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200-176
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 6, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC F-84B MILNE PT UNIT F-84B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/06/2023 F-84B 50-029-22931-02-00 200-176-0 W SPT 6680 2001760 1670 2145 2146 2146 2146 425 512 512 512 4YRTST P Bob Noble 3/11/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT F-84B Inspection Date: Tubing OA Packer Depth 1022 2920 2894 2888IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN230312124330 BBL Pumped:2.1 BBL Returned:2 Thursday, April 6, 2023 Page 1 of 1 Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/04/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-84B (PTD 200-176) Injection Profile 09/28/2020 Please include current contact information if different from above. Received by the AOGCC 12/04/2020 PTD: 2001760 E-Set: 34360 Abby Bell 12/09/2020 MEMORANDUM TO: Jim Regg �7 P.I. Supervisor 11 FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, March 22, 2019 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC F -84B MILNE PT UNIT F -84B Ste: Inspector Reviewed By: P.I. Sup"L Comm Well Name MILNE PT UNIT F -84B API Well Number 50-029-22931-02-00 Inspector Name: Lou Laubenstein Insp Num: mid-01,190316160715Permit Number: 200-176-0 Inspection Date: 3/16/2019 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1-8413 - Type Inj w TVD 6680 "Tubing 2262 szez -i1- 2262 2262 PTD 2001760-TypeTest SNr Testpsi i670 IA 926 1759 1750 1748 — — BBL Pumped: i BBL Returned: i - OA 268 292 298 - 294 Interval 4YRTsr P/F Notes: Friday, March 22, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,April 01,2015 TO: Jim Regg l .z/ 6165 P.I.Supervisor ( ` SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC F-84B FROM: John Crisp MILNE PT UNIT KR F-84B Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry-J -- NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR F-84B API Well Number 50-029-22931-02-00 Inspector Name: John Crisp Permit Number: 200-176-0 Inspection Date: 3/19/2015 Insp Num: mitJCr150325123656 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well i F-84B !Type Inj W !TVD ! 6680 -1 Tubing 920 7 920- T 920 920 . — — — PTD'- 2001760 !Type Test SPT Test psi! 1670 - IA 228 2029 - i 2001 - 1996 — Interval- !OTR P/F P Fr OA 270 350 - 350 I 350 ' Notes: 2 bbls pumped for test Returned to injection after LTSI. SCANNED 4 "r.. Wednesday,April 01,2015 Page 1 of 1 Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, March 17, 2015 8:43 AM To: Wallace, Chris D (DOA); Alaska NS - Milne - Field Foreman; Alaska NS - Milne -Wellsite Supervisors Cc: Chris Kanyer; Regg, James B (DOA) Subject: Injector MPF-84B (PTD # 2001760) Ready For Injection Attachments: image001 jpg; image003 jpg All, Injector MPF-84B (PTD#2001760) had a passing pre MIT-IA on 3/16/15. Well was shut-in and not available for testing prior to its AOGCC MIT-IA anniversary date. Well is ready to return to injection for stabilization and compliance testing. Plan Forward—Operations 1) Place well on injection. Use caution,annuli are fluid packed. 2) AOGCC MIT-IA when well is on injection and thermally stable. Thank You, Wyatt Rivard Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED MAR 1 8 2015 lliiww A1a4a,IAA Wt. From: Wyatt Rivard Sent: Monday, March 09, 2015 1:27 PM To: 'Wallace, Chris D (DOA)'; Alaska NS - Milne - Field Foreman; Alaska NS - Milne - Wellsite Supervisors Cc: Chris Kanyer; 'jim.regg@alaska.gov' Subject: Injector MPF-84B (PTD # 2001760) Due for AOGCCC MIT-IA All, Injector MPF-84B (PTD# 2001760) is due for an AOGCC MIT-IA on 3/12/2015.The well will not be brought online in time for the test.The well will be added to the Quarterly Long Term Shut-in Injector Report until it is ready to return to injection for stabilization and compliance testing. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 1 Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, March 09, 2015 1:27 PM To: Wallace, Chris D (DOA); Alaska NS - Milne - Field Foreman; Alaska NS - Milne - Wellsite Supervisors Cc: Chris Kanyer; Regg,James B (DOA) Subject: Injector MPF-84B (PTD# 2001760) Due for AOGCCC MIT-IA Attachments: image002 jpg All, Injector MPF-84B (PTD#2001760) is due for an AOGCC MIT-IA on 3/12/2015.The well will not be brought online in time for the test.The well will be added to the Quarterly Long Term Shut-in Injector Report until it is ready to return to injection for stabilization and compliance testing. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Ilikorp .%h*i I a. ILIA. 1 STATE OF ALASKA SEP 2 8 2012 AKA OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate 11 Other U BrightWater Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Wee 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑ Exploratory ❑ " 200 -176 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service 0 6. API Number: r Anchorage, AK 99519 -6612 50- 029 - 22931 -02 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0388235 MPF -84B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): . To Be Submitted MILNE POINT, KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 11980 feet Plugs measured None feet true vertical 7150.76 feet Junk measured None feet Effective Depth measured 11875 feet Packer measured 11490 feet true vertical 7049.39 feet true vertical 6679.57 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 82 20" 91.5# H-40 27 - 109 27 - 109 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 11933 7" 26# L -80 25 - 11958 25 - 7129.52 7240 5410 Liner None None None None None None Perforation depth Measured depth 11696 - 11712 feet 11720 - 11730 feet 11738 - 11758 feet 11769 - 11774 feet True Vertical depth 6876.99 - 6892.35 feet 6900.04 - 6909.65 feet 6917.34 - 6936.58 feet 6947.17 - 6951.99 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 25 - 11525 _ - 6713.05 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Perm Ps 11490 6679.57 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11696' - 11712'; 11720' 11730'; 11738' - 11758'; 11769' - 11774' SCANNED JAN 2 3 2 Treatment descriptions including volumes used and final pressure: 3,030 Gallons EC9360A Surfactant; 13,991 Gallons EC9398A Polymer 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 2700 0 977 Subsequent to operation: 0 0 3278 0 1479 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service -' Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: U q Oil U Gas U WDSPL GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature )J Ca Phone 564 -4424 Date 9/25/2012 I ��I v MS SEP 2 8112Cr(l 1,0)) o I r Form 10 -404 Revised 11/2011 Submit Original Only Casing / Tubing Attachment ADLO388235 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 20" 91.5# H -40 27 - 109 27 - 109 1490 470 PRODUCTION 11933 7" 26# L -80 25 - 11958 25 - 7129.52 7240 5410 SURFACE 151 9 -5/8" 47# L -80 32 - 183 32 - 183 6870 4760 SURFACE 5647 9 -5/8" 40# L -80 183 - 5830 183 - 4282.75 5750 3090 TUBING 11500 4 -1/2" 12.6# L -80 25 - 11525 25 - 6713.05 8430 7500 • Daily Report of Well Operations ADL0388235 _...__ T /T /Zf 1 �00/ Temp= o rig a er eser weep o Pumping brightwater chemicals down TBG while on water injection © 3300 bwpd. Pumped 323 gal. EC9360A (Surfactant) Average of 17.9 gph for 18 hrs. Pumped a total of 323 gal. since start of project. Pumped 1157 gal. EC9398A ( Polymer) Average of 64.2 gph for 18 hrs. Pumped a total of 1157 gal. since start of project. 8/20/2012 ** *Continued on WSR 08- 21- 2012 * ** T /I /O = 1283/600/360 ** *Continued WSR from 08 -20- 2012 * ** Temp =Hot (Brightwater • Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection © 3300 bwpd. Pumped 364 gal. EC9360A (Surfactant) Average of 15.16 gph for 24 hrs. Pumped a total of 687 gal. since start of project. Pumped 1555 gal. EC9398A ( Polymer) Average of 64.79 gph for 24 hrs. Pumped a total of 2712 gal. since start of project. 8/21/2012 ** *Continued on WSR 08 -22- 2012 * ** T /I /O = 1339/600/360 ** *Continued WSR from 08 -21- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 3300 bwpd. Pumped 342 gal. EC9360A (Surfactant) Average of 14.25 gph for 24 hrs. Pumped a total of 1029 gal. since start of project. Pumped 1552 gal. EC9398A ( Polymer) Average of 64.66 gph for 24 hrs. Pumped a total of 4264 gal. since start of project • 8/22/2012 ** *Continued on WSR 08/23/2012 * ** T/I/0 = 136 /7600 /360 * *continued WSR from 08 -22- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection © 3300 bwpd. Pumped 301 gal. EC9360A (Surfactant) Average of 12.5 gph for 24 hrs. Pumped a total of 1330 gal. since start of project. Pumped 1514 gal. EC9398A ( Polymer) Average of 63.08 gph for 24 hrs. Pumped a total of 5778 gal. since start of project 8/23/2012 ** *Continued on WSR 08/24/2012 * ** Daily Report of Well Operations ADL0388235 T /I /O = 1436/600/360 ** *Continued WSR from 08 -23- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 3300 bwpd. Pumped 329 gal. EC9360A (Surfactant) Average of 13.7 gph for 24 hrs. Pumped a total of 1659 gal. since start of project. Pumped 1465 gal. EC9398A ( Polymer) Average of 61.04 gph for 24 hrs. Pumped a total of 7243 gal. since start of project 8/24/2012 ** *Continued on WSR 08/25/2012 * ** ?/1/0 = 1472/600/340 ** *Continued WSR from 08 -24- 2012 * ** Temp =Hot ( Brightwater • Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 3300 bwpd. Pumped 327 gal. EC9360A (Surfactant) Average of 13.625 gph for 24 hrs. Pumped a total of 1986 gal. since start of project. Pumped 1516 gal. EC9398A ( Polymer) Average of 63.16 gph for 24 hrs. Pumped a total of 8759 gal. since start of project 8/25/2012 ** *Continued on WSR 08/26/2012 * ** ?/I/O = 1499/600/340 ** *Continued WSR from 08 -25- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 3300 bwpd. Pumped 306 gal. EC9360A (Surfactant) Average of 12.75 gph for 24 hrs. Pumped a total of 2292 gal. since start of project. Pumped 1596 gal. EC9398A ( Polymer) Average of 66.5 gph for 24 hrs. Pumped a total of 10355 gal. since start of project 8/26/2012 ** *Continued on WSR 08/27/2012 * ** ?/I /O = 1527/600/340 ** *Continued WSR from 08 -26- 2012 * ** temp =Hot ( Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 3300 bwpd. Pumped 299 gal. EC9360A (Surfactant) Average of 12.45 gph for 24 hrs. Pumped a total of 2591 gal. since start of project. Pumped 1471 gal. EC9398A ( Polymer) Average of 61.29 gph for 24 hrs. Pumped a total of 11826 gal. since start of project 8/27/2012 ** *Continued on WSR 08/28/2012 * ** Daily Report of Well Operations ADL0388235 T /I /O = 1548/600/340 ** *Continued WSR from 08 -27- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection © 3300 bwpd. Pumped 302 gal. EC9360A (Surfactant) Average of 12.5 gph for 24 hrs. Pumped a total of 2893 gal. since start of project. Pumped 1501 gal. EC9398A ( Polymer) Average of 62.5 gph for 24 hrs. Pumped a total of 13327 gal. since start of project 8/28/2012 ** *Continued on WSR 08/29/2012 * ** T /I /O = 1582/600/300 ** *Continued WSR from 08 -28- 2012 * ** Temp =Hot (Brightwater • Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 3300 bwpd. Pumped 137 gal. EC9360A (Surfactant) Average of 13.04 gph for 10.5 hrs. Pumped a total of 3030 gal. since start of project. Pumped 664 gal. EC9398A ( Polymer) Average of 66.4 gph for 10 hrs. Pumped a total of 13991 gal. since start of project. Pumped 220 total hrs since start of project. 8/29/2012 FWHP= 1590/600/300 ** *Well injecting on departure * ** • • • Tree: Cameron 4.1/16", 5M QQ /� Orig. DF Elev. = 44.08 (N 27E) Wellhead: FMC 11" x 7-1/16" 5M, M P U F - Orig. GL Elev. = 11.90' Gen. 5a w/ 6" x 4.5" FMC Tbg. Hnr. ' RT To Tbg. Spool = (N 27E) w/ 4.5" nsct threads top and btm. 4" CIW H BPV profile NOTE: Well requires the installation of a SSSV during the next RWO. 20" 91.1 ppf, H -40 112' KOP @ 400 to 4,200' ' O Max. hole angle = 75 deg. 70 - 75 deg. 6,000' - 9,800' 9 5/8" Howco `ES' Hole angle thru' perfs = 17 deg. Cementei 2111' and 9 5/8 ", 40 / 47 ppf, L -80 Btrc. 5,833' ` 40# 4,186'-5,833' / 47#4,186'- 35' Well was side tracked 12/20/00 see old diagram for old btm. hole location, kickoff @ 5851' wlm is 7" 26 ppf, L -80, BTC -mod casing ( drift ID = 6.276 ", cap. = 0.0383 bpf ) 4.5" 12.6 # /ft , L -80 NSCT prod. tbg. ( drift ID = 3.958 ", cap. = 0.0152 bpf 4.5" HES X- Nipple 11,469' Perforation Summary 4.5" Baker S 3 Perm. Pkr. 11,490' Ref log : SWS USIT dated 12/18/00 MI I Size spf Interval (TVD) 1 11 4.5 "HES XN Nipple ( 3.725 id ) 2-7/8' 4 11,696'- 11,712' 6,876'- 6,891' 4.5 "WLEG 11,526' 2 -7/8" 4 11,720'- 11,730' 6,899'- 6,908' ELMD 11,532' 2 -7/8' 4 11,738' - 11,758' 6,916'- 6,935' W/L tag after CTU / FCO 2.7/8"" 4 11,769'- 11,774' 6,947'- 6,951' @ win. 7" float collar 11,874' k 7" float shoe 11,961' DATE REV. BY COMMENTS 12/11/98 MDO Cased hole & ESP completion 27E MILNE POINT UNIT WELL No.: F - 84i 03/20/99 MDO Convert injector 4es / 7/4/00 sidetrack API : 50 - 029 - 22931 - 12/23/00 MDO Sidetrack Injector Doyon 141 • BP EXPLORATION (AK) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 IUD FEB 2' L ��� Mr. Tom Maunder ' 76 Alaska Oil and Gas Conservation Commission Doo 333 West 7 Avenue ( 4 5 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -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 • 1111 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF -02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF-05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF -34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF -45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -61 1951170 50029225820000 62 Need top job MPF -62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF -69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF-81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF-83 2000930 50029229630000 1.2 N/A 1.2 N/A 13.6 8/3/2011 ----}' MPF -84B 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF-86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 s • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim R e-5Z - 5( DATE: Monday, March 14, 2011 gg P.I. Supervisor ( l it SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC F -84B FROM: Jeff Jones MILNE PT UNIT KR F -84B Petroleum Inspector Src: Inspector Reviewed B P.I. Supry NON - CONFIDENTIAL Comm Well Name: MILNE PT UNIT KR F - 84B — API Well Number: 50 029 - 22931 - 02 - 00 Inspector Name: Jeff Jones Insp Num: mitJJ110314073346 Permit Number: 200 - 176 - Inspection Date: 3/12/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well F -84B -' Type Inj. W TVD 6680 . 1 IA _ 320 2020 2000 2000 P.T.D1 2001760 ' TypeTest SPT Test psi 1670 _1 OA , 230 430 430 430 Interval 4YRTST P/F P Tubing 1500 1500 1500 1500 Notes: 1.5 BBLS diesel pumped. 1 well inspected; no exceptions noted. 4.0 as W MAR 0 1E Monday, March 14, 2011 Page 1 of 1 F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ~ Abandon 0 SuspendD Operation Shutdown 0 Perforate 0 WaiverD Otherl.J:::j" Alter CasingD Repair WellD Plug PerforationsO Stimulate D Time ExtensionD Change Approved ProgramD Pull TubingD Perforate New Pool 0 Re-enter Suspended Well 0 Atb'1ll~ 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 200-1760 Development 0 ExploratoryD 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 Service ŒJ 50-029-22931-02-00 7. KB Elevation (ft): 9. Well Name and Number: 41.40 MPF-84B 8. Property Designation: 10. Field/Pool(s): ADL-388235 Kuparuk River Field I Kuparuk River Oil Pool, Milne Point Unit 11. Present Well Condition Summary: Total Depth measured 11980 feet true vertical 7150.8 feet Plugs (measured) None Effective Depth measured 11875 feet Junk (measured) None true vertical 7049.4 feet Casing Length Size MD TVD Burst Collapse Conductor 82 20" 91.5# H-40 30 - 112 30.0 - 112.0 1490 470 Production 11933 7" 26# L-80 28 - 11961 28.0 - 7132.4 7240 5410 Surface 151 9-5/8" 47# L-80 35 - 186 35.0 - 186.0 6870 4760 Surface 5647 9-5/8" 40# L-80 186 - 5833 186.0 - 4284.2 5750 3090 Perforation depth: Measured depth: 11696 -11712,11720 -11730,11738 -11758,11769 -11774 RECEIVED True vertical depth: 6876.99 - 6892.35,6900.04 - 6909.65,6917.34 - 6936.58,6947.17 - 6951.99 JAN 2 0 2004 Tubing (size, grade, and measured depth): 4-112" 12.6# L-80 @ 25 - 11525 Alaska Oil & Gas Cons. Commission Packers & SSSV (type & measured depth): 4-112" Baker S-3 Perm Packer @ 11490 Anchorage 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 RePresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure TubinQ Pressure Prior to well operation: 0 0 3777 50 3130 Subsequent to operation: 0 0 4026 85 2916 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD Service ]] Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D OilO GasD WAG ŒI GINJD WINJD WDSPLD Daily Report of Well Operations. ~ Prepared by Garry Catron (907) 564-4657. 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 Garry Catron NI A Printed Name Garry Catron Title Production Technical Assistant Signature]3 . ~ . Phone 564-4657 Date 1/15/04 <;;;:.rr' ~\ 1:,JII",lllcJi'i II g ~I'I 6» 1 tJryOð. ~;-.?)~tr'~l~~B~!k~'J ",ßHli~ &,9 l_~ . 1j N A L Form 10-404 Revised 12/2003 0 R \ G \ R8DMS BFL JAN 2 1 2ßO~ ( ( M PF-848 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/24/03 MIRU OS CTU #9. RIH w/2.5" JSN taking returns to MPF-81 and to return tanks. Tagged TD at 117601 CTMD. PUH. Shut in returns and establish injection. Initial injection 1.0 bpm @ 1760 psig WHP. 08/24/03 Shut in returns and establish injection. Initial injection 1.0 bpm @ 1760 psig WHP. Pump 20 bbls 7.5% DAD acid jetting/injecting from 11680' to 117601. Flushed to perfs. Found hard crust at 117601. Pump 20 bbls 7.5% DAD acid jetting/injecting from 117601 to 118401. Flushed to perfs. Pumped remianing 11 bbls of 7.5% DAD acid across entire interval from 11790' up to 11670' leaving acid across perfs. POOH filling pipe void while displacing coil with methonal. 08/25/03 POOH. Top well with 1 bbl 50/50 methonal. 08/29/03 Drift w/2.7" Cent, TEL, 51 x 2" bailer to 118591 ELM FLUIDS PUMPED BBLS 152 10 PPQ Brine 39 50/50 Methanal 51 7.5% DAD Acid 242 TOTAL Page 1 Tree: Cameron 4.1/16", .....,111 MPU F-84.8B J'I'::f' OF Elev. = 44.08' (N 27E) Wellhead: FMC 11" x 7-1/16" 5M, Orig. GL Elev. = 11.90' Gen. 5a wI 6" x 4.5" FMC Tbg. Hm. RT To Tbg. Spool = (N 27E) wI 4.5" nsct threads top and btm. 4" CIW H BPV profile 20" 91.1 ppf, H-40 I 112' I KOP @ 400 to 4,200' Max. hole angle = 75 deg. , 70 - 75 deg. 6,000' - 9,800' 9 5/8' Howco 'ES' Cementel Hole angle thru' perfs = 17 deg. I I 2111' md 95/8",40/47 ppf, L-80 Btrc. 5,833' 40# 4,186'-5,833' 147#4,186'- 35' Well was side tracked 12/20100 see old diagram for old btm. hole location, kickoff @ 5851' wlm 7" 26 ppf, L-80, BTC-mod casing ( drift 10 = 6.276", cap. = 0.0383 bpf ) 4.5" 12.6 #/ft , L-80 NS~T prod. tbg. ( drift 10 = 3.958", cap. = 0.0152 bpf - 4.5" HES X-Nipple 111":~ rii Perforation Summary jil':'~ :¡i. I I Ref log: SWS USIT dated 12/18/00 ~¡' Ii: 4.5" Baker S-3 Perm. Pkr. 11,490' ~,~ : I: SiZ~ s f Int~rval, ~D, 0 4.5" HES XN Nipple (3.725' id ) 111 ,513: 1 2-7/8 4 11,696 -11 ,712 6,876 - 6,891 ,,,J 4.5" WLEG 111,526 I 2-7/8' 4 11,720'-11,730' 6,899'- 6,908' ELMO I 11,532' I 2-7/8' 4 11,738'-11,758' 6,916'-6,935' W/LtagafterCTU/FCO 2-7/8' 4 11,769'-11,774' 6,947'-6,951' @11.830'wlm. 7" float collar I 11,874' I 7" float shoe I 11 ,961' I DATE REV. BY COMMENTS MILNE POINT UNIT 12/11/98 MOO Cased hole & ESP completion 27E WELL No.: F-84i 03/20/99 MOO Convert injector 4es / 7/4/00 sidetrack API: 50-029-22931-02 12/23/00 MOO Sidetrack Injector Ooyon 141 BP EXPLORATION (AK) "'"'"' STATE OF ALASKA "'"'"" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 41 feet 3. Address Exploratorym 7. Unit or Property name P. O. Box 196612 Stratigraphic._ Anchora~le, AK 99519-6612 Service x Milne Point Unit 4. Location of well at surface 8. Well number 3239' FNL, 2976' FEL, Sec. 06, T13N, R10E, UM (asp's541587, 6035491)~ MPF-84B At top of productive interval~ 9. Permit number / approval number 1465' FNL, 239' FEL, Sec. 02, T13N, R09E, UM (asp's533876, 6037225) ~,~ 200-176 At effective depth 10. APl number 1422' FNL, 256' FEL, Sec. 02, T13N, R09E, UM (asp's 533859, 6037268) 50-029-22931-02 At total depth 11. Field / Pool 1356' FNL, 283' FEL, Sec. 02, T13N, R09E, UM (asp's 533831, 6037334) Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 11980 feet Plugs (measured) Tagged @ 11709', Cement & Drilling Mud. true vertical 7151 feet Effective depth: measured 11709 feet Junk (measured) true vertical 6889 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 112' 20" 250 sx Arctic Set (Aprox) 148' 148' Surface 5797' 9-5/8" 1300 sx PF 'E', 330 sx 5833' 4284' 'G', 170 sx PF 'C' Production 11933' 7" 150 sx Class 'G' 11961' 7132' Perforation depth: measured Open Perfs 11696'-11712', 11720'-11730', 11738'-11758', 11769'-11774'. true vertical Open Perfs 6876'-6891 ', 6899'-6908', 6916'-6935', 6947'-6951'. ~:~-~.-_.._--_-- ;...._ .... · . _..___ ii-- "' - "'! "'~--- --- ' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 NSCT TBG @ 11526' MD. '"~ '"' -'~ :'" '~'~' '? ---'--"~ !' ':' ' -- -'-: Packers& SSSV (type & measured depth) 7"x 4-1/2" Baker S-3 Packer @ 11490'. No SSSV. ~ ! i r~-[' 13. Stimulation or cement squeeze summary ;-'--:~;~.~'i~i~.:-: ........... '" ' '~ - ...... ' Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 02/21/2003 3775 3520 Subsequent to operation 03/13/2003 788 4558 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ ' ..... Daily Report of Well Operations __ Oil __ Gas __ Suspended ~ Service . WAG Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Technical Assistant Date Mamh 14, 2003 eWayne R. Sc norr ~l~_~_/~tt~e~,a_~ ~ ~,~ z~ ~ .... Prepared byDeWa~ne R. Schnorr564-5174 Form 10-404 Rev 06/15/88 · MPF,-84B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/22/2003 WAG SWAP: WATER TO GAS. EVENT SUMMARY 02/22/03 WELL SUPPORT TECHS RIGGED UP AND SWAPPED BLINDS, GREASED TREE, FLUSHED SENSOR LINES AND VERIFIED THE ORIFICE PLATE SIZE. ALL FLANGES WERE TORQUED TO SPEC. ~ FESCO RIGGED UP AND PRESSURE TESTED THE WATER LEG TO 4100 PSI AND THEN PUMPED 2 BBLS METHANOL DOWN IT. RIGGED UP AND PRESSURE TESTED THE GAS LINE TO 4500 PSI AND THEN PUMPED 30 BBLS METHANOL DOWN THE TUBING. JOB WAS COMPLETED WITH NO PROBLEMS AND WELL WAS TURNED OVER TO OPERATOR TO PUT ON INJECTION. Fluids Pumped BBLS 32 METHANOL 32 TOTAL APE 5 2003 Page I Permit to Drill 2001760 DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. MIl_NE PT UNIT KR F-84B Operator BP EXPLORATION (ALASKA) INC MD 11980 TVD 7151 Completion Dat 1/15/2001 Completion Statu WAGIN Current Status WAGIN APl No. 50-029-2293t-02-00 UIC Y REQUIRED INFORMATION Mud Log N._9.o Sample N._~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name ED C./'-.~/' Ver LIS Verification ED D'-~'~'~ Ver LIS Verification '~'/' ._.T,~' .. R R L L C C (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run Scale Media No Start Stop OH ! Dataset CH Received Number~ C~q. omments 5745 11980 Open 4/19/2002 10770~'~'~ 5752 11932 Open 2/7/2002 d~606 D~WD ional Survey iD'onal Survey it~.ectional Survey ~.Dif~nal Survey ,.....9927 (J~.~' ~' ?'-' FINAL FINAL · --'4980 11791 Case 2/26/2001 0~,9~27 4980-11791~--- 2/21/2001 MWD Dir Survey Paper Copy MWD Dir Survey Digital Data 2/21/2001 FINAL FINAL FINAL FINAL 5OO0 1185O CH 4980 11791 ch 2/21/2001 2/21/2001 2/23/2001 2/26/2001 ,,~927 Dir Survey Paper Copy Dir Survey Digital Data 5000-11850 Color Print / 4980-11791 Digital Data_~ i~ ~/~ ~/)//C~ Well Cores/Samples Information: Name Start Inter~al Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~ Chips Received? ~ Analysis R~.c~.iv~.d? Daily History Received? ~ N Formation Tops ~)/N Comments: Permit to Drill 2001760 DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Well Name/No. MILNE PT UNIT KR F-84B Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22931-02-00 MD 11980 TVD 7151 Completion Dat 1/15/2001 Completion Statu WAGIN Current Status WAGIN UIC Y Compliance Reviewed By: Date: To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 74 Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPF-84B, AK-MM-00293 February 19, 2002 MPF-84B: Digital Log Images: 50-029-22931-02 1 CD Rom PLEASE AcKNoWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF ~ TRANSMITTAL LETTER TO THE ATTEN .TION OF: Sperry-Sun Drilling Services Arm: 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 ,~",~" i'", i Alasl~e Oil & O~s Co~s. Cor~o~ WELL LOG TRANSMITYAL To: State of Alaska February 4, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPF-84B, AK-MM-00293 1 LIS formatted Disc with verification listing. API#: 50-029-22931-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Ar, etic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 , ECE.IVED Fr-~ 0 7 200?. STATE OF ALASKA ' ALASKa, ~IL AND GAS CONSERVATION COM~,...,SIoN WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water & Gas Injector 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-176 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22931-02 4. Location of well at surface : ...................... ~,'-?~--'---,.,-~. 9. Unit or Lease Name 2040' NSL, 2182' EWL, SEC. 06, T13N, R10E, UM ~ e,,'..~,..~'.:'.""~C,.;'. '.~.,~ ' ~;'~'~'"~ . ~ 1'~'~.,~, -,~3 i Milne Point Unit At top of Productive interval ~ /.~.~,,:~/ ' ~t~~1 3814' NSL, 239' WEL, SEC. 02, T13N, R09E, UM t .......... · '~.::,.-~..':,-. ',~ 10. Well Number At total depth !--~-..~-v-~;L ,:..., MPF-84Bi 3923' NSL, 283' WEL, SEC. 02, T13N, R09E, UM i. ........ . 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. 11. Field and Pool Milne Point Unit / Kuparuk River Sands KBE = 41.40' ADL 388235 12. Date Spudded 113. DateT. D. Reached114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 116. Nc. of Completions 12/11/2000 1 2/18/2000 1/15/2001 N/A MSL I One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 11980 7151 ETI 11875 7049 ETI [] Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, GR, RES, PWD, USlT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 Surface 112' 24" 250 sx Arctic Set (Approx.) 9-5/8" 40# /47# L-80 36' 5833' 12-1/4" 1300 sx PF 'E', 330 sx 'G', 170 sx PF 'C 7" 26# L-80 28' 11961' 8-1/2" 150 sx Class 'G' 24. Perforations pp. en to. P.r~ucti.on (M.D+.TVD of Top and 25. TUBING RECORD Bottom and ~nmrva~, s~ze ano numDerj SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 11526' 11490' MD TVD MD TVD 11696'- 11712' 6877'-6892' 11720' - 11730' 6900' - 6910' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11738' - 11768' 6917' - 6937' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11769' - 11774' 6947' - 6952' : Freeze Protected with 133 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 1,2001 Water Injection Date of Test Hours Tested PRODUCTION FOR ~OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD .. I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-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. LL.J c.,./ o Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplic~e 129. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Kuparuk D 11548' 6735' LCU / Kuparuk B 11665' 6847' Kuparuk A 11687' 6868' Kuparuk A3 11694' 6875' Kuparuk ^2 11716' 6896' Kuparuk A1 11734' 6914' '- Miluveach 11795' 6972' LEi c:~ E c:3 E o o 31. List of Attachments: Summary of Daily Drilling Reports, Surveys (submitted by Vendor) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ,~.~_~.. ~__~_~..~ Title Technical Assistant Date M P F-84Bi 200-176 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. ~NSTRUCTIONS 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. tram 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 AN~) 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 ORIGINAL , (' (" RECEIVED . , BP AMOCO MAR 0 1 ZOO1 Page 2 of 5 Operations Summary Report Alaska 0il & Gas Cons. Commission Anchorage Legal Well Name: MPF-84 Common Well Name: MPF-84 Spud Date: 6/18/2000 Event Name: REENTER+COMPLETE Start: 12/7/2000 End: 12/20/2000 Contractor Name: DOYON Rig Release: 12/20/2000 Group: RIG Rig Name: DOYON 141 Rig Number: Sub Date From-To Hours Task Code Phase Description of Operations 12/6/2000 19:00 - 00:00 5.00 RIGU :PRE Moving rig from MPE-225 to MPF-84iB. 12/7/2000 00:00 - 12:00 12.00 RIGU PRE Move and rig up on MPF-84iB. 12:00 - 12:30 0.50 RIGU PRE Accept rig at 12:00 hrs 12-07-00. Began nippling down tree, discovered drilling spool is required. 12:30 - 13:00 0.50 RIGU PRE Dig out & thaw snow packed cellar. 13:00 - 18:00 5.00 RIGU SUPP PRE Wait on drilling spool from FMC. Load pipe shed and strap pipe. 18:00 - 22:30 4.50 BOPSUF PROD1 NU FMC drilling spool (removed top two seal rings on packoff to ease tiffing wellhead). NU BOP. 22:30 - 00:00 1.50 BOPSUF PROD1 Test BOP's. Close blinds and test casing against lower seal assy and flange to 3500 psi 10 min. Test BOP 250psi Iow for 5 min, then 3500psi high for 10 min. Good test. Jeff Jones AOGCC waived witnessing test. 12/8/2000 00:00 - 04:00 4.00 BOPSUF PROD1 Finish testing bop's. 250~ 3500 psi. Jeff Jones w! Aogcc waived witnessing test. 04:00 - 05:00 1.00: STKOH PROD1 Pick up 27 jts of 3-1/2 drill pipe and tih. 05:00 - 06:00 1.00 STKOH PROC PROD1 While attempting to make up jt #28 with the iron rough neck the drill pipe jumped out of the air slips and fell in the hole. Hands slips were used for the first 21 jts. After evaluating all the factors, it was determined to be more economical to leave the fish in the well. 06:00 - 09:00 3.00 STKOH PROD1 Pick up 3-1/2" drill pipe and tih to 3000'. 09:00 - 10:00 1.00 STKOH PROD1 Circulate diesel from well 10:00 - 11:00 1.00 STKOH PROD1 Pooh, standing back drill pipe in derrick. 11:00 - 13:00 2.00 STKOH PROD1 R/u schlumberger and run 5.8" gauge ring/junk basket to 6100'. Junk basket was full of scale. 13:00 - 15:00 2.00 STKOH PROD1 Re run gr/jb. Only a small amount of scale in junk basket. 15:00 - 17:00 2.00 STKOH PROD1 Rig up and run baker permanent bridge plug. set same at 5940'. Pooh and rid schlumberger. 17:00 - 18:30 1.50 STKOH PROD1 Change out top rams to 7" rams. 18:30 - 19:00 0.50 STKOH PROD1 Test BOP body to 2000psi. 19:00 - 23:30 4.50 STKOH PROD1 MU Baker 7" casing cutter & TIH to 3000' out of derrick, continue TIH picking up drillpipe to 5939'. 23:30 - 00:00 0.50 STKOH PROD1 Pick up to 5937' and cut casing. 12/912000 00:00 - 00:30 0.50 STKOH PROD1 Finish making cut on 7" casing 00:30 - 01:30 1.00 STKOH i PROD1 Circulate sweep around. Monitor well. Pump dry job. ~01:30 - 03:00 1.50 STKOH PROD1 Pooh and I/d casing cutter. Cutter indicated it had cut through the casing. 03:00 - 05:00 2.00 STKOH PROD1 Make up 7" casing spear with packoff. Latch onto casing and attempt to work casing free. Attempted to circulate and could not. Casing )ulled free with 350,000. Pull hanger and packoff to rig floor. 05:00 - 08:30 3.50 STKOH PROD1 Lay down 7" casing spear and 7" mandrel hanger. Rig up 350 ton casing tools 08:30 - 09:30 1.00 STKOH PROD1 Pooh to casing shoe. Laid down 3 jts 7" 29~ 563 casing. 09:30 - 10:30 1.00 STKOH PROD1 Lay down 350 ton casing tools and rig up 150 ton casing tools. 10:30 - 12:00 1.50 STKOH PROD1 Circulate out freeze protection and circulate seawater around. 12:00 - 21:30 9.50 STKOH PROD1 Pull 7" casing and lay down same. Total of 147 jts plus cut jt laid down. 21:30 - 22:30 1.00 STKOH PROD1 Clear rig floor and change bails. 22:30 - 00:00 1.50 STKOH PROD1 Change 7" top rams back to 3-1/2" x 6" variable and test doors to 2000 psi. 12/10/2000 00:00 - 02:00 2.00 STKOH PROD1 =Trip in hole with 3-1/2" drill pipe to 9-5/8" casing shoe-5833' 02:00 - 04:00 2.00 STKOH PROD1 Wash and ream from 5833'-5837'. Circulate and condition mud until sewater was completely around. Printed: 1/26/2001 4:31:39 PM ( RECEIVED BP AMOCO MAR 0 I ?_001 Page 3 of 5 Operations Summary Repol/Ir ska oit & ( as cons. commission Anchorage Legal Well Name: MPF-84 Common Well Name: MPF-84 Spud Date: 6/18/2000 Event Name: REENTER+COMPLETE Start: 12/7/2000 End: 12/20/2000 Contractor Name: DOYON Rig Release: 12/20/2000 Group: RIG !Rig Name: DOYON 141 Rig Number: Date From - To Hours Task Sub Code Phase Description of Operations 12/lO/2000 04:00 - 05:00 1 .oo STKOH PROD1 Pre job safety meeting. Test lines 2500 psi. Mix and pump 27 bbls (130 sxs) Class"G" 15.6 ppg. Displace with rig and spot balanced plug. Top of cement +/-5600'. 05:00 - 05:30 0.50 STKOH PROD1 Break off cement line and pull 5 stands slow. !05:30 - 06:30 1.00 STKOH PROD1 Drop drill pipe wiper dart and circulate bottoms up. No cement to , surface. Pump dry job. 06:30 - 11:30 5,00 STKOH PROD1 Pooh laying down 3-1/2" drill pipe. 11:30 - 13:00 1.50 STKOH PROD1 Change bottom rams to 5" and test doors to 2000 psi 13:00 - 15:30 2.50 STKOH PROD1 Change top drive saver sub to 4-1/2" IF and rig up handling tools. 15:30 - 21:30 6.00 STKOH PROD1 Pick up 5" drill pipe and rih. Tag cement at 5600' 21:30 - 00:00 2.50 STKOH PROD1 Circulate and displace seawater with drilling mud. 12/11/2000 00:00 - 01:30 1.50 STKOH PROD1 Pooh standing back 5" drill pipe in derrick. 01:30 - 04:00 2.50 STKOH I PROD1 M/U and orient sidetrack/drilling bha. Load MWD/LWD and test. 04:00 - 09:30 5.50 STKOH PROD1 Trip in hole with bha picking up 5" drill pipe. Tag cement at 5600'. 09:30 - 11:00 1.50 STKOH PROD1 Drill hard cement to 5851' 11:00 - 19:00 8.00 STKOH PROD1 Time drill from 5851'-6036'. Cuttings and direction indicated well was sidetracked. 19:00 - 00:00 5.00 DRILL PROD1 ' Directional drill 6036'-6340'. Art-1.55, Ast-9.15. 5-10wob, 80rpm, 450gpm, 1650psi, 15000fi-lbs. 12/12/2000 00:00 - 10:00 10.00. DRILL PROD1 Directional drill 6340'-7320'. Art-7.25, Ast-.215. 5-10wob, 70rpm, 500gpm, 2000psi, 15000fi-lbs. 10:00 - 11:00 1.00 DRILL PROD1 Pump sweep and circulate hole clean. 11:00 - 12:30 1.50 DRILL PROD1 16 stand wiper trip to casing shoe. No problems. 12:30 - 00:00 11.50 DRILL PROD1 Directional drill 7320' TO 8266. Art-7.0, Ast-2.0. 5-10wob, 70rpm, 500gpm, 2360psi, 20,000ft-lbs. Upweight 198k, Down wt 110k, String wt 138k 12/13/2000 00:00 - 12:00 12.00 DRILL PROD1 Directional drill 8286'-9264'. Art- 6.2 hrs, Ast- 1.2 hrs. 5-10K WOB, 70 Rpm/235 rpm btm, 500 gpm, 2400psi, 15-20,000 ft lbs torque. 12:00 - 13:30 1.50 DRILL PROD1 Pump sweep and circulate hole clean. 13:30 - 15:30 2.00 DRILL PROD1 21 stand wiper trip to 7250'. No problems. 15:30 - 00:00 8.50 DRILL PROD1 Directional drill 9264'-9939'. Art- 4.35 hrs, Ast- 1.8 hrs. 5-10K VVOB, 70 Rpm, 500 gpm, 2600psi, 15-20,000 ft lbs torque. 12/14/2000 00:00 - 15:00 15.00 DRILL PROD1 Directional drill 9939'- 10,755'. Art- 2.75 hrs; Ast-9.5 hrs; 5-10 K wob; 70/235 Rpms; 500 gpm; 2700 psi; 15-20,0000 ft lbs torque. 15:00 - 16:00 1.00 DRILL PROD1 Circulate bottoms up 16:00 - 18:00 2.00 DRILL PROD1 16 stand wiper trip to 9200'. No problems. Trip in hole and pick up stands drill pipe. 18:00 - 00:00 6.00 DRILL PROD1 Directional drill 10,755'- 11090'. Art- 0.85 hrs; Ast-4.6 hrs; 5-10k WOB, 70RPM, 235 rpm on btm, 500gpm, 2920 psi, 16k torque. 12/15/2000 00:00 - 15:00 15.00 DRILL PROD1 Directional drill 11,090-11,950'. Art- 9.1 hrs; Ast- 1.1 hrs; 5-10 K wob; 100/235 rpms; 500 gpm; 2750 psi; 20,000--28,000 ft lbs. Torque increased to 28, 000 ff lbs at 11,700' and continued until well was TD. Pumped sweeps and lube pill, but nothing reduced the torque. 15:00 - 16:00 1.00 DRILL PROD1 Pump lo/high vis sweep and circulate hole clean. 16:00 - 19:30 3.50 DRILL PROD1 Pump 5 stands-no swabbing. Pump dry job and pooh to casing shoe. 19:30 - 21:00 1.50 DRILL PROD1 Slip and cut drilling line. Service top drive. '21:00 - 23:30 2.50 DRILL PROD1 Test choke manifold. 3500 high, 300 Iow. 23:30 - 00:00 0.50. DRILL PROD1 Hang Drill pipe on storm packer to allow BOP Test. Recieving and tallying last of 7" casing. 12/16/2000 00:00 - 05:00 5.00 DRILL PROD1 Install test plug and test bop's per BP's policy. 250 Iow -5 minutes/3500 high - 10 minutes on all valves and rams. 250/2000 psi on annular. There was two failures. The #10 and #12 vlaves failed. The packing was replaced and re-tested ok. Printed: 1/26/2001 4:31:39 PM (' ( RECFIVFI' BP AMOCO MAR 0 1 7nl age 4 of 5 Operations Summary Report Alaska Oil & Gas Cons. Commission rtl I~,~1 IVI ~,~,~ Legal Well Name: MPF-84 Common Well Name: MPF-84 Spud Date: 6/18/2000 Event Name: REENTER+COMPLETE Start: 12/7/2000 End: 12/20/2000 Contractor Name: DOYON Rig Release: 12/20/2000 Group: RIG Rig Name: DOYON 141 Rig Number: Date From - To Hours Task Sub Code Phase Description of Operations 12118/2000 05:00 - 05:30 0.50 DRILL PROD1 Pull test plug and install wear ring. 05:30 - 06:00 0.50 DRILL PROD1 Release and pull Howco's 9-5/8" storm packer. 06:00 - 09:00 3.00 DRILL PROD1 Tih. Wash and ream last stand to botom. No problems. 09:00 - 09:30 0.50 DRILL PROD1 Drill 11,950'-11,980'. Drilled additional hole for casing with 20' of rathole. 09:30 - 14:30 5.00 DRILL PROD1 Circulate and condition mud. Mud started coming back thick, 10.3 ppg with 137 vis. Hole started taking fluid. Slowed pumps from 500 gpm to 400 gpm. Lost 100 bbls before getting bottoms up. Once bottoms up was was attained full returns were acheived with no losses. Pump hi/lo vis sweep around. 14:30 - 15:00 0.50 DRILL PROD1 Monitor well. Well gave back 30 bbls in 30 minutes. At first the well gave 2 bbls per minute and then slowed down to 1 bpm. Pump dry job. 15:00 - 15:30 0.50 DRILL PROD1 Pull 3 stands. Pulled 100K over through the sands. No problem going back in hole. 15:30 - 18:30 1.00 DRILL PROD1 Circulate dry job out 16:30 - 17:30 1.00 DRILL PROD1 Pump and rotate out 5 stands. No problems. Pump dry job. 17:30 - 22:00 4.50 DRILL PROD1 POOH Stand back Drill pipe and Heavy weight. Proper fill on trip. 22:00 - 00:00 2.00 DRILL PROD1 Lay down BHA, Down load MWD/LWD. 12/17/2000 00:00 - 01:30 1.50 DRILL PROD1 Finish laying down bha. Download MWD. 01:30 - 03:00 1.50 DRILL PROD1 Pull wear ring, set test plug, change top rams to 7", test 1000 psi, pull test plug. 03:00 - 04:00 1.00 CASE PROD1 Rig up casing tools. PJSM. 04:00 - 09:00 5.00 CASE PROD1 Run 7" 26# L-80 BTC Mod casing to 9-5/8" casing shoe. 09:00 - 10:00 1.00 CASE PROD1 Circulate casing volume. Start pumping with 3 bpm and increased to 8 bpm wit 770 psi. No losses. 10:00 - 15:00 5.00 CASE PROD1 Continue running 7" 26# L-80 BTC Mod. casing. Run a total of 291 jts and landing jt. Casing shoe at 11,961'. No losses running casing. 15:00 - 19:00 4.00 CASE PROD1 Rig up cement head and break circulation at 3 bpm with 620 psi. Final 5 bpm at 570 psi. Lost 270 bbl mud. Full returns when ready to cement. 19:00 - 21:00 2.00 CASE PROD1 Safety meeting. RU and pump 10 bbl water, Test lines to 3500 psi, 30 bbl weighted spacer at 10.6 ppg, 150 sacks Class G with .2% D046, .3% D085, .4% D165, ,15% D800. Mixed at 15.8 ppg. Washed lines and dropped plug. Displaced with rig pump and seawater 454 bbl. 1750 psi. Floats held. Annulus wanted to flow so shut in with annular. 21:00 - 00:00 3.00 CASE PROD1 Wait on cement. 12/18/2000 00:00 - 01:00 1.00 CASE PROD1 ~Wait on cement. L/d cement head and casing elevators. Change bails. :Open annular-well still flowing. 01:00 - 02:00 1.00 CASE PROD1 Lay down landing jt( 10 minutes) and close blind rams. Remove flow line and prep to lay down drill pipe. 02:00 - 10:30 8.50 CASE PROD1 L/d 5" dril pipe out of derrick. 10:30 - 11:30 1.00 CASE PROD1 Open annular, bled off 25 bbls mud, open lower casing valve, only a trickle of mud coming out. Make up pack off, set and test same to 5000 :)si for 10 minutes. 11:30 - 13:30 2.00 CASE PROD1 Change top rams to 3-1/2" x 6 variable and the bottom rams to 3-1/2. 13:30 - 14:30 1.00 CASE PROD1 Test rams 250 psi for 5 minutes and 3500 psi for 10 minutes. Pull test plug and install wear ring. 12/19/2000 05:00 - 15:00 10.00 CASE PROD1 Run packer assembly on 4-1/2"NSCT 12.6~ L-80 tubing. Total of 285 its run. 15:00 - 18:00 1.00 CASE PROD1 Make up tubing hanger (4-1/2" NSCT Thds in top) and landed tubing. Run in lock down screws. Install TWC. Test TWC to 1000 psi from Pdnted: 1126/2001 4:31:39 PM . . RECEIVED MAR 0 1 ZOO1 BP AMOCO Page 5 of 5 Operations Summary Report Alaska 0il &AnchorageGaS Cons. Commission Legal Well Name: MPF-84 Common Well Name: MPF-84 Spud Date: 6/18/2000 Event Name: REENTER+COMPLETE Start: 12/7/2000 End: 12/20/2000 Contractor Name: DOYON Rig Release: 12/20/2000 Group: RIG Rig Name: DOYON 141 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 12/19~2000 15:00 - 16:00 1.00 CASE PROD1 bottom and top. 16:00 - 18:00 2.00 BOPSUF PROD1 Nippled down 13-518" BOP stack. 18:00 - 20:30 2.50 WHSUR PROD1 Installed 11" 5K X 4" SBMS SH adapter flange.and 4-1/8" 5K single action carbon Cameron tree. Tested tree and tubing hanger to 5000 psi. OK. Pulled TWC. 20:30 - 22:30 2.00 WHSUR PROD1 Reverse circulated seawater treated with 25 gals/100 bbls of Corrision Inhibitor. 22:30 - 00:00 1.50 WHSUR PROD1 Freeze protect 4-1/2" X 7" with 68 bbls of diesel down the annulus. Rigged up and u-tubed diesel. 12/20/2000 00:00 - 00:30 0.50 WHSUR PROD1 Finished allowing diesel to U-tube. 00:30 - 02:00 1.50 CASE PROD1 Dropped 1-7/8" steel ball down tubing and allowed it to fall on seat. Pressured up 1000 psi to set slips. Increased pressure to 3500 psi to set packer and element. 02:00 - 04:30 2.50 CASE PROD1 Increased pressure to 4500 psi for MIT and held tubing pressure for 30 minutes. Bled off pressure. Pressure tested annulus to 3500 psi for 30 minutes. 04:30 - 06:00 1.50 WHSUR PROD1 Installed BPV. Secured tree. Clear cellar and prep for rig move. RIG RELEASED AT 0600 HRS 12-20-2000 Printed: 1/26/2001 4:31:39 PM ... (" .... RECEIVED MAR 0 1 ~'age 1 of 5 BP AMOCO ~,0 01 Operations Summary Report Alaska 0il & Gas Cons. Commission Anchorage Legal Well Name: MPF-84 Common Well Name: MPF-84 Spud Date: 6/18/2000 Event Name: REENTER+COMPLETE Start: 12/7/2000 End: 12/20/2000 Contractor Name: DOYON Rig Release: 12/20/2000 Group: ELEC Rig Name: DOYON 141 Rig Number: Date From-To Hours Task Sub Code Phase Description of Operations 12/18/2000 14:30 - 00:00 9.50 CASE PROD1 Rig up Schlumberger and run GR USIT bond tolls to 11845'. Repeat w/o pressure. Main run w/1000 psi. Top of good cement at 11200'. Top of fair cement at 9800'. Tie in with GR at 5200'. POOH, RU and run 6" GPJJB. 12/19/2000 00:00 - 03:00 3.00 CASE PROD1 ! Finish running 6.0" gr/jb to 11,600'. Pooh and rig down Schlumberger. 03:00 - 04:00 1.00 CASE PROD1 Pressure test casing for 30 minutes to 4500 psi-good test. Pull wear ring. 04:00 - 05:00 1.00 CASE PROD1 PJSM. Make up wireline entry assembly with XN nipple, Baker S-3 7" X 4-112" permanent packer, and X nipple assembly. Printed: 1/26/2001 4:31:39 PM RECEIVED MAR 0 1 ZOO1 Well: MPF-84Bi Field: Milne Point Unit Alaska Oil & Gas Cons. Commission APl: 50-029-22931-02 Anchorage Permit: 200-176 Date POST RIG WORK SUMMARY 01/15/01 Rigged up SWS. RIH with 2-7/8" 5' gun with roller below and above the gun. Rolled past deviation to 11875'. Made tie-in pass from 11875' through jewelry to 11227'. Dropped back, made correction. Logged into position at 11761.7. eCL to top shot = 7.3'. Put 250 psi on wellhead to see shot. Perfed interval 11769' - 11774'. Wellhead pressure went to zero. Logged off. POOH and rig down. 01/16/01 Worked 5', 2-7/8" gun to the lower five feet of the lower section of the 36' Kuparuk sands. 01/17/01 Return to the well with 3-3/8" guns to continue the perforations. Unable to work the guns through an area of 75 deg. at 6200'. An attempt to use HB&R to assist the gun failed, the well pressured right, no Injectivity. Called the engineer and it was decided to change gun size for the rest of the job to 2-7/8". 01/19101 Start in with 10' gun run, return to surface with another short. Finally made it down and tagged up at 11,765'. Slickline dummy gun run tag at 11,880 corrected. We had previously shot a five foot gun at 11,769 - 11,774', but all seems to be covered at this time. This explains the lack of Injectivity. Discussed with engineer in town and decided to go ahead and perf the middle section with the 10' gun 11,720' - 11,730' shots fired. Ran in the hole with 20' gun and shot the upper section of the lower perfs 11,738' to 11,758', the tag was the same as the first run tag. After a second misrun of the day the final 16' of the upper section was shot. 01/20/01 Tagged well with slickline and retrieved a sample of the fill. Correlated back to e-line depths. It appears that some additional fill has entered the well bore, up to approximately 11,709'. Only 13' of all perforations are clear at this time. 01/20101 Move in and rig up. Pressure tested surface equipment. RIH and located tubing tail at 11503' sim / 11532' elmd. Tagged fill at 11680' sim / 11709' corrected. Tagged 5' up into the upper set of perforations (11696' - 11714') all other perforations seem to be covered at this time. Bottom is very sticky, full of gray heavy mud. /I ~-~gl~.li~,:~.,.':~lI NO. 912 GeoQuest 3940 Arctic Blvd Company Anchorage, AK 99503 ATTN: Sherrie Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 1/26/01 Well Job # Lo~l Description Date BL Sepia CD MPF-84B 21021 USIT (PDC~r 001218 ! PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Al-tN: Sherrie Received GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 866 Company Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage. AK 99501 Milne Point (Cased Hole) 1/15/01 Well Job # Lo~l Description Date Color Sepia CD 1- MPF-84B 20519 USIT 001218 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: C~'¢~ ~ 0 1 Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Al-tN: Sherrie Received by:~~~,, ~ 05-Jan-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 DEFINATIVE SURVEYS Re: Distribution of Survey Data for Well MPF-84B Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 5,847.32' MD 5,854.00' MD 11,980.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Milne Point Unit Alaska Drilling & Wells Milne Point MPF, Slot MPF-84 MPF-84B Surveyed: 15 December, 2000 SURVEY REPORT 9 January, 2001 Your Ref: AP1500292293102 Surface Coordinates: 6035490.85 N, 541586.61 E (70° 30' 28.2589" N, Kelly Bushing: 41.40fl above Mean Sea Level 149° 39' 35.1223" HO DRILLING SERVICES .... A Halliburton Company Survey Ref: svy9747 Sperry-Sun Drilling Services Survey Report for MPF-84B Your Ref: APl 500292293'102 Surveyed: f5 December, 2000 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 5847.32 61.970 268.590 4249.46 4290.86 5854.00 62.000 268.550 4252.59 4293.99 5893.52 63.910 272.120 4270.57 4311.97 5924.77 64.840 274.890 4284.08 4325.48 5953.85 66.020 277.410 4296.18 4337.58 5987.81 67.450 280.300 4309.59 4350.99 6018.04 68.410 282.820 4320.95 4362.35 6046.64 69.300 285.160 4331.27 4372.67 6081.27 71.240 287.950 4342.96 4384.36 6112.11 72.670 290.390 4352.52 4393.92 6140.17 74.240 292.230 4360.51 4401.91 6233.10 75.450 292.360 4384.80 4426.20 6325.86 75.190 289.830 4408.31 4449.71 6420.78 75.350 289.090 4432.45 4473.85 6513.62 75.310 286.970 4455.96 4497.36 6605.97 75.330 286.570 4479.36 4520.76 6697.67 74.570 286.010 4503.18 4544.58 6790.10 73.900 287.000 4528.29 4569.69 6883.51 73.560 290.440 4554.47 4595.87 6976.63 73.350 285.780 4581.00 4622.40 7069.39 72.790 287.060 4608.01 4649.41 7162.36 73.310 289.310 4635.12 4676.52 7253.40 73.360 290.560 4661.23 4702.63 7345.18 73.430 289.980 4687.45 4728.85 7441.57 73.350 289.550 4715.01 4756.41 7533.79 73.210 291.770 4741.54 4782.94 7628.03 72.940 289.680 4768.98 4810.38 7717.69 73.420 291.370 4794.93 4836.33 7810.76 73.210 293.150 4821.65 4863.05 7903.76 72.880 290.470 4848.78 4890.18 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 25.84S 3331.92W 6035446.35 N 538254.88 E 25.99 S 3337.82W 6035446.17 N 538248.99 E 25.78 S 3373.01W 6035446.19 N 538213.80 E 24.05 S 3401.13W 6035447.76 N 538185.67 E 21.22 S 3427.42W 6035450.45 N 538159.37 E 16.41S 3458.24W 6035455.08 N 538128.52 E 10.79 S 3485.68W 6035460.54 N 538101.04 E 4.34 S 3511.56W 6035466.85 N 538075.13 E 4.95 N 3542.80W 6035475.96 N 538043.84 E 14.58 N 3570.49W 6035485.44 N 538016.09 E 24.35 N 3595.55W 6035495.07 N 537990.98 E 58.38 N 3678.54W 6035528.64 N 537907.80 E 90.68 N 3762.25W 6035560.46 N 537823.91 E 121.26 N 3848.81W 6035590.56 N 537737.18 E 149.06 N 3934.20W 6035617.88 N 537651.63 E 174.83 N 4019.74W 6035643.18 N 537565.95 E 199.67 N 4104.74W 6035667.54 N 537480.82 E 224.94 N 4190.03W 6035692.33 N 537395.39 E 253.71N 4274.94W 6035720.63 N 537310.32 E 281.45 N 4359.75W 6035747.89 N 537225.35 E 306.54 N 4444.87W 6035772.50 N 537140.09 E 334.29 N 4529.35W 6035799.78 N 537055.46 E 364.03 N 4611.34W 6035829.06 N 536973.30 E 394.50 N 4693.85W 6035859.06 N 536890.63 E 425.73 N 4780.77W 6035889.81 N 536803.53 E 456.89 N 4863.41W 6035920.51 N 536720.72 E 488.79 N 4947.73W 6035951.94N 536636.23 E 518.89 N 5028.10W 6035981.58 N 536555.69 E 552.66 N 5110.60W 6036014.89 N 536473.00 E 585.70 N 5193.18W 6036047.47 N 536390.23 E Dogleg Rate (°/'lOOft) 0.69 9.38 8.53 8.86 8.88 8.35 8.24 9.43 8.84 8.42 1.31 2.65 0.77 2.21 0.42 1.02 1.26 3.55 4.80 1.45 2.38 1.32 0.61 0.44 2.31 2.14 1.88 1.85 2.78 Alaska Drilling & Wells Milne Point MPF . Vertical Section Comment 3224.66 3230.34 3264.51 3292.20 3318.39 3349.45 3377.43 3404.11 3436.67 3465.87 3492.56 3581.35 3670.41 3761.82 3851.42 3940.66 4029.15 4118.03 42O7.39 4296.42 4385.08 4473.78 4560.55 4648.00 4739.93 4827.67 4917.23 5002.51 5090.77 5178.92 TIE ON POINT AK-6 BP_IFR-AK WINDOW POINT 9 January, 2001 - f5:29 Page 2 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPF-84B Your Ref: AP1 500292293102 Surveyed: t5 December, 2000 Milne Point Unit Measured Depth Incl. Azim. Sub-Sea Depth (~t) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (rt) (ft) (fi) 7996.31 72.640 292.460 4876.21 4917.61 8089.09 72.290 290.490 4904.16 4945.56 8180.71 71.850 288.040 4932.37 4973.77 8274.92 72.970 291.170 4960.85 5002.25 8368.02 73.870 291.140 4987.42 5028.82 8460.68 73.600 291.170 5013.37 5054.77 8552.48 73.140 291.850 5039.64 5081.04 8646.75 72.770 291.190 5067.27 5108.67 8740.03 72.250 290.140 5095.31 5136.71 8832.90 71.990 291.400 5123.82 5165.22 8924.64 72.550 290.760 5151.76 5193.16 9018.51 73.280 290.520 5179.34 5220.74 9112.03 74.550 292.310 5205.25 5246.65 9205.29 75.210 293.250 5229.58 5270.98 9297.98 75.080 292.220 5253.34 5294.74 9391.05 75.110 292.060 5277.28 5318.68 9484.27 74.850 291.520 5301.44 5342.84 9577.12 74.990 290.300 5325.60 5367.00 9670.52 73.760 290.310 5350.75 5392.15 9762.94 71.080 289.650 5378.66 5420.06 9855.23 68.740 288.650 5410.36 5451.76 9947.91 66.720 287.760 5445.49 5486.89 10038.16 63.130 286.470 5483.73 5525.13 10131.50 59.750 286.580 5528.35 5569.75 10225.08 55.290 287.660 5578.59 5619.99 10318.77 51.390 291.470 5634.53 5675.93 10413.00 46.220 295.140 5696.58 5737.98 10505.20 42.790 300.010 5762.35 5803.75 10598.36 40.170 305.720 5832.16 5873.56 10690.74 36.840 310.310 5904.46 5945.86 618.05 N 5275.44W 6036079.36 N 536307.79 E 650.43 N 5357.76W 6036111.28 N 536225.29 E 679.19 N 5440.04W 6036139.58 N 536142.85 E 709.33 N 5524.62W 6036169.24N 536058.10 E 741.53 N 5607.84W 6036200.98 N 535974.71E 773.63 N 5690.79W 6036232.61N 535891.57 E 805.88 N 5772.63W 6036264.41 N 535809.56 E 838.95 N 5856.47W 6036297.00 N 535725.53 E 870.34 N 5939.71W 6036327.93 N 535642.12 E 901.68 N 6022.35W 6036358.81N 535559.30 E 933.11N 6103.89W 6036389.78 N 535477.59 E 964.74N 6187.86W 6036420.94 N 535393.45 E 997.55 N 6271.50W 6036453.28 N 535309.62 E 1032.41 N 6354.51W 6036487.67 N 535226.42 E 1067.04N 6437.14W 6036521.83 N 535143.60 E 1100.93 N 6520.45W 6036555.26 N 535060.10 E 1134.35 N 6604.05W 6036588.22 N 534976.32 E 1166.35 N 6687.79W 6036619.74N 534892.39 E 1197.56 N 6772.15W 6036650.48 N 534807.86 E 1227.67 N 6854.94W 6036680.12 N 534724.90 E 1256.10 N 6936.81W 6036708.10 N 534642.87 E 1282.90 N 7018.28W 6036734.44 N 534561.26 E 1306.97 N 7096.39W 6036758.07 N 534483.02 E 1330.28 N 7174.97W 6036780.94 N 534404.31E 1353.49 N 7250.40W 6036803.73 N 534328.75 E 1378.59 N 7321.20W 6036828.43 N 534257.81 E 1406.54N 7386.32W 6036856.02 N 534192.54 E 1436.36 N 7443.60W 6036885.52 N 534135.09 E 1469.75 N 7495.42W 6036918.62 N 534083.08 E 1505.08 N 7540.75W 6036953.69 N 534037.55 E Dogleg Rate (O/'lOOft) 2.07 2.06 2.59 3.38 0.97 0.29 0.87 0.78 1.21 1.32 0.90 0.82 2.29 1.20 1.08 0.17 0.63 1.28 1.32 2.98 2.73 2.35 4.18 3.62 4.86 5.29 6.22 5.25 4.94 4.75 Alaska Drilling & Wells Milne Point MPF Vertical Section Comment 5266.59 5354.32 5441.14 5530.52 5619.08 5707.37 5794.60 5883.98 5972.37 6060.16 6146.90 6236.05 6325.18 6414.19 6502.77 6591.84 6681.07 6770.10 6859.52 6947.16 7033.50 7119.04 7200.66 7282.56 7361.37 7436.16 7506.13 7568.96 7627.37 7679.96 9 January, 2001 - 15:29 Page 3 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPF-84B Your Ref: AP1 500292293102 Surveyed: f5 December, 2000 Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 10782.44 33.220 317.260 5979.57 6020.97 1541.34 N 7578.79 W 10874.84 28.860 323.960 6058.74 6100.14 1577.99 N 7609.11 W 10967.47 23.460 328.240 6141.86 6183.26 1611.77 N 7631.99 W 11060.44 18.880 336.040 6228.55 6269.95 1641.27 N 7647.85 W 11154.00 17.750 338.570 6317.37 6358.77 1668.38 N 7659.21 W 6036989.74 N 533999.31E 6037026.22 N 533968.78 E 6037059.87 N 533945.72E 6037089.28 N 533929.69 E 6037116.33 N 533918.18 E 11245.60 17.520 338.400 6404.66 6446.06 1694.20 N 7669.39W 11338.98 16.860 338.490 6493.87 6535.27 1719.86 N 7679.53W 11432.61 17.380 339.630 6583.35 6624.75 1745.61 N 7689.37W 11525.44 16.830 339.640 6672.08 6713.48 1771.20 N 7698.87W 11616.27 16.520 338.750 6759.09 6800.49 1795.57 N 7708.13W 6037142.09 N 533907.86 E 6037167.70 N 533897.58 E 6037193.38 N 533887.59 E 6037218.93 N 533877.94 E 6037243.24 N 533868.55 E 11709.91 16.140 338.670 6848.95 6890.35 1820.10 N 7717.69W 11802.51 15.440 337.090 6938.05 6979.45 1843.44N 7727.17W 11863.87 15.110 336.940 6997.25 7038.65 1858.32 N 7733.48W 11980.00 15.110 336.940 7109.36 7150.76 1886.18 N 7745.34W 6037267.72 N 533858.85 E 6037291.01N 533849.24 E 6037305.85 N 533842.85 E 6037333.64 N 533830.83 E All data is in feet 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 26.392° (06-Dec-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 284.140° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11980.00ff., The Bottom Hole Displacement is 7971.70ft., in the Direction of 283.687° (True). Dogleg Rate (o/ioof. t) 5.87 6.01 6.17 5.77 1.48 0.26 0.71 0.66 0.59 0.44 0.41 0.89 0.54 0.00 Alaska Drilling & Wells Milne Point MPF Vertical Section Comment 7725.70 7764.O6 7794.50 7817.08 7834.72 785O.9O 7867.00 7882.83 7898.30 7913.23 7928.49 7943.39 7953.14 7971.45 PROJECTED SURVEY 9 January, 2001 - 15:29 Page 4 of 5 DriilQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPF-84B Your Reft AP1500292293102 Surveyed: f5 December, 2000 Milne Point Unit Alaska Drilling & Wells Milne Point MPF Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 5847.32 4290.86 25.84 S 3331.92W 5854.00 4293.99 25.99 S 3337.82W 11980.00 7150.76 1886.18 N 7745.34W Comment TIE ON POINT WINDOW POINT PROJECTED SURVEY Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) <Surface> <Surface> 5827.57 4281.62 Casing Detail 13 3/8" Casing Survey tool program for MPF-84B From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (~t) 0.00 0.00 5847.32 5847.32 4290.86 11980.00 Vertical Depth (ft) 4290.86 7150.76 Survey Tool Description AK-2 BP_CG (MPF-84 GYRODATA) AK-6 BP_IFR-AK (MPF-84B) 9 January, 200t - f5:29 Page 5 of 5 DrillQuest 2.00.06 Milne Point Unit Alaska Drilling & Wells Milne Point MPF, Slot MPF-84 MPF-84B MWD Surveyed: 15 December, 2000 $ UR VEY REPORT 9 January, 2001 Your Ref: APl 500292293102 Surface Coordinates: 6035490.85 N, 541586.61 E (70° 30' 28.2589" N, Kelly Bushing: 41.40ft above Mean Sea Level 149° 39' 35.1223" 140 DRILLING SERVICES Survey Ref: svy9748 A Halliburton Company Sperry-Sun Drilling Services Survey Report for MPF-84B MWD Your Ref: APl 500292293102 Surveyed: t5 December, 2000 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 5847.32 61.970 268.590 4249.46 4290.86 5854.00 62.000 268.550 4252.59 4293.99 5893.52 63.910 272.120 4270.57 4311.97 5924.77 64.840 274.890 4284.08 4325.48 5953.89 66.020 277.410 4296.19 4337.59 5987.81 67.450 280.150 4309.59 4350.99 6018.04 68.410 282.840 4320.95 4362.35 6046.64 69.300 287.480 4331.27 4372.67 6081.27 71.240 292.650 4342.97 4384.37 6112.11 72.670 290.390 4352.53 4393.93 6140.17 74.240 292.230 4360.52 4401.92 6233.10 75.450 292.360 4384.81 4426.21 6325.86 75.190 289.830 4408.32 4449.72 6420.78 75.350 289.090 4432.46 4473.86 6513.62 75.310 286.970 4455.97 4497.37 6605.97 75.330 286.440 4479.37 4520.77 6697.67 74.570 288.960 4503.19 4544.59 6790.10 73.900 289.320 4528.30 4569.70 6883.51 73.560 292.690 4554.48 4595.88 6976.63 73.350 286.200 4581.02 4622.42 7069.39 72.790 289.750 4608.04 4649.44 7162.36 73.310 292.260 4635.15 4676.55 7253.40 73.360 294.360 4661.26 4702.66 7345.18 73.430 292.430 4687.49 4728.89 7441.57 73.350 292.400 4715.04 4756.44 7533.79 73.210 294.140 4741.58 4782.98 7628.03 72.940 291.920 4769.02 4810.42 7717.69 73.420 294.590 4794.96 4836.36 7810.76 73.210 295.550 4821.69 4863.09 7903.76 72.880 292.660 4848.81 4890.21 25.84 S 3331.92W 25.99 S 3337.82W 25.78 S 3373.01W 24.05 S 3401.13W 21.21S 3427.45W 16.45 S 3458.24W 10.87 S 3485.69W 3.89 S 3511.43W 7.30 N 3542.03W 18.05 N 3569.31W 27.83 N 3594.36W 61.85 N 3677.36W 94.15 N 3761.07W 124.73 N 3847.62W 152.53 N 3933.02W 178.21N 4018.58W 205.12 N 4102.94W 234.29 N 4186.97W 266.42 N 4270.67VV 296.12 N 4354.79W 323.50 N 4439.19W 355.38 N 4522.20W 389.89 N 4602.29W 424.81 N 4683.01W 460.03 N 4768.40W 494.92 N 4849.53W 530.19 N 4932.50W 564.07 N 5011.34W 601.85 N 5092.09W 638.18 N 5173.28W 6035446.35 N 538254.88 E 6035446.17 N 538248.99 E 6035446.19 N 538213.80 E 6035447.76 N 538185.67 E 6035450.45 N 538159.33 E 6035455.04 N 538128.51 E 6035460.47 N 538101.03 E 6035467.30 N 538075.26 E 6035478.32 N 538044.59 E 6035488.92 N 538017.26 E 6035498.55 N 537992.15 E 6035532.12 N 537908.97 E 6035563.94 N 537825.08 E 6035594.04 N 537738.35 E 6035621.36 N 537652.80 E 6035646.56 N 537567.09 E 6035673.00 N 537482.59 E 6035701.70 N 537398.39 E 6035733.36 N 537314.51 E 6035762.59 N 537230.23 E 6035789.49 N 537145.68 E 6035820.91N 537062.49 E 6035854.97 N 536982.21E 6035889.44 N 536901.30 E 6035924.18 N 536815.71E 6035958.61N 536734.39 E 6035993.42 N 536651.22 E 6036026.86 N 536572.19 E 6036064.18 N 536491.23 E 6036100.06 N 536409.84 E Dogleg Rate (°/lOOft) 0.69 9.38 8.53 8.85 8.53 8.84 15.45 15.13 8.37 8.42 1.31 2.65 0.77 2.21 0.56 2.78 0.82 3.48 6.68 3.71 2.64 2.21 2.02 0.09 1.81 2.27 2.90 1.01 2.99 Alaska Drilling & Wells Milne Point MPF Vertical Section Comment 3224.66 3230.34 3264.51 3292.20 3318.43 3349.45 3377.43 3404.09 3436.5O 3465.57 3492.26 3581.05 3670.11 3761.52 3851.12 3940.36 4028.74 4117.35 4206.36 4295.19 4383.71 4472.00 4558.09 4644.90 4736.30 4823.50 4912.57 4997.3O 5O84.83 5172.44 TIE ON POINT MWD Magnetic WINDOW POINT 9 January, 200f - f5:30 Page 2 of 5 DrillQuest ZOO.06 Sperry-Sun Drilling Services Survey Report for MPF-84B MWD Your Ref: AP1 500292293102 Surveyed: t5 December, 2000 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 7996.31 72.640 295.200 4876.25 4917.65 8089.09 72.290 292.650 4904.20 4945.60 8180.71 71.850 290.940 4932.41 4973.81 8274.92 72.970 294.170 4960.89 5002.29 8368.02 73.870 293.100 4987.46 5028.86 8460.68 73.600 293.210 5013.41 8552.48 73.140 294.030 5039.68 8646.75 72.770 '293.670 5067.31 8740.03 72.250 292.360 5095.35 8832.90 71.990 293.630 5123.86 5054.81 5081.08 5108.71 5136.75 5165.26 8924.64 72.550 293.040 5151.80 5193.20 9018.51 73.280 291.590 5179.38 5220.78 9112.03 74.550 296.710 5205.31 5246.71 9205.29 75.210 293.460 5229.64 5271.04 9297.98 75.080 296.100 5253.40 5294.80 9391.05 75.110 294.660 5277.35 5318.75 9484.27 74.850 290.500 5301.51 5342.91 9577.12 74.990 293.670 5325.68 5367.08 9670.52 73.760 293.010 5350.83 5392.23 9762.94 71.080 289.570 5378.75 5420.15 9855.23 68.740 291.360 5410.45 5451.85 9947.91 66.720 290.730 5445.57 5486.97 10038.16 63.130 289.030 5483.82 5525.22 10131.50 59.750 286.910 5528.44 5569.84 10225.08 55.290 289.270 5578.69 5620.09 10318.77 51.390 291.560 5634.62 5676.02 10413.00 46.220 295.300 5696.67 5738.07 10505.20 42.790 301.460 5762.45 5803.85 10598.36 40.170 305.440 5832.25 5873.65 10690.74 36.840 310.490 5904.55 5945.95 674.03 N 5254.07W 709.90 N 5334.92W 742.27 N 5415.86W 776.71N 5498.78W 812.48 N 5580.52W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 6036135.45 N 536328.85 E 6036170.88 N 536247.80 E 6036202.79 N 536166.68 E 6036236.77 N 536083.57 E 6036272.08 N 536001.63 E 847.46 N 5662.31W 6036306.60 882.70 N 5742.90W 6036341.39 919.15 N 5825.33W 6036377.37 953.93 N 5907.21W 6036411.70 988.46 N 5988.57W 6036445.77 1023.07 N 6068.81W 6036479.93 1057.13 N 6151.81W 6036513.53 1093.90 N 6233.77W 6036549.83 1132.06 N 6315.30W 6036587.53 1169.60 N 6396.63W 6036624.63 1208.15 N 6477.89W 6036662.72 1242.71N 6561.00W 6036696.82 1276.42 N 6644.06W 6036730.05 1312.06N 6726.65W 6036765.23 1344.05 N 6808.71W 6036796.77 1374.35 N 6889.91W 6036826.60 1405.15 N 6969.95W 6036856.96 1432.95 N 7046.80W 6036884.33 1458.26 N 7124.75W 6036909.21 1482.73 N 7199.78W 6036933.25 1508.90 N 7270.21W 6036959.03 1536.99 N 7335.26W 6036986.76 1567.59 N 7392.11W 6037017.03 1601.53 N 7443.60W 6037050.69 1636.81N 7488.96W 6037085.71 N 535919.65 E N 535838.86 E N 535756.23 E N 535674.15 E N 535592.60 E N 535512.17 E N 535428.98 E N 535346.82 E N 535265.08 E N 535183.53 E N 535102.06 E N 535018.76 E N 534935.51E N 534852.72 E N 534770.48 E N 534689.12 E N 534608.91E N 534531.90 E N 534453.8O E N 534378.64 E N 534308.07 E N 534242.86 E N 534185.84 E N 534134.16 E N 534088.61E 2.63 2.65 1.84 3.48 1.47 0.31 0.99 0.54 1.45 1.33 0.86 1.67 5.43 3.44 2.76 1.50 4.32 3.30 1.48 4.58 3.12 2.27 4.33 4.13 5.22 4.60 6.25 5.98 3.99 4.96 Alaska Drilling & Wells Milne Point MPF Vertical Section Comment 5259.54 5346.71 5433.10 5521.92 5609.92 5697.78 5784.53 5873.37 5961.27 6048.60 __ 6134.86 6223.67 6312.13 6400.51 6488.55 6576.76 6665.80 6754.58 6843.37 6930.76 7016.90 7102.03 7183.35 7265.13 7343.86 7418.55 7488.49 7551.09 7609.31 7661.92 9 January, 200f- f5:30 Page 3 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPF-84B MWD Your Ref: AP1500292293102 Surveyed: f5 December, 2000 Milne Point Unit Measured Sub-Sea Vertical Local Coordinates' Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 10782.44 33.220 316.800 5979.65 6021.05 1673.00 N 7527.09W 10874.84 28.860 324.180 6058.83 6100.23 1709.56 N 7557.49W 10967.47 23.460 328.460 6141.95 6183.35 1743.43 N 7580.24W 11060.44 18.880 336.100 6228.64 6270.04 1772.98 N 7596.02W 11154.00 17.750 338.800 6317.46 6358.86 1800.11N 7607.31W 6037121.68 N 534050.28 E 6037158.08 N 534019.67 E 6037191.82 N 533996.73 E 6037221.28 N 533980.78 E 6037248.35 N 533969.34 E 11245.60 17.520 338.710 6404.75 6446.15 1825.98 N 7617.37W 11338.98 16.860 338.530 6493.96 6535.36 1851.68 N 7627.43W 11432.61 17.380 340.200 6583.44 6624.84 1877.47 N 7637.14W 11525.44 16.830 339.320 6672.17 6713.57 1903.09 N 7646.58W 11616.27 16.520 338.750 6759.18 6800.58 1927.43 N 7655.90W 6037274.16 N 533959.14 E 6037299.80 N 533948.94E 6037325.54 N 533939.08 E 6037351.10 N 533929.50 E 6037375.39 N 533920.04 E 11709.91 16.140 338.670 6849.04 6890.44 1951.96 N 7665.46W 11802.51 15.440 337.800 6938.14 6979.54 1975.36 N 7674.80W 11863.87 15.110 336.720 6997.34 7038.74 1990.27 N 7681.05W 11980.00 15.110 336.720 7109.45 7150.85 2018.08 N 7693.01W 6037399.87 N 533910.34 E 6037423.22 N 533900.87 E 6037438.09 N 533894.54 E 6037465.83 N 533882.42 E All data is in feet 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 26.389° (09-Dec-00) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 284.140° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11980.00ft., The Bottom Hole Displacement is 7953.30ft., in the Direction of 284.699° (True). Dogleg Rate (°llOOft) 5.58 6.26 6.17 5.74 1.51 0.25 0.71 0.76 0.65 0.39 0.41 0.80 0.71 0.00 Alaska Drilling & Wells Milne Point MPF Vertical Section Comment 7707.73 7746.14 7776.47 7799.OO 7816.58 7832.65 7848.68 7864.39 7879.81 7894.8O 7910.06 7924.83 7934.53 7952.93 PROJECTED SURVEY 9 January, 2001 - ~5:30 Page 4 of 5 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for MPF-84B MWD Your Ref: AP1500292293f02 Surveyed: f5 December, 2000 Milne Point Unit Alaska Drilling & Wells Milne Point MPF Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 5847.32 4290.86 25.84 S 3331.92W 5854.00 4293.99 25.99 S 3337.82W 11980.00 7150.85 2018.08 N 7693.01W Comment TIE ON POINT WINDOW POINT PROJECTED SURVEY Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (rt) (ft) (ft) <Surface> <Surface> 5827.57 4281.62 Casing Detail 13 3/8" Casing Survey tool program for MPF-84B MWD From To Measured Vertical Measured Depth Depth Depth (ft) (rt) (ft) Vertical Depth (rt) 0.00 0.00 5847.32 4290.86 5847.32 4290.86 11980.00 7150.85 Survey Tool Description AK-2 BP_CG (MPF-84 GYRODATA) MWD Magnetic (MPF-84B MWD) 9 January, 2001.15:30 Page 5 of 5 DrillQuest2.00.06 ALASKA OIL AND GAS CONSERVATION COPLSllSSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Steve Schultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99501 Re: Milne Point Unit MPF-84Bi BP Exploration (Alaska) Inc. Permit No: 200-176 Sur. Loc. 2040'NSL, 2182'EWL, Sec. 06, T13N, R10E, UM Btmhole Loc. 3988'NSL, 289'WEL, Sec. 02, T13N, R09E, UM Dear Mr. Schultz: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25'.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, J M Heusser Commissioner BY ORDER OF THE COMMISSION .DATED this ~.t~l day of November, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ' ' ALAS OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Drill [] Redrill I lb. Type of wel~ [] Exploratory [] Stratigraphic Test L"] Development Oil 1 a. Type of work L, Re-Entry [] Deepen .l~r Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 29.5' Milne Point Unit / Kuparuk 3. Address 6. Property Designation River Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ~-~?,7~.~,'. ADL 388235 4. Location of well at surface 7. Unit iS'i~roperty Name 11. Type Bond (See 20 AAC 25.025) 2040' NSL, 2182' EWL, SEC. 06, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 3909' NSL, 252' WEL, SEC. 02, T13N, R09E, UM MPF-84Bi Number 2S100302630-277 At total depth 9. Approximate spud date 3988' NSL, 289' WEL, SEC. 02, T13N, R09E, UM 12/01/00 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 355018, 1292'I No Close Approach 1920 11936' MD / 7119' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 5900' Maximum Hole Angle 73.9 ° Maximum surface 1312 psig, At total depth (TVD) 7058' / 2018 psig 18. CaSing Program Specifications Setting DePth Size Top Bottom Quantitv of Cement Hole Casinq Wei.qht Grade Couplina Lenath MD TVD MD TVD {include staqe data) 8-1/2" 7" 26# L-80 BTC 11906' 30' 30' 11936' 7119' 250 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11298 feet Plugs (measured) Set (3rd) Cement Retainer at approx. 10353' (07/03/00) true vertical 6819 feet P&A w/(2nd) Cement Plug at approx. 10253' (07/03/00) Effective depth: measured 10253 feet Junk (measured) Stuck 2nd Sidetrack attempt BHA, left in hole (06/00) true vertical 6367 feet Casing Length Size Cemented MD 'I'VD Structural Conductor 112' 20" 250 sx Arctic set I (Approx.) 112' 112' Surface 5797' 9-5/8" 1300 sx PF 'E', 330 sx 'G', 170 sx PR 5833' 4286' Intermediate Production 11219' 7" 165 sx Class 'G' 10398' 6440' Liner R E C ~!IV [~ D OCT ,.3 o 000 Perforation depth: measured None Alaska 0il & Gas C0'ns, C0mmissi0nORIGINAL true vertical None A~h0rage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Shultz, 564.5491 Prepared By Name/Number. Sondra Stewman, 564-4750 21., hereby certify that the foregl(~il~ is true(~ i('dOcql~/rect to.. the best of my knowledge .~ /~'~? S,i~r.,n,.~d,~ ~lev: Shu,~, ~~ .f~i ~,u~~ ,T,,itl~ ~Senio[ Dr, illi,n,g ~ngin~r ~' Date,.,,,/ Permit Number I APl Number Approval Date See cover letter .2g:~-/'7~, 50-D?--ff -- 2_.2.'~23 I'- 4D '2._ Ii 12~,11)O for other requirements Conditions of Approval: Samples Required [] Yes ,1~ No Mud Log Recl~ui~'ed ~ [] Yes [~No Hydrogen Sulfide Measures ,i~Yes [] No Directional Survey Required ~ Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~,3.5K psi,f~ ero. Approved By ORIGIN^k $1ONED I~¥Commissioner the commission Date Form 10-401 Rev. 12-01-85 J.M. Heusser Friplicate (' Well Plan Summary Well Name: [ MPF-84iB Type of Well (Producer or Injector) 1WAG Iniector Surface Location: Target Bottom Hole Location 2040' NSL, 2976' WEL, SEC 06,T13N,R10E,UM X:541,586'E, Y:6035,490N 3909' NSL, 252'WEL, SEC 02, T13N, R09E X:533,862'E, Y:6037320'N 3988'NSL, 289'WEL, SEC 02,T13N, R09E X:533,825'E, Y:6037399'N I AFE# ] I I Rig [ Doyon#141 I I EstimatedStml Decl,2000 I Days to Drill/Comp 16 MD I 11,936' I I TVD I Well Design (Conventional, Slimhole, ect.) I 7119 I I KBE I 29.5' I Sidetrack and case with 7" log string Objective: Prepare F-84iB by cutting and pulling the existing 7" casing 100 feet below the shoe of the 9 5/8" surface shoe. Set a cement plug in the open hole and then sidetrack the well to the 7" casing point into the Kupamk Sand and then mn and cement a string of 7" casing in place. ..P,.ECE VED OCT 30 ~000 Alas!a 0il & Gas Cons. Commission Anchorage ( Formation Markers Formation Tops MD TVD EMW Formation Pressure Base Permafrost 1902 1800 8.4 ppg 786 psi NA Top Schrader 5493 3910 8.4 ppg 1708 psi Top of HRZ 11,418 6634 TKUD 11,685 6884 TKUB 11,823 7014 TKUA 11,866 7054 TKUA3 11,871 7058 5.5 ppg 2018 psi TKUA2 11,892 7079 5.5 ppg 2024 psi TKUA 1 11,919 7104 5.5 pp~ 2031 psi Miluveach TD 11,936 7120 Casing Hole Size Csg/Tbg Wt/Ft Grade Conn Length Top . Bottom MD/TVD MD/TVD 8 V2" 7" 26# L-80 BTC 11906 30/30 11936/7119 Cementing Program Hole Casing Interval Spacer Density of Volumes Category Size/Depth Cement Production 7" 10,500'- 11,936' 30 bbls 15.6 ppg 250 sx , o Ensure thicking times are adequate relative to pumping job requirement. Actual times should be based on job requirements and lab tests. Perform lab tests on mixed cements, spacers and mud's to ensure compatibility prior to pumping job. Centralizer placement: Run 1 ridgid blade centalizer every other joint for first 10 joints Running 10% excess over theoretical Logging/Formation Evaluation Program: Sperry Sun I 8 ~" Intermediate Hole I MWD/LWD, GR/Res/PWD Current Well Information Well: API: Well Type: Current Status: Last H2S Sample: Cement: BHP: BHT: MPF-84iB IWAG Injector into Kuparuk Sand Well has been temporarily abandon for sidetrack 0 ppg Top of cement plug at 10,250' 1820 psi (5.0 ppg MWE) @ 7000'TVD 165° F@7000'TVD Mechanical Condition: MPF-F-84iB Wellhead Doyon # 141 Tubing: Casing: Casinghead: Tubinghanger: Tree: Casing fluid: Cellar Box MSL=I 1.9' RKB/MSL=29.5'/41.4' Three stands of 3 aA", 9.3# hung off of tubing hanger Conductor: 112', 20", 91.1 ppf, H-40 Surface: 5833', 9 5/8", 40/47#, L-80 Butt Intermediate: 11,252', 7", 29#, L-80,Hydril 563 TOC @ 10,250' FMC- 1 l",5M FMC-11" X 3 aA" Cameron 5M, 3 1/8" Seawater and 2000 feet of diesel Materials Needed: 7", 26#, L-80, Butt Casing (12,000') 11,500' of 3 aA", 9.3 ppf, L-80 NSCT 7X3 Va" Baker S-3 Production Packer 1-3 aA" "XN" nipple with 2.635"ID 2-3 aA" "X" nipples with 2.75" ID 3 aA" WLEG 2-each-3 aA" pup joints (2',4',6',8',10') Mud Program: Baroid Drilling Fluids Inc. Density Vis. YP 10 sec PH API HTHP gels Filtrate 9.6 40-50 10-25 5-8 9.0-9.5 <12 <15 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Expected BHP is 2018 psi. at 7058 feet TVD, with a colume of gas to surface (. l#/ft gradient) the maximum surface pressure would be 1312 psi. Therefore plan to test BOPE to 2000/250 psi for Rams and Valves and 2,000/250 psi for annular Directional: KOP Build section from 62.2° to 73.9°, turning from 268° to 290° Tangent Section at 73.9° Dropping angle from 73.9° to 20°, turning from 290° to 335° Tangent Section @ 20° and 335° Azimuth TD Close Approach Issues 5900' 5900' -6193' 6193 '-9659' 9659'-11100' 11100'-11935' 11935' None Bit Recommendations Plan to run a Hycalog DS 70 for the entire interval Disposal and Wastes Disposal: No "Disposal wastes will be injected or disposed into the F-84iB while drilling this well. Cuttings Handling: Cuttings should be hauled to the ball mill at DS4. The Milne Point reserve pit can be opened in emerfencies by notifying Julie Arin with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations. With all drilling fluids being taken to DS3. Drilling Hazards and Risks 1) Well Control Manatory Well Control Drills Drill Type D 1 Tripping D2 Drilling D3 Accum. D4 Well Kill Frequency Comments (1) per week Inside casing only (1) per week per crew Open or Cased Prior to spud Approx. every 30 days Prior to drill out Prior to drill out Reservoir Pressure Formation pressures are expected to be low due to past production from this block. Pore pressure in the Kupamk reservoir is expected to be 5.5 ppg. 2) Hydrogen Sulfide n Milne Point F pad has not observed any H2S 3) Kick Tolerance a Infinite at 11,936' TD 4) Breathing a Breathing may be a problem wince the Coleville will be opn during drilling therefore, ECD's will be monitored while drilling the 8 W' hole section. 5) Lost Circulation a There is a stron possibility that losses will be incurred while drilling through the production zone. We will be drilling with 8.6 ppg mud weight and the corresponding formation pressure is only 5.5 ppg giving us a differential of 3.1 ppg. 6) Differential Sticking ~ There is a good possibility of differential sticking on this well. If the Kupamk sands are at a formation pressure of only 5.5 ppg as prognosed, the mud will be 3.1 ppg heavier then the formation pressure. 7) Faults We have designed the directional drilling of this well to drill in areas that have less risks of encountering faults. Close Approach Issue n No close approach issues OCT 3O Alaska Oil & 6~s Cons. Commission A~ch0ra.ge Operations Summary Procedure . 2. 3. 4. 5. 6. 7. 8. 9. 10, 11. 12. 13.~ ~ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. MIRU Nabors 22E ND X-mas tree and NU BOPE Pull 3 stands of 3 V2" tubing out of hole and LD same RU wireline and make a JB GR run to top of cement RIH with permanent bridge plug on wireline, set at +5900' MU mechanical casing cutter on 3 V2" drill pipe and RIH Cut 7" casing at +5900' POOH, MU 7", 29# spear, RIH to 300 feet and engage casing Pull casing free and LD same RIH with ~-~.~ drill pipe to +5900' Spot cement kickoff plug from +5900' to +5600' POOH with 3 ¥,-" drill pipe and LD same MU ~ directional drilling assembly RIH on 5" drill pipe Drill out cement and directionally drill to 11,936' Circulate bottoms up RU and run 7", 26#, BUTT casing to TD Cement 7" casing place LD 5" drill pipe in mouse hole RU wireline and RIH with GR/JB to float collar, POOH RIH with CBL to float collar and log back up to 10,500' POOH with wireline and prep for running 4 ~" tubing RIH with 4 V2" completion Land tubing and pump 2000' of diesel freeze protect Drop ball and hydraulically set packer in 7" casing Install BPV ND BOPE and NU X-mas tree RDMO F-84iB Proposed 9 5/8" Casing @ 5833' Seawater inside casing 4 1/2", 12.6#, NSCT TOC @10,250' retainer @ 10350 OP @10398' retainer @ 10,862' 9.6 ppg Drill Mud KOP @ 10,862' 11,066' MD 11,298' Mr 7", 26~ Casing Shoe @11,936' MD 4 1/2" Liner@11,55(] 7", 29#, Casing @ 11,252' D.. 'tllQuest North Slope Alaska Alaska State Plane 4 Milne Point MPF MPF-84B WPs 4800 - Scale: linch = 1200ft Eastings -8400 -7200 -6000 -4800 -3600 I .7' Uner- 11935.95 MD. 7119.60TVD MPF.84BTIJ6878.653"VO / TotaJ Depth: 11935.95ff MD, 7119.60ft'rVD /Begin DIr O 4.000°/10Oft: 9659.02ft MD, 5384.56fl 'rVD / .=_== 13 3/8' Casing .c \ -~_ .... 5327 ~? ~ "~ End DIr '. 6193.22ft MD, 4424.49ft TVD (f~ ST Exit O 8.000°ll00ft, 64.734° TF: 5900.00ff MD, 4314.03ft TVD / I I I I -8400 -7200 -6000 -4800 -3600 Scale: linch = 1200ft Eastings Reference is True North 13 3/8" Casing - 5827.57 MD, 4280.15 TVD .,~o /ST Exit ~ 8.000°/100It 64.734° TF: 5900.00ft MD, 4314.03ffTVD '~~ ~,.~/aegln Dir ~ 4.000°ll00ft: 9659.02ft MD, 5334.56ft 'rVD ~ .... ~/End DIr: 11168.73ft MD, 6398.65ft TVD 3600 4800 6000 7200 8400 Scale: linch = 1200ft Vertical Section Section Azimuth: 284.135° (True North) Current Well Profllrtbe 14odz(mlsl Cu~xt:lndel: Rd. GJQI~I Ceadr,.l~: eoos4~J~ H, Mi SM.61 E I R~. ~u~ R~.~'I~:M~7.S/N. ~..~ E jRig. Oeoglqdllcd CoolcBtalel: 70' 3i7283778' N. 14~ 3G* ~S,a484" W I~ Bevalmt: 3&es1 d~vl k Bee Lf*,d Propoeel Data for MPF-a4B WP01 ~ 8~ I1~ ~ 3~ ~ 1~35N ~.13W ~ o~ SInglo Weft Tarpt Oaa f~ MPF44B WPo : c~ . - 1200 ~o Sperry-Sun Drilling Services Proposal Data - MPF-84B WPs - MPF-84B WP01 [ I)o3. t...'~ '!,!b:,,,' HI.) (i~t.:) ...~ ~ ';,~oc. c.:~:; I~:~. ~.:~,,i ~s. ?, ~:~ .~.~.~ ~.. o~{., ' '. . '.: '. 2vt ~.~ ~s .~ ~°?:~6.~..~ .':~..~.;~"~';:~':i{ 2 61.93.22:i. 293.221 '~'3.93. S 290 35'~ 4424.49 ~ 2:~6'.'46 ,","~82 ...... ' .... ~ ................... . ,, 75 , . .. .. ..' '. ~ ~ ~"'.. ',. ,'2' ~:. :, ~ . , .. ,u. "' ' , ...' ' . ' ;' .~es.,.~. o~:~ 3, ~ '~3.~.~ o 3 ' ~ '" ~ .800 29 ~' ;.~.~.~;,.~.'~2'~ ~.t,o~.'~o~ >.c..cc~: :~.~:, c.~:,c. 6:~,.~ ~o~.oS'~'n:~:':o~'~".'~,~':';.~".~'''' ~" '": '" :'~' " . 000 ',,,,;I"":"~95~ :' .. ,,t{:' . , :. "C.. ':, ' ' ' ~s.~.~.~;'~2.rs:.~:~. ~';",o.,o~'~ 2o.ooo :~'~.ooo ~,,?~.~ ~o.oo.~v2.~ , '~'~.v~ ~ "'".'.'..";;.67,'oo.6 ~o.~b'..~."~':7~.~'~.:~';'.4'~'' . ~,.~. iL.,..,431 ~.06.,,SJz~..~uO: ................... J ............... ~ ....... j...~.. ~..:%/.?..~'~.j .~ ~ ,~. ,.~ o ,~.~ 31 August, 2000 - 13:26 - I - DrillQuest Sperry-Sun Drilling Services Proposal Report for MPF-84B WPs - MPF-84B WP01 Revised: 31 August, 2000 North Slope Alaska Measured Depth (ft) 5900.00 Incl. 62.234 Azim. 268.352 Sub-Sea Depth (ft) 4275.38 6000.00 65.873 276.279 4319.18 6100.00 69.897 283.745 4356.87 6193.22 73.918 290.355 4385.84 6200.00 73.918 290.355 4387.72 6300.00 73.918 290.355 4415.42 6400.00 73.918 290.355 4443.12 650~00 73.918 290.355 4470.82 6600.00 73.918 290.365 4498.52 6700.00 73.918 290.355 4526.22 6800.00 73.918 290.355 4553.93 6900.00 73.918 290.355 4581.63 7000.00 73.918 290.355 4609.33 7100.00 73.918 290.355 4637.03 7200.00 73.918 290.355 4664.73 7300.00 73.918 290.355 4692.43 7400.00 73.918 290.355 4720.13 7500.00 73.918 290.355 4747.83 7600.00 73.918 290.355 4775.53 7700.00 73.918 290.355 4803.24 7800.00 73.918 290.355 4830.94 7900.00 73.918 290.355 4858.64 8000.00 73.918 290.355 4886.34 8100.00 73.918 290.355 4914.04 8200.00 73.918 290.355 4941.74 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft). (ft) (ft) 4314.03 27.16 S 3380.90 W 6035444.76 N 538205.92 E 4357.83 23.445 3470.63W 6035447.98 N 538116.17 E 4395.52 7.26 S 3561.74W 6035463.65 N 538024.96 E 4424.49 18.75 N 3646.37W 6035489.19 N 537940.19 E 4426.37 21.02 N 3652.48W 6035491.42N 537934.07 E 4454.07 54.44 N 3742.56W 6035524.34 N 537843.80 E 4481.77 87.86 N 3832.65W 6035557.25N 537753.53 E 4509.47 121.28 N 3922.74W 6035590.17 N 537663.26 E 4537.17 154.71N 4012.82W 6035623.09 N 537572.98 E 4564.87 188.13 N 4102.91W 6035656.01N 537482.71E 4592.58 221.55 N 4193.00W 6035688.92 N 537392.44 E 4620.28 254.97N 4283.08W 6035721.84 N 537302.17 E 4647.98 288.40 N 4373.17W 6035754.76N 537211.89 E 4675.68 321.82 N 4463.26W 6035787.68 N 537121.62 E 4703.38 355.24N 4553.34W 6035820.59 N 537031.35 E 4731.08 388.66 N 4643.43W 6035853.51N 536941.08 E 4758.78 422.08 N 4733.52W 6035886.43N 536850.81E 4786.48 455.51N 4823.60W 6035919.35 N 536760.53 E 4814.18 458.93 N 4913.69W 6035952.26 N 536670.26 E 4341.89 522.35 N 5003.78W 6035985.18 N 536579.99 E 4869.59 555.77N 5093.86W 6036018.10 N 536489.72 E 4897.29 589.20 N 5183.95W 6036051.02N 536399.44 E 4924.99 622.62 N 5274.04W 6036083.93 N 536309.17 E 4952.69 656.04 N 5364.12W 6036116.85 N 536218.90 E 4980.39 689.46 N 5454.21W 6036149.77N 536128.63 E Dogleg Rate (°llOOfl) 8.000 8.000 8.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Milne Point MPF Vertical Section (ft) 3271.91 3359.83 3452.14 3540.55 3547.03 3642.55 3738.07 3833.59 3929.11 4024.63 4120.16 4215.68 4311.20 4406.72 4502.24 4597.76 4693.28 4788.80 4884.32 4979.84 5075.36 5170.89 5266.41 5361.93 5457.45 Comment · ST Exit @ 8 000°/100ft. 64.734° TF i' 5900.00ft MD, 4314.03ft TVD End Dir: 6193.22ft MD, 4424.49ft TVD Continued... 31 August 2000-13:26 -I- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPF-84B WPs - MPF-84B WP01 Revised: 31 August, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 8300.00 73.918 290.355 4969.44 5008.09 8400.00 73.918 290.355 4997.14 5035.79 8500.00 73.918 290.355 5024.84 5063.49 8600.00 73.918 290.355 5052.55 5091.20 8700.00 73.918 290.355 5080.25 5118.90 8800.00 73.918 290.355 5107.95 5146.60 8900.00 73.918 290.355 5135.65 5174.30 9000.00 73.918 290.355 5163.35 5202.00 9100.00 73.918 290.355 5191.05 5229.70 9200.00 73.918 290.355 5218.75 5257.40 9300.00 73.918 290.355 5246.45 5285.10 9400.00 73.918 290.355 5274.16 5312.81 9500.00 73.918 290.355 5301.86 5340.51 9600.00 73.918 290.355 5329.56 5368.21 9659.02 73.918 290.355 5345.91 5384.56 9700.00 72.343 290.830 5357.80 5396.45 9800.00 68.506 292.028 5391.30 5429.95 9900.00 64.677 293.290 5431.02 5469.67 10000.00 60.860 294.635 5476.77 5515.42 10100.00 57.057 296.084 5528.33 5566.98 10200.00 53.273 297.662 5585.44 5624.09 10300.00 49.511 299.404 5647.84 5686.49 10400.00 45.779 301.352 5715.20 5753.85 10500.00 42.084 303.563 5787.21 5825.86 10600.00 38.438 306.112 5863.51 5902.16 Local Coordinates Global Coordinates Northings Eastings Northings Eastings 722.89 N 5544.30W 6036182.69 N 536038.35 E 756.31N 5634.38W 6036215.60 N 535948.08 E 789.73 N 5724.47W 6036248.52N 535857.81E 823.15 N 5814.56W 6036281.44 N 535767.54 E 856.57N 5904.64W 6036314.36 N 535677.27 E 890.00 N 5994.73W 6036347.27 N 535586.99 E 923.42 N 6084.82W 6036380.19 N 535496.72 E 956.84 N 6174.90W 6036413.11N 535406.45 E 990.26 N 6264.99W 6036446.03 N 535316.18 E 1023.69 N 6355.07W 6036478.94 N 535225.90E 1057.11N 6445.16W 6036511.86 N 535135.63 E 1090.53 N 6535.25W 6036544.78 N 535045.36 E 1123.95 N 6625.33W 6036577.70 N 534955.09 E 1157.38 N 6715.42W 6036610.61N 534864.81E 1177.10 N 6768.59W 6036630.04 N 534811.54 E 1190.89 N 6805.30W 6036843.63 N 534774.75 E 1225.30 N 6892.99W 6036677.54 N 534686.87 E 1260.63 N 6977.67W 6036712.40 N 534602.00E 1296.72N 7058.91W 6036748.03 N 534520.55 E 1333.39 N 7136.32W 6036784.27 N 534442.93 E 1370.46 N 7209.53W 6036820.93 N 534369.52 E 1407.75N 7278.18W 6036857.83 N 534300.66 E 1445.08 N 7341.94W 6036894.80 N 534236.70E 1482.26 N 7400.49W 6036931.66 N 534177.94 E 1519.12 N 7453.54W 6036968.22 N 534124.68 E Dogleg Rate (o/100ft) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 Alaska State Plane 4 Milne Point MPF Vertical Section (fi) 5552.97 5648.49 5744.01 5839.53 5935.05 6030.57 6126.10 6221.62 6317.14 6412.66 6508.18 6603.70 6699.22 6794.74 6851.12 6890.08 6983.52 7074.26 7161.86 7245.88 7325.93 7401.61 7472.55 7538.40 7598.86 Comment Benin Dir @ 4.000°/1001t: 9659.02ft MD, 5384.56ft TVD Continued... 31Augus~ 2000-13:26 -2- DrillQuest 1.05.05;; r- Sperry-Sun Drilling Services Proposal Report for MPF-84B WPs - MPF-84B WP01 Revised: 31 August, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (~) 10700.00 34.857 309.102 5943.74 10800.00 31.364 312.673 6027.49 10900.00 27.991 317.023 6114.37 11000.00 24.789 322.426 6203.95 11100.00 21.832 329.252 6295.80 11168.73 20.000 335.000 6360.00 11200.00 20.000 335.000 6389.39 11300.00 20.000 335.000 6483.36 11400.00 20.000 335.000 6577.33 11418.81 20.000 335.000 6595.00 11461.37 20.000 335.000 6635.00 11500.00 20.000 335.000 6671.30 11525.22 20.000 335.000 6695.00 11600.00 20.000 335.000 6765.27 11679.53 20.000 335.000 6840.00 11684.85 20.000 335.000 6845.00 11700.00 20.000 335.000 6859.23 11785.95 20.000 335.000 6940.00 11800.00 20.000 335.000 6953.20 11823.19 20.000 335.000 6975.00 11865.76 20.000 335.000 7015.00 11871.08 20.000 335.000 7020.00 11892.37 20.000 335.000 7040.00 11900.00 20.000 335.000 7047.17 11918.97 20.000 335.000 7065.00 Ve~ical Local Coordinates · Global Coordinates Depth Nodhings Eastings Nothings Eastings (fi) (fi) (~) (~) (~) 5982.39 1555.48 N 7500.85W 6037004.32 N 534077.17 E 6066.14 1591.16 N 7542.18W 6037039.76 N 534035.64 E 6153.02 1625.98 N 7577.32W 6037074.39 N 534000.30 E 6242.60 1659.78N 7606.11W 6037108.02 N 533971.32 E 6334.45 1692.39 N 7628.41W 6037140.51N 533948.84E 6398.65 1714.03 N 7639.92W 6037162.08 N 533937.22 E 6428.04 1723.72 N 7644.44W 6037171.75 N 533932.64E 6522.01 1754.72N 7658.89W 6037202.66 N 533918.02 E 6615.98 1785.71N 7673.34W 6037233.58 N 533903.39 E 6633.65 1791.54 N 7676.06W 6037239.39 N 533900.64 E 6673.65 1804.74 N 7682.22W 6037252.55 N 533894.41E 6709.95 1816.71N 7687.80W 6037264.50 N 533888.76 E 6733.65 1824.53 N 7691.45W 6037272.29 N 533885.07E 6803.92 1847.71N 7702.25W 6037295.41N 533874.13 E 6878.65 1872.36 N 7713.75W 6037320.00 N 533862.50 E 6883.65 1874.01N 7714.52W 6037321.65 N 533861.72E 6897.88 1878.71N 7716.71W 6037326.33 N 533859.51E 6978.65 1905.35 N 7729.13W 6037352.90 N 533846.93 E 6991.85 1909.70N 7731.16W 6037357.24 N 533844.88 E 7013.65 1916.89 N 7734.51W 6037364.42N 533841.49 E 7053.65 1930.09 N 7740.67W 6037377.58 N 533835.26 E 7058.65 1931.74 N 7741.44W 6037379.22 N 533834.48 E 7078.65 1938.34 N 7744.51W 6037385.80 N 533831.37E 7085.82 1940.70 N 7745.62W 6037388.16 N 533830.25 E 7103.65 1946.58 N 7748.38W 6037394.03 N 533827.48 E Dogleg Rate (°/100~) 4.000 4.000 4.000 4.000 4.000 4.000 0.000 0.000 0.000 0,000 0.000 0.000 0.000 0.000 0,000 0.000 0.000 0.000 0,000 0.000 0.000 0,000 0.000 0,000 0.000 Alaska State Plane 4 Milne Point MPF Ve~ical Section (~) 7653.61 7702.40 7744.98 7781.16 7810.74 7827.18 7833.93 7855.52 7877.10 7881.16 7890.35 7898.69 7904.14 7920.28 7937.45 7938.59 7941.86 7960.42 7963.45 7968.46 7977.65 7978.79 7983.39 7985.04 7989.13 Comment End Dir: 11168.73ft MD, 6398.65ft TVD THRZ BHRZ KLGM Target - MPF-84B T1 TKUD TKUB TKUA TKA3 TKA2 TKA1 Continued... 31 August 2000-13:26 -3- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPF-84B WPs - MPF-84B WP01 Revised: 31 August, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 11935.95 20.000 335.000 7080.95 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 7119.60 1951.84 N 7750.81 W 6037399.27 N 533824.99 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MPF-84B. Northings and Eastings are relative to MPF-84B. Dogleg Rate (°/100ft) 0.000 Alaska State Plane 4 Vertical Section (ft) 7992.80 Milne Point MPF ..,. Comment Total De~th: 11935.95ft MD, 7119.60ft TVD 7" Liner The Dogleg Severity is in Degrees per 100ft. Vertical Section is from MPF-84B and calculated along an Azimuth of 284.135° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11935.95ft., The Bottom Hole Displacement is 7992.80ft., in the Direction of 284.135° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 5900.00 4314.03 27.16 S 3380.90 W 6193.22 4424.49 18.75 N 3646.37 W 9659.02 5384.56 1177.10 N 6768.59 W 11168.73 6398.65 1714.03 N 7639.92 W 11935.95 7119.60 1951.84 N 7750.81 W Comment ST Exit @ 8.000°/100ft, 64.734° TF: 5900.00ft MD, 4314.03ft TVD End Dir: 6193.22ft MD, 4424.49ft TVD Begin Dir @ 4.000°/100ft: 9659.02ft MD, 5384.56ft TVD End Dir: 11168.73ft MD, 6398.65ft TVD Total Depth: 11935.95ft MD, 7119.60ft TVD Continued... 31 August, 2000- 13:26 -4- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for MPF-84B WPs - MPF-84B WP01 Revised: 31 August, 2000 North Slope Alaska Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings Eaatings Formation Name (ft) (ft) (ft) (ft) (ft) 11418.81 6633.65 6595,00 1791,54 N 7676.06 W THRZ 11461.37 6673.65 6635.00 1804.74 N 7682.22 W BHRZ 11525.22 6733.65 6695,00 1824.53 N 7691.45 W KLGM 11684.85 6883.65 6845.00 1874.01 N 7714.52 W TKUD 11823.19 7013.65 6975.00 1916.89 N 7734.51 W TKUB 11865,76 7053.65 7015.00 1930.09 N 7740.67 W TKUA 11871,08 7058.85 7020.00 1931,74 N 7741,44 W TKA3 11892,37 7078.85 7040.00 1938.34 N 7744,51 W TKA2 11918,97 7103.65 7065,00 1946.58 N 7748,36 W TKA1 Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) <Surface> <Surface> 5840.09 4286.00 <Surface> <Surface> <Run-TD> <Run-TD> Casing Detail 9 5/8" Casing 7" Liner Alaska State Plane 4 Milne Point MPF Continued... 31 August, 2000 - 13:26 DrillQuest 1.05.05a .. Sperry-Sun Drilling Services Proposal Report for MPF-84B WPs - MPF-84B WP01 Revised: 31 August, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPF Targets associated with this wellpath Target Name MPF-84B Polygon MPF-84B T1 Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Boundary Point #1 #2 #3 #4 Mean Sea Level/Global Coordinates #1 #2 #3 #4 Geographical Coordinates #1 #2 #3 #4 Mean Sea Level/Global Coordinates: Geographical Coordinates: Target TVD (ft) 8803.65 8765.00 8803.65 8803.65 8803.65 8803.65 8765.00 8765.00 8765.00 8765.00 6878.65 6840.00 Entry Coordinates Northings Eastings (ft) (ft) 7435.78 N 1874.05 E 6042937.00 N 543419.00 E 70°31'41.5111" N 149° 38'39.8343"W 7536.33 N 1774.61 E 7535.21 N 1974.60 E 7335.22 N 1973.48 E 7336.34 N 1773.49 E 6043037.00 N 543319.00 E 6043037.00 N 543519.00 E 6042837.00 N 543519.00 E 6042837.00 N 543319.00 E 70° 31' 42.5004" N 149° 38' 42.7655" W 70° 31' 42.4889" N 149° 38' 36.8687" W 70° 31' 40.5218" N 149° 38' 36.9033" W 70° 31' 40.5333" N 149° 38' 42.7999" W 1872.36 N 7713.75W 6037320.00 N 533862.50 E 70°30'46.7542"N 149° 43'22.3486'W Target Target Shape Type Polygon Point 31 August, 2000 - 13:26 - 6 - DrillQuest 1.05.05a H 17 405 DATE 101200 PYMT HANDL INVOICE I CREDIT MEMO CK1012OOA iOMMENTS: 'NG INST: PERI S/H THE ATI'ACHED CHECK IS IN PAYMENT FOR ITEMS DESCRiiF.~ ABOVE. 10/17/00 VE.OO. At OESC.~m~ON GROSS O,SCOUNT liT TO DRILL SONDRA X4730 .'EE 100.00 100.00 CHECK NO. 0017&405 ~SKASTAT 10 NET 100.00 100.00 ,' ;i, ? P, t, 0 5,' ~:0 h I, ~0 36 c] 5': 008 t, WELL PERMIT CHECKLIST COMPANY FIELD & POOL ADMINISTRATION 1. . 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE _ 12. WELL NAME INIT CLASS ,~;~iE.~,t/c--~-''- /~),~9/,4,/ ENGINEERING PROGRAM: exp dev redril "/ serv v/' wellbore seg GEOL AREA ~'~'~'~ UNIT# (~)///~Z.. ~ _DATE ann. disposa! para req ON/OFF SHORE ~)~ Permit fee attached ....................... Lease number appropriate ................... Unique well name and.number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... ' Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ...... : . Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... GEOLOGY ,. 14. Conductor string provided .... · ........ ' ....... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg.......... 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ......... _.~... 2.6. BOPE press rating appropriate; test to ~,~S'(~r~ ~)s~gl 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued wlo hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones .......... '.'".. ~ ~,/"Y N 33. Seabed condition survey (if off-shore) ....... ... //,4 ~' y N 34. Contact name/phone for weekly progress reports./~ratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste .... to surface; " Comments/Instructions: Y N Y N (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and " (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLQG.Y; ENGINEERING: UlClAnnular COMMISSION: c:VnsoffiCe\wordian~iana~checklist (rev. 02/17100) .. Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No 'special'effort has been made to chronologically organize this category of information. '...: Sperry-Sun Dril].Sng Services LIS Scan Utilit._v SRevision: 3 S LisLib SRevision: 4 $ Tue Jan 29 13:19:59 2002 keel Header Service name ............. LISTPE Date ..................... 02/01/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/01/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services 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: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-00293 R. FRENCH J. PYRON MPF-84B 500292293102 BP Exploration (Alaska), Inc. Sperry Sun 29-JAN-02 6 13N 10E 2040 2182 .00 41.40 11.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.625 5823.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GBb94A RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). GAMMA RAY LOGGED BEHIND CASING TO 5823' MD, 4279' TVD. 4. DIGITAL AND LOG DATA ARE DEPTH CORRECTED TO THE PDC GR LOG OF 12/18/00 WITH KBE = 41.4' A.M.S.L.. MPF-84B KICKS OFF FROM MPF-84 AT 5854' MD, 4294' TVD. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. MWD RUN 1 REPRESENTS WELL MPF-84B WITH AP1 # 50-029-22931-02. THIS WELL REACHED A TOTAL, DEPTH OF 11980' MD, 7151' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERI'VED 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 $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 5752.0 11932.5 RPX 5820.0 11925.0 RPS 5820.0 11925.0 RPM 5820.0 11925.0 RPD 5820.0 11925.0 ROP 5861.0 11986.0 FET 5861.0 11925.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 5752.0 5745.0 5756.0 5749.5 5759.5 5752.0 5767.0 5759.0 5777.5 5770.5 5779.0 5772.5 5786.5 5779.0 5797.0 5789.0 5808.5 5802.0 5826.5 5819.5 5829.5 5823.5 EQUIVALENT UNSHIFTED DEPTH 5834.5 5843.5 5846.5 5855.0 5858.5 5861.5 5869.0 5895.5 5907.5 5913.5 5916.0 5925.0 5929.5 5939.0 5962.5 5974.0 5994.5 5996.5 5998.0 6003.5 6014.5 6018.0 6019.5 6032.0 6036.5 6046.0 6062.5 6066.5 6073.0 6078.5 6088.5 6101.5 6107.5 6121.0 6122.5 6134.0 6144.5 6160.0 6164.5 6168.5 6172.0 6176.0 6179.5 6203.5 6215.5 6228.5 6239.5 6250.0 6260.5 6266.5 6268.0 6273.0 6278.0 6286.5 6293.0 6301.5 6314.0 6330.0 6335.5 6354.0 6363.0 6379.0 6402.5 6413.0 6424.5 6430.0 6440.0 6455.0 6489.0 6562.5 6573.0 6579.5 6601.0 6605.0 6618.5 5827.0 5834.5 5840.0 5848.5 5853.0 5854.5 5863.0 5888.5 5901.5 5909 0 5911 0 5920 5 5927 0 5935 0 5956 5 5966.5 5987.0 5989.0 5992.5 5997.5 6007.0 6011.5 6013.5 6026 0 6030 5 6041 0 6057 5 6063 0 6069 5 6074 5 6084.5 6096.5 6103.5 6120.5 6125.0 6136.0 6144.5 6157.0 6160.5 6165.0 6168.0 6172.5 6179.0 6198.0 6212.0 6227.5 6235.5 6247.0 6255.0 6260.5 6262.5 6267.0 6271.0 6281.0 6289.0 6297.5 6313.0 6330.0 6333.5 6355.0 6363.5 6380.0 64 00.0 6408.5 6420.0 6426.5 6437.5 6450.0 6486.0 6562.0 6569.5 6574.0 6593.5 6599.0 6615.5 6625.5 6640.5 6644.0 6650.5 ,.3660.0 C:,664.0 6665.5 6667.5 6673.5 6679.0 6688.5 6697.0 6702.0 6703.5 6706.5 6709.0 6714.5 6723.0 6724.0 6730.5 6734.5 6738.0 6742.0 6748.5 6752.5 6754.0 6761.5 6770.0 6792.5 6798.0 6822.0 6828.5 6852.5 6857.5 6859.0 6861.0 6888.5 6900.0 6907.0 6908.5 6921.5 6932.0 6959.5 6962.0 6967.0 6968.5 6976.0 6989.0 6990.5 6991.5 6996.5 6998.0 6999.5 7005.0 7018.5 7025.0 7037.0 7041.5 7046.5 7052.5 7066.5 7072.5 7081.5 7083.0 7O88.0 7094.0 7099.5 7112.5 7129.0 7131.5 7138.0 7160.5 7198.5 7230.0 7247.0 6621.5. 6638.5 6642.5 6648.5 6656.5 6660.0 6662.5 6663.5 6668.5 6674.5 6684.5 6693.0 6696.5 6698.5 6702.5 6704.5 6709.0 6717.0 6720.0 6726.5 6731.0 6736.5 6739.5 6745.0 6747.5 6750.5 6759.0 6767.5 6784.5 6794.5 6818.0 6826.5 6849.5 6854.5 6855.5 6857.0 6883.5 6898.0 6908.0 6909.5 6922.5 6931.5 6958.0 6962.0 6965.5 6968.5 6975.0 6990.0 6991.5 6992.5 6995.0 6997.5 6998.5 7002.0 7017.0 7021.5 7034.0 7036.5 7047.0 7053.0 7064.0 7069.5 7079.5 7082.0 7087.0 7093.0 7099,5 7106.5 7129.5 7133.5 7143.0 7167.0 7207.5 7238.0 7257.5 7263.0 7292.0 7295.5 7299.0 7305.5 7320.0 7324.0 7325.5 7326.5 7330.0 7347.0 7351.5 7358.0 7360.5 7363.0 7366.0 7372.0 7381.5 7403.5 7414.0 7452.0 7457.0 7460.5 7480.0 7486.0 7495.5 7498.0 7503.5 7510.5 7525.0 7527.5 7532.5 7548.5 7598.0 7607 0 7610 0 7635 5 7662 0 7667 5 7670 5 7672 0 7675.5 7680.5 7686.5 7692.0 7695.0 7703.5 7712.0 7741.0 7749.0 7754.0 7762.5 7774.0 7790.5 7792.0 7794.5 7798.0 7800.5 7829.5 7842.0 7846.5 7900.5 7901.5 7910.5 7914.5 7922.5 7932.0 7938.5 7942.0 7946.0 7969.5 7977.5 7992.0 8002.0 8014.0 7273.0 7304.5 7306.5 7310. '~. 7320.0 7333.5 7336.0 7337.5 7339.0 7342.5 7354.5 7359.0 7367.0 7371.0 7373.0 7376.5 7382.0 7395.0 7416.0 7425.5 7457 5 7461 0 7464 0 7481 5 7487 0 7494 5 7497 0 7501 0 7508.5 7521.5 7524.5 7530.0 7545.0 7594.5 7604.0 7606.0 7632.5 7658.5 7665.0 7668.0 7669.5 7671.0 7674.5 7681.0 7684.5 7685.5 7693.0 7700.0 7734.0 7742.5 7745.5 7752.5 7770.5 7786.0 7788.5 7791.5 7794.0 7797.0 7828.0 7839.5 7845.5 7895.5 7897.5 7907.5 7911.5 7915.5 7925.0 7930.0 7936.0 7940.5 7964.5 7973.5 7987.5 7999.0 8010.0 8015 5 8023 0 8035 5 8061 0 8120 0 8134 5 ,9154 5 8163.5 8165.0 8168.0 8170.5 8173.0 8176.0 8190.5 8199.0 8203.0 8212.0 8221.5 8225.0 8228.5 8233.5 8235.0 8238.5 8241.0 8247.5 8251.0 8253 0 8260 0 8337 0 8356 5 8361 0 8372 0 8376 5 8397 5 8402 0 8414 0 8427.5 8428.5 8436.5 8438.5 8510.0 8512.5 8516.0 8522.0 8530.5 8535.5 8549.0 8565.0 8572.0 8575.5 8586.5 8598.0 8604.0 8613.0 8643.0 8649.5 8661.0 8663.5 8670.0 8688.0 8691.5 8696.0 8698.5 8700.0 8706.0 8752.0 8763.5 8771.5 8787.0 8788.5 8792.5 8794.0 8803.5 8818.5 8825.0 8012.0 8020.0 8033.5 8C)58.5 8112.5 8127.0 8146.5 8155.5 8158.0 8162.5 8165.0 8168.0 8169.5 8183.5 8193.5 8197.0 8206.5 8216 5 8219 5 8222 5 8228 0 8229 0 8231 0 8234 0 8238 5 8243.0 8246.5 8252.5 8330.0 8351.5 8356.0 8364.0 8367.0 8397.5 8402.5 8415 5 8428 0 8430 0 8436 0 8439 0 8506 0 8509.0 8512.0 8520.0 8530.0 8534.5 8551.5 8566.5 8576.5 8581.5 8592.5 8600.0 8607.0 8612.5 8639.5 8644.5 8656.0 8658.5 8664.5 8681.5 8684 0 8689 5 8691 0 8693 5 8700 5 8747 0 8759.5 8767.0 8784.5 8785.5 8790.0 8792.0 8799.0 8811.0 8819.0 ~832 5 °835 0 ,., . °85° 0 8861.5 8876.0 °886 0 ,_., . 8890.0 8903.0 8907.0 8918.0 8921.0 8943.5 8969.0 8999.5 9017.0 9034.0 9039.5 9045.5 9053.5 9067.5 9090.5 9095.5 9098.0 9119.0 9124.0 9141.0 9145.5 9154.0 9181.0 9193.5 9210.0 9254.0 9259.5 9261.0 9265 5 9271 0 9272 5 9275 0 9290 0 9331 0 9337 5 9347.5 9360.5 9363.5 9368.0 9400.5 9406.5 9420.5 9429.0 9434.5 9446.0 9452.0 9455.0 9463.0 9467.5 9486.5 9488.5 9492.0 9503.5 9513.0 9523.5 9534.0 9544.5 9550.5 9560.5 9564.5 9580.0 9589.5 9592.0 9608.5 9626.5 9629.5 9631.0 9636.0 9665.5 8829. 8831. 8852.5 8854. 8866.5 8876.5 8882.5 8897.0 8901.0 8912.0 8915.5 8935.0 8962.0 8996.5 9014.0 9029.0 9034.0 9040 0 904 9 0 9064 0 9084 0 9089 5 9091 0 9111 0 9117.0 9132.0 9137.0 9147.0 9174.0 9188.5 9205.0 9245.5 9251.0 9253.5 9257.0 9262.0 9264.0 9267.0 9280.5 9325.0 9331.0 9342.5 9352.0 9357.0 9360.5 9394.0 9401.5 9414.5 9421.5 9426.5 9439.0 9444.5 9448.0 9457.0 9460.5 9478.5 9480.5 9483.0 9493.0 9505.0 9515.5 9526.5 9536.0 9541.0 9551.5 9555.5 9568.5 9580.0 9583.5 9600.0 9615.5 9618.0 9620.5 9626.5 9658.0 9677.0 967 8.5 9680.5 9682 5 9684 0 9689 5 9697 0 9699 5 9711 5 9726 0 9730 5 97,~ 3.0 9747.0 9756.5 9760.0 9770.5 9782.5 9797.5 9800.5 9805.0 9810.0 9813.0 9822.5 9824.0 9829.5 9837.0 9838.0 9849.5 9854.5 9856.0 9884.0 9892.5 9933.5 9944.0 9952.5 9960.0 9970.5 9981.0 9984.5 9991.5 9993.0 9999.5 10009.0 10025.5 10043.0 10049.0 10051.0 10053.0 10062.5 10081.5 10093.0 10097.5 10106.5 10121.5 10126.5 10152.0 10158.0 10159.0 10181.5 10189.5 10197.0 10204.0 10206.5 10209.5 10214.0 10221.5 10234.5 10258.0 10260.5 10277.0 10282.0 10290.5 10291.5 10295.5 10311.0 9671 il, 9673 5 9675 { 9677 < 9679 5 9690 0 9697 5 9701 5 9710 0 9722 5 9727 0 9739.5 9743.5 9751.5 9754.5 9764.0 9776.0 9795.0 9797.5 9800.5 9805.0 9808.5 9816.0 9818.0 9824.5 9833.0 9835.5 9845.5 9850.0 9852.0 9880.5 9888.5 9930.5 9942.0 9952.0 9958.5 9967.0 9973.0 9977.0 9986.0 9987.5 9998.5 10007.0 10024.5 10040.5 10046.0 10048.0 10050.5 10057.0 10074.5 10085.0 10091.0 10100.0 10116.0 10122.5 10142.0 10149.5 10151.5 10173.5 10184.0 10189.5 10197.5 10199.5 10203.0 10207.0 10215.5 10227.5 10250.5 10253.5 10271.0 10275.5 10284.0 10286.0 10291.0 10310.5 ].0316.0 10334.5 10360.0 10369.0 ] 0378.0 10384.5 10386.0 10387.0 10402.0 10411.5 10422.5 10433.5 10450.5 10462.5 10473.5 10492 0 10510 5 10522 0 10524 5 ]. 0527 0 10535 5 10656 5 10712 0 10838 0 10840 0 10882.5 10915.0 10946.0 10985.5 10995.5 11000.0 11003.5 11032.0 11033.5 11041.0 11050.0 11062.0 11064.5 11069.5 11080.0 11082.0 11093.0 11103.5 11107.5 11109.0 11146.0 11152.5 11157.5 11159.0 11161.5 11166.5 11173.5 11187.0 11204.0 11209.5 11212.5 11215.5 11226.0 11232.0 11236.0 11239.5 11245.5 11259.5 11267.5 11271.0 11275.5 11284.5 11290.5 11293.0 11294.5 11297.0 11307.0 11312.0 11318.5 11320.0 10313.5 10330. 10359.5 ! 0368. < 10376.5 10382.5 10384.0 10386.0 10396.0 10404.5 10415.5 104'29.5 10440.0 10455.0 10470.5 10488.5 10507.0 10517.0 10520.0 10522.0 10531.0 10653.5 10707.0 10835.0 10837.5 10879.5 10911.5 10942.0 10981.5 10992.0 10998.0 11001.5 11029.0 11030.0 11038.5 11049.0 11060.5 11062.5 11068.5 11077.5 11078.5 11087.5 11100.5 11107.0 11110.0 11145.0 11151.0 11157.0 11159.0 11161.5 11166.0 11172.0 11185.0 11201.5 11206.0 11208.5 11211.5 11223.5 11230.5 11233.0 11235.5 11242.0 11257.0 11263.5 11267.0 11270.5 11282.0 11287.0 11290.0 11291.5 11294.0 11305.0 11307.5 11316.0 11317.5 ].1324.5 11337.5 11346.5 11349.5 11358.0 11363.0 1137° 5 ,., 11383 0 11392 5 11394 5 11398 0 11405 0 11409.0 11411.5 11413.0 11415.5 11418.0 11434.0 11442.0 11482.5 11487.5 11504.5 11514.0 11519.0 11521.5 11523.5 11527.5 11529.5 11533.5 11538.0 11556.0 11558.0 11564.0 11565.5 11572.0 11577.5 11582.5 11590.0 11594.0 11598.5 11602.0 11603.5 11607.0 11620.5 11625.5 11629.5 11634.5 11636.5 11638.0 11651.0 11654.5 11662.5 11665.5 11669.5 11677.5 11683.5 11703.0 11707.0 11713.0 11717.5 11722.0 11730.5 11734.0 11737.5 11741.0 11745.0 11751.5 11760.0 11762.0 11764.0 11773.0 11780.0 11781.5 11783.5 11986.0 1] 323; 11336 C' !!34t: '~ 11356 5 11361 0 11376 0 11382 0 11389 0 11390 5 11394 5 11402 0 11405 5 11408 0 11410 5 11412 5 11414 5 11430 5 11438 5 11477 5 11483 5 11501 0 11510.5 11515.5 1151 9 0 11520 5 11522 0 11524 5 11529 5 11534 5 11552 5 11554.0 11560.0 11562.5 11568.5 11574.5 11580.5 11587.0 11590.5 11595.5 11598.0 11599.5 11602.5 11615.5 11621.0 11624.0 11629.0 11631.5 11634.0 11647.5 11649.5 11658.0 11661.5 11665.5 11673.0 11679.0 11698.0 11702.5 11710.0 11715.0 117].7.5 11726.5 11729.5 11733.5 11736.5 11740.5 11747.0 11755 5 11757 0 11759 5 11768 5 11775 0 11776 5 11778 0 11980.5 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 1 5745.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order MERGE BASE 11980.5 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 HR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 5752 11986 ROP MWD FT/H 3.06 450.74 GR MWD API 35.59 328.59 RPX MWD OHMM 0.71 1300.3 RPS MWD OHMM 0.69 1041.58 RPM MWD OHMM 0.64 1931.05 RPD MWD OHMM 0.68 2000 FET MWD HR 0.29 19.38 First Reading For Entire File .......... 5752 Last Reading For Entire File ........... 11986 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 First Mean Nsam Reading 8869 1.2469 5752 128.61 12251 5861 105.651 12362 5752 3.27926 12211 5820 3.26322 12211 5820 3.78521 12211 5820 5.75256 12211 5820 1..08122 121,29 5861 Last Reading 11986 1].986 11932.5 11925 11925 11925 11925 11925 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5745.0 11927.0 RPX 5813.0 11919.5 RPS 5813.0 11919.5 RPM 5813.0 11919.5 RPD 5813.0 11919.5 ROP 5854 . 5 11 980.5 FET 5854 . 5 11919.5 $ LOG HEADER DATA DATE LOGGED: 16-DEC-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05 DOWNHOLE SOFTWARE VERSION: 65.44 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11980.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 15.1 MAXIMUM ANGLE: 75.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01765HWRG6 EWR4 ELECTROMAG. RESIS. 4 PB01765HWRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT:. MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 8.500 11980.0 Water Based 9.70 54.0 8.8 700 2.8 1.980 74.0 .983 156.0 2.200 74.0 2.450 74.0 Name Service Order DEPT ROP MWD010 3R MWD010 RPX MWDO10 RPS MWD010 RPM MWD01 0 RPD ~D010 FET MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HR 4 1 68 28 8 Name Service Unit Min DEPT FT 5745 ROP MWD010 FT/H 3.06 GR MWD010 APl 35.59 RPX MWD010 OHMM 0.65 RPS MWD010 OHMM 0.69 RPM MWDO10 OHMM 0.64 RPD MWD010 OHMM 0.68 FET MWD010 HR 0.29 First Max Mean Nsam Reading 11980.5 8862.75 12472 5745 465.93 128.712 12253 5854.5 328.59 105.649 12365 5745 1300.3 3.28747 12214 5813 1041.58 3.27181 12214 5813 1931.05 3.81627 12214 5813 2000 6.02323 12214 5813 19.38 1.08108 12131 5854.5 First Reading For Entire File .......... 5745 Last Reading For Entire File ........... 11980.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/01/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Last Reading 11980.5 11980.5 11927 11919.5 11919.5 11919.5 11919.5 11919.5 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/01./29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Nu~er ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/01/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWqq Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
