WO) Start Date:11/24/2014 End Date:12/5/2014 X4-01005-E:(1,200,000.00) Project:Milne Point Site:M Pt I Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/7/2001 12:00:00AM Rig Release:12/5/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292303800 Active datum:MPI-12:@63.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 06:30 2.50 BOPSUR P DECOMP PJSM.PULL TWC. P/U OFF SET LUBRICATOR. -PRESSURE TEST TO 250 PSI LOW,3,500 PSI HIGH FOR 5 MINUTES.GOOD TEST. -PULL TWC. -R/D WELL SUPPORT LUBRICATOR. 06:30 - 08:00 1.50 PULL P DECOMP PJSM.MAKE UP LANDING JT TO HANGER. -MAKE UP TOP DRIVE TO LANDING JT.BACK OUT LOCK DOWN SCREWS. -PULL HANGER OFF SEAT AND ESTABLISH TUBING IS FREE,93K UP WT. SLACK OFF UNTIL HANGER IS ABOUT 3' FROM BEING LANDED. 08:00 - 08:30 0.50 PULL P DECOMP PJSM.CLOSE BAG AROUND LANDING JT. -LINE UP THRU CHOKE AND MUD GAS 'SEPARATOR. -CIRCULATE(50)BBLS THRU CHOKE TO PITS,6 BPM=730 PSI. -LOST 25 BBLS DURING THAT CIRCULATION. OPEN ANNULAR PREVENTER. -MONITOR WELL,ELECT TO CIRCULATE ANOTHER 68 BBLS AT 6 BPM=730 PSI,LOST 17 BBLS. MONITOR WELL,FLUID SLOWLY DROPPING. 08:30 - 10:00 1.50 PULL P DECOMP PJSM.PULL HANGER TO FLOOR,LAY DOWN HANGER. -BLOW DOWN TOP DRIVE,MAKE UP SAFETY JT. -FILL HOLE WHILE DOING THIS AND ESTABLISH LOSS RATE. -LOSS RATE=37 BPH. -POOH,L/D(4)JTS AND GLM. 10:00 - 11:30 1.50 PULL P DECOMP PJSM.HANG ESP SHEAVE AND TRUNK FOR ESP CABLE. I-STRING ESP&HEAT TRACE THRU ESP SHEAVE. CONTINUOUS HOLE FILL,LOSS RATE DROPPED TO 28 BPH. 11:30 - 12:00 0.50 PULL P DECOMP PJSM.POOH,STANDING BACK 2 7/8"EUE 8 ROUND TUBING. -SPOOLING UP ESP CABLE AND HEAT TRACE. -ACQUIRE SLOW CIRCULATING RATES. LOSSES TO WELL BORE LAST(12)HRS=335 BBLS OF 9.8 PPG BRINE. O/A=160 PSI. 12:00 - 12:30 0.50 PULL P DECOMP SERVICE RIG AND INSPECT FLOOR EQUIPMENT. -CHECK PIT VOLUMES AND INSPECT PIPE ELEVATOR. CHECK CROWN 0 MATIC,OK. 12:30 - 20:00 7.50 PULL P DECOMP PJSM.CONTINUE TO POOH AND STANDING BACK 2 7/8"EUE 8 RND TUBING. -SPOOLING ESP CABLE AND HEAT TRACE. -POOH FROM 9,343'MD TO 7,147'MD. -CONTINUOUS HOLE FILL,LOSS RATE=25 BPH. Printed 12/15/2014 3:02:10PM North America-ALASKA-BP Page 6 of 15 Operation Summary Report Common Well Name:MPI-12 AFE No Event Type:WORKOVER(WO) Start Date:11/24/2014 End Date:12/5/2014 X4-010Q5-E:(1,200,000.00) Project:Milne Point Site:M Pt I Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/7/2001 12:00:OOAM Rig Release:12/5/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292303800 Active datum:MPI-12:@63.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 20:30 0.50 PULL P DECOMP PJSM.ATTEMPT TO CIRCULATE TUBING BELOW GLM. -R/U HEAD PIN TO 2-7/8"TUBING. -PUMP 1 BBL,PRESSURED UP TO 2,950 PSI. SHUT DOWN AND BLEED OFF PRESSURE. 20:30 - 00:00 3.50 PULL P DECOMP PJSM.CONTINUE TO POOH AND STANDING BACK 2 7/8"EUE 8 RND TUBING. -SPOOLING ESP CABLE AND HEAT TRACE. -POOH FROM 7,147'MD TO 6,136'MD. STAND BACK 37 STANDS IN DERRICK. -CONTINUOUS HOLE FILL,LOSS RATE=25 BPH. -NO PUMP OPERATIONS WITH SLOW CIRCULATING RATES. LOSSES TO WELL BORE LAST(24)HRS=651 BBLS OF 9.8 PPG BRINE. O/A=140 PSI. 11/28/2014 00:00 - 00:30 0.50 PULL P DECOMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS -CHECK CROWN-0-MATIC.OK. 00:30 - 10:00 ' 9.50 PULL P DECOMP PJSM.CONTINUE TO POOH AND UD 2 7/8" EUE 8 RND TUBING. -SPOOLING ESP CABLE TO SPOOLING UNIT. -POOH FROM 7,147'MD. -CONTINUOUS HOLE FILL,LOSS RATE=22 BPH. -POOH TO 122'&ESP ASSEMBLY. -MONITOR WELL,(10 MINUTES),LOSS RATE 22 BPH. 10:00 - 15:00 5.00 PULL P DECOMP PJSM.LAY DOWN ESP ASSEMBLY. -REMOVE CLAMPS FROM MOTOR ASSEMBLY,TERMINATE ESP CABLE. -BREAK DOWN&LAY DOWN MOTOR/PUMP ASSEMBLY. -RECOVERED(507)5'DUAL CLAMPS,(304)2' CANNON CLAMPS. -RECOVERED(9)SINGLE CHANNEL CLAMPS, (4)BANDS AND(3)FLAT GUARDS. -CLEAR AND CLEAN RIG FLOOR. -R/D ELEPHANT TRUNK AND ESP SHEAVE. FLUID LOSS(12)HOURS=288 BBLS 9.8 PPG BRINE. OA=160 PSI. 15:00 - 15:30 0.50 DHB P DECOMP PJSM.P/U 7"HES RBP. M/U HES RBP RUNNING TOOL. • 15:30 - 16:00 0.50 DHB P DECOMP PJSM.SERVICE PIPE SKATE,TOP DRIVE AND 'RIG FLOOR EQUIPMENT. 16:00 - 00:00 8.00 DHB P DECOMP PJSM.RIH_WITH 7"HES RBP._ -M/U 7"HES RBP. -RIH ON 4"DRILL PIPE FROM SHED. -RIH FROM SURFACE TO 5,229'MD.PUW= 90K,SOW=69K. FLUID LOSS(24)HOURS=515 BBLS 9.8 PPG BRINE.LOSS RATE=20 BPH. OA=120 PSI. 11/29/2014 00:00 - 00:30 0.50 DHB P DECOMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS -CHECK CROWN-0-MATIC.OK. Printed 12/15/2014 3:02:10PM North America-ALASKA-BP Page 7 of 15 Operation Summary Report Common Well Name:MPI-12 AFE No Event Type:WORKOVER(WO) Start Date:11/24/2014 End Date:12/5/2014 X4-010Q5-E:(1,200,000.00) Project:Milne Point Site:M Pt I Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/7/2001 12:00:OOAM Rig Release:12/5/2014 Rig Contractor:DOYON DRILLING INC. l UWI:500292303800 Active datum:MPI-12:@63.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00:30 - 02:00 1.50 DHB P DECOMP PJSM.RIH WITH 7"HES RBP. -RIH ON 4"DRILL PIPE FROM SHED. -RIH FROM 5,229'MD TO 6,014'MD.PUW= 96K,SOW=70K. -ACQUIRE SLOW CIRCULATING RATES. 02:00 - 03:00 1.00 DHB P DECOMP PJSM.TROUBLE SHOOT AND SERVICE TOP DRIVE. 03:00 - 04:30 1.50 DHB P DECOMP PJSM.SET 7"HES RBP. -$ET RBP AT 6.014'MD.SET DOWN 15K,RBP SET. -ATTEMPT TO PRESSURE TEST RBP TO 250 PSI LOW,2,000 PSI HIGH.UNSUCCESSFUL.. -CHECK ALL SURFACE LINES AND EQUIPMENT,ALL GOOD. 04:30 - 06:00 1.50 DHB N RREP DECOMP TROUBLE SHOOT TOP DRIVE. -GRABBER SYSTEM NOT ALLOWING TOP DRIVE TO BREAK OUT. -HAVING TO ENGAGE MANUALLY. 06:00 - 07:30 1.50 DHB P DECOMP PJSM.OPT TO PUMP TO ENSURE ALL AIR IS OUT OF SYSTEM. j-BREAK CIRCULATION,CIRCULATE I BOTTOMS UP AT 7 BPM=1,050 PSI. 1` -SHUTAND DOWNRG PUMP,TO CLOSE UPPER PIPE RAMS IUP -TEST 7"CASING FROM TOP OF BRIDGE L,)g PLUG AT 6,014'TO SURFACE. -TEST AT 250 PSI FOR 5 MIN.OK TEST AT . i 2000 PSI AT 5 MIN.GOOD TEST. _ " -0/A MONITORED THROUGHOUT,NO t INDICATION OF COMMUNICATION. -BLEED ALL PRESSURE,OPEN PIPE RAMS, RIG DOWN TEST EQUIPMENT. 07:30 - 09:00 1.50 DHB P DECOMP PJSM.SLIP AND CUT 74'OF DRILLING LINE. -CHECK CROWN 0 MATIC,OK. 09:00 - 11:00 2.00 DNB P DECOMP PJSM.POOH WITH 4"DRILL PIPE FROM 5,956' MT TO 2,165'MD. -PUW=68K,SOW=69K. 11:00 - 12:00 1.00 DHB P DECOMP RIG HANDS NOTICED BAD SPOT IN DRILLING LINE,VERY GOOD CATCH. '-PJSM.SLIP AND CUT 61'OF DRILLING LINE. -ACQUIRE SLOW CIRCULATING RATES. LOSSES TO WELL BORE LAST(12)HOURS= 66 BBLS OF 9.8 PPG BRINE. 12:00 - 12:30 0.50 DHB P DECOMP SERVICE RIG,INSPECT FLOOR EQUIPMENT AND PIPE SKATE. _ -CHECK CROW 0 MATIC,OK 1230 - 14:30 2.00 DHB P DECOMP PJSM.PICKUP AND MAKE UP HALLIBURTON 7"26#RTTS. -RIH TO 96'&SET AS PER HALLIBURTON, HANGING OFF DRILL PIPE. -STAND BACK(1)STAND AND LAY DOWN RUNNING TOOL. -FILL HOLE,CLOSE BLIND RAMS AND TEST TOP OF RTTS©250/3500 PSI,5 MIN EACH/ CHARTED/GOOD TESTS. -RIG DOWN TEST EQUIPMENT,DRAIN STACK Printed 12/15/2014 3:02:10PM A North America-ALASKA-BP Page 8 of 15 Operation Summary Report Common Well Name:MPI-12 AFE No Event Type:WORKOVER(WO) Start Date:11/24/2014 End Date:12/5/2014 X4-010Q5-E:(1,200,000.00) Project:Milne Point Site:M Pt I Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/7/2001 12:00:00AM Rig Release:12/5/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292303800 Active datum:MPI-12:t 63.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 17:00 2.50 BOPSUR P DECOMP PJSM.NIPPLE DOWN 13 5/8"5M BOPE AND NIPPLE UP TC SPOOL. -R/D RISER,TURN BUCKLES,MOUSE HOLE AND KOOMEY LINES. !, ,J -N/D BOP AND SECURE ON STUMP. -N/U TC SPOOL AND FUNCTION LDS,AS PER CAMERON REP. 17:00 - 19:00 2.00 BOPSUR P DECOMP 'PJSM.NIPPLE UP 13-5/8"5M BOPE. =N/U BOPE. -R/U RISER,TURN BUCKLES,MOUSE HOLE AND KOOMEY LINES. -ENERGIZE KOOMEY. 19:00 - 19:30 0.50 BOPSUR P DECOMP PJSM.TEST BREAKS. -FILL UP BOPE STACK. -TEST TC ATTACHMENT BREAKS TO 250 PSI LOW,3,500 PSI HIGH,GOOD TEST. �C 19:30 - 20:00 0.50 BOPSUR P DECOMP PJSM.RIH TO RETRIEVE 7"STORM PACKER. -INSTALL WEAR RING,ID=7". I-RIH AND RETRIEVE RTTS. -POOH AND L/D RTTS. 20:00 - 22:00 2.00 BOPSUR P DECOMP PJSM.RIH WITH 4"DP FROM DERRICK RIH TO 6,014'MD.PUW=93K,SOW=68K 22:00 - 23:00 1.00 BOPSUR P DECOMP ;PJSM.CIRCULATE 9.8 PPG HI-VIS BRINE. --ACQUIRE SLOW CIRCULATING RATES. -DISPLACE WELL WITH 196 BBLS. 23:00 - 23:30 0.50 I BOPSUR P DECOMP ,PJSM.RELEASE RBP AS PER HES REPRESENTATIVE. VERIFY IA ON A VACUUM. 23:30 - 00:00 0.50 BOPSUR P DECOMP BULLHEAD 550 BBLS 9.8 PPG HI-VIS BRINE. -PUMP AT 7 BPM=770 PSI. LOSSES TO WELL BORE LAST(24)HOURS= 66 BBLS OF 9.8 PPG BRINE. OA=200 PSI. 11/30/2014 00:00 - 01:30 1.50 CLEAN P DECOMP CONTINUE BULLHEAD 550 BBLS 9.8 PPG HI-VIS BRINE. -PUMP AT 7 BPM=770 PSI,FCP=930 PSI. 01:30 - 02:00 0.50 CLEAN P DECOMP MONITOR WELL FOR(30)MINUTES.STATIC. 02:00 - 03:30 1.50 CLEAN P DECOMP PJSM.POOH WITH 7 HES RBP. -BLOW DOWN TOP DRIVE AND KILL LINE. -POOH FROM 5,482'MD TO 5,197'MD(5) STANDS,HOLE FILL OFF 1.5 BBLS. '-BRINE IS VERY THICK AND BRIDGE PLUG IS CLOSE TO ID OF 7"CASING. -SHUT DOWN,MONITOR WELL,WELL IS STABLE. 03:30 - 04:30 1.00 CLEAN P DECOMP PJSM.PUMP OUT OF HOLE FROM 5,482'MD TO 5,197'MD. PUMPING AT 2.5 BPM=660 PSI,15 BBLS LOST TO FORMATION. 04:30 - 05:30 1.00 CLEAN P DECOMP VOLUME IN PITS DOWN,STOP OPS AND TAKE ON VISCOSIFIED BRINE. I-MONITOR WELL WHILE TAKING ON BRINE. -WELL IS STABLE,SLIGHT DROP IN FLUID LEVEL WHILE TAKING ON BRINE. Printed 12/15/2014 3:02:10PM • North America-ALASKA-BP Page 9 of 15 Operation Summary Report Common Well Name:MPI-12 AFE No Event Type:WORKOVER(WO) Start Date:11/24/2014 End Date:12/5/2014 X4-01005-E:(1,200,000.00) Project:Milne Point Site:M Pt I Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/7/2001 12:00:OOAM Rig Release:12/5/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292303800 Active datum:MPI-12:@63.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 - 10:00 4.50 CLEAN P DECOMP PJSM.CONTINUE TO PUMP OUT OF HOLE, PUMP AT 2.5 BPM=650 PSI WHILE PULLING PIPE. -POOH FROM 5,197'MD TO 3,017'MD.(55 BBLS LOST TO FORMATION). -ACQUIRE SLOW CIRCULATING RATES. 10:00 - 12:00 2.00 CLEAN P DECOMP PJSM.BLOW DOWN TOP DRIVE AND PULL PIPE ON ELEVATORS. -POOH FROM 3,017'MD TO SURFACE.CHECK HOLE FILL EVERY 5 STANDS. -WELL TAKING ALMOST(1)BBL OVER 'CALCULATED DISPLACEMENT EVERY(5) STANDS. 'LOSSES TO WELL BORE LAST(12)HOURS, (ASIDE FROM BULLHEAD OPERATION),=168 BBLS. O/A=160 PSI. 12:00 - 13:00 1.00 CLEAN P DECOMP PJSM.BREAK DOWN AND LAY DOWN HALLIBURTON BRIDGE PLUG RETRIEVING TOOL. BREAK DOWN SAFETY JT,RACK BACK LAST STAND. 13:00 - 14:30 1.50 CLEAN P DECOMP PJSM.CLEAR AND CLEAN RIG FLOOR. -MOBILIZE TOOLS AND CROSSOVERS FOR CLEAN OUT RUN. -MAKE UP FLOOR VALVE X/OAND MAKE UP BULL NOSE ASSEMBLY. 14:30 - 00:00 9.50 CLEAN P DECOMP PJSM.M/U AND RIH WITH 2-7/8"7.8#FOX TUBING AND 2-7/8"6.5#8RD EUE. -RIH FROM SURFACE TO 3,152'MD WITH 2-7/8"7.8#FOX TUBING. -RIH FROM 3,152'MD TO 4,691'MD WITH 2-7/8"6.5#8RD EUE.PUW=57K,SOW=48K. LOSSES TO WELL BORE LAST(24)HOURS= 192 BBLS. O/A=150 PSI. 12/1/2014 00:00 - 00:30 0.50 CLEAN P DECOMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS -CHECK CROWN-O-MATIC.OK. 00:30 - 04:00 3.50 CLEAN P DECOMP PJSM.RIH WITH 2-7/8"6.5#8RD EUE AND 4" DRILL PIPE. -RIH FROM 4,691'MD TO 6,939'MD WITH 2-7/8"6.5#8RD EUE. -RIH FROM 6,939'MD TO 9,855'MD WITH 4" DRILL PIPE. -ACQUIRE SLOW CIRCULATING RATES AT 9,855'MD USING 9.8 PPG BRINE. 04:00 - 07:30 3.50 CLEAN P DECOMP WASH DOWN WITH 4"DRILL PIPE. -TAG FILL AT 9,855'MD,WASH DOWN TO 10,049'MD. PUMP AT 7 BPM=1,720 PSI. UP WT=93K,DOWN WT=64K. -WASH STANDS DOWN TO 11,024'.LOSSES EXTREME. -150 BBLS LEFT IN THE PITS,(3)TRUCKS HAULING,LOSS RATE PUMPING OFF BOTTOM @ 2 BPM=94 BPH. Printed 12/15/2014 3:02:10PM • • North America-ALASKA-BP Page 10 of 15 Operation Summary Report Common Well Name:MPI-12 AFE No Event Type:WORKOVER(WO) Start Date:11/24/2014 ' End Date:12/5/2014 X4-010Q5-E:(1,200,000.00) Project:Milne Point Site:M Pt I Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/7/2001 12:00:00AM Rig Release:12/5/2014 Rig Contractor:DOYON DRILLING INC. OM:500292303800 Active datum:MPI-12:©63.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth j Phase Description of Operations (hr) (usft) _ 07:30 - 12:00 4.50 CLEAN N DPRB DECOMP CALL TOWN,DECISION MADE TO KEEP GOING AS WE HAVE BEEN. -CIRCULATE 60'OFF TOP OF FILL,1 BPM 02 1300 PSI,VERY LITTLE RETURNS. -WAIT ON BRINE FROM 38 BPH LOSS RATE W/WAITING. -O/A=160 PSI,LOSSES LAST(12)HRS=750 BBLS OF 9.8 PPG VISCOSIFIED BRINE. 12:00 - 14:00 2.00 CLEAN N DPRB DECOMP PJSM.CONTINUE TO CIRCULATE AT 10,964' MD. -WAIT ON BRINE AND GET ANOTHER TRUCK HAULING. 14:00 - 18:30 4.50 CLEAN P DECOMP PJSM.PITS FULL AND(1)TRUCK RIGGED UP DIRECTLY TO MUD PUMP. -CONTINUE WASHING DOWN FROM 11,024', WT TRANSFER GETTING SKETCHY. -VARY PUMP RATES TO WASH DOWN, STACKING WT FROM TIME TO TIME. -LOSS RATE VARIES WITH PUMP RATE. -WASH DOWN PUMPING AT 2-6 BPM= 750-2,150 PSI. -WASH DOWN TO 12,045'MD,COULD NOT GO FURTHER.PUW=115K,SOW=45K. MONITOR WELL FOR(10)MINUTES.STATIC. 18:30 - 22:00 3.50 CLEAN P DECOMP PJSM.POOH WITH CLEAN OUT STRING. -PUMP OUT OF HOLE FROM 10,045'MD TO 9,861'MD.STANDING BACK DP IN DERRICK -PUMP AT 2 BPM=1,200 PSI. -ACQUIRE SLOW CIRCULATING RATES. 22:00 - 23:30 1.50 CLEAN P DECOMP PJSM.SLIP AND CUT DRILL LINE. -CLEAR AND CLEAN RIG FLOOR. -CUT 60'OF DRILL LINE. 23:30 - 00:00 0.50 CLEAN P DECOMP PJSM.CONTINUE POOH 1MTH CLEAN OUT STRING. -PULLING OUT WET,MUST PUMP OUT OF HOLE. -POOH FROM 9,861'MD TO 9,672'MD.PUW= 105K,SOW=65K.UD DP 1 X 1 TO SHED. 1-O/A=160 PSI,LOSSES LAST(24)HRS= 1,135 BBLS OF 9.8 PPG VISCOSIFIED BRINE. 12/2/2014 00:00 - 00:30 0.50 CLEAN P DECOMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS -CHECK CROWN-O-MATIC.OK. 00:30 - 06:00 5.50 CLEAN P DECOMP PJSM.CONTINUE POOH WITH CLEAN OUT. STRING. -PULLING OUT WET,MUST PUMP OUT OF HOLE. -POOH FROM 9,672'MD TO 7,200'MD. -PUMPING OUT OF HOLE AS BRINE IS VERY VISCOUS AND WILL NOT FALL IN DRILL PIPE/ TUBING. -IF WE PULL W/O PUMPING,HOLE FILL IS LESS THAN IT SHOULD BE.ODE NOTIFIED. -PUMP 25 BBLS 11.1 PPG DRY JOB.STILL PULLING WET. -CONTINUE TO PUMP OUT OF HOLE. Printed 12/15/2014 3:02:10PM • • North America-ALASKA-BP Page 11 of 15 Operation Summary Report Common Well Name:MPI-12 AFE No Event Type:WORKOVER(WO) Start Date:11/24/2014 End Date:12/5/2014 X4-010Q5-E:(1,200,000.00) Project:Milne Point Site:M Pt I Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/7/2001 12:00:00AM Rig Release:12/5/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292303800 Active datum:MPI-12:©63.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 08:30 2.50 CLEAN P DECOMP PIPE STARTED PULLING DRY. -DOUBLE CHECK HOLE FILL AFTER PULLING (10)JTS,HOLE FILL CORRECT. -CONTINUE TO POOH AND LAY DOWN 4" DRILL PIPE. -CHANGE OUT ELEVATORS. 08:30 - 12:00 3.50 CLEAN P DECOMP PJSM.POOH AND LAY DOWN 2-7/8"EUE 8RD TUBING. -POOH FROM 6,539'MD TO 4,139'MD.PUW= 60K,SOW=50K. -CONTINUOUS HOLE FILL,LOSING A VERY SLIGHT AMOUNT OF FLUID,(DISPLACEMENT IS 0.2 BBLS OVER CALCULATED W/30 JTS OUT). FLUID LOSS(12)HOURS=68 BBLS 9.8 PPG BRINE. OA=160 PSI. 12:00 - 12:30 0.50 CLEAN P DECOMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS CHECK CROWN-O-MATIC.OK. 12:30 - 16:30 4.00 CLEAN P DECOMP PJSM.CONTINUE POOH WITH AND LAY DOWN 2-7/8"EUE 8RD TUBING. POOH FROM 4,139'MD TO 3,100'MD.PUW= 59K,SOW=51K. -POOH AND LAY DOWN 2-7/8"FOX TUBING. -POOH FROM 3,100'MD TO SURFACE. 16:30 - 18:00 1.50 CLEAN P DECOMP PJSM.RIH WITH 4"DP STANDS FROM DERRICK. -RIH FROM SURFACE TO 914'MD. 18:00 - 21:00 3.00 CLEAN P DECOMP PJSM.POOH AND LAY DOWN 4"DP TO SHED. POOH FROM 914'MD TO SURFACE. 21:00 - 22:30 1.50 CLEAN P DECOMP CLEAR ND CLEAN RIG FLOOR,IRON ROUGHNECK,TONGS,SLIPS AND ELEVATORS. -PULL WEAR RING. 22:30 - 00:00 1.50 RUNCOM P RUNCMP PJ.SM-3/1LTQ R(J11 'COMPLETION. -M/U FLOOR VALVE. -CHANGE OUT SLIPS/ELEVATORS. -P/U CENTRILIFT TOOLS TO RIG FLOOR. -HANG ESP SHEAVE IN DERRICK. FLUID LOSS(24)HOURS=98 BBLS 9.8 PPG BRINE. OA=150 PSI. 12/3/2014 00:00 - 01:30 1.50 RUNCOM P RUNCMP PTSM.PULL MOTOR LEAD ESP TO RIG FLOOR. 01:30 - 08:00 6.50 RUNCOM P RUNCMP PJSM.P/U AND SERVICE ESP MOTOR ASSEMBLY. -M/U RECEIVING ASSEMBLY. -INSTALL MOTOR LEAD TO MOTOR/SEAL ASSEMBLY. 08:00 - 10:00 2.00 RUNCOM N WAIT RUNCMP WAIT ON CENTRILIFT FOR FLAT GUARDS. 10:00 - 11:00 1.00 RUNCOM N SFAL RUNCMP PJSM.REMOVE PROTECTOLIZERSAND INSTALL CANNON CLAMPS ONLY ON MOTOR/SEAL ASSEMBLY. Printed 12/15/2014 3:02:10PM • North America-ALASKA-BP Page 12 of 15 Operation Summary Report Common Well Name:MPI-12 AFE No Event Type:WORKOVER(WO) Start Date:11/24/2014 End Date:12/5/2014 X4-010Q5-E:(1,200,000.00) Project Milne Point Site:M Pt I Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/7/2001 12:00:00AM Rig Release:12/5/2014 Rig Contractor:DOYON DRILLING INC. UVN:500292303800 Active datum:MPI-12:©63.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 12:00 1.00 RUNCOM P RUNCMP CENTRILIFT TERMINATE I-WIRE AND TEST. FLUID LOSS(12)HOURS=21 BBLS 9.8 PPG BRINE. OA=160 PSI. 12:00 - 13:30 1.50 RUNCOM P RUNCMP PJSM.PRESSURE TEST TECH WIRE TO 5,000 PSI.GOOD TEST. '-PERFORM CONDUCTIVITY TEST ON ESP CABLE.GOOD. 13:30 - 15:00 1.50 RUNCOM P RUNCMP PJSM.RIH WITH 3-1/2"9.3#L-80 EUE 8RD ESP COMPLETION. '-USING BEST-O-LIFE 2000 PIPE DOPE. -TORQUING EACH CONNECTION TO 2,550 FT-LBS. -FILLING TUBING EVERY 15 JOINTS. -RIH FROM SURFACE TO 1,000'MD. -CHECK CONDUCTIVITY -1,000'MD. 15:00 - 15:30 0.50 RUNCOM . P RUNCMP PJSM.CIRCULATE TUBING WITH 9.8 PPG BRINE.(NON-VIS) -R/U HEAD PIN. -PUMP 9.8 PPG BRINE DOWN TUBING. -ACQUIRE SLOW CIRCULATING RATES. -PERFORM CONDUCTIVITY TEST ON ESP CABLE.GOOD. 15:30 - 22:00 6.50 RUNCOM P RUNCMP PJSM.R/U SWS SLICKLINE AND EQUIPMENT TO INSTALL TTC-ESPCP. 1-RUN#1:TTC-ESPCP. 1-RUN#2:D&D PACKOFF ASSEMBLY. -RUN#3:INSTALL PRESSURE TEST TOOL. -PRESSURE TEST TO 250 PSI LOW,1,000 PSI i HIGH FOR 15 CHARTED MINUTES.GOOD TEST. -RUN#4:RETRIEVE PRESSURE TEST TOOL -RUN#5:RUN D&D TUBING STOP ASSEMBLY. 22:00 - 00:00 2.00 RUNCOM P RUNCMP PJSM.RIH WITH 3-1/2"9.3#L-80 EUE 8RD ESP COMPLETION. -USING BEST-O-LIFE 2000 PIPE DOPE. -TORQUING EACH CONNECTION TO 2,550 1 FT-LBS. -FILLING TUBING EVERY 15 JOINTS. -CHECKING CONDUCTIVITY EVERY-2,000' MD. RIH FROM 1,000'MD TO 2,247'MD.PUW= 60K,SOW=56K. -NO OPERATIONS WITH SLOW CIRCULATING RATES.CAN NOT PUMP THROUGH ESPCP. FLUID LOSS(24)HOURS=21 BBLS 9.8 PPG BRINE. OA=150 PSI. 12/4/2014 00:00 - 00:30 0.50 RUNCOM P RUNCMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS -CHECK CROWN-O-MATIC.OK. Printed 12/15/2014 3:02:10PM North America-ALASKA-BP Page 13 of 15 Operation Summary Report Common Well Name:MPI-12 AFE No Event Type:WORKOVER(WO) Start Date:11/24/2014 End Date:12/5/2014 X4-010Q5-E:(1,200,000.00) Project:Milne Point Site:M Pt I Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/7/2001 12:00:00AM Rig Release:12/5/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292303800 Active datum:MPI-12:@63.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00:30 - 10:30 10.00 RUNCOM P RUNCMP PJSM.RIH WITH 3-1/2"9.3#L-80 EUE 8RD ESP COMPLETION. -USING BEST-O-LIFE 2000 PIPE DOPE. -TORQUING EACH CONNECTION TO 2,550 FT-LBS. -FILLING TUBING EVERY 15 JOINTS. -CHECKING CONDUCTIVITY EVERY-2,000' MD. -RIH FROM 2,247'MD TO 7,368'MD. 10:30 - 12:00 1.50 RUNCOM P RUNCMP CENTRILIFT PERFORM CONDUCTIVITY TEST. -PERFORM REEL TO REEL SPLICE. -NO OPERATIONS WITH SLOW CIRCULATION RATES. FLUID LOSS(12)HOURS=65 BBLS 9.8 PPG BRINE. OA=160 PSI. 12:00 - 15:00 3.00 RUNCOM P RUNCMP CENTRILIFT CONTINUE REEL TO REEL SPLICE. 15:00 - 16:00 1.00 RUNCOM P RUNCMP PJSM.RIH WITH 3-1/2"9.3#L-80 EUE 8RD ESP COMPLETION. USING BEST-O-LIFE 2000 PIPE DOPE. -TORQUING EACH CONNECTION TO 2,550 FT-LBS. FILLING TUBING EVERY 15 JOINTS. -CHECKING CONDUCTIVITY EVERY-2,000' MD. -RIH FROM 7,368'MD TO 7,987'MD. 16:00 - 20:00 4.00 RUNCOM N HMAN RUNCMP CENTRILIFT PERFORM CONDUCTIVITY TEST. -PERFORM REEL TO REEL SPLICE. 20:00 - 22:00 2.00 RUNCOM P RUNCMP PJSM.RIH WITH 3-1/2"9.3#L-80 EUE 8RD ESP COMPLETION. -USING BEST-O-LIFE 2000 PIPE DOPE. -TORQUING EACH CONNECTION TO 2,550 FT-LBS. -FILLING TUBING EVERY 15 JOINTS. -CHECKING CONDUCTIVITY EVERY-2,000' MD. -RIH FROM 7,987'MD TO 9,551'MD.PUW= 103K,SOW=50K. 22:00 - 00:00 2.00 RUNCOM P RUNCMP PJSM.TERMINATE ESP CABLE AT HANGER. -P/U LANDING JOINT AND MAKE UP TO HANGER. -INSTALL PENETRATOR AND TERMINATE ESP CABLE. -PULL REMAINING ESP CABLE BACK TO SPOOLING UNIT. -R/D ESP SHEAVE. FLUID LOSS(24)HOURS=38 BBLS 9.8 PPG BRINE. OA=150 PSI. 12/5/2014 00:00 - 01:30 1.50 RUNCOM P RUNCMP PTSM.CONTINUE TERMINATE ESP CABLE AT HANGER. -CLEAR AND CLEAN RIG FLOOR. 01:30 - 02:30 1.00 RUNCOM P RUNCMP PJSM.LAND TTC-ESPCP COMPLETION. -FINAL PUW=107K,SOW=57K. -FMC REPRESENTATIVE RILDS. L/D LANDING JOINT. 02:30 - 03:00 0.50 BOPSUR P RUNCMP PJSM.INSTALL TWC. -DRY ROD IN TWC. Printed 12/15/2014 3:02:10PM North America-ALASKA-BP Page 14 of 15 Operation Summary Report Common Well Name:MPI-12 AFE No Event Type:WORKOVER(WO) Start Date:11/24/2014 End Date:12/5/2014 X4-010Q5-E:(1,200,000.00) Project:Milne Point Site:M Pt I Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/7/2001 12:00:OOAM Rig Release:12/5/2014 Rig Contractor:DOYON DRILLING INC. UW:500292303800 Active datum:MPI-12:©63.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 03:30 0.50 BOPSUR P RUNCMP PRESSURE TEST TWC. -PERFORM ROLLING TEST FROM BELOW TO 500 PSI FOR 5 CHARTED MINUTES.GOOD TEST. PRESSURE TEST FROM ABOVE TO 250 PSI LOW,3,500 PSI HIGH FOR 5 CHARTED MINUTES.GOOD TEST. 03:30 - 08:00 4.50 BOPSUR P RUNCMP PJSM.R/D SURFACE EQUIPMENT. -CLEAN ALL RIG FLOOR EQUIPMENT AND HANDLING EQUIPMENT OF BRINE RESIDUE. -FLUSH KILL,CHOKE,CHOKE MANIFOLD AND 'TOP DRIVE WITH FRESH WATER. -FUNCTION ALL RAMS AND WASH DOWN. -VACUUM OUT STACK. -N/D RISER AND MOUSE HOLE. 08:00 - 09:30 1.50 BOPSUR P RUNCMP PJSM.N/D 13-5/8"FOUR PREVENTER BOPE. -REMOVE ACCUMULATOR LINES,CHOKE AND KILL LINES. -SET BACK BOPE ON STUMP. 09:30 - 12:00 2.50 WHSUR P RUNCMP N/U TUBING HEAD ADAPTER AND TREE. i-FMC TEST VOID TO 250 PSI LOW,5,000 PSI HIGH FOR 30 MINUTES.GOOD TEST. CENTRILIFT PERFORM FINAL CHECKS ON ESP CABLE.GOOD TEST. FLUID LOSS(12)HOURS=0 BBLS 9.8 PPG BRINE. OA=160 PSI. 12:00 - 16:00 4.00 WHSUR P RUNCMP PJSM.PULL TWC AND INSTALL BPV. -R/U TEST EQUIPMENT AND LUBRICATOR TO TREE. -PRESSURE TEST LUBRICATOR AND TREE TO 250 PSI LOW,5,000 PSI HIGH FOR 5 MINUTES.GOOD TEST. -PULL TWC. -PRESSURE TEST LUBRICATOR TO 250 PSI LOW,3,500 PSI HIGH FOR 5 MINUTES.GOOD TEST. -SET BPV. -R/D LUBRICATOR. 16:00 - 18:00 2.00 WHSUR P RUNCMP PJSM.FREEZE PROTECT WELL WITH LRS. -R/U LRS AND PRESSURE TEST LINES TO 250 PSI LOW,3,500 PSI HIGH.GOOD TEST. -CIRCULATE DOWN TUBING AT 1 BPM=600 PSI. -NOTED CRUDE AT SLOP TANK AFTER—5 BBLS PUMPED AWAY.RECOVERED—85 BBLS OF CRUDE IN SLOP TANK. -PERFORM ROLLING TEST FROM BELOW BPV AT 500 PSI FOR 10 MINUTES.GOOD TEST. Printed 12/15/2014 3:02:10PM North America-ALASKA-BP Page 15 of 15 Operation Summary Report Common Well Name:MPI-12 AFE No Event Type:WORKOVER(WO) Start Date:11/24/2014 End Date:12/5/2014 X4-010Q5-E:(1,200,000.00) Project:Milne Point Site:M Pt I Pad Rig Name/No.:DOYON 16 Spud Date/Time:10/7/2001 12:00:00AM Rig Release:12/5/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292303800 Active datum:MPI-12:©63.40usft(above Mean Sea Level) Date From-To Hrs Task Code NPT !: NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 21:00 3.00 WHSUR P RUNCMP PJSM.LOWER DERRICK. -BRIDLE UP BLOCKS AND READY FLOOR FOR RIG MOVE. SECURE RIG FLOOR,LOWER CATTLE CHUTE. -UNPIN AND LOWER DERRICK ONTO DERRICK STAND. -MOVE CREW TRAILER AND SLOP TANK -RAISE CELLAR DOORS. RELEASE DOYON 16 FROM MPI-12 AT 21:00 HRS ON 12/5/2014 FOR MOVE TO DS 15-24. Printed 12/15/2014 3:02:10PM e ~ Milne Point Unit Well: MPU 112L1 SCHEMATIC Last Completed: 12/5/2014 H;Icorn, Ia ka,1,1,1PTD: 201-164 CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm RKB Eley=64.7' 20" Conductor 92/H-40/Welded N/A Surf 108' 10-3/4" Surface 45.5/L-80/Btrc. 9.794 Surf 2,906' 7" Intermediate 26/L-80/Btc-Mod 6.151 Surface 10,228' 20' 4-1/2" Liner"A" 12.6/L-80/IBT 3.833 9,936' 12,393' . Itil 4-1/2" Liner"B" 12.6/L-80/IBT 3.833 10,164' 12,396' 3.833 9,980' 12,393' 1 TUBING DETAIL n 3-1/2" Tubing I 9.3/L-80/EUE 8rd 2.867 Surf 9,582' LINER DETAIL 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.833 9,936' 9,980' ` 4-1/2" OA Slotted Lnr 12.6/L-80/IBT � 2 4-1/2" OB Solid Liner 12.6/L-80/IBT 3.833 10,164' 10,373' 4-1/2" OB Slotted Lnr 12.6/L-80/IBT 3.833 10,373' 12,396' 10-3/4".4 2_(,�C4 JEWELRY DETAIL No Depth Item 1 201' GLM 3.5"x 1"Camco KBMG w/Orifice Valve&BK Latch 2 2,485' GLM 3.5"x 1"Camco KBMG w/Open/Empty Pocket 3 9,493' 3.5"Well Lift Discharge Gauge Unit 4 9,555' Tandem Seal Section q0 , O 5 9,570' Motor 562MSP1,84hp,2,210 v/23 amp ffryy ( y„1 6 9,579' Well lift MGU Gauge J 7 9,581' Centralizer-Bottom @ 9,582' 8 9,627' Baker Hook Wall,Hanger above 7"Window L7fi7,' 9 9,642' Baker Hook Wall,Hanger below 7"Window 10 9,650' Baker Tension Lock Swivel 11 9,906' Baker Tie Back Sleeve 12 9,928' Baker ZXP Liner Top Packer 13 9,930' Baker 7"x 5"HMC Liner Hanger 14 10,116' Btm 4-1/2"Pack-off Bushing 15 10,128' Btm 4-1/2"Guide Shoe 16 10,147' Btm Baker Pack-off Bushing 17 12,395' Btm Baker 4-1/2"Guide Shoe 3 o,,tOG LATERAL WINDOW DETAIL II Top of"OA"Window @ 9,916'MD;Bottom @ 9,928'MD;Angle @ top of window is 8odeg Top of"OB"Window @ 10,228'MD;Bottom @ 10,240'MD;Angle @ top of window is 87 deg „ WELL INCLINATION DETAIL ii ¶4 KOP@300'MD Max Wellbore Angle=85.5 deg @ 8,102'MD ,i , 63.74 deg @ 2,550'MD $ 5 OPEN HOLE/CEMENT DETAIL 6 20" Cmt w/650 sx of Arcticset I in 30"Hole 1 7 'i 10-4/4" Cmt w/585 sx AS Lite,502 sx Class"G"in 13-1/2"Hole i 7 7" Cmt w/1,172 sx Class"G"in 9-7/8"Hole G WELLHEAD Wellhead FMC Tubing Hanger,11"x 4-1/2"TC-ll Top& Bottom GENERAL WELL INFO . g API:50-029-23038-60-00 9 Drilled and Cased by Nabors 4-ES -12/8/2001 10 14 NOTES: „�Latey 'I.---/Ar Need Cementing Report to Establish Tops l"*.; 15 I'" 1/ Need Casing&Tubing Tallies 12 - I ,� 13 \... ..,,_ O6'Lateral 7' Ng17 TD=12,470'(MD)/TD=3,712'(TVD) PBTD=12,470'(MD)/PBTD=3,712'(TVD) Created By:TDF 12/19/2014 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder SLANNEOVEB Alaska Oil and Gas Conservation Commission P 1 — 1 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPI -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPI -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 1 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPI -Pad 10/9/2011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement _ pumped cement date inhibitor sealant date ft bbls ft gal i MPI -01 1900900 50029220650000 0.1 NA 0.1 NA 8.5 9/5/2011 MPI -02 1900910 50029220660000 Sealed coductor NA NA NA NA NA MPI-03 1900920 50029220670000 Sealed coductor NA NA NA NA NA MPI-04A 2010920 50029220680100 Sealed coductor NA NA NA NA NA MPI-05 1951200 50029225830000 2.7 NA 2.7 NA 27.2 11/2/2009 MPI-06 1971950 50029228220000 Open Flutes - Treated NA NA MPI -07 1951510 50029226020000 1.7 NA 1.7 NA 16.2 8/21/2011 MPI-08 1971920 50029228210000 1.3 NA 1.3 NA 15.3 11/2/2009 MPI-09 2001030 50029229640000 1.3 NA 1.3 NA 13.6 11/1/2009 MPI -10 2001090 50029229660000 Open Flutes - Treated NA NA MPI -11 2011370 50029230330000 1.3 NA 1.3 NA 10.2 8/19/2011 -- 1 1 ' MPI -12 2011630 50029230380000 0.2 NA 0.2 NA 7.7 10/9/2011 MPI -13 2010750 50029230120000 0.85 NA 0.85 NA 8.5 9/5/2011 MPI -14 2041190 50029232140000 1.9 NA 1.9 NA 16.2 8/23/2011 MPI -15 2021520 50029231060000 1 NA 1 NA 9.4 8/19/2011 MPI -16 2041580 50029232210000 1.75 NA 1.75 NA 17.0 8/19/2011 MPI -17 2040980 50029232120000 1.75 NA 1.75 NA 13.6 8/23/2011 MPI -19 2041350 50029232180000 1.4 NA 1.4 NA 10.2 8/19/2011 STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI N REPO~OF SUNDRY WELL OPERA NS 1, Operations Performed: ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension Replace failed ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit T~ Drill Number: \ BP Exploration (Alaska) Inc. ®Development ^ Exploratory 201-163 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 SO-029-23038-00-00 7. Property Designation: '~ 8. Well Name and Number. ADL # 025906 & 025517 MPI-12 9. Field /Pool(s): Milne Point Unit / Schrader Bluff 10. Present well condition summary Total depth: measured 12470 feet true vertical 3712' feet Plugs (measured) None Effective depth: measured 12470 feet Junk (measured) None true vertical 3712' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 108' 108' 1490 470 Surtace 2878' 10-3/4" 2906' 2408' 5210 2480 Intermediate 10201' 7" 10228' 3706' 7240 5410 Production Liner 2313' 4-1/2" 10128' - 12441' 3691' - 3714' 8430 7500 [•• Perforation Depth: Measured Depth: 10374' - 12397' True Vertical Depth: 3710' - 3715' Tubing (size, grade, measured and true vertical depth): 2-7/8", 6.5# L-80 9654' 3599' Packers and SSSV (type, measured and true vertical depth): None 11. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~a~~ i~~L. Treatment description including volumes used and final pressure: . ~ ~~ ~~~ CttSSt011 ' ~,raska~ + ~,~Ch#lCd~ 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ^ Copies of Logs and Surveys run 14. Well Class after work: ^ Exploratory ®Development ^ Service erations il R rt f Well O ® D epo p a y o ® Well Schematic Diagram 15. Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Mackie Derrick, 564-5891 N/A Printed Name Terrie Hubble Title Drilling Technologist ~ Prepared ey Name/Number. Signature Phone 564-4628 Date ~Terrie Hubble, 564-4628 Form 10-404 Revi~i~001~ 5ubmd Original Only VVIIYYFFa~~ ~u~. 2 s ~~~~ ~- ~-Z ~ , o L~ North America -ALASKA - BP Page 1 of i Operation Summary Report __ __ _ __ Common Well Name: MPI-12 DIMS AFE No Event Type: MOBILIZATION (MOB) Start Date: 6/23/2010 End Date: X4-0009D-E (75,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 10/7/2001 12:0O:OOAM Rig Release: 6/30/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: MPI-12: @63.4ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) - -- 6/24/2010 02:00 - 05:30 i 3.50 MOB P PRE PREP RIG FOR MOVE TO MP I-12. SCOPE AND LD DERRICK, RD LINES ON PITS __ 05:30 - 07:30 2.00 MOB N _ WAIT PRE WAIT ON TRUCKS. -PEAKS DRIVERS WERE TIMED OUT. -HAD TO WAIT FOR THEM TO GET SOME SLEEP BEFORE RIG MOVE COULD START. 07:30 - 09:30 2.00 MOB P PRE,` RDMO TO MPI-12 -SUBBASE WAS PULLED OFF OF WELL AT 08:45 -RIG WAS OFF OF LOCATION AT 09:30 09:30 10:00 0.50 MOB P __ PRE MOVE RIG ALONG MPS. PAD ACCESS RD TO MILNE POINT SPINE RD. 10:00 - 11:00 1.00 MOB N WAIT PRE WAIT AT INTERSECTION OF MPS PAD ACCESS RD AND MILNEPOINTSPINE RD. -MPU CALLED AND ASKED US TO HOLD THERE UNTIL THEY CALLED. THEY WERE STARTING A TURBINE AND WANTED THE ROAD CLEAR IN CASE OF EMERGENCY. 11:00 - 16:00 5.00 MOB P PRE CONTINUE TO MOVE RIG TO MPI PAD. -RIG ON MPI PAD AT 16:00. ----- -- 16:00 - 18:00 2.00 MOB P PRE ' SPOT SUB ON WELL USING ONE LAYER OF MATTING BOARDS. _ 18:00 - 21:00 3.00 MOB P PRE SPOT PITS AND PIPE SHED. 21:00 - 00:00 3.00 MOB P' PRE RAISE & SCOPE DERRICK. RU LINES TO TREE AND TO TIGER TANK. 6/25/2010 ~ 00:00 - 01:00 1.00 MOB P PRE FILL PIT WITH 8.7 PPG BRINE. CONTINUE TO RU ~ LINES TO TREE. ACCEPT RIG AT 01:00 HOURS. Printed 7/19/2010 11:48:20AM • • North America -ALASKA - BP Page 1 or ~ Operation Summary Report __ Common Well Name: MPI-12 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 6/25/2010 End Date: 7/1/2010 X4-OOQ9D-E (375,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 10/7/2001 12:0O:OOAM Rig Release: 6/30/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: MPI-12: @63.4ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 6/25/2010 01:00 - 02:30 1.50 _ KILLW P DECOMP FILL PITS WITH 110 DEGREE 8.7 PPG BRINE. _ CONTINUE TO RU LINES TO TREE. _ 02:30 - 03:30 1.00 KILLW P DECOMP RU LUBRICATOR AND TEST TO 500 PSI. PULL $PV. 200 PSI TRAPPED. 03:30 - 04:00 0.50 KILLW P DECOMP PJSM WELL KILL. 04:00 - 09:00 5.00 KILLW P DECOMP INITIAL TUBING PRESSURE 90 PSI, ANNULAR PRESSURE 970 PSI. -CIRCULATE 1000 STROKES (-59 BBLS) DOWN THE TUBING. 1 - 3 BPM @ 220 - 460 PSI. -SHUT fN AND BULLHEAD LINERS WITH AN ADDITIONAL 2000 STROKES (-118 BBLS);. - OPEN THE CHOKE AND. CONTINUE TO CIRCULATE 2- 4 BPM @ 470 - 1500 PSI. UNTIL RETURNS CLEAN UP. - 330 BBLS -PUMPED A TOTAL OF 507 BBLS. -SHUT IN AND MONITOR WELL. TBG = 50 PSI, IA = 50 PSI. 09:00 - 13:00 4.00 KILLW P __ OECOMP CIRCULATE THROUGH THE GAS BUSTER. - 2 BPM @ 280 PSI. - PUMPED 380 STROKES (-22 BBLS). - NO LOSS. SHUT IN AND MONITOR WELL -TBG = 50 PSI, IA = 50 PSI. BLEED OFF TBG FOR 5 MINUTES AND THEN SHUT IN AND OBSERVE FOR 15 MINUTES. -THIS PROCESS WAS REPEATED FOR 1.5 HRS. - A TOTAL OF 7 BBLS WAS BLED OFF IN 1 TO 0.25 BBL INCREMENTS UNTIL THE WELL WAS STATIC. 13:00 - 14:30 1.50 KILLW P DECOMP MONITORED WELL WHILE RWO SUPERINTENDANT AND RWO ENGINEER WERE APPRAISED OF THE SITUATION. AFTER SOME DISCUSSION THE DECISION WAS MADE TO WEIGHT UP TO 9.1 PPG TO MAKE SURE THAT ~ WE WERE OPERATING WITH AT LEAST A 75 PSI ~ _ _ OVERBALANCE. 14:30 - 19:30 5.00 KILLW X FLUD DECOMP WAIT ON TRUCK WITH 290 BBLS OF 9.9 PPG SPIKE FLUID TO INCREASE WEIGHT OF BRINE IN PITS TO 9.1 PPG. D-5 DRILL (KILL DRILL) -WHILE WAITING FOR TRUCKS RIG CREWS SPOTTED AND RU THE SPOOLING UNIT, PU ~ TUBING RUNNING EQUIPMENT AND SERVICED RIG. _ 19:30 21:00 1.50 _ KILLW X FLUD _ DECOMP BLEND 9.9 WITH 8.7 TO YIELD 9.1 PPG BRINE. Printed 7/19/2010 11:48:52AM North America -ALASKA - BP P'~e z or ~~ Operation Summary Report Common Well Name: MPI-12 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 6/25/2010 End Date: 7/1/2010 X4-OOQ9D-E (375,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 10/7/2001 12:0O:OOAM Rig Release: 6/30/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: MPI-12: @63.4ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ~ (ft) _-- _ 21:00 - 00:00 ~ 3.00 KILLW X FLUD DECOMP CIRCULATE 56 BBL OF 9.1 BBP BRINE THRU TUBING @ 4 BPM 1130 PSI. SHUT IN AND BULLHEAD 60 BBL TO FORMATION @ 2 BPM 670 PSI. CIRCULATE 9.1 PPG BACK TO SURFACE 4`BPM AT 1050 PSI. LOST 15 BBL TO FORMATION. 6/26/2010 00:00 - 01:30 1.50 KILLW _ P DECOMP INITIAL SHUT IN PRESSURE 60 PSI TUBING AND 30 PSI ANNULUS. BLEED OF TO FORMATION IN 35 MINUTES TO 10 PSI TUBING 0 PSI ANNULUS. ~ BLEED OF TUBING PRESSURE. MONITOR WELL. 01:30 - 03:00 1.50 WHSUR P DECOMP ~ TWC WITH DRY ROD. TEST TWC FROM ABOVE TO'3500 PSI CHARTED FOR 10 MINUTES. CONDUCT ROLLING TEST BELOW TWC TO 500 PSI @ 4 BPM: CHART TEST FOR 10 MINUTES. 03:00 - 04:00 1.00 WHSUR P _ DECOMP ND TREE AND ADAPTER FLANGE. 04:00 - 05:30 1.50 WHSUR P DECOMP NU_BOR 05:30 - 06:00 0.50 WHSUR P DECOMP RU TEST EQUIPMENT. SERVICE CHOKE MANIFOLD. ~ 08:00 - 09:00 1.00 WHSUR P DECOMP FUNCTION TEST BOP. D-4 DRILL -- --- -- 09:00 - 09:30 0.50 WHSUR P DECOMP PU TEST TOOLS. 09:30 - 10:00 0.50 WHSUR P DECOMP FILL IA WITH 9 BBL. 10:00 - 11:00 1.00 WHSUR P DECOMP REBUILD SENSORS. PURGE LINES. FLUSH AIR FROM STACK. 11:00 - 15:30 4.50 WHSUR P DECOMP TEST BOP 2.50/ 3500 PSLT~ST BLINDS, CHOKE MANIFOLD, CHOKE & KILL LINE VALVES, FLOOR VALVE,2-7/8 X 5 VBR'S, & ANNULAR WITH 2-7/8 TEST JOINT. AOGCC WITNESSING OF TEST WAIVED BY LOU GRIMALD @ 08:40 6-25-2010 ~ TEST WITNESSED BY BP WSL AND NABOR'S TP PERFORM KOOMEY TEST i 200 PSI BUILDUP TO 1900 PSI FROM 1700 PSI = I 41 SECONDS FULL BUILDUP TO 3000 PSI = 172 SECONDS 4 BOTTLES X 2100 PSI 15:30 - 16:00 0.50 ~ _ WHSUR P DECOMP LD TEST TOOLS 16:00 - 18:00 2.00 i PULL P DECOMP RU LUBRICATOR AND TEST TO 500 PSI. PULL TWC _ 18:00 - 18:30 0.50 REST P _ DECOMP LD DUTCH SYSTEM. PU LANDING JOINT AND BOLDS. 18:30 - 19:00 0.50 PULL P DECOMP PULL HANGER TO FLOOR. PU WT 40K SO WT 20K. LD HANGER. 19:00 - 20:30 1.50 PULL P __ DECOMP FILL WELL WITH 5 BBL. CIRCULATE WELL ~ SBPM @ 1320PSI. TOTAL 5600 STROKES ~ PUMPED. LOST 35 BBL TO FORMATION. ~ 20:30 - 21:00 0.50 _ PULL P _ DECOMP FLOW CHECK WELL. NO FLOW. 21:00 - 22:30 1.50 PULL P DECOMP CUT AND SLIP 90' OF DRILL LINE. 22:30 - 00:00 1.50 PULL P DECOMP PULL 2-7/8 COMPLETION. 6/27/2010 00:00 06:00 6.00 PULL P DECOMP CONTINUE TO POOH W/ 2 7/8" COMPLETION STRING. CONTINUOUS HOLE FILL. LD JOINT 148. ~oP Printed 7/19/2010 11:48:52AM r~ North America -ALASKA - BP Page a ~r s Operation Summary Report Common Well Name: MPI-12 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 6/25/2010 ~ End Date: 7/1/2010 X4-0009D-E (375,000.00 ) -{- ~ - Project: Milne Point ~ Site: M Pt I Pad Rig Name/No.: NABORS 4ES ~ Spud Date/Time: 10/7/2001 12:0O:OOAM Rig Release: 6/30/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: MPI-12: @63.4ft (above Mean Sea Level) Date From - To Hrs Task Code ~ NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 07:00 1.00 PULL P DECOMP CREW CHANGE - SERVICE BLOCKS AND DRAWWORKS -ENVIRONMENTAL WALKAROUNDS -CHECK AND SET PVT ALARMS ~ -DERRICK INSPECTION DISCUSSED POTENTIAL DROPPED OBJECTS .DURING. PRETOUR MEETING. THERE IS A LOOSE 1 ".'DUMMY GLV IN THE STRING THAT WAS KNOCKED OUT PRE-RIG. __ 07:00 - 08:00 1.00 PULL P _ DECOMP CONTINUE.TO POOH W/ 2-7/8" ESP COMPLETION. - LD 2-7/8" L-80, EUE 8RD TUBING. ON JOINT #t80 AT 08:00. ' -CURRENT LOSS RATE°= 9 BPH + DISPLACEMENT. -CONTINUOUS HOLE FILL. - ---------- 08:00 - 14:00 6.00 - PULL P - bECOMP CONTINUE TO' POOH W/ 2-7/8" ESP COMPLETION. ~ j - LD 2-7/8" L-80, EUE 8RD TUBING. -LOSS RATE - 9 BPH + DISPLACEMENT. ' ~ -CONTINUOUS HOLE FILL. -D1 TRIP DRILL -D5 KILL DRILL ' -RECOVERED DUMMY GLM FROM TOP OF PUMP. 14:00 - 16:00 2.00 PULL P DECOMP PULL AND LD PUMP ASSEMBLY. ----- 16:00 - 19:00 I 3.00 PULL. P DECOMP CLEAN RIG FLOOR. LOAD PIPE SHED. 19:00 00:00 5.00 PULL P DECOMP CONTINUE TO LOAD ,DRIFT AND TALLY 2-718 EUE 8RD TUBING. __ 6/28/2010 00:00 - 02:00 j 2.00 RUNCOM P RUNCMP CONTINUE TO LOAD DRIFT AND TALLY 2-7/8 EUE 8RD TUBING. LOSS RATE5 BPH. 02:00 - 02:30 0.50 __ __ RUNCOM P _ RUNCMP WEEKLY SAFETY MEETING. 02:30 - 06:00 3.50 RUNCOM P RUNCMP ASSEMBLE AND SERVICE ESP COMPONENTS. 06:00 - 08:00 2.00 RUNCMM P RUNCMP MAKE UP MLE. 08:00 - 11:00 3.00 RUNCOM P RUNCMP RIH W/ ESP ON 2-7/S", L-80, EUE 8RD PIPE. - PICKING UP TUBING FROM PIPE SHED 1X1. -CANNON CLAMPS ON EVERY JOINT. ~ RWO SUPERINTENDANT AND CHECK 6 ONSITE ~ _ _ FOR OBSERVATIONS AND DISCUSSIONS. Printed 7/19/2010 11:48:52AM >• North America -ALASKA - BP Page a or e Operation Summary Report - - ___ Common Well Name: MPI-12 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 6/25/2010 End Date: 7/1/2010 X4-0009D-E (375,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name/No.: NABORS 4ES Spud DatelTime: 10/7/2001 12:0O:OOAM Rig Release: 6/30/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: MPI-12: @63.4ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ~ (ft) 11:00 - 12:00 1.00 i RUNCMM P RUNCMP D1 -KICK WHILE TRIPPING DRILL. j ~ - TOOLPUSHER PUSHED ON THE FLOWLINE ~ FLOAT PADDLE TO SIMULATE A KICK. - 62 SECONDS AT INITIALIZING THE ALARMS THE WELL WAS SECURED. - RIG CREW RESPONDED APPROPRIATELY. AAR WAS HELD WITH THE TOOLPUSHER, RWO SUPERINTENDANT, CHECK 6, AND THE RIG CREW.... -CREW DID A GOOD JOB OF RECOGNIZING AND RESPONDING TO THE "KICK" / -RIG CREW ONLY PUT THE FULL OPENING ,K/ SAFETY VALVE ON HAND TIGHT. DISCUSSION WAS HELD ON HOW THEY SHOULD DRILL AS THOUGH IT IS THE REAL THING AND SHOULD PRACTICE TORQUING UP THE TIW DURING THE DRILL. 12:00 - 00:00 12.00 RUNCOM --P RUNCMP. CONTINUE TO RIH W/ ESP ON 2-7/8" L-80, EUE SRD PIPE. - PICKING UP TUBING FROM PIPE SHED 1X1. - CANNON CLAMPS ON EVERY JOINT. - FILL TUBING AND CHECK ESP CABLE EVERY 2000'. - AT 23:59 HRS PU JOINT 195 START OF HEAT TRACE. D-1 DRILL PU PUP JOINT TO ALLOW MAKE UP OF TIW WITH TONGS. CREW HAD GOOD RESPONCE .SIMULATED CUTTING ESP CABLE, MOVED JOINT INTO POSITION AND SIMULATED CLOSING PIPE RAMS. HELD AFTER ACTION REVIEW AGREED TO HAVE THIRD PARTY GO TO MUSTAR AREA I.E. CENTRILIFT. __ 6/29/2010 00:00 - 06:00 6.00 RUNCMM P _ RUNCMP CONTINUE TO RIH W/ ESP ON 2-7/8", L-80, EUE 8RD PIPE. - PICKING UP TUBING FROM PIPE SHED 1X1. - CANNON CLAMPS ON EVERY JOINT. - FILL TUBING AND CHECK ESP CABLE EVERY 2000'. - AT 04:30 HRS PU JOINT 208 START OF HEAT TRACE. 06:00 - 14:00 8.00 _ RUNCMM __ P RUNCMP CONTINUE TO RIH W/ ESP ON 2-7/8", L-80, EUE 8RD PIPE. - PICKING UP TUBING FROM PIPE SHED 1X1. -CANNON CLAMPS ON EVERY JOINT. - FILL TUBING AND CHECK ESP CABLE EVERY 2000'. - AT JNT 242 @ 14:00 __ ~ 14:00 - 17:00 3.00 RUNCMM P _ RUNCMP MAKE REEL TO REEL SPLICE -C/O SPOOLS. - -+ -PU CANNON CLAMPS. Printed 7/19/2010 11:48:52AM North America -ALASKA - BP Page 5 of s Operation Summary Report Common Well Name: MPI-12_DIMS j AFE No Event Type: WORKOVER (WO) Start Date: 6/25/2010 End Date: 7/1/2010 X4-0009D-E (375,000.00 ) Project: Milne Point Site: M Pt I Pad Rig Name/No.: NABORS 4ES Spud Date/Time: 10/7/2001 12:0O:OOAM Rig Release: 6/30/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: MPI-12: @63.4ft (above Mean Sea Level) Date From - To I Hrs Task Code ~ NPT NPT Depth Phase Description of Operations _ _ _ ~ (hr) ~ (ft) 17:00 - 20:00 3.00 RUNCOM P RUNCMP CONTINUE TO RIH W/ ESP ON 2-7/8", L-80, EUE 8RD PIPE. ' -PICKING UP TUBING FROM PIPE SHED 1X1. -MAINTAINING CONT HOLE FILL DURING TRIP, __ _ _ AVG LOSS RATE - 3-4 BPH. 20:00 - 22:00 2.00 RUNCOM P RUNCMP INSPECT DAMAGED HEAT TRACE ARMOR @ THE TOP OF JNT # 245 CENTRILIFT REPAIRED THE ARMOR AND PERFORMED MEG TEST, EVERYTHING TESTED GOOD __ _ __ ___ _ 22:00 - 00:00 2.00 RUNCMM P RUNCMP _ CONTINUE,TO RIH W/ ESP ON 2-7/8", L-80, EUE I 8RD PIPE. - PICKING UP TUBING FROM PIPE SHED 1X1. -THE ESP CABLE SPLICE CAME OUT RIGHT AT THE COLLAR ON JNT 251. -REPLACED ARMOR ON ESP CABLE AND INSTALLED 4..05" PUP BETWEEN JNTS 250-251 ' TO SPACE OUT THE SPLICE FROM THE COLLAR.__ 6/30/2010 00:00 - 06:00 6.00 RUNCOM ' P _ RUNCMP CONTINUE TO RIH W/ ESP ON 2-7/8", L-80, EUE SRD PIPE. -PICKING UP TUBING FROM PIPE SHED 1X1. -CANNON CLAMPS ON EVERY JOINT. - FILL TUBING AND CHECK ESP CABLE EVERY 2000'. -CONTINUOUS HOLE FILL DURING TRIP, AVG LOSS RATES - 3-4 BPH 06:00 - 06:30 __ 0.50 ___ RUNCOM P ~ RUNCMP CREW CHANGE. -SERVICE DRAWWORKS, CHECK AND SET PVTS, ENVIRONMENTAL WALK AROUND. ____ 06:30 - 09:30 3.00 RUNCOM P _ RUNCMP CONTINUE TO RIH W/ ESP ON 2-7/8", L-80, EUE 8RD PIPE. -PICKING UP TUBING FROM PIPE SHED 1X1. -CANNON CLAMPS ON EVERY JOINT. I -FILL TUBING AND CHECK ESP CABLE EVERY i 2000'. - CONTINUOUS HOLE FILL DURING TRIP, AVG LOSS RATES - 3-4 BPH 09:30 - 10:00 0.50 __ RUNCOM _ P _ _ _ RUNCMP PU AND MU TUBING HANGER. 10:00 - 12:30 2.50 RUNCMM P RUNCMP MU TUBING HANGER SPLICE FOR ESP CABLE AND FOR HEAT TRACE CABLE. _ _ 12:30 - 13:00 0.50 RUNCOM P RUNCMP CHECK ORIENTATION AND l1~ND TUBING HANGER IN TUBING SPOOL - PU WEIGHT = 52K LBS - SO WEIGHT = 27K LBS - 3 FLAT GUARDS, 6-PROTECTOLIZERS, 193- CANNON CLAMPS, 110 CANNON X-COLLAR CLAMPS, 533 CANNON 5' MID JNT 2 LINE CLAMPS , 12-S.S BANDS Printed 7/19/2010 11:48:52AM Common Well Name: MPI-12 DIMS Event Type: WORKOVER (WO) Project: Milne Point Rig Name/No.: NABORS 4ES Rig Contractor: NABORS ALASKA DRILLING INC. Active Datum: MPI-12: @63.4ft (above Mean Sea t Date From - To Hrs (hr) __ 13:00 - 14:00 1.00 North America -ALASKA - BP Operation Summary Report Start Date: 6/25/2010 End Date: 7/1/2010 Site: M Pt I Pad Spud Date/Time: 10/7/2001 12:0O:OOAM Task WHSUR 14:00 - 17:00 3.00 I BOPSUR 17:00 - 18:30 1.50 ~ WHSUR --- ~ 18:30 - 20:30 2.00 WHSUR I 20:30 - 21:30 1.00 WHSUR 21:30 - 00:00 2.50 WHSUR Page 6 of 6 ~ _- AFE No X4-0009D-E (375,000.00 ) Rig Release: 6/30/2010 UWI: Code NPT NPT Depth Phase Description of Operations (ft) P _ RUNCMP DRY ROD TWC IN TUBING HANGER. -TESTED TWC FROM ABOVE TO 1000 PSI FOR 10 CHARTED MINUTES -- GOOD TEST. -TESTED TWC FROM BELOW TO 500 PSI FOR 10 CHARTED MINUTES, ROLLING TEST. -- GOOD TEST. P ~ _ RUNCMP PJSM TO BLOW DOWN LINES & ND BOPE -ND 13-5/8" GK HYDRILL BOP. =SINGLE$ARRIER DISPENSATION IN PLACE FOR MiLNE POINT WELL -TESTED TWC INSTALLED FOR NIPPLE DOWN *** 24 HR NOTIFICATION'OF BOP TESTING FOR UPCOMING MPI-13 *** -JOHN CRISP AND TOLD US HE WOULD LIKE A .CALL TOMORROW MORNING WITH AN UPDATE. P RUNCMP NU 2-9/16" 5M ,FMC TREE P RUNCMP pT TREE &TUBING HEAD ADAPTER TO 5,000 PSI FOR 5 MINUTES WITH DIESEL -PT HANGER VOID FOR 30 MIN @ 5000 PSI CENTRILIFT PERFORMED FINAL CHECKS ON ESP AND HEAT TRACE -GOOD TESTS. ____ P RUNCMP RU LUBRICATOR AND TEST WITH DIESEL TO 500 PSI. -PULL 2.5" CIW "H" STYLE TWC P RUNCMP -INSTALL & TEST BPV FROM BELOW TO 500 PSI FOR 10 CHARTED MIN. -PUMPING @ 5 BPM TOTAL OF 90 BBLS LD LUBRICATOR -SECURE WELL AND CELLAR -AAR FOR MPI-12 *** RIG RELEASED AT 00:00 *** Printed 7/19/2010 11:48:52AM Wellhead: 11" 5M Gen 5 w/2-7/8" 8 rd. T&B Tubing Hanger w/ M P I - ~ 2 Orig. K = 64.7' (Nabors 22-E) CIW "H" BPV profile Orig. GL ev. = 34.7' (Nabors 22-E) 20", 92 #/ft H-40 Welded 112' Camco 2-7/8" x 1" 202' sidepocket KBMM GLM 10.75", 45.5#/ft BTC L-80 2905' Camco 2-7/8" x 1" 2,508' sidepocket KBMM GLM 2 7/8" 6.5 ppf, L-80, 8rd, EUE production tubing ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, BTC-Mod production casing 2-7/8" XN nipple 9 573` (drift ID = 6.151", cap. = 0.0383 bpf) (ID 2.205") , 2-7/8" x 3 1/2" X-Over 9,587' KOP @ 300 ' WeIILift Discharge gauge g 589° Max well bore Angle: 85.5° @ 8102' MD Gauge = 3587' ND 63.74° @ 2550' MD Hole angle through perfs = 90°+/- PCP Pump LTZOOO with 9 595' Flex-shaft Assy csezz33axa , - Gear Reduction Unit g 587, GRU 5386 11.43:1 Tandem Seal Section ' GSB3 DB UT/LT H17 VH PFS FEI 9,627 Motor, KMH, 76 HP, 1360 volt, ' 34 amp, rerated t0 55 HP, 9,642 Q D 801 volt, 41 amp, KMH-A WeIILift MGU Gauge w/6 fin 9,650' Centralizer Gauge = 3599' ND Top of "OA" Window - 9916` and Bottom of "OA" Window - 9928' and Angle @ Top of Window - 80° Top of "OB" Window - 10228' and Bottom of "OA" Window - 10240' and Angle @ Top of Window - 87° Baker Tie Back Sleeve 10116` Baker ZXP Liner Top Packer 10128' Baker 7" x 5" HMC Liner Hanger 10147' 7" Halliburton Float Collar 10265` 7" Halliburton Ream Shoe 10347' Baker Hook Wall Hanger above 7" Window @ 9906' Baker Hook Wall Hanger below 7" Window @ 9928' Baker Tension Lock Swivel @ 9930' 6 1 /8" Hole TD @ 12500' I OA Lateral 1 jt. - 4-1/2" 12.6# L-80 IBT Solid Liner (9936' - ss8o'> 76 Jts - 4 1/2" 12.6# L-80 IBT Slotted Liner (9980' - 12393') Btm. 4 1/2" Packoff Bushing 12395' Solid bent jt. - 4-1/2", 12.6# L-80 IBT (uncentralized), (12395' -12435') Btm. 4 1/2" Guide Shoe 12435' 6 1/8° Hole td @ 12470' OB Lateral 5 Jts - 4-1/2" 12.6# L-80 IBT Solid Liner (10164' - 10373') ~ 53 Jts - 4 1/2" 12.6#/ft. L-80 IBT Slotted Liner (10373'-12396') Btm. Baker 4 1/2" Guide Shoe 12439' DATE 1 REV. BY I COMMENTS 11/15/01 GMH Nabors 22E Drill Multi-lat & Run Tbg. 12/15/01 BMH ESP Completion Nabors 4ES 06/30/10 Hulme Convert to PCP - Nabors 4ES MILNE POINT UNIT WELL I-12 API NO: 50-029-23038 BP EXPLORATION (AKA • ~ 4,.G ~ ~. ~~. ~~ SARAH PAL/N GOV ~ ~ ERNOR ~~ OI~ ~ ~ 333 W. 7th AVENUE, SUITE 100 C01~5IiRQATIOIK COl-II-iISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ali Husain Well Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 ~'"~ APR ~ 9 2008 Re: Milne Point Unit, Schrader Bluff Oil Pool, MPI-12 / ~ ~ 3 Sundry Number: 308-118 ~ ` Dear Mr. Husain: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Comrriission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such fiu-ther time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of April, 2008 Encl. ' ~ '~~ STATE OF ALA KA • ~~~~' Y S ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVA ~~AP ~ Z~o~~ 20 AAC 25.280 a ~I~ & f;Ae n,.__ .. 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver ' Altercasing^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ~BACK• Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl0 Exploratory ^ 201-1630 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23038-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPI-12 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-025517 63.4 KB Milne Point Field / Schrader Bluff Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12470 ~ 3712.33 12470 3712.33 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 79' 20" 92# H-40 Surface 108' Surface 108' Surface 2878' 10-3/4" 45.5# L-80 Surface 2906' Surface 2407' 5210 2480 Production 10201' 7" 26# L-80 27' 10228' Surface 3706' 7240 5410 Liner 2313' 4-1/2" 12.6# L-80 10128' 12441' 3691' 3714' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): OA Lat SL 9936' - 12435' 3654' - 3718' 2-7/8" 6.5# L-80 Surface - 9656' OB Lat SL 10164' - 12396' 3697' - 3715' - Packers and SSSV Type: BAKER ZXP LINER TOP PACKER Packers and SSSV MD (ft): 10128' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/16/2008 OIL Q GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ali Husain Printed Name Ali Husain Title Well Engineer Signature Phone 564-4152 Date 4/2/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~-~p ~.- J/ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Loca tion Clearance ^ (t \ - R Other: S`1 C ~.tSC 5~.~~c~~ V c~,~Vrc ~V S~ ~1jtc- ~~S~U prlOC- "moo C~n~`-~~` Y~V3~ 1~c ~-Z~~ ~~Sp~cc.~oc- . oQ~~.~~o~s c~v~~o~,Z~ ~ -~o r-~`-~lc~c,,~~, Subsequent Form Required: y~U ` ~~ ~i~%F, t~t1' i~l~~i APPROVED BY Approved by: C M I N~~ T E COMMISSION Date: Form 10-40 Revised 06/2006 ~ ~ ~'" Submit in Duplicate ~ Y~ 7. • Proposed work on MPI-11 and MPI-12 412/08 History: MPl-11 and MPI-12 are both drilled as multi-lateral welts in the OA and OB zone Schrader Bluff formation. Both were completed with ESP in late 2001. The two wells came online with 1000 bopd but the rate dropped dramatically a few days later with suspect plugging in the ESP. Several attempts were done to rescue the ESP's with either RWO or coil tubing cleanouts but it was clear that was due to high viscous materials the ESP would get plugged and stop surfacing fluids and the two wells were declared LTSI for poor oil quality in early 2003. Proposal: There is a plan this year to re-evaluate the situation on both MPI-11 and MPI-12 and come up with a plan forward to bring them online. The two ESP's were checked if they are functioning electrically and the results showed that MPI-12 to have a functioning ESP and MPI-11 ESP was declared dead. Unfortunately all of the ESP surface equipment has been demobilized and removed. The good news is that the SBHP in the area is relatively high and close to virgin reservoir pressure (--1800 psi). So we think we can free flow MPI-11 and MPI-12 (if we can't find / a portable unit to start the ESP). . The reasoning behind a temporary flow to tanks is to capture some oil samples for API, SG and •/ composition analysis to help us choosing the new lifting mechanism for the wells. The job scope will be to rig up flow back tanks to the wells and try to flow MP1-12 with the ESP or free flow it if we can't start the ESP. The plan for MPI-11 is to attempt to free flow the well to a , tank. .- Wellhead: 11" 5M Gen 5 w/~" 8 rd. T&B Tubing Hanger w! GIW "H" BPV profile ' 20", 92 #/ft H-40 Welded 112' 10.75", 45.5#!ft BTC L-80 2905' Camco 2-7/8" x 1" 141' sidepocket KBMM GLM 2 7/8" 6.5 ppf, L-80, 8 rd, EUE production tubing ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btc-mod production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) KOP @ 300 ' Max wellbore Angle: 85.5° @ 8102' MD 63.74° @ 2550' MD Hole angle through perfs = 90°+/- Top of "OA" Window - 9916` and Bottom of "OA" Window - 9928' and Angle @ Top of Window - 80° Top of "OB" Window - 10228' and Bottom of "OA" Window - 10240' and Angle @ Top of Window - 87° Baker Tie Back Sleeve 10116' Baker ZXP Liner Top Packer 10128' Baker 7"x 5" HMC Liner Hanger 10147` 7" Halliburton Float Collar 10265` 7" Halliburton Ream Shoe 10347' MP!-12 Or~B elev. = 64.7' (Nabors 22-E) Orig. GL elev. = 34.7' (Nabors 22-E) Camco 2-7/8" x 1" 2515' sidepocket KBMM GLM 1" Dummy GLV dropped in tubing. Last known depth 3160' slm. 1/15/02 2-7/8" XN nipple 9 556' (ID 2.205") , Triple Tapered Pump, 16 Stg. ` 1:1 GCNPSH, 29 Stg 1:1 9,599 GC2900 & 67 Stg 1:2 GC 1700 Tandem Gas Separator 9,623' GRSTX BAR H6 Intake 9,623` MD = 3,594' TVD Tandem Seal Section O GSB3 DB UT/LT IL H6 PFS Aflas/HSN 9,628 Motor, 114 HP, 2330 volt, ` 30 amp, rerated to 9,642 138 HP, 2435 V, 36 A. KMH-J PumpMate w/6 fin Centralizer 9,656' Baker Hook Wall Hanger above 7" Window @ 9906' Baker Hook Wall Hanger below 7" Window @ 9928' Baker Tension Lock Swivel @ 9930' 6 1/8" Hole td @ 12500` OA Lateral 1 jt. - 4-1/2" 12.6# L80 IBT Solid Liner (9936' - 9980') 76 jts. - 4 1/2" 12.6# L-80 IBT Slotted Liner (9980' - 12393') Bttm. 4 1/2" Packoff Bushing 12395' Solid bent jt. - 4-1/2", 12.6# L-80 IBT (uncentralized), (12395' - 12435') Bttm. 4 1/2" Guide Shoe 12435' 6 1/8" Hole td @ 12470' OB Lateral 5 jts. - 4-1/2" 12.6# L80 IBT Solid Liner (10164' -10373') ~ 53 jts - 4 1/2" 12.6#/ft. L80 IBT Slotted Liner (10373'-12396') 1 Bttm. Baker 4 1/2" Packoff Bushing 12396' ', Bttm. Baker 4 1/2" Guide Shoe 12439' I .DATE REV. BY COMMENTS 11/15/01 GMH Nabors 22E Drill Multilat & Run Tbg. 12/15/01 BMH ESP Completion Nabors 4ES MILNE POINT UNIT WELL I-12 API NO: 50-029-23038 BP EXPLORATION (AKA . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\MÏcrofilm _ Marlœr.doc 2, J(Vh. À-Ò~ ~ DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2011630 Well Name/No. MILNE PT UNIT SB 1-12 Operator BP EXPLORATION (ALASKA) INC S/7~ 7 O(.t-~1 API No. 50-029-23038-00-00 MD 12470- ND 3712 /' Completion Date 12/8/2001 r- Completion Status 1-01L Current Status 1-01L UIC N -- ----- ----- REQUIRED INFORMATION Mud Log No Samples No Directional Survey No . ~-- ------ --- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) :~, Log/ Data Digital Type Med/Frmt ~ C I LED D I k.EÐ...D I <tßÐ' C Electr Dataset Number ""'Õ832 ios99 m597 '*0830 Ü$VenftCäfion Name USVêrificå,tióh . Log Log Run Scale Media No 1 Interval OH/ Start Stop CH Received Comments 108 13243 Open 5/9/2002 PB1 252 13169 Open 2/20/2002 PB1 252 12406 Open 2/20/2002 108 12470 Open 5/9/2002 --. - ----~ Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? .~ Daily History Received? @N (ýj/N ~=c- Formation Tops Analysis Received? V / þJ ---- -- --- Comments: Compliance Reviewed By: \~ Date: -~_J~ ~~I ( ( WELL LOG TRANSMITIAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 March 7, 2002 RE: MWD Fonnation Evaluation Logs - 1vIPI-12, :MPI-12 LI, & PBI AK-~-11164 MPI-12: aC 1"'1 /.!) 3 Digital Log Images: Jo-a7- 0 I 50-029-23038-00 W 3 D J O'6-/~4 7'0 ~OJ-~lo4.,- J/...¡O-O J l°'ö -/~5ðO lo'3D MPI-12PBl: ~Ol-Jb~ Digital Log Images: 1 a - a 7 - 0/ 50-029-23038-70 103 0 } o~-13a~3 } 083D' ~ 1 CD Rom MPI-12 Ll: Digital Log Images: 50-029-23038-60 L,o~31 " 1 CD Rom , tC5~5bé;cl;.~~:~~ ~ 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LEITER TO THE A'ITENTION OF: Speny-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Sign~.oo (,OCb.p0 RECEIVED Date: r,~ .\\.' n ¡Î 0!1/YJ i ,~" : L: ;1 .:...'.. ~ C. .4faska OU & Gas Cons. Commission , Anchorage • • Maunder, Thomas E (DOA) From: Sent: To: Cc: Subject: a~~-~3~ Attachments: =I jack hartz.vcf (2 KB) Bill, ~O~-\to3 I reviewed the proposal regarding circulation of water through the annuli of wells at MPU and found it to be a reasonable approach to handle the problems that were outlined. The type of completion employed in these wells did not require a packer, so there were no regulatory issues that required a permit. We agree with your proposal to circulate water to improve pump efficiency. It looks like a novel approach to an unexpected problem. Let us know if you have any questions. Jack Hartz ~,ut+Y3'~~ NQ~ ~ ~ ~~~17 "Mathews, William L" wrote: > Morning Jack, > I don't have any velocity concerns with what we are proposing. At 750 > bwpd in the 7" x 2-7/8" annulus we are moving water at-17-:25 ft/min. > Compare this to some of our current jet pump applications where we are > moving up to 2000 bwpd down a 7" x 3-1/2" annulus (well MPJ-23). This ft/min. > Flow rates at S-pad will be even higher as we plan to use up to 4000 > bwpd down a 7-5/8" x 4-112" annulus giving us 106 ft/min. > Bill > -----Original Message----- > From: Jack Hartz [mailto:jack hartz@admin.state.ak.us] > Sent: Tuesday, April 02, 2002 8:43 AM > To: Mathews, Bill > Subject: [.Fwd: [Fwd: Milne Pt. Well I-12]] > Bill, > I left a message on your machine earlier this a.m., regarding the > proposal to circulate water thru the well annuli. My only question is > are there any velocity issues or concern about erosion? The rates you > suggest appear nominal. I don't think there are any other questions > from here. > Thanks, > Jack Hartz > 793-1232 ~..EC ~ c c,`' \```_o~ ~ Jack Hartz [jack hartz@adminstate.ak.usj Wednesday, April 03, 2002 5:49 PM Mathews, William L Thomas E Maunder Milne Pt. JI-11, I-12 and E-30A - annular water circulation jack hartz.vcf ~ 7C7 l - p l \ equates to 52.5 • • Maunder, Thomas E (DOA) From: Jack Hartz [jack_hartz~admin.state.ak.us] Sent: Tuesday, Apri{ 02, 2002 11:08 AM To: Dan{el T Seamount JR; Camille Tay{or Cc: Thomas E Maunder Subject: Adjudication Meeting 4/2/2002 -MPU I-11, I-12 and E-30A Attachments: jack hartz.vcf +=f jack_ha~tz.vcf (2 KB) Subject: Milne Pt. Unit - Schrader Bluff - Water circulation down annuli of wells to provide heat and volume to pumped fluids. BPX has requested approval to circulate water down the annulus of 3 MPU Schrader Bluff wells. The purpose of the water circulation is to heat wellbore produced fluids and increase the efficiency of the ESPs installed in these wells. Lower API gravity in this area has caused lower rate compounded by higher viscosity making the pumps oversized for the rates being produced. No heat trace was installed initially because they anticipated higher gravity and higher rates (warmer production conditions). The circulating water substitutes as a different type of heat trace. Circulating water down the annulus will increase the pump efficiency by heating the fluids and adding volume to the pump. The Schrader Bluff wells will not flow on their own and have been completed without packers to allow more efficient separation of the gas from the well stream. There are no mechanical, velocity, erosion or reservoir issues to inhibit their doing this procedure. Recommendation: I recommend we acknowledge their proposal and indicate our agreement. In my opinion, they don't need approval to conduct this operation. Let me know if there are any questions, etc. Jack (Following is a copy of the Emails from BPX on the subject. I'll bring the mechanical diagrams to the meeting.} -jdh » »»»»» » »»»»»»»»»»»»»»»»»»»»»»»»»»» Subject: RE: [Fwd: [Fwd: Milne Pt. Well I-12]] Date: Tue, 2 Apr 2002 12:07:50 -0600 From: "Mathews, William L" <MathewWL@BP.com> To: "'Jack Hartz"' <jack hartz@admin.state.ak.us> Morning Jack, I don't have any velocity concerns with what we are proposing. At 750 bwpd in the 7" x 2-7/8" annulus we are moving water at 17.25 ft/min. Compare this to some of our current jet pump applications where we are moving up to 2000 bwpd down a 7" x 3-1/2" annulus (well 1 • MPJ-23). This equates to 52.5 ftlmin. Flow rates at S-pad will be even higher 4-1/2" annulus giving us 106 ft/min. Bill • as we plan to use up to 4000 bwpd down a 7-5/8" x -----Original Message----- From: Jack Hartz [mailto:jack_hartz@admin.state.ak.us] Sent: Tuesday, April 02, 2002 8:43 AM To: Mathews, Bill Subject: [Fwd: [Fwd: Milne Pt. Well I-12J] Bill, I left a message on your machine earlier this a.m., regarding the proposal to circulate water thru the well annuli. My only question is: are there any velocity issues or concern about erosion? The rates you suggest appear nominal. I don't think there are any other questions from here. Thanks, Jack Hartz 793-1232 »»»»»»»»»»»»»»»»»»»»»»»»»»»»»»»»»» Subject: [Fwd: Milne Pt. Well I-12] Date: Fri, 22 Mar 2002 16:10:47 -0900 From: Tom Maunder <tom maunder@admin.state.ak.us> To: John D Hartz <jack_hartz@admin.state.ak.us> Jack, FYI. I think this is a good idea. Water should be less problematic than heat trace. What do you think? Tom Subject: Milne Pt. Well I-12 Date: Fri, 22 Mar 2002 13:45:38 -0600 From: "Mathews, William L" <MathewWL@BP.com> To: "'tom_maunder@admin.state.ak.us'" <tom maunder@admin.state.ak.us> Tom, Milne Pt, well I-12 was drilled and completed in December of 2001 as a multi-lateral producer in the Schrader Bluff OA and OB sands. The well was expected to come on line at >1500 bopd, but due to poorer than anticipated oil quality (17 deg API/200+cp versus an expected 21 deg API/22 cp), has failed to produce up to expectation. Initial rates were around 800 bopd and quickly fell off to less than 300 bopd. Since the well completion was designed around the higher rates, heat trace was not installed in the well. As rates fell, welibore fluids cooled off, making it difficult to keep the well on production. The well would have eventually died due to the high viscosity and cooler temperture of the crude. To prevent this, a temporary water line was installed to allow operations to slip stream 500-1000 bwpd down the annulus in an effort to warm up the well and improve the ESP efficiency. This was successful, allowing the well to stay on production at 350 bopd. The well was shut in pending an acid stimulation and appraisal for a more permanent water installation. A foam divert acid stimulation was performed in a • early March. The well came back on line and has so far been able to sustain an oil rate of 500-700 bopd with a water slip stream of 750 bwpd. BP is requesting approval to permanently tie-in this well to the injection water header to allow us to continue to slip-stream water down the annulus at 500-1000 bwpd. A more permanent installation will provide a cost effective way to keep this well on line. In addition to well I-12, there are two more wells that may benefit from a similar installation. These are well I-11 (recently drilled well adjacent to I-12 and now shut in) and well E-30A which was drilled last year along the northern periphery of the Schrader Bluff field. BP is requesting approval to permanently tie these wells in should it be necessary to maintain their ability to produce at economical rates. I've attached wellbore schematics and a production plot for MPI-12 for your consideration. Please give me a call if you would like to discuss this in more detail or have any questions. Bill Mathews Schrader Bluff Completion Engineer 564-5476 440-8496 cell «MPI-12 Schematic.ZIP» «MPI-11 Schematic.ZIP» «MPE-30A Schematic.pdf» «MPI-12 Well Tests.doc» 3 \, \ \' ~, WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 J\nchorage,Alaska 99501 RE: MWD Fonnation Evaluation Logs February 13, 2002 AK-MM-11164 1 LIS fonnatted Disc with verification listing. API#: 50-029-23038-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Sign~~ RÊCetvED FEB 2 0 2002 AIa8k8 Oil & Gas COns. COIUßiIion AndIof898 ( ~""""""""I"""""il,:¡;;~""" "I'"'' 1", ";~"'¡'I" EJ>iJ": ";'J')t~' ""'2 ',:"t':"'C\;,,,¡,,'I:;:~,,;I~,O WELL LOG TRANSMITIAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 J\nchorage,AJaska 99501 February 12, 2002 RE: MWD F onnation Evaluation Logs l\1PI-12 PB 1, AK-lVIM:-11164 1 LIS fonnatted Disc with verification listing. API#: 50-029-23038-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (AJaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 DatREœtvED FEB 2 0 2002 Alaska Oil & Gas Cons. ComInision Anchorage Sign~~ \ ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ŒlOil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-163 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-23038-00 4. Location of well at surface ... . -" .,,-., tOCA'hONS' 9. Unit or Lease Name 2345' NSL, 3996' WEL, SEC. 33, T13N, R10E, UM . . ¡;§l Milne Point Unit " At top of productive interval ¡..LZ_~-f--~,!:2L 3494' NSL, 1652' WEL, SEC. 31, T13N, R10E, UM \'F:-'~:J-:I~~J 10. Well Number At total depth ._~&tt:.-::'~) ~ ..~~ . .. '"...- MPI-12 3554' NSL, 3831' WEL, SEC. 31, T13N, R10E, UM .'~".~'-~~'rI~~"~ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Milne Point Unit I Schrader Bluff KBE = 63.40' ADL 025517 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 16. No. of Completions 10-7-2001 11-5-2001 ' 12-8-2001 NIA MSL One 17. Total Depth (MD+ TV D). 1 18. Plug Back Depth (MD+ TVD) .119. Directional Survey 120. Depth where SSSV se~ 121. Thickness of Permafrost 12470 3712 FT 12470 3712 FT ŒI Yes 0 No NIA MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, DIR, DIR (IFR), GR, RES, PWD, ABGR, ABI 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PUllED 20" 92# H-40 29' 108' 30" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# L-80 28' 2906' 13-1/2" 585 sx AS Lite, 502 sx Class 'G' 7" 26# L-80 27' 10228' 9-7/8" 1172 sx Class 'G' 4-1/2" 12.6# L-80 10128' 12441' 6-1/8" Uncemented Slotted Liner 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 2-7/8", 6.5#, L-80 9656' NIA MD TVD MD TVD 10374' - 12397' 3710' - 3715' 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Set EZSV & Whipstock for Plugback Freeze Protected wI 95 Bbls of Dead Crude 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) December 19, 2001 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR Oll-BSl GAs-McF WATER-BBl CHOKE SIZE 1 GAS-Oil RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED Oll-BSl GAs-McF WATER-BSl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECE"r' RED ' . -" V, 'J . ~ II L.. ~Il ~ "I ~ì,:mtm No core samples were taken. 9 ~i znæ) t.: "., , L ;-' L Alaska Oil & Gas Cons. Commission Anchoraqe Form 10-407 Rev. 07-01-80 I . R B 0 M 5 B F L C. [:::FEB 7 ~ubmit In Duplicate -, (' (' 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. NA NB NC 9395' NE 9470' NF 9738' Top of Schradder Bluff OA Sands 9898' Base of Schrader Bluff OA Sands 10080' Top of Schrader Bluff OB Sands 10280' 9100' 3493' 9241' 3522' 3552' 3566' 3615' 3647' 3682' 3709' N ~:: 20DZ Alaska Oil 8(, G:as Cens. Commission !\nchmage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak-Off Integrity Test 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date D( ~ ;<'"3 -0 MPI-12 Well Number 201-163 Permit No. / A roval No. Prepared By Name/Number: Sondra Stewman, 564-4750 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: MPI-12 Common Name: MPI-12 Test Date 10/12/2001 10/21/2001 11/3/2001 T~stT)'pe FIT FIT FIT Test Depth (TMD) 2,906.0 (ft) 10,355.0 (ft) 10,228.0 (ft) BPE.XPLORA TION L~ak~Øf1F Test'$ummary Test DepthfTYD) 2,406.0 (ft) 3,720.0 (ft) 3,709.0 (ft) AMW 9.10 (ppg) 9.20 (ppg) 9.20 (ppg) SûrfâcePressure 487 (psi) 370 (psi) 346 (psi) Leak Off Pressure (BHP) 1,624 (psi) 2,148 (psi) 2,119 (psi) Page 1 of 1 EMW 13.00 (ppg) 11.11 (ppg) 11.00 (ppg) Printed: 11/19/2001 10:03:55 AM BP EXPLORATION Page 1 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/6/2001 06:00 - 12:00 6.00 MOB P PRE PREPARE RIG FOR MOVE - BLOW DOWN WATER AND STEAM SYSTEM - DISCONNECT ALL LINES BETWEEN COMPLEXES - DISCONNECT AND PULL BACK ELECTRICAL CABLES 12:00 - 12:30 0.50 MOB P PRE HOLD PRE-JOB SAFETY MEETING WITH PEAK OILFIELD SERVICES RIG MOVERS AND NABORS PERSONAL 12:30 - 13:30 1.00 MOB P PRE MOVE MOTOR COMPLEX 13:30 - 14:30 1.00 MOB P PRE MOVE ROCK WASHER 14:30 -15:30 1.00 MOB P PRE MOVE MUD PIT AND PUMP COMPLEX - MOVE TWO PIPE SHED UNITS 15:30 - 16:30 1.00 MOB P PRE MOVE SUB BASE AND MAST OFF WELL 16:30 - 17:30 1.00 MOB P PRE REMOVE MATTING BOARDS AND PICK UP HERCULlTE AROUND CELLAR 17:30 - 22:30 5.00 MOB C PRE RIG MOVE OPERATION SUSPENDED - CONSTRUCTION CREWS INSTALL FLOW LINES AND WELL HOUSE ON WELL MPI-11 INSTALL FMC QUICK CONNECT, 20" DIVERTER SPOOL WITH 16" KNIFE VALVE, AND 21 1/4" ANNULAR ON NEXT WELL MPI-12 - MOVE CAMP GENERATOR, TRUCK SHOP, AND CAMP TO MAKE ROOM FOR PRODUCTION MANIFOLD INSTALLATION. 22:30 - 00:00 1.50 MOB P PRE LEVEL LOCATION AROUND WELL MPI-12 WITH DOZER- SET MATTING BOARDS AND LAY HERCULlTE - MOVE SUB BASE AND MAST DOWN PAD TO POSITION OVER WELL. 1 0/7/2001 00:00 - 02:00 2.00 RIGU P PRE HOLD PRE-JOB SAFETY MEETING - MOVE SUB BASE AND MAST OVER WELL MPI-12 02:00 - 03:00 1.00 RIGU P PRE SET MATTING BOARDS - SPREAD HERCULlTE - SET MUD PIT PUMP COMPLEX, AND ROCK WASHER 03:00 - 05:00 2.00 RIGU P PRE SPOT PIPE SHEDS AND MOVE MOTOR SHED COMPLEX INTO POSITION 05:00 - 06:00 1.00 RIGU P PRE SPOT RIG FUEL STORAGE TANK, PIPE SHED TIOGA HEATER, AND CUTINGS TANK 06:00 - 08:00 2.00 RIGU P PRE BERM AROUND RIG - HOOK UP UTILITIES BETWEEN COMPLEXES 08:00 - 10:00 2.00 RIGU P PRE CIRCULATE STEAM AND WATER AROUND RIG - TAKE ON WATER INTO PITS 10:00 - 15:30 5.50 BOPSUF P SURF NIPPLE UP 20" DIVERTER SYSTEM AND 16" DIVERTER LINE - INSTALL RISER, FLOW LINE AND TURNBUCKLES - MIX SPUD MUD 15:30 - 16:00 0.50 BOPSUF P SURF RIG UP 5" PIPE HANDLING TOOLS ON RIG FLOOR 16:00 - 17:30 1.50 BOPSUF P SURF PICK UP AND STAND BACK IN MAST 14 JOINTS OF 5" HWDP AND DRILLING JARS 17:30 - 19:30 2.00 BOPSUF P SURF PICK UP 131/2" BIT AND BHA NO.1 WITH SPERRY SUN DIRECTIONAL DRILLER 19:30 - 20:00 0.50 BOPSUF P SURF HOLD PRE-SPUD MEETING WITH ALL PERSONAL 20:00 - 20:30 0.50 BOPSUF P SURF FUNCTION TEST DIVERTER SYSTEM - ENSURE PACKING CLOSED COMPLETELY AND KNIFE VALVE FULLY OPENED - PREFORM ACCUMULATOR TEST - CHECK LEL AND H2S GAS DETECTION SYSTEM - WITNESS OF TEST WAIVED BY AOGCC REPRESENTIVE CHUCK SCHEVE. 20:30 - 21 :00 0.50 BOPSUF P SURF BLOW AIR THRU MUD LINES - CIRCULATE WATER BACK TO MUD PITS - CHECK FOR LEAKS AROUND RIG 21 :00 - 23:30 2.50 DRILL P SURF NABORS RIG 22E ACCEPTED FOR WELL WORK ON MPI-12 AT 12:00 HOURS 10/07/01 (AFE NO. 337247) - SPUD ( ( Printed: 11/19/2001 10:04:11 AM BP EXPLORATION Page 2 of25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1 0/7/2001 21 :00 - 23:30 2.50 DRILL P SURF WELL @ 21:00 HOURS ON 10/07/01 WITH BIT NO.1- CLEAN OUT 20" CONDUCTOR PIPE WITH FRESH WATER- SWAP TO SPUD MUD AND DRILL AHEAD FROM 108' TO 300' 23:30 - 00:00 0.50 DRILL P SURF CIRCULATE HOLE CLEAN - POH F/ BHA CHANGE 10/8/2001 00:00 - 03:00 3.00 DRILL P SURF HOLD PRE-JOB SAFETY MEETING - STAND BACK 2 STANDS HWDP - CHANGE BHA PICK UP MWD, HANG OFF SUB, UBHO SUB, AND (3) FLEX DRILL COLLARS & RIH WITH BHA - SURFACE TEST MWD TOOL - CONTINUE TO RIH WITH JARS, AND (1) STAND OF HWDP - BREAK CIRCULATION AND WASH LAST 60' TO BOTTOM 03:00 - 04:00 1.00 DRILL P SURF RIG UP SLICK LINE UNIT AND RUN GRYO WITH WELLS GROUP AND SPERRY SUN 04:00 - 08:00 4.00 DRILL P SURF DIRECTIONAL DRILL AHEAD PER PROGRAM FROM 300' TO 534' 08:00 - 08:30 0.50 DRILL P SURF RUN GRYO WITH WELLS GROUP AND SPERRY SUN - RIG DOWN SLICK LINE UNIT 08:30 - 00:00 15.50 DRILL P SURF DIRECTIONAL DRILL FROM 534' TO 1,936' - WEIGHT ON BIT 20K TO 35K - PUMP RATE AT 450 TO 541 GPM - OFF BOTTOM PUMP PRESSURE AT 1400 PSI. & ON BOTTOM PUMP PRESSURE AT 1,550 PSI. - TOP DRIVE AT 80 RPM MUD MOTOR AT 82 RPM - OFF BOTTOM TORQUE AT 2K & ON BOTTOM TORQUE AT 6K - ROTATING STRING WEIGHT AT 125K - WITH PUMPS ON DRAG UP AT 125K AND DRAG DOWN AT 100K. 10/9/2001 00:00 - 09:30 9.50 DRILL P SURF DIRECTIONAL DRILL FROM 1,936' TO 2,916' - WEIGHT ON BIT 10K TO 25K - PUMP RATE AT 450 TO 550 GPM - OFF BOTTOM PUMP PRESSURE AT 1400 PSI. & ON BOTTOM PUMP PRESSURE AT 1,600 PSI. - TOP DRIVE AT 70 TO 80 RPM MUD MOTOR AT 82 RPM - OFF BOTTOM TORQUE AT 3K & ON BOTTOM TORQUE AT 7K - ROTATING STRING WEIGHT AT 125K - WITH PUMPS ON DRAG UP AT 125K AND DRAG DOWN AT 120K. 09:30 - 11 :00 1.50 DRILL P SURF CIRCULATE AND CONDITION MUD WHILE PUMPING SWEEPS 11 :00 - 13:30 2.50 DRILL P SURF HOLD PRE-JOB SAFETY MEETING - MONITOR WELL (STATIC) - POH (SLM NO CORRECTION) TO BHA - NO PROBLEMS 13:30 - 15:00 1.50 DRILL P SURF SERVICE TOP DRIVE, TRAVELING BLOCKS, AND CROWN SHEAVES - LEVEL SUB BASE 15:00 - 16:00 1.00 DRILL P SURF RIH (NO PROBLEMS & NO FILL) 16:00 - 19:00 3.00 DRILL P SURF CIRCULATE AND CONDITION MUD FOR CASING WHILE PUMPING SWEEPS 19:00 - 21 :00 2.00 DRILL P SURF MONITOR WELL (STATIC) - POH 5 STANDS - PUMP DRY JOB - BLOW DOWN TOP DRIVE AND MUD LINE - CONTINUE TO POH 21 :00 - 23:00 2.00 DRILL P SURF LAY DOWN BHAAND DOWN LOAD MWD DATA 23:00 - 23:30 0.50 DRILL P SURF CLEAR RIG FLOOR 23:30 - 00:00 0.50 CASE P SURF RIG UP TO RUN 10 3/4" CASING 10/10/2001 00:00 - 03:00 3.00 CASE P SURF RIG UP CASING EQUIPMENT, FRANKS FILL UP TOOL, AND STABING BOARD 03:00 - 07:30 4.50 CASE P SURF PICK UP SHOE TRACK AND INSTALL CENTRILlZERS PER (' ( Printed: 11/19/2001 10:04:11 AM BP EXPLORATION Page 3 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/10/2001 03:00 - 07:30 4.50 CASE P SURF WELL PLAN - PUMP THRU SHOE TRACK AND VERIFY FLOATS OPERATIONAL - CONTINUE TO PICK UP A TOTAL OF 69 JOINTS OF 103/4" L-80 BTC 45.5 LB CASING PER PROCEDURE AND RIH - WORK THRU TIGHT SPOT AT 2,025' TO 2,045' - CONTINUE TO RIH WITH CASING. 07:30 - 08:00 0.50 CASE P SURF LAND CASING - HOLD PRE JOB SAFETY MEETING - RIG DOWN FRANKS FILL UP TOOL - INSTALL HALIBURTON CROSS OVER AND DOUBLE PLUG CEMENT HEAD - MAKE UP CIRCULATING SURFACE LINES 08:00 - 09:30 1.50 CASE P SURF CIRCULATE AND CONDITION MUD - HOLD PRE JOB MEETING WITH ALL PERSONAL REGUARDING UP COMING CEMENT OPERATION - RECIPROCATE CASING STRING 195K UP WEIGHT AND 145K DOWN WEIGHT. 09:30 - 13:00 3.50 CEMT P SURF TURN OVER TO HALIBURTON ENERGY SERVICES - PUMP 10 BBL. FRESH WATER - TEST SURFACE LINES @ 3,000 PSI. - CONTINUE TO PUMP ADDITIONAL 10 BBL. WATER - MIX AND PUMP 50 BBL 10.2 PPG ALPHA SPACER@ 5.2 BPM & 370 PSI. WITH RED DYE ADDED - DROP BOTTOM WIPER PLUG - BATCH UP AND MIX TYPE "L" PERMAFROST 1 0.7 PPG LEAD CEMENT wi YIELD OF 4.15 FT3/SK - PUMP @ 5.5 BPM wi 480 PSI. - TOTAL LEAD SLURRY PUMPED 432 BBLS. OR 585 SACKS - STOP RECIPROCATING CASING STRING WHEN 350 BBLS. LEAD SLURRY PUMPED DUE TO LOSS OF 30K STRING WEIGHT - FOLLOW UP LEAD CEMENT wi SURFACE TAIL DESIGN CLASS "G" PREMIUM 15.8 PPG wi YIELD OF 1.15 FT3/SK - TAIL CEMENT JOB WAS PUMPED @ 4.5 BPM & 550 PSI. - TOTAL TAIL SLURRY PUMPED 103 BBLS. OR 502 SACKS - DROP TOP WIPER PLUG - HALIBURTON PUMPED 20 BBL. BEHIND TO CLEAR LINES TURNED OVER TO RIG FOR DISPLACEMENT - DISPLACED @ 8 BPM wi 9.4 SPUD MUD - PUMPED 2,543 STROKES TO BUMP PLUG - TOTAL CEMENT BACK TO SURFACE 250 BBLS. - FINAL CIRCULATION PRESSURE DURING DISPLACEMENT@ 900 PSI. - CONTINUE TO PRESSURE UP TO 1,900 PSI. AFTER BUMPING PLUG AND HOLD FOR 5 MIN. - BLEED PRESSURE TO 0 PSI. CHECK FLOATS (OK) CEMENT IN PLACE @ 12:41 HOURS 13:00 - 14:00 1.00 CEMT P SURF RIG DOWN SURFACE CIRCULATING LINE AND HALIBURTON CEMENTING HEAD - REMOVE ADAPTOR SWEDGE - DRAIN AND FLUSH DIVERTER SYSTEM - BACK OUT AND LAY DOWN LANDING JOINT - CLEAR RIG FLOOR 14:00 - 16:00 2.00 CEMT P SURF HOLD PRE JOB SAFETY MEETING - REMOVE 16" HYDRAULIC KNIFE VALVE AND DIVERTER LINE - NIPPLE DOWN 211/4 2M ANNULAR, DIVERTER SPOOL, AND FMC QUICK CONNECT 16:00 - 17:00 1.00 DRILL N DPRB SURF FLUTED HANGER HYDRAULlCED OUT OF HOLE 24" SINCE PLUG WAS BUMPED - RIG UP CASING TOOLS AND PICK UP LANDING JOINT 17:00 - 18:00 1.00 DRILL N DPRB SURF PICK UP ON CASING STRING TO 150K INCLUDING TOP DRIVE WEIGHT - SET EMERGENCY SLIPS IN TENSION WITH 80K ( (' Printed: 11/19/2001 10:04:11 AM BP EXPLORATION Page 4 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/10/2001 18:00 - 21 :00 3.00 DRILL N DPRB SURF BACK OUT AND LAY DOWN LANDING JOINT - MAKE ROUGH CUT ON 10 3/4" CASING - MAKE FINAL CUT - INSTALL TRANSITION NIPPLE - PRE HEAT AND WELD- POST HEAT AND WRAP FOR COOL DOWN PEROID 21 :00 - 00:00 3.00 DRILL P INT1 CLEAN MUD SYSTEM - PICK UP 50 STANDS OF 5" DRILL PIPE IN MOUSE HOLE FOR NEXT HOLE SECTION AND STAND BACK IN MAST. 10/11/2001 00:00 - 06:30 6.50 DRILL P INT1 CONTINUE TO PICK UP 50 STANDS OF 5" DRILL PIPE & BHA IN MOUSEHOLE STAND BACK IN MAST FOR NEXT HOLE SECTION 06:30 - 07:30 1.00 DRILL N SFAL INT1 TEST FMC TRANSITION NIPPLE AROUND WELD (FAILED) REWELD NIPPLE AND TEST TO 1750 PSI. (OK) 07:30 - 08:30 1.00 DRILL P INT1 SERVICE TOP DRIVE, TRAVELING BLOCKS, AND CROWN SHEAVES 08:30 - 13:30 5.00 DRILL P INT1 INSTALL FMC CASING HEAD AND TUBING SPOOL - NIPPLE UP BOP AND RELATED EQUIPMENT - TEST METAL TO METAL SEAL (OK) -INSTALL BELL NIPPLE AND FLOW LINE - HOOKUP TURNBUCKLES AND INSTALL SECOND LOWER ANNULUS VALVE. 13:30 - 14:30 1.00 DRILL P INT1 INSTALL BOP TEST PLUG - RIG UP TEST EQUIPMENT 14:30 - 20:00 5.50 DRILL P INT1 TEST BOP EQUIPMENT - TEST ANNULAR AT THE FOLLOWING PRESSURES 250 LOW & 2,500 PSI HIGH - TEST UPPER AND LOWER PIPE RAMS, BLIND RAMS, CHOKE MANIFOLD, MANUAL AND HCR VALVES ON CHOKE AND KILL LINES, FULL OPENING SAFETY VALVE AND DART VALVE, TOP DRIVE UPPER AND LOWER IBOP VALVES AT THE FOLLOWING PRESSURES 250 LOW AND 3,500 PSI HIGH - PREFORM ACCUMULATOR TEST AND CHECK H2S AND LEL GAS MONITORS 20:00 - 20:30 0.50 DRILL P INT1 CIRCULATE THRU CHOKE MANIFOLD TO POOR BOY GAS BUSTER - INSTALL LONG WEAR RING & RIG DOWN TESTING EQUIPMENT - BLOW DOWN CHOKE LINES 20:30 - 23:00 2.50 DRILL P INT1 MAKE UP BHA NO.2 - PICK UP SPERRY MUD MOTOR & MAKE UP PDC BIT, MAKE UP MWD TOOLS AND ADJUSTABLE STABILIZER - RIH WITH BHA - SURFACE TEST MWD TOOLS AND MUD MOTOR 23:00 - 00:00 1.00 DRILL P INT1 BLOW DOWN MUD LINE AND TOP DRIVE - RIH WITH 5" DRILL PIPE FROM MAST 10/12/2001 00:00 - 01 :00 1.00 DRILL P INT1 RIH WITH 5" DRILL PIPE FROM MAST FROM 1,677' TO 2,736', WASH LAST STAND DOWN TO 2,802' 01 :00 - 02:00 1.00 DRILL P INT1 CIRCULATE AND CONDITION MUD FOR CASING TEST (GOOD 9.1 PPG MUD AROUND) 02:00 - 03:00 1.00 DRILL P INT1 BREAK OFF TOP DRIVE AND BLOW DOWN, RIG UP HEAD PIN FOR CASING TEST - TEST 10 3/4" CASING AT 1,500 PSI. FOR 30 MINUTES (GOOD TEST) - RIG DOWN TEST EQUIPMENT 03:00 - 04:30 1.50 DRILL P INT1 BREAK CIRCULATION AND DRILL CEMENT STRINGERS FROM 2,802' AND TAG WIPER PLUGS AT 2,818' & TOP OF FLOAT COLLAR AT 2,820' - DRILL FLOAT COLLAR AND CEMENT TO TOP OF FLOAT SHOE AT 2,904' - DRILL FLOAT SHOE TO 2,906' - WASH 131/2" RAT HOLE TO 2,916' - DRILL NEW 9 7/8" HOLE TO 2,936' 04:30 - 05:00 0.50 DRILL P INT1 CIRCULATE BOTTOMS UP AND CONDITION MUD FOR FIT , ( (' Printed: 11/19/2001 10:04:11 AM f ( BP EXPLORATION Page 5 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/12/2001 05:00 - 05:30 0.50 DRILL P INT1 PREFORM FORMATION INTEGRITY TEST - INJECTING AT 180 PSI. WITH 9.1 PPG MUD -EMW AT 10.5 - CHECK SURFACE EQUIPMENT AND SWAP MUD PUMPS - VERIFY FINDINGS WITH SECOND FIT TEST. 05:30 - 06:30 1.00 DRILL N DPRB INT1 CIRCULATE AND CONDITION MUD AT SLOW RATE WHILE GETTING INPUT FROM DRILLING ENGINEER AND DRILLING SUPERINTENDENT 06:30 - 07:00 0.50 DRILL P INT1 DRILL AHEAD FROM 2,936' TO 2,966' 07:00 - 08:00 1.00 REMCM N DPRB INT1 CIRCULATE BOTTOMS UP - PUMP DRY JOB - BLOW DOWN TOP DRIVE - MONITOR WELL (STATIC) 08:00 - 11 :00 3.00 REMCM N DPRB INT1 POH WITH 5" DRILL PIPE - DOWN LOAD MWD DATA- STAND BACK BHA AND CLEAR RIG FLOOR 11 :00 - 12:00 1.00 REMCM N DPRB INT1 RIH WITH MULE SHOE ON 5" DRILL PIPE TO 2,966' 12:00 - 14:00 2.00 REMCM N DPRB INT1 CHANGE OUT BALES TO LONGER SET - INSTALL HEAD PIN & CIRCULATE HOLE CLEAN 14:00 - 14:30 0.50 REMCM N DPRB INn HOLD PRE JOB SAFETY MEETING WITH ALL PERSONAL INVOLVED IN SQUEEZE CEMENT OPERATION. 14:30 - 15:00 0.50 REMCM N DPRB INn TURN OVER TO HALIBURTON ENERGY SERVICES - PUMP 5 BBLS. WATER - TEST SURFACE EQUIPMENT AT 2,000 PSI. - PUMP 11 BBLS WATER FOLLOWED UP WITH 79 BBLS. PREMIUM 15.8 PPG CEMENT SLURRY - DISPLACE DRILL PIPE WITH 6 BBLS. WATER AND 30 BBLS. 9.1 PPG MUD TO BALANCE CEMENT PLUG. 15:00 - 16:00 1.00 REMCM N DPRB INn POH SLOW THRU CEMENT TO 1,913' 16:00 - 16:30 0.50 REMCM N DPRB INn REVERSE CIRCULATE TWO DRILL PIPE VOLUMES -10 BBLS +1- CEMENT CONTAIMANTED MUD BACK TO SURFACE 16:30 - 18:00 1.50 REMCM~ N DPRB INn SHUT WELL IN FOR SQUEEZE OPERATION - ESTABLISH INJECTION RATE 4 BPM AT 200 PSI. - STAGE 30 BBLS INTO FORMATION PRESSURE INCREASE TO 400 PSI.- STAGED 10 MORE BBLS. PRESSURE AT 400 PSI.- STAGED 5 MORE BBLS. PRESSURE AT 360 PSI. - STAGED 1 BBL. FINAL PRESSURE AT 350 PSI. WITH 46 TOTAL BBLS. CEMENT INTO FORMATION AND 31 BBLS. CEMENT CALCULATED IN CASING. 18:00 - 22:00 4.00 REMCM N DPRB INT1 HOLD PRESSURE ON CEMENT PLUG - FOLLOWING PRESSURE RECORDED: 19:00 HOURS 250 PSI. 20:00 HOURS 240 PSI. 21 :00 HOURS 230 PSI. 22:00 HOURS 220 PSI. BLEED OFF PRESSURE - MONITOR WELL (STATIC) 22:00 - 22:30 0.50 REMCM N DPRB INT1 CIRCULATE BOTTOMS UP - PUMP DRY JOB 22:30 - 23:30 1.00 REMCM"N DPRB INT1 POH WITH 5" DRILL PIPE FROM 1,913' & STAND BACK IN MAST 23:30 - 00:00 0.50 REMCM N DPRB INT1 MAKE UP BHA 10/13/2001 00:00 - 02:00 2.00 DRILL N DPRB INT1 MAKE UP HAND OFF SUB - INITIALIZE MWD TOOL - MAKE UP FLEX DRILL COLLARS, JARS, AND HWDP - SURFACE TEST MWD TOOL AND SPERRY MUD MOTOR 02:00 - 03:00 1.00 DRILL N DPRB INT1 RIH WITH 5" DRILL PIPE FROM MAST TO 1,865' - BREAK CIRCULATION - BLOW DOWN MUD LINES AND TOP DRIVE 03:00 - 06:00 3.00 DRILL N DPRB INT1 WAIT ON CEMENT - CLEAN RIG FLOOR AND CELLAR Printed: 11/19/2001 10:04:11 AM ( (' BP EXPLORATION Page 6 of.25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/13/2001 06:00 - 08:30 2.50 DRILL N DPRB INn RIH FROM 1,865' TAG CEMENT STRINGERS @ 2,230'- WASH AND REAM FROM 2,230' TO 2,700' (FIRM CEMENT)- DRILL CEMENT FROM 2,700' TO 2,936' 08:30 - 09:00 0.50 DRILL N DPRB INT1 CIRCULATE CEMENT OUT AND CONDITION MUD FOR FORMATION INTEGRITY TEST 09:00 - 09:30 0.50 DRILL N DPRB INT1 PREFORM FORMATION INTEGRITY TEST AT 2,936' MD & 2,406' ND WITH 9.2 PPG MUD - LEAK OFF AT 400 PSI. GIVING EQUALlVANT MUD WEIGHT OF 12.4 PPG. 09:30 - 10:00 0.50 DRILL N DPRB INT1 DRILL CEMENT FROM 2,936' TO 2,966' - DRILL 20' OF NEW 97/8" HOLE FROM 2,966' TO 2,986' 1 0:00 - 1 0:30 0.50 DRILL N DPRB INT1 CIRCULATE BOTTOMS UP 10:30 - 11 :00 0.50 DRILL N DPRB INT1 PREFORM FORMATION INTEGRITY TEST AT 2,986' WITH 9.2 PPG MUD - LEAK OFF AT 370 PSI. GIVING EQUALlVANT MUD WEIGHT OF 12.1 PPG. 11 :00 - 00:00 13.00 DRILL P INn DRILL AHEAD FROM 2,986' TO 5,434' - WEIGHT ON BIT 3K TO 10K - PUMP RATE AT 550 GPM - OFF BOTTOM PUMP PRESSURE AT 1800 PSI. & ON BOTTOM PUMP PRESSURE AT 2,100 PSI. - TOP DRIVE AT 70 TO 110 RPM MUD MOTOR AT 176 RPM - OFF BOTTOM TORQUE AT 4K & ON BOTTOM TORQUE AT 7K - ROTATING STRING WEIGHT AT 120K - WITH PUMPS ON DRAG UP AT 145K AND DRAG DOWN AT 1 05K. 10/14/2001 00:00 - 01 :00 1.00 DRILL P INT1 CIRCULATE SWEEP AROUND - MONITOR WELL (STATIC) 01 :00 - 05:00 4.00 DRILL P INT1 STAND BACK FIRST STAND (KELLY) POH SLOW STARTING TO SWAB ON SECOND STAND - PUMP OUT OF THE HOLE FROM 5,247' TO 4,212' - BACK REAM OUT OF THE HOLE FROM 4,212' TO 3,648' - PUMP OUT OF THE HOLE FROM 3,648' TO 2'897' - MONITOR WELL AT SHOE (STATIC) - BLOW DOWN TOP DRIVE AND MUD LINE. 05:00 - 05:30 0.50 DRILL P INn SERVICE TOP DRIVE, TRAVELING BLOCKS, AND CROWN SHEAVES 05:30 - 06:30 1.00 DRILL P INT1 RIH FROM 2,897' TO 5,100' - HOLE TIGHT - BREAK CIRCULATION 06:30 - 07:30 1.00 DRILL P INT1 WASH AND REAM FROM 5,100' TO BOTTOM AT 5,434' 07:30 - 08:00 0.50 DRILL P INT1 CIRCULATE BOTTOMS UP 08:00 - 09:30 1.50 DRILL P INT1 DRILL AHEAD FROM 5,434' TO 5,598' - MWD FAILURE 09:30 - 10:00 0.50 DRILL N DFAL INT1 CIRCULATE BOTTOMS UP FOR TRIP 10:00 - 14:00 4.00 DRILL N DFAL INT1 PUMP OUT OF THE HOLE FROM 5,598' TO 4,683' (NO PROBLEMS) - PUMP DRY JOB & CONTINUE TO POH TO SPERRY MWD TOOL. 14:00 - 16:00 2.00 DRILL N DFAL INT1 DOWN LOAD SPERRY MWD TOOL - FOUND CEMENT IN BAFFLE PLATE LOCATED IN HANG OFF SUB - CHANGE PROBE AND INITIALIZE SPERRY MWD TOOL 16:00 - 16:30 0.50 DRILL N DFAL INT1 RIH WITH BHA SURFACE TEST MWD TOOL 16:30 - 19:30 3.00 DRILL N DFAL INT1 FOUND CEMENT IN TOP OF HWDP - REMOVE DRILL PIPE FROM SERVICE USED DURING SQUEEZE JOB OPERATION - REARRANGE PIPE IN MAST - LOAD PIPE SHED WITH 93 JOINTS OF 5" DRILL PIPE - THAW OUT AND SLM 19:30 - 23:00 3.50 DRILL N DFAL INT1 PICK UP AND RABBIT 93 JOINTS OF 5" DRILL PIPE FROM PIPE SHED AND RIH - CIRCULATE DRILL PIPE VOLUME AND TEST MUD TOOL - RIH WITH 5" DRILL PIPE FROM Printed: 11/19/2001 10:04:11 AM BP EXPLORATION Page 7 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/14/2001 19:30 - 23:00 3.50 DRILL N DFAL INT1 MAST TO 5,530' - BREAK CIRCULATION AND WASH TO BOTTOM AT 5,598' (NO PROBLEMS OR FILL ON TRIP IN HOLE) 23:30 - 00:00 0.50 DRILL P INT1 DRILL AHEAD FROM 5,598' TO 5,810' - WEIGHT ON BIT 3K TO 10K PUMP RATE AT 550 GPM - OFF BOTTOM PUMP PRESSURE AT 1800 PSI. & ON BOTTOM PUMP PRESSURE AT 2,100 PSI. - TOP DRIVE AT 70 TO 110 RPM MUD MOTOR AT 176 RPM - OFF BOTTOM TORQUE AT 4K & ON BOTTOM TORQUE AT 7K - ROTATING STRING WEIGHT AT 120K - WITH PUMPS ON DRAG UP AT 145K AND DRAG DOWN AT 1 05K. 10/15/2001 00:00 - 00:30 0.50 DRILL P INT1 WASH AND REAM HOLE SECTION FROM 5,717' TO 5,810' 00:30 - 01 :00 0.50 DRILL N FLUD INT1 CHANGE SHAKER SCREENS - BLINDING OFF 01 :00 - 03:00 2.00 DRILL P INT1 DRILL AHEAD FROM 5,810' TO 6,093' 03:00 - 03:30 0.50 DRILL N SFAL INT1 FOUND 5/8" NUT ON CROSS MEMBER BEAM IN MAST JUST ABOVE DERRICKMANS MONKEY BOARD ON DRAW WORKS SIDE OF MAST DRILLERS SIDE - PREFORM MAST INSPECTION 03:30 - 07:30 4.00 DRILL P INT1 DIRECTIONAL DRILL AHEAD FROM 6,093' TO 6,656' 07:30 - 08:00 0.50 DRILL N RREP INT1 REMOVE AND TIGHTEN BOLT ON VARCO TOP DRIVE 08:00 - 16:30 8.50 DRILL P INT1 DRILL AHEAD FROM 6,656' TO 7,951' - WEIGHT ON BIT 5K TO 20K PUMP RATE AT 550 GPM - OFF BOTTOM PUMP PRESSURE AT 2000 PSI. & ON BOTTOM PUMP PRESSURE AT 2,300 PSI. - TOP DRIVE AT 100 RPM MUD MOTOR AT 176 RPM - OFF BOTTOM TORQUE AT 10K & ON BOTTOM TORQUE AT 12K - ROTATING STRING WEIGHT AT 130K- WITH PUMPS ON DRAG UP AT 190KAND DRAG DOWN AT 90K. 16:30 - 17:30 1.00 DRILL P INT1 CIRCULATE SWEEPS AROUND AND CIRCULATE HOLE CLEAN 17:30 - 21 :00 3.50 DRILL P INT1 MONITOR WELL BORE (STATIC) FOR SHORT TRIP - POH FROM 7,971' TO 7,503' START PULLING 10K TO 15K ABOVE NORMAL UPWARD DRAG AND SWABING - PUMP OUT OF THE HOLE WHILE BACK REAMING TO 5,530' - MONITOR WELL AND ADJUST TOP DRIVE MOTOR ALIGNMENT CYLINDER. 21 :00 - 23:30 2.50 DRILL P INT1 RIH FROM 5,530' TO 7,700' (NO PROBLEMS) - WORK THRU TIGHT AREA AT 7,700 TO 7,794' - CONTINUE TO WASH TO BOTTOM AT 7,971' 23:30 - 00:00 0.50 DRILL P INT1 DRILL AHEAD FROM 7,971' TO 8,157' 10/16/2001 00:00 - 00:30 0.50 DRILL P INT1 DRILLED FROM 8065-8158 FT. 00:30 - 01 :00 0.50 DRILL N SFAL INT1 GENERATOR #2 OFF LINE. 01 :00 - 10:30 9.50 DRILL P INT1 DRILLED FROM 8158-9378 FT. 80-120 RPM, 5-20K WOB, 533 GPM. 2200 PSI ON BTM, 2400 PSI OFF BTM PUW 215K, SOW 80K, ROTW 135K, TQ ON BTM 16K, TQ OFF BTM 13K. ADDING DRILL N SLIDE LUBRICANT TO MUD SYSTEM TO 3.5% CONCENTRATION. 10:30 - 11 :00 0.50 DRILL P INT1 CIRCULATE BOTTOMS UP & WAIT ON ORDERS FROM GEOLOGIST. 11 :00 - 21 :30 10.50 DRILL P INT1 DRILLED 9378-10355 FT MD. LANDED INTERMEDIATE HOLE IN TOP OF OB SAND PER GEOLOGIST ON-SITE. PUW 225K, SOW 90K, ROTW 135K, WOB 10K, RPM 100, 2350 PSI ON BTM, 2300 PSI OFF BTM. 15K TORQUE ON ( ( Printed: 11/19/2001 10:04:11 AM (' ( BP EXPLORATION Page 8 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/16/2001 11 :00 - 21 :30 10.50 DRILL P INT1 BTM. 12K TORQUE OFF BTM. 10.9 ECD WITH 9.5 PPG MUD. 21 :30 - 00:00 2.50 DRILL P INT1 PUMP 25 BBL VISCOUS SWEEP & CIRCULATE HOLE CLEAN PRIOR TO SHORT TRIP TO 10 3/4" CASING POINT. 10/17/2001 00:00 - 00:30 0.50 DRILL P INT1 CONTINUE TO CIRCULATE HOLE CLEAN. MONITOR WELL FOR 10 MINS. HOLE STABILE. 00:30 - 01 :30 1.00 DRILL P INT1 POOH 10355 TO 10038 & WELL STARTED SWABBING. PUMP OUT 10038-9473. HOLE PACKING OFF. 01 :30 - 06:00 4.50 DRILL P INT1 BACK-REAM & PUMP 9473-7408. PUMP OUT 7408-7126'. 06:00 - 08:30 2.50 DRILL P INT1 PUMP DRY JOB. BLOW-DOWN TOP DRIVE & MUD LINE. POOH 7126-2897 FT. TIGHT AT 6785'. 08:30 - 10:00 1.50 DRILL P INT1 CUT & SLIP 108' DRILLING LINE. 10:00 - 11 :00 1.00 DRILL P INT1 RIG SERVICE TOP DRIVE & CROWN. 11 :00 - 15:00 4.00 DRILL P INT1 RIH 2897' TO 10355'. FILLING DRILL PIPE EVERY 15 STANDS. 15:00 - 19:00 4.00 DRILL P INT1 CIRCULATE & CONDITION MUD. PUMP VISCOUS SWEEP. SPOT 7 PPB STICKLESS GLASS BEADS IN OPEN HOLE. 19:00 - 00:00 5.00 DRILL P INT1 POOH 5 STANDS. HOLE IN GOOD CONDITION WITH NO EXCESSIVE DRAG. PUMP SLUG. POOH 5 ADDITIONAL STANDS. PUW 230K, SOW 100K, ROTW 140K, TORQUE 15KAT 20 RPM WITH PUMPS OFF. POOH RECORDING WEIGHTS AND TORQUE EVERY 500 FT. 10/18/2001 00:00 - 05:30 5.50 DRILL P INT1 POOH LDDP FROM 3648 TO 2830 FT. WET PIPE. ATTEMPT TO PUMP DRY JOB & FOUND DRILL STRING PLUGGED OFF. CONTINUE POOH 2830-267'. 05:30 - 09:00 3.50 DRILL P INT1 LD BHA & FOUND IT PACKED OFF WITH GLASS BEADS. DOWNLOAD MWD. 09:00 - 11 :30 2.50 DRILL P INT1 CLEAR FLOOR FOR BHA. ATTEMPT TO PULL WEAR RING. PULLED 30-50K OVER & WEAR RING CAME FREE. METAL SHAVINGS FOUND ON OUTSIDE. REMOVE RUNNING TOOL. 11 :30 - 12:30 1.00 DRILL P INT1 MEETING WITH BP DRILLING SUPT. BOTH CREWS. 12:30 - 13:30 1.00 CASE P INT1 CHANGE TOP RAMS FROM 3 1/2" X 6" TO 7". 13:30 - 14:30 1.00 CASE P INT1 TEST RAM DOOR SEALS TO 1000 PSI. RD TEST TOOLS. 14:30 - 15:30 1.00 CASE P INT1 RU CSG RUNNING TOOLS ON FLOOR. 15:30 - 16:00 0.50 CASE P INT1 PLANNING & SAFETY MEETING ON RUNNING 7 INCH HYDRIL 521 CASING, RIGGING UP DRIVE BUSHINGS, & RUNNING IN HOLE. 16:00 - 19:00 3.00 CASE P INT1 RIH W/7 INCH HYDRIL 521 CASING TO 2880 FT. RECORD PUW 130K, SOW 11 OK, ROTW 120K, & TORQUE 4K. 19:00 - 19:30 0.50 CASE P INT1 CIRCULATE BOTTOMS UP. 19:30 - 00:00 4.50 CASE P INT1 RIH TO 6315 FT(150 JTS IN) & PIPE STARTED "FLOATING" & STACKING OUT WEIGHT. BEGIN ROTATING & CIRCULATING EVRY JOINT 54 SPM, 240 GPM, 350 PSI. 15-20 RPM, 15K TORQUE, 130 ROTW, 70 SOW, 170 PUW. ROTATE & CIRCULATE TO 6555'. 10/19/2001 00:00 - 01 :00 1.00 CASE P INT1 CONTINUE RIH WASHING AND ROTATING EACH JT DOWN 6805 FT(170 JTS) 55 SPM, 240 GPM, 350 PSI. 15-20 RPM, 15K TORQUE, 130 ROTW, 70 SOW, 170 PUW. 01 :00 - 02:00 1.00 CASE P INT1 CIRCULATE BOTTOMS UP AT 6805'. 02:00 - 13:00 11.00 CASE P INT1 ATTEMPT TO RUN WITHOUT PUMPING OR ROTATING BUT WE COULD ONLY RUN 2JTS BEFORE CASING STARTED FLOATING. WASH AND REAM EACH JTTO Printed: 11/19/2001 10:04:11 AM BP EXPLORATION Page 9 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/19/2001 02:00 - 13:00 11.00 CASE P INT1 BOTTOM WITH 55 SPM ,240GPM, AND 350 PSI. 15-18,000 FT LBS TORQUE. 13:00 - 14:00 1.00 CASE P INT1 MAKE UP LANDING JT AND ATTEMPT TO RUN IN HOLE WITH PUMPS. WEIGHT STACKED OUT. PULLED PIPE OUT OF HOLE IN ATTEMPT TO WORK IT AND STARTED LOOSING HOLE. UD LANDING AND MAKE UP LAST JT OF CASING. 14:00 - 16:30 2.50 CASE P INT1 CIRCULATE DOWN LAST JT. INCREASE PUMP RATE TO 10 BPM WITH NO LOSSES WITH 650 PSI. TORQUE 20-25,000 FT LBS. ATTEMPT TO WORK PIPE DOWN WITHOUT ROTATING AND COULD NOT. CIRCULATE TWO MORE BOTTOMS UP. 16:30 -19:00 2.50 CASE P INT1 PJSM. TEST LINES 3500 PSI. PUMP 20 BBLS WATER. MIX AND PUMP 70 BBLS 10.5 ALPHA SPACER, 240 BBLS 15.8 PPG"G" CEMENT. FOLLOW CEMENT WITH 1 0 BBLS WATER AND DISPLACE WITH RIG PUMPS. BUMP PLUG 2900 PSI. CIP @ 18:45. FLOAT HELD. FULL RETURNS ENTIRE JOB. 19:00 - 19:30 0.50 CASE P INT1 BLOW-DOWN TOP DRIVE, MUD LINE, & CMT LINE. RIG DOWN CEMENT HEAD. REMOVE FLOW LINE. RU BRIDGE CRANE. SPLIT BOP STACK AT TUBING SPOOL. 19:30 - 00:00 4.50 CASE P INT1 PU BOP STACK. PULL 1 OOK TENSION. SET SLIPS. ROUGH CUT 7" & LD LANDING JT. FINAL CUT & DRESS 7" STUB. PU RUNNING TOOL ON 1 STAND HWDP & INSTALL PACK-OFF. NU BOP STACK. TEST PACK-OFF TO 4000 PSI OK. 10/20/2001 00:00 - 04:00 4.00 CASE P INT1 CHANGE 7" RAMS TO 3 1/2 X 6" RAMS. NU FLOWLINE, CENTER BOPS. LA YDOWN CASING & CEMENTING TOOLS. CHANGE-OUT TOP DRIVE & IRON ROUGHNECK TO 31/2" SLIPS & ELEVATORS. 04:00 - 11 :00 7.00 CASE P INT1 TEST BOP'S, ANNULAR, & CHOKE MANIFOLD TO 250 PSI LOW & 3500 PSI HIGH. AOGCC WAIVED WITNESSING TEST(LOU GRIMALDI). 11 :00 - 12:30 1.50 CASE P INT1 PUMP THROUGH CHOKE & GAS BUSTER OK. BLOW DOWN MUD LINE, RU TO LD 5 INCH DRILLPIPE. LAYDOWN LONG BAILS & INSTALL SHORT BAILS & 51N ELEVATORS. 12:30 - 18:30 6.00 CASE P INT1 LAYDOWN 2 HWDP & 133 JTS 51N DP FROM DERRICK. LAY DOWN 5 INCH TOOLS. INSTALL WEAR RING. 18:30 - 22:00 3.50 CASE P INT1 SINGLE IN HOLE WITH 99 JTS 3 1/2" DRILLPIPE. 22:00 - 23:30 1.50 CASE P INT1 STAND BACK 33 STANDS 31/2 DRILLPIPE. CLEAR FLOOR. 23:30 - 00:00 0.50 CASE P INT1 PJSM. START PU 61/8" BHA. 10/21/2001 00:00 - 02:30 2.50 DRILL P PROD1 CONTINUE MAKING UP 61/8" BHA. MU MWD, HOC. ORIENT & UPLOAD MWD. PU 3 FLEX NMDC, SMITH HYDRAULIC JARS ON 2 JTS 31/2" DP. 02:30 - 13:00 10.50 DRILL P PROD1 PICK UP 31/2" DP FROM PIPE SHED & RUN IN HOLE TO 8240'. 13:00 - 14:00 1.00 DRILL P PROD1 HOLE DRAG CAUSING DRILLSTRING TO STACK OUT WEIGHT. SPOT EP MUD LUBE & CIRCULATE. BLOW DOWN TOP DRIVE & MUDLlNE. 14:00 - 15:30 1.50 DRILL P PROD1 RIH PICKING UP 31/2" DP TO 9147'. ( ( Printed: 11/19/2001 10:04:11 AM ( ( BP EXPLORATION Page 10 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/21/2001 15:30 - 16:30 1.00 DRILL P PROD1 CIRCULATE & SPOT EP MUD LUBE TO REDUCE HOLE DRAG & INCREASE RIH SPEED. BLOW DOWN TOP DRIVE & MUDLlNE. 16:30 - 17:00 0.50 DRILL P PROD1 RIH & TAG FLOAT COLLAR AT 10265'. 17:00 - 18:00 1.00 DRILL P PROD1 CIRCULATE BOTTOMS UP. 18:00 - 19:00 1.00 DRILL P PROD1 PRESSURE TEST CASING TO 3500 PSI FRO 30 MINS. BLOW-DOWN KILL LINES 19:00 - 20:30 1.50 DRILL P PROD1 DRILL OUT FLOAT COLLAR, SHOE TRACK, AND REAMING SHOE TO 10355'. MWD SIGNAL FADING. MUD WAS AIRED UP AND CEMENT CONTAMINATED(TREATED WI BICARB) AND ASSUMPTION WAS MADE THAT THIS WAS CAUSING THE MWD PULSE RECEPTION PROBLEMS. DECIDED TO GO AHEAD WITH MUD SWAP AS ALL TRUCKS WERE ON LOCATION AND STANDING BY. PRE-TREATED CASING WITH EP MUD LUBE PRIOR TO DISPLACING MUD. 20:30 - 22:30 2.00 DRILL P PROD1 DISPLACED 9.5 PPG LSND "OLD" MUD WITH 9.2 PPG "NEW" BARADRILLN. STAND PIPE PRESSURE SPIKED 1000 PSI AT 2130 HRS WHILE CIRCULATING AT 230 GPM STEADY. MWD SIGNAL COMPLETELY LOST. 22:30 - 00:00 1.50 DRILL N DFAL PROD1 MIX & PUMP 25 BBL, 11 PPG WEIGHTED DRY JOB. START TO TRIP OUT OF HOLE TO INVESTIGATE MWD COMMUNICATION PROBLEMS. 10/22/2001 00:00 - 04:00 4.00 DRILL N DFAL PROD1 POOH FROM 10297 TO 10267 FT. 04:00 - 07:00 3.00 DRILL N DFAL PROD1 FOUND SPACERS DAMAGED BETWEEN DIRECTIONAL MODULE AND HCIM MODULE. PULSER WAS IMPROPERLY INSTALLED RESULTING IN ELECTRICAL FAILURE BETWEEN TOOLS. PRESSURE SPIKES OBSERVED PRIOR TO TOOL FAILURE WERE PROBABLY DUE TO TEFLON SPACER DEBRIS IN FLOW DIVERTER. CHANGE OUT DM, HCIM TOOL. PU MWD TOOL FROM PIPE SHED. MU MWD(GR-RES-PWD) AND UPLOAD MWD. 07:00 - 09:00 2.00 DRILL N DFAL PROD1 FOUND PULSER IN HOC WAS OUT OF ADJUSMENT. BROKE OUT AND RESET TOOL. MU HOC, UPLOAD MWD. MU FLEX NMDC'S, AND JARS ON 1 STAND DP. SURFACE TEST MWD WI PUMPS ON OK. 09:00 - 12:30 3.50 DRILL N DFAL PROD1 TIH TO 10355 FT. FILLING PIPE EVERY 25 STANDS. 12:30 - 13:00 0.50 DRILL P PROD1 RIG SERVICE TOP DRIVE. 13:00 - 13:30 0.50 DRILL P PROD1 DRILL 10355 TO 10385 FT. 13:30 - 14:30 1.00 DRILL P PROD1 CIRCULATE BOTTOMS UP. 14:30 - 15:00 0.50 DRILL P PROD1 CONDUCT F.I.T. TO 11.1 EMW. 15:00 - 00:00 9.00 DRILL P PROD1 DRILL FROM 10385 TO 11011 FT. 10/23/2001 00:00 - 23:30 23.50 DRILL P PROD1 DRILL AHEAD IN OB LATERAL FROM 11011 TO 13243 FT. PUW 120K, SOW 90K, ROTW 120K, TO ON BTM 4K, TO OFF BTM 3K, 56 SPM, 238 GPM, 2950 PSI ON BTM, 2600 PSI OFF BTM, 90 RPM ROTARY, 250 RPM MOTOR. 23:30 - 00:00 0.50 DRILL P PROD1 WHILE MAKING CONNECTION AND TAKING DIRECTIONAL SURVEY DRILLER OBSERVED FLOW INDICATION. TOP PIPE RAMS WERE SHUT-IN. SICP 140 PSI. SIDDP 20 PSI ON CHOKE PANEL GAUGES. LINED UP CHOKE MANIFOLD, OPENED HCR VALVE. DUE TO CONCERNS OVER TOP DRIVE FREEZE-UP IT WAS DECIDED TO Printed: 11/19/2001 10:04:11 AM (' (' BP EXPLORATION Page 11 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/23/2001 23:30 - 00:00 0.50 DRILL P PROD1 INITIATE CIRCULATION AND RAISE MUD WEIGHT TO KILL WEIGHT OF 9.5 PPG. (KICK CALCULATED AT .1 PPG BASED ON INITIAL PRESSURE OBSERVATIONS). 6 BBL PIT GAIN REPORTED. 10/24/2001 00:00 - 03:00 3.00 DRILL N DPRB PROD1 SIDPP-20 PSI. SICP 140 PSI. 6 BBL PIT VOLUME INCREASE(KICK VOLUME 6 BBL) OBSERVED BY DRILLER DRILLPIPE PICKED UP OFF BOTTOM AND CLOSE UPPER PIPE RAMS IN MIDDLE OF JOINT. WELL CONTROL CALCULATIONS INDICATE A 0.1 PPG KICK. START PUMPING THROUGH THE CHOKE WITH 9.2 PPG MUD IN THE SURFACE SYSTEM USING THE DRILLER'S METHOD AT 20 SPM WHILE WEIGHTING UP TO 9.4 PPG. MUD LOSSES AT 60-100 BBLS/HOUR 03:00 - 06:00 3.00 DRILL N DPRB PROD1 SHUT DOWN PUMP AND CLOSED CHOKE. 260 PSI SIDPP AND 340 PSI SICP READINGS. WELL CONTROL CALCULATIONS YIELDED 1.4 PPG INFLUX. ORDER 5ÙO BBLS MUD FROM MIXING PLANT. 06:00 - 12:00 6.00 DRILL N DPRB PROD1 CONTINUED CIRCULATING 10 BBL MUD EVERY 15 MINUTES THROUGH TOP DRIVE TO PREVENT FREEZE-UP WHILE WAITING ON MUD. MIX 10.5 PPG KILL MUD IN SURFACE SYSTEM. 12:00 - 16:30 4.50 DRILL N DPRB PROD1 PUMPING 20 SPM, 9.5 MW, CIRCULATING GAS CUT MUD OUT & LOSING 60 BPH. 16:30 - 20:00 3.50 DRILL N DPRB PROD1 SHUT WELL IN. 450 SIDPP, 360 SICP. CONTINUE PUMPING 9.5 PPG MUD. MIXING 10.5 PPG KILL MUD. 20:00 - 22:30 2.50 DRILL N DPRB PROD1 SHUT DOWN PUMP, CLOSED CHOKE, BLEED DOWN STAND PIPE PRESSURE AND AFTER 15 MINS PRESSURES STABILIZED AT 310 SIDPP WITH 350 SICP. EXECUTING 10.5 PPG KILL MUD PUMP SCHEDULE AT 20 SPM. LOSING 75 BBL MUD PER HOUR ADDING LCM AT 5 PPB. 22:30 - 00:00 1.50 DRILL N DPRB PROD1 DECREASE KILL RATE TO 15 SPM ON KILL SCHEDULE IN AN EFFORT TO CURTAIL MUD LOSSES. CONTINUING WITH 10.5 PPG KILL MUD CIRCULATION. LOSING 60 BBL PER HR ADDING LCM AT 5 PPB. 10/25/2001 00:00 - 02:00 2.00 DRILL N DPRB PROD1 CONTINUE WITH 10.5 PPG WELL KILL SCHEDULE AT 15 SPM KILL RATE. SURFACE TO SURFACE STROKE TOTAL 4292 STKS. PUMPED 6200 STROKES AND FINALLY HAD 10.5 PPG KILL MUD RETURN FLOW. LOST 183 BARRELS TOTAL MUD DURING THIS KILL CIRCULATION. SHUT PUMPS & CLOSED CHOKE. RELEASED TRAPPED DRILLPIPE PRESSURE. 02:00 - 02:30 0.50 DRILL N DPRB PROD1 ALLOWED PRESSURES TO STABILIZE AND RECORDED 230 SIDP & 310 SICP. RELIEVED DRILLSTRING PRESSURE AND ALLOWED TO STABILIZE AGAIN. RECORDED 170 PSI SIDP AND 300 PSI SICP AFTER 30 MINS. KILL MUD WEIGHT CALCULATED AT 11.4 PPG AT 3681ND, 10.5 PPG MW, AND 850 PSI SLOW PUMP RATE(20 SPM) CIRCULATING PRESSURE. ADDING 5 PPB LCM (BAROFIBRE) 02:30 - 07:00 4.50 DRILL N DPRB PROD1 RESUME PUMPING 10.5 PPG MUD AT 20 SPM. BEGAN BUILDING 11.0 PPG MUD WEIGHT IN SURFACE SYSTEM IN PREPARATION FOR NEXT KILL CIRCULATION. 10.5 Printed: 11/19/2001 10:04:11 AM (' (' BP EXPLORATION Page 12 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/25/2001 02:30 - 07:00 4.50 DRILL N DPRB PROD1 PPG MUD IN AND OUT. CIRCULATING AT 1100 PSI, 20 SPM. 07:00 - 09:30 2.50 DRILL N DPRB PROD1 CIRCULATE 10.5 PPG MUD AT 20 SPM, 1070 PSI, 120 PSI CHOKE MANIFOLD PRESSURE(ANNULUS). FULL MUD RETURNS METERED. CONTINUED BUILDING 11 PPG KILL MUD IN SURFACE PITS. 09:30 - 15:00 5.50 DRILL N DPRB PROD1 STOPPED PUMP & CLOSE CHOKE. RECORDED 170 PSI SIDP 300 PSI SICP. KILL MUD WEIGHT AGAIN CALCULATES TO 11.4 PPG. START PUMPING 11 PPG MW AT 20 SPM, 1060 PSI, 200 PSI ON THE CHOKE. AFTER 1870 STKS RECORDED 1040 PSI WITH CHOKE FULL OPEN. MUD LOSSES REPORTED AT 8 BPH. PUMPED 220 BBL OVER CALCULATED SURFACE TO SURFACE VOLUME AND MUD WEIGHT OUT STILL RECORDED AT 10.6 PPG. NOTED CHLORIDES MEASUREMENT DROPPED FROM 79000 PPM TO 39000 PPM. 15:00 - 15:30 0.50 DRILL N DPRB PROD1 STOPPED PUMP & CLOSED CHOKE. RECORDED 70 PSI SIDP & 200 PSI SICP. KILL MUD WEIGHT CALCULATES TO 11.4 PPG. 15:30 - 17:00 1.50 DRILL N DPRB PROD1 RESUME 20 SPM CIRCULATION WITH 11.0 PPG MUD WEIGHT WHILE BUILDING 11.5 PPG KILL MUD IN SURFACE PITS. ADDING 5 PPB LCM (BAROFIBRE) ICP 1170 PSI. AT 360 BBLS OVER SURFACE TO SURFACE VOLUME RETURN MUD FINALLY OBSERVED WEIGHING 11.0 PPG. CHLORIDES 63000 PPM. 17:00 - 22:30 5.50 DRILL N DPRB PROD1 STOPPED PUMP & CLOSE CHOKE. PUMP 11.5 PPG MUD PER KILL SCHEDULE AT 1150 PSI INITIAL CIRCULATING PRESSURE CHOKE PRESSURE 10 PSI AT 20 SPM. INCREASED RATE TO 25 SPM. CIRCULATING PRESSUE 1260 PSI WITH CHOKE FULL OPEN. OBSERVING MUD WEIGHT INCREASING TO 11.3 PPG APPROXIMATELY 2000 STROKES PAST SURFACE TO SURFACE VOLUME. 22:30 - 00:00 1.50 DRILL N DPRB PROD1 OBSERVING 11.5 KILL MUD WEIGHT IN RETURN FLOW. PUMPING AT 2.5 BPM & RETURNS MEASURED AT 1.7 BPM. 10/26/2001 00:00 - 01 :30 1.50 DRILL N DPRB PROD1 CONTINUE CIRCULATING 11.5 PPG KILL MUD AT 25 SPM THROUGH FULL OPEN CHOKE AT 1290 PSI STANDPIPE PRESSURE. 0 PSI CHOKE PRESSURE. ADDING BARAFIBRE LCM AT 5-10 PPB. GAS CUT MUD IN RETURN FLOW. 11.5 PPG IN AND 11.4+ PPG OUT. 01 :30 - 02:00 0.50 DRILL N DPRB PROD1 SHUT IN PUMP AND CLOSE CHOKE. RELEASE TRAPPED PRESSURE FROM DRILLSTRING AND ALLOW PRESSURES TO STABILIZE FOR 30 MINS. RECORDED 20 PSI SIDP AND 170 PSI SICP. 800 BBL OF 11.5 KILL MUD PUMPED BEYOND THE SFC TO SFC VOLUME ON THE KILL SCHEDULE. 02:00 - 04:00 2.00 DRILL N DPRB PROD1 RESUME PUMPING 11.5 PPG KILL MUD AT 25 SPM THROUGH FULL OPEN CHOKE AT 1280 PSI SPP. 2.5 BPM IN AND 2.0 BPM OUT. 30 BPH MUD LOSSES TO WELLBORE. 04:00 - 04:30 0.50 DRILL N DPRB PROD1 SHUT DOWN PUMP & CLOSE CHOKE. RELEASE TRAPPED PRESSURE AND ALLOW PRESSURES TO STABILZE IN 30 MINS TO 10 PSI SIDP & 170 PSI SICP. Printed: 11/19/2001 10:04:11 AM BP EXPLORATION Page 13 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/26/2001 04:00 - 04:30 0.50 DRILL N DPRB PROD1 15100 STKS PUMPED THIS CIRCULATION FOR 1077 BBLS PUMPED BEYOND SFC TO SFC VOLUME. 11.5 PPG IN & 11.4 PPG+ GAS CUT MUD RETURNS. WELL CONTROL CALCULATIONS INDICATE AN 11.6 PPG MUD WEIGHT REQUIREMENT. 04:30 - 05:00 0.50 DRILL N DPRB PROD1 RESUMED CIRCULATION AT 25 SPM. BEGIN WEIGHT UP TO 11.6 PPG KILL MUD WEIGHT. ORDERED OUT 300 BBLS 11.6 PPG MUD (BARITE, BARAZAN, STARCH). LOSING 36 BPH TO WELLBORE. 05:00 - 06:00 1.00 DRILL N DPRB PROD1 STARTED 11.6 PPG KILL MUD AT 25 SPM AND RE-SET STROKE COUNTER. LOSING 30 BPH MUD. 06:00 - 10:30 4.50 DRILL N DPRB PROD1 PUMPING 11.6 PPG KILL MUD AT 20 SPM. LOSSES SLOWED. 10:30 - 12:00 1.50 DRILL N DPRB PROD1 STOPPED PUMPS & CLOSED CHOKE. 0 PSI SIDP & 140 PSI SICP. CONTINUE PUMPING 11.9 PPG KILL MUD AT 20 SPM. 12:00 - 15:00 3.00 DRILL N DPRB PROD1 PUMPING 11.9 PPG KILL MUD AT 17 SPM. SHUT IN PUMP AND CHOKE AND RECORDED 0 PSI SIDP & 140 PSI SICP. CONTINUE PUMPING AT 17 SPM. 15:00 - 17:00 2.00 DRILL N DPRB PROD1 SHUT IN PUMP AND CHOKE AND RECORDED 0 PSI SIDP & 0 PSI SICP. OPEN PIPE RAMS. NO FLOW. BEGIN CIRCULATING 11.9 PPG MUD THROUGH FLOW LINE. BLOW DOWN CHOKE AND GAS BUSTER. 17:00 - 00:00 7.00 DRILL N DPRB PROD1 BEGIN WORKING DRILL PIPE & ATTEMPT TO FREE UP STUCK BHA. PUT 6000 - 9000 FT-LBF TORQUE IN PIPE & SLACK OFF WEIGHT (TORQUE AND SLUMP). WORK PIPE TO MAXIMUM 374,000 LBF WEIGHT INDICATOR(80% TENSILE PLUS TOP DRIVE WEIGHT). STROKING PIPE MAX 8 FT. CIRCULATING 10 SPM & 1050 PSI. (NEW SLOW PUMP RATE & PRESSURE). 11.9 PPG MW IN 11.5 PPG MUD WEIGHT OUT. 1 BPM IN WITH NO RETURNS. PUMPING 10 BBLS EVERY 15 MINS TO PREVENT SURFACE LINE FREEZING. 10/27/2001 00:00 - 07:00 7.00 DRILL N DPRB PROD1 CONTINUE WORKING DRILL PIPE & ATTEMPT TO FREE UP STUCK BHA. 6000 - 9000 FT-LBF TORQUE IN PIPE & SLACK OFF WEIGHT (TORQUE AND SLUMP). WORK PIPE TO MAXIMUM 374,000 LBF WEIGHT INDICATOR(80% TENSILE PLUS TOP DRIVE WEIGHT). STROKING PIPE MAX 8 FT. CIRCULATING 10 SPM & 1050 PSI. (NEW SLOW PUMP RATE & PRESSURE). 11.9 PPG MW IN 11.5 PPG MUD WEIGHT OUT. 1 BPM IN NO RETURNS. PUMPING 10 BBLS EVERY 15 MINS TO PREVENT FREEZING SURFACE LINES 07:00 - 12:00 5.00 DRILL N DPRB PROD1 WAIT ON SCHLUMBERGER WIRE LINE. SERVICE TOP DRIVE, CROWN, & BLOCKS. LAY DOWN 2 SINGLES. CIRCULATE ACROSS TOP OF WELL. INSTALL DP SAFETY(TIW) VALVE. 12:00 - 17:30 5.50 DRILL N DPRB PROD1 RU SCHLUMBERGER WIRELlNE. SPOT TRUCK & TRAILER. HANG SHEAVES. RU 5000PSI LUBRICATOR W/ GREASE HEAD. REPAIR E-LlNE & CONNECTOR HEAD. MU WIRELlNE BOPE. 17:30 - 19:30 2.00 DRILL N DPRB PROD1 MU 2.125" CHEMICAL CUTTER. 19:30 - 00:00 4.50 DRILL N DPRB PROD1 START IN HOLE WITH CHEMICAL CUTTER. PUMPED ( ( Printed: 11/19/2001 10:04:11 AM BP EXPLORATION Page 14 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/27/2001 19:30 - 00:00 4.50 DRILL N DPRB PROD1 TOOL DOWN DRILLPIPE AT 2.5 BPM, 1400 PSI DOWN TO 10400 FT. LOG CCL UP & CUT 3 1/2" DRILLPIPE AT +1- 10250'. CUTTER POSITIONED 6' BELOW TOOLJOINT. TOOL ENERGIZED TO INITIATE CUT. START PULLING WIRELlNE OUT OF HOLE. LOST 180 BBLS 11.9 PPG MUD TO WELLBORE. NO RETURN CIRCULATION. 10/28/2001 00:00 - 01 :30 1.50 DRILL N STUC PROD1 POOH WITH CHEMICAL CUTTER-CCL TOOL ON E-LlNE WITH APPROX 400 LBS LINE TENSION. TOOL HUNG UP AT 767 FT AND LINE TENSION INCREASED TO 1300 LBS(ROPE SOCKET PULLS OUT AT EST'D 1400 LBS). SCHLUMBERGER CREW SUSPECTS THAT ANCHOR DOGS ARE DRAGGING. PUT MUD PUMP ON LINE AND PUMPED AT 2.5 BPM 1400 PSI. TOOL STARTED MOVING AS DOGS APPARENTLY RETRACTED WITH INCREASED EXTERNAL PRESSURE. 01 :30 - 07:00 5.50 DRILL N STUC PROD1 PULLED CUTTING TOOL INTO LUBRICATOR DRAINED LUBRICATOR, FOUND CUTTING TOOL ANCHOR DOGS STUCK IN TOP TOOL JOINT. PULLED CHEMICAL CUTTERlCCL TOOL UP USING BLOCK HANGING WINCH. RELEASE PRESSURE INSIDE TOOL AND EXPANDED DOGS WERE REMOVED. TOOL WAS LA YED OUT DOWN BEAVER SLIDE BY SCHLUMBERGER PERSONNEL TO SECURE AND DISASSEMBLE. 07:00 - 08:00 1.00 DRILL N STUC PROD1 RIG CREW NOTICED CHEMICAL ODOR ENTERING RIG FROM GROUND LEVEL WHERE SCHLUMBERGER TRUCK WAS WORKING ON CHEMICAL CUTTING TOOL. RIG PERSONNEL WERE EVACUATED TO SAFE BRIEFING AREA. BP PERSONNEL IMMEDIATELY MET WITH SCHLUMBERGER AND DETERMINED THAT A BROMINE TRIFLUORIDE CHEMICAL LEAK WAS IN PROGRESS AT THE "UN-FIRED" CUTTING TOOL CHEMICAL CYLINDER WHERE IT WAS LAYED OUT ON LOCATION. NOTIFICATIONS WERE MADE. 08:00 - 10:00 2.00 DRILL N STUC PROD1 SAFETY STAND DOWN. INVESTIGATE INCIDENT. WARM UP SCHLUMBERGER CHEMICAL CYLINDERS. WARM UP MUD IN PITS TO 70 F. 10:00 -17:15 7.25 DRILL N STUC PROD1 RUN IN WITH 21/8" CHEMICAL CUTTER AND CCL. PUMP TOOLS DOWN DRILL PIPE WITH NO RETURNS. LOST 140 BBL MUD TO FORMATION. MADE CUT AT 10252' E-LlNE MEASUREMENT. SURFACE INDICATIONS THAT TOOL FIRED AND PIPE SEVERED. 17:15 - 20:15 3.00 DRILL N STUC PROD1 POH WITH E-LlNE AND CHEMICAL CUTTER TOOL HUNG UP AT 1945 FT. RU AND PUMP DOWN DRILL PIPE WITH 3.5 BPM AND 1200 PSI. NO RETURNS. SUSPECT THAT ANCHOR DOGS DRAGGING IN TOOL JOINT AS INDICATED BY INCREASED DRAG ACROSS EACH TOOL JOINT. 20:15 - 22:00 1.75 DRILL N STUC PROD1 PULLING TOOL WITH 400-700 LBS DRAG WITH PUMP ON DRILLPIPE AT 3.5 BPM, 1200 PSI. NO RETURNS. WITH THE TOOL AT RIG FLOOR AND STUCK IN THE TOP TOOL JOINT, DRAINED AND PICKED UP LUBRICATOR VENT PRESSURE FROM CUTTING TOOL, ANCHOR DOGS RETRACTED AND REMOVED FROM TOOL. PULLED CHEMICAL CUTTER AND CCL TOOL UP USING BLOCK ( ( Printed: 11/19/2001 10: 04: 11 AM ( (' BP EXPLORATION Page 15 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/28/2001 20:15 - 22:00 1.75 DRILL N STUC PROD1 HANGING WINCH. LA YED CHEMICAL CUTTER-CCL OUT SLIDE AND STARTED TO CLEAR THE RIG FLOOR. 22:00 - 00:00 2.00 DRILL N STUC PROD1 CLEARED FLOOR. RIG DOWN SCHLUMBERGER SHEAVES & LINES. LOWERED BLOCKS AND PICKED UP ON DRILLPIPE. FOUND DRILLPIPE CUT AND SEVERED. CONTINUE RIGGING DOWN SCHLUMBERGER E-LlNE EQUIPMENT. PREPARING TO TOOH WI +1- 10250 FT DRILLPIPE & CUT-OFF JOINT. 10/29/2001 00:00 - 01 :00 1.00 DRILL N STUC PROD1 RIG DOWN SCHLUMBERGER E-LlNE EQUIPMENT. PREPARE TO POH WITH CUT OFF DRILLPIPE. 01 :00 - 01 :30 0.50 DRILL N STUC PROD1 ENGAGE TOP DRIVE ATTEMPT TO CIRCULATE. PUMP 50 BBL AT 2 BPM WITH MINIMAL RETURNS. LOST 45 BBL. 01 :30 - 08:00 6.50 DRILL N STUC PROD1 POH TO 9200'. HOLE FILL NOT CORRECT. FLOW CHECK, WELL STATIC. POH PUMPING OUT EVERY 3 STANDS. 08:00 - 11 :00 3.00 DRILL N RREP PROD1 REPAIR PURGEICOOLlNG AIR BLOWER ON TOP DRIVE. 11 :00 - 13:30 2.50 DRILL N STUC PROD1 POH. HOLE FILL CORRECT. ANNULUS FALLING VERY SLOWLY. RECOVERED 110 1/3 STANDS AND 3' CUT-OFF. CHEMICAL CUTTER MADE A CLEAN CUT. TOP OF FISH AT 10,256' DRILLER'S STEEL LINE MEASUREMENT(SLM). 13:30 - 16:30 3.00 DRILL N STUC PROD1 MAKE UP OVERSHOT ASSEMBLY. RIH TO 977 FT. CIRCULATE WI FULL REURNS 2 BPM 250 PSI. 16:30 - 18:00 1.50 DRILL N STUC PROD1 RIH TO 2863 FT. CIRCULATE LOST CIRCULATION MATERIAL(HEAW SLUDGE) FROM WELLBORE. 3 BPM, 350 PSI WI FULL RETURNS. 18:00 - 20:00 2.00 DRILL N STUC PROD1 RIH TO 3761 FT. CIRCULATE 3 BPM, 350 PSI, FULL RETURNS. CONTINUE TO CIRCULATE UNTIL LCM SLUDGE CLEARS UP OVER SHAKER SCREENS. 20:00 - 22:00 2.00 DRILL N STUC PROD1 RIH TO 4686 FT. CIRCULATE 3 BPM 375 PSI. CIRCULATE UNTIL LCM CLEARED UP OVER SHAKER SCREENS. 22:00 - 00:00 2.00 DRILL N RREP PROD1 REPAIR BLOWER MOTOR ON TOP DRIVE. 10/30/2001 00:00 - 01 :00 1.00 DRILL N RREP PROD1 REPAIR BLOWER MOTOR ON TOP DRIVE. 01 :00 - 02:00 1.00 REMCM N STUC PROD1 RIH FROM 4686' TO 5750'. 02:00 - 03:00 1.00 REMCM N STUC PROD1 CIRCULATE AT 5 BPM 900 PSI. CIRCULATE AND CLEAN UP MUD OVER SHAKERS. 03:00 - 03:30 0.50 REMCM N STUC PROD1 RIH FROM 5750' TO 6780'. 03:30 - 04:30 1.00 REMCM N STUC PROD1 CIRCULATE AT 5 BPM 1000 PSI. CIRCULATE AND CLEAN UP MUD OVER SHAKERS. 04:30 - 08:30 4.00 REMCM N STUC PROD1 RIH FROM 6780' TO 10,230'. CIRCULATE AT 7806',8835' AND 10,230' 08:30 - 10:00 1.50 REMCM N STUC PROD1 CIRCULATE AT 5 BPM 1100 PSI. CIRCULATE AND CLEAN UP MUD OVER SHAKERS. NO MUD LOSSES. OBTAIN SLOW PUMP RATE AT 10, 20 AND 30 SPM. 10:00 - 10:30 0.50 REMCM N STUC PROD1 WASH OVER TOP OF FISH AT 10,256' PUMPING AT I BPM WITH 970 PSI. ESTABLISH CIRCULATION THROUGH FISH. CIRCULATE MUD FROM BOTOM TO TOP OF FISH DEPTH. INCREASE PUMP RATE TO 4 BPM WITH 2000 PSI. LOSING MUD AT 60 BPH. 10:30 - 13:00 2.50 REMCM N STUC PROD1 PULL OFF FROM FISH AND CIRCULATE MUD FROM TOP OF FISH TO SURFACE AT 3 BPM WITH 920 PSI. LOST 56 BBL MUD. Printed: 11/19/2001 10:04:11 AM ( (' BP EXPLORATION Page 16 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/30/2001 13:00 - 13:30 0.50 REMCM N STUC PROD1 POH ONE STAND, MAKE UP 15' PUP JOINT AND RIH TO TOP OF FISH. 13:30 - 14:00 0.50 REMCM N STUC PROD1 RIG UP HALLIBURTON CEMENT LINES. HOLD PJSM WITH CEMENTING CREW AND RIG CREW. 14:00 -15:30 1.50 REMCM N STUC PROD1 PUMP 5 BBL KCL WATER - TEST LINES TO 3000 PSI.- PUMP 15 BBL KCL WATER - PUMP 110 BBLS (540 SACKS) OF 15.8 PPG CLASS 'G' CEMENT WITH THE FOLLOWING ADDITIVES 0.2% HALAD-344 (FLUID LOSS), 0.25% CFR-3 (DISPERSANT) - PUMP 10 BBL FRESH WATER - SHUT DOWN AND TURN OVER TO RIG DISPLACE WITH 61 BBLS 12.0 PPG BARADRILL MUD AT 4 BPM WITH 3160 PSI. 15:30 - 16:00 0.50 REMCM N STUC PROD1 POH WITH (1) SINGLE - BREAK DOWN CEMENT LINE - CONTINUE TO POH STANDING BACK IN MAST (5) STANDS - RIG UP TO REVERSE CIRCULATE 16:00 - 17:00 1.00 REMCM N STUC PROD1 REVERSE CIRCULATE CEMENT 15 BBLS CEMENT BACK TO SURFACE - SHUT DOWN 17:00 - 18:30 1.50 REMCM N STUC PROD1 OPEN ANNULAR AND MONITOR WELL (STATIC) - BLOW DOWN KILL LINE - DROP DRILL PIPE I.D. WIPER AND CIRCULATE BOTTOMS UP - PUMP DRY JOB - RIG DOWN CIRCULATING LINES - BLOW DOWN MUD LINE 18:30 - 21 :30 3.00 REMCM N STUC PROD1 POH WITH 31/2" DRILL PIPE & BAKER OIL TOOLS 21 :30 - 22:30 1.00 REMCM N STUC PROD1 BREAK AND LAY DOWN BAKER OIL TOOLS - CLEAR RIG FLOOR 22:30 - 00:00 1.50 DRILL N STUC PROD1 PICK UP 6 1/8" BIT (OPEN), CASING SCRAPER, (9) 4 3/4" DRILL COLLARS, JARS, (18) 3 1/2" HWDP 10/31/2001 00:00 - 03:30 3.50 DRILL N STUC PROD1 CHANGE OUT BALES AND RIH WITH BIT AND SCRAPER FROM 860' TO 9227' 03:30 - 07:30 4.00 DRILL N STUC PROD1 PJSM CHANGE OUT 1 3/8" DRILLING LINE TO NEW SPOOL 07:30 - 09:00 1.50 DRILL N STUC PROD1 CONTINUE TO RIH FROM 9,227' TAG CEMENT AT 10,230' 09:00 - 09:30 0.50 DRILL N STUC PROD1 WASH AND ROTATE FROM 10.230' TO 10,256' TAG TOP OF FISH 09:30 - 10:30 1.00 DRILL N STUC PROD1 CIRCULATE BOTTOMS UP FOR CASING TEST 10:30 - 11 :30 1.00 DRILL N STUC PROD1 RIG UP TO TEST CASING - MAXIMUM PRESSURE ACHIEVED 610 PSI. BLED BACK TO 250 PSI. -ATTEMPT TO TEST (5) TIMES TOTAL FLUID PUMPED AWAY (14) BBLS. 11 :30 - 12:00 0.50 DRILL N STUC PROD1 CIRCULATE BOTTOMS UP AND CONDITION MUD 12:00 - 12:30 0.50 DRILL N STUC PROD1 HOLD PRE-JOB SAFETY MEETING - ESTABLISH INJECTION RATE INTO FORMATION FOR FUTURE CEMENTING OPERATION 12:30 - 17:00 4.50 DRILL N STUC PROD1 MONITOR WELL BORE (STATIC) - PUMP DRY JOB - BLOW DOWN TOP DRIVE AND MUD LINE - POH WITH 3 1/2" DRILL PIPE STAND BACK IN MAST - LAY DOWN JARS, FLOAT SUB, CASING SCRAPER, AND BIT - CLEAR RIG FLOOR 17:00 - 21 :30 4.50 DRILL N STUC PROD1 PICK UP RUNNING TOOL AND EZSV RETAINER - RIH WITH (18) JOINTS OF 31/2" HWDP AND 31/2" DRILL PIPE FROM MAST TO 1 0, 152' 21 :30 - 22:30 1.00 DRILL N STUC PROD1 CHANGE OUT BALES FOR LONG SET TO ENABLE USAGE OF TIW VALVE AND HEAD PIN - PICK UP 10' PUP JOINT 22:30 - 23:00 0.50 DRILL N STUC PROD1 RIH TO 10,251' - MAKE UP SAFETY VALVE, HEAD PIN, AND CIRCULATING HOSE 23:00 - 00:00 1.00 REMCM N STUC PROD1 SET EZSV RETAINER AT 10,246' - SHEAR OFF AND Printed: 11/19/2001 10:04:11 AM BP EXPLORATION Page 17 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/31/2001 23:00 - 00:00 1.00 REMCM N STUC PROD1 UNSTING - SLACK OFF 20K AND VERIFY PLACEMENT - TEST CASING AT 1,000 PSI. FOR 15 MINUTES (GOOD TEST) 11/1/2001 00:00 - 02:00 2.00 REMCM N STUC PROD1 HOLD PRE-JOB SAFETY MEETING - SWAP OVER TO HALIBURTON ENERGY SERVICES - PUMP 5 BBL MUD - TEST SURFACE EQUIPMENT AT 4,000 PSI. - STING INTO RETAINER AND ESTABLISH INJECTION RATE WITH 5 BBL 12.0 PPG MUD AT 1 BPM WITH 950 PSI. SHUT DOWN FORMATION HOLDING 350 PSI. BLEED TO 0 PSI. & UNSTING FROM RETAINER - PUMP 10 BBL FRESH WATER - 10.2 BBL 15.8 PPG CEMENT AT 4 BPM WITH 1,700 PSI. WHILE HOLDING 200 PSI. BACK PRESSURE WITH CHOKE MANIFOLD - PUMP 5 BBL FRESH WATER BEHIND CEMENT & DISPLACE WITH 53.3 BBLS. 12.0 PPG MUD - STING INTO RETAINER INCREASE PRESSURE ON BACK SIDE TO 500 PSI. - PUMP 10 BBL MUD AND 6.5 BBL WATER AT 1 BPM WITH 770 PSI. 02:00 - 02:30 0.50 REMCM N STUC PROD1 UNSTING FROM RETAINER - REVERSE CIRCULATE 1 BBL CEMENT TO SURFACE 02:30 - 03:00 0.50 REMCM N STUC PROD1 RETEST CASING AND EZSV TO 1,000 PSI. (TEST GOOD) 03:00 - 04:30 1.50 REMCM N STUC PROD1 DISPLACE WELL TO 9.2 PPG BARADRIL MUD - PUMP DRY JOB & BLOW DOWN SURFACE EQUIPMENT 04:30 - 09:30 5.00 REMCM~ N STUC PROD1 POH WITH EZSV RUNNING TOOL 09:30 - 10:30 1.00 DRILL P PROD1 HOLD PRE-JOB SAFETY MEETING - PULL WEAR RING AND INSTALL TEST PLUG 10:30 - 11 :30 1.00 DRILL P PROD1 RIG UP BOP TESTING EQUIPMENT - FILL BOP STACK, CHOKE MANIFOLD, AND TEST JOINT WITH WATER 11 :30 - 18:00 6.50 DRILL P PROD1 TEST BOP AND RELATED EQUIPMENT - UNABLE TO GET HIGH PRESSURE TEST ON ANNULAR PACKING ELEMENT - TEST CHOKE MANIFOLD, MANUAL & HCR VALVES ON CHOKE AND KILL LINE'S, FULL OPENING SAFETY VALVE & DART VALVE, UPPER & LOWER IBOP VALVES ON TOP DRIVE, UPPER AND LOWER PIPE RAMS, BLIND RAMS ALL AT 250 PSI. LOW PRESSURE AND 3,500 PSI. HIGH PRESSURE - PREFORM ACCUMULATOR TEST - CHECK PIT VOLUME TOTALIZER & FLOW SHOW - TEST H2S & LEL GAS DETECTION SYSTEM. *NOTE* TEST WITNESSED BY AOGCC REPRESENTATIVE JOHN CRISP 18:00 - 18:30 0.50 DRILL P PROD1 BLOW DOWN CHOKE MANIFOLD, CHOKE LINE, & KILL LINE 18:30 - 00:00 5.50 DRILL N SFAL PROD1 HOLD PRE-JOB SAFETY MEETING - REMOVE FLOW LINE & RISER - CLEAN ANNULAR - CHANGE OUT PACKING ELEMENT ON 13 5/8 5M MSP HYDRIL ANNULAR PREVENTER 11/2/2001 00:00 - 01 :00 1.00 DRILL N RREP PROD1 RIG UP RISER AND FLOW LINE - INSTALL TEST PLUG- TEST 135/8 5M HYDRIL PACKING ELEMENT AT 250 PSI. LOW AND 2500 PSI. HIGH 01 :00 - 02:00 1.00 DRILL P PROD1 RIG DOWN TEST EQUIPMENT AND INSTALL WEAR RING ( ( Printed: 11/19/2001 10:04:11 AM (' (' BP EXPLORATION Page 18 of25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/212001 01 :00 - 02:00 1.00 DRILL P PROD1 AND CLEAR RIG FLOOR 02:00 - 06:30 4.50 STWHIP P PROD1 MAKE UP WINDOW MASTER WHIPSTOCK AND MILLING ASSEMBLY - ORIENT MWD TOOL TO WHIPSTOCK AND RIH WITH BHA 06:30 - 07:30 1.00 STWHIP P PROD1 SERVICE TOP DRIVE, TRAVELING BLOCKS, AND CROWN SHEAVES 07:30 - 13:00 5.50 STWHIP N HMAN PROD1 THAW OUT KELLY HOSE AND TOP DRIVE 13:00 - 13:30 0.50 STWHIP P PROD1 SURFACE TEST MWD TOOL AND KELLY HOSE AT 3,500 PSI. 13:30 - 18:30 5.00 STWHIP P PROD1 RIH WITH 3 1/2" DRILL PIPE FROM MAST TO 10,186' 18:30 - 19:30 1.00 STWHIP P PROD1 STRING TAKING WEIGHT - ORIENT WINDOW MASTER WHIPSTOCK TO HIGH SIDE AND WASH AND WORK TO TOP OF EZSV AT 10,246' - SET BOTTOM TRIP WHIPSTOCK AT 10,246' AND SHEAR RELEASE BOLT 19:30 - 00:00 4.50 STWHIP P PROD1 ESTABLISH ROTATION AND MILL WINDOW IN 7" CASING- TOP OF WINDOW AT 10,228' AND BOTTOM OF WINDOW AT 10,240' - DRILL AHEAD TO 10,243' - TOP DRIVE RPM 50 - 1350 PSI. AT 210 GPM - WEIGHT ON MILL 10K WITH 9K TORQUE - UP WEIGHT 155K - DOWN WEIGHT 85K - ROTATING WEIGHT 110K 11/3/2001 00:00 - 00:30 0.50 STWHIP P PROD1 CONTINUE TO MILL WINDOW AND NEW FORMATION FROM 10,243' TO 10,252' - RECOVERED (35) LBS. OF METAL DURING MILLING OPERATION 00:30 - 01 :30 1.00 STWHIP P PROD1 PULL INTO 7" CASING & CIRC. BOTTOMS UP WHILE PUMPING SWEEP - MONITOR WELL BORE (STATIC) 01 :30 - 02:00 0.50 STWHIP P PROD1 PERFORM FORMATION INTEGRITY TEST WITH 9.2 PPG MUD (ND @ 3,709' WITH 348 PSI.) TO OBTAIN 11.0 PPG MUD EQUIVALENT 02:00 - 07:00 5.00 STWHIP P PROD1 PUMP DRY JOB - BLOW DOWN TOP DRIVE AND MUD LINE - TURN TOP DRIVE ROTARY HOSE - POH WITH 31/2" DRILL PIPE 07:00 - 09:30 2.50 STWHIP P PROD1 BREAK AND LAY DOWN BHA - DOWN LOAD MWD AND STAND BACK IN MAST - LAY DOWN MILLING ASSEMBLY 09:30 - 11 :30 2.00 DRILL P PROD1 PICK UP (69) JOINTS OF 31/2" (15.5 LB.) DRILL PIPE AND RIH FOR THIS HOLE SECTION 11 :30 - 12:00 0.50 DRILL P PROD1 CIRCULATE THRU DRILL PIPE TO REMOVE SCALE DEPOSITS 12:00 - 13:00 1.00 DRILL P PROD1 POH WITH 31/2" DRILL PIPE AND STAND BACK IN MAST 13:00 - 13:30 0.50 DRILL P PROD1 FUNCTION RAMS ON 135/8 5M BOP AND FLUSH METAL CUTTINGS FROM RAM CAVITIES WITH FLUSHING TOOL 13:30 -14:30 1.00 DRILL P PROD1 SERVICE TOP DRIVE, TRAVELING BLOCKS, AND CROWN SHEAVES 14:30 - 15:00 0.50 DRILL P PROD1 PULL WEAR BUSHING SERVICE AND REINSTALL 15:00 - 17:00 2.00 DRILL P PROD1 MAKE UP BHA (NO.1 0) AND ORIENT MUD MOTOR TO MWD TOOL - INITIALIZE MWD AND SURFACE TEST (OK) - BLOW DOWN TOP DRIVE 17:00 - 21 :00 4.00 DRILL P PROD1 RIH WITH 31/2" DRILL FROM MAST TO 10,213' FILL DRILL STEM AS NEEDED - BREAK CIRCULATION AND ORIENT MUD MOTOR TO HIGH SIDE 21 :00 - 21 :30 0.50 DRILL P PROD1 HOLD PRE-RESEVIOR MEETING WITH COMPANY MAN AND DRILLING CREWS - PREFORM KICK DRILL - CHECK SLOW PUMP RATE 21 :30 - 00:00 2.50 DRILL P PROD1 WORK THRU WINDOW TOP AT 10,228' AND BOTTOM AT Printed: 11/19/2001 10:04:11 AM BP EXPLORATION Page 19 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/312001 21 :30 - 00:00 2.50 DRILL P PROD1 10,240 AND WASH TO BOTTOM AT 10,252' - DIRECTIONAL DRILL AHEAD FROM 10,252' TO 10,336' - (55) SPM AT 2,350 PSI. ON BOTTOM PRESSURE 2,250 PSI. OFF BOTTOM PRESSURE - TORQUE ON BOTTOM 8K WITH 70 RPM - UP WEIGHT 165K, DOWN WEIGHT 92K, ROTATING WEIGHT 115K, WEIGHT ON BIT 15K - CHECK FOR A "NO FLOW" ON CONNECTIONS AND SURVEY'S BEFORE RESUMING PUMPING 11/4/2001 00:00 - 13:00 13.00 DRILL P PROD1 CONTINUE TO DIRECTIONAL DRILL AHEAD FROM 10,336' TO 10,486' - SWAP MUD OVER TO CLEAN BARADRIL-N SYSTEM ON THE FLY - CONTINUE TO DRILL AHEAD FROM 10,486' TO 11,138' - (55) SPM AT 2,450 PSI. ON BOTTOM PRESSURE 2,300 PSI. OFF BOTTOM PRESSURE - TORQUE ON BOTTOM 6K WITH 80 RPM - UP WEIGHT 130K, DOWN WEIGHT 90K, ROTATING WEIGHT 108K, WEIGHT ON BIT 2K TO 6K - CHECK FOR A "NO FLOW" ON CONNECTIONS AND SURVEY'S BEFORE RESUMING PUMPING TRUCK ON LOCATION WITH 12.0 PPG MUD FOR KILL OPERATION IF NEEDED 13:00 - 14:00 1.00 DRILL N DPRB PROD1 DUE TO MAGNETIC INTERFERANCE FROM FISH LEFT IN THE HOLE CONSULT WITH TOWN REGUARDING SURVEY IRREGULARITIES - RECIPROCATE AND ROTATE DRILL STRING AND CONDITION MUD 14:00 - 00:00 10.00 DRILL P PROD1 CONTINUE TO DRILL AHEAD FROM 11,138' TO 12,070' - (55) SPM AT 2,450 PSI. ON BOTTOM PRESSURE 2,300 PSI. OFF BOTTOM PRESSURE - TORQUE ON BOTTOM 6K WITH 80 RPM - UP WEIGHT 130K, DOWN WEIGHT 90K, ROTATING WEIGHT 108K, WEIGHT ON BIT 2K TO 6K- CHECK FOR A "NO FLOW" ON CONNECTIONS AND SURVEY'S BEFORE RESUMING PUMPING 11/5/2001 00:00 - 04:30 4.50 DRILL P PROD1 CONTINUE TO DRILL AHEAD FROM 12,070' TO 12,470'- (55) SPM AT 2,450 PSI. ON BOTTOM PRESSURE 2,300 PSI. OFF BOTTOM PRESSURE - TORQUE ON BOTTOM 6K WITH 80 RPM - UP WEIGHT 130K, DOWN WEIGHT 90K, ROTATING WEIGHT 108K, WEIGHT ON BIT 2K TO 6K- CHECK FOR A "NO FLOW" ON CONNECTIONS AND SURVEY'S BEFORE RESUMING PUMPING. 04:30 - 06:30 2.00 DRILL P PROD1 FLOW CHECK, WELL STATIC. PUMP HIGH VIS WEIGHTED SWEEP AND CIRCULATE AROUND. NO SIGNIFICENT AMOUNT OF CUTTINGS WITH BOTTOMS UP. 06:30 - 09:00 2.50 DRILL P PROD1 SHORT TRIP TO 7" CASING WINDOW. PULL FIRST TWO JOINTS AND WELL SWABBING. PUMP OUT OF THE HOLE TO THE WINDOW. FLOW CHECK, WELL STATIC. BLOW DOWN TOP DRIVE. 09:00 - 10:00 1.00 DRILL P PROD1 RIH TO BOTTOM. WASH LAST STAND TO BOTTOM AS PRECAUTION. 10:00 - 12:30 2.50 DRILL P PROD1 CIRCULATE AND CONDITION MUD PRIOR TO TRIP OUT FOR LINER - MONITOR WELL STATIC 12:30 - 14:30 2.00 DRILL P PROD1 PUMP OUT OF THE HOLE FROM 12,470' TO 10,230 NO PROBLEMS ( { Printed: 11/19/2001 10:04:11 AM ( ( BP EXPLORATION Page 20 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/512001 14:30 - 18:30 4.00 DRILL P PROD1 MONITOR WELL AT "OB" LATERAL WINDOW - PUMP DRY JOB BLOW DOWN TOP DRIVE AND MUD LINES - CONTINUE TO POH TO BHA AT 266' 18:30 - 19:00 0.50 DRILL P PROD1 LAY DOWN BHA AND CLEAR RIG FLOOR 19:00 - 19:30 0.50 CASE P PROD1 HOLD PRE-JOB SAFETY MEETING AND RIG UP TO RUN LINER 19:30 - 22:00 2.50 CASE P PROD1 PICK UP AND RIH WITH (58) JOINTS OF 41/2" 12.6 LB. L-80 IBT SLOTTED LINER PER PROGRAM - CHANGE ELEVATORS AND CASING TONGS - MAKE UP BAKER FLEX LOCK LINER HANGER AND ZXP PACKER - SERVICE SAME - RIG DOWN CASING TONGS INSTALL STRIPPING RUBBER AND CLEAR RIG FLOOR 22:00 - 00:00 2.00 CASE P PROD1 RUN SLOTTED LINER IN HOLE WITH (65) STANDS 31/2" DRILL PIPE FROM MAST 11/6/2001 00:00 - 01 :45 1.75 CASE P PROD1 CONTINUE TO RIH WITH SLOTTED LINER TO 10,218' NEAR TOP OF THE "OB" LATERAL WINDOW 01 :45 - 02:30 0.75 CASE P PROD1 BREAK CIRCULATION AND PUMP DRILL PIPE AND LINER VOLUME AT 25 SPM WITH 700 PSI. 02:30 - 05:30 3.00 CASE P PROD1 RIH WITH SLOTTED LINER THRU OPEN HOLE SECTION ~ TO 10,553' WORK THRU TIGHT SPOT TO 10,583' - CONTINUE TO RIH 12,050' WITH NO PROBLEMS - WORK LINER HARD FROM 12,050' TO 12,357' - RIH TO LINER SHOE SETTING DEPTH AT 12,440' WITH NO PROBLEMS 05:30 - 08:00 2.50 CASE P PROD1 BREAK CIRCULATION - DROP 7/8" BALL AND PUMP TO SEAT WITH 618 STROKES - PRESSURE UP TO 1,650 PSI. TO SET BAKER FLEX LOCK LINER HANGER - SLACK OFF AND VERIFY HANGER SET WITH 25K LBS. WEIGHT - CONTINUE TO PRESSURE UP DRILL PIPE TO 3,150 PSI. TO ACTUATE HYDRAULIC PUSHER TOOL TO SET ZXP PACKER & SHEAR NEUTRALIZER - BLEED PRESSURE TO 0 PSI. AND CLOSE BAG ATTEMPT TO PRESSURE UP TO 500 PSI. TO VERIFY PACKER SETTING (NO GOOD) - PRESSURE UP TO 3,950 PSI TO RELEASE "HR" SETTING TOOL AND BLOW BALL SEAT - SET PACKER MECHANICALY BY ROTATING TO THE RIGHT AND SLACKING OFF 25K TO 35K WEIGHT - ATTEMPT TO RETEST ZXP PACKER BACK SIDE TO 500 PSI. TWO MORE TIMES (SECOND TIME TEST GOOD) - BLEED PRESSURE TO 0 PSI. AND OPEN BAG 08:00 - 09:00 1.00 CASE P PROD1 PULL RS. PACK OFF FREE OF BAKER ZXP PACKER - LAY DOWN SINGLE OF 31/2" DRILL PIPE - CIRCULATE BOTTOMS UP AT 10,115'- MONITOR WELL (STATIC) - PUMP DRY JOB 09:00 - 14:00 5.00 CASE P PROD1 BLOW DOWN TOP DRIVE AND MUD LINE - POH WITH BAKER LINER RUNNING TOOL ASSEMBLY AND LAY DOWN SAME - CLEAR RIG FLOOR 14:00 - 18:00 4.00 STWHIP P PROD2 PICK UP SPACE OUT TUBULARS, WIDOW MASTER WHIPSTOCK, AND MILLING ASSEMBLY - PICK UP MWD TOOL AND ORIENT - INITIALIZE MWD TOOL - CONTINUE TO PICK UP REMAINING BHA AND RIH - SURFACE TEST MWD TOOL 18:00 - 22:00 4.00 STWHIP P PROD2 RIH WITH WHIPSTOCK ON 3 1/2" DRILL PIPE FROM MAST 22:00 - 22:30 0.50 STWHIP P PROD2 TAKE SLOW PUMP RATES AND ORIENT WHIPSTOCK TO Printed: 11/19/2001 10:04:11 AM ( (' BP EXPLORATION Page 21 of25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/612001 22:00 - 22:30 0.50 S1WHIP P PROD2 35 DEGREES LEFT OF HIGH SIDE - SLACK OFF AND LAND THE LOCATOR SEAL ASSEMBLY IN LINER HANGER PACKER BELOW AT 10,128' - SHEAR BOTTOM TRIP ANCHOR AND CONFIRM SETTING - SHEAR RELEASE BOLT - ESTABLISH ROTATION 22:30 - 00:00 1.50 S1WHIP P PROD2 MILL WINDOW FOR "OA" LATERAL - TOP OF WINDOW AT 9,916' AND BOTTOM OF WINDOW AT 9,928' - (7') TOTAL FOOTAGE MILLED AT 00:00 HOURS - TOP DRIVE RPM 80 TO 100 - 2000 PSI. AT 225 GPM - WEIGHT ON MILL 3K TO 6K WITH 8K TORQUE - UP WEIGHT 125K, DOWN WEIGHT 98K, ROTATING WEIGHT 110K 11/7/2001 00:00 - 03:00 3.00 S1WHIP P PROD2 CONTINUE TO MILL "OA" LATERAL WINDOW TOP AT 9,916' TO BOTTOM AT 9,928'- MILL NEW FORMATION TO 9,943' - RECOVERED 20 LBS. OF METAL DURING MILLING OPERATION. 03:00 - 04:00 1.00 S1WHIP P PROD2 PULL INTO AND OUT OF 7" CASING AND CIRCULATE BOTTOMS UP WHILE PUMPING SWEEP. 04:00 - 04:30 0.50 S1WHIP P PROD2 MONITOR WELL BORE (STATIC) - PUMP DRY JOB - STAND BACK (1) STAND IN MAST - BLOW DOWN TOP DRIVE AND MUD LINE. 04:30 - 06:30 2.00 S1WHIP P PROD2 CUT AND SLIP 123 FEET OF 1 3/8" DRILLING LlNE- SERVICE TOP DRIVE, TRAVELING BLOCKS, AND CROWN SHEAVES. 06:30 - 10:00 3.50 S1WHIP P PROD2 POH WITH 3 1/2" DRILL PIPE AND MILLING ASSEMBLY TO 850' (BHA) - OBSERVE WELL (STATIC). I 10:00 - 12:30 2.50 S1WHIP P PROD2 LAY DOWN BHA & MILLING TOOLS - CLEAR RIG FLOOR. 12:30 - 13:00 0.50 BOPSUr:; P PROD2 FLUSH BOP STACK WITH MIXING SUB - BLOW DOWN TOP DRIVE AND MUD LINE. 13:00 -14:00 1.00 BOPSUr:; P PROD2 PULL WEAR BUSHING & INSTALL TEST PLUG - RIG UP TEST EQUIPMENT. 14:00 -18:00 4.00 BOPSUr:; P PROD2 FILL BOP STACK, CHOKE MANIFOLD, AND TEST JOINT WITH WATER - TEST ANNULAR PACKING ELEMENT AT 250 PSI. LOW PRESSURE AND 2,500 PSI. HIGH PRESSURE - TEST CHOKE MANIFOLD, MANUAL & HCR VALVES ON CHOKE AND KILL LINE'S, FULL OPENING SAFETY VALVE & DART VALVE, UPPER & LOWER IBOP VALVES ON TOP DRIVE, UPPER AND LOWER PIPE RAMS, BLIND RAMS ALL AT 250 PSI. LOW PRESSURE AND 3,500 PSI. HIGH PRESSURE - PREFORM ACCUMULATOR TEST- CHECK PIT VOLUME TOTALIZER & FLOW SHOW - TEST H2S & LEL GAS DETECTION SYSTEM. *NOTE* WITNESS OF TEST WAIVED BY AOGCC REPRESENTATIVE JOHN CRISP 18:00 - 18:30 0.50 BOPSUF P PROD2 RIG DOWN TEST EQUIPMENT - BLOW DOWN TOP DRIVE CHOKE AND KILL LINES - INSTALL WEAR BUSHING 18:30 - 20:00 1.50 DRILL P PROD2 MAKE UP PDC BIT PICK UP DRILLING BHA - ORIENT MWD AND MUD MOTOR INITIALIZE MWD AND SUFACE TEST- BLOW DOWN TOP DRIVE 20:00 - 23:00 3.00 DRILL P PROD2 RIH WITH BHA NO.12 WITH 31/2" DRILL PIPE FROM MAST Printed: 11/19/2001 10:04:11 AM (" ( BP EXPLORATION Page 22 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11nl2001 20:00 - 23:00 3.00 DRILL P PROD2 TO 9,840' - FILL DRILL STEM AS NEEDED 23:00 - 00:00 1.00 DRILL P PROD2 ORIENT MUD MOTOR TO 35 LEFT OF HIGH SIDE AND WORK THRU WINDOW (NO PROBLEMS) - DRILL AHEAD TO 9,988' WHILE PUMPING SPACER AND DISPLACING TO NEW BARADRIL-N MUD ON THE FLY. 11/8/2001 00:00 - 00:00 24.00 DRILL P PROD2 DIRECTIONAL DRILL AHEAD FROM 9,988' TO 12,210' - TOP DRIVE RPM 80 TO 90 - PUMPING AT 235 GPM ON BOTTOM PRESSURE 2800 PSI. & OFF BOTTOM PRESSURE AT 2600 PSI. - WEIGHT ON BIT 2K TO 12K WITH ON BOTTOM TORQUE AT 5K & OFF BOTTOM TORQUE AT 3K - UP WEIGHT 135K, DOWN WEIGHT 85K, ROTATING WEIGHT 100K. CHECK FOR FLOW ON SURVEYS AND CONNECTIONS BEFORE RESUMING PUMPING OPERATION. 11/9/2001 00:00 - 03:30 3.50 DRILL P PROD2 DIRECTIONAL DRILL AHEAD FROM 12,210' TO 12,500'- TOP DRIVE RPM 80 TO 90 - PUMPING AT 235 GPM ON BOTTOM PRESSURE 2800 PSI. & OFF BOTTOM PRESSURE AT 2600 PSI. - WEIGHT ON BIT 2K TO 12K WITH ON BOTTOM TORQUE AT 5K & OFF BOTTOM TORQUE AT 3K - UP WEIGHT 135K, DOWN WEIGHT 85K, ROTATING WEIGHT 100K. CHECK FOR FLOW ON SURVEYS AND CONNECTIONS BEFORE RESUMING PUMPING OPERATION. 03:30 - 06:00 2.50 DRILL P PROD2 PUMP SWEEP AND CIRCULATE HOLE CLEAN WHILE ROTATING AND RECIPROCATING DRILL STRING 06:00 - 09:00 3.00 DRILL P PROD2 PUMP OUT OF THE HOLE FROM 12,500' TO 10,010' - SHUT DOWN PUMP AND PULL INTO WINDOW TO 9,800' - MONITOR WELL (STATIC) - PUMP DRY JOB - BLOW DOWN MUD LINE AND TOP DRIVE 09:00 - 13:00 4.00 DRILL P PROD2 POH STANDING BACK 3 1/2" DRILL PIPE IN MAST FROM 9,800' TO BHA 13:00 -14:00 1.00 DRILL P PROD2 LAY DOWN BHA NO.12 - DOWN LOAD MWD DATA IN PIPE SHED 14:00 - 15:00 1.00 DRILL P PROD2 PICK UP HOLE OPENER AND MAKE UP BHA NO.13 15:00 - 19:00 4.00 DRILL P PROD2 RIH WITH HOLE OPENER TO 9,850' - BREAK CIRCULATION AND CONTINUE TO WASH IN THE HOLE TO 10,010' ALLOWING TOP STRING STABILIZER TO CLEAR "OA" LATERAL WINDOW 19:00 - 00:00 5.00 DRILL P PROD2 WASH AND REAM 61/8" HOLE AT 400 FPH WITH HOLE OPENER FROM 10,010' TO 11,320' - TOP DRIVE RPM 120 - PUMPING AT 300 GPM WITH 2300 PSI. - OFF BOTTOM TORQUE AT 3K - UP WEIGHT 125K, DOWN WEIGHT 90K, ROTATING WEIGHT 110K. 11/10/2001 00:00 - 06:00 6.00 DRILL P PROD2 WASH AND REAM 61/8" HOLE AT 400 FPH WITH HOLE OPENER FROM 11,320' TO 12,500' - TOP DRIVE RPM 120 - PUMPING AT 300 GPM WITH 2300 PSI. - OFF BOTTOM TORQUE AT 3K - UP WEIGHT 125K, DOWN WEIGHT 90K, ROTATING WEIGHT 110K. 06:00 - 08:00 2.00 DRILL P PROD2 PUMP SWEEP AND CIRCULATE HOLE CLEAN WHILE Printed: 11/19/2001 10:04:11 AM BP EXPLORATION Page 23 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/10/2001 06:00 - 08:00 2.00 DRILL P PROD2 ROTATING AND RECIPROCATING DRILL STRING. 08:00 - 12:00 4.00 DRILL P PROD2 MONITOR WELL (STATIC) - LAY DOWN SINGLE OF 31/2" DRILL PIPE - ATTEMPT TO POH "WELL SWABBING" PUMP OUT OF THE HOLE FROM 12,500' TO 9,793' WITH NO PROBLEMS. 12:00 - 13:00 1.00 DRILL P PROD2 MONITOR WELL (STATIC) - CIRCULATE AND PUMP DRY JOB - BLOW DOWN TOP DRIVE AND MUD LINE. 13:00 - 17:00 4.00 DRILL P PROD2 POH WITH 31/2" DRILL PIPE STAND BACK IN MAST. 17:00 - 18:00 1.00 DRILL P PROD2 LAY DOWN BHA NO.13 - LAY DOWN HOLE OPENER, (3) STABS, LEAD COLLAR, FLEX COLLARS, DRILLING JARS, AND CLEAR RIG FLOOR. 18:00 - 20:00 2.00 DRILL P PROD2 PICK UP BHA NO.14 - MAKE UP WHIPSTOCK HOOK AND SPERRY MWD TOOLS ORIENT SAME - CONTINUE TO PICK UP BUMPER SUB, OIL JARS, AND (9) SPIRAL 4 3/4" DRILL COLLARS - SURFACE TEST MWD TOOL - BLOW DOWN TOP DRIVE AND MUD LINE. 20:00 - 23:00 3.00 DRILL P PROD2 RIH WITH WHIPSTOCK RETRIEVING HOOK AND BHA ON 3 1/2" DRILL PIPE FROM MAST TO 9,864' 23:00 - 23:30 0.50 DRILL P PROD2 BREAK CIRCULATION AND ORIENT HOOK FOR NO LATCH UP - RECORD UP AND DOWN WEIGHTS - SLACK OFF TO TOP OF WHIPSTOCK AT 9,916' WHILE JETTING OUT SLOT CONTINUE TO SLACK OFF TO 9,921' - SHUT DOWN PUMPS AND PULL ABOVE WHIPSTOCK - ORIENT WITH MWD TO ALIGN LUG WITH WHIPSTOCK FACE LOWER HOOK AND ENGAGE WHIPSTOCK - PICK UP AND CONFIRM HOOK ENGAGED - CONTINUE TO PICK UP TO 210K (82K ABOVE NORMAL UP WEIGHT) RELEASING BOTTOM TRIP ANCHOR ON WHIPSTOCK - MONITOR WELL BORE (STATIC) - PULL WHIPSTOCK UP THE HOLE TO 9,894' HOLE SWABBING 23:30 - 00:00 0.50 DRILL P PROD2 CIRCULATE AND CONDITION MUD 11/11/2001 00:00 - 01 :00 1.00 DRILL P PROD2 CIRCULATE BOTTOMS UP AND CONDITION MUD AFTER UNSEATING WHIPSTOCK - MONITOR WELL BORE (STATIC) 01 :00 - 10:30 9.50 DRILL P PROD2 ATTEMPT TO POH (SLOW) WITH WHIPSTOCK - NO GOOD WELL SWABBING - PUMP OUT OF THE HOLE 10:30 - 13:30 3.00 DRILL P PROD2 LAY DOWN BHA, WHIPSTOCK ASSEMBLY, SPACE OUT JOINTS, AND CROSS OVER SUBS - CLEAR RIG FLOOR 13:30 - 14:00 0.50 CASE P PROD2 RIG UP TO RUN 41/2" SLOTTED LINER - HOLD PRE-JOB SAFETY MEETING WITH COMPANYMAN AND NABORS PERSONAL REGUARDING LINER RUNNING OPERATION. 14:00 - 17:00 3.00 CASE P PROD2 PICK UP AND RIH WITH (78 JOINTS) 41/2" 12.6 LB. L-80 IBT SLOTTED LINER - PICK UP BAKER WALL HOOK HANGER 17:00 - 19:30 2.50 CASE P PROD2 CONTINUE TO RUN SLOTTED LINER WITH 31/2" DRILL PIPE FROM MAST TO TOP OF WINDOW - ESTABLISH ALL UP, DOWN, AND ROTATIONAL WEIGHTS 19:30 - 22:30 3.00 CASE P PROD2 CONTINUE TO ORIENT AND WORK LINER FROM TOP OF "OA" LATERAL WINDOW AT 9,916' TO BAKER ZXP PACKER AT 10,128' - SUCESSFULL AFTER MANY ATTEMPS 22:30 - 23:30 1.00 CASE P PROD2 CONTINUE TO RUN LINER FROM "OA" LATERAL WINDOW AT 9,916' TO 12,436' GUIDE SHOE DEPTH - CHECK UP (' ( Printed: 11/19/2001 10:04:11 AM (' ( BP EXPLORATION Page 24 of 25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/11/2001 22:30 - 23:30 1.00 CASE P PROD2 AND DOWN WEIGHTS 23:30 - 00:00 0.50 CASE P PROD2 WORK LINER AND ATTEMPT TO ENGAGE BAKER WALL HOOK HANGER INTO LOWER SECTION OF WINDOW AT 9,928' 11/12/2001 00:00 - 01 :00 1.00 CASE P PROD2 CONTINUE TO ORIENT BAKER WALL HOOK HANGER TO ENGAGE LOWER PORTION OF "OA" LATERAL WINDOW AT 9,928' - AFTER MANY ATTEMPTS HANGER ENGAGED AND LANDED - TOP OF BAKER WALL HOOK HANGER AT 9,906' 01 :00 - 02:00 1.00 CASE P PROD2 DISCONNECT TOP DRIVE AND DROP BALL - PUMP TO SEAT WITH 569 STROKES - PRESSURE UP TO 2600 PSI. AND BLEED PRESSURE TO 0 PSI. - VERIFY HYDRAULIC RELEASE TOOL FUNCTIONED BY PICKING UP STRING WEIGHT THEN SLACK BACK DOWN TO 65K - SHEAR OUT BALL SEAT WITH 3,100 PSI. - PICK UP AND STAND BACK ONE STAND IN MAST CLEARING "HR" SETTING TOOL FROM TOP OF WALL HOOK HANGER. 02:00 - 03:30 1.50 CASE P PROD2 CIRCULATE BOTTOMS UP FLUID GAS CUT TO 8.3 PPG- CONTINUE TO CIRCULATE UNTIL GOOD 9.1 PPG MUD BACK TO SURFACE - MONITOR WELL BORE (STATIC) 03:30 - 04:00 0.50 CASE P PROD2 PUMP DRY JOB - BLOW DOWN TOP DRIVE AND MUD LINE. 04:00 - 05:30 1.50 CASE P PROD2 POH FROM 9,833' TO 7,620 - NOT TAKING THE CORRECT AMOUNT OF FILL 4.95 BBLS SHORT (CALCULATED 11.25 BBLS-ACTUAL 6.3 BBLS) MONITOR WELL (STATIC) 05:30 - 06:30 1.00 CASE P PROD2 CIRCULATE BOTTOMS UP 06:30 - 07:30 1.00 CASE P PROD2 RUN IN HOLE TO 9,913' ABOVE TOP OF WALL HOOK HANGER 07:30 - 08:30 1.00 CASE P PROD2 CIRCULATE BOTTOMS UP - BLOW DOWN TOP DRIVE 08:30 - 09:30 1.00 CASE P PROD2 MONITOR WELL FOR 30 MINUTES (STATIC) 09:30 - 19:00 9.50 CASE P PROD2 PUMP OUT OF THE HOLE FROM 9,913' TO 42' 19:00 - 19:30 0.50 CASE P PROD2 LAY DOWN BAKER LINER HANGER RUNNING TOOLS- CLEAR RIG FLOOR - MONITOR WELL BORE (STATIC) 19:30 - 20:00 0.50 CASE P PROD2 HOLD PRE-JOB SAFETY MEETING - LAY DOWN SINGLE IN MOUSEHOLE - PICK UP BAKER BRIDGE PLUG AND RUNNING TOOL 20:00 - 00:00 4.00 DRILL P PROD2 RIH WITH BRIDGE PLUG ON 31/2" DRILL PIPE FROM MAST - FILL DRILL PIPE AT 30 STANDS IN THE HOLE- CONTINUE TO RIH WITH 4 STANDS TAKING WEIGHT AND PUSHING FLUID DOWNHOLE - WORK BRIDGE PLUG UP AND DOWN AND CONTINUE TO RIH PUSHING FLUID 3.5 BBLS PER STAND AHEAD OF BRIDGE PLUG. 11/13/2001 00:00 - 04:00 4.00 CASE P PROD2 CONTINUE RIH WITH BAKER BRIDGE PLUG. PIPE FLOATING UNTIL 42 STANDS WERE IN HOLE. PLUG FREED UP AND GOT FULL RETURNS. CONTINUE RIH TO 9800' WITH NO PROBLEMS. 04:00 - 05:00 1.00 CASE P PROD2 BREAK CIRCULATION AND DROP BALL. BALL SEATED AFTER 498 STROKES. PRESSURED UP 2100 PSI. P/U AND SHEAR OUT WITH 145 K. 05:00 - 05:30 0.50 CASE P PROD2 RU AND PRESSURE TEST BRIDGE PLUG 1000 PSI FOR 15 MINUTES. RECORDED ON CHART. 05:30 - 07:00 1.50 CASE P PROD2 CIRCULATE BOTTOMSUP AND CLEAN PITS FOR KCL Printed: 11/19/2001 10:04:11 AM ( ( BP EXPLORATION Page 25 of25 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: DRILL +COMPLETE Start: 10/7/2001 End: 11/14/2001 Contractor Name: NABORS Rig Release: 11/14/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11113/2001 05:30 - 07:00 1.50 CASE P PROD2 WATER. 07:00 - 09:00 2.00 CASE P PROD2 CIRCULATE AND DISPLACE WELL WITH 9.2 KCL WATER. 09:00 - 10:00 1.00 CASE P PROD2 CLEAN TROUGHS AND UNDER SHAKER. SERVICE TOP DRIVE. 10:00 - 21 :00 11.00 CASE P PROD2 PUMP DRY JOB. POOH LAYING DOWN 3-1/2" DRILL PIPE. 21 :00 - 22:00 1.00 CASE P PROD2 SLIP AND CUT 134' DRILL LINE 22:00 - 23:00 1.00 BOPSUR P PROD2 CHANGE TOP RAMS 2-7/8" AND TEST DOOR SEALS. 23:00 - 00:00 1.00 CASE P PROD2 RIG UP, MU BAKER RETRIEVING HEAD AND RIH PICKING UP 2-7/8" TUBING. 11114/2001 00:00 - 08:30 8.50 CASE P PROD2 FINISH RUNNING PLUG RETRIEVING TOOL ON 2-7/8" TUBING. A TOTAL OF 310 JTS WERE RUN. 08:30 - 09:30 1.00 CASE P PROD2 BLOW DOWN HOLE FILL LINE AND STAND PIPE. DRAIN BOP STACK. 09:30 - 11 :00 1.50 CASE P PROD2 INSTALL DUMMY ESP AND LAND HANGER. BOTTOM OF TUBING AT 9714'. RILDS. 11 :00 - 12:00 1.00 WHSUR P PROD2 INSTALL TWO CHECK AND TEST 1000 PSI-OK 12:00 - 17:00 5.00 BOPSUF P PROD2 NIPPLE DOWN BOP'S. OPEN DOORS AND REMOVE RAM BODIES. REMOVE DOUBLE STUDDED ADAPTOR AND SET STACK ON BOP STAND. 17:00 - 20:00 3.00 WHSUR P PROD2 NIPPLE UP ADAPTOR FLANGE AND FMC 2-9/16 5M DOUBLE ACTUATED TREE. TEST TREE 5000 PSI. 20:00 - 22:30 2.50 WHSUR P PROD2 PULL TWO CHECK AND FREEZE PROTECT 2-7/8" X 7" AND INSIDE TUBING WITH 90 BBLS DIESEL. 22:30 - 23:30 1.00 WHSUR P PROD2 LET DIESEL EQUALIZE INSIDE 2-7/8" TUBING AND 7" ANNULUS. 23:30 - 00:00 0.50 WHSUR P PROD2 INSTALL BPV AND RELEASE RIG. Printed: 11/19/2001 10:04:11 AM BP EXPLORATION Page 1 of 1 Operations Summary Report Legal Well Name: MPI-12 Common Well Name: MPI-12 Spud Date: 10/7/2001 Event Name: WORKOVER Start: 12/6/2001 End: 12/8/2001 Contractor Name: NABORS Rig Release: 12/8/2001 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/6/2001 10:00 - 11 :30 1.50 MOB P DECaMP SCOPE AND LOWER DERRICK. RDMO. 11 :30 - 15:00 3.50 MOB P DECOMP MOVE FROM MPI-11 TO MPI-12. STANDBY AT MPI-12 FOR WELL HOUSE TO BE SET ON MPI-11. SPOT RIG AT MPI-12. 15:00 - 17:00 2.00 RIGU P DECOMP RAISE AND SCOPE DERRICK. COMPLETE RIG UP. ACCEPTED RIG AT 17:00 HRS. 17:00 - 18:00 1.00 REST P DECOMP CHECK WHITBG PRESS = O. PU LUBRICATOR AND PULL BPV. INSTALL TWC. CREW CHANGE. 18:00 - 18:30 0.50 REST P DECOMP TEST TWC. 18:30 - 19:30 1.00 REST P DECOMP NIPPLE DOWN PRODUCTION TREE. 19:30 - 21:00 1.50 REST P DECOMP NIPPLE UP BOPE. 21 :00 - 23:30 2.50 REST P DECOMP PERFORM BOP TEST PER AOGCC AND BP REQUIREMENTS...25/2500 PSI. STATE'S RIGHT TO WITNESS WAIVED BY C. SHEVE 23:30 - 00:00 0.50 REST P DECOMP PU LUBRICATOR AND PULL TWC. 12/7/2001 00:00 - 00:30 0.50 REST P DECOMP MU LANDING JT. BOLDS. PULL TBG HANGER TO FLOOR. LD HANGER AND LANDING JT. 00:30 - 02:30 2.00 REST P DECOMP CIRCULATE WELL OVER TO 9.0 LBIGAL BRINE. 02:30 - 03:00 0.50 REST P DECOMP RIH AND TAG RET BRIDGE PLUG AT 9804-FT. EQUALIZE AND RELEASE BP. 03:00 - 04:30 1.50 REST P DECQMP CIRCULATE BTMS UP. MONITOR. WELL DEAD. 04:30 - 06:00 1.50 REST P DECOMP START TOH WITH 2 7/8" TBG AND BP. CREW CHANGE. 06:00 - 09:00 3.00 REST P DECOMP FINISH TOH. LD BP. HALF OF ONE RUBBER ELEMENT MISSING. 09:00 - 15:30 6.50 REST N DPRB DECOMP ORDER OUT REVERSE BASKET. MU REV BASKET AND TIH TO TOP OF BAKER HOOK WALL HANGER AT 9,906-FT. 15:30 - 18:00 2.50 REST N DPRB DECOMP START TOH WITH 2 7/8" TBG AND REV BASKET. CREW CHANGE. 18:00 - 20:00 2.00 REST N DPRB DECOMP FINISH TOH WITH TGB AND REV BASKET. LD. RECOVERED RUBBER ELEMENT. 20:00 - 23:30 3.50 REST P DECOMP PU AND SERVICE ESP ASSY 23:30 - 00:00 0.50 REST P DECOMP START TIH WIESP ASSY AND 2 7/8" TBG. 12/8/2001 00:00 - 03:30 3.50 RUNCO~ P COMP RUN IN HOLE WITH ESP COMPLETION 03:30 - 06:00 2.50 RUNCO~ P COMP SPLICE ESP CABLE MID-LINE SPLICE. 06:00 - 07:30 1.50 RUNCO~ P COMP CONTINUE TO RIH WITH ESP COMPLETION TO 9656' 07:30 - 10:00 2.50 RUNCO~ P COMP MAKE UP HANGER & INSTALL ESP PENETRATORS & SPLICE CABLE AND LAND SAME. RILDS 10:00 - 11 :30 1.50 BOPSUF P COMP NIPPLE DN BOP 11 :30 - 13:30 2.00 WHSUR P COMP NIPPLE UP TREE & TEST TO 5000 PSI. & PULL TWC AND SET BPV. 13:30 - 15:00 1.50 CHEM P COMP FREEZE PROTECT WELL WITH 80-BBL.. DEAD CRUDE IN ANNULUS AND 15-BBL. IN TBG. RIG RELEASED @ 1500 HRS. 12/08/2001 f ( Printed: 12/10/2001 11: 18:30 AM -<- Milne Point Unit Alaska Drilling & Wells Milne Point MPI, Slot MPI-12 MPI-12 MWD Job No. AKMM11164, Surveyed: 5 November, 2001 R~CIEIV€ t:£B D AJ~- 0 7 - .'SQJI'IQ"¡, 2002 A Gis Cons. . Your Ref: API 500292303800 ~ ~n. Surface Coordinates: 6009458.18 N, 551375.14 E (70026' 11.7316" N, 149034' 52.0644" W) Kelly Bushing: 63.40ft above Mean Sea Level SURVEY REPORT 7 February, 2002 ~- 5I=JE!r''-'Y-5UI! DRIL-L-ING seRVices A Halliburton Company Survey Ref: svy10028 Sperry-Sun Drilling Services . Survey Report for MPI-12 MWD Your Ref: API 500292303800 Job No. AKMM11164, Surveyed: 5 November, 2001 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 10177.88 81 .240 284.260 3636.51 3699.91 1572.76 N 8039.11 W 6010975.52 N 543325.39 E 8181.84 Tie-On Point 10223.00 82.740 277.990 3642.81 3706.21 1581.37 N 8082.93 W 6010983.83 N 543281.51 E 14.156 8226.44 Window Point ~ 10228.00 82.910 278.000 3643.43 3706.83 1582.06 N 8087.84 W 6010984.49 N 543276.59 E 3.406 8231.40 10256.77 88.520 249.930 3645.62 3709.02 1579.05 N 8116.07 W 6010981.29 N 543248.39 E 99.185 8258.90 10288.61 89.820 281.750 3646.1 0 3709.50 1576.77 N 8147.41 W 6010978.79 N 543217.06 E 100.008 8289.59 10319.99 90.060 293.150 3646.13 3709.53 1586.17 N 8177.30 W 6010987.98 N 543187.11 E 36.337 8320.52 10345.70 89.450 279.730 3646.24 3709.64 1593.43 N 8201.90 W 6010995.07 N 543162.45 E 52.251 8345.91 10377.65 87.170 274.870 3647.18 3710.58 1597.48 N 8233.57 W 6010998.91 N 543130.76 E 16.795 8377.83 10407.65 86.490 269.770 3648.84 3712.24 1598.70 N 8263.49 W 6010999.91 N 543100.83 E 17.125 8407.61 10440.65 86.370 276.950 3650.90 3714.30 1600.63 N 8296.35 W 6011001.62 N 543067.96 E 21.718 8440.41 10474.23 86.430 275.540 3653.01 3716.41 1604.27 N 8329.66 W 6011005.03 N 543034.63 E 4.194 8473.90 10503.88 86.620 279.110 3654.81 3718.21 1608.04 N 8359.01 W 6011008.60 N 543005.25 E 12.035 8503.49 10532.07 86.670 286.360 3656.46 3719.86 1614.24 N 8386.44 W 6011014.61 N 542977.78 E 25.675 8531.52 10568.15 87.910 294.220 3658.17 3721.57 1626.73 N 8420.22 W 6011026.87 N 542943.92 E 22.030 8566.75 10599.16 88.650 295.100 3659.10 3722.50 1639.66 N 8448.38 W 6011039.61 N 542915.66 E 3.707 8596.48 10629.96 88.400 166.540 3660.56 3723.96 1624.06 N 8467.53 W 6011023.88 N 542896.62 E 417.147 8613.18 10661.21 90.310 272.700 3661.07 3724.47 1603.30 N 8484.73 W 6011002.99 N 542879.57 E 339.719 8627.21 10689.95 90.800 295.730 3660.79 3724.19 1610.31 N 8512.40 W 6011009.81 N 542851.85 E 80.146 8655.60 10718.41 90.990 121.290 3655.05 3718.45 1594.67 N 8520.91 W 6010994.12 N 542843.45 E 611.944 8661.77 '~ 10751.40 90.920 294.160 3649.39 3712.79 1575.99 N 8530.73 W 6010975.36 N 542833.76 E 523.246 8668.79 10782.76 90.740 182.930 3648.71 3712.11 1562.08 N 8553.47 W 6010961.30 N 542811.11 E 354.632 8689.29 1 0811 .84 90.800 117.740 3648.27 3711.67 1538.15 N 8539.84 W 6010937.47 N 542824.91 E 224.152 8672.36 10843.91 90.620 113.970 3647.87 3711.27 1524.17 N 8510.99W 6010923.68 N 542853.85 E 11. 768 8641.79 10876.09 90.120 1.890 3647.56 3710.96 1538.66 N 8487.87 W 6010938.33 N 542876.88 E 348.282 8621.00 10906.56 89.880 115.620 3647.56 3710.96 1551.99N 8465.89 W 6010951 .82 N 542898.76 E 373.253 8601 .17 10937.10 89.570 296.010 3663.48 3726.88 1562.14 N 8460.93 W 6010962.00 N 542903.65 E 587.183 8597.73 10969.61 89.630 183.470 3663.82 3727.22 1548.26 N 8484.71 W 6010947.96 N 542879.97 E 346.158 8619.26 10996.23 89.690 215.570 3663.99 3727.39 1523.50 N 8493.49 W 6010923.14 N 542871.36 E 120.584 8624.38 11029.57 89.260 151.280 3664.33 3727.73 1491.94 N 8495.38 W 6010891.56 N 542869.69 E 192.826 8621.70 11061 .79 89.260 112.920 3664.76 3728.16 1470.74 N 8471.92 W 6010870.53 N 542893.29 E 119.046 8595.43 7 February, 2002 - 11 :05 Page 2 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for MPI-12 MWD Your Ref: API 500292303800 Job No. AKMM11164, Surveyed: 5 November, 2001 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 11087.46 89.690 298.980 3667.65 3731.05 1485.72 N 8464.64 W 6010885.55 N 542900.46 E 677.249 8590.39 "~ 11122.93 89.750 340.560 3667.83 3731.23 1512.21 N 8487.05 W 6010911.89 N 542877.87 E 117.224 8616.38 11150.84 90.310 245.270 3667.81 3731.21 1521.86 N 8509.90 W 6010921.39 N 542854.96 E 341 .423 8640.38 11171.87 90.680 251.740 3667.63 3731.03 1514.16 N 8529.45 W 6010913.55 N 542835.46 E 30.815 8658.62 11212.98 89.880 264.240 3667.42 3730.82 1505.63 N 8569.58 W 6010904.74 N 542795.39 E 30.468 8697.10 11244.53 89.140 275.620 3667.70 3731 .1 0 1505.59 N 8601.08 W 6010904.48 N 542763.89 E 36.144 8728.26 11273.22 87.540 264.390 3668.53 3731.93 1505.59 N 8629.71 W 6010904.29 N 542735.26 E 39.520 8756.60 11309.74 86.920 258.650 3670.30 3733.70 1500.21 N 8665.77 W 6010898.66 N 542699.24 E 15.790 8791 .51 11335.70 89.630 260.470 3671.08 3734.48 1495.51 N 8691.29 W 6010893.79 N 542673.76 E 12.573 8816.08 11369.28 89.880 261.930 3671.22 3734.62 1490.38 N 8724.47 W 6010888.42 N 542640.61 E 4.411 8848.18 11402.01 90.000 262.560 3671 .25 3734.65 1485.96 N 8756.90 W 6010883.78 N 542608.21 E 1.959 8879.63 11431 .64 90.000 265.400 3671.25 3734.65 1482.85 N 8786.37 W 6010880.47 N 542578.77 E 9.585 8908.34 11463.61 89.200 267.690 3671.48 3734.88 1480.93 N 8818.27 W 6010878.33 N 542546.87 E 7.587 8939.64 11495.64 89.140 269.410 3671.94 3735.34 1480.12 N 8850.29 W 6010877.29 N 542514.86 E 5.373 8971 .20 11526.63 88.460 268.960 3672.59 3735.99 1479.67 N 8881.27W 6010876.64 N 542483.89 E 2.631 9001 .80 11556.70 88.830 271 .280 3673.30 3736.70 1479.74 N 8911.33 W 6010876.50 N 542453.83 E 7.811 9031 .55 11599.25 91.170 274.900 3673.30 3736.70 1482.03 N 8953.81 W 6010878.50 N 542411.34 E 10.130 9073.92 11647.94 91.790 275.430 3672.04 3735.44 1486.41 N 9002.28 W 6010882.54 N 542362.83 E 1.675 9122.52 11694.79 91.290 276.570 3670.79 3734.19 1491.31 N 9048.86 W 6010887.12 N 542316.22 E 2.656 9169.31 '-' 11744.82 91.170 275.410 3669.71 3733.11 1496.53 N 9098.60 W 6010892.00 N 542266.44 E 2.330 9219.29 11786.71 91.110 276.240 3668.88 3732.28 1500.78 N 9140.27 W 6010895.96 N 542224.75 E 1.986 9261.13 11832.88 90.120 275.050 3668.38 3731.78 1505.32 N 9186.21 W 6010900.18 N 542178.78 E 3.353 9307.25 11878.80 89.940 275.930 3668.36 3731.76 1509.71 N 9231.92 W 6010904.26 N 542133.04 E 1.956 9353.12 11925.93 89.750 275.040 3668.49 3731.89 1514.22 N 9278.83 W 6010908.44 N 542086.10 E 1.931 9400.19 11973.82 89.630 274.820 3668.74 3732.14 1518.33 N 9326.54 W 6010912.23 N 542038.36 E 0.523 9448.00 12019.91 89.510 275.300 3669.09 3732.49 1522.40 N 9372.45 W 6010915.98 N 541992.42 E 1.073 9494.01 12069.60 89.200 275.930 3669.65 3733.05 1527.26 N 9421.90 W 6010920.50 N 541942.94 E 1.413 9543.64 1 211 7.72 89.820 276.350 3670.06 3733.46 1532.41 N 9469.74 W 6010925.32 N 541895.06 E 1.556 9591.73 12161.91 89.940 279.170 3670.15 3733.55 1538.37 N 9513.52 W 6010930.98 N 541851 .24 E 6.387 9635.91 12206.11 91 .410 277.880 3669.63 3733.03 1544.92 N 9557.23 W 6010937.23 N 541807.49 E 4.425 9680.11 7 February, 2002 - 11 :05 Page 3 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-12 MWD Your Ref: API 500292303800 Job No. AKMM11164, Surveyed: 5 November, 2001 . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/1 OOft) 12260.55 92.640 280.420 3667.71 3731.11 1553.57 N 9610.94 W 6010945.51 N 541753.73 E 5.181 9734.50 -.~ 12305.44 92.830 279.820 3665.57 3728.97 1561.45N 9655.08 W 6010953.09 N 541709.53 E 1.401 9779.32 12353.40 92.830 278.810 3663.20 3726.60 1569.21 N 9702.35 W 6010960.51 N 541662.21 E 2.103 9827.21 12405.45 92.520 276.370 3660.77 3724.17 1576.07 N 9753.88 W 6010967.02 N 541610.63 E 4.720 9879.20 12424.94 92.340 276.900 3659.94 3723.34 1578.32 N 9773.23 W 6010969.14 N 541591.27 E 2.870 9898.66 12470.00 92.340 276.900 3658.10 3721.50 1583.73 N 9817.92 W 6010974.24 N 541546.54 E 0.000 9943.67 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.096° (05-Nov-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 278.285° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12470.00ft., The Bottom Hole Displacement is 9944.84ft., in the Direction of 279.163° (True). ~ 7 February, 2002 - 11 :05 Page 4 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-12 MWD . Your Ref: API 500292303800 Job No. AKMM11164, Surveyed: 5 November, 2001 . Milne Point Unit Alaska Drilling & Wells Milne Point MPI Comments --' Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10177.88 10223.00 12470.00 3699.91 3706.21 3721.50 1572.76 N 1581.37 N 1583.73 N 8039.11 W 8082.93 W 9817.92 W Tie-On Point Window Point Projected Survey Survey tool program for MPI-12 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 0.00 12470.00 3721.50 MWD Magnetic (MPI-12PB1 MWD) -- 7 February, 2002 - 11 :05 Page 5 of 5 DrillQuest 2.00.08.005 (Y) -S)" ......... ~ (J 15 DEFINITIVE ~ Milne Point Unit Alaska Drilling & Wells Milne Point MPI, Slot MPI-12 MPI-12 Job No. AKZZ11164, Surveyed: 5 November, 2001 O--'~ I, SURVEY REPORT 3 December, 2001 (-') ~ Your Ref: API 500292303800 Surface Coordinates: 6009458.18 N, 551375.14 E (70026' 11.7316" N, 149034' 52.0644" W) Kelly Bushing: 63.40ft above Mean Sea Level ---- sper'l'y-sul! DRILLING SERVices A Halliburton Company Survey Ref: svy10025 Sperry-Sun Drilling Services . Survey Report for MPI-12 Your Ref: API 500292303800 Job No. AKZZ11164, Surveyed: 5 November, 2001 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) \....,., 10177.88 81.240 277 .890 3636.05 3699.45 1140.06 N 8117.86 W 6010542.29 N 543249.62 E 8196.36 Tie-On Point 10223.00 82.740 277.990 3642.34 3705.74 1146.23 N 8162.11 W 6010548.16 N 543205.33 E 3.332 8241.03 Window Point 10228.00 82.910 278.000 3642.96 3706.36 1146.92 N 8167.02 W 6010548.82 N 543200.41 E 3.406 8246.00 '~ 10256.77 88.520 277 .560 3645.11 3708.51 1150.81 N 8195.44 W 6010552.50 N 543171.97 E 19.559 8274.67 10288.61 89.820 277.070 3645.57 3708.97 1154.86 N 8227.01 W 6010556.34 N 543140.37 E 4.363 8306.51 10319.99 90.060 276.590 3645.61 3709.01 1158.59 N 8258.17 W 6010559.86 N 543109.18 E 1.710 8337.89 10345.70 89.450 276.190 3645.72 3709.12 1161.45 N 8283.72 W 6010562.54 N 543083.62 E 2.837 8363.59 10377.65 87.170 275.700 3646.66 3710.06 1164.76 N 8315.48 W 6010565.63 N 543051.83 E 7.299 8395.52 10407.65 86.490 275.240 3648.32 3711.72 1167.61 N 8345.30 W 6010568.28 N 543022.00 E 2.735 8425.46 10440.65 86.370 274.730 3650.37 3713.77 1170.48 N 8378.11 W 6010570.92 N 542989.16 E 1.585 8458.38 10474.23 86.430 274.210 3652.48 3715.88 1173.09 N 8411.52 W 6010573.30 N 542955.74 E 1.556 8491.86 10503.88 86.620 273.750 3654.28 3717.68 1175.14 N 8441.05 W 6010575.15 N 542926.20 E 1.676 8521.41 10532.07 86.670 273.320 3655.93 3719.33 1176.88 N 8469.13 W 6010576.69 N 542898.10 E 1.533 8549.50 10568.15 87.910 272.770 3657.63 3721.03 1178.79 N 8505.12 W 6010578.36 N 542862.10 E 3.759 8585.45 10599.16 88,650 272.300 3658.57 3721.97 1180.16 N 8536.09 W 6010579.51 N 542831.12 E 2.827 8616.35 10629.96 88.400 271.830 3659.36 3722.76 1181.27 N 8566.86 W 6010580.41 N 542800.35 E 1.728 8647.03 10661.21 90.310 271.350 3659.71 3723.11 1182.14 N 8598.09 W 6010581.06 N 542769.11 E 6.302 8678.13 10689.95 90.800 270.910 3659.43 3722.83 1182.71 N 8626.83 W 6010581.43 N 542740.37 E 2.291 8706.72 10718.41 90,990 270.480 3658.99 3722.39 1183.05 N 8655.28 W 6010581.58 N 542711.92 E 1.652 8735.00 10751.40 90.920 269.980 3658.44 3721.84 1183.18 N 8688.26 W 6010581.49 N 542678.93 E 1.530 8767.76 .~ 10782.76 90.740 269.500 3657.98 3721.38 1183.04 N 8719.62 W 6010581.13 N 542647.58 E 1.635 8798.86 10811.84 90.800 269.060 3657.59 3720.99 1182.68 N 8748.70 W 6010580.56 N 542618.50 E 1.527 8827.67 10843.91 90,620 268.570 3657.19 3720.59 1182.01 N 8780.76 W 6010579.68 N 542586.45 E 1.628 8859.41 10876.09 90.120 268.080 3656.99 3720.39 1181.07 N 8812.92 W 6010578.52 N 542554.29 E 2.175 8891.22 10906.56 89,880 267.620 3656.99 3720.39 1179.93 N 8843.37 W 6010577.16 N 542523.85 E 1.703 8921.30 10937.10 89.570 267.160 3657.13 3720.53 1178.54 N 8873.88 W 6010575.56 N 542493.35 E 1.816 8951.41 10969.61 89,630 266.670 3657.36 3720.76 1176.79 N 8906.34 W 6010573.59 N 542460.90 E 1.518 8983.41 10996.23 89.690 266.270 3657.52 3720.92 1175.15 N 8932.91 W 6010571.77 N 542434.35 E 1.519 9009.58 11029.57 89.260 265.770 3657.82 3721.22 1172.84 N 8966.17 W 6010569.22 N 542401.11 E 1.978 9042.30 11061.79 89.260 265.280 3658.24 3721.64 1170.32 N 8998.29 W 6010566.49 N 542369.01 E 1.521 9073.87 3 December, 2001 - 10:56 Page 2 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for MPI-12 Your Ref: API 500292303800 Job No. AKZZ11164, Surveyed: 5 November, 2001 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) ',-, 11087.46 89.690 264.890 3658.4 7 3721.87 1168.12 N 9023.86 W 6010564.11 N 542343.45 E 2.261 9098.99 11122.93 89.750 264.360 3658.65 3722.05 1164.80 N 9059.17 W 6010560.55 N 542308.16 E 1.504 9133.63 11150.84 90.310 263.960 3658.63 3722.03 1161.96N 9086.94 W 6010557.52 N 542280.41 E 2.466 9160.84 '-~ 11171.87 90.680 263.330 3658.45 3721.85 1159.63 N 9107.84 W 6010555.05 N 542259.53 E 3.474 9181.29 11212.98 89.880 262.100 3658.25 3721.65 1154.42 N 9148.62 W 6010549.55 N 542218.79 E 3.569 9221 .13 11244.53 89.140 261.160 3658.52 3721.92 1149.83 N 9179.83 W 6010544.74 N 542187.61 E 3.792 9251.54 11273.22 87.540 260.310 3659.35 3722.75 1145.21 N 9208.13W 6010539.93 N 542159.34 E 6.314 9279.07 11309.74 86.920 260.900 3661.12 3724.52 1139.26 N 9244.12 W 6010533.73 N 542123.39 E 2.342 9314.06 11335.70 89.630 263.340 3661.90 3725.30 1135.70 N 9269.82 W 6010530.00 N 542097.72 E 14.044 9339.13 11369.28 89.880 262.460 3662.04 3725.44 1131.55 N 9303.14 W 6010525.62 N 542064.43 E 2.724 9371.69 11402.01 90.000 261.920 3662.08 3725.48 1127.10 N 9335.56 W 6010520.95 N 542032.03 E 1.690 9403.33 11431.64 90.000 264.440 3662.08 3725.48 1123.58 N 9364.98 W 6010517.23 N 542002.64 E 8.505 9432.09 11463.61 89.200 266.910 3662.30 3725.70 1121.17 N 9396.86 W 6010514.60 N 541970.78 E 8.121 9463.43 11495.64 89.140 268.830 3662.76 3726.16 1119.98 N 9428.86 W 6010513.18 N 541938.79 E 5.997 9495.05 11526.63 88.460 269.640 3663.41 3726.81 1119.57 N 9459.84 W 6010512.56 N 541907.81 E 3.412 9525.75 11556.70 88.830 271.640 3664.12 3727.52 1119.90 N 9489.90 W 6010512.69 N 541877.75 E 6.762 9555.62 11599.25 91.170 274.900 3664.12 3727.52 1122.33 N 9532.37 W 6010514.82 N 541835.26 E 9.431 9598.07 11647.94 91.790 276.190 3662.87 3726.27 1127.03 N 9580.82 W 6010519.19 N 541786.79 E 2.939 9646.73 11694.79 91.290 276.160 3661.61 3725.01 1132.07 N 9627.38 W 6010523.91 N 541740.19 E 1.069 9693.55 11744.82 91.170 275.370 3660.53 3723.93 1137.10 N 9677.14 W 6010528.59 N 541690.39 E 1.597 9743.56 -~- 11786.71 91.110 275.410 3659.70 3723.10 1141.03 N 9718.84 W 6010532.23 N 541648.67 E 0.172 9785.42 11832.88 90.120 275.010 3659.20 3722.60 1145.22 N 9764.82 W 6010536.11 N 541602.67 E 2.313 9831.57 11878.80 89.940 275.010 3659.18 3722.58 1149.23 N 9810.56 W 6010539.80 N 541556.90 E 0.392 9877.46 11925.93 89.750 274.110 3659.31 3722.71 1152.98 N 9857.54 W 6010543.23 N 541509.89 E 1.952 9924.54 11973.82 89.630 274.210 3659.57 3722.97 1156.45 N 9905.30 W 6010546.37 N 541462.11 E 0.326 9972.37 12019.91 89.510 275.460 3659.91 3723.31 1160.34 N 9951.23 W 6010549.94 N 541416.16 E 2.724 10018.43 12069.60 89.200 275.960 3660.47 3723.87 1165.28 N 10000.67 W 6010554.54 N 541366.68 E 1.184 10068.10 12117.72 89.820 276.200 3660.88 3724.28 1170.38 N 10048.51 W 6010559.31 N 541318.80 E 1.382 10116.21 12161.91 89.940 277.410 3660.98 3724.38 1175.61 N 10092.39 W 6010564.24 N 541274.89 E 2.752 10160.40 12206.11 91.410 276.360 3660.46 3723.86 1180.91 N 10136.27 W 6010569.24 N 541230.98 E 4.087 10204.60 3 December, 2001 - 10:56 Page 3 of 5 DrillQucst 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-12 Your Ref: API 500292303800 Job No. AKZZ11164, Surveyed: 5 November, 2001 . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) ",- 12260.55 92.640 278.840 3658.53 3721.93 1188.11 N 10190.19 W 6010576.06 N 541177.01 E 5.082 10258.99 12305.44 92.830 278.330 3656.39 3719.79 1194.80 N 10234.53 W 6010582.45 N 541132.62 E 1.211 10303.82 12353.40 92.830 277.590 3654.02 3717.42 1201.43 N 10281.97 W 6010588.76 N 541085.14 E 1.541 10351.71 "-' 12405.45 92.520 277.540 3651.59 3714.99 1208.28 N 10333.51 W 6010595.25 N 541033.55 E 0.603 10403.70 12424.94 92.340 277.250 3650.77 3714.17 1210.78 N 10352.82 W 6010597.62 N 541014.23 E 1.750 10423.17 12470.00 92.340 277 .250 3648.93 3712.33 1216.47 N . 10397.48 W 6010602.99 N 540969.53 E 0.000 10468.20 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.096° (05-Nov-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 277.030° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12470.00ft., The Bottom Hole Displacement is 10468.40ft., in the Direction of 276.673° (True). '-. "-c~ 3 December, 2001 - 10:56 Page 4 of 5 DriflQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-12 Your Ref: API 500292303800 Job No. AKZZ11164, Surveyed: 5 November, 2001 . Milne Point Unit Alaska Drilling & Wells Milne Point MPI Comments "- Measured Depth eft) Station Coordinates TVD Northings Eastings eft) eft) eft) Comment ~ 10177.88 10223.00 12470.00 3699.45 3705.74 3712.33 1140.06 N 1146.23 N 1216.47 N 8117.86 W 8162.11 W 10397.48 W Tie-On Point Window Point Projected Survey Survey tool program for MPI-12 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description eft) eft) eft) eft) 0.00 0.00 12470.00 3712.33 AK-6 BP _IFR-AK (MPI-12PB1) "".-~ 3 December, 2001 - 10:56 Page 50'5 DrillQuest 2.00.08.005 .{ AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 f Definative Surveys Re: Distribution of Survey Data for Well MPI-12PB1 ~bl'/(o.3 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Su rvey: Window / Kickoff Survey Projected Survey: 0.00' MD , MD (if applicable) 13,243.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Su rvey Manager Attachment(s) 03-Dec-01 RECEIVED DEe "11 2001 Alaska Oil & Gas Comt Comrn!ssion Anctwrage rY) ~ "" I -... <J . co DEFINITIVE ...~. Milne Point Unit Alaska Drilling & Wells Milne Point MPI, Slot MPI-12 MPI-12PB1 Job No. AKZZ11164, Surveyed: 23 October, 2001 SURVEY REPORT 30 November, 2001 Your Ref: API 500292303870 Surface Coordinates: 6009458.18 H, 551375.14 E (700 26'11.7316" N, 149034' 52.0644" W) Kelly Bushing: 63.40ft above Mean Sea Level ~.- speI'l'V-su" DRILLING SERVices A Halliburton Company Survey Ref: svy9935 Sperry-Sun Drilling Services . Survey Report for MP/.12PB1 Your Ref: API 500292303870 Job No. AKZZ11164, Surveyed: 23 October, 2001 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -63.40 0.00 0.00 N O.DOE 6009458.18 N 551375.14 E 0.00 AK-6 BP _'FR-AK 310.60 0.770 102.310 247.19 310.59 0.44 8 2.04E 6009457.75 N 551377.18 E 0.248 -2.08 397.36 0.650 86.140 333.94 397.34 0.548 3.10 E 6009457.67 N 551378.24 E 0.268 -3.14 --~ 489.12 0.960 5.860 425.70 489.10 0.26 N 3.70E 6009458.47 N 551378.84 E 1.160 -3.62 578.59 1.180 333.900 515.15 578.55 1.84 N 3.37E 6009460.04 N 551378.50 E 0.700 -3.08 669.57 2.920 326.370 606.07 669.47 4.61 N 1.67 E 6009462.80 N 551376.78 E 1.931 -1.01 764.37 4.300 338.790 700.68 764.08 9.93N 0.95W 6009468.10 N 551374.12 E 1.665 2.33 858.05 6.460 336.750 793.94 857.34 18.05 N 4.30W 6009476.20 N 551370.71 E 2.314 6.78 951.99 8.960 333.780 887.03 950.43 29.47 N 9.62W 6009487.58 N 551365.32 E 2.694 13.64 1045.53 10.360 329.000 979.24 1042.64 43.21 N 17.17 W 6009501.27 N 551357.67 E 1.724 23.03 1139.49 11.170 319.220 1071.55 1134.95 57.35 N 27.47 W 6009515.34 N 551347.28 E 2.123 35.20 1233.24 13.780 301.190 1163.12 1226.52 70.01 N 42.96 W 6009527.90 N 551331.70 E 4.969 52.31 1327.31 16.570 294.160 1253.91 1317.31 81.31 N 64.79 W 6009539.04 N 551309.79 E 3.548 75.50 1420.07 15.780 293.350 1342.99 1406.39 91.72 N 88.44 W 6009549.29 N 551286.07 E 0.886 100.37 1515.01 16.520 289.740 1434.19 1497.59 101.40 N 112.99 W 6009558.80 N 551261.45 E 1.313 126.04 1602.03 20.090 279.830 1516.81 1580.21 108.13 N 139.38 W 6009565.35 N 551235.02 E 5.429 153.10 1703.34 20.810 279.460 1611.74 1675.14 114.06 N 174.28 W 6009571.04 N 551200.08 E 0.722 188.49 1797.91 21.300 279.470 1699.99 1763.39 119.65 N 207.79 W 6009576.39 N 551166.53 E 0.518 222.45 1891.65 25.300 277.160 1786.07 1849.47 124.95 N 244.47 W 6009581.44 N 551129.81 E 4.376 259.51 1985.90 30.810 276.610 1869.22 1932.62 130.24 N 288.47 W 6009586.43 N 551085.78 E 5.853 303.82 2080.02 38.080 276.380 1946.78 2010.18 136.25 N 341.33 W 6009592.07 N 551032.88 E 7.725 357.00 2174.66 44.050 278.630 2018.11 2081.51 144.44 N 402.92 W 6009599.84 N 550971.24 E 6.498 419.13 2268.86 49.140 277.710 2082.82 2146.22 154.14 N 470.64 W 6009609.07 N 550903.45 E 5.450 487.54 2363.55 53.210 278.540 2142.17 2205.57 164.57 N 543.65 W 6009619.01 N 550830.37 E 4.352 561.29 2456.65 58. 690 278.430 2194.28 2257.68 175.95 N 619.92 W 6009629.85 N 550754.03 E 5.887 638.40 2550.68 63.740 278.520 2239.54 2302.94 188.09 N 701.40 W 6009641.44 N 550672.46 E 5.371 720.78 2644.91 68.980 279.740 2277.31 2340.71 201.80 N 786.59 W 6009654.56 N 550587.17 E 5.686 807.06 2739.70 74.100 281.570 2307.32 2370.72 218.44 N 874.92 W 6009670.59 N 550498.74 E 5.703 896.84 2832.92 78.290 281.850 2329.56 2392.96 236.81 N 963.54 W 6009688.35 N 550409.99 E 4.504 987.16 2870.38 78.410 282.320 2337.13 2400.53 244.49 N 999.42 W 6009695.78 N 550374.06 E 1.270 1023.75 -- ------- --- 30 November, 2001 - 17:34 Page 20f8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for MPI-12PB1 Your Ref: API 500292303870 Job No. AKZZ11164, Surveyed: 23 October, 2001 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 3037.39 78.920 285.890 2369.96 2433.36 284.40 N 1158.20 W 6009734.59 N 550215.01 E 2.118 1186.55 3133.33 82.280 284.330 2385.63 2449.03 309.06 N 1249.57 W 6009758.63 N 550123.47 E 3.852 1280.4 7 3228.07 80.100 284.990 2400.14 2463.54 332.75 N 1340.14 W 6009781.69 N 550032.74 E 2.402 1373.45 - 3321.32 78.930 284.640 2417.11 2480.51 356.20 N 1428.78 W 6009804.53 N 549943.94 E 1.308 1464.50 3414.30 79.600 284.640 2434.43 2497.83 379.29 N 1517.17 W 6009827.01 N 549855.40 E 0.721 1555.24 3508.43 80.550 283.840 2450.65 2514.05 402.09 N 1607.04 W 6009849.19 N 549765.37 E 1.311 1647.42 3602.44 78.490 284.340 2467.75 2531.15 424.59 N 1696.69 W 6009871.08 N 549675.56 E 2.253 1739.34 3696.96 77.650 284.740 2487.29 2550.69 447.81 N 1786.21 W 6009893.68 N 549585.89 E 0.980 1831.22 3788.27 81.420 278.100 2503.89 2567.29 465.55 N 1874.16 W 6009910.80 N 549497.82 E 8.256 1920.78 3881.96 82.850 278.870 2516.71 2580.11 479.24 N 1965.95 W 6009923.87 N 549405.94 E 1.730 2013.58 3976.14 83.280 279.050 2528.08 2591.48 493.80 N 2058.30 W 6009937.79 N 549313.49 E 0.494 2107.06 4069.89 82.780 279.740 2539.46 2602.86 508.99 N 2150.11 W 6009952.35 N 549221.58 E 0.905 2200.09 4166.58 82.660 276.590 2551.71 2615.11 522.61 N 2245.03 W 6009965.31 N 549126.56 E 3.234 2295.99 4260.24 82.730 275.640 2563.62 2627.02 532.51 N 2337.40 W 6009974.57 N 549034.12 E 1.009 2388.84 4354.33 81.410 276.060 2576.60 2640.00 542.00 N 2430.11 W 6009983.43 N 548941.36 E 1.471 2481.96 4448.16 80.990 275.870 2590.96 2654.36 551.64 N 2522.33 W 6009992.43 N 548849.07 E 0.490 2574.62 4542.36 82.540 273.250 2604.45 2667.85 559.05 N 2615.25 W 6009999.20 N 548756.10 E 3.207 2667.67 4636.56 83.160 273.520 2616.18 2679.58 564.57 N 2708.55 W 6010004.07 N 548662.76 E 0.717 2760.83 4729.07 81.600 273.140 2628.44 2691.84 569.89 N 2800.09 W 6010008.77 N 548571.19 E 1.735 2852.21 4822.85 81.670 272.600 2642.09 2705.49 574.54 N 2892.76 W 6010012.78 N 548478.50 E 0.575 2944.62 "- 4916.63 80.540 273.250 2656.59 2719.99 579.27 N 2985.29 W 6010016.87 N 548385.94 E 1.386 3036.91 5011.75 79.930 273.020 2672.72 2736.12 584.39 N 3078.89 W 6010021.35 N 548292.30 E 0.684 3130.31 5105.24 78.860 273.970 2689.93 2753.33 589.99 N 3170.61 W 6010026.32 N 548200.54 E 1.519 3221.91 5198.57 79.350 273.880 2707.57 2770.97 596.27 N 3262.04 W 6010031.96 N 548109.07 E 0.533 3313.32 5292.76 79.050 273.690 2725.21 2788.61 602.37 N 3354.36 W 6010037.43 N 548016.71 E 0.375 3405.59 5389.12 79.550 273.730 2743.11 2806.51 608.50 N 3448.84 W 6010042.91 N 547922.19 E 0.520 3500.01 5485.97 79.100 276.440 2761.05 2824.45 616.93 N 3543.63 W 6010050.69 N 547827.34 E 2.789 3595.05 5574.80 79.290 275.060 2777.70 2841.10 625.67 N 3630.45 W 6010058.83 N 547740.47 E 1.541 3682.23 5670.33 79.600 275.160 2795.20 2858.60 634.04 N 3723.99 W 6010066.55 N 547646.87 E 0.340 3776.03 5764.30 79.170 275.630 2812.51 2875.91 642.72 N 3815.94 W 6010074.60 N 547554.86 E 0.672 3868.29 -..--. ------- 30 November, 2001 - 17:34 Page 3 of 8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for MPI-12PB1 Your Ref: API 500292303870 Job No. AKZZ11164, Surveyed: 23 October, 2001 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5858.40 79.360 274.390 2830.04 2893.44 650.80 N 3908.04 W 6010082.04 N 547462.71 E 1.310 3960.61 5951.90 80.730 274.680 2846.20 2909.60 658.08 N 3999.84 W 6010088.69 N 547370.86 E 1.497 4052.53 6045.58 79.740 274.550 2862.09 2925.49 665.51 N 4091.86 W 6010095.48 N 547278.79 E 1.066 4144.69 .- 6138.93 77.030 276.070 2880.89 2944.29 673.96 N 4182.90 W 6010103.31 N 547187.70 E 3.312 4236.02 6233.21 77.350 276.190 2901.79 2965.19 683.78 N 4274.30 W 6010112.50 N 547096.23 E 0.361 4327.90 6326.91 76.540 276.720 2922.96 2986.36 694.04 N 4365.00 W 6010122.13 N 547005.46 E 1.025 4419.14 6419.16 78.480 276.4 70 2942.91 3006.31 704.38 N 4454.47 W 6010131.86 N 546915.92 E 2.120 4509.18 6512.90 78.740 275.970 2961.42 3024.82 714.34 N 4545.82 W 6010141.19 N 546824.50 E 0.592 4601.03 6609.32 79.550 275.290 2979.58 3042.98 723.63 N 4640.06 W 6010149.83 N 546730.21 E 1.089 4695.64 6702.88 79.100 275.150 2996.91 3060.31 731.99 N 4731.62 W 6010157.56 N 546638.59 E 0.503 4787.47 6797.46 77.910 276.400 3015.76 3079.16 741.32 N 4823.83 W 6010166.25 N 546546.32 E 1.806 4880.08 6891.60 79.220 276.920 3034.42 3097.82 752.02 N 4915.47 W 6010176.32 N 546454.60 E 1.493 4972.32 6985.83 78.410 277 .240 3052.70 3116.10 763.41 N 5007.21 W 6010187.08 N 546362.79 E 0.922 5064.75 7079.77 78.280 276.240 3071.68 3135.08 774.21 N 5098.57 W 6010197.25 N 546271.35 E 1.052 5156.72 7172.40 78.430 276.370 3090.37 3153.77 784.17 N 5188.75 W 6010206.59 N 546181.11 E 0.212 5247.41 7266.44 77.670 275.300 3109.84 3173.24 793.53 N 5280.27 W 6010215.31 N 546089.53 E 1.376 5339.34 7360.52 78.740 276.020 3129.08 3192.48 802.61 N 5371.91 W 6010223.77 N 545997.82 E 1.362 5431.35 7455.62 80.660 276.060 3146.08 3209.48 812.46 N 5464.96 W 6010232.97 N 545904.71 E 2.019 5524.86 7549.53 80.420 275.760 3161.51 3224.91 821.99 N 5557.10 W 6010241.87 N 545812.51 E 0.406 5617.43 7642.95 80.120 274.630 3177.30 3240.70 830.33 N 5648.79W 6010249.58 N 545720.76 E 1.235 5709.39 ~- 7736.71 80.660 274.520 3192.95 3256.35 837.71 N 5740.94 W 6010256.32 N 545628.56 E 0.587 5801.67 7830.65 82.160 274.730 3206.99 3270.39 845.20 N 5833.52 W 6010263.17 N 545535.93 E 1.612 5894.39 7924.60 83.530 273.880 3218.69 3282.09 852.19 N 5926.48 W 6010269.53 N 545442.93 E 1.712 5987.41 8015.53 84.390 274.980 3228.26 3291.66 859.18 N 6016.63 W 6010275.89 N 545352.73 E 1.530 6077.66 8109.73 85.500 276.620 3236.56 3299.96 868.66 N 6109.98 W 6010284.73 N 545259.32 E 2.097 6171.41 8203.41 82.850 274.940 3246.06 3309.46 878.05 N 6202.69 W 6010293.48 N 545166.55 E 3.344 6264.53 8295.55 80.170 273.420 3259.67 3323.07 884.69 N 6293.57 W 6010299.50 N 545075.63 E 3.335 6355.44 8392.44 78.610 274.600 3277.51 3340.91 891.35 N 6388.56 W 6010305.50 N 544980.59 E 2.006 6450.44 848f>. 18 78.560 273.830 3296.06 3359.46 898.10 N 6480.20 W 6010311.62 N 544888.91 E 0.807 6542.12 8580.52 78.540 273.660 3314.79 3378.19 904.14 N 6572.46 W 6010317.03 N 544796.60 E 0.178 6634.33 30 November, 2001 - 17:34 Page 4 of 8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for MPI-12PB1 Your Ref: API 500292303870 Job No. AKZZ11164, Surveyed: 2~ October, 2001 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical, Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 8673.67 77.660 275.670 3334.00 3397.40 911.55N 6663.30 W 6010323.81 N 544705.72 E 2.313 6725.31 8768.11 77.600 274.840 3354.23 3417.63 920.00 N 6755.16 W 6010331.63 N 544613.80 E 0.861 6817.45 8859.89 76.720 277.020 3374.63 3438.03 929.24 N 6844.16 W 6010340.25 N 544524.74 E 2.506 6906.87 ~ 8950.98 76.460 276.540 3395.75 3459.15 939.70 N 6932.15 W 6010350.11 N 544436.68 E 0.587 6995.45 9048.92 78.160 276.4 70 3417.27 3480.67 950.53 N 7027.08 W 6010360.28 N 544341.68 E 1.737 7090.96 9140.46 77.800 278.570 3436.33 3499.73 962.24 N 7115.83 W 6010371.38 N 544252.85 E 2.278 7180.49 9236.51 77.150 279.180 3457.16 3520.56 976.71 N 7208.48 W 6010385.21 N 544160.11 E 0.918 7274.24 9330.26 78.920 281.630 3476.60 3540.00 993.28 N 7298.67 W 6010401.16 N 544069.80 E 3.178 7365.86 9424.01 79.670 281.060 3494.01 3557.41 1011.40 N 7388.99 W 6010418.65 N 543979.36 E 0.998 7457.83 9518.31 79.430 281.990 3511.12 3574.52 1029.92 N 7479.85 W 6010436.55 N 543888.37 E 1.003 7550.39 9612.39 79.550 281.040 3528.28 3591.68 1048.39 N 7570.49 W 6010454.39 N 543797.61 E 1.001 7642.72 9706.37 79.300 281.390 3545.53 3608.93 1066.36 N 7661.11 W 6010471.74 N 543706.87 E 0.453 7734.96 9801.18 78.420 279.780 3563.85 3627.25 1083.45 N 7752.55 W 6010488.20 N 543615.32 E 1.907 7827.88 9894.91 78.360 278.590 3582.71 3646.11 1098.10 N 7843.18 W 6010502.23 N 543524.58 E 1.245 7919.67 9989.64 78.730 278.700 3601.52 3664.92 1112.06 N 7934.97 W 6010515.55 N 543432.70 E 0.407 8012.51 10083.51 78.870 279.120 3619.76 3683.16 1126.32 N 8025.94 W 6010529.19 N 543341.63 E 0.464 8104.58 10177.88 81.240 277.890 3636.05 3699.45 1140.06 N 8117.86 W 6010542.29 N 543249.62 E 2.820 8197.52 10270.76 84.330 278.100 3647.72 3711.12 1152.88 N 8209.10 W 6010554.48 N 543158.30 E 3.334 8289.66 10306.77 84.090 278.370 3651.35 3714.75 1158.01 N 8244.55 W 6010559.37 N 543122.80 E 1.000 8325.48 10365.74 83.840 279.230 3657.55 3720.95 1166.98 N 8302.51 W 6010567.94 N 543064.79 E 1.511 8384.12 "- 10412.47 87.480 284.120 3661.09 3724.49 1176.41 N 8348.12 W 6010577.05 N 543019.12 E 13.020 8430.60 10458.81 91.170 282.190 3661.63 3725.03 1186.95 N 8393.23 W 6010587.29 N 542973.94 E 8.986 8476.74 10506.16 92.890 283.370 3659.96 3723.36 1197.42 N 8439.37 W 6010597.43 N 542927.72 E 4.404 8523.89 10555.30 89.940 282.710 3658.74 3722.14 1208.50 N 8487.22 W 6010608.19 N 542879.79 E 6.152 8572.82 10603.66 90.000 281.200 3658.77 3722.17 1218.52 N 8534.53 W 6010617.88 N 542832.41 E 3.125 8621.07 10647.23 88.340 279.850 3659.40 3722.80 1226.48 N 8577.36 W 6010625.54 N 542789.53 E 4.911 8664.59 10689.69 91.850 279.850 3659.33 3722.73 1233.74 N 8619.19 W 6010632.52 N 542747.65 E 8.267 8707.02 10739.90 91.660 279.810 3657.79 3721.19 1242.31 N 8668.64 W 6010640.74 N 542698.15 E 0.387 8757.18 10787.43 93.140 275.940 3655.80 3719.20 1248.81 N 8715.67 W 6010646.92 N 542651.07 E 8.710 8804.66 10833.11 91.600 272.170 3653.91 3717.31 1252.04 N 8761.19W 6010649.84 N 542605.53 E 8.908 8850.18 30 November, 2001- 17:34 Page 5 of 8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for MPI-12PB1 Your Ref: API 500292303870 Job No. AKZZ11164, Surveyed: 23 October, 2001 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10876.42 90.060 272.410 3653.28 3716.68 1253.77 N 8804.46 W 6010651.27 N 542562.25 E 3.599 8893.27 10925.83 89.260 270.710 3653.58 3716.98 1255.11 N 8853.85 W 6010652.27 N 542512.86 E 3.802 8942.36 10966.46 89.880 270.440 3653.88 3717.28 1255.52 N 8894.47 W 6010652.40 N 542472.23 E 1.664 8982.65 .~~ 11019.31 91.290 273.200 3653.34 3716.74 1257.20 N 8947.29 W 6010653.72 N 542419.40 E 5.864 9035.18 11062.82 90.490 273.930 3652.67 3716.07 1259.90 N 8990.71 W 6010656.12 N 542375.97 E 2.489 9078.55 11111.09 90.180 273.860 3652.38 3715.78 1263.18 N 9038.87 W 6010659.07 N 542327.79 E 0.658 9126.70 11157.68 89.630 274.210 3652.46 3715.86 1266.46 N 9085.34 W 6010662.03 N 542281.29 E 1.399 9173.17 11204.39 88.340 274.740 3653.29 3716.69 1270.11 N 9131.90 W 6010665.35 N 542234.71 E 2.986 9219.79 11249.44 88.030 275.470 3654.71 3718.11 1274.11 N 9176.75 W 6010669.05 N 542189.83 E 1.760 9264.76 11299.27 88.150 277.050 3656.38 3719.78 1279.54 N 9226.25 W 6010674.14 N 542140.29 E 3.178 9314.53 11345.13 88.950 277.070 3657.54 3720.94 1285.18 N 9271.75 W 6010679.46 N 542094.76 E 1.745 9360.37 11393.07 89.320 277.210 3658.26 3721.66 1291.14 N 9319.31 W 6010685.09 N 542047.16 E 0.825 9408.30 11437.63 89.260 276.830 3658.81 3722.21 1296.58 N 9363.53 W 6010690.23 N 542002.90 E 0.863 9452.85 11487.08 89.200 277.090 3659.48 3722.88 1302.57 N 9412.61 W 6010695.88 N 541953.78 E 0.540 9502.29 11531.86 89.260 276.320 3660.08 3723.48 1307.80 N 9457.08 W 6010700.80 N 541909.27 E 1.725 9547.05 11581.22 90.000 276.460 3660.40 3723.80 1313.29 N 9506.14 W 6010705.96 N 541860.18 E 1.526 9596.39 11626.20 90.310 275.780 3660.28 3723.68 1318.09 N 9550.86 W 6010710.45 N 541815.43 E 1.661 9641.34 11675.54 88.220 276.220 3660.91 3724.31 1323.25 N 9599.92 W 6010715.26 N 541766.33 E 4.329 9690.65 11720.97 87.910 276.070 3662.44 3725.84 1328.11 N 9645.06 W 6010719.81 N 541721.16 E 0.758 9736.03 11766.80 87.910 276.550 3664.11 3727.51 1333.14 N 9690.59 W 6010724.53 N 541675.60 E 1.047 9781.81 ~~- 11814.92 88.770 275.970 3665.51 3728.91 1338.38 N 9738.40 W 6010729.45 N 541627.75 E 2.155 9829.88 11861.92 89.140 275.630 3666.36 3729.76 1343.13 N 9785.15 W 6010733.88 N 541580.97 E 1.069 9876.84 11908.30 88.770 275.810 3667.21 3730.61 1347.76 N 9831.29 W 6010738.18 N 541534.80 E 0.887 9923.17 11956.19 89.020 275.920 3668.13 3731.53 1352.65 N 9878.92 W 6010742.74 N 541487.13 E 0.570 9971.02 12002.47 88.950 275.720 3668.95 3732.35 1357.34 N 9924.96 W 6010747.12 N 541441.07 E 0.458 10017.26 12048.89 88.520 276.910 3669.98 3733.38 1362.44 N 9971.08 W 6010751.91 N 541394.91 E 2.725 10063.65 12096.41 90.490 277.200 3670.39 3733.79 1368.28 N 10018.24 W 6010757.42 N 541347.71 E 4.190 10111.16 12142.17 90.550 277.780 3669.97 3733.37 1374.25 N 10063.61 W 6010763.07 N 541302.31 E 1.274 10156.91 12187.97 90.980 277.360 3669.36 3732.76 1380.28 N 10109.00 W 6010768.79 N 541256.87 E 1.312 10202.71 12232.23 91.290 277.480 3668.49 3731.89 1385.99 N 10152.88 W 6010774.20 N 541212.95 E 0.751 10246.95 30 November, 2001 - 17:34 Page 6 of 8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for MPI-12PB1 Your Ref: API 500292303870 Job No. AKZZ11164, Surveyed: 23 October, 2001 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12278.93 91.850 278.150 3667.21 3730.61 1392.34 N 10199.13 W 6010780.23 N 541166.66 E 1.869 10293.64 12324.97 91.780 278.460 3665.75 3729.15 1398.99 N 10244.67 W 6010786.56 N 541121.08 E 0.690 10339.65 12370.40 92.520 278.280 3664.04 3727.44 1405.60 N 10289.58 W 6010792.86 N 541076.12 E 1.676 10385.05 - 12416.99 92.960 277.600 3661.82 3725.22 1412.02 N 10335.67W 6010798.97 N 541029.99 E 1.737 10431.59 12461.06 94.130 278.130 3659.09 3722.49 1418.04 N 10379.24 W 6010804.69 N 540986.38 E 2.914 10475.57 12509.68 94.620 278.540 3655.38 3718.78 1425.07 N 10427.21 W 6010811.39 N 540~38.36 E 1.313 10524.05 12553.29 94.370 278.310 3651.96 3715.36 1431.44 N 10470.21 W 6010817.46 N 540895.31 E 0.778 10567.52 12599.81 94.000 278.160 3648.57 3711.97 1438.09 N 10516.13 W 6010823.79 N 540849.35 E 0.858 10613.92 12648.45 92.710 277.540 3645.72 3709.12 1444.72 N 10564.23 W 6010830.09 N 540801.21 E 2.942 10662.47 12692.15 91.970 277.780 3643.94 3707.34 1450.54 N 10607.51 W 6010835.61 N 540757.89 E 1.780 10706.14 12734.98 91.540 276.820 3642.63 3706.03 1455.98 N 10649.97 W 6010840.76 N 540715.40 E 2.455 10748.94 12785.81 92.650 277.420 3640.77 3704.17 1462.27 N 10700.37 W 6010846.71 N 540664.95 E 2.482 10799.73 12834.22 92.830 276.980 3638.45 3701.85 1468.33 N 10748.34 W 6010852.44 N 540616.94 E 0.981 10848.08 12878.84 92.280 276.950 3636.47 3699.87 1473.74 N 10792.59 W 6010857.54 N 540572.65 E 1.234 10892.65 12922.38 92.710 276.310 3634.57 3697.97 1478.76 N 10835.80 W 6010862.26 N 540529.41 E 1.770 10936.13 12971.54 93.270 276.150 3632.01 3695.41 1484.09 N 10884.60 W 6010867.25 N 540480.57 E 1.185 10985.20 13017.41 93.570 277.210 3629.27 3692.67 1489.41 N 10930.08 W 6010872.27 N 540435.06 E 2.398 11030.98 13063.30 93.260 276.300 3626.54 3689.94 1494.80 N 10975.57 W 6010877.34 N 540389.54 E 2.092 11076.77 13108.80 93.570 277.010 3623.83 3687.23 1500.07 N 11020.68 W 6010882.29 N 540344.39 E 1.700 11122.18 13153.72 93.630 276.850 3621.01 3684.41 1505.47 N 11065.18 W 6010887.40 N 540299.85 E 0.380 11167.00 --,~ 13243.00 93.630 276.850 3615.35 3678.75 1516.10 N 11153.65 W 6010897.41 N 540211.31 E 0.000 11256.09 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.109° (23-0ct-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 278.020° (True). Based lIPon Minimum Curvature type calculations, at a Measured Depth of 13243.00ft., The Bottom Hole Displacement is 11256.22ft., in the Direction of 277.741° (True). -~-- -- --.-- - - _.------ 30 November, 2001 - 17:34 Page 7 of 8 DrillQuest 2.00.08.005 Milne Point Unit Comments ~ Measured Depth (ft) -- 13243.00 Sperry-Sun Drilling Services Survey Report for MPI-12PB1 Your Ref: API 500292303870 Job No. AKZZ11164, Surveyed: 23 October, 2DD1 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 3678.75 1516.10 N 11153.65 W Projected Survey Survey tool program for MPI-12PB1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 " ~ 30 November, 2001- 17:34 0.00 13243.00 3678.75 AK-6 BP _IFR-AK Page 8 of8 . Alaska Drilling & Wells Milne Point MPI DrillQuest 2.00.08.005 Re: MPI-12 ML changes ( I' \ Subject: Re: MPI-12 ML changes Date: Fri, 07 Sep 2001 14:00:26 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Franks, James D" <FranksJD@BP.com> CC: "Shultz, Steve Mil <ShultzSM@BP.com> James and Steve, Thanks for the information. luck. Tom Maunder, PE Sr. Petroleum Engineer AOGCC This is as per your remedy proposal after MPI-13. Good "Franks, James 0" wrote: > Tom, > > This will look vary familiar to you. I am using the same format that Steve > Campbell used. He gets all of the credit. > > I wíll be out of the state from the 9th of Sept to the 28th of Sept. so if > you need anything on this over that time period, send me an e-mail or > contact Steve Shultz. > > Thanks!! > > james > > «MPI-12ML WBD2.ZIP» «MPI-12 ML sundry notice. doc» > > James Franks > BP Alaska Drilling & Wells > office: 907-564..4468 > cell: 907..440-0187 > > ........-.......-.-..-.............-.------............-.......----------..-...--.......--....-.....---...--- > > > > > > > Name: MPI-12ML WBD2.ZIP MP/-12ML WBD2.ZIP Type: Zip Compressed Data (application/x-zip-compressed) Encoding: base64 Name: MP/-12 ML sundry notice.doc MPI..12 ML sundry notice.doc Type: WINWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1of2 dO \ - \ b-S ....----- 9/7/01 2:00 PM ( ( INTEROFFICE MEMORANDUM TO: FROM: TOM MAUNDER JAMES FRANKS SUBJECf: MPI-12 ML SURFACE CASING DA11E: 9/6/01 CC: Due to the higher than anticipated mud weights after drilling the MPI-13, we have decided to add a shallow set surface casing to the MPI -12 well. We could be moving on to this well by October 7, 2001. Your prompt attention in this matter is appreciated. Changes to the original well plan are as follows: Dill 13-1/2" surface hole to 2750t MD, 2,300t TVD with a 9.0 ppg mud weight Run and cement a full string of 10..3/4t, 45.5# L-80 BTC, Cement with 718 sxs lead (attic) and 544 sxs tail (class G) (cement to surface) Nipple down the diverter and Nipple up and test BOP's 250/2500 psi low/high Test 10..3/4" casing to 1500 psi. driU out float equipment and 20' of new formation and perform a FIT to 13 ppgwith a 9.0 ppg mud. Drill 9-7 /8" hole to TD (10,411' MD, 3,714' TVD) as per the original well plan Run and cement the 7" 26# L-80 Hydril 521 production pipe, Cement with 595 SX9 tail cement (class G) estimated top of cement at 8400' MD. Lead cement will not be pumped on this string. The 7t, x 10..3/4t, annulus wiD be &eeze protected down to the 10-3/4" shoe at tht end of the well. Finish well a$ originally permitted ( ( BP EXPLORATION Milne Point Unit 1-12& 1-12 L 1 RDID B'''''' 11I111III & Mas EOl BHl OB:3926' FSl643' FWL See 31 T13N RiDE ENG: Steve Campbell RIG: Nabors 22E MSL 34.7' RKB: 64.7' Field: Milne Point Well: 1-12 ML Actual Surface Location: 2345' FSL 3996' FEL EOL BHL OA:3914' FSL 543' FWL See 31 T13N RiDE DIRECTIONAL LWD OPEN HOLE LOGGING FORMATION DEPTH MD TVD TOC HOLE CASING MUD INFO TOC SIZE SPECS PIT INFO INFORMATION Wellhead FMC Gen 6 20" xii" 5M 20" 91.5#, N/A 30" H-40 Welded Cameron 3", 5K NONE NONE 108' 108' Top of Lead Cement Surf Surf Dir/GR/RES NONE GYRO IF REQ'D Base of Permafrost 1,947' 1840' KOP #4 @ 2017' - 6°/100' MXC-1 10-3/4" 45.5# L-80 BTC 9.0 ppg FIT = 13.0 PPG AA=80 DEG 2,750' 2,300' 13-1/2" EOB @ 2851' 6600' MD @ 80.3° Tangent Top of Tail Cement 8,400' Dir/GR/PWD/Res Top of N sand 9,424' 3487 D:~~:;Š - . - ~~~.. -I~: :~; -.. - .. ;,:2:- .3;:': -.. -.. - . -.. -.. -.. -.... -.. -.. 1:;.3J:¡' ..3~5.:>~ , " .... .... """"- 6-1/8" Hole - 4-1/2", 12.6#, L-80 Slotted Liner Production Casing 7" 26# L-80 HYDRIL 521 MW = 9.5 Land 7" Csg @ 92° 9-7/8" 6-1/8" Hole - 4-1/2", 12.6#, L-80 Slotted Liner 9/6/01 MPI-12Ml WSD2.xls (" ~ ~ifÆiŒ (ID~ fÆ~fÆ~[{fÆ ALASKA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. ]TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Shultz Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Milne Point Unit MPI-12 BP Exploration (Alaska) Inc. Permit No: 201-163 Sur Loc: 2345' NSL, 3996' WEL, SEC. 33, T13N, R10E, UM Btmhole Loc. 3926' NSL, 4718' WEL, SEC. 31, T13N, RI0E, UM Dear Mr. Shultz: Enclosed is the approved application for pennit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Milne Point Unit MPI-12. ' Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test ofBOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. , BY ORDER OF THE C~MISSION DATED this? day of August, 2001 jjc/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. I STATE OF ALASKA f ALASKA UIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~1,f 1/1/61 i--%/ ~ 1 a. Type of work iii Drill 0 Redrill 11 b. Type of well 0 Exploratory 0 Stratigraphic Test iii Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned KBE = 64.7' Milne Point Unit / Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 25517 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2345' NSL, 3996' WEL, SEC. 33, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 3500' NSL, 1746' WEL, SEC. 31, T13N, R10E, UM MPI-12 Number 2S 100302630-277 At total depth 9. Approximate spud date 3926' NSL, 4718' WEL, SEC. 31, T13N, R10E, UM 09/12/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025519,543' MD No Close Approach 2560 13378' MD /3721' TVD 16. To be completed for deviated wells 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 92 Maximum surface 1249 psig, At total depth (TVD) 3731'/1679 psig 18. Casing Program Specifications Setting Depth Quantitv of Cement Size Too Bottom Hole Casina Weiaht Grade CouDlina Lenath MD TVD MD TVD (include staae data) 3011 2011 92# H-40 Welded 78' 30' 30' 108' 108' 1260 sx Arctic Set (Approx.) 9-7/811 711 26# L-80 H521 10381' 30' 30' 10411' 3778' 916 sx PF, 708 sx Class 'G' 6-1/811 4-1/211 12.6# L-80 IBT 3117' 1 0261' 3778' 13378' 3721' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface RECEIVED Intermediate Production Liner JUL 3 1 2001 Alaska Oil & Gas Cons. Commission Perforation depth: measured Anchorage true vertical 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch iii Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Jim Rose, 564-4787 /' Prepared By Name/Number: Sandra Stewman, 564-4750 21. I hereby certify that the fore,) ~ru<}tJ 'ßct to the best of my knowledge 7/ð¡); / ~ Title Senior Drilling Engineer Date Signed Steve Shultz /' ~ cõlmlml~'sš'~!o:ñlli!l'[jišê!:!lliÖlñ'ly"':I"""":I""!II:d'l" 'I,'"'! Permit Number 1 API Number 1 I~Pft~~1 frate I See cover letter 2-oJ"" /6 S 50-0Z-r.... 230 3? Oì ,() J for other reauirements Conditions of Approval: Samples Required DYes MNo Mud Log'Required DYes ~NO Hydrogen Sulfide Measures DYes:m No Directional Survey Required øYes D No Required Working Pressure for BOPE D2K D3K D4K D5K D 10K D 15K ~.5K psi .¡rnr Other: ORIGINAL SIGNED B'Y T 'lor Seamount by order of Date 0)( 10 ~ In J Approved By """' -. 0 ay Commissioner the commission Form 10-401 Rev. 12-01-85 UKlb'll\JAL Sùb'mit In'Triplicate ( { M PI-12 Drilling Permit 1. Well Plan Summar'l IWell Name: I MPI-12 I Type of Well (producer or in~ector): I Schrader Bluff Multilateral producer Surface Location: 23451 FSL,39961 FEL, SEC. 33,T13N, R10E X = 551375.01 Y = 6009458.19 1-12 Target OB: 35001 FSL, (1778' FNL), 1746' FEL (3517' FWL), SEC. 31, T13N, R10E X =543053.79 Y = 601 0561.5Z = 3710.54TVDss 1-12 Target (Bottom Hole 39261 FSL, (13531 FNL), 47181 FEL (5431 FWL), SEC. 31, T13N, R10E Location OB sand): X =540077.76 Y =6010970.22 Z = 3657' TVDss 1-12L 1 Target OA: 3442' FSL, (1837' FNL), 1357' FEL (3907' FWL), SEC. 31, T13N, R10E X=543444.04, Y=6010505.30 1-12L 1 Target (Bottom 3914' FSL (1365' FNL), 4719' FEL (543' FWL), SEC. 31, T13N, R10E Hole Location OA sand): X=540077.76, Y=6010958.23 [ffiãJ Nabors 22E I 64.7 I 138.4 I KOP: 300 KBE: I Estimated Start Date: Sept 12, 2001 I Operating days to complete: 13,378' 13,372' TVDrkb (TD) TVDrkbL 1 (TD) Max. Inc. Max. Inc.L 1 91.979° 92.875° I Well Design (conventional, slim hole, etc.): I Multilateral Producer I Scope: I Drill and Complete a Multilateral Producer in the Schrader Bluff OA and OB sands. Version #1, 6/20/2001 { t MPI-12 Drilling Permit 2. Current Well Information 2.1. General Well Name: MPI-12 API Number: Well Type: Current Status: BHP: BHT: MPI-12 Development - Schrader Bluff Multilateral Producer - lower leg Conductor Set 1679 psi @ 3731' TVDss Base of Schrader Bluff OB Sands. 80°F @ 4020' TVDss Estimated (SOR) 2.2. Current Mechanical Condition MPI-12: Nabors 22E: Conductor: Cellar Box above MSL = 34.7 KB from Ground Level = 30' 20",92 I bItt, H-40 Welded set at 78' MD 2.3. Target Estimates Estimated Reserves: 1.6MMBBL Expected Initial Rate: 3000 BOPD Expected 6 month avg: 1476 BOPD 2 ( ,( MPI-12 Drilling Permit 3. Drilling Hazards and Contingencies Drill D1 D2 D3 D4 D5 3.2. Kick Tolerance 3.2.1.The 7" casing will be cemented to surface. The top of the 15.8 Ib/gal tail cement slurry is planned to be 1000' MD above the NA Sands - 8400' MD 3.2.2.The Kick Tolerance for the production casing based on the 8.65 expected pore pressure is infinite. 3.3. Lost Circulation 3.3.1. Lost circulation has not been encountered while drilling this interval on previous I-Pad wells. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 3.4. Unexpected Pressures 3.4.1.lt is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be 1679 psi (8.65 Ib/gal). In this well, the Schrader Bluff formation will be drilled with 9.2-ppg mud. 3.5. Stuck Pipe 3.5.1.Good drilling practices to avoid differential sticking are required. Minimum mud weights and proper mud properties as outlined in the Baroid mud program must be closely followed. 3.5.2.Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! 3.6. Pad Data Sheet 3.6.1. Please Read the I-Pad Data Sheet thoroughly. 3.7. Hydrocarbons 3.7.1.Hydrocarbons will be encountered in the Ugnu and Schrader Bluff intervals. 3.8. Faults 3.8.1.lt appears likely that the wellbore for both of the laterals will intersect a series of small faults at -12500' MD. The first fault encountered is downthrown to the west, by -40'. 300' westward of this fault is a down to the east fault with similar throw to the first fault. We will probably want to be 3 ( ( MPI-12 Drilling Permit deeper in the OA and OB prior to hitting the first fault and then higher in section for the second fault. 3.9. Hydrogen Sulfide 3.9.1. MPI Pad is not designated as an H2S Pad. Below is a summary of the most recent H2S readings: Welll- Well Type H2S Status Date taken 1 Long Term Shut In Feb 2000 2 SBF Prod <2.00 Apr2000 3 SBF Prod <2.00 Feb 2000 4 SBF Prod <2.00 Feb 2000 5i SBF Inj Injector Apr2000 6 SBF Prod <2.00 Feb 2000 7 SBF Prod <2.00 Feb 2000 8 SBF Prod <2.00 Feb 2000 4 (' (' MPI-12 Drilling Permit 4. Drilling Program Overview 4.1. Surface and Anti-Collision Issues Surface Shut-in Wells: 1-13i will be shut in prior to drilling 1-12 Close Approach Wells: Well Name Current Production Precautions Status Priority N/A N/A N/A N/A 4.2. Well Control Max Ex BOPE Ratin 135/8" 5M ~ ~fZ1t~/'( Planned BOPE Test Pres. Rams & Valves:.~psi/250 psi Annular: 2500 si 1250 si 4.3. Mud Program Spud - LSND Freshwater Mud H API Filtrate LG Solids 9.0- 9.5 < 6 < 6.5 KCI-CaC03 Baradrill N Mud H API Filtrate LG Solids 8.0 - 8.5 4 - 6 < 12 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal 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. 4.4. Formation Markers Formation Tops ft MD ft TVDss Pore (psi) EMW (ppg) Base Permafrost 1775 Top Uç:mu 3186 1434 8.65 Top UQnu M 3432 1544 8.65 Schrader -NA 3487 1569 8.65 Schrader -NB 3515 1582 8.65 Schrader -NC 3546 1596 8.65 Schrader -NE 3565 1604 8.65 Schrader -NF 3611 1625 8.65 Schrader -OA 3647 1641 8.65 TSBC - Base OA 3681 1656 8.65 TSBB-OB 3709 1669 8.65 SBA5 - Base OB 3731 1679 8.65 TD-OA 3591 TD - OB 3657 5 ( ( MPI-12 Drilling Permit 4.5. CasinglTubing Program Hole Size Csgl WtlFt Grade Conn Length Top Bottom Tbg O.D. MD 1 TVDrkb MD 1 TVDrkb 30" 20" 92# H-40 Welded 78' 30' 1 30' 108' /108' 9-7/8" 7" 26# L-80 H521 1 0381 ' 30' 1 30' 10411' / 3778' OA 6-1/8" 4-1/2" Slotted 12.6# L-80 1ST +1- 3552' 9820' 1 3677' 13372' / 3655' OB 6-1/8" 4-1/2" Slotted 12.6# L-80 1ST +1- 3117' 10261' 1 3778' 13378' / 3721 ' TubinQ 3-1 12" 9.3# L-80 EUE-Mod +1- 9670' 30' 1 30' 9700' / 3632' 4.6. Cement Calculations 4.7. Survey and Logging Program 9-7/8" Hole Section: Open Hole: MWD/DIR/GR/Res IPWD 6-1/8" Hole Section: Open Hole: MWD 1 DIR(IFR) 1 ABGR 1 Res 1 PWD 1 ABI Res placed as close to bit as possible. Cased Hole: None 6 ( ~( MPI-12 Drilling Permit 5. MPI-12 Operations Summar'l 5.1. Pre-Rig Operations 1. Grade and level pad. 2. Install 20" Conductor. 5.2. Procedure r0,'Þ ~'y 1. MIRU, NU riser on 20" conductor, PU 5" drill pipe 2. Drill 9-7/8" surface hole as per directional plan. Maximum tangent angle 90° 3. Condition mud with lubes and spot casing running lube pill prior to r casing run. POOH laying down DP 4. Run and cement 7" casing from TD to surface. TAM Port Collar @ 1000' as contingency should cement not reach the surface. 5. ND riser. 6. Install FMC 11" 5m horizontal wellhead 7. N/U and test 13 %" 5m BOP 8. Test casing to 3,500 psig. 9. Drill out float eqpt and 30' of formation. 10. Perform FIT to 11.5 ppg equiv. 11. Drill 6-1/8" OB horizontal production hole as per directional plan. 12. Run 4-1/2" slotted liner and hang off 150' inside 7" casing. ''^-J ,\,,"'-S!:~~~"'~ ,13. Make up Baker Window Master milling assembly with bottom trip anchor and MWD. 14. RIH. Orient and set whipstock to place window at top of the OA interval. 15. Shear off and mill window thru 7" casing. 16. RIH. Displace hole to clean Bara Drill mud. 17. Drill 30' of new formation 18. Perform FIT to 11.5 ppg equiv. 19. Drill 6-1/8" OA lateral geosteering and short tripping as required. 20. Displace OA lateral with clean Bara Drill mud 21. MU whipstock retrieving tool and pull whipstock 22. Run 4 V2" slotted liner with 2 %" inner string, Baker Hook Hanger and hang off in 7" casing 23. POOH laying down 3 V2" drill pipe 24. Run in hole with 3-1/2" tubing to top of OA liner 25. Displace r casing to 9.1 Ib/gal completion fluid 26. Land tubing hanger 27. Set tubing plug and BPV 28. ND BOP 29. Install and test tree 30. Pull tubing plug and BPV 31. Freeze protect the tubing and annulus 32. Install BPV and secure the well 3. RD/MO ~ ~~ 7 ( ( MPI-12 Drilling Permit 6. MPI-X1 Nabors 4ES Operations Summar'l 1. 2. 3. 4. 5. 6. 7. 8. MI/RU Nabors 4ES. Circulate out freeze protection with 9.1 ppg brine. Remove tree and install BOP. Pull and stand back the 3 1/2" tubing. Make up the ESP completion and run in on the 3 1/2" tubing. Freeze protect the well. Set tubing plug and BPV. Remove the BOP. Install and test the tree. RD/MO. Hook up flowlines and instrumentation. 8 TREE: FMC Horizontal 3-1/8" 5M ( . WELLHEAD: FMC Horizontal 11", 5M tbg. head 11" x 3-1/2", EUE (btm) FMC tbg. hanger, 'H' BPV profile PROPOSED COMPLETION ~VlP 1-12 & 1-12L 1 KB. ELEV = 64.00' Cellar Box ELEV = 34.00' "" \'1: - \:d- (X)\ ,~ 1'=:0 9 f)JJ 1081 20" 92 Ib/tt, H-40 Welded 7",26#, L-80, H-521 Casing Drift: 6.151" Casing 10: 6.276" Baker Hughes Hook Hanger system I Window in 7" casing @ +1- 9820' I 7" Casing Shoe @ 104 Well Inclination @ Sh DATE REV. BY COMMENTS 7/24/2001 Jim Rose level 3 Multi-lateral, 3 1/2" ESP Completion I I \ \. , , OA Horizontal ~........ \ --.....---------------. (' 3 1/2", 9.2 Ib/ft, L-80, EUE 8rd Centrilift Electric Submersible Pump I EOT @ +/- 9700 I I I , ~ ........ ........ ---------------_1 I Multi-lateral Junction @+/-9820' I 6-1/8" OA Lateral TD 4 ~/2" Slotted Liner and Hook Hanger 113372' I .....~--........_..._-~........ , , .....--------------- \ \ , , , OB Horizontal ........ ---------------- 6-1/8" OB Lateral TD 4-1/2" Slotted Liner & Hanger BP Exploration (Alaska) 5per'f""IY-SUI1 I Milne Point Unit CRIL..L.ING seRVices Alaska Drilling & Wells A HaUlburton Company Milne Point MPI I DrillQuestN MPI-12 Wp05 Single Well Target Data for MPI-12 Wp05 ",,".S!Kemen! Units: 11 Coord...te T .rget Point TVD TVDaa Northlnga Eastlnga Northing. Eut..g. Target Name Type ASP4Y ASP4X Shop. MPI-12 Drr Poly F.nuy Po8tl m8,OO 3714.00 6010566,68 N 543016.83 E lIM,05N 8350,411 W Boundar}' Poi'll A m8,OO 3714,00 rolœo2.00N 543616,00 E 1197,24 N 775LOHW I'ul)'gun B m8.00 3714.00 rol06li5,OO N 542637,00 E 12M,98 N 8729.1>2 W C m8.00 3714,00 6010062,00 N 54115(lOO E 1474.22 N 10215.2.1 W D 3778.00 3714.00 6011009,00 N 540261.00 E 1627.34 N 11103,19 W E 3778,00 3714,00 6010737,00 N 540222.00 E 1355.62 N 11144.U7 W F 3778,00 3714,00 601(X;I7,OO N 541113,00 E 1229,48 N 10253,91 W G 3778,00 3714,00 6010107,00 N 542598.00 E (XJ9.26 N 8770.40 W H m8.00 3714,00 6010349,00 N 543582.00 E 944.48 N 7786,112 W MPI- I 2 GooPoly Entry Point 3778.00 3714,00 6010566.68 N 543016,83 E IIM,05N 83<;(].48 W Boundary Poi:lt A 3778.00 3714.00 6011153,00 N 54001\5.00 E 1T7H>9 N 11298,20 W Pul]'gun B 3778.00 3714,00 6010820.00 N 54213O,OOE 1425,47 N 9235,54 W C 3778,00 3714.00 6010684,00 N 543805,00 E 1277.94 N 7<;f,1.52W D 3778,00 3714.00 6010201.00 N 543536.00 E 7%,80 N 7833.84 W E 3778.00 3714,00 6010630,00 N 540065,00 E 1249,70 N 113OUIOW MPI-12 T1 EnlJ)'Point 3549,00 3485,00 6010430.87 N 543%9,85 E 1023,68 N 7398,41 W I'unt MPI-12 1'2 Nev.' Entry Point 3778,00 3714.00 6010566,68 N 543016.83 E IIM.05N 83<;(],4H W Pllnt I I ~ MPI-12 1'3 EnlJ)'Point 3752.00 3688,00 601(x;70,59 N 542271.67 E 1275.œ N 1JW4,90 W Punl MPI-12T4 Entry Point 3729,00 3665,00 6010868,35 N 540847.78 E 14H2,M N 10517,40W Punt MPI-12 T5 EnlJ)'Point Jn1.00 31\57,00 6011910,22 N 540077.76 E 1589,83 N 11286.70W I'uilt Proposal Data for MPI-12 WpOS Vertical Origin: Wen Horizontal Origin: Wen Measlrement Units: ft North Reference: True North Dogleg severity: Degrees per 100 feel (US) Vertical Section Azimuth : 278.018° Vertical Section Description: Wen Vertical Section Origin: 0.00 N.O,oo E Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 0.00 0.1)00 0.395 0.00 O.OON O,OOE 0,00 300.00 0,000 0.395 300.00 O,OON O.OOE 0,00 0.000 800,00 5,000 350,000 799.37 21.47N 3,79W 6,74 1.000 1147.46 10,000 310,000 1143,95 55,82 N 2956 W 37.05 2.000 188756 30.000 277,200 ]83755 ]2U3N 265,3] W 279.61 3,000 2017,41 30.000 277.200 1950,00 129,27 N 329,72 W 344,52 0,000 285] ,27 80,032 277.212 2413,05 212,29 N 986,18 W 1006,15 6,000 9413.70 80.D32 277.212 3549,00 1023.68 N 7398.41 W 7468.88 0,000 9662.21 67,713 278,903 3617.90 1056,97 N 7634.34 W 7707.14 5.000 9804.37 67,713 278,903 3671,82 1077.32 N 7764,29 W 7838,66 0.000 10411.19 91.979 278.333 3778.00 1166,05 N 8350.48 W 8431.49 4,000 11164,01 91.979 278.333 3752.00 1275,09 N 9094,90 W 9183,85 0,000 11199,83 90.905 278.303 3751.10 1280,27 N 9130,33 W 9219,66 3,000 12585.49 90.905 278.303 3729,21 1480,36 N 10501.30 W 10605,13 0.000 12601.75 90,590 277.931 3729,00 1482,66 N 10517,40 W 10621.39 3,000 13378,52 90.590 277.931 3721.00 1589.83 N 11286.70 W 11398,12 0.000 1400 .J:: ã. Q) 0 (ij () :;::; Q¡ > 2800 .::: 0 0 '<t II .c 0 c: :;:: 4200 CD (ij 0 en Drill Quest 2.00.09.001 U.. u ill' .,.j .~~ RIID ..WUII.IWlIi I WIllS True North Feet(US) MPI-12 Wp05 Formations Measured Vertical Sub-Sea Depth Depth Depth Formation Name (ft) (ft) (ft) 1889.23 1839J)() 1775J)() Base Permafrost 7686,36 325(J.()() 3186,(XJ Top Ugnu 9107,51 3496J)(J 3432,(J(J Tog Ugnu M 9424,94 3551.1)() 3487,((J Schrader NA 9544,93 3579J)() 3515.1)0 Schrader NB 964{),89 36IOJ)() 3546JX) Schrader NC 9691.47 3629J)() 3565.()() Schrader NE 9812,82 3675,()() 3611.((J Schrader NF 9918,99 3711.1)() 3647J)() Schrader OA 10049,61 3745J)(J 3681.!X) TSBC (hasc OA) 10232,(3 3773.()( 3709JX) TSBB-OB Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordha1es : Ref. Stru:ture Reference: Ref. Geographical Coordinates: RKB Elevafun : MPI-12 Wp05 6009458.18 N. 551375.14 E 328,78 S, 802.79 W 70' 26'11,7316' N,149' 34' 52,0644' W 64,0011 above Mean Sea Level 64,0011 above Structure Reference North Reference: Unfts: 0 41r.z-L~'r 13378.5211 ...0 3721.00ftTVO Begin Oir @ 1,000'/10011 : 300,0011 MO, 300,0011 TVO Oir Rate lrerease @ 2.000'/10011 : 8OO.OOI1MO,799.37ftTVD ell sign Oir Rate lrerease @ 3,000'/10011 : 1147,46ftMO.II43,95I1TVO p ve r r;f>~Q ~Q ~Q ",,{I'b' #'''- ,,<§:-' ~Q' 4>'1-' 4'''' ,,-:-<>'; ~Q' #Q' ,,,~" rJ-<;>"~ "o"o,,'þ (\~' ,," ,," o,,"'!> ,," 6" ....fiJ \,,# ~~'?-J ~~ . fiJ~ 9'1>1:- ",,<f é'" Ç¡./;' Ç¡./; fiJ 9'1>1:- x,,,b <öif "b.;f' ~ ~Q Q r;f>~ f:)~~Q ,9' ~'?-J ~ ",,"1' 4>" ,,'þ ~Q' ~<:)' ""(;. '\~~ ~~ ~Q' ~""". 0,,$'1i'~ rfr' ,,~" o,,'ò~ -15\" ~'!- ",fr' ~~ ,¡"fiJ,#\ Ç¡./;fiJ ...'I>I:-~'lifiJ"" i$~ .~? Q~ <ö'" b<:) 'S' ~ ,<-'" <Ö~'C"lng ~ .. .. . . .11. 10411,19ftMO . 000,00 377&,OOftTVO OO~OO .. \ u . , - --'-- .....evtd'Jl:J''i\ ~!PJ.!]Tl / :U.J9.t;fj lYD [bZ3.6.>{ :V> 7:;9'-;../¡ W End Oir. Start San @ 30.000' : 1887,5611MO.1837.55ftTVO Begin Oir @ 6,000"/10011 : 2017.4111 MO, 1950,0011 TVD ~Q AQ '1-"~ r;f>~' ~' 4-0,,' ~Q' ~Q' ...~ ,,'!-~~ ,<:;\Q .,,'1-</J>~' ..,,,'& (\'1-,,#' ,,# . c§>,?<f> ~Q~ ",,#\ ~ fiJ (\'ò'?~ Ç¡./;fiJ 9i:'¡ ..""""" ,ft" Ç¡./;' <jðq'$' ~ ,<-"b ",ð-'ii> ~. End Dir, Start Sail @ 80.032' : 2851.27ftMO,2413.05ftTVD \ \fI'í.!.~ 75 .-;¡.~{.r-I} n'I' í5''J..'(I.\-. tí.:~',,;( ~\ ;i1P¡~I] T2 :'f:el~' 37;.,'?{!t) T!'jj ¡ J6t.'<)5 A~ SJSiJA8 W MPI-{ 2 Drfr Pnfy 0 Scale: 1 inch = 1400ft 1400 2800 4200 5600 Vertical Section 7000 8400 9800 11200 Section Azimuth: 278.018° (True North) 5pe!1""'''''Y-SUI1 IJRIL.L.ING seRVices A Halliburton Company Milne Point Unit Alaska Drilling & Wells Milne Point MPI MPI-12 Wp05 DrillQuestN Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure Reference: Ref. Geographical Coordinates: RKB Elevation: Current Well Properties MPI-12 Wp05 6009458.18 N, 551375.14 E 328.78 S, 802.79 W 700 26' 11.7316" N, 1490 34' 52.0644" W 64.00ft above Mean Sea level 64.00ft above Structure Reference Single Well Target Data for MPI-12 Wp05 Measurement Units: ft Coordinate Target PoInt TVD TVD.. Northing. Ea8Unga Northing. E..llng. Tlrg.t Name Type ASP4Y ASP4X Shipe MPI-12 Dd'Poly Entry Point 3778,00 3714,00 6010566,68 N 543016.83 E 1166.0S N 83ftO.4H W Boundary Poin< A 3778.00 3714.00 6010602.00 N 543616.00 E 1197.24 N 77SI.OK W Poln;"n B 3778,00 3714.00 601O66S,OO N 5426.H.OO E 12M.I)KN 8729.62 W C m8.00 3714,00 6OIOU2.00 N 5411~,OO E 1474,22 N U215.2~ W D 3778,00 3714,00 6011009.00 N 540261.00 E 1627.34 N 111O~.I'JW E 3778,00 3714,00 6010737.00 N 540222.00 E 1.'55.62 N 11144.07 W F 3778.00 3714.00 6010617.00 N 541113,OOE 1229.4& N 1025J.91 W G 3778,00 3714,00 601 ()4()7.00 N S42598.00 E 1009,26 N 8770.40 W H 3778,00 3714,00 6010349,00 N 543582.00 E 1J4-4.48N 77&6.82 w MPI-12 GooPoly Eotry Poin< 3778,00 3714,00 6010566,68 N 543016.831, 1166,OS N K3SO.4K W Boundary Poin< A 3778.00 3714,00 601IIHOO N 54006S.00 E 1772.&) N I I 21J8. 20 W Pol)'~l.In B 3778.00 3714.00 6010820.00 N 542130.00 E 1425.47 N 92H.~ W c 3778.00 3714,00 6010684.00 N 543805.00 E 1277.94 N 75(,1.52 W D 3778.00 3714.00 6010201.00 N 543S36.00 E 796.&0 N 7K.'.UW W E 3778,00 3714,00 6010630,00 N 540065.00 E I 24IJ.70 N IDOI.KUW MPI-]2 TI Enlry Point 3549,00 348S,OO 6010430,87 N 543969.8S" 102:\.68 N 7:\1)8.41 W )Jilin! MPI-12 T2 New EoIry Poin< 3778.00 3714,00 6010566.68 N 54~016.8J E J 166.0~ N g.l~).4KW P,lÍnt MPI-I2 T3 Eotry Poin< 375200 3688,00 6010670,S9 N 542271.67 E 127H'9N t)OtJ4.90W Puinl MP]-I2T4 Entry Poin< 3129.00 3665.00 60] 0868, 3S N S40847.78 E 1482.66 N )I)~n.40W Poinl MPI-]2TS EoIry Poin< 3721.00 36S7.oo 6010970.22 N 540077.76 E 15&9.83 N 11286.70 W )Juinl /~ Proposal Data for MPI-12 Wp05 Vertical Origin: WeB HoriZortal Origin: Well MeaslJ'emert Urits: II North Refererce: True North Dogleg sever~y : Degrees per 100 feet (US) Vertical Seclion Azirnuh : 278,018' Vertical Section Descrption: Well Vertical Section Origin: 0,00 N,O.OO E Measured IncL Azlm. Verticel Northlngs Eastlngs Vertical Dogleg Deplh Deplh Sec1lon Rate 0,00 0.000 0.395 0,00 O.OON O,OOE 0.00 300,00 0,000 0.395 300,00 O,OON O,OOE 0,00 0,000 800,00 5,000 350,000 799.37 21.47 N 3,79W 6,74 1.000 1]47.46 10,000 310,000 1143,95 55.82 N 29,56 W 37,05 2,000 1887,56 30,000 277.200 ]83755 121.13 N 265.31 W 279,61 3,000 2017.41 30,000 277,200 1950.00 12927 N 329,72 W 34452 0,000 2851.27 80,032 277212 2413,05 21229N 986,18 W 1006,15 6,000 9413,70 80.032 277.212 3549.00 1023.68 N 7398.41 W 7468.88 0,000 9662,21 67,713 278,903 3617,90 1056,97 N 7634,34 W 7707,]4 5,000 9804,37 67.713 278,903 3671.82 1077.32 N 7764.29 W 7838,66 0,000 10411.19 91.979 278.333 3178.00 1166,05 N 8350.48 W 8431.49 4,000 11164,01 91.979 278.333 3752,00 1275.09 N 9094,90 W 9183,85 0,000 11199,83 90,905 278.303 3751.10 128027 N 9130.33 W 9219,66 3,000 12585,49 90,905 278.303 3729.21 1480.36 N 10501.30 W 10605.13 0,000 ]2601.75 90,590 277,931 3729.00 1482,66 N 10517.40 W 10621.39 3,000 1337852 90,590 277.931 3721.00 1589,83 N 11286,70 W 11398,12 0,000 pproved ell esign North Reference: Units: True North Feet (US) 2800 1400 Tolal Dep1h: 13378,52ftMD,3721.OOIITVD End Dir, 51art Sa~ @ 90,590' : 12601,75I1MD,3729.OOIITVD Begin Dir @ 3,000'/100II: 12585.4911 MD, 3729,2111 TVD End Dir, 51artSail @ 90,905': 11199,B3ftMD,3751,1OOTVD ~in Dir @ 3,000"/100II: 11164.0111 MD. 3752,00II TVD r Casilg End Dir. 51art Sail @ 91,979': 10411.1911MD,3778.OOIITVD 10411,19ftMD / Begin Dir @ 4,000'/100II: 9604,3711 MD. 3671,8211 TVD 3n800f1TVD I End D~, 51art Sail @ 67.713': 9662.21I1MD¿3617,9OftTVD , , Begin Dir @ 5,000"/100II: 9413,700 Mu. 3549.00II TVD ~ (J) C) c: £ 0 z ,00 End Dir, 51art SM @ 30,000': 1887,56ttMD,I837,55I1TVD Begin Dir @ 6,ooO'/1001t : 2017.4111 MD. 1950,0011 TVD End Dir, 51art Saa @ 80,032': 2851.27I1MD,2413,05ftTVD ,00 800,00 ,00 iS8V.:"!} S, n~8(t:-.7(1'~' .1.-£P[.:211 3;j~.¡;{I-:n"lJ 1] l5JJ9 ,v. ÿ(N-f. ÿt) H. j If>tiJJ5 :~'. 83Sl)A~'t W w 0 ~ 0 0 '<t II .c 0 .!: Dir Rate Ircrease @ 3,000'/10011 : 1147.46I1MD,1143.95ftTVD Dir Rate Ircrease @ 2,000'/100II : 8oo.00IIMD.799,37ftTVD åi <iš 0 en Begin Dir @ 1.000'/10011 : 300,000 MD. 300,0011 TVD -11200 Scale: 1 inch = 1400ft -9800 -8400 -7000 -5600 Eastings -4200 -2800 -1 400 0 Reference is True North DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Data.. MPI-12 Wps.. MPI..12 Wp05 ''''-''r ,'" "M'Õ"' , "T"":');~tf~' ":"'-"ï~~lin.'" ""k.~~th""rn-'TVD' """""--D~lt~""""'-"N~rthi~~-".-:-: :E~stï~g;' ""I" 'ö~i~g--J ''ï: 'ë~ïid'---""i T~'~ :"'-:::"T~If~c~ "':"VS-'(C278'~)Î ! (ft) l MD' (ft), (°) ,(°) I '(ft).. TVD(ft) . (ft), . (ft) ¡ (0/10Oft) I (D/1ooft) (0/100ft) , (") :' (ft) . I . ' " '.., ! . . , " ,', ' . .. ... " , , .." , I 1 O.OOO¡ : 0.000' 0.000: 0.00; 0.00: 0.00: ¡ 0.0001 0.000, 0.001 '2 300.000: 300.0001 0.000' 0.000' 300.00f 300.00, O.OO! 0.00' 0.0001 1.0001 0.000 0.000 0.001 .... :...!....... ; ...:. . ¡ . .: : ¡ .. .. .... .1 ,3; 800.000!. 500.0001 5.000: 350.000; 799.37¡ ,499.37: 21.47 N 3.79 w' ,1.000i 0.7721 -21.1?O, , 350.000 ,6.741 4 ; 1147.4581 3~7.458! 10.000, 310.000: 1143.95¡ 344.58; 55.82 N¡ . 29.56 W. ,2:000/ 2.0921 -12.383:", 292.697 37:051 . 5 ' 1887.5621 740:1,041 30.000; 277.200;, 1837.5S: 693:61. 121.13 Nj 265.31, W: 3.0ooj 0.0001 ,0.000: 314.2131, ,279.61! 6 2017.4061 129,844: 30.000; 277.200: 1950.00¡ 112.45 129.27 Ni 329.72 W: 0.000) 6.0001 0.003, 0.000 344.52' 7 2851:272" 83i86so 80.032' 277.212 2413.05" ""463.0"5'''''''''2Ü~.29 N' .""" '986.18 W~"" '''6.ÖOO'. , Õ:ÖÖÖ' , 'o.oöO""_.'-""-'.Ö.01-S. 10"06.1'5! 8T '. ~413~~~a... ß5~,2,:~g? ,ß~:0.3,~_....,2?,7.212., 3549.00"..11~5.9,~ 1023.68 N, 73,98.41 W, . ,,0:9.00, ,-4.9~~ ",-_"....9.644 . 9:~0- 7468~88.1 9 9662.207 248.509 67.713 278.903 3617.90 68.90 1056.97 N 7634.34 W 5.000 0.000 0.000 172.708 7707.141 10' 9804.366 142.159 67.713 278.903.3671.82 53.91 1077.32N 7764~29W 0.000 3.999 -0.105 0.000 7838.66 "11T--10411.189,,,_,ß06.82.3, 91.979: 27,8.333, 3778.00 ,106:,1_~, 1166.05N, 8350.48W, 4.000, O.O~." ,n. 0.000, ,~5.~:~~,~ 8431.49! ¡ 12T : 11164.009! 752.819: 91.979 278.333: 3752.00~ -26.00 1275.09 N; 9094.90 W: 0.000\ -2.9991 -0.083. 0.0001 9183.85\ . --------.-----=----.-.-------. ---.- ----- .--~ -.--.-.....-- . ... ..... -. .------------- -. .... . .. .... .:. . .. . ...........~.. . ~ ._-_...._.....~------_._-------_._--------~-----~-~ 13 11199.829 35.82090.905278.3033751.10 -0.90 1280.27N 9130.33W 3.000 0.000 0.000 181.584 9219.66: 14. 12585.491 1385.663 90.905 278.303 3729.21 -21.89 1480.36 N 10501.30 W 0.000 -1.937 -2.292 0.000 10605.13: ~_!~!n..,._!.?'~Q~.:??~n_'._!~:~~~--, ~0.590,:".. 2..?7:~31: 3729.00 ~_n___~~.2!. 1482.66 N 10517.40 W ..~:g~~,,_--E.:..~9.9_-_0.0~~9.797, 10621.39j L1~T': ,1,3378.5231 776-7.70 ,90~59()",27?931: 3721.00' -8.00 1589.83N 11286.70W: ,,0:90.°1, 0.000 ,,~.OOO, ,o.000L..1,~,39,8..12: ./~~ .-... 10 July, 2001 - 13:00 - 1 - DrillQuest Milne Point Unit Alaska Drilling & Milne Po. "\ MPI-12 W~ ~~ SAL REPORT 10 July, 2001 Surface Coordinates: 6009458.18 N, 551375.14 E (70026' 11.7316" N, 149034' 52.0644" W) Ke/Iy Bushing: 64.00ft above Mean Sea Level ~. 5pe""""'Y-5UI! DFtIL.L.ING seRVIc:es A Halliburton Company Proposal Ref: pro9874 Sperry-Sun Drilling Services Proposal Report for MPI-12 Wps - MPI-12 Wp05 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1000) 0.00 0.000 0.000 -64.00 0.00 O.OON 0.00 E 0.00 100.00 0.000 0.000 36.00 100.00 0.00 N 0.00 E 0.000 0.00 200.00 0.000 0.000 136.00 200.00 O.OON 0.00 E 0.000 0.00 300.00 0.000 0.000 236.00 300.00 0.00 N 0.00 E 0.000 0.00 Begin Dir @ 1.0000/100ft : 300.000 MD, 300.00ft TVD ~~- 400.00 1.000 350.000 335.99 399.99 0.86 N 551374.98 E 1.000 0.27 500.00 2.000 350.000 435.96 499.96 3.44N 551374.51 E 1.000 1.08 600.00 3.000 350.000 535.86 599.86 7.73 N 551373.72 E 1.000 2.43 700.00 4.000 350.000 635.68 699.68 13.74 N 551372.62 E 1.000 4.32 800.00 5.000 350.000 735.37 799.37 21.47 N 551371.21 E 1.000 6.74 Dir Rate Increase @ 2.0000/100ft : 800.0OOMD, 799.37ftTVD 900.00 6.059 332.239 834.91 898.91 30.43 N 7.00W 6009488.57 N 551367.93 E 2.000 11.18 1000.00 7.510 320.502 934.21 998.21 40.15 N 13.62 W 6009498.23 N 551361.25 E 2.000 19.08 1100.00 9.169 312.759 1033.15 1097.1 50.60 N 23.62 W 6009508.62 N 551351.17 E 2.000 30.45 1147.46 10.000 310.000 1079.95 1143.95 - 55.82 N 29.56 W 6009513.79 N 551345.20 E 2.000 37.05 Dir Rate Increase @ 3.0000/100ft : 1147.46ftMD,1143.95ftTVD 1200.00 11 .156 304.151 11 31 .60 1195.60 61.60 N 37.26 W 6009519.52 N 551337.46 E 3.000 45.49 1300.00 13.589 295.913 1229.27 1293.27 72.17 N 55.83 W 6009529.96 N 551318.81 E 3.000 65.36 1400.00 16.210 290.213 1325.91 1389.91 82.13 N 79.50 W 6009539.76 N 551295.07 E 3.000 90.18 1500.00 18.941 286.091 1421.23 1485.23 91 .45 N 108.20 W 6009548.88 N 551266.31 E 3.000 119.90 1600.00 21.741 282.985 1514.99 1578.99 100.11 N 141.85 W 6009557.31 N 551232.60 E 3.000 154.43 1700.00 24.587 280.563 1606.92 1670.92 108.09 N 180.36 W 6009565.03 N 551194.04 E 3.000 193.67 1800.00 27.463 278.618 1696.78 1760.78 115.36 N 223.62 W 6009572.00 N 551150.73 E 3.000 237.52 ~ 1887.56 30.000 277.200 1773.55 1837.55 121.13 N 265.31 W 6009577.48 N 551109.01 E 3.000 279.61 End Dir, Start Sail @ 30.000° : 1887.56ftMD, 1837.55ftTVD 1889.23 30.000 277.200 1775.00 1839.00 121.24 N 266.14 W 6009577.58 N 5511 08.18 E 0.000 280.44 Base Permafrost 1900.00 30.000 277.200 1784.32 1848.32 121.91 N 271 .48 W 6009578.22 N 551102.83 E 0.000 285.83 2000.00 30.000 277.200 1870.93 1934.93 128.18 N 321 .08 W 6009584.14 N 551053.18 E 0.000 335.82 2017.41 30.000 277.200 1886.00 1950.00 129.27 N 329.72 W 6009585.17 N 551044.54 E 0.000 344.52 Begin Dir @ 6.0000/100ft : 2017.41ft MD, 1950.00ft TVD 10 July, 2001 - 13:03 Page 2 of 12 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MPI-12 Wps - MP/-12 Wp05 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 0 Oft) 2100.00 34.956 277.202 1955.65 2019.65 134.83 N 373.70 W 6009590.43 N 551000.52 E 6.000 388.86 2200.00 40.956 277.204 2034.47 2098.47 142.53 N 434.70 W 6009597.72 N 550939.47 E 6.000 450.33 2300.00 46.956 277.206 2106.42 2170.42 151.24 N 503.53 W 6009605.94 N ~~0870.58 E 6.000 519.70 2400.00 52.956 277.207 2170.73 2234.73 160.84 N 579.44 W 6009615.02 N 550794.60 E 6.000 596.21 2500.00 58.956 277.209 2226.69 2290.69 171.23 N 661 .61 W 4;;16009624.85 N 550712.37 E 6.000 679.02 ,~~ 2600.00 64.956 277.210 2273.68 2337.68 09635.31 N 550624.77 E 6.000 767.23 2700.00 70.956 277.210 2311.20 2375.20 09646.31 N 550532.78 E 6.000 859.87 2800.00 76.956 277.211 2338.82 2402.82 6009657.71 N 550437.40 E 6.000 955.92 2851.27 80.032 277.212 2349.05 2413.05 6009663.67 N 550387.52 E 6.000 1006.15 End Dir, Start Sail @ 80.032° : 2851.27ftMD,2413.05ftTVD 2900.00 80.032 277.212 2357.48 2421.48 6009669.37 N 550339.86 E 0.000 1054.14 3000.00 80.032 277.212 2374.79 1131.51 W 6009681.06 N 550242.07 E 0.000 1152.62 3100.00 80.032 277.212 2392.10 1229.22 W 6009692.75 N 550144.28 E 0.000 1251 .10 3200.00 80.032 277.212 2409.41 1326.93 W 6009704.44 N 550046.48 E 0.000 1349.58 3300.00 80.032 277.212 2426.72 1424.64 W 6009716.13 N 549948.69 E 0.000 1448.06 3400.00 80.032 277.212 2444.03 1522.35 W 6009727.82 N 549850.89 E 0.000 1546.55 3500.00 80.032 277.212 2461.34 2525.34 292.50 N 1620.06 W 6009739.51 N 549753.10 E 0.000 1645.03 3600.00 80.032 277.212 2478.65 2542.65 304.86 N 1717.78 W 6009751.20 N 549655.31 E 0.000 1743.51 3700.00 80.032 277.212 2495.96 2559.96 317.23 N 1815.49 W 6009762.89 N 549557.51 E 0.000 1841.99 3800.00 80.032 277.212 2513.27 2577.27 329.59 N 1913.20 W 600977 4.58 N 549459.72 E 0.000 1940.47 3900.00 80.032 277.212 2530.58 2594.58 341.96 N 2010.91 W 6009786.28 N 549361.92 E 0.000 2038.95 4000.00 80.032 277.212 2547.89 2611 .89 354.32 N 2108.62 W 6009797.97 N 549264.13 E 0.000 2137.43 .-..> 4100.00 80.032 277 .212 2565.20 2629.20 366.68 N 2206.33 W 6009809.66 N 549166.33 E 0.000 2235.91 4200.00 80.032 277.212 2582.51 2646.51 379.05 N 2304.04 W 6009821.35 N 549068.54 E 0.000 2334.39 4300.00 80.032 277.212 2599.82 2663.82 391.41 N 2401 .75 W 6009833.04 N 548970.75 E 0.000 2432.87 4400.00 80.032 277.212 2617.13 2681.13 403.78 N 2499.47 W 6009844.73 N 548872.95 E 0.000 2531.35 4500.00 80.032 277.212 2634.44 2698.44 416.14 N 2597.18 W 6009856.42 N 548775.16 E 0.000 2629.83 4600.00 80.032 277.212 2651.75 2715.75 428.51 N 2694.89 W 6009868.11 N 548677.36 E 0.000 2728.31 4700.00 80.032 277.212 2669.06 2733.06 440.87 N 2792.60 W 6009879.80 N 548579.57 E 0.000 2826.79 4800.00 80.032 277.212 2686.37 2750.37 453.23 N 2890.31 W 6009891.49 N 548481.78 E 0.000 2925.27 4900.00 80.032 277.212 2703.68 2767.68 465.60 N 2988.02 W 6009903.18 N 548383.98 E 0.000 3023.76 10 July, 2001 -13:03 Page 3 of 12 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MP/-12 Wps - MPI-12 Wp05 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5000.00 80.032 277.212 2720.99 2784.99 477.96 N 3085.73 W 548286.19 E 0.000 3122.24 5100.00 80.032 277.212 2738.30 2802.30 490.33 N 3183.44 W 548188.39 E 0.000 3220.72 5200.00 80.032 277.212 2755.61 2819.61 502.69 N 3281.16 W 8090.60 E 0.000 3319.20 5300.00 80.032 277.212 2772.92 2836.92 515.05 N 3378.87 W 7992.80 E 0.000 3417.68 5400.00 80.032 277.212 2790.23 2854.23 527.42 N 3476.58 W 547895.01 E 0.000 3516.16 ----~ 5500.00 80.032 277.212 2807.54 2871 .54 .33N 547797.22 E 0.000 3614.64 5600.00 80.032 277.212 2824.85 2888.85 09985.02 N 547699.42 E 0.000 3713.12 5700.00 80.032 277.212 2842.16 2906.16 6009996.71 N 547601.63 E 0.000 3811.60 5800.00 80.032 277.212 2859.47 2923.47 6010008.40 N 547503.83 E 0.000 3910.08 5900.00 80.032 277.212 2876.78 2940.78 6010020.09 N 547406.04 E 0.000 4008.56 6000.00 80.032 277.212 2894.09 4062.85 W 6010031.78 N 547308.25 E 0.000 4107.04 6100.00 80.032 277.212 2911.40 4160.56 W 6010043.47 N 547210.45 E 0.000 4205.52 6200.00 80.032 277.212 2928.71 4258.27 W 6010055.16 N 547112.66 E 0.000 4304.00 6300.00 80.032 277.212 2946.02 4355.98 W 6010066.85 N 547014.86 E 0.000 4402.49 6400.00 80.032 277.212 2963.33 4453.69 W 6010078.55 N 546917.07 E 0.000 4500.97 6500.00 80.032 277.212 2980.64 3044.64 663.42 N 4551.40 W 6010090.24 N 546819.28 E 0.000 4599.45 6600.00 80.032 277.212 2997.95 3061 .95 675.79 N 4649.11 W 6010101.93 N 546721 .48 E 0.000 4697.93 6700.00 80.032 277.212 3015.26 3079.26 688.15 N 4746.83 W 6010113.62 N 546623.69 E 0.000 4796.41 6800.00 80.032 277.212 3032.57 3096.57 700.52 N 4844.54 W 6010125.31 N 546525.89 E 0.000 4894.89 6900.00 80.032 277.212 3049.88 3113.88 712.88 N 4942.25 W 6010137.00 N 546428.10 E 0.000 4993.37 7000.00 80.032 277.212 3067.19 3131.19 725.25 N 5039.96 W 6010148.69 N 546330.30 E 0.000 5091 .85 7100.00 80.032 277.212 3084.50 3148.50 737.61 N 5137.67 W 6010160.38 N 546232.51 E 0.000 5190.33 -- 7200.00 80.032 277.212 3101.81 3165.81 749.97 N 5235.38 W 6010172.07 N 546134.72 E 0.000 5288.81 7300.00 80.032 277.212 3119.12 3183.12 762.34 N 5333.09 W 6010183.76 N 546036.92 E 0.000 5387.29 7400.00 80.032 277.212 3136.43 3200.43 774.70 N 5430.80 W 6010195.45 N 545939.13 E 0.000 5485.77 7500.00 80.032 277.212 3153.74 3217.74 787.07 N 5528.52 W 6010207.14 N 545841 .33 E 0.000 5584.25 7600.00 80.032 277.212 3171.05 3235.05 799.43 N 5626.23 W 6010218.83 N 545743.54 E 0.000 5682.73 7686.36 80.032 277.212 3186.00 3250.00 810.11 N 5710.61 W 6010228.93 N 545659.08 E 0.000 5767.79 Top Ugnu 7700.00 80.032 277.212 3188.36 3252.36 811.79N 5723.94 W 6010230.53 N 545645.75 E 0.000 5781.21 7800.00 80.032 277.212 3205.67 3269.67 824.16 N 5821.65 W 6010242.22 N 545547.95 E 0.000 5879.70 10 July, 2001-13:03 Page 4 of 12 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MP/-12 Wps - MPI-12 Wp05 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northin9s Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 7900.00 80.032 277.212 3222.98 3286.98 836.52 N 5919.36 W 6010253.91 N 545450.16 E 0.000 5978.18 8000.00 80.032 277.212 3240.29 3304.29 848.89 N 6017.07 W 6010265.60 N 545352.36 E 0.000 6076.66 8100.00 80.032 277.212 3257.60 3321.60 861.25 N 6114.78 W 6010277.29 N 545254.57 E 0.000 6175.14 8200.00 80.032 277.212 3274.91 3338.91 873.62 N 6212.49 W 6010288.98 N 645156.78 E 0.000 6273.62 8300.00 80.032 277.212 3292.22 3356.22 885.98 N 6310.21 W 010300.67 N 545058.98 E 0.000 6372.10 --- 8400.00 80.032 277.212 3309.53 3373.53 898.34 N 10312.36 N 544961.19 E 0.000 6470.58 8500.00 80.032 277.212 3326.84 3390.84 910.71 N 10324.05 N 544863.39 E 0.000 6569.06 8600.00 80.032 277.212 3344.15 3408.15 923.07 N 6010335.74 N 544765.60 E 0.000 6667.54 8700.00 80.032 277.212 3361.46 3425.46 935.44 N 6010347.43 N 544667.80 E 0.000 6766.02 8800.00 80.032 277.212 3378.77 3442.77 947.80 N 6010359.12 N 544570.01 E 0.000 6864.50 8900.00 80.032 277.212 3396.08 3460.08 960.16 N 6896.47 W 6010370.81 N 544472.22 E 0.000 6962.98 9000.00 80.032 277.212 3413.39 3477.39 972.53 N 6994.18 W 6010382.51 N 544374.42 E 0.000 7061.46 9100.00 80.032 277.212 3430.70 3494.7 984.89 N 7091.90 W 6010394.20 N 544276.63 E 0.000 7159.94 9107.51 80.032 277.212 3432.00 3496.0 985.82 N 7099.24 W 6010395.07 N 544269.28 E 0.000 7167.35 Tog Ugnu M 9200.00 80.032 277.212 3448.01 3512.01 997.26 N 7189.61 W 6010405.89 N 544178.83 E 0.000 7258.43 9300.00 80.032 277.212 3465.32 3529.32 1009.62 N 7287.32 W 6010417.58 N 544081 .04 E 0.000 7356.91 9400.00 80.032 277.212 3482.63 3546.63 1021.99 N 7385.03 W 6010429.27 N 543983.25 E 0.000 7455.39 9413.70 80.032 277.212 3485.00 3549.00 1023.68 N 7398.41 W 6010430.87 N 543969.85 E 0.000 7468.88 Begin Dir @ 5.000° 1100ft : 9413.70ft MD, 3549.000 TVD Target - MPI-12 T1, Geological 9424.94 79.474 277.284 3487.00 3551.00 1025.07 N 7409.39 W 6010432.19 N 543958.87 E 5.000 7479.94 Schrader NA 9500.00 75.752 277.776 3503.10 3567.10 1034.68 N 7482.06 W 6010441.29 N 543886.13 E 5.000 7553.24 --'- 9544.93 73.525 278.078 3515.00 3579.00 1040.65 N 7524.97 W 6010446.97 N 543843.18 E 5.000 7596.56 Schrader NB 9600.00 70.795 278.458 3531.87 3595.87 1048.19 N 7576.84 W 6010454.15 N 543791 .26 E 5.000 7648.97 9640.89 68.769 278.749 3546.00 3610.00 1053.93 N 7614.77 W 6010459.63 N 543753.29 E 5.000 7687.34 Schrader NC 9662.21 67.713 278.903 3553.90 3617.90 1056.97 N 7634.34 W 6010462.53 N 543733.70 E 5.000 7707.14 End Dir, Start Sail @ 67.713° : 9662.21 ftMD,3617.90ftTVD 9691.47 67.713 278.903 3565.00 3629.00 1061.16 N 7661.09 W 6010466.54 N 543706.93 E 0.000 7734.21 Schrader NE 9700.00 67.713 278.903 3568.24 3632.24 1062.38 N 7668.89 W 6010467.71 N 543699.12 E 0.000 7742.10 9800.00 67.713 278.903 3606.16 3670.16 1076.70 N 7760.30 W 6010481.40 N 543607.61 E 0.000 7834.62 9804.37 67.713 278.903 3607.82 3671 .82 1077.32 N 7764.29 W 6010481.99 N 543603.61 E 0.000 7838.66 Begin Dir @ 4.0000/100ft : 9804.37ft MD, 3671.82ft TVD 9812.82 68.051 278.894 3611.00 3675.00 1078.54 N 7772.03 W 6010483.15 N 543595.87 E 4.000 7846.49 Schrader NF 9900.00 71 .537 278.806 3641.11 3705.11 1091.12 N 7852.86 W 6010495.18 N 543514.95 E 4.000 7928.28 10 July, 2001 - 13:03 Page 5 of 12 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MPI-12 Wps - MPI-12 Wp05 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 9918.99 72.296 278.787 3647.00 3711 .00 1093.88 N 7870.69 W 6010497.82 N 543497.10 E 4.000 7946.33 Schrader OA 10000.00 75.536 278.708 3669.44 3733.44 1105.72 N 7947.62 W 6010509.12 N 543420.09 E 4.000 8024.16 10049.61 77.520 278.661 3681 .00 3745.00 1113.00 N 7995.31 W 6010516.08 N 5tJ3372.35 E 4.000 8072.40 TSBC (base OA) 10100.00 79.535 278.614 3691.02 3755.02 1120.42 N 8044.13 W 6010523.16 N 543323.48 E 4.000 8121.77 10200.00 83.534 278.523 3705.74 3769.74 1135.15 N 8141.92 W 010537.22 N 543225.60 E 4.000 8220.66 --- 10232.13 84.819 278.494 3709.00 3773.00 10541.73 N 543193.96 E 4.000 8252.62 TSBB-OB 10300.00 87.533 278.433 3713.53 3777.53 10551.23 N 543126.91 E 4.000 8320.33 10400.00 91 .532 278.343 3714.34 3778.34 6010565.13 N 543027.91 E 4.000 8420.31 1 0411 .1 9 91 .979 278.333 3714.00 3778.00 6010566.68 N 543016.83 E 4.000 8431 .49 End Dir, Start Sail @ 91.979° : 1 0411.19ftMD,3778.00ftTVD 7" Casing Target - MPI-12 T2 New, Geological 10500.00 91 .979 278.333 3710.93 8438.30 W 6010578.94 N 542928.92 E 0.000 8520.25 10600.00 91 .979 278.333 3707.48 3771.4 8537.18 W 6010592.74 N 542829.94 E 0.000 8620.18 10700.00 91 .979 278.333 3704.03 3768.03 8636.07 W 6010606.54 N 542730.96 E 0.000 8720.12 10800.00 91 .979 278.333 3700.57 3764.57 8734.95 W 6010620.35 N 542631.98 E 0.000 8820.06 10900.00 91 .979 278.333 3697.12 3761.12 8833.84 W 6010634.15 N 542532.99 E 0.000 8920.00 11000.00 91 .979 278.333 3693.66 3757.66 8932.72 W 6010647.95 N 542434.01 E 0.000 9019.94 11100.00 91 .979 278.333 3690.21 3754.21 1265.82 N 9031.61 W 6010661.76 N 542335.03 E 0.000 9119.88 11164.01 91 .979 278.333 3688.00 3752.00 1275.09 N 9094.90 W 6010670.59 N 542271 .67 E 0.000 9183.85 Begin Dir @ 3.0000/100ft : 11164.01 ft MD, 3752.00ft TVD Target - MPI-12 T3, Geological 11199.83 90.905 278.303 3687.10 3751.10 1280.27 N 9130.33 W 6010675.53 N 542236.20 E 3.000 9219.66 End Dir, Start Sail @ 90.905°: .- 11199.83ftMD,3751.1OftTVD 11200.00 90.905 278.303 3687.10 3751.10 1280.30 N 9130.50 W 6010675.55 N 542236.03 E 0.000 9219.83 11300.00 90.905 278.303 3685.52 3749.52 1294.74 N 9229.44 W 6010689.31 N 542137.00 E 0.000 9319.81 11400.00 90.905 278.303 3683.94 3747.94 1309.18 N 9328.38 W 6010703.07 N 542037.96 E 0.000 9419.80 11500.00 90.905 278.303 3682.36 3746.36 1323.62 N 9427.32 W 6010716.82 N 541938.92 E 0.000 9519.79 11600.00 90.905 278.303 3680.78 3744.78 1338.06 N 9526.26 W 6010730.58 N 541839.89 E 0.000 9619.77 11700.00 90.905 278.303 3679.20 3743.20 1352.50 N 9625.20 W 6010744.34 N 541740.85 E 0.000 9719.76 11800.00 90.905 278.303 3677.62 3741.62 1366.94 N 9724.14 W 6010758.10 N 541641.82 E 0.000 9819.74 10 July, 2001 -13:03 Page 6 of 12 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MPI-12 Wps - MPI-12 Wp05 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 11900.00 90.905 278.303 3676.04 3740.04 1381.38 N 9823.08 W 6010771.86 N 541542.78 E 0.000 9919.73 12000.00 90.905 278.303 3674.46 3738.46 1395.82 N 9922.02 W 6010785.61 N ,541443.74 E 0.000 10019.72 12100.00 90.905 278.303 3672.88 3736.88 1410.26 N 10020.96 W 6010799.37 N ~1344.71 E 0.000 10119.70 12200.00 90.905 278.303 3671.30 3735.30 1424.70 N 10119.90 W 6010813.13 N 541245.67 E 0.000 10219.69 12300.00 90.905 278.303 3669.72 3733.72 1439.13N 10218.84 W 010826.89 N 541146.63 E 0.000 10319.68 ~ 12400.00 90.905 278.303 3668.14 37~2.14 1453.57 N 541047.60 E 0.000 10419.66 12500.00 90.905 278.303 3666.56 3730.56 1468.01 N 540948.56 E 0.000 10519.65 12585.49 90.905 278.303 3665.21 3729.21 1480.36 N 540863.89 E 0.000 10605.13 Begin Dir @ 3.0000/100ft : 12585.49ft MD, 3729.21ft TVD 12600.00 90.624 277.971 3665.02 3729.02 6010868.12 N 540849.52 E 3.000 10619.64 12601.75 90.590 277.931 3665.00 3729.00 6010868.35 N 540847.78 E 3.000 10621.39 End Dir, Start Sail @ 90.590° : 12601 .75ftMD,3729.0OftTVD Target - MPI-12 T4, Geological 12700.00 90.590 277.931 3663.99 10614.70 W 6010881.23 N 540750.39 E 0.000 10719.63 12800.00 90.590 277.931 3662.96 10713.74 W 6010894.35 N 540651.26 E 0.000 10819.62 12900.00 90.590 277.931 3661.93 10812.78 W 6010907.46 N 540552.12 E 0.000 10919.62 13000.00 90.590 277.931 3660.90 10911.81 W 6010920.58 N 540452.99 E 0.000 11019.61 13100.00 90.590 277.931 3659.87 11010.85 W 6010933.69 N 540353.86 E 0.000 11119.61 13200.00 90.590 277.931 3658.84 3722.84 1565.20 N 11109.89W 6010946.81 N 540254.73 E 0.000 11219.60 13300.00 90.590 277.931 3657.81 3721.81 1578.99 N 11208.93 W 6010959.92 N 540155.60 E 0.000 11319.60 13378.52 90.590 277.931 3657.00 3721 .00 1589.83 N 11286.70 W 6010970.22 N 540077.76 E 0.000 11398.12 Total Depth: 13378.52ftMD,3721.00ftTVD 4 1/2" Liner --..." Target - MPI-12 T5, Geological All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 278.018° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13378.52ft., The Bottom Hole Displacement is 11398.12ft., in the Direction of 278.018° (True). 10 July, 2001 - 13:03 Page 7 of 12 DrillQuest 2.00.09.001 Milne Point Unit Comments Measured Depth (ft) 300.00 800.00 1147.46 1887.56 2017.41 2851.27 9413.70 9662.21 9804.37 1 0411 .1 9 11164.01 11199.83 12585.49 12601.75 13378.52 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 300.00 799.37 1143.95 1837.55 1950.00 2413.05 3549.00 3617.90 3671.82 3778.00 3752.00 3751.10 3729.21 3729.00 3721.00 0.00 N 21.47 N 55.82 N 121.13N 129.27 N 212.29 N 1 023.68 N 1 056.97 N 1077.32 N 1166.05 N 1275.09 N 1280.27 N 1480.36 N 1482.66 N 1589.83 N 0.00 E 3.79W 29.56 W 265.31 W 329.72 W 90 9130. 10501.30 W 1 0517.39 W 11286.70 W Sperry-Sun Drilling Services Proposal Report for MPI-12 Wps - MPI-12 Wp05 Alaska Drilling & Wells Milne Point MPI Comment Begin Dir @ 1.0000/100ft : 300 Dir Rate Increase @ 2.000° Dir Rate Increase @ End Dir, Start S . Begin Dir VD ,.99.37ftTVD .46ftMD,1143.95ftTVD 1887:56ftMD, 1837 .55ftTVD 7.41ft MD, 1950.00ft TVD ~. .032° : 2851.27ftMD,2413.05ftTVD 5.0000/100ft : 9413.70ft MD, 3549.000 TVD Sail @ 67.713° : 9662.21ftMD,3617.90ftTVD ir @ 4.0000/100ft : 9804.37ft MD, 3671.82ft TVD ir, Start Sail @ 91.979° : 10411.1OOMD,3778.0OOTVD Begin Dir @ 3.0000/100ft : 11164.01 ft MD, 3752.00ft TVD End Dir, Start Sail @ 9.0.905° : 11199.83ftMD,3751.1 OOTVD Begin Dir @ 3.0000/100ft : 12585.400 MD, 3729.21 ft TVD End Dir, Start Sail @ 90.590° : 12601.75ftMD,3729.0OOTVD Total Depth: 13378.52ftMD,3721.00ftTVD Formation Tops Formati on Plane Profile Penetration Poi n t (Below Well Origin) Measured Vertical Sub-Sea -- Sub-Sea Dip Dip Dir. Depth Depth Depth Northings Eastings Formation Name (ft) Deg. Deg. (ft) (ft) (ft) (ft) (ft) 1775.00 0.000 0.395 1889.23 1839.00 1775.00 121.24 N 266.14 W Base Permafrost 3186.00 0.000 0.395 7686.36 3250.00 3186.00 810.11N 5710.61 W Top Ugnu 3432.00 0.000 0.395 9107.51 3496.00 3432.00 985.82 N 7099.24 W Tog Ugnu M 3487.00 0.000 0.395 9424.94 3551.00 3487.00 1025.07 N 7409.39 W Schrader NA 3515.00 0.000 0.395 9544.93 3579.00 3515.00 1040.65 N 7524.97 W Schrader NB 10 July, 2001 - 13:03 Page 8 of 12 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MPI-12 Wps - MPI-12 Wp05 Milne Point Unit Alaska Drilling & Wells Milne Point MPI Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. Profile Penetration Point Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) Northings (ft) Eastings (ft) Formation Name Formation Tops (Continued) 3546.00 0.000 0.395 9640.89 3610.00 3546.00 Schrader NC 3565.00 0.000 0.395 9691.47 3629.00 3565.00 Schrader NE 3611.00 0.000 0.395 9812.82 3675.00 3611.00 Schrader NF 3647.00 0.000 0.395 9918.99 3711 .00 3647.00 Schrader OA 3681.00 0.000 0.395 10049.61 3745.00 3681.00 TSBC (base OA) 3709.00 0.000 0.395 10232.13 3773.00 8173.52 W TSBB-OB 3731.00 0.000 0.395 SBA5 (base OB) Casing details Fro m To Measured Vertical Measured Vertical Depth Depth Depth Depth Casing Detail (ft) (ft) (ft) (ft) <Surface> <Surface> 10411.19 3778.00 7" Casing <Surface> <Surface> 13378.52 3721.00 4 1/2" Liner --. -- 10 July, 2001 - 13:03 Page 9 of 12 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MPI-12 Wps - MPI-12 Wp05 Milne Point Unit Alaska Drilling & Wells Milne Point MPI Targets associated with this well path Entry Coordinates Northings Eastings Target Target (ft) (ft) Shape Type 8350.48 W Polygon Drillers 543016.83 E ~ 149038' 57.1990" W 7751.08 W 8729.62 W 10215.23 W 11103.19 W 11144.07 W 10253.91 W 8770.40 W 7786.82 W LeveVGlobal Coordinates #1 3714.00 6010602.00 N 543616.00 E #2 3714.00 6010665.00 N 542637.00 E #3 3714.00 6010862.00 N 541150.00 E #4 3714.00 6011009.00 N 540261.00 E #5 3714.00 601 0737.00 N 540222.00 E #6 3714.00 6010617.00 N 541113.00 E #7 3714.00 6010407.00 N 542598.00 E #8 3714.00 6010349.00 N 543582.00 E Geographical Coordinates #1 700 26' 23.4678" N 149038'39.6041" W .-- #2 70026' 24.1431" N 149039' 08.3325" W #3 70026' 26.1629" N 1490 39' 51 .9525" W #4 70026' 27.6564" N 149040' 18.0272" W #5 700 26' 24.9832" N 149040'19.2152" W #6 700 26' 23.7552" N 1490 39' 53.0784" W #7 700 26' 21 .6077" N 149039' 09.5206" W #8 70026' 20.9813" N 1490 38' 40.6456" W Target Name MPI-12 Drlr Poly 10 July, 2001 - 13:03 Page 10 of 12 DrillQuest 2.00.09.001 Milne Point Unit Target Name Targets associated with this well path (Continued) MPI-12 GeoPoly MPI-12 T1 MPI-12 T2 New MPI-12 T3 Sperry-Sun Drilling Services Proposal Report for MPI-12 Wps - MPI-12 Wp05 Alaska Drilling & Wells Milne Point MPI Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Target Target Shape Type 8350.48 W Polygon Geological 543016.83 E ~, 149038' 57.1990" W 11298.20 W 9235.54 W 7561.52 W 7833.84 W 11301 .80 W ¡j' obal Coordinates #1 3711.00 6011153.00 N 540065.00 E #2 3711.00 6010820.00 N 542130.00 E #3 3711.00 6010684.00 N 543805.00 E #4 3711.00 601 0201 .00 N 543536.00 E #5 3711.00 6010630.00 N 540065.00 E Geographical Coordinates #1 700 26' 29.0832" N 1490 40' 23.7585" W #2 700 26' 25.6959" N 149039' 23.1901" W #3 700 26' 24.2634" N 1490 38' 34.0418" W #4 700 26' 19.5283" N 149038'42.0213" W #5 700 26' 23.9391" N 149040' 23.8410" W -- 3549.00 1023.68 N 7398.41 W Point Geological Mean Sea LeveVGlobal Coordinates: 3485.00 6010430.87 N 543969.85 E Geographical Coordinates: 70026' 21.7641" N 1490 38' 29.2463" W 3778.00 1166.05 N 8350.48 W Point Geological Mean Sea LeveVGlobal Coordinates: 3714.00 6010566.68 N 543016.83 E Geographical Coordinates: 700 26' 23.1546" N 149038' 57.1990" W 3752.00 1275.09 N 9094.90 W Point Geological Mean Sea LeveVGlobal Coordinates: 3688.00 6010670.59 N 542271 .67 E Geographical Coordinates: 700 26' 24.2185" N 149039'19.0561" W 10 July, 2001 - 13:03 Page 11 of 12 DrillQuest 2.00.09.001 Milne Point Unit Target Name Targets associated with this well path (Continued) MPI-12 T4 MPI-12 T5 Sperry-Sun Drilling Services Proposal Report for MPI-12 Wps - MPI-12 Wp05 Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Mean Sea LeveVGlobal Coordinates: Geographical Coordin 10517.40 W 540847.78 E 149040' 00.8237" W 1589.83 N 11286.70 W 6010970.22 N 540077.76 E 70026'27.2847" N 149040' 23.4127" W Alaska Drilling & Wells Milne Point MPI Target Target Shape Type Point Geological -, Point Geological ~c 10 July, 2001- 13:03 DrillQuest 2.00.09.001 Page 12 of 12 Name +NI-S Phn MPI-12 1062-653 1136_474 6009458,190 551375-010 7!f26'1J.732N 14<r34'52,068W NlA SW1i1g F RIm TV» .y ~+ tS" $W $' ~~ ~ .c--..~ \:'! eO~-"" ~ ~T ~ I?~ .$ ~ ~} 210 . r§' _ß..' \. Y \.} ~ ~~'" ~\:' \. ~ ,..ç\:' \. 150 ...~ ...~v "?\.'l>-~' "?\.'l>-~' 160 ~~ ~\:'\.\. ~~:y\.\. ~ ~\~ ,,\~ 160 150 125 100 75 50 25 0 270 25 50 75 100 125 +EI-W Northing WElL DETAIlS COMPANY DETAIlS SURVEY PROGRAM ANTI-COLLISION SETI1NGS WIUJ'A'J'H DETAlI$ I'hnMI'I-12 Ea>ting Latkude LongWde Sbl BP AImeo th Fm Depth Tn Su",,)'lPlm _001 800,001 Phoned: MPI-12 Wp05 VI ',001 13379,485 Phoned: ~ß'1.12 Wp05 VI Toul Interpolation Method:MD Interval: !OO.OOO Depth Range From: 64.000 To: 13379.485 Maximum Range: 153 I ,549 Reference: Plan: MPI- I 2 Wp05 Cak:uhrDn Method: Milinum CUO'ature Error S)'SIem: ISCWSA Scan Method: Trav C)'li1de.- North Error Surface: ~(Ïcaj + Casmg Wamng Method: Rub; Based v. SCL: (jilin i\nglc 278_018 OJJOO CB-(òYRO-SS MWI},.U'R+MS Rig: Ref- IßIum: 12 :œWI<;JIW7IMJOI M,IXXJfI Orign + Nt,S ::C.W O,OO;¡ OJJOO /~/~- .//./// // .// < ~~m Colour To MD ~ ~'\: 0 - 500 ...!.. ~~ 500 750 ~ ~<:5 750 - .iboo '--' ~ 1000 - ~500 ,~ 1500 - 32000 ~ 2000 - a;2500 ::g 2500 OCooo e 10000 1'"'\ ' 00(}.8 ~ .8 u ..c: '--' u ;¡;; ~ r:: ~ ~ ---., e - ..... r:: ~læ 0 9 ~ ~ ~æ' '¡;: ~ ~ õ: .~ '--'~ ~ . ';fo~ ~ \ 90 ~ \ ~...!.. ...!.. \ ~ ~ .k I, Mai" R~k "-1a;:lfRf¡.k , NOERRORS 'I.b;'rRj.;.k ...ta}ll Rt-.k ). Maj'r Ri<;k IHõENIJ - MI'I-02 (MPI-02) ,-. . . - "'11'1.03 (MPI-03) ..... . I - MPI.o.t^ WililWig - ~rllrc dclctWig (MPI-Ot - MPI-04 (MPI-OI) .. . . - MI'I.04 (MI'I-OII ". R~k - MI'I,04(1'hn~I(' ,- I4ALI),Maj',R~k - MI'I-OI (I'hn~1 ( . ,- ,04A), Maj" R~k - MI'I,J.I (I'hnH (, .. 14A), Maj', R~k MI'I,05 (MI'I,05) .. . . MI'I,IXi (MI'I,()(,) ". .. MPI-07 (MI'I-07) ". - 0 - MJI.()K(~1I'1.()K).... .. MI'I-09(MI'I-(JOI) .. . - MI'I.IO(MPI.IO) , . - MI'I.IO(MI'I.IOA ,-. - Pbn ~U)I.II (PW ... I'bn MPI,II (Phr " - 1'110 MI'I.12 (l'br " ----- Pkln MPI-13 (P1ar ... - f'bn ~U'I.XI (1'1.1." ~ - 1'110 MI'I.XI (I'lL" ~ - Pbn MI'I.12 MPI.12 Wr05 ~- // // // /// / / / / /- / / I //--- ,/ I I ; i i ! / / I / / ; i ! \ 0 I'bn: MI'I.12 Wp05 (l'bn MI'I.I2IPhn MPI.12) C,caloo B)': Duan. H, Vaagro Cho<:ked:.___-- 1)'1.: (17IIMtX) 1>.1Ic:_-- Rc......"",-a.t:_---- l}dIC:_- SECTION lJET AII_~ See MD TVD +Nt-S +E/-W DI.cg ll:;:¡\:c VS", Target M,OOI 0_001 0_000 0,00 OJro O.lXJO 300,001 0,000 0.001 O,(X) O,O(X) O.tXX] 7'7'1,366 21.472 .3,7!!6 I.(XJ 350-000 ~_744 1143,948 55,817 .29557 2,00 2'12-(,97 37.054 1837550 121.130 - 2M305 3-m 314_213 279,('(J>! 1950.lXJ.I 129,2~8 .329,718 0,00 O.(XX) 34452h 2413,056 212-292 .--200 ~_m O.olS IIXXi_171 3549,001 1023,7(,9 -73'7'1,001 0,00 O,(XX] 74(,<},470 MI'I.12 TI 3617,817 1057.IJJ8 .7~34,7JO 5,00 172.6K3 1707,535 3671.931 1077.493 .17M-244 o,m o,tXX) 78W,~2~ 3m,OOI 11(,6,199 .8351.156 4,00 .1.397 11432-IK4 ~U'I.12 TI N<,.w 3752,001 1275,22~ .9095510 O,{)(] 0,000 91114,4(,<} MI'I,IN4 D 375UJ98 121!OAœ -9130_954 3,{)(] -178,43K 9220.289 3729,212 1480542 -10502-210 0,00 0,000 I ((,()(,,055 3729,001 1482-83-1 -10518283 3.00 .BO.255 1()(,22-291 MI'I,IN4 1"4 3721.001 1590,029 .112I!7,653 O,{)(] O_(XJO I \Jw.lm MI'I-IN4 T5 (nc Azi / 1 61_001 0,001 0,001 2 300_001 0,001 0,001 3 800_001 5,001 350,001 4 1147.460 10_001 310,000 5 181!7,5liQ 30,001 277,200 6 2017.410 30_001 277.200 7 2851.291 1!O,033 277.212 8 9414,284 80.033 277.212 9 9662582 67,725 278.9fY1 10 9805,342 67,725 278,9fY1 II 1(J.I11.1!70 91.979 278333 12 11161_616 91.979 278_333 13 11200,449 90,905 278301 14 12586,405 90_905 278_JOI 15 12602,612 90,590 217.932 16 13379-485 90-590 277.932 .~~/ 180tmr-- ~ ------ 150 entre to Centre Separation [50ft/in] ( (' Sperry-Sun Anticollision Report Company: Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Milne Point M Pt I Pad Plan MPI-12 Plan MPI-12 Date: 07/10/2001 Time: 16:00:08 Page: 1 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan MPI-12, True North 12 : 08 9/15/1997 16:09 64.0 Db: Oracle GLOBAL SCAN APPLIED: All well paths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 100.000 ft Depth Range: 64.000 to 13379.485 ft Maximum Radius: 1531.549 ft Reference: Error Model: Scan Method: Error Surface: Plan: MPI-12 Wp05 & NOT PLANNED P GRA ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Casing Points MD TVD ft ft 10411.189 3778.023 13379.485 3720.983 Diameter in Hole Size in Name 7.000 4.500 9.875 6.125 7" 41/2" Plan: MPI-12 Wp05 Date Composed: Version: Tied-to: 06/21/2001 1 From Well Ref. Point Principal: Yes Summary < ---------------------- Offset. W ellpath -------------_.-~----- > Reference Offset Ctr-Ctr No-Go Allowable Site WeD Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft M Pt I Pad MPI-02 MPI-02 V1 498.078 500.000 242.230 9.801 232.430 Pass: Major Risk M Pt I Pad MPI-03 MPI-03 V1 498.316 500.000 185.768 13.711 172.058 Pass: Major Risk M Pt I Pad MPI-04A Waiting on r MPI-04A V1 499.006 500.000 122.968 12.602 110.366 Pass: Major Risk M Pt I Pad MPI-04 MPI-04 V5 499.006 500.000 122.968 12.602 110.366 Pass: Major Risk M Pt I Pad MPI-04 MPI-04PB1 V3 499.006 500.000 122.968 12.602 110.366 Pass: Major Risk M Pt I Pad MPI-04 Plan#1 (CTD) MPI-04AL 1 499.006 500.000 122.968 12.602 110.366 Pass: Major Risk M Pt I Pad MPI-04 Plan#1 (Rotary) MPI-04 499.006 500.000 122.968 12.602 110.366 Pass: Major Risk M Pt I Pad MPI-04 Plan#3 (CTD) MPI-04A V 499.006 500.000 122.968 12.602 110.366 Pass: Major Risk M Pt I Pad MPI-05 MPI-05 V1 597.340 600.000 211.793 10.393 201.405 Pass: Major Risk M Pt I Pad MPI-06 MPI-06 V10 888.421 900.000 154.823 19.850 135.015 Pass: Major Risk M Pt I Pad MPI-07 MPI-07 V1 598.559 600.000 97.195 18.014 79.185 Pass: Major Risk M Pt I Pad MPI-08 MPI-08 V3 1579.674 1600.000 56.214 29.864 30.683 Pass: Major Risk M Pt I Pad MPI-09 MPI-09 V12 Plan: MPI-O 299.982 300.000 270.373 6.942 263.431 Pass: Major Risk M Pt I Pad MPI-10 MPI-10 V7 2348.066 2600.000 220.276 78.632 144.637 Pass: Major Risk M Pt I Pad MPI-10 MPI-10A V1 2259.048 2501.650 215.010 71.793 146.227 Pass: Major Risk M Ptl Pad Plan MPI-11 Plan MPI-11 L 1 VO Plan 599.008 600.000 25.767 12.869 12.901 Pass: Major Risk M Pt I Pad Plan MPI-11 Plan MPI-11 V2 Plan: M 599.008 600.000 25.767 12.869 12.901 Pass: Major Risk M Pt I Pad Plan MPI-12 Plan MPI-12L1 V8 Plan: 800.000 800.000 0.000 0.001 -0.001 FAIL: NOERRORS M Pt I Pad Plan MPI-13 Plan MPI-13 V10 Plan: 400.100 400.000 30.238 9.183 21.056 Pass: Major Risk M Pt I Pad Plan MPI-X1 Plan MPI-X1 V2 Plan: M 400.105 400.000 30.691 9.180 21.512 Pass: Major Risk M Pt I Pad Plan MPI-X1 Plan MPI-X1 L 1 V5 Plan: 400.105 400.000 30.691 9.081 21.611 Pass: Major Risk Site: M pt I Pad Well: MPI-02 Rule Assigned: Major Risk Wellpath: MPI-02 V1 Inter-Site Error: 0.000 ft Refei"cnce Offset Seini-Major Axis Cti"-ctr. No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI. TFO-HS. . Casing Distance Area Deviation ft ft ft ft ft ft deg deg in ft ft ft 100.000 100.000 100.000 100.000 0.083 0.147 92.851 92.851 240.459 1.753 238.706 Pass 200.000 200.000 200.000 200.000 0.475 0.192 92.850 92.850 240.405 4.063 236.342 Pass 300.000 300.000 300.000 300.000 0.698 0.259 92.831 92.831 240.320 5.934 234.385 Pass 399.069 399.064 400.000 400.000 0.885 0.322 93.007 103.007 240.537 7.675 232.862 Pass 498.078 498.038 500.000 499.991 1.061 0.525 93.488 103.488 242.230 9.801 232.430 Pass 596.900 596.767 600.000 599.854 1.231 0.947 93.922 103.922 247.684 12.567 235.118 Pass 695.405 695.091 700.000 699.459 1.401 1.388 94.276 104.276 256.884 15.382 241.506 Pass 793.467 792.858 800.000 798.704 1.477 1.834 94.609 104.609 269.480 17.917 251.570 Pass 883.657 882.651 900.000 897.241 1.487 2.285 94.519 119.837 287.595 20.176 267.442 Pass 971.129 969.570 1000.000 994.591 1.498 2.743 93.874 130.481 313.416 22.436 291.070 Pass 1056.183 1053.849 1100.000 1090.981 1.516 3.206 93.021 137.242 345.206 24.725 320.709 Pass 1138.349 1134.973 1200.000 1186.142 1.542 3.674 91.964 141.470 382.780 27.022 356.193 Pass 1211.866 1207.231 1300.000 1278.947 1.575 4.154 90.580 147.584 428.661 29.289 400.145 Pass 1280.034 1273.845 1400.000 1369.956 1.614 4.648 89.173 151.858 481.459 31 .557 451. 138 Pass 1343.281 1335.242 1500.000 1459.168 1.662 5.152 87.828 154.626 540.300 33.824 508.292 Pass I \ I , ........ , .., ~: I IIIIIII T M Azimuths to True North Magnetic North: 26.32° Magnetic Field Strength: 57438nT Dip Angle: 80.76° Date: 2/21/2001 Model: BGGM2001 Field: Milne Point Site: M Pt I Pad Well: Plan MPI-12 WeIlpath: Plan MPI-12 120- ..," 10v i 8v 'i? ~ 0 [:!. s:: 0 ''¡;: ¡;! CtI & Ç/) C1.) ~ 60- u a ~ s:: C1.) U "",1,,,,, ,,,"....,,.. """''''''''1'''''''''''''' "'["'"¡''''' , ,,,,,, .Jil!t' õ11,~1;' \1;1'!.1l';;':: f)i~¡:m~'~' ' '"--...-- ... -. I 0- ~o- .....¡.." (" Name MPI-IN4 T3 MPI-IN4 T4 MPI-IN4 T5 MPI-12 TI MPI-12 T2 New MPI-12 GeoPoly ( 5per'r'\I-5un DRILLING SERVIc:es TVD 3752.00 3729.00 372 LOO 3549.00 3778.00 3778.00 A HALLIBURTON COMPANY T ARGET DETAILS +N/-S +E/-W Shape 1275.23 -9095.51 1482,83 -10518.28 1590.03 -11287.65 1023.77 -7399.00 1166.20 -8351.16 1164,88 -8351.33 Point Point Point Point Point Polygon SURVEY PROGRAM Depth Fro Depth To Survey/Plan Date: 2/21/2001 Validated: No Version: 6 Tool 500.00 Planned: MPI-12 Wp05 VI 13379.48 Planned: MPI-12 Wp05 VI , I ~" ~... )1# ( ,i! / è' j it 'I il / .I,l' I ,;;It 7, if "'''7 ,ill" ..-..........---- ""! ~~!¡'I¡t;;............ 64.00 500.00 .."" ""...'" ....,..., ..... "I"" f "-.- I~ ; ¡ "...t..... \ i . ... '~."' ",.....,:'..' I "1 ; "I' ,+" [ j ¡ ; ! I i i . ' ' ; i ; I ' ' I ' 600 800 Measured Depth [200ft/in] v I . i ! i I : , ! j I ! i ¡ i 400 , 0 200 , I . , CB-GYRO-SS MWD+IFR+MS , ........ .,"",'m .......... , , II FOI "'!J) '.'.. , u ... .. ----......- ~~ '~i~!~'~~ \:¡¡~~::~h ~i~~:~:,¡¡;~~ ~~~~~ rl('1~~:~¡' (\~P~'~o~~?,~a1~r ~it ........ \IPI-Q4 (\IPI-04I'B I): Major RIsk ¡ ; ........ \11'1-';:,;, PI \". : ,(TD, \Ii"! .;' t \1. '. \!.Ii," R ,,~ -- \WI-:':,!,!,!:' ¡,t~I:,'\.\II:-(I,;\, \1.:i,):R¡,:, -- \11'~-",; ,I': ,:1 : .(1 I), \11'1-",\ \, \~.II"r R:,I. ......... .. I'. \I!'I-I'_~ I \11'1-1,1.' \III'~: 1\.,"" :o.1!'1.'(', .\!PI-V \::!'I 1: :~:., '~!"!- ; - ., !PI..'Y' . ~. ~..I ,~: .:~: ~~. ~...... ¡MPI-98 (MPI-08), Maj~;¡r Risk <"',",>:', ,¡MP.~~9~,{MPJ799)""Mi1:i',?I,Rj,~k,,,, ; -- [MPI-!O (M¡>I-IO), Maj,)~ Ris~ ¡ ! -- 'MPI~IO(fv1"I-IOA)~M~JorR]s~. .!.... .! ........ !Pla:nMPI"I:I(Plin MPl~1IL1),M*jorRisk ,.;.:~,,:,:.:.:~.:.~:~, :r~:-!r ~.fPT-~:~ rp:.:'.-. \fP\"..~ 1), :\f:!~;J:' Ri::~: .11" "111,,"1111 P..'.:', '.!!>! ~.: 'I\:~:~ '.!P. !~!. . '.:.:'.:: !~'..; I' ;':: ..:,'1-';;. ~):::I: \11' - i::" \1:1:;1: R!.;; -- I"'" ..",,-,.. 01'1',., 'H'I-~:' "1""'i~'.1 . -- ¡pi~~ ¥pi-x ¡ (p¡;n.'" MP.I-)()[,.l), '~jor R;isk ' -- ,Plan MPI-12 , , ¡ ! , .! 'I I ' 1000 1200 ¡ ",, ¡ I ! . ' I ¡ I ! , I I 1400 Survey Program for MPI -12 Well Plan Profùe ID sper'r'}I-sun CRILLINt; SERVices WP5. Hole/Csg Survey Survey Equipment Survey Directional BHA Interference Extra Comments (Inches) Interval Instrument Supplier Station Survey Objective Review Sub (Feet) Frequency. (Initials) e.g. PBL ** subs* 7" CSG Surface to Photo Gyro Sperry-Sun JORP's 0 Contingency to use PG to 800'MD due 800'MD to Mag. Cross Axial interference from other wellbores 7" CSG Surface to MWD+IIFR: Sperry-Sun JORP's 0 10411 MD MS 4 )Iz "Liner 10411 'MD MWD+IIFR: Sperry-Sun JORP's 0 Running IIFR:MS eliminates the need to MS to drop an ESS and increases the size of 13378'MD the drillers target. 4 )Iz "Liner 9820'MD MWD+IIFR: Sperry-Sun JORP's 0 Running IIFR:MS eliminates the need L1 to MS to drop an ESS and increases the size of 13373 'MD the drillers target. Utilize MS to monitor Crossazial interference from the lower leg that you will be drilling above. Drillinf! Enf!ineer* * Note. (A check mark indicates YES) . Below is an Excemt from Section 3.5 of Whenever a Steel/Magnetic PBL sub or Sperrv-Sun's Current JORPs (Mav 1998) other downhole component is run that will 3.5 Survey frequency will depend on the prevent the use of an ESS tool. It shall be drilling requirements. For a valid so noted on this document. The signing of definition of well trajectory, survey this document indicates proper dispensation interval will be one or two stands in if necessary. tangent sections, decreasing to every stand for doglegs up to 5°/100' and every single ** Note. at doglegs in excess of 5°/100'. Where The MWD Coordinator(s) have reviewed while-drilling position is not critical, the proposed BHA for proper Survey highly curved sections may optionally be operation including the non-mag spacing. surveyed in a separate pass after drilling. Date SMS Coordinator William T. Al1en or Ken Al1en Date MWD Coordinator Jim Galvin or Tim Flynn Date DD Coordinator Gordon Hecht Date All surveys are to be carried out as oer the individual survevinl! contractors Joint Ooeratinl! and Reoortinl! Procedures (JORPs). SMS SPS Ver 1.5 ~~, -- 6011400 - f-'n'--'mn_m..m'n,.n".."~'-'-_..':...._mn__n..mm'nmnnm'.n..n_.." ..n~.n" .' ---, _n___m"n___n__'mn"_"n__n_'m,__,__,_",~,n'-.m'__n""_'.'"_n_""_'n_nnm'_n'nn"_"_"_'_"_n"~"_n~.m__'_"__n_' n_-:_nn____'n__~~,~~-=~~ I ~ .... . - I ~ - -.............. Direction of Dnlllng Dnllers boundary --,. ~-- .... . ~'.I ~-. .. . - I' -,-,",...' ""..' .. - ---......-- I 6011000 -too- -, -- j I i ' 6010800 -L I I I ' - I' i I 6010600 -r'c", - - -- --. .- -~. _. . R -M. . ._--_...-~ ".-- Wellbore I I - 6010400 ,- 6010200 ~- I ! - ¡ MWD+IIFR+MS tool type ¡ ! - 601 0000 -t~-'~~-~~=_._-"-r-'~"~-'^~ï~'-~--r 539500 540000 540500 541000 541500 ...-------..--- 542000 542500 543000 543500 ~. - ~MPI-12 -'-DD Target -m-T argets r ~- N~ True Referance 544000 ( (' If i, -' .,'.,' H 19332~ DATE 07/06/01 CHECK NO. 00193328 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 070201 CK0702010 PYMT OMMENTS: HANDL NG INST: 100.00 100.00 Per it to Drill ee S/H - Terrie Hub Ie X4628 or Sondra Ste man X4750 PI - I ~ riE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ " .. . " ~. " Oi'4E...HUNDRED & OO/100***~,~************t**~*it**~*********** Up .D(:jLLAR '>DATS< ,AMOUNT ¿}ÙcÝ6101 .'I,;Ôi,:;:L. ... .. ~il°9:",ø;@;I' NQJ\VAUOAFTER12Ò DAYS " , , " ' , . .' , . ~;~~~;> 00193328 Bp.EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No~H 56-389 412, PAY To The ORDER Of , , ' ALASKA OIL ANI) GAB ' CONSERV~TIONl :ÇOMrvlISSION 3:3:3WESj)! 7J:'H AVENUE ' SUITE 1<:)0 ,,' , ANCHORAG.E II. ~ g :l :l 2 B II. I: 0... ~ 20 :l a g 51: 00 a ... ~ ~ '111. ~ WELL PERMIT CHECKLIST COMPANY WELL NAMEA'/I- /2 PROGRAM: exp - dev - redrll - serv - wellbore seg _ann. disposal para req - FIELD & POOL >2S/~t":> INITCLASS /ÌP~ /-4// GEOLAREA ~/ð UNIT# //¿2'ð"" ON/OFFSHORE ð,u -. ' ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . /,!\ N 2. Lease number appropriate. . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Suffident acreage available' in drilling unit.. . . . . . . . . . . Y N, 8. If deviated, is well bore plat included.. . . . . . . . . . . ... . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can.be issued without administrative approval.. . . . . l ~ NN 13. Can permit be approved before 15-day wait.. . . . . . . . . . \Y 14. Conductor string provided . . . . . . . . .. . . . . . . . . . iN 15. Surface casing protects all known USDWs. . .. . . . . . . . Y NN 16. CMT vol adequate to drculate on conductor & suñ csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y N ~~ \ ~~~~-\~ ~~ \ ~~~~ ~'- t\~ ~,,\'( 18. CMT will cover all known productive horizons. . . . .'. . . . . ~YY' eÑ" ~ \<e ~~ \t ,,~"" \,>\c:'\ ~t-..~ ~ 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 'ì\r 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N ~~~~ ~~ J \"-~ ~CtNCt.. ~\~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N ~ 23. Ifdiverterrequired,doesitmeetregulations . . . . . . . . . . N ~~"':~~~~~~.l~~\'{~'\o:;.\>~Cß> 24. Drilling ,fluid program schematic & equip list adequate. . ~ . . Y N 25. BOPEs, do they meet regulation. . . . . . . . . . .. . . . . N '" DATE 26. BOPE press rating appropriate; test to ~Ö psig. N \.U~~~ ~~~~<t! \d..~ "'~, f>\<::.H'\t\.~ ~~~ ~-\-\~ '5~~~\ ð¡~( . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdbwn. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ GEOLOGY ~~: 6:~:r:~~t~~s~~e:o::~ti:r~~g;~e:~~~ez:~::u.r~s.. ." ." ."': Ã~ N ~ ti AF?PR--2~!~ , ~~: ~:~=~ ~~~~~n o:~~:~o(~. ~~~s:~:)s: : : : : : : : : : : : : Y N -: /\. ~ ~ ~ 34. Contact name/phone for weekly progress reports [exploratory 0 , 1 Y N_- ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to suñace; " " (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage produdng formation or impair recovery frpm a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING:' UIC/Annular COMMISSION: ~þ~ WM'--- --...8?s ~14"-Ö\ JM AJP) ~ ENGINEERING APPR DATE c 0 Z 0 ~ :E :::0 -I' m - z ~ ,:J: en :Þ :xl f m » Y N Y N Comments/Instructions: '117/67 c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ~( Well H ¡story File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. , To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically . . organize this category of information. ~' :( Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Feb 12 08:09:21 2002 Reel Header Service name. . . . . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 02 / 12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Tape Header Service name. . . . . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 02 / 12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. ~~\.þ: J lJJ 3 ' 'I' ( Scientific Technical Services Writing Library. Scientific Technical Services 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: MWDRUN 1 AK-MM-11164 T. GALVIN D. FERGUSON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 4 AK-MM-11164 D. LABRECQUE J. PYRONE # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) MPI-12 PB1 500292303870 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 12-FEB-02 MWDRUN 2 AK-MM-11164 D. LABRECQUE J. PYRONE MWD RUN 6 AK-MM-11164 T. GALVIN J. PYRONE 33 13N 10E 2345 3996 63.40 34.70 MWD RUN 3 AK-MM-11164 D. LABRECQUE J. PYRONE ( f # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 13.500 9.875 6.125 CASING SIZE (IN) 20.000 10.750 7.000 DRILLERS DEPTH (FT) 108.0 2906.0 10342.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3 . MWD RUNS 1 - 6 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 2 - 6 INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUNS 5 & 6 ALSO INCLUDED AT-BIT INCLINATION (ABI). 4. THERE IS AN UNEXPLAINED SROP DATA GAP FROM 9566.5'MD TO 9659.5'TVD. 5. MWD RUN 5 WAS TERMINATED AFTER DRILLING ONLY 4 FEET, DUE TO MWD FAILURE. THE ONLY USEABLE CURVE DATA WERE SROP, WHICH WERE MERGED INTO THE TOP OF MWD RUN 6. 6. DUE TO WELL-CONTROL PROBLEMS, WHICH RESULTED IN THE LOSS OF THE BHA, ONLY REAL-TIME DATA ARE AVAILABLE FOR MWD RUN 6. FOR EWR4 THIS INCLUDES SESP, SEDP, AND SFXE ONLY. 7. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D.SCHNORR (GEOQUEST/BP), DATED 2/05/02. MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1-6 REPRESENT WELL MPI-12 PB1 WITH API#: 50-029- 23038-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13243'MD/ 3679'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. SLIDE = NON-ROTATED INTERVALS $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/12 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE ROP FET RPD RPM RPS RPX GR $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 108.5 244.5 244.5 244.5 244.5 244.5 252.5 STOP DEPTH 13243.0 13176.0 13176.0 10294.5 13176.0 10294.5 13169.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ---- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 108.5 2916.0 MWD 2 2916.0 2966.0 MWD 3 2966.0 5598.0 MWD 4 5598.0 10355.0 MWD 6 10355.0 13243.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 ( (" RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 108.5 13243 6675.75 26270 108.5 13243 ROP MWD FT/H 0.02 2592.55 323.956 26083 108.5 13243 GR MWD API 6.39 453.55 70.2024 25763 252.5 13169 RPX MWD OHMM 0.42 2000 14.0001 20101 244.5 10294.5 RPS MWD OHMM 0.3 2000 18.3956 25774 244.5 13176 RPM MWD OHMM 0.2 2000 19.7171 20101 244.5 10294.5 RPD MWD OHMM 0.06 2000 32.4667 25774 244.5 13176 FET MWD HOUR 0.0464 138.127 1.82268 25774 244.5 13176 First Reading For Entire File......... .108.5 Last Reading For Entire File.......... .13243 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/12 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...... .02/02/12 Maximum Physical Record. .65535 File Type.... . . . . . . . . . . . .LO Previous File Name...... .STSLIB.001 Cormnent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP RPM RPS RPD FET RPX GR $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 108.5 244.5 244.5 244.5 244.5 244.5 252.5 STOP DEPTH 2916.0 2857.5 2857.5 2857.5 2857.5 2857.5 2865.5 # LOG HEADER DATA ( DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O t' 09-0CT-Ol Insite 66.16 Memory 2916.0 108.0 2916.0 .6 78.4 TOOL NUMBER PB02220HRGF8 PB02220HRGF8 13.500 2906.0 SPUD MUD 9.30 104.0 8.8 900 21.0 5.100 5.358 4.500 6.000 68.0 64.4 68.0 68.0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 ( { RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 108.5 2916 1512.25 5616 108.5 2916 ROP MWD010 FT/H 6.55 423.23 147.332 5616 108.5 2916 GR MWD010 API 22.92 117.43 67.9103 5227 252.5 2865.5 RPX MWD010 OHMM 0.42 70.22 20.1148 5227 244.5 2857.5 RPS MWD010 OHMM 0.3 115.97 26.9317 5227 244.5 2857.5 RPM MWD010 OHMM 0.2 2000 36.6016 5227 244.5 2857.5 RPD MWD010 OHMM 0.22 2000 39.5505 5227 244.5 2857.5 FET MWD010 HOUR 0.2011 6.1981 0.760783 5227 244.5 2857.5 First Reading For Entire File......... .108.5 Last Reading For Entire File.......... .2916 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/12 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...... .02/02/12 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPS RPX FET RPD GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2858.0 2858.0 2858.0 2858.0 2858.0 2866.0 2916.5 STOP DEPTH 2905.5 2905.5 2905.5 2905.5 2905.5 2912.5 2966.0 # LOG HEADER DATA DATE LOGGED: 12-0CT-01 (, SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O (' Insite 66.16 Memory 2966.0 2916.0 2966.0 .0 .0 TOOL NUMBER PB02219HWRGVF6 PB02219HWRGVF6 9.875 LSND 9.10 50.0 9.6 700 7.4 3.600 3.984 3.900 3.100 70.0 62.6 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 ( RPD MWD020 FET MWD020 OHMM HOUR 4 4 (I 1 68 1 68 24 28 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2858 2966 2912 217 2858 2966 ROP MWD020 FT/H 39.55 379.42 212.258 100 2916.5 2966 GR MWD020 API 19.52 47.64 31.4535 94 2866 2912.5 RPX MWD020 OHMM 1.15 5.19 3.05896 96 2858 2905.5 RPS MWD020 OHMM 1.36 7.78 4.37823 96 2858 2905.5 RPM MWD020 OHMM 0.89 2000 139.398 96 2858 2905.5 RPD MWD020 OHMM 0.06 2000 800.795 96 2858 2905.5 FET MWD020 HOUR 67.3532 69.6253 68.7437 96 2858 2905.5 First Reading For Entire File......... .2858 Last Reading For Entire File.......... .2966 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/12 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...... .02/02/12 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 2906.0 2906.0 2906.0 2906.0 2906.0 2913.0 2966.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE STOP DEPTH 5538.0 5538.0 5538.0 5538.0 5538.0 5544.5 5598.0 14-0CT-01 ( SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ( Insite 66.16 Memory 5598.0 2966.0 5598.0 77.7 83.2 TOOL NUMBER PB02219HWRGVF6 PB02219HWRGVF6 9.875 LSND 9.20 45.0 12.0 1700 6.8 1.940 1.778 1.910 1.900 70.0 77.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 ( (" FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2906 5598 4252 5385 2906 5598 ROP MWD030 FT/H 0.02 1901.47 454.642 5264 2966.5 5598 GR MWD030 API 6.39 135.2 65.5357 5264 2913 5544.5 RPX MWD030 OHMM 1.01 2000 12.9 5265 2906 5538 RPS MWD030 OHMM 1.27 2000 15.0344 5265 2906 5538 RPM MWD030 OHMM 0.28 2000 14.5084 5265 2906 5538 RPD MWD030 OHMM 1.92 2000 18.0666 5265 2906 5538 FET MWD030 HOUR 0.055 96.3817 1.51904 5265 2906 5538 First Reading For Entire File......... .2906 Last Reading For Entire File.......... .5598 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/12 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPS RPX RPM RPD FET GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 5538.5 5538.5 5538.5 5538.5 5538.5 5545.0 5598.5 STOP DEPTH 10294.5 10294.5 10294.5 10294.5 10294.5 10301.5 10355.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE 16-0CT-01 VERSION: Insite (' DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O f 66.16 Memory 10355.0 5598.0 10355.0 76.5 85.5 TOOL NUMBER PB02219HWRGVF6 PB02219HWRGVF6 9.875 10342.0 LSND 9.20 48.0 9.8 1200 .0 1.990 1.475 1.930 1.960 70.0 96.8 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 (' First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5538.5 10355 7946.75 9634 5538.5 10355 ROP MWD040 FT/H 9.86 2592.55 432.913 9327 5598.5 10355 GR MWD040 API 21.4 130.39 71.3503 9514 5545 10301.5 RPX MWD040 OHMM 5.16 56.61 11.3596 9513 5538.5 10294.5 RPS MWD040 OHMM 5.29 55.82 11.7325 9513 5538.5 10294.5 RPM MWD040 OHMM 5.53 56.38 12.1148 9513 5538.5 10294.5 RPD MWD040 OHMM 5.98 55.32 12.6695 9513 5538.5 10294.5 FET MWD040 HOUR 0.0464 14.3842 0.758262 9513 5538.5 10294.5 First Reading For Entire File......... .5538.5 Last Reading For Entire File.......... .10355 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/12 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/12 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPS FET GR ROP $ 6 header data for each bit run in separate files. 6 .5000 START DEPTH 10295.0 10295.0 10295.0 10302.0 10355.5 STOP DEPTH 13176.0 13176.0 13176.0 13169 . 0 13243.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : 23-0CT-01 Insite 66.16 Memory 13243.0 (, TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 10355.0 13243.0 83.8 94.6 ( TOOL NUMBER 2208HA4/2205GR4 2208HA4/2205GR4 6.125 LSND 9.20 46.0 8.1 25000 7.2 .190 .153 .160 .430 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPD MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 Name Service Unit Min Max Mean Nsam 68.0 86.0 68.0 68.0 First Reading Last Reading ( ( DEPT FT 10295 13243 11769 5897 10295 13243 ROP MWD060 FT/H 1.86 706.83 202.576 5776 10355.5 13243 GR MWD060 API 32.58 453.55 75.3696 5664 10302 13169 RPS MWD060 OHMM 0.41 2000 25.0606 5673 10295 13176 RPD MWD060 OHMM 0.21 2000 59.5001 5673 10295 13176 FET MWD060 HOUR 0.3303 138.127 3.73534 5673 10295 13176 First Reading For Entire File......... .10295 Last Reading For Entire File.......... .13243 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/12 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02/02 / 12 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. . . . . . . . . . . . . . . . . . . . .02/02/12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File (' Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Feb 13 13:42:22 2002 Reel Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02/02/13 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Tape Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/02/13 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. (: ::\,'1" " I .OOI"I"".XI',~~,¡Jr ;",;~ .."f~'!!~I':!:I'ifl);v'" Scientific Technical Services Writing Library. Scientific Technical Services 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: MWDRUN 1 AK-MM-11164 T. GALVIN D. FERGUSON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 4 AK-MM-11164 D. LABRECQUE J. PYRONE # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL:' MSL 0) MPI-12 500292303800 BP Exploration (Alaska), Inc Sperry-Sun Drilling Services 13-FEB-02 MWDRUN 2 AK-MM-11164 D. LABRECQUE J. PYRONE MWDRUN 8 AK-MM-11164 D. LABRECQUE D. FERGUSON 33 13N 10E 2345 3996 63.40 34.70 MWDRUN 3 AK-MM-11164 D. LABRECQUE J. PYRONE ( ( # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 13.500 9.875 6.125 CASING SIZE (IN) 20.000 10.750 7.000 DRILLERS DEPTH (FT) 108.0 2906.0 10228.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL SEGMENT WAS KICKED-OFF FROM A WHIPSTOCK IN THE MPI-12 PB1 WELL BORE AT 10228'MD/3706'TVD (TOP). THE LOWERMOST SECTION OF THE ORIGINAL WELL BORE HAD BEEN PLUGGED AND ABANDONED DUE TO WELL-CONTROL PROBLEMS. 4. MWD RUNS 1 - 4 (MPI-12 PB1) AND 8 (MPI-12) WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 2 - 4 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). ROP DATA FROM MWD RUN 7 (WHIPSTOCK/MILL RUN) WERE ADDED TO THE TOP OF MWD RUN 8. 5. THERE IS AN UNEXPLAINED ROP DATA GAP FROM 9566.5'MD TO 9659.5'MD. 6. DEPTH SHIFTING/CORRECTION OF E-MAIL FROM D.SCHNORR (GEOQUEST/BP) DATED 2/05/02. MWD DATA ARE CONSIDERED PDC. MWD DATA WAS WAIVED PER TO R. KALISH (SSDS), 7. MWD RUNS 1-4, 8 REPRESENT WELL MPI-12 WITH API#: 50-029-23038-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12470'MD/3712'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. SLIDE = NON-ROTATED INTERVALS $ File Header Service name............ .STSLIB.001 (' ~" Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/13 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE ROP FET RPD RPM RPS RPX GR $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 108.5 244.5 244.5 244.5 244.5 244.5 252.5 STOP DEPTH 12470.0 12413.0 12413.0 12413.0 12413.0 12413.0 12406.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ---- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 108.5 2916.0 MWD 2 2916.0 2966.0 MWD 3 2966.0 5598.0 MWD 4 5598.0 10228.0 MWD 8 10228.5 12470.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 (' t, First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 108.5 12470 6289.25 24724 108.5 12470 ROP MWD FT/H 0.02 2592.55 328.044 24537 108.5 12470 GR MWD API 6.39 136.2 70.2335 24308 252.5 12406 RPX MWD OHMM 0.11 2000 14.9017 24338 244.5 12413 RPS MWD OHMM 0.3 2000 17.4153 24338 244.5 12413 RPM MWD OHMM 0.2 2000 21.4777 24338 244.5 12413 RPD MWD OHMM 0.06 2000 25.6373 24338 244.5 12413 FET MWD HOUR 0.05 434.283 1.68268 24338 244.5 12413 First Reading For Entire File......... .108.5 Last Reading For Entire File.......... .12470 File Trailer Service name............ .STSLIB.001 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .02/02/13 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...... .02/02/13 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP RPM RPS RPD FET RPX GR $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 108.5 244.5 244.5 244.5 244.5 244.5 252.5 STOP DEPTH 2916.0 2857.5 2857.5 2857.5 2857.5 2857.5 2865.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 09-0CT-01 Insite 66.16 Memory ( TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O { 2916.0 108.0 2916.0 .6 78.4 TOOL NUMBER PB02220HRGF8 PB02220HRGF8 13.500 SPUD MUD 9.30 104.0 8.8 900 21.0 5.100 5.358 4.500 6.000 68.0 64.4 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 i( Name Service Unit Min DEPT FT 108.5 ROP MWD010 FT/H 6.55 GR MWD010 API 22.92 RPX MWD010 OHMM 0.42 RPS MWD010 OHMM 0.3 RPM MWD010 OHMM 0.2 RPD MWD010 OHMM 0.22 FET MWD010 HOUR 0.2 (' First Last Max Mean Nsam Reading Reading 2916 1512.25 5616 108.5 2916 423.23 147.332 5616 108.5 2916 117.43 67.9103 5227 252.5 2865.5 70.22 20.1148 5227 244.5 2857.5 115.97 26.9317 5227 244.5 2857.5 2000 36.6016 5227 244.5 2857.5 2000 39.5505 5227 244.5 2857.5 6.2 0.760729 5227 244.5 2857.5 First Reading For Entire File....:.... .108.5 Last Reading For Entire File.......... .2916 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/13 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...... .02/02/13 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPS RPX FET RPD GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2858.0 2858.0 2858.0 2858.0 2858.0 2866.0 2916.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : STOP DEPTH 2905.5 2905.5 2905.5 2905.5 2905.5 2912.5 2966.0 12-0CT-01 Insite 66.16 Memory 2966.0 (' TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O (' 2916.0 2966.0 .0 .0 TOOL NUMBER PB02219HWRGVF6 PB02219HWRGVF6 9.875 LSND 9.10 50.0 9.6 700 7.4 3.600 3.984 3.900 3.100 70.0 62.6 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 ( ( ( First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2858 2966 2912 217 2858 2966 ROP MWD020 FT/H 39.55 379.42 212.258 100 2916.5 2966 GR MWD020 API 19.52 47.64 31.4535 94 2866 2912.5 RPX MWD020 OHMM 1.15 5.19 3.05896 96 2858 2905.5 RPS MWD020 OHMM 1.36 7.78 4.37823 96 2858 2905.5 RPM MWD020 OHMM 0.89 2000 139.398 96 2858 2905.5 RPD MWD020 OHMM 0.06 2000 800.795 96 2858 2905.5 FET MWD020 HOUR 67.35 69.63 68.7444 96 2858 2905.5 First Reading For Entire File......... .2858 Last Reading For Entire File.......... .2966 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/02/13 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...... .02/02/13 Maximum Physical Record. .65535 File Type... . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 2906.0 2906.0 2906.0 2906.0 2906.0 2913.0 2966.5 STOP DEPTH 5538.0 5538.0 5538.0 5538.0 5538.0 5551.0 5598.0 # 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): 14-0CT-01 Insite 66.16 Memory 5598.0 2966.0 ( BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 5598.0 77.7 83.2 TOOL NUMBER PB02219HWRGVF6 PB02219HWRGVF6 9.875 LSND 9.20 45.0 12.0 1700 6.8 1.940 1.778 1.910 1.900 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 ( 70.0 77.0 70.0 70.0 First Last ( " ( Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2906 5598 4252 5385 2906 5598 ROP MWD030 FT/H 0.02 1901.47 454.642 5264 2966.5 5598 GR MWD030 API 6.39 135.2 65.5069 5277 2913 5551 RPX MWD030 OHMM 1.01 2000 12.9 5265 2906 5538 RPS MWD030 OHMM 1.27 2000 15.0344 5265 2906 5538 RPM MWD030 OHMM 0.28 2000 14.5084 5265 2906 5538 RPD MWD030 OHMM 1.92 2000 18.0666 5265 2906 5538 FET MWD030 HOUR 0.05 96.38 1.51905 5265 2906 5538 First Reading For Entire File......... .2906 Last Reading For Entire File.......... .5598 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/13 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/13 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPS RPD FET RPX GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 5538.5 5538.5 5538.5 5538.5 5538.5 5551.5 5598.5 STOP DEPTH 10228.0 10228.0 10228.0 10228.0 10228.0 10228.0 10228.0 # 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): 16-0CT-01 Insite 66.16 Memory 10355.0 5598.0 10228.0 ( BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 76.5 85.5 TOOL NUMBER PB02219HWRGVF6 PB02219HWRGVF6 9.875 LSND 9.20 48.0 9.8 1200 .0 1.990 1.475 1.930 1.960 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 ,1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam ( 70.0 96.8 70.0 70.0 First Reading Last Reading ( ( DEPT FT 5538.5 10228 7883.25 9380 5538.5 10228 ROP MWD040 FT/H 9.86 2592.55 438.572 9073 5598.5 10228 GR MWD040 API 21.4 130.39 71.0209 9354 5551.5 10228 RPX MWD040 OHMM 5.16 56.61 11.3938 9380 5538.5 10228 RPS MWD040 OHMM 5.29 55.82 11.7643 9380 5538.5 10228 RPM MWD040 OHMM 5.53 56.38 12.1356 9380 5538.5 10228 RPD MWD040 OHMM 5.98 55.32 12.6817 9380 5538.5 10228 FET MWD040 HOUR 0.05 14.38 0.762886 9380 5538.5 10228 First Reading For Entire File......... .5538.5 Last Reading For Entire File.......... .10228 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/13 Maximum Physical Record. .65535 File Type..... . . . . . . . . . . .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/13 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER' FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR ROP FET $ 6 header data for each bit run in separate files. 8 .5000 START DEPTH 10228.5 10228.5 10228.5 10228.5 10228.5 10228.5 10228.5 STOP DEPTH 12413.0 12413.0 12413.0 12413.0 12406.0 12470.0 12413.0 # 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): 05-NOV-Ol Insite 66.16 Memory 12470.0 10228.0 12470.0 f HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 86.4 92.8 TOOL NUMBER 2248HA4/2240GRV 2248HA4/2240GRV 6.125 KCl polymer 9.20 50.0 8.5 28000 5.8 .280 .269 .300 .320 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 Name Service Unit DEPT FT Min 10228.5 Max 12470 Mean Nsam 11349.3 4484 (" 79.0 82.4 79.0 79.0 First Reading 10228.5 Last Reading 12470 ( ( ROP MWD080 FT/H 0.23 1473.37 184.697 4484 10228.5 12470 GR MWD080 API 43.62 136.2 77.8931 4356 10228.5 12406 RPX MWD080 OHMM 0.11 1716.84 18.8679 4370 10228.5 12413 RPS MWD080 OHMM 0.4 1716.78 21.3173 4370 10228.5 12413 RPM MWD080 OHMM 0.57 2000 29.2465 4370 10228.5 12413 RPD MWD080 OHMM 1.21 2000 28.8967 4370 10228.5 12413 FET MWD080 HOUR 0.3212 434.283 3.48368 4370 10228.5 12413 First Reading For Entire File......... .10228.5 Last Reading For Entire File.......... .12470 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/13 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Date.....................02/02/13 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. . . . . . . . . . . . . . . . . . . . .02/02/13 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File