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Home My WebLink About200-093CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Not Operable: WAG Injector MPF-83 (PTD: 2000930) Not Operable due to being shut in for its 4-year MIT-IA Date:Monday, November 24, 2025 10:27:03 AM From: Stephen Soroka <steve.soroka@hilcorp.com> Sent: Monday, November 24, 2025 10:25 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: Not Operable: WAG Injector MPF-83 (PTD: 2000930) Not Operable due to being shut in for its 4-year MIT-IA Mr. Wallace WAG Injector MPF-83 (PTD: 2000930) is currently shut in and will not be brought online for its scheduled 4-year MIT-IA, due in November. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any questions. Thank You. Steve Soroka Hilcorp Alaska LLC Field Well Integrity Steve.Soroka@hilcorp.com P: (907) 830-8976 Alt: Chris Casey The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM TO: Jim Regg 711 P.I. Supervisor FROM: Bob Noble Petroleum Inspector ;/-7(,v-Z-- NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, January 3, 2022 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC F-83 MILNE PT UNIT F-83 Src: Inspector Reviewed By: P.I. Supry Comm Well Name MILNE PT UNIT F-83 API Well Number 50-029-22963-00-00 Inspector Name: Bob Noble Permit Number: 200-093-0 Inspection Date: 11/14/2021 ' InSp Num: mitRCN211115131112 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well F-83 f Type lnj w - TVD 6436 Tubing 1740 1743 1739 1737 PTD 2000930 (Type Test j SPT (Test psi 1609 IA 109 2302215 2203 ' BBL Pumped: 1.1 jBBL Returned 1.2 OA 341 643 622 615 - —. Interval -- — 4YRTST �P/F — P Notes: Monday, January 3, 2022 Page 1 of I From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector MPU F-83 (PTD #200093) Ready for Injection Date:Thursday, November 18, 2021 10:52:14 AM From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Monday, November 8, 2021 10:01 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com> Subject: OPERABLE: Injector MPU F-83 (PTD #200093) Ready for Injection Mr. Wallace, Injector MPU F-83 (PTD #200093) is ready for Injection. The well is now classified back to OPERABLE. An AOGCC witnessed MIT-IA will be performed when the well is on stabilized injection. Please respond with any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA RECEIVED _-,SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS FEB 0 6 2014 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other/ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ t v Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WeII❑ VGF 572—z. //cI- 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development❑ Exploratory ❑ t 200-093-0 3.Address: P.O.Box 196612 StratigraphiC Service ❑., 6.API Number: Anchorage,AK 99519-6612 * 50-029-22963-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0388235 • 2.7sD 9 , KUP MPF-83 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): GR/CCUSCMT • MILNE POINT,KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured • 14182 feet Plugs measured 10430 feet true vertical 6985.11 feet Junk measured None feet Effective Depth measured 10430 feet Packer measured See Attachment feet true vertical 6908.48 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 82 20"91.5#H-40 28-110 28-110 1490 470 Surface 4808 9-5/8"40#L-80 29-4837 29-4262.71 5750 3090 Intermediate None None None None None None Production 10519 7"26#L-80 26-10545 26-6939.8 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet SCANNED MAY 2 9 2014 True Vertical depth See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 25-8198 25-6474.27 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDMSMAY 17 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 11 Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service❑Q Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPIL GSTOR ❑ WINJ ❑ WAG Q GINJ ❑ SUSP ❑ SPLUC-❑ 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 Nita Summerhays Email Nita.Summerhays bp.com Printed Name NitaSummerhaysTitle Data Coordinator Signatu - ,i fic /i,Tiii r,#,. _ Phone 564-4035 Date 2/6/2014 V - F 5/2Zlc1- Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0388235 AC IVI BA . - - ^r• of v= o. ••Ie we: in", V , n , e . Rig up, Start BOP test. 1/6/2014 ***Continued on 1/07/14*** CTU#9 1.75"Coil (CV=44.2) Job Objective: Drift, SCM 1, WRP, Perf. ***Continued from 1/06/14*** Performed weekly BOP test-passed. BOP function tested upon installation.Load well with 260 bbls of kcl. RIH w/BHA; 2.875"ctc, dfcv, disco, 3.13"crossover, 3.36"wtbar, 3.1"crossover, 2.1"ported sub, 3.65"WRP drift, 2"crossover, 3"nozzle. (oal= 13.99')to 10850'. Pooh. RIH w/BHA;2.875" ctc, dfcv, disco, crossover, 1.69"memory GR,CCL, SCMT logging tools(oal= 36.34'), Log from 10775'-9775', with coil flag log from 10775'-7950', Flag placed at 10350'. 1/7/2014 ***Continued on 1/08/14*** CTU#9 1.15"Coil (CV=44.2) Job Objective: Drift, SCM f,WRP, Pert. ***Continued from 1/07/14*** SCMT data downloaded and good. MU RIH with WFD 4.5"WRP SC, OAL 15.60'. Discussed setting depth with APE and set 3.68"Weatherford WRP,top of plug at 10430'. pooh. Test plug to 4k. passed, Bled tubing to zero..good. RIH w/BHA; 2.875"ctc, dfcv, disco, crossover,3.06"TCP efire fill sub, 3.375"x 5'gun with 1'of shot. (oal=21.89')charge data: 3406 PJ HMX,22.7 gm, 0.37" EH, 36.50"penetration. Tag plug, pull slack, correct depth to bottom shot. pull up to target depth 10275- 10276'. Fired Gun, POOH,All shots fired. Start rig down. Tubing is freeze protected with 60 bbls 60/40, Final WHP 535 psi. 1/8/2014 ***Continued on 1/09/14*** CTU#9 1.75"Coil (CV=44.2) Job Objective: Drift, SCM r, WRP, Pert ***Continued from 1/07/14*** SCMT data downloaded and good. MU RIH with WFD 4.5"WRP SC, OAL 15.60'. Discussed setting depth with APE and set 3.68"Weatherford WRP, top of plug at 10430'. pooh. Test plug to 4k. passed, Bled tubing to zero..good. RIH w/BHA; 2.875"ctc, dfcv, disco, crossover,3.06"TCP efire fill sub, 3.375"x 5'gun with 1'of shot. (oal=21.89'). Tag plug, pull slack, correct depth to bottom shot. 1/8/2014 pull up to target depth 10275-10276'. CTU#9 1.75"Coil (CV=44.2) Job Objective: Drift, SCMT, WRP, Perf. ***Continued from 1/08/14*** Rig down unit. 1/9/2014 ***JOB Completed*** FLUIDS PUMPED BBLS 400 60/40 METH 721 1% SLICK KCL 1 121 TOTAL fO M r M ,,, M O LO N- 0 , , NI- '1- 01CO3-- M L Cfl Cfl O M M N- N- r M V N M M N- O) LU r 4 O CO O CO to r 4 O 4 N O N O) m f- O NO 4 LU to CO CO NO OO CO to to u) M N r r O p CO O O N_ 0 0 0 0 0 0000 000000 p 0N- h. ti ti > F a O 1- M V V N- N- 00 M M M LO Cb to N N- N O) M to V O) to O N M N CO N M O O. 00 M V r O O V CO LU O) t.C) O CO CO r N- O N N- O) r N V to 10 CO CO N- Cfl 0000 - M N N p CO O) 0 0 0 0 0 0 0 0 0 0000 0 0 0 0 0 w N fC m t 00 ,-- 00 ‘4- 0000d- 00 to tf) O N L O O LU O - ▪ N- M r to C V Cfl N 00 O to = MW = O) CO 00 N V O) O- N QO O) O) O r r N N N N Md- ,4- 6) r V CC) N- 00 00 C 0 0 0 0 0 r r r r N CV N N N CV CO COM CO) M CO r r r . . . . . a- c- r r r r r r t0 N t 2 V Q co a co o M ~ = o L t!") O O Lo CC) M O tC) Lo O O Lo LU 00 O to O O) to O) J O N- r O) M N- N CC) O CO 00 LU 1- 1- MM CA M O) to CO O_ n N N OO M O) O r r N N r N M V V M p 0 0 0 0 N N N N N N M Cr) C') Cr) M M Q r r r r r r r r r r r c- r r r r r r r r r I_ m L N O 2 t a 0 U O• LL_ (n U) U) Cn U) Cf) W U) U) U) (n (n U) (.0 U) U) U) U) O) m CL O_ O_ O_ O_ O_ 0_ EL CL 0_ 0_ O_ 0_ O_ O_ 0_ d CL O_ CL QCT) Cn CO CO CT) CO CO CO CO CO CO CO CO CO CO CO CO CT) CO CY) a 0 t N a 0• v v v v v v v v v v v v v v v v v 4 4 v v r r r r r r r r = = = = = = C00000000000 0000 OOOOOO CV CV N N CV N N N N N CV N N N N N N N N N N 00 00 00 00 CO CO QO OO o0 00 aO CO o0 00 00 CO 00 CO00 00 00 a = = = = = = = = = = = r r r r = = = = = = N m M M M M M CM CM M M M M (0 (0 (0 (0 (0 (0 (0 (0 (0 (0 z o0 co co co co co co co co ao ao Co CO Co Co 00 0o ao 0o Cn o0 11111111ILL LL LL lL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL Ci) 0_ 0_ 0_ O 0_ O_ a_ CL CL 0_ O_ 0_ O_ O_ 0_ 0Q003_ 22222222222 2222 2122222 a) p 0 0 c, 0 0 0 R O c o rn On Ln Lo L U y 0 0 0 0 0 0 L. 6) M NT Lf) M 7 V V c,n Nr- 00 V m co ti to co ▪ M I— co O M Lc) N- N v- CO M M N V aO C) O (O I� O O N ct O N- O N' (O • 1 1 1 1 1 1 H co �Y CO V V CD N Ln co N N N 00 co CO O O43) N- C O O 00 O CO N- M O r- c- O O ;2,1? a) V coO V CULOCI I I i N rn v M co co co N a ,_ N N N = r- }- ~ Q o 0 0 0 co co o co C) ,r CD • C, CC) OJI# O fns OO T- O - 0 N 00 O N N ; O ✓ N ,sr co co O)N N N- O f— C CO CO CO O O J M co Z 0 °D OE- E- w • D U O CU 0 tY CC 0ILiZ U O Z _ Z_ c D D U J J d U) F- Packers and SSV's Attachment ADL0388235 SW Name Type MD TVD Depscription MPF-83 PACKER 8100 6399.22 4-1/2" Baker Premier Packer MPF-83 PACKER 10339 6846.61 5" Baker ZXP Top Packer MPF-83 PACKER 11034 6998.59 2-7/8" BWB Perma Packer Tree:4 1/16"Cameron 5M MPF-83i Orig. KB Elev. =38.85 (Doyen-141) Wellhead:Gen 5 Ultra Slimhole System Orig. GL Elev. =28.5 (Doyon-141) 11"X 4 1/2"FMC Hgr w/TC-II thread T&B RT To Tbg. Spool =26.10 (Doyon-141) 4.5"CIW'H'BPVT Well required to have a SSSV installed. 20"91.51 ppf, H-40 78' © 9 5/8"Tam port collar 1007' KOP @ 700 to 9,880' Max. hole angle =95 deg. 111 HES X-Nipple 3.813" ID 2097' deg.6,800' - 11,050'40-80 deg. Hole angle thru' perfs= 90+deg. U-Shaped sec. 11,000'-14,182' 9 5/8",40 ppf, L-80 Btrc. 4,837' I 4.5" 12.6 ppf, L-80 TC-II tubing (drift id =3.833", cap=0.0152 bpf) 7"26 ppf, L-80, BTC-M casing (drift id =6.276", cap. =0.0383 bpf) ) SLB 4.5"X 1" KBG-2 GLM 8014' (Cap w/4.5"tbg inside= .0186) Liner: 4.5" 12.6 ppf, L-80, NSCT (drift ID=3.958",cap.=0.0152 bpf) HES X-Nipple 3.813" ID 8079' El �. Baker 7"x 4.5" Premier Pkr 8100' III HES X-Nipple 3.813" ID 8127' II HES XN-Nipple 3.813" ID 8186' (no-go 3.725"ID) WLEG 8198' Perforate 3 7/8/6 SPF/(MD)10,275'-10,276 ----► 01/08/14 6' Baker tie back sleeve 10,338' 7"x 5" Baker ZXP Liner pkr. 10,348' Set W-Ford WRP 3.68 10,430' p,„ Baker"HMC"hyd.Liner hng. I . I , 7"float collar 10,462' I 7"float shoe 10,545' I Perforation Summary HES 4.5"X 2 7/8"'BWB' Perma Pkr 11034' Ref log: MWD log. 7/25/00 Size Spf Interval (TVD) mi 2 7/8"HES XN-Nipple 2.205"no-go 11063'i *See Program TCP in ervals * • ID w/XXN plug installed ' WLEG 11071' 2-7/8" , 15.2 gram 34j uj, RDX charges I Angle through perfs 79 deg -95 deg. 60 deg. phasing 490' and of shots I U-Shaped. 4.5" Landing Collar(PBTD) 14,082' and 4.5'float collar 14,124' and 4.5'float shoe 14,168' and DATE REV.BY COMMENTS MILNE POINT UNIT 07/30/00 MDO - Cased hole Doyon 141 08/27/00 _ MDO Pens and Completions 4-ES WELL No.: MPF-83i 06/20/04 MDO Weatherford patch set API : 50-029-22963-00 08/14/04 MDO Pulled Weatherford patch 11/26/04 Lee HulmeRecomplete and set Isolation Pkr N-4ES 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 WthittiEDFEB 2 1 Zt 1L Mr. Tom Maunder a0 0— -3 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 1 ¥ 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 • • 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 12 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 WA 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 NIA 13.6 8/12011 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 8/12011 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 8/12011 MPF-45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/112011 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 9/192011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 102 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 9/12011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/112011 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 WA 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 WA 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 12 N/A 1.2 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 12 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 8/122011 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 12 N/A 12 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 WA 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/132011 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 9/12011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 :'~/~-I 1 1 ?fV,;"'; --·,\.Iv BPFAX ;t' cç/' -¡-Ö &. Ct; +J _ .... f?,('~JI ( Pl¡;Y FACSIMILE REPLY NUMBER . ,9Q1) 610.3390 CONFIRMATION NUMBER . ~ 907J 670-33Ot -... '. ' La¡J ð C!. Jl?i.((. (' 4 t t/ l-kw<j C/ '(. Il ? Cf¡ ,.r~ (} ~L ý' A--J'C: ¿", I~ P£ Ii. 'ÎQØ'I - 0 { Ad v' f 5 fJ R. w,' {( be ,.:1-8 >iiJT íò 10/11-(( wt..''ùU Iv.'(eç RIi.rUfl..tI·0, _ ...4/. '\. ¡'" . I FAX NIJIIIŒR:.. , ,~911~ 6~O.3390 : SPECIAL msTlttTC:'::ONS t ; .".. J .. . ... "'.. a .-t. .... ... _ _.' ... ' ~. ... taT!:: .... . .,.. NoMaD. 0'1' PAGES: ·z_~.. . '" I ç'~:.. Il"-_·?-~.1.~_ '.. ., '" _.' _ '. .~ ~~:tNQ .çOV1£,..1\ ....' '1'0 : ] '{ó 11/1. 114 AU /oj ¡JEll -. - I .... ,,~. .. _ ...... .." : LOCA'1'%Olf, . I A. 0 ~t. G. '" ""- .... : . .... ..... L.." ""1"'" . . -. "AX ~~: . ;À.7 fa .- 7'("<-( 'z.-. .. ......\.. .. "r" ,. I'ItOlh (,-; Pc¿... c. IC ¡¡ Iv( pI ; 4^1 C't¿ A d 1/1 { (/ '-: . . '_ "------I'!. - - ", ~.: - ~ .. - ....~ - ~.oJ f"-IM. J - \, "LOCAT%()IÏ I . . . - : '" \fILNE POINT '\. ... " stCANNEt) ,,]f-\N :1 ~l ZDOb ¡P MJ:LN.E POINT FACSXNXLE ~SMISS:ON COVEa ~1:u:¡,C..L' ¡ -. . I ~ "1],,: dOO -0<; ~ 907 276 7542;# 1/ 2 BPX-MILNE POINT~ ) ;10-11- 0 ; 8:33AM ; ) SENT BY:BPX-MPOC SENT BY:BPX-MPOC ;10-11- 0 ; 8:34AM; BPX-MILNE POINT~ 907 276 7542;# 2/ 2 ') casing Pressure Report ) dOG -o~ ~ This form is to be used when the casing pressure reaches 1750 PSI, or when :he Arctic Pack presßure reaches 1000 PSI. Well #.. ~ªp ; t !D ~7/ · 23'W .. J)f.ß Da e...'{)r()~. " T1.me -..' - In~t~als '. . '. Well status: H20 injector~, Gas injector____, Producer Initial Pressures: Tubing. 22..{ C....... , Casing (1 to , Arctic Pack 2W Bleed the affected pressure; casing pressure to 500 PSI, or the Arctic Pack pressure tó 250 PSI. If the total volume of fluid recovered is 2 bbls greater than the volume recovered during the last report, notify the production specialist- wells. . ~O()O ..-'J I \ ( .. \/ A,,( "- Bleed time to ~ PSI - casing.,::.::::: ('v\ II' , Fluid encountered atj(rv,¡6-,P. PSI. Ble@d time to 250 PSI - Arctic Pack ........... ( Flu.id encountered at PSI. Recovered Fluids: ( Csg . ) Type of flu i d 1>~. ê?~:'~6r.·.. ~:....._, _ Vol. recovered 1(' Bbr~ f IV . Recovered Fluids: ( Ann. ) Type of fluid , Vol. recovered Monitor conditions.. . .,. -.,... .-.- ..... --.. . , ,.0. .... ...\-- Day/Time Ioj. Rate BPD'Tbg. Pres. Csg. Pres. A. P. pres. 1 hr. d~;"'~~lJ9õ IdOÞ ~ I) '7 fie, day 2 ,r~.< Iv'v day 3 (1;(10 .._ ... lo-h, ."_' . day 42.~OU Yf)~7 day ~J1-~1J day 6'5ftJo .""'.' .. , ... /l··.~... day 7J70 ___.I, .-:/e 36(~...... ,....."J..b /::¿ ~J~51f 3~·60 .. ..... .............. 30"60. ..356tJ ....4ff·7 ...,$3(. ,.... , ~ 2.2(Q .. "..:I. J ~_( .., J:t .3 ~ Z. 2' 'f~' -/....7-7 " L. (" C) . ..... .,.."·......._~"'._·n.' ,. "".""""_..._..."..,, (i~1.:7 p ".." .. .,. - ,,- .- a~~CJ ! j:¿~J (~75 ......... /.fl!t!.. __..,.."../Z ~.(J ( qt(- D ./1.60 /9t t? /961 1'6& Comments ¡tJû . ....... - "-"-'.' '.," /9t!J /1ft) ( ¿5{) ( ¡~{c/ lio .1Þ"tJ, ,.... (~~~ - Please turn this form in to the PS Wells. If the casing or Arctic pack pressures increase by 500 PSI or greater, or the well must be bled more thah 2 times in a 30 day period, notify the PS Wells. If the pressures stablize, re$ume weekly monitoring. Formtool~ csgRptJK P.01 93% 'j :'Îï,l .,.. - '~ . . :..{ ''''. \ ' 'k", \ .... '" I I 0, .,' ...., ;;~ : ~~ . :>~ ' ':' , ~I~~ JOO~? J? . : "..~i;. ·:·'···(':·;·~i: ~..~ f :t '~ '.;~ :,:il :;~¡ .;;~ I ',I' r .). ,.....,~:~.. .' . " . . ~;. ~ :"'¿ , '\;~~ ". . ~ .;:1 ".-- ) ) P.001 08/Z0l00 11:15P , ' , 1 st test Time Tub Cas o 1800 4080 5 ., ·f85tj"-·-·'..¡071j" 10: 1850 4060 15 1900 4050 '._.~~~.-=..~?º, . 1900 4030' 25 1950 4020 30 1975 4010 ...."....-......- 2nd test Time .tu-Þ-=~-=--ç.~~ o 1950 1540 ,__~,_ __192º 1540 .'..'__ ,.. ,,1.0 1890 1540 __,....J.,~1880 1540 20, 1870" . f54õ" r--=, 25:-1850···'·..'1540 30' 1840 1540 . ....._..-4-..__ 3rd test -...--........ ] Time Tub Cas ___.,..,9 , 2075 2950 5 ~100 . 294Ö 1 0 .. 2,1~,~' ,: ., 2'9'~Õ' 15 2125 2920 ."_ 20 2145 2920 ?5 2160 2910 30 2175 29ÖÖ ) 1~ ~ \~~ ë7 s ~b ~O ( :î \,$ ~C)Ü ØS/2Ø/ØØ 11:1SP P.ØØ2 '\ 1 ~o o to to ~Ü o "ù £ Of'v 00 ù ~O Ð tJ$" ' if ~() ~o to ~Ù d-Ù lO d()O-O<;~ to LO LU ~ì \0 S d- o-~ ~(p ¿ ~1é0'o b,J~ 2JvCQ \ \>0 ~ ~~~Q6 \J<7 (\ 0 \ L6;D ~ \ffi"ð ~\,s AUG-21-2000 00:21 \ P.02 F:\LaserFiche\CvrPgs _ Inserts\Microfilm _Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE .';;!!#' wt" '~.~ ~-~-" ~ ""~ ., ~ " ';'"i.t. ... 'Iõ - '\ STATE OF ALASKA) ALASKA vfL AND GAS CONSERVATION COI\tIlVlISSION .......-, .. 'V.E..'....:.D":-.'-~ REPORT OF SUNDRY WELL OPERATION~ECE .. ; DEC 2 1 2004 Upgr~de T~~in~ C mssiOf 0 Stimulate Ataska i\i1~~'S 005. 0 0 Waiver 0 Ti~~J~~~~n 0 Re-Enter Suspended Well 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 38.85' .J 8. Property Designation: ADL 388235 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): a Repair Well 0 Plug Perforations a Pull Tubing 0 Perforate New Pool 0 Operation Shutdown 0 Perforate 14182 6985 14083 6994 110' 4808' 10519' 3829' 4. Current Well Class: 0 Development 0 Exploratory 0 Stratigraphic a Service 5. Permit To Drill Number: 200-093 6. API Number: 50-029-22963-00-00 9. Well Name and Number: M PF-83i 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst 20" 110' 110' 9-5/8" 4837' 4263' 5750 7" 10545' 6940' 7240 4-1/2" 10339' - 14168' 6885' - 6986' 8430 SCANNED DEe 2 "1 2004 Collapse 3090 5410 7500 10810' - 13890' 6999' - 7009' 4-1/2", 12.6# Tubing Size (size, grade, and measured depth): 2-7/8",6.5# Packers and SSSV (type and measured depth): Baker 7" x 3-1/2" SAB-3 Perm packer 4-1/2" x 2-7/8" BWD Perm Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): L-80 L-80 8198' 11034' - 11071' 8059' 11034' Treatment description including volumes used and final pressure: RBDMS BFL DEC 2 2 2004 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 0 Daily Report of Well Operations 0 Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory 0 Development a Service 16. Well Status after proposed work: 0 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 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 David Reem, 564-5743 304-413 Printed Name David Reem Title Drilling Engineer Phone _r4. ¡ Prepared By Name/Number: Date 12~ Ii vìSondra Stewman, 564-4750 I Submit Original Only 564-;p14\y r ! \ L t \; þ ) Tree: 41/16" Cameron 5M Wellhead: Gen 5 Ultra Slimhole System 11" X 41/2" FMC Hgr wi TC-II thread T & B 4.5" CIW 'H' BPVT 20" 91.51 ppf, H-40 ~ KOP @ 700 to 9,880' Max. hole angle = 95 deg. deg. 6,800' - 11,050' 40 - 80 deg. Hole angle thru' perfs = 90+ deg. U-Shaped sec. 11 ,000'-14,182' 9 5/8", 40 ppf, L-80 Btrc. I 4,837 ~ 4.5" 12.6 ppf, L-80 TC-II tubing ( drift id = 3.833", cap = 0.0152 bpf ) 7" 26 ppf, L-80, BTC-M casing ( drift id = 6.276", cap. = 0.0383 bpf ) ( Cap wI 4.5" tbg inside = .0186) Liner' 4.5" 12.6 ppf, L-80, NSCT ( drift 10 = 3.958", cap. = 0.0152 bpf ) Perforation Summary Ref log: MWO log. 7/25/00 Size Spf Interval (TVO) * See ::>rogram TCP irtervals * 2-7/8" , 15.2 gram 34j uj, ROX charges 60 deg. phasing 490' md of shots DATE 07/30/00 08/27/00 06/20/04 08/14/04 11/26/04 MPF-83i . Orig. ) Elev. = 38.85 (Doyon -141) Orig. GL Elev. = 28.5 (Doyon -141) RT To Tbg. Spool = 26.1 O(Doyon -141) 0 95/8" Tam portcollar 11007' I r'. 1 .~ .~ ; ~ ~ :¡ .! ~~ .:;.J ~"" .:: :1 'i! .Î R . ,J .:;:'-;:':~::*=..' """""@::;':¡':"':";::. ~ HES X-Nipple 3.813" 10 I 2097' I , SLB 4.5" X 1" KBG-2 GLM 1 8014' I HES X-Nipple 3,813" 10 1 8079' I 18100' I I 81 27' I I 8186' I WLEG I 8198' I Baker 7" x 4.5" Premier Pkr HES X-Nipple 3.813" ID HES XN-Nipple3.813" 10 (no-go 3.725" ID) 6' Baker tie back sleeve 110,338' I 7"x 5" Baker ZXP Liner pkr. 110,348' I Baker "HMC" hyd. Liner hng. ~ 7" float collar 7" float shoe 1 0,462' 10,545' HES 4.5" X 2 7/8" 'BWB' Perma Pkr 111 034' I 27/8" HES XN-Nipple 2.205" no-go I 11063' I tD wi XXN plug installed WLEG I 11071'1 Angle through perfs 79 deg - 95 deg. U-Shaped. 4.5" Landing Collar (PBTO) 4.5" float collar 4.5" float shoe 14,082' md 14,124' md 14,168' md REV. BY COMMENTS MDO Cased hole Doyon 141 MDO Perfs and Completions 4-ES MDO Weatherford patch set., MDO Pulled Weatherford patch Lee Hulme ~ecomplete and set Isolation Pkr N-4ES MILNE POINT UNIT WELL No.: MPF-83i API: 50-029-22963-00 BP EXPLORATION (AK) ') BP EXPLORATION Operations Summary Report Page 1 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-83 MPF-83 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 11/19/2004 Rig Release: 11/28/2004 Rig Number: Spud Date: 7/5/2000 End: 11/28/2004 Date From - To Hours Task Code NPT Phase Description of Operations 11/18/2004 11 :00 - 13:00 2.00 RIGD P PRE PJSM. Scope down & layover derrick. Rig down. 13:00 - 15:00 2.00 MOB P PRE PJSM. Move rig components from MPF-38 to MPF-83. 15:00 - 17:00 2.00 RIGU P PRE PJSM. Rig up on MPF-83. Raise & scope up derrick. Rig accepted @ 17:00 hrs, 11/18/2004. 17:00 - 18:00 1.00 KILL P DECOMP PJSM. Rig up lines to tiger tank & install HCR vlave on I/A. 18:00 - 19:30 1.50 KILL P DECOMP PJSM. P/U lubricator, pull BPV. Take on 120 degree seawater. 19:30 - 20:00 0.50 KILL P DECOMP Pre well kill meeting. 20:00 - 20:30 0.50 KILL P DECOMP PJSM. Pressure test lines @ 350/3500 psi. 20:30 - 00:00 3.50 KI LL P DECOMP PJSM. SITP = 1110 psi, SICP = 1290 psi. Bleed pressure off well & commence circulating 120 deg seawater @ 3-4 bpm I 150 -200 psi. 11/19/2004 00:00 - 01 :00 1.00 KILL P DECOMP Complete circulation of 605 Bbls of 120 F seawater. 01 :00 - 02:30 1.50 KILL P DECOMP Wait on 12.3 ppg brine. Take on 12.3 ppg brine to Mud Pits. 02:30 - 04:00 1.50 KILL P DECOMP Circulate 300 Bbls 12.3 ppg brine throughout wellbore. 04:00 - 04:30 0.50 KILL P DECOMP Install and test TWC. 04:30 - 06:00 1.50 WHSUR P DECOMP NID tree. 06:00 - 09:30 3.50 BOPSUP P DECOMP N/U BOPE. 09:30 - 15:00 5.50 BOPSUR P DECOMP Pressure test BOPE 250 low, 4000 psi high, annular 3500 psi. Witnessed by John Chrisp, AOGCC. 15:00 - 15:30 0.50 BOPSUP P DECOMP Bleed down lines, drain BOPE stack, RID test equipment. 15:30 - 16:30 1.00 BOPSUP P DECOMP P/U Lubricator and Lub ext, pull and UD TWC. Take on 2nd truckload 12.3 ppg brine. 16:30 - 18:00 1.50 BOPSUPP DECOMP N/U secondary IA valve. R/U and test lines to circulate 12.3 ppg until returns to Mud Pits are 12.3 ppg. 18:00 - 18:30 0.50 BOPSUP P DECOMP Bleed and RID circulating lines. 18:30 - 19:30 1.00 PULL P DECOMP M/U landing joint to XO and Lifting sub; M/U to hanger, pull hanger to floor wi 68K. No drag. 19:30 - 00:00 4.50 PULL P DECOMP POH and UD and number 3-1/2",9.3#, L-80, NSCT tubing. (136 jts laid down) 11/20/2004 00:00 - 03:00 3.00 PULL P DECOMP POH and UD and number 3-1/2" completion string. Recovered 255 jts 3-1/2" tbg, two 'X' Nipples wi pups, and 9.19' of a chemical cut pup joint. 03:00 - 05:30 2.50 PULL P DECOMP Clear and clean rig floor. Install wear ring. R/U eqpt to run 3-1/2" DP. 05:30 - 06:30 1.00 CLEAN P OECOMP M/U BHA #1: Packer Milling Assy. 06:30 - 13:00 6.50 CLEAN P DECOMP PJSM. RIH wi milling BHA, picking up 31/2" DP 1x1. 244 jts. 13:00 - 15:30 2.50 CLEAN P DECOMP PJSM. Pick up kelly. 116K up wt, 75K down. 3500 ft I Ibs freespin torque. Bring on pump @ 4 bpm 1250 psi. Tag top of stub @ 8054'. Commence milling ops w/5K WOB, 80 RPM. Mill approximately 3' to 8057'. 15:30 - 16:00 0.50 CLEAN P DECOMP PJSM. Cease milling operations. Line up & pressure test 7" casing @ 2500 psi I 30 minutes, bled 150 psi. Opt to do spool change-out prior to milling packer. 16:00 - 18:00 2.00 CLEAN P DECOMP PJSM. CBU @ 5 bpm 11750 psi. 18:00 - 20:30 2.50 CLEAN P DECOMP POH and SIB 3-1/2" DP. 20:30 - 21 :30 1.00 CLEAN P OECOMP SIB DCs, breakout and UD BHA #1, clean Boot Baskets. 21 :30 - 22:00 0.50 WHSUR P DECOMP P/U Halco RBP running tool, M/U to 7" Halco RBP. 22:00 - 00:00 2.00 WHSUR P DECOMP TIH Halco RBP on 79 stds DP to set @ 7500'. 11/21/2004 00:00 - 02:00 2.00 WHSUR P DECOMP Finish TIH wi Halco RBP and set @ 7506'. 02:00 - 03:00 1.00 WHSUR P DECOMP RlU and pressure test RBP to 2500 psi, 15 minutes. Good test. 03:00 - 04:00 1.00 WHSUR P DECOMP P/U and SIB 2 stands. Up wt, 100K; On wt, 74K. M/U Halco running tool to Halco Storm Pkr, TIH and set @ 23'. POH wI running tool and PT to 2500 psi for 15 minutes. Good test. Printed: 11/29/2004 11 :52:48 AM BP EXPLORATION Operations Summary Report Page 2 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-83 MPF-83 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 11/19/2004 Rig Release: 11/28/2004 Rig Number: Spud Date: 7/5/2000 End: 11/28/2004 Date From - To Hours Task Code NPT Phase Description of Operations 11121/2004 04:00 - 06:00 2.00 BOPSUP P 06:00 - 08:30 2.50 WHSUR P 08:30 - 10:00 1.50 BOPSUR P 10:00 - 10:30 0.50 BOPSUP P 10:30 - 11 :00 0.50 DHB P 11 :00 - 11 :30 0.50 DHB P 11 :30 - 14:00 2.50 CLEAN P 14:00 - 15:00 1.00 CLEAN P 15:00 - 17:00 2.00 CLEAN P 17:00 - 20:30 3.50 CLEAN P 11/23/2004 00:00 - 01 :00 1.00 FISH P DECOMP Drain BOPE, bleed lines, N/D BOPE. DECOMP PJSM. N/D 7" x 11" tbg spool, N/U 11" x 11" tbg spool. Test pack off @ 3000 psi, OK. DECOMP PJSM. N/U BOPE & flow nipple. DECOMP PJSM. Pressure test breaks @ 250 I 4000 psi charted, OK. DECOMP PJSM. RIH, screw into & release Halliburton Storm Packer, POOH & UD same. DECOMP PJSM. RIH & release Halliburton RBP @ 7506'. Monitor well, well stable. DECOMP PJSM. POOH wI 31/2" DP & Halliburton RBP. DECOMP PJSM. UD Halliburton RBP, set wear bushing. P/U packer milling BHA. DECOMP RIH wI packer milling BHA on 31/2" DP. 244 jts. DECOMP PJSM. Pick up kelly. Establish parameters. 4000 ft Ibs torque off bottom. 112K up wt, 78K down wt, 94K rotating wt. Bring on pump @ 4 bpm 11200 psi & begin milling on packer approximately 5-6' in on kelly @ 8057' wi 5K WOB. DECOMP Stop milling after making additional 3' to 8060' and seeing drilling break. Monitor well; continued to flow. St, monitor well; pressures @2130 hrs DP 90, CP 150. Need to weight-up fluid, Order two truckloads 12.9 ppg brine. Pressures @ 2230 hrs DP 100, CP 150; @ 2400 hours DP 110, CP 150. DECOMP Wait on brine. Cleanout Tiger Tank to collect return fluids. Cleanout Mud Pit for 12.9 ppg. Perform rig maintenance. Load and tally 4-1/2", 12.6#, L-80, TCII tubing. Notified AOGCC State rep of wellbore influx necessitating shutting in of well & weighting up. DECOMP PJSM. Line up & circulate down DP @ 4 bpm I 1650 psi, taking returns thru choke to mud pits, holding 150 - 200 psi back pressure. After displacing DP volume, bullhead @ 3 bpm 1900 psi, 88bbls. DECOMP Monitor well & take on more 12.9 ppg brine. DECOMP PJSM. Bullhead another 15 bbls, 3 bpm @ 900 psi, then open choke & take returns thru gas buster to pits pumping 4 3/4 bpm @ 1700 psi, maintaining constant DP pressure. Pumped 235 bbls total after bullheading, seeing 12.1 ppg returns. Out of brine. DECOMP PJSM. Monitor well. Annulus on vacuum, tubing on slight I vacuum, well dead. DECOMP PJSM. RIH w/3 1/2" DP 1x1. Tag hard 24' in on #269 @ 8872. Pick up kelly & rotate lightly wI no resistance. Tag up again on next joint. Kelly up, rotate & pick up wI 25K drag. Pulled free. Wait on fluid. DECOMP PJSM. Slip & cut drilling line. DECOMP Wait on 12.7 ppg brine. Take on brine to Mud Pits. I DECOMP \. RIU to circulate. Start circulating 12.7 ppg brine@3BPM,750 psi. Fluid level in DP @ 180', in Annulus @ -900'. First fluid II returns 11 ppg then quickly increased to 12.9 ppg. Continue to , circulate 12.7 ppg and resume milling operations to push I remainder of packer downhole. Fluid loss began to increase to 1 Bbl/min as the 12.9 was being brought to surface; total loss 156 Bbls when SI pump @ 2400 hrs. DECOMP P/U and circulate above packer. Loss rate is 2.7 Bbls/5 20:30 - 00:00 3.50 CLEAN P 11/22/2004 00:00 - 08:00 8.00 CLEAN P 08:00 - 09:30 1.50 CLEAN P 09:30 - 10:30 10:30 - 12:00 1.00 CLEAN P 1.50 CLEAN P 12:00 - 12:30 0.50 CLEAN P 12:30 - 14:00 1.50 CLEAN P 14:00 - 15:30 15:30 - 20:30 20:30 - 00:00 1.50 CLEAN P 5.00 CLEAN P 3.50 CLEAN P Printed: 11/29/2004 11 :52:48 AM I ') ') BP EXPLORATION Operations Summary Report Page 3 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-83 MPF-83 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 11/19/2004 Rig Release: 11/28/2004 Rig Number: Spud Date: 7/5/2000 End: 11/28/2004 Date From - To Hours Task Code NPT Phase Description of Operations 11/23/2004 00:00 - 01 :00 1.00 FISH P DECOMP minutes = 32 Bbls/hr. Static loss was 21 Bbls/hr wi 12.9 ppg in well. Still seeing 12.9 ppg in returns. Order out 280 Bbls 12.7 ppg fluid. 01 :00 - 03:00 2.00 FISH P DECOMP Work packer downhole to 10,326'. 03:00 - 09:30 6.50 FISH P DECOMP Wait on fluid. 09:30 - 10:00 0.50 FISH P DECOMP PJSM. Fill hole. approximately 10 bbls hole fill. Observe well. Fluid level relatively static. 10:00 - 13:00 3.00 FISH P DECOMP PJSM. POOH w/3 1/2" DP & packer milling BHA, filling hole wI 12.7 ppg brine. Took 14 Bbls. 13:00 - 14:00 1.00 FISH P DECOMP Breakout BHA #1; clean boot baskets, get back 2 gallons metal cuttings and debris. 14:00 - 17:00 3.00 FISH P DECOMP M/U BHA #2, spear assy, TIH on 316 jts from Derrick and Pipe Shed. 17:00 - 18:00 1.00 FISH P DECOMP R/U circulating hose, wash down into packer. M/U Kelly. Check fluid loss, 1 Bbll5 mins. 18:00 - 19:30 1.50 FISH P DECOMP Work spear into packer and engage. POH one joint. Check packer engagement--good indication. 19:30 - 20:30 1.00 FISH P DECOMP B/O Kelly, stand back and drain, set back Kelly. R/U circulating line, drop dart to open pump-out sub. P/U one joint and work pipe to verify packer engaged--more joy. Fill hole wI 22 Bbls fluid, circulate in remainder of 12.7 fluid, returns to pits -12.6 ppg. Call for the load of 12.7 fluid which will have to be watered back wI freshwater @ 1 Bbll40 Bbls heavy fluid for every 1/10th ppg reduction required. 20:30 - 00:00 3.50 FISH P DECOMP Wait on 12.7 ppg brine. Clean out Mud Pits. 11/24/2004 00:00 - 01 :00 1.00 FISH P DECOMP Load 12.7 fluid to Mud Pits. Split load to Pit 2 and 3. Water back one pit to 12.5 for pipe displacement while TOH. 01 :00 - 02:30 1.50 FISH P DECOMP TOH wI packer and SIB DP. Pull 10 stands dry and 11 th wet. Stop and pump Drain Sub ball to Drain Sub wi 10 Bbls of 12.5 ppg, pressure up to 2400 psi and open Drain Sub. Circulate in 5 more Bbls of 12.5 ppg fluid and annular fluid came to surface. 02:30 - 06:00 3.50 FISH P DECOMP Continue to TOH, pump DP displacement every 5 stands. 06:00 - 08:30 2.50 FISH P DECOMP Finish POOH with 31/2" Drill Pipe, BHA #2, and Fish. 08:30 - 09:00 0.50 FISH P DECOMP Lay down BHA #2 and "Milled-up" Packer and Tail Pipe. TFL = 36.64' 09:00 - 10:00 1.00 FISH P DECOMP PEs shoot Fluid Level. FL = 300 ft. Make-up BHA #3 as follows: Rev Basket Head, Bushing, Ext's, Top Sub, XO, Boot Basket, 7" Csg Scraper, XO, Bumper Jar, Oil Jar, 9 ea Drill collars. 10:00 - 14:00 4.00 FISH P DECOMP Start TIH with BHA #3 and 3-1/2" Drill Pipe. Take weight at 8,896'. Work down to 8,920'. No further progress. Pop Jars to free. 14:00 - 18:00 4.00 FISH P DECOMP Abort further attempt to reach top of Liner with present BHA configuration due to dog-legs in this section of the Hole. POOH. 18:00 - 18:30 0.50 FISH P DECOMP M/U BHA #4: 6-1/8" RR Tooth Bit, 4-3/4" Boot Basket, 7" Casing Scraper, Bit Sub, Bumper Jar, Oil Jar, 9-DCs. 18:30 - 22:00 3.50 FISH P DECOMP TIH BHA #4 on 315 jts 3-1/2" DP from Derrick, 2 from Pipe Shed. Tag TOL @ 10335', 4ES RKB, which is 10' in on jt #317. Saw no restrictions while TIH. 22:00 - 00:00 2.00 FISH P DECOMP TOH, UD 104 jts 3-1/2" DP, SIB 71 stds in Derrick. Use single Pipe Displacement while TOH. Printed: 11/29/2004 11 :52:48 AM ( ) ) BP EXPLORATION Operations Summary Report Page 4 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-83 MPF-83 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 11/19/2004 Rig Release: 11/28/2004 Rig Number: Spud Date: 7/5/2000 End: 11/28/2004 Date From - To Hours Task Code NPT Phase Description of Operations 11/25/2004 00:00 - 01 :00 1.00 CLEAN P DECOMP TOH, LID 104 jts 3-1/2" DP. Use single displacement while TOH. 01 :00 - 03:30 2.50 CLEAN P DECOMP Finish TOH, SIB 71 stands DP and 3 stands DC's in Derrick, BIO BHA #4. Use single displacement while TOH. 03:30 - 05:00 1.50 CLEAN P DECOMP Clean out Junk Basket, retrieve 2 gallons of cuttings and debris. Clear and Clean Rig Floor. R/U equipment to run PAC Pipe. 05:00 - 10:30 5.50 CLEAN P DECOMP M/U BHA #5: 3-5/8" Junk Mill, 120-jts 2-7/8" PAC DP. PEs shoot Fluid level at 800 ft. 10:30 - 11 :00 0.50 CLEAN P DECOMP Rig down 2 7/8" Handling Equipment and rig up for 3 1/2" Drill Pipe. 11 :00 - 14:00 3.00 CLEAN P DECOMP Run Drill Collars, Jars, Bumper Sub. TIH with 31/2" Drill Pipe from Derrick. Drop through 4 1/2" Liner top at 10,335' with minor problems. Park Mill at 10,800'. 14:00 - 15:00 1.00 CLEAN P DECOMP Stop to Cut and Slip Drilling Line 15:00 - 19:00 4.00 CLEAN P DECOMP Continue to single in 3 1/2" Drill Pipe from Pipe Shed to 41/2" Packer setting target at 11030' with no problems. Continue to drift Liner. Check PUW every 6 Jts. Saw no restrictions within the liner, and stopped @ -13,976'. 19:00 - 00:00 5.00 CLEAN P DECOMP POH, SIB 105 stds 3-1/2" DP, UD 86 jts PAC Pipe, SIB 11 stands PAC Pipe to prepare for the installation of the Halco 4.5" packer. Use DP displacement each 5 stands while TOH. 11/26/2004 00:00 - 01 :00 1.00 CLEAN P DECOMP Breakout and UD Oil Jar, Bumper Jar, and 3-1/2" x 2-7/8" XO. R/U PAC Pipe handling equipment. 01 :00 - 04:30 3.50 CLEAN P DECOMP Resume TOH, UD 86 jts 2-7/8" PAC Pipe, SIB 11 stands PAC Pipe. 04:30 - 06:30 2.00 CLEAN P DECOMP Clear and clean Rig Floor. R/U to run Halco 4.5" packer to 11,030'. Lubricate rig. 06:30 - 12:00 5.50 RUNCOrvP RUNCMP PJSM. M/U 4.5" Halco Pkr and 2 7/8" Tailpipe Assy (Put 5/8" Setting Ball in place due to high hole angle at Pkr setting depth and high fluid loss to get Ball pumped to seat). TIH to 10,300'. 12:00 - 12:30 0.50 RUNCOMP RUNCMP RlU Circulating Hose (Charge Pump) to fill Drill Pipe and verify that packer setting ball is on seat. 12:30 - 14:00 1.50 RUNCOIVP RUNCMP Resume TIH. No problems entering Liner Top. However, encountered trash inside Liner. Gently (!!!) work Pkr to setting depth at 11,034'. PUW = 125K. 14:00 - 15:00 1.00 RUNCOrvP RUNCMP R/U Circulating Hose and set Packer with initial setting pressure of 500 psi. Final setting pressure at 2,000 psi. Pull 5K over normal PUW and release setting tool. Setting Tool free, however Drill Pipe pressure did not drop. Pull up above Pkr setting depth...bleed pressure. Went back down to setting depth and tagged top of Packer (set down 5K) to verify packer has set and released from setting tool. Attempted several times to get Setting Tool to drain with no joy. 15:00 - 00:00 9.00 RUNCOIVP RUNCMP TOH wet due to plugged Pkr setting tool, laying down 3-1/2" DP. 11127/2004 00:00 - 00:30 I 0.50 RUNCOIVP RUNCMP POH and UD 3-1/2" DP. 00:30 - 01 :00 0.50 RUNCOIVP RUNCMP RID 3-1/2" DP handling eqpt, R/U 2-7/8" PAC Pipe handling eqpt. 01 :00 - 02:30 1.50 RUNCOIVP RUNCMP POH and UD 34 joints 2-7/8" PAC Pipe. 02:30 - 05:00 2.50 RUNCOIVP RUNCMP Clear and clean Rig Floor. R/U Torque-Turn equipment. 05:00 - 09:30 4.50 RUNCOIVP RUNCMP Start TIH wi new completion: 201 jts 4-1/2", 12.6#, L-80, TCII tubing, 7" Baker Premier Hydraulic Set Packer, 3-"X. Nipples, Printed: 11/29/2004 11 :52:48 AM \ I ) ) BP EXPLORATION Operations Summary Report Page 5 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-83 MPF-83 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 11/19/2004 Rig Release: 11/28/2004 Rig Number: Spud Date: 7/5/2000 End: 11/28/2004 Date From - To Hours Task Code NPT Phase Description of Operations 11/27/2004 05:00 - 09:30 4.50 RUNCOrvP RUNCMP 1-IXN" Nipple, and 1-GLM. Torquing all connections to 3,850 ft-Ibs. BakerLok connections below Packer. 09:30 - 10:00 0.50 RUNCOMP RUNCMP Stop to close in Well so PEs can shoot Fluid Level. FL remains at 800'. 10:00 - 17:00 7.00 RUNCOMP RUNCMP Continue to single in 4 1/2" Completion from Pipe Shed. 17:00 - 19:00 2.00 RUNCOMP RUNCMP M/U Landing Joint, Hanger. P/U wt = 85K, S/O wt = 62K. Land Hanger, RILDS. RID Torque-Turn Equipment, clear Rig Floor. P/U and set TWC. 19:00 - 20:00 1.00 BOPSUF P RUNCMP N/D BOPE. 20:00 - 21 :30 1.50 WHSUR P RUNCMP N/U Adaptor Flange and Tree; test to 5000 psi. 21 :30 - 22:30 1.00 WHSUR P RUNCMP P/U lubricator, pull TWC. 22:30 - 23:30 1.00 WHSUR P RUNCMP R/U lines to tree, take on 12.4 brine to Pits. 23:30 - 00:00 0.50 WHSUR P RUNCMP Wait on Little Red for fluid transfer and Packer setting operation. 11/28/2004 00:00 - 01 :00 1.00 WHSUR P RUNCMP Wait on Little Red. 01 :00 - 03:30 2.50 RUNCOMP RUNCMP R/U Little Red to reverse circulate 190 Bbls 12.4 ppg brine. Test lines to 4000 psi. Circulate 2 BPM, 800#, 140 F. 03:30 - 04:30 1.00 RUNCOMP RUNCMP Drop ball and rod. Pressure tubing to 4000 psi, record and hold 30 mins. 04:30 - 05:30 1.00 RUNCOrvP RUNCMP Bleed tubing to 2000 psi, pressure annulus to 4000 psi, record and hold 30 mins.. Bleed Tubing pressure down and sheared the DCK-SV. Pump both ways to verify. 05:30 - 06:00 0.50 RUNCOtvIP RUNCMP Secure Cellar. Release Rig at 06:00 hrs. Printed: 11/29/2004 11:52:48 AM ) ) c-)GO v- [1 hþ BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 November 29, 2004 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: MPF-83i (PTD 2000930) Application to cancel Sundry #302-204 Dear Mr. Aubert: Attached is Application to Cancel Sundry form 10-404 for Sundry #302-204. This request is to cancel the current sundry for slow T x IA communication at injection well MPF-83i. The well has recently been worked over and new tubing installed on 11/28/04. A successful MIT-IA was performed shortly after landing the new completion. If you require any additional information or clarification, please contact me at 564-4660 or John Cubbon at (907) 670-3387. s~nCereIY'~') 0~ . ~ark Sau e Milne Point Production Coordinator Attachment: 1) Application for Sundry Cancellation form 10-404 SCANNEr.'; DEC 1 3 2004 jIo ) STATE OF ALASKA', ALASKA OIL AND GAS CONSERVATION COMI",{SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D Repair Well 0 PluÇJ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate D 38.85 8. Property Designation: ADL-388235 11. Present Well Condition Summary: 4. Current Well Class: Development D Stratigraphic D 9. Well Name and Number: MPF-83 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool, Milne Point Unit ExploratoryD Service ŒI Stimulate 0 Other[! WaiverD Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 200-0930 6. API Number 50-029-22963-00-00 Cancel Sundry 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 14182 feet true vertical 6985.1 feet Plugs (measured) Junk (measured) None Effective Depth measured 14083 feet true vertical 6993.6 feet None Casing Conductor Liner Production Surface Perforation depth: Length 82 3829 10519 4808 Size 20" 94# K-55 4-1/2" 12.6# L-80 7" 26# L-80 9-5/8" 40# L-80 MD TVD 28 110 28.0 - 110.0 10339 - 14168 6885.5 - 6986.3 26 - 10545 26.0 - 6939.8 29 - 4837 29.0 - 4262.7 Burst Collapse 520 7500 5410 3090 2110 8430 7240 5750 Measured depth: 10810 -10830,10890 -10911,10935 -10955,11075 -11095,11123 -11144,11160 -11165,11205 -11225 11265 -11285,12180 -12200,12250 -12254,12315 -12318,12415 -12435,12465 -12485,12890 -12910,13190 -13198 13465 - 13485, 13640 - 13680, 13699 - 13720, 13755 - 13848 True vertical depth: 6998.84 -7002.61,7013.44 -7017.09, 7021.17 -7024.5, 7044.17 -7047.33,7051.58 -7054.39, 7056.23 -7056.75 7060.23 -7061.77, 7064.73 -7066.15,7071.45 -7070.8, 7068.88 -7068.7, 7065.55 -7065.37, 7059.02 -7057.47 7055.27 -7054.25, 7050.32 -7050.32, 7044.7 -7044.34, 7036.29 -7035.74,7026.68 -7022.99,7021.25 -7019.68 7017.64 - 7012.11 Tubing ( size, grade, and measured depth): 3-1/2" 9.3# L-80 @ 25 8097 Packers & SSSV (type & measured depth): 3-1/2" SAB-3 Perm Packer 5" Baker ZXP Liner Top Packer @ 8059 @ 10339 12. Stimulation or cement squeeze summary: Intervals treated (measured): 13 Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Iniection Data Gas-Met Water-Bbl Casing Pressure Oil-Bbl Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - Daily Report of Well Operations - ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD Development D Service ŒI 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Printed Name Ma,~k sauve, þ) Signature I~"L,Æ~- WAG ŒJ GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 302-204 Title MP Artificial Lift & Production Coordinator Phone 564-4660 Date 12/2/04 RBDMS BFL DEC 0 7 2004 Form 10-404 Revised 4/2004 MPF-83i (PTD #2000930) post RWO MITIA ) Subject: MPF-83i (PTD #2000930) post RWO MITIA From: "Cubbon, John R" <CubbonJR@BP.com> Date: Sun, 28 Nov 2004 17:11 :21 -0900 To:: "Jim Regg (E-mail)" <jim_regg@admin.state.ak.us>, "Bob Fleckenstein (E-mail)" <bpb_fleckenstein@admin.state.ak.us>, "Tom Maunder (E-mail)" . <tqm- maunder@admin.state.ak.us> . . . CG: "Sauve, Mark A" <mark.sauve@BP.com>,"MPU;Well Operations Supervisor". <~elloperationssupervisor@BP.com>, "MPU, Wells Ops Coord2". .. . . <MPUWells()psCoord2@BP.com>, "MPU, Wells Ops.Coord" <MPUWellsOpsC~ord@BP.com>, "G-urbanov, Ali G"<GurbanAG@BP.com>, "Engel, Hany R" <EngèlHR@BP.com> . . ) ..., . .ø-r;t!l,~;72: o,.l}(JJ::-"""\:.,i.i¡.t.:;i ~~ ~,z..'1-04- Hi Bob, Tom, and Jim, Please see the attached MIT form for MPF-83i. This well was just worked over to replace the tubing. The well was operating under sundry #302-204 for PWI with slow T x IA communication. Mark Sauve will be submitting a form 10-404 to cancell this sundry because the well has been repaired. We will have an AOGCC witnessed MITIA once the well is POI. If you have any questions, please don't hesisitate to contact either Mark Sauve, or myself. Thanks, John Cubbon MPU Well Operations Coordinator 1-907-670-3387 «MIT MPU F-83 11-28-04.xls» MPU F -83 Content-Description: MIT MPU F-83 11-28-04.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 SCANNED DEC 0 1 2004 1 of 1 11/29/2004 8:57 AM ") ;T ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration - Alaska Milne Point Unit IF-pad 11/28/04 Lee Hinkel Packer Depth Pretest Initial 15 Min. 30 Min. Well F-83i Type Inj. G TVD Tubing 0 2,000 2,000 2,000 Interval P.T.D. 2000930 Type test P Test psi 4,000 Casing 0 4,000 4,000 4,000 P/F Notes: MIT performed on the rig after RWO to change out tubing. AOGCC witnessed MITIA to be performed once well is POI. AOGCC sundry #302-204 for injection service with T x IA communication will be cancelled. Well Type Inj. TVD Tubing P. T. D. Type test T est psi Casing Notes: 0 P Interval P/F Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S,= Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 2004-1128_MIT _MPU_F-83.xls ) ) @ ~ ff1\ '7 re ~ re ff1\ ~ ff1\ @ ~f! ff1\ æ) ~ LÆ W' lJ:d J LÆ -b LÆ Q)) ~~ LÆ ALASKA OIL AND GAS CONSERVATION COMMISSION I / I FRANK H. MURKOWSKI, GOVERNOR 333 W. -¡m AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~Ðb.~ (£)13 Re: Milne Point MPF-83i Sundry Number: 304-413 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. . er~ BY ORDER OF THE COMMISSION DATED this If) day of November, 2004 Encl. SCANNED NOV 1 5 2004 - " P{5S ) STATE OF ALASKA ) /// /d/(2- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Ih\l\o NOV 0 2004 1. Type of Request: 0 Abandon III Repair Well 0 Plug Perforations 0 Stimulate 0 Alter Casing III Pull Tubing 0 Perforate New Pool 0 Waiver 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well Opg/:åðê:rf~'b¡~~i~ , III Other 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 38.85' 4. Current Well Class: 0 Development 0 Exploratory 0 Stratigraphic 111 Service 5. Permit To Dri!J. Number 200-093 ./ 6. API Number: ./ 50- 029-22963-00-00 9. Well Name and Number: MPF-83i 8. Property Designation: 10. Field / Pool(s}: ADL 388235 Milne Point Unit / Kuparuk River Sands " , ,,~~I;SßNTYV:~U..QQNPIJJON:$I;Jry1Î\~;~R)1"'1 ' " , Total Depth TVD (ft): I Effective Depth MD (ft): I Effective Depth TVD (ft): Plugs (measured): 6985 14083 6994 None Length Size MD TVD Burst 11.' Total Depth MD (ft): 14182 Casing Structural Conductor Surface Intermediate Production Liner Junk (measured): None èollapse 110' 20" 110' 110' 4808' 9-5/8" 4837' 4263' 5750 3090 10519' 7" 10545' 6940' 7240 5410 3829' 4-1/2" 10339' - 14168' 6885' - 6986' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): 10810' - 13890' 6999' - 7009' Packers and SSSV Type: Baker 7" x 3-1/2" SAB-3 Perm packer Tubing Size: 3-1/2",9.3# Tubing Grade: L-80 Packers and SSSV MD (ft): 8059' Tubing MD (ft): 8097' 12. Attachments: 111 Description Summary of Proposal 0 Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby cert~ that the foregoing is true and correct to the best of my knowledge. Printed Nam, \r' - I J,\"DaVid_Ree}li1 /l <} Title Drilling Engineer Signature {~( /' ¡~ Phone 564-5743 Çpmmi$$ipl) Y$~..Ql)ly 0 BOP Sketch 13. Well Class after proposed work: 0 Exploratory 0 Development 111 Service 15. Well Status after proposed work: 0 Oil 0 Gas 111 WAG DGINJ 0 Plugged DWINJ 0 Abandoned 0 WDSPL November 15,2004 Date: Contact David Reem, 564..5743 Conditions of approval: Notify Commission so that a representative may witness 0 Plug Integrity ~OP Test ~echanicallntegrity Test 0 Location Clearance . ~Ç'S' ~C)~ ~Ç.:\-Q.S. ~\o-~ . . "\ Other. ..., ð 00 \~<>:.\-~ \' L ~'\ ~ ~~ O(..~vtro-~\t:i:c \X-'" ð-\J Þ>..l\ '- d S' . 4SD<'<:"" Date "/~) Dý I Sundry Number: 3d1-¥-/3 Prepared By Name/Number: Sondra Stewman, 564-4750 COMMISSIONER APPROVED BY THE COMMISSION RBDMS BFL NOV 1 2 2004 Date /I.!,ð(ðc.t SX~: In Dl.IOlicate ~ ORIGINAL -) ') Project: MPF-83i Rig W orkover/Tubing Upgrade MPF-83i Status: SI with known 3.5" tubing leak. Scope of Work: work will be performed by Nabors 4ES 1) MIRU Nabors 4ES 2) Kill Well, set TWC, ND tree, NU and test BOPE to 4000 psi 3) Pull existing 3.5", 9.2#/ft, L-80 completion down to chemical cut 4) Mill & retrieve Baker SAB-3 Packer/tubing tail @ 8059' MD 5) Bit & scraper run, and FCO to PBTD inside 4.5" liner 6) Run 4.5" x 2.875" WD packer and tailpipe (plug installed) and set at 11030' MD 7) Set 7" RBP and storm packer. Change out wellhead and tubing hanger 8) Run 4.5" 12.6#/ft, L-80 Tcn injection completion & set permanent packer at 8050' MD. PT tubing to 4000 psi f/30-minutes, PT IA to 4000 psi f/30-minutes 9) Install new tree 10) RDMO Nabors 4ES Pressure: 12.2 ppg brine will be required to kill this well SCANNED NOV 1 5 2004 CURRENT . ' Tree:Cameron 3 1/8", S ) Wellhead:FMC 11" x 7-1/16" 5M, Gen. Sa wI 6" x 3.5" FMC Tbg. Hnr. wI 3.5' eue threads top and btm. 3" CIW H BPV profife MPU F-83i Orig. ') Elev. = 28.5 (Doyon -141) Orig. GL Elev. = RT To Tbg. Spool = ~ 20" 91.51 ppf, H-40 ~ 0 9 5/8" Tam port collar I 1007' I KOP @ 700 to 9,880' Max. hole angle = 95 deg. deg. 6,800' - 11,050' 40 - 80 deg. Hole angle thru' perfs = 90+ deg. U-Shaped sec. 11,000'-14,182' 9 5/8", 40 ppf, L -80 Btrc. I 4,837 ~ HES X-Nipple 2.813" id I 2,191' I 3.5" 9.3 ppf, L-80 nsct tubing. ( drift id = 2.992", cap = 0.0087 bpf ) , ;1 " ;~ . ¡ "1 , 'j :j HES X-Nipple 2.813" id I 8,047' I I 8,059' I '~(,"-\JÙ\ \-~cl ~ Co %-C 7" 29 ppf, L-80, btc mod. casing ( drift id = 6.276", cap. = 0.0383 bpf ) .. I . ;;:::::::::~~r:::m§M:;:m.I_BS¡!1iWmi;::~m~¡:;:,:,::::: . ~J r " t ~j .WrnI Baker 7"x3.5" SAB-3 perm pkr. HES XN-Nipple 2.750" id I 8,085' I Angle at nipple 68 deg. WLEG I 8,097' I SCANNED NO\! 1 5 2004 6' Baker tie back sleeve 110,338' I 7"x 5" Baker ZXP Liner pkr. 110,348' I Baker "HMC" hyd. Liner hng. Ai ~ 7" float collar 7" float shoe 10,462' 10,545' ~ Coc;. ~~ (~J ~,,~O Peñoration Summary Ref log: MWD log. 7/25/00 Angle through perfs 79 deg - 95 deg. U-Shaped. Size Spf I nte rval (TVD) *See :>rogram TCP irtervals * 2-7/8" , 15.2 gram 34j uj, RDX charges 60 deg. phasing 490' md of shots ~ ~ ~G-"~ \Qç;\()~ b~C;~ \-~CJ ~ 6\---~,~ \ :,~Ù~ ì Q(f\.\"j ~ \~\\' Q~v\ '\()~ \ \~ d ,J%mwx.."w.<-_..... DATE REV. BY 07/30/00 MDO 08/27/00 MDO 06/20/04 MDO 08/14/04 MDO 4.5" 12.6 ppf, L-80, NSCT (drift ID = 3.958", cap. = 0.0152 bpf) 4.5" Landing Collar (PBTD) 4.5" float collar 4.5" float shoe 14,082' md 14,124' md 14,168' md bC;c; ~ .~,,;) COMMENTS Cased hole Doyon 141 Perfs and Completions 4-ES Weatherford patch set Pulled Weatherford patch set MILNE POINT UNIT WELL No.: F-83i API: 50-029-22963-00 BP EXPLORATION (AK) PRoPOSED ..)PU F-83i I' . rree:Cameron 3 1/8", 5M Wellhead:FMC 11" x 7-1/16' 5M, Gen. Sa wI 6" x 3.5" FMC Tbg. Hnr. wI 3.5' eue threads top and btm. 3" CIW H BPV profile 20" 91.51 ppf, H-40 [Æ] A KOP @ 700 to 9,880' Max. hole angle = 95 deg. deg. 6,800' .. 11,050' 40 - 80 deg. Hole angle thru' perfs = 90+ deg. U-Shaped sec. 11,000' -14,182 ~: ,~ ;r :1 J ~ ,~ ,~ ~I .~ . ,;~ ~ cJlI: ~JC ~ ? '~ '~ ;!I ~ ~.J 95/8", 40 ppf, L-80 Btrc. I 4,837' ~ .. 7" 29 ppf, L-80, btc mod. casing ( drift id = 6.276", cap. = 0.0383 bpf ) 4.5" 12.6 ppf, L-80 nsct tubing. ( drift id = 3.958", cap = 0.01521 bpf) .':::::::::::8~~*=:::.:;:;:;:::::'::. tJ SCANNED NO\ll 5 2004 .. Perforation Summary Ref log: MWO log. 7/25/00 Size Spf Interval (TVO) *See =>rogram TCP jrtervals * 2-7/8" , 15.2 gram 34j uj, ROX charges 60 deg. phasing 490' md of shots DATE 07/30/00 08/27/00 06/20/04 08/14/04 REV. BY MOO MOO MDO MDO COMMENTS Cased hole Doyon 141 Perfs and Completions 4-ES Weatherford patch set Pulled Weatherford patch set Orig. OF Elev. = 2l þoyon -141) Orig. GL Elev. = RT To Tbg. Spool = 0 95/8" Tam port collar I 1007' I HES X-Nipple 2.813" íd I 2,191' I i HES X-Nipple 2.813" id I 8,047' I Baker 7"x4.5" SAB-3 perm pkr. I HES XN-Nipple 2.750" id I 8,085' I Angle at nipple 68 deg. WLEG I 8,097' I 6' Baker tie back sleeve 110,338' I 7"x 5" Baker ZXP Liner pkr'10,348' I Baker "HMC" hyd. Liner hng. I ... 7" float collar 1 0,462' I 7" float shoe 10,545' 01 Retrievable Plug 11,030' Angle through perfs 79 deg - 95 deg. U-Shaped. 4.5" 12.6 ppf, L-80, NSCT ( drift 10 = 3.958", cap. = 0.0152 bpf ) ~: 4.5" Landing Collar (PBTO) 14,082' md 4.5" float collar 14,124' md 4.5" float shoe 14,168' md MILNE POINT UNIT WELL No.: F-83i API : 50-029-22963-00 BP EXPLORATION (AK) Tree:Cameron 3 1/8", 5" ) Wellhead:FMC 11" x 7-1/16" 5M, Gen. Sa w/ 6" x 3.5" FMC Tbg. Hnr. w/ 3.5' eue threads top and btm. 3" CIW H BPV profile A 20" 91.51 ppf, H-40 ~ KOP @ 700 to 9,880' Max. hole angle = 95 deg. deg. 6,800' - 11,050' 40 - 80 deg. Hole angle thru' perfs = 90+ deg. U-Shaped sec. 11,000'-14,182' 9 5/8", 40 ppf, L-80 Btrc. I 4,837 ~ 7" 29 ppf, L-80, btc mod. casing ( drift id = 6.276", cap. = 0.0383 bpf ) 3.5" 9.3 ppf, L-80 nsct tubing. ( drift id = 2.992", cap = 0.0087 bpf ) :;CANNED NOV 1. 5 2004 Perforation Summary Ref log: MWD log. 7/25/00 Size Spf (TVD) Interval * See :>rogram TCP irtervals * 2-7/8" , 15.2 gram 34j uj, RDX charges 60 deg. phasing 490' md of shots MPU F-83i .,"', ,.. . ::;,::::::':::~~;;:,:.:''m:~:;ì!f;S!R_BBWl:~¡:w:m,'1:':':::';:::;:. f .~ ,,;1 .. DATE 07/30100 08/27/00 06/20/04 08/14/04 REV. BY MDO MDO MOO MDO COMMENTS Cased hole Doyon 141 Perfs and Completions 4-ES Weatherford patch set Pulled Weatherford patch set Orig. ) Elev. = 28.5 (Doyon -141) Orig. GL Elev. = RT To Tbg. Spool = 0 95/8" Tam port collar I 1007' I HES X-Nipple 2.813" id I 2,191' I , HES X-Nipple 2.813" id I 8,047' I Baker 7"x3.5" SAB-3 perm pkr. I 8,059' I HES XN-Nipple 2.750" id I 8,085' I Angle at nipple 68 deg. WLEG I 8,097' I 6' Baker tie back sleeve 110,338' I 7"x 5" Baker ZXP Liner pkr. 110,348' I Baker "HMC" hyd. Liner hng. ~ 7" float collar 7" float shoe 10,462' 10,545' Angle through perfs 79 deg - 95 deg. U-Shaped. 4.5" 12.6 ppf, L-80, NSCT ( drift ID = 3.958", cap. = 0.0152 bpf ) 4.5" Landing Collar (PBTD) 4.5" float collar 4.5" float shoe 14,082' md 14,124' md 14,168' md MILNE POINT UNIT WELL No.: F-83i API: 50-029-22963-00 BP EXPLORATION (AK) ) d(X)-O~ 3> MECHANICAL INTEGRITY REPORT' '--. -= ï G ~ t"i ':.' .:: ::-. . <t!>I", -, -O"~ . .. - t\ .... ...J -.Þ r. "-' ,"" .. 0 OPER & FIELD - ~." \-1\-, \~((. ~,~ w"ELL NUH:BER ~ \' ç:. - ~'~"') =PUD DA!E: : Casing: TD: \l.\\cad.MD.. b~~Ç TVD; :?ETD: \l.\O~S H:I? ~<;C; Ll TVD 'ì '" . Shoe: \C>S\..f5 till .~<;'3() TVD; DV:' ~~ MD .T'Vl) ~:':1e~ :t,\l~ Shoe: \titt,<611D '~la'\<;l.{ TVD i :OP: $rš3~HD~~<O :"'ID :~bi;:¡g: StS" P acke:: ~ MD~<O'-\d'Ò TVD i Set ê. t \ \ ~'-'>\~\p\(t \"~~~\~ :". ~.. ~o le Size <6 Ië) anå Co (ß Perfs \0'6\.0 to \ ~ x~ O. "C) <D<;<;~'~~ ~OO~ ~,~~ :~ ~LL DATA tŒ:CèIÞ_NICf..L INTEGRITY - PART /1 Annulus Press Test: ~:P ; 15 min ; 30 min COW!!le~ts: "'-\<r\\ ~~ ~~~~ <:C\~~~~~~",-\t> '-(:'\-1 'P~~~, '1 ~,:>~,~-\Ð ~61~~~~ \ /' . . <:"'\'~L"'\ ~..ç.. \\~, '~~ HECHÞ_1\IICÞ.~ INTEGRITY - PART /2 ,<; \~,,\~ \ ~ "'S~\.>\~ Cement Volumes:' þ...mt. Line.r LtbS-S)( i Cs ~ S~ \ s'( ; DV ~ ~ . Cüit: -"01 to cove!:' perfs ~G-~ <n'" ~C~;(~ '( ~ \.\C'\ c;"" S~\G:'U'-\- ~ et:Ñ~'~ ~~~ sœ \ Theoretical Toe <..~~~~~';.ò..«:~\~~~~\\-..t \\~~p ~ '" ) e:;( \ b - 00 , " Cement Bond Log (Yes or No) '\<.£ ~ ;;Ln AOGCC File .",,~<f!..> " . --- .. '.._, '--'---'-'------.--. -.,-....."... . u \ eBL Evalu!,-tion, zone ê.Q.Qve ,Lerfs \<)~\., C'I'..''''' \" "\"n.~",\ \0 ~1D <6~OO \r ~\\\..., ~ \\~\Q:~~~~ ~~O$~s.c~:\t~ ~~c..~~w:\ ~ rex ~'.. ~~OO' -s;.~~\~,~~~~~/~~ \~,,~\t.,> ,-\-~~ \~\~~ ' -+~~""\\.(ô.. Ð'~~\~ ~ '1''-s~. '<:.<i;.I/Vútt\.~~I..«:,'o.\~~ ~-\dr<>~'~; Prociuc.tion Log: Typ~ ; Evaluation . ¡ I . ' CONCLUSIONS: :? a.r:: : Z : SCANN" . €n No Iv .1 .., 5 2004 ~1: \""~~Q~~Act)" . 1O/'7'J'1 \ \/lo-o~ ? art: 1 : Rþ: MPF:83i ~g workover ') ) Subject: RE: MPF-83i rig workover From: "Reem, David C" <ReemDC@BP.com> Date: Fri, 05 Nov 2004 10:33:59 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Tom, this is an inverted horizontal Kuparuk injector. Perfs extend from 10810' md to 13890' md in several discreet intervals all shot with 2.875" TCP guns 8/18/2000. The current 3.5" x ?" packer is set at 8059' md (-6425' tvd), the 4.5" x 7" liner-top packer is set at 10348' md (-68901 tvd), and the top perf is 10810' md (-6992' tvd). The lower packer is to allow flexibility to inject in Kuparuk A1, A2 above the packer and not lose majority of injection into thief towards the toe of this inverted liner, so lIyes" isolation is the intended purpose. Hope this info helps Tom. From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, November OS, 2004 10: 15 AM To: Reem, David C Subject: .Re: MPF-83i rig workover Thanks Dave. Where are the perfs in the well?? Could be a long way from where the upper packer is being set. Are you giving some isolation ability by running the lower packer assembly?? Tom Maunder, PE AOGCC Reem, David C wrote: Tom, this proposed workover has gone thru many permutations over the last couple of weeks which is why I have not yet submitted a Sundry application for the workover itself. As of yesterday, the Milne Point Asset seems fairly confident that the work scope is at long last ironed out. As such, just wanted to give you a general "heads-up" as to the proposed plans for this injector. 1) Kill well, ND tree/NU and test to 4000 psi the BOPE, pull existing 3.5" completion down to the cut just above the packer. 2) mill and recover permanent 3.5" x 7" packer w/tailpipe 3) cleanout 4.5" liner to PBTD 4) run and set 2.875" x 4.5" packer and tailpipe (with tubing tail plug installed). 11030'md. 5) run 4.5" 12.6# L-80 TCII completion with permanent packer set at -8050'md. 6) MIT-T to 4000 psi, MIT-IA to 4000 psi. 7) set BPV, ND BOPE, NU tree and test to 5000 psi. RDMO. Set depth = Tom, I'm trying to get a proposed diagram generated from the Milne engineer - hope it's not as difficult as getting a final job scope. Once I get that in hand we'll apply for a Sundry for this workover. Please call with any questions/concerns. Thanks. Dave Reem Wells/Workover Engineer 564-5743 (w) 632-2128 (c) SCANNED NOV 1 5 2004 1 of 1 11/1 0/2004 8:52 AM Re: MPF-83i (PTD #2000930) MITIA for PWI with slow T x lA, su... .. .. 10' ) ) Subject: Re: MPF-83i (PTD #2000930) MITIA for PWI with slow T x IA, sundry (#302-204) From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 09 Jun 2004 06:50:58 -0800 To: Jim Regg <jim_regg@admin.state.ak.us> BP just submitted a sundry to install a patch in this well so they can start up MI again. Tom Cubbon, John R wrote: Hi Jim, Tom, and Bob, Please see the attached MIT form for Milne Point injector MPF-83i. This well is has a sundry (#302-204) for slow T x IA communication due to slow IA pressurization when on injection. However, the leak rate continues to be so slow that the well passes standard MITIAs. If you have any questions, or need any additional details, please let me know. Thanks, John Cubbon MPU Well Operations Coordinator l-907-670-3387 «040608 AOGCC MIT form F-83i.xls» 8CANN~r- , c'1) NO 1/ 1 ~ . . oj 2004 1 of 1 11/10/20048:51 AM MPF-83i (PTD #2000930) MITIA for PWI with slow T x lA, sundry... ., ... ) ') Subject: MPF-83i (PTD #2000930) MITIA for PWI with slow T x IA, sundry (#302-204) From: "Cubbon, John R" <CubbonJR@BP.com> Date: Tue, 08 Jun 2004 19:57:15 -0800 To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak.us>, "Jim Regg (E-mail)" <jim _regg@admin.state.ak.us>, "Bob Fleckenstein (E-mail)..<bob_fleckenstein@admin.state.ak.us> CC: "Sauve, Mark A" <mark.sauve@BP.com>, "Hulme, Lee (APC)" <HulmePL@BP.com>, "MPU, Well Operations Supervisor" <welloperationssupervisor@BP.com>, "MPU, Wells Ops Coord" <MPUW ellsOpsCoord@BP.com> Hi Jim, Tom, and Bob, Please see the attached MIT form for Milne Point injector MPF-83i. This well is has a sundry (#302-204) for slow T x IA communication due to slow IA pressurization when on injection. However, the leak rate continues to be so slow that the well passes standard MITIAs. If you have any questions, or need any additional details, please let me know. Thanks, John Cubbon MPU Well Operations Coordinator 1-907-670-3387 «040608 AOGCC MIT form F-83i.xls» AOGCC MIT form C t t D . f . 040608 AOGCC MIT form on en - escnp Ion. F-83i.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 SC,ANNEn NO\i 1 5 200!~. 1 of 1 11/10/2004 8:51 AM . I , "" I ) -) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration - Alaska Milne Point Unit / F-pad 06/08/04 John Cubbon Packer Depth Pretest Initial 15 Min. 30 Min. Well F-83i Type Inj. S TVD 7,125' Tubing 3,100 3,100 3,100 3,100 Interval P.T.D. 2000930 Type test P Test psi 1,781 Casing 2,000 4,200 4,060 4,000 P/F Notes: Water Injector operating under AOGCC variance #302-204 requiring a leak rate test between tubing and IA every year Also requires a CMIT T x IA every 4 years. Well Type Inj. TVD P.T.D. Type test Test psi Notes: v P Tubing Casing Interval P/F Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: This well passed a standard MITIA while attempting the annual LLRT-IA. This test satisfies both the annual LLRT-IA requirement and the 4-year CMIT T x IA. This well will continue to be classified as a water injector with slow T x IA communicaiton since it is known to have slow IA pressurization when on water injection. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) SCANNEn NO\! 1 5 2004 MIT Report Form Revised: 06/19/02 040608 AOGCC MIT form F-83i.xls ~ ~ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 Repair Well 0 PluQ PerforationsD Pull TubingO Perforate New PoolO Operation ShutdownO Perforate 0 38.85 8. Property Designation: ADL-388235 11. Present Well Condition Summary: 4. Current Well Class: Development 0 Stratigraphic 0 9. Well Name and Number: MPF-83 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool, Milne Point Unit ExploratoryD ServiceŒ] Stimulate 0 OtherŒ WaiverD Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 200-09 0 6. API Number 50-029-22963-00-00 Pull Patch 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 14182 feet true vertical 6985.1 feet Effective Depth measured 14083 feet true vertical 6993.6 feet Plugs (measured) Junk (measured) None None Casing Conductor Liner Production Surface Length 82 3829 10519 4808 Size 20" 94# K-55 4-1/2" 12.6# L.80 7" 26# L-80 9-5/8" 40# L-80 MD TVD Burst 2110 8430 7240 5750 Collapse 520 7500 5410 3090 28 110 28.0 110.0 10339 . 14168 6885.5 - 6986.3 26 - 10545 26.0 - 6939.8 29 . 4837 29.0 - 4262.7 Perforation depth: Measured depth: 10810 -10830,10890 -10911,10935 -10955,11075 -11095,11123 -11144,11160 -11165,11205 -11225 11265 -11285,12180 -12200,12250 -12254,12315 -12318, 13465 -13485,13640 -13680,13699 -13720,13755 -13848 True vertical depth: 6998.84 - 7002.61,7013.44 - 7017.09, 7021.17 - 7024.5, 7044.17 - 7047.33, -,7051.58 - 7054.39, 7056.23 - 7056.75 7060.23 - 7061.77,7064.73 - 7066.15,7071.45 - 7070.8,7068.88 - 7068.7,7065.55 - 7065.37, 7059.02 - 7057.47 7055.27 - 7054.25,7050.32 - 7050.32, 7044.7 - 7044.34,7036.29 - 7035.74,7026.68 - 7022.99,7021.25 - 7019.68 7017.64 - 7012.11 Tubing ( size, grade, and measured depth): 3-1/2" 9.3# L-80 @ 25 8097 Packers & SSSV (type & measured depth): 3-1/2" SAB-3 Perm Packer 5" Baker ZXP Liner Top Packer @ 8059 @ 10339 ~ECE'VE[ 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Recresentative Dailv Averaae Production or Iniection Data . ,~i' n c ~n14 ')" ~. Gas Cons. , " An~~' 13 Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Gas-Me! Water-Bbl Casing Pressure Tubing Pressure 0 0 -4786 3050 3237 0 0 -2687 2900 2842 Copies of Logs and Surveys run - Daily Report of Well Operations. ~ 15. Well Class after proposed work: Exploratory 0 16. Well Status after proposed work: OilD GasD DevelopmentD Service I]] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature WAG ŒI GINJD WINJD WDSPLD Prepared b Gar Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA Title Production Technical Assistant Phone 564-4657 Date 9/3/04 Form 10-404 Revised 4/2004 OR\G\NAL IØIIS SF L SEP 1 3 2UUl¡ r--- .~ MPF-83 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/14/04 «WELL INJECTING ON ARRIVAL». PULL WEATHERFORD PATCH ASSEMBLY. FESCO PUMPED 30 BBLS METHANOL DOWN TUBING FOR FREEZE PROTECT. «JOB IN PROGRESS, LAY SWCP DOWN FOR NIGHT» 08/14/04 FREEZE PROTECT TBG WITH 30 BBLS METH.lWHP=2800/3000/0. FWHP=2950/3000/0 FLUIDS PUMPED BBLS 30 30 I Methonal TOTAL Page 1 Tree:Cameron 3118", 5... Welihead:FMC 11" x 7-1/16" 5M, Gen. 5a w/ 6" x 3.5" FMC Tbg. Hm. w/ 3.5' eue threads top and btm. 3" CIW H BPV profile 20" 91.51 ppf, H-40 ~ KOP @ 700 to 9,880' Max. hole angle = 95 deg. deg. 6,800' - 11 ,050' 40 - 80 deg. Hole angle thru' perfs = 90+ deg. U-Shaped sec. 11 ,000'-14,182' 95/8",40 ppf, L-80 Btrc. 7" 29 ppf, L-80, btc mod. casing ( drift id = 6.276", cap. = 0.0383 bpf ) 3.5" 9.3 ppf, L-80 nsct tubing. ( drift id = 2.992", cap = 0.0087 bpf ) Peñoration Summary Ref log: MWD log. 7/25/00 Interval ervals * 2-7/8" ,15.2 gram 34j uj, ADX charges 60 deg. phasing 490' md of shots TVD MPU F-83i DATE REV. BY COMMENTS 07/30/00 MDO Cased hole Doyon 141 08/27/00 MDO Perfs and Completions 4-ES 06/20/04 MOO Weatherford patch set Orig. . Elev. = 28.5 (Doyon -141) Orig. GL Elev. = AT To Tbg. Spool = 9 5/8" Tam port collar I 1007' I HES X-Nipple 2.813" id I 2,191' I HES X-Nipple 2.813" id I 8,047' I Baker 7"x3.5" SAB-3 perm pkr. I 8,059' I HES XN-Nipple 2.750" id I 8,085' I Angle at nipple 68 deg. WLEG I 8,097' I 6' Baker tie back sleeve 110,338' I 7"x 5" Baker ZXP Liner pkr. 110,348' I Baker "HMC" hyd. Liner hng. 7" float collar 7" float shoe Angle through perfs 79 deg - 95 deg. U-Shaped. 4.5" 12.6 ppf, L-80, NSCT ( drift ID = 3.958", cap. = 0.0152 bpf ) 4.5" Landing Collar (PBTD) 4.5" float collar 4.5" float shoe 14082' md 14,124' md 14,168' md MILNE POINT UNIT WELL No.: F.83i API: 50-029-22963-00 BP EXPLORATION AK ,.---.... ,~ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1, Operations Performed: AbandonD Alter CasingD Change Approved Program D 38.85 8. Property Designation: ADL-388235 11. Present Well Condition Summary: 4. Current Well Class: Development 0 Stratigraphic 0 9. Well Name and Number: MPF-83 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool, Milne Point Unit ExploratoryD ServiceŒ Stimulate D OtherD WaiverD Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 200-0930 6. API Number 50-029-22963-00-00 Repair WellŒ PluQ PerforationsD Pull TubingD Perforate New Pool 0 Operation ShutdownD Perforate 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 14182 feet true vertical 6985.1 feet Effective Depth measured 14083 feet true vertical 6993.6 feet Plugs (measured) Junk (measured) None None Casing Conductor Liner Production Surface Length 82 3829 10519 4808 Size 20" 94# K-55 4-1/2" 12.6# L-80 7" 26# L-80 9-5/8" 40# L-80 MD TVD 28 110 28.0 - 110.0 10339 - 14168 6885.5 - 6986.3 26 - 10545 26.0 - 6939.8 29 - 4837 29.0 - 4262.7 Burst 2110 8430 7240 5750 Collapse 520 7500 5410 3090 Perforation deDth: Measured depth: 10810 -10830,10890 -10911,10935 -10955,11075 -11095,11123 -11144,11160 -11165,11205 -11225 11265 -11285,12180 -12200,12250 -12254,12315 -12318,13465 -13485,13640 -13680,13699 -13720,13755 -13848 True vertical depth: 6998.84 - 7002.61,7013.44 - 7017.09,7021.17 - 7024.5,7044.17 - 7047.33, -,7051.58 - 7054.39, 7056.23 - 7056.75 7060.23 - 7061.77,7064.73 - 7066.15, 7071.45 - 7070.8,7068.88 - 7068.7, 7065.55 - 7065.37, 7059.02 - 7057.47 7055.27 - 7054.25.7050.32 - 7050.32,7044.7 - 7044.34, 7036.29 - 7035.74.7026.68 - 7022.99,7021.25 - 7019.68 7017.64 - 7012.11 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 3-1/2" 9.3# L-80 2-3/8" 4.7# L-80 3-1/2" SAB-3 Perm Packer 5" Baker ZXP Liner Top Packer 3-1/2" WF Patch Packer 3-112" WF Patch Packer @ 25 @ 5314 @ 8059 @ 10339 @ 5314 @ 5346 8097 5351 RECE IVEO 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ReDresentative Dailv Averaae Production or Iniection Data ". ..:., ' ,,~: /', I . '1',14 ~~ 13 Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure 0 0 -4408 3200 3131 0 0 -4339 3200 3104 Copies of Logs and Surveys run - Daily Report of Well Operations. ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil 0 GasD DevelopmentD ServiceŒ] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature WAG ŒI GINJD WINJD WDSPLD Prepared b Gar Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 304-219 Title Production Technical Assistant Phone 564-4657 Date 9/3/04 Form 10-404 Revised 4/2004 ORIGINAL ,RBDMS Sf L SEP 1 ;3 2004 ~ ~ MPF-83 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/20/04 PUMP DOWN WELL WITH 40 BBLS METH 06/20/04 SET WFD 3.5" PATCH ELEMENTS 5348' & 5317' WITH TOP @5314.5', MIN ID 1.745". FLUIDS PUMPED BBLS 40 40 I Metho"al TOTAL Page 1 Tree:Cameron 3 1/8", b,., Welihead:FMC 11" x 7-1/16" 5M, Gen. 5a wI 6" x 3.5" FMC Tbg. Hnr. wI 3.5' eue threads top and btm. 3" CIW H BPV profile 20" 91.51 ppf, HAO ~ KOP @ 700 to 9,880' Max. hole angle = 95 deg. deg. 6,800' - 11,050' 40 - 80 deg. Hole angle thru' perfs = 90+ deg. U-Shaped sec. 11,000'-14,182' 95/8",40 ppf, L-80 Btrc. 7" 29 ppf, L-80, btc mod. casing ( drift id = 6.276", cap. = 0.0383 bpf ) 3.5" 9.3 ppf, L-80 nsct tubing. ( drift id = 2.992", cap = 0.0087 bpf ) Peñoration Summary Ref log: MWD log. 7/25/00 Interval arvals * 2-718" ,15.2 gram 34j uj, RDX charges 60 deg. phasing 490' md of shots TVD MPU F-83i DATE REV. BY COMMENTS 07/30100 MDO Cased hole Doyon 141 08/27/00 MDO Perfs and Completions 4-ES 06/20/04 MOO Weatherford patch set Orig. ..JF Elev. = 28.5 (Doyon -141) Orig. GL Elev. = RT To Tbg. Spool = 9 5/8" Tam port collar I 1007' I HES X-Nipple 2.813" id I 2,191' I HES X-Nipple 2.813" id I 8,047' I Baker 7"x3.5" SAB-3 perm pkr. I 8,059' I HES XN-Nipple 2.750" id I 8,085' I Angle at nipple 68 deg. WLEG I 8,097' I 6' Baker tie back sleeve 110,338' I 7"x 5" Baker ZXP Liner pkr. 110,348' I Baker "HMC" hyd. Liner hng. 7" float collar 7" float shoe Angle through perfs 79 deg - 95 deg. U-Shaped. 4.5" 12.6 ppf, L-80, NSCT ( drift ID = 3.958", cap. = 0.0152 bpf) 4.5" Landing Collar (PBTD) 4.5" float collar 4.5" float shoe 14082' md 14,124' md 14,168' md MILNE POINT UNIT WELL No.: F-83i API: 50-029-22963-00 BP EXPLORATION AK l-ds C!\J II. WELL LOG TRANSMITTAL s:<~ - () 73 #- /2-5 05 ProActive Diagnostic Services, 'nc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE: Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration(Alaska), Inc. Petro-Technical Data Center LR2-1 900 East Benson Blvd. Anchorage, Alaska 99508 WELL DATE LOG TVPE DIGITAL OR CD-ROM 1 MVLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUELINE Open Hole 1 MP F-83i 4-5-04 Res. Eva!. CH 1 1 ~.\3~ ,~ 1 Mech. CH 1 Caliper Survey Print Name: / A all' 1.7 / ¡: r jl/¿,te L1- /1. t vt¿11-ll tLA,-../ ;:/e/¿fGJ u.s--!{b,-/~/1¿:t~1 7!Qjo! Signed: Date: PRoAoi\JE DiACINOSTi( SER\Ji(['), I\(", PO Box I ~b9 STAffoRd IX 77477 Phone:(281) 565-9085 Fa.'\:(28I ) 565-1369 E-mail: pdsl.~.memorylog.comWebsite:\nn\.memorylog.com STATE OF ALASKA ~ - RECÉ'VEDl~(~ ALASKA OIL AND GAS CONSERVATION COMMISSION JUN APPLICATION FOR SUNDRY APPROVAL 072004 20 AAC 25.280 Alaska Oil & Gas Cons. Commíssior Anchorage PerforateD WaiverO Annular DisposalD StimulateD Time ExtensionO OtherD Re-enter Suspended Well 0 5. Permit to Drill Number: 200-0930 ../ Stratigraphic 0 Service ŒI 9. Well Name and Number: MPF-83 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool, Milne Point Unit PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): IEffective Depth TVD (ft): 14083 6954.8 S~ MD nD top bottom top 28 110 10339 14168 26 10545 29 4837 I Tubing Size: 3.5 " 9.3 # Packers and SSSV MD (ft): ~- ",,- - ~ 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: Suspend 0 RepairWell 00 Pull Tubing 0 BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 38.85 KB 8. Property Designation: ADL-388235 11. Total Depth MD (ft): 14182 Casing ITotal Depth TVD (ft): 6985.1 Length Conductor 82 20" 94# K-55 Liner 3829 4-1/2" 12.6# L-80 Production 10519 7" 26# L-80 Surface 4808 9-5/8" 40# L-80 Perforation Depth MD (ft): I Perforation Depth TVD (ft): See Attachment Packers and SSSV Type: 3-1/2" SAB-3 Perm Packer 5" Baker ZXP Liner Top Packer 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 00 BOP Sketch 0 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: June 18, 2004 Date: Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Exploratory 0 6. API Number ./ 50-029-22963-00-00 Plugs (md): None Burst Junk (md): None Collapse 28.0 6885.5 26.0 29.0 bottom 110.0 2110 6986.3 8430 6939.8 7240 4262.7 5750 I Tubing Grade: TUbing MD (ft): L-80 25' 8097 520 7500 5410 3090 8059 10339 13. Well Class after proposed work: ExploratoryD DevelopmentD Service 00 15. Well Status after proposed work: Oil D GasD PluggedD AbandonedD WAG D GINJD WINJŒ WDSPLD Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature ~~ow"c:.end ,~~ ..p Contact Monte Townsend Title Phone Petroleum Engineer 564-4306 6/4/04 Commissìon Use Only I Sundry Number: .......-/ ..30 ~-.;).I f BOP TestD Conditions of approval: Notify Commission so that a representative may witness Location Clearance 0 Other: Subsequent Approved by Form 10-403 Revised 12/2003 ---. Mechanciallntegrity Test ø. BY ORDER OF THE COMMISSION Date: ~f fØIAS Bf L JUM 0 8 1M' no, r, 1 t\' A L SUBMIT IN DUPLICATE - ~ r"\ Attachment Perforation Depth MD (ft): 10810 - 10830 10890 - 10911 10935 - 10955 11075 - 11095 11123 - 11144 11160 - 11165 11205 - 11225 11265 - 11285 12180 - 12200 12250 - 12254 12315 - 12318 12415 - 12435 12465 - 12485 12890 - 12910 13190 - 13198 13465 - 13485 13640 - 13680 13699 - 13720 13755 - 13848 13869 - 13890 Perforation Depth TVD (ft): 6998.84 - 7002.6 7013.44 - 7017.1 7021.17 - 7024.5 7044.17 - 7047.3 7051.58 - 7054.4 7056.23 - 7056.8 7060.23 - 7061.8 7064.73 - 7066.2 7071.45 - 7070.8 7068.88 - 7068.7 7065.55 - 7065.4 7059.02 - 7057.5 7055.27 - 7054.3 7050.32 - 7050.3 7044.7 - 7044.3 7036.29 - 7035.7 7026.68 - 7023.0 7021.25 - 7019.7 7017.64 - 7012.1 7010.69 - 7009.2 Page 1 ~- ~ r"\ . , To: Clint Spence/Jerry Bixby Date: May 25, 2004 From: Nick Frazier, Pad Engineer Subject: MPF-83i Patch Request Est. Cost: $60 M lOR: 250 BOPD This procedure includes the following steps: Step Type Procedure 1 2 3 S E 0 PuIlIBP. Drift w/Patch Dummy (pre-patch) Run -30' 3-1/2" Eclipse Tbg Patch MIT IA ~'i ~~\e r~ ~,~~> Current Status: Max Deviation: Min. 10: Last TO tag: Last Downhole Ops: Latest H2S level: Water injection - 1600 BWPD @ 2500 psi 96 degrees @ 13683' MD 2.75" @ 8085' HES XN-Nipple (angle at nipple 682) 8/3/2000 IPROF 4/6/04 « 2 ppm This well is an injection well with tubing by IA communication. The purpose of this procedure is to patch a hole at 5333' MD confirmed by a video log (5/29/02) so this well can be returned to gas injection. If you have any questions or comments regarding this procedure, please call Nick Frazier at (W)564-4638, (H)346-2918, (Cell)830-5450. cc: w/a: Well File M. Townsend K. Carpenter Page 1 of 2 ~ ~ MPF-83i Tubing Patch ~ Patch Specs 3-1/2" Eclipse patch, 10= 1.745", 00= 2.8", Pressure rating burst & collapse=6000 psi Patch Depth Collar leak is at 5333' MD. Set patch @ 5318' MD -5348' MO Pre-Patch Fulibore/Slickline 1. Run dummy patch to - 6500' Eline Set Patch 2. AU EL. RIH and tie into X-Nipple @ 2191' MO. 3. Set patch from 5323' MO -5343' MO per manufacturer's recommendations. Post Patch MIT 5. MIT IA. 2 ..~- ~ Tree: Cameron 3 1/8", SM Wellhead: FMC 11" x 7-1/16" SM, Gen. Sa wi 6' x 3.S' FMC Tbg. Hnr. wi 3.S' eue threads top and btm 3' CIW H BPV profile 20" 54.5# ppf, K-55 ~ KOP @ 700 to 9,880' Max. hole angle = 95 deg. deg. 6,800' - 11,050' 40 - 80 deg. Hole angle thru' perfs = 90+ deg. U-Shaped sec. 11,000' -14,182' 9518",40 ppf, L-80 Btrc. I 4,837' ~ 7" 29 ppf, L-80, btc mod. casing ( drift id = 6.276", cap. = 0.0383 bpi ) 3.5" 9.3 ppf, L-80 nsct tubing. ( drift id = 2.992" , cap = 0.0087 bpi ) Perforation Summary Ref log: MWD log. 7/25/00 Size spf Interval (TVD) * See ::>rogram TCP intervals * 2-7/8" ,15.2 gram 34j uj, RDX charges 60 deg. phasing 490' md of shots DATE 07/30/00 REV. BY MDO MDO COMMENTS Cased hole Doyon 141 Perfs and Completions 4-ES 08/27/00 MPU F-83i ... r"\ Orig. DF Elev. = 28.5 (Doyon -141) Orig. GL Elev. = AT To Tbg. Spool = 0 9 5/8" Tam port collar~ HESX-Nipple2.813" id HES X-Nipple 2.813" id Baker 7"x3.5" SAB-3 perm pkr. f2:19fl 1 8,047' 1 18,059' 1 HES XN-Nipple 2.750" id 1 8,085' I Angle at nipple 68 deg. WLEG I 8,097' I 6' Baker tie back sleeve 7"x 5" Baker ZXP liner pkr. Baker "HMC" hyd. Linerhng. 7" float collar ~ 7" float shoe Angle through perfs 79 deg - 95 deg. U-Shaped. 110,338' I 110,348' I 4.5" 12.6 ppf, L-80, NSCT (drift ID = 3.958", cap. = 0.0152 bpf) 4.5" Landing Collar (PBTD) 4.5" float collar 4.5" float shoe 14.082' md 14,124' md 14,168' md MILNE POINT UNIT WELL No.: F-83i API: 50-029-22963-00 BP EXPLORATION (AK) 1 3 5 7 9 11 13 ~ 15 17 19 21 23 25 27 29 31 0 ....),. a a a I\.) a a a Q) a a a ~ a a 0 VJ a a a 0'1 a a a + t + + ~~>~ -I \J\J I m \J r" ~ ~ -'1J 11 \ ex) Jl .., ,.. ¿s 0 ~ vJ ..... MPU May increased monitoring information ./"'... ~, Subject: MPU May increased monitoring information From: "Sauve, Mark A" <marksauve@bp.com> Date: Thu, 03 Jun 2004 13:23:06 -0800 To: "AOGCC- Tom Maunder (E-mail)" <tom_maunder@admin.state.ak.us>, "AOGCC-Bob Fleckenstein (E-mail)" <bob - fleckenstein@admin.state.akus>, Jim Regg <jimJegg@admin.state.ak.us> CC: "MPU, Well Operations Supervisor" <welloperationssupervisor@bp.com>, "MPU, Wells Ops Coord" <MPUW ellsOpsCoord@bp.com> Gentlemen, Enclosed below is the May 2004 enhanced monitoring spreadsheet for MPU injector F-83i currently approved for water injection with a known tubing to IA leak as per AOGCC variance number 302-204 dated 7/9/02. The last combined tubing/IA MIT was performed 6/14/02 and the last tubing to IA leak rate test was performed 6/1/03. «040531 MPF-83i Annulus Monitoring.xls» We continue to have no evidence of any IA x OA communication. Please feel free to contact me if you have any questions. ---- - - - ---- - ---- - -------- - - - - -- ---------- E:nclost::d below ie: the May 2004 enhanced monitorinQ sprp.::J.dihoct fur MPU injector E-03i currently approved for gas injection with a kr~,",v.tn 0,\ prp~sure source as per AOGCC variance number 304..007 \ci~ted 1/10/04. Tne last E-03i tubing/IAlOA MIT was performed 12/1-8/03. <;<;040G31 MÆ-O3j Annulus Monitoring.xls» We continue to have no evidence of any tuDing x IA .-: IA x eV\ - - rmnumcation and the OA is maintaining prp.~suro unOOr' tile 'I !>UO psi threshold. Please feel free to contact me If yOu IIë:1vc. any questions. Mark Sauve Milne Point Artificial Lift Coordinator BP Exploration. Alaska 900 E. Benson Blvd Anchorage, AK 99519 Work Ph #: 907-5644660 Work Fax #: 907-564-4440 E-mail: sauvema@bp.com : C t t D . t. .040531 MPF-83i Annulus , on en - escnp Ion. M ' . 1 omtonng.x s 040531 MPF-83i Annulus Monitoring.xls 'c t t T I' t. n/ d I : on en - ype: app lca 10 vn ,ms-exce Content-Encoding: base64 " - - --- --- -- 040531 MPE-O3i Annulus Monitoring.xls Content-Description: MO405.31 ~PE-IO3i Annulus omtonng.x s Iof2 6/8/2004 6:55 AM Permit to Drill 2000930 MD 14182 TVD DATA SUBMITTAL COMPLIANCE REPORT 3~3~2003 Well Name/No. MILNE PT UNIT KR F-83 6985 Completion Dat 8/20/2000 Operator BP EXPLORATION (ALASKA) INC Completion Statu WAGIN Current Status WAGIN APl No. 50-029-22963-00-00 REQUIRED INFORMATION Mud Log Nc) Sample Nc) Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Name Scale Interval Log Run Media No Start Stop (data taken from Logs Portion of Master Well Data Maint OH / Dataset CH Received Number Comments R ~ L MWD LIS 9900~-./ LIS Verification USIT MWD Formation Eval TVD GR/Res MD ROP/GPJRes 5 2/5 2/5 FINAL t.~J~i T FINAL FINAL 7250 8996 CH 235 14136 7250 8996 Case 235 14136 ~" FINAL 120 14182 CH FINAL 120 14182 CH 1/9/2001 2/22/2001 2/22/2001 9/8/2000 1/9/2001 10/13/2000 2/22/2001 2/21/2001 2/21/2001 Verification Listing 9900~/LIS Verification Digital Data LIS Verification Paper Copy BL(C) 7250-8996 235-14136 Digital Data 09756/'~7250-8996 09900 ~'35-14136 120-14182 BL, Sepia 120-14182 BL, Sepia Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? ~ Analysis R ~.c.~.ivc. d ? Daily History Received? ~ N Formation Tops ~/N Comments: Permit to Drill 2000930 MD 14182 TVD DATA SUBMITTAL COMPLIANCE REPORT 31312003 Well Name/No. MILNE PT UNIT KR F-83 Operator BP EXPLORATION (ALASKA) INC 6985 Completion Dat 8/20/2000 Completion Statu WAGIN Current Status WAGIN APl No. 50-029-22963-00-00 UIC Y Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Variance for ./ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Inject Water Change approved program _ Pull tubing _ Vadance _X Perforate _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_ RKB 39.0 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 196612 Stratigraphic __ Anchorage, AK 99519-6612 Service__X Milne Point Unit 4. Location of well at surface 8. Well number 3263' FNL, 2992' FEL, Sec. 06, T13N, R10E, UM (asp's 541570, 6035466) MPF-83 j At top of productive interval 9. Permit number / approval number 3067' FNL, 3992' FEL, SEC 01, T13N, R09E, UM (asp's 535421, 6033720) 200-093 At effective depth 10. APl number 3118' FNL, 1448' FEL, Sec. 02, T13N, R09E, UM (asp's 532675, 6035567) 50-029-22963-00 At total depth 11. Field / Pool 3067' FNL, 1533' FEL, Sec 02 T13N, R09E, UM (asp's 532590, 6035617) Milne Point Unit/Kuparuk River Sands 12. Present well condition summary Total depth: measured 14182 feet Plugs (measured) true vertical 6985 feet Effective depth: measured 14083 feet Junk (measured) true vertical 6994 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 260 sx Arcticset I (Approx 139' 139' Surface 4808' 9-5/8" 686 sx Arctic 3, 202 sx 4837' 4263' Class 'G' Intermediate 10519' 7" 361 sx Class 'G' 10545' 6940' Liner 3829' 4-1/2" 465 sx Class 'G' 10339'- 14168' 6886'- 6986' Perforation depth: measured Open Perfs 10801-830, 10890-911, 10935-955, 11075-095, 11123-144, 11160-165, 11208-225, 11265-285, 12180-200,12250-254, 12315-318, 12415-435, 12465-485, 12890-910, 13190-198, 13465-485, 13640-680, 13699-13720, 13755-13848, 13869-890 true vertical Open Perfs 6999-7003, 7013-7017, 7021-7024, 7044-7047, 7052-7054, 7056-7057, 7060-7062, 7065-7066, 7071-7071, 7069-7069, 7065-7065, 7059-7057, 7056-7054, 7050-7050, 7045-7044, 7036-7035, 7027-7023, 7021-7020, 7018-7012, 7011-7009 Tubing (size, grade, and measured depth 3-1/2", 9.3#, L-80 NSCT TBG @ 8059' MD. 3-1/2" Tubing Tail @ 8097'. Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker SAD-3 Perm Packer @ 8059' MD. 3-1/2" HES 'X' Nipple @ 2191' MD. .'~ ~ ,~ ~ 13. Attachments Description summary of proposal --X Detailed operatiOns program _ ~1~_~,. ~e_.t(~,~-_ V ~" 14. Estimated date for commencing operation 15. Status of well classification as: June 17, 2002 --, 16. If proposal was verbally approved Oil_ Gas_ S ded_1 2002 Name of approver Date approved Service WAG Well AJa~:~ 0ii & ~ 0011~. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Patricia M. I~1~t~6. Signed ~~'/X~', ~ Title: Milne Point Production Engineer Date June 11,2002 _ Patricia M. Hill Prepared by DeWayne R. Schnorr 564-5174 . FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness J App_~v~al_.no Location clearanceI Plug integrity__ .~OP Test__ __ Mechanical Integrity Test X, ,, · , I Subsequent form required 10- _ Approved by order of the uommission {3n,~,,,.,~ e.._~ ~_ ICommissroner ' Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE bp ( June 24, 2002 Tom Maunder Alaska Oil and Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: Milne Point Well MPF-83 Application for Sundry Approval BP Explorateion (Alaska) Inc. 900 East Benson Blvd PO Box 196612 Anchorage, AK 99519-6612 (907) 561-5111 Dear Mr. Maunder: Attached is Application for Sundry Approval for Milne Point injection well MPF-83. This re~est is for a varience approval to inject water only with known tubing by inner, annulus communicatiorlT. A summary proposal and wellbore schematic is attached. If you require any additional information or clarification, please contact Monte Townsend at 564-4602 or Patty Hill at 564-4346. Monte Townsend Sr. Petroleum Engineer Attachments: Summary Proposal 'Application for Sundry Approval Wellbore Schematic CC: MPU Well Operations Supervisor MPU Wells Operations Coordinator Jim Welch Patty Hill Madelyn Millholland MPF-83 Well File Water Injection Well MPF-83 Summary Proposal 6/24/02 Problem: MWAG injection well with slow tubing by inner annulus communication Well History and Status Milne Point water injection well MPF-83 is a U-shaped Kuparuk WAG injector completed in the A 1, A2, and A3 sands with 19 sets of perfs in the toe and two sections of the heel. It was drilled as a high angle well in 2000 to support production wells F-80 and F-81 in HU 301. From the time it began injecting, inner annulus pressure was noted to be increasing during routine daily monitoring The well was kept on water-only injection while leak detection efforts took place. Recent events: 4/22/01 · 8/01- 12/01 the leak · 12/01- 1/02 · 1/14/02 · 5/28/02 Passed state-witnessed MIT / Leak detection efforts couldn't successfully identify the location of Attempt leak hunt with MI; unsuccessful / Well was shut in until the leak could be identified A small collar leak was found on a video log at 5333' leaking at about 10 - 15 psi/hr This sundry request is to allow for approval of a variance for water injection. The following supports the request: · Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. · The successful combined tubing and casing pressure test with the tubing plug installed indicates competent production casing. · An annual IA leak rate test will be conducted to monitor the leak severity./~ · A combined tubing and casing pressure test against a tubing plug will be conducted every 4 years to confirm production casing integrity. Proposed Action Plan 1. Allow well to continue water-only injection. 2. Record wellhead pressure, annuli pressures, and injection rates daily. 3. Perform an annual IA leak rate test. 4. Perform combination MIT Tubing and IA against a tailpipe plug every 4 years. 5. Submit a monthly report of daily pressures and injection rates. 6. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. Tree: Cameron3 1/8", 5M MPU= ~,~,~=~"'~'~'~i Orig. DF Elev. = 28.5 (Doyon-141) Wellhead: FMC 11" x 7-1/16' 5M, Orig. GL Elev. = Gen. 58 w/6' x 3.5' FMC Tbg. Hnr. ~ '~ RT To Tbg. Spool = w/3.5' cue threads top and btm. 3' ClW H BPV profile ~ ~ 20" 54.5# ppf, K-55 ~ ) 9 5/8" Tam port collarI 1007' I KOP @ 700 to 9,880' Max. hole angle = 95 deg. I RES X-Nipple 2.813" id deg. 6,800' - 11,050' 40 - 80 deg. ~i i~ii ! iHole angle thru' perfs = 90+ deg. 'i;!i ii 9 5/8", 40 ppi, L-80 Btrc. 7" 29 ppf, L-80, btc mod. casing ( drift id = 6.276", cap. = 0.0383 bpf ) ( drift id = 2.992", cap = 0.0087 bpf ) I I HES X-Nipple 2.813" id I 8,047'1 I ~ i~ Baker7"x3.5"SAB-3permpkr. I HES XN-Nipple 2.750" id ~ ~ 6' Baker tie back sleeveI ' 110'338' I · ~; 7"x 5" BakerZXPLinerpkr. 110,348,1 '~' Baker"HMC' hyd. Liner hng. ,al k. 7" fl°at c°llar [ 10'462'I 7" float shoe 10,545' Perforation Summary Ref log: MWD log. 7/25/00 ~ Angle through perfs 79 deg - 95 deg. i U-Shaped. Size spf Interval ]'VD) · See ~rogram TCP irltervals* -i 4.5" 12.6 ppf, L-80, NSCT 2-7/8", 15.2 gram 34j uj, RDX charges ! ( drift ID = 3.958", cap. = 0.0152 bpf ) 60 deg. phasing 490' md of shots 4.5" Landing Collar (PBTD) 14,082' md ~~k~J~ 4.5" float collar 14,124' md 4.5" float shoe 14,168' md DATE REV, BY COMMENTS MILNE POINT UNIT 07/30/00 MDO Cased hole Doyon 141 WELL No.: F-83i 08/27/00 MDO Perfs and Completions 4-ES APl: 50-029-22963-00 BP EXPLORATION IAK! STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Convert - Water to WAG Iniector Pu, tubing _ Stimulate _ Plugging _ Perforate _ Alter casing _ Repair well _ Other_X Convert to WAG Inj 2. Name of Operator BP Exploration (Alaska), Inc. 5. Type of Well: Development __ Explorato~___ Stratigraphic__ Service_X 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface -'- 3263' FNL, 2992' FEL, Sec. 06, T13N, R10E, UM (asp's 541570, 6035466) At top of productive interval 3067' FNL, 3992' FEL, Sec. 01, T13N, R09E, UM (asp's 535421, 6033720) At effective depth 3118' FNL, 1448' FEL, Sec. 02, T13N, R09E, UM (asp's 532675, 6035567) At total depth 3067' FNL, 1533' FEL, Sec. 0~09E, UM (asp's 532590, 6035617) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 4808' Production 10519' Liner 3829' · 14182 feet Plugs (measured) 6985 feet 6. Datum elevation (DF or KB feet) RKB 39 feet 7. Unit or Property name Milne Point Unit 8. Well number MPF-83 9. Permitnumber/approvalnumber 200-0930 10. APInumber 50-029-22963-00 11. Field / Pool Miline Point Unit / Kuparuk River Sands RECEIVED JAN i 5 2002 14083 feet Junk (measured) 6994 feet Alaska 0il & Gas Coos. Commission Anchorage Size Cemented Measured Depth True Vertical Depth 20" 260 sx Arctic Set (Approx 139' 139' 9-5/8" 686 sx Arctic 3, 202 sx Class 'G' 4837' 4263' 7" 361 sx Class 'G' 10545' 6940' 4-1/2" 465 sx Class 'G' 10339'- 14168' 6886'- 6986' Perforation depth: Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) measured Open Perfs 10801-830, 10890-911, 10935-955, 11075-095, 11123-144, 11160-165, 11208-225, 11265-285, 12180-200, 12250-254, 12315-318, 12415-435, 12465-485, 12890-910, 13190-198, 13465-485, 13640-680, 13699-13720, 13755-13848, 13869-890 true vertical Open Perfs 6999-7003, 7013-017, 7021-7024, 7044-047,7052-054, 7056-057, 7060-062, 7065-066, 7071-071, 7069-069, 7065-065,7059-057, 7056-054, 7050-050, 7045-044, 7036-035, 7027-023, 7021-020, 7018-012, 7011-009 3-1/2", 9.3#, L-80 NSCT TBG @ 8059' MD. 3-1/2" Tubing Tail @ 8097'. 7" x 3-1/2" Baker SAB-3 Perm Packer @ 8059'. 3-1/2" HES 'X' Nipple @ 2191'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) '\ Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Productio r Iniection Data OiI-Bbl Gas-Mcf //Water-Bbl Prior to well operation 11/10/2001 Water Injection // 3358 ( Subsequent to operation 01/07/2002 Gas Injection 1000 Casing Pressure Tubing Pressure 2900 4000 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service WAG Iniection Well 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Technical Assistant , DeWayne R. Schnorr ~,.,, Form 10-404 Rev 06/15/88 · ORIGINAL Date January 07, 2002 Prepared b~/DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE~' MPF-83 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/30/2001 CONVERTED WELL FROM WATER TO WAG INJECTION. EVENT SUMMARY 1 2/30/01 CONVERTED WELL FROM WATER INJECTION ONLY TO WAG INJECTION. THIS IS THE FIRST TIME THAT GAS WAS INJECTED INTO THIS WELL. Page 1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7~ Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPF-83, AK-MM-00092 February 02, 2001 MPF-83: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22963-00 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22963-00 1 Blueline~'~ 1 Rolled Sepia/ 1 Blueline ~ 1 Rolled Sepia } 5" M~D Neutron & Density Logs: "l'Blueline ~ 50-029~22963-00 1 Rolled Sepia 2"x 5'TVD' Neutron & Density LOgs: 1 Blueline / ~ 50-029-22963-00 1 Rolled Sepias// PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 ArCtic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc: Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Signe ~ r~ '~ To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 October 31, 2000 MWD Formation Evaluation Logs MPF-83, AK-MM-00092 1 LDWG formatted Disc with verification listing. AP1//: 50-029-22963-00 PLEASE ACKNOWLEDGE RECEIFr BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date' Signed: GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: 5herrle NO. 597 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage~ AK 99501 Field: Milne Point (Cased Hole) 10/11/00 ~Ioo. ~o x~_ Well Job # Log Description Date BL Sepia CD MPI-09 ~J~ ~ '~ ~- 20408 USlT (PDC) 000812 1 MPF-83 ~.- ~_ ~-~ ~(~ 20409 USlT (PDC) , 000817 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: Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATrN: Sherrie Received ~ , -~STATE OF ALASKA oo.s,.v^.,o,_ ....oo 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. 200-093 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22963-00 4. Location of well at surface ': '..'.: ""':c :'.:' i '[.OCA ~! 9. Unit or Lease Name :. ,- 2016' NSL, 2993' WEL, SEC. 06, T13N, R10E, UM-~;?"'='"~-'-~'-- _ I VEItlREO Milne Point Unit At top of productive interval 302' NSL' 3992' WEL' SEC' 01' T13N' R09E' UM i '~¥?'!~"i:~.~,~:;~! At total depth"""" ~~9,.~.~, ..... :...:..i ) 10. Well Number ,. 2211' NSL, 1533' WEL, SEC. 02, T13N, R09E, UM ~:~:' 2: ~ MPF-83i 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Sedal No. Milne Point Unit / Kuparuk River Sands KBE = 38.85' ADL 388235 ,2. Date SpuddedT/5/2000 I ' 3' Date T'D' Reached 114' Date C°mp'~usp'~'~r Aband' 115' Water depth' "°fish°re 116' N°' °f C°mpleti°ns7124,2000 8/3~/2000"'"' .N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey1 20. Depth where SSSV set1 21. Thickness of Permafrost 14182 6985 FT[ 14083 6994 FT[ [] Yes [] No[ (Nipple) 2192' MD[ 1800' (Approx.) 22. Type Electric or Other Logs Run DIR, GR, ESS, RES, PWD, ABI 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SiZE CEMENTING RECORD AMOUNT PULLED 20" 54.5# K-55 Surface 110' 26" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 29' 4837' 12-1/4" 686 sx Arcticset 3,202 sx Class 'G' , 7" 26# L-80 26' 10545' 8-1/2" 361 sx Class 'G' 4-1/2" 12.6# L-80 10339' 14168' 6-1/8" 465 sx Class 'G' 24. Perforations open to. Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Please See Attached 3-1/2", 9.3#, L-80 8097' 8059' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 80 Bbls of Diesel , Date First Production Method 0f Operation (Flowing, gas lift, etc.) I~,,~ I I ~/-~ L ~ i [~\t /i~ , September 7, 2000 Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS'MCF WATER-BBL CHOKE SIZE ] GAS-OIL RATIO TEST PERIOD I I~low Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY'API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top of HRZ 8416' 6553' Base of H RZ 8679' 6640' Kuparuk D 9769' 6810' Kuparuk B 10530' 6936' Kuparuk A 10765' 6990' Kuparuk A3 10789' 6995' Kuparuk A2 10887' 7013' Kuparuk A1 11049' 7040' 31 "' List of Attachments: Summary Of Daily Dr:ilJing R~P'orts, Surveys,'Perforati0n Summary ............. 32. I 'hereby certif~ ihat the foregoing is true and correct 'to the 'best of my kr~owledge ......................... Signed TerrieHubble ~'~~~ ~ Title TechnicalAssistant Date ,,, ,,,,,, ,, MPF-83i 200-093 Prepared By Name/Numbec Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Inje~i~r~Sl~ut-~n, ~O~h~x~in. ITEM 28: If no cores taken, indicate 'none'. OCT ,.~ ¢, ,~ '~,: ~; ,,~ Form 10-407 Rev. 07-01-80 . .. Well Name: MPF-83i, APl #50-029-22963-00, 200-093 24. . ........... (10-407) Affachment- PeHorations open to Production 1081 O' - 10830' 6999' - 7003 10890'- 10910' 7013'- 7017' 10935'-10955 7021'-7025' 11075'-11095 7044'-7047' . 11125'-11145' 7052'-7055' 11160'-11180' 7056'-7058' 11205'-11225' 7060'-7062' 11265'-11285' 7065'-7066' 12180'- 12200' 7071'- 7071' ....... 12250'-12270' 7069'-7068' ........................................ 12315'-12335 7066'-7064' 12415'-12435' 7059'-7057' 12465'-12485' 7055'-7054' 12890'-12910' 7050'-7050' . ..... 13190'-13210' 7045'-7044' 13465'-13485' 7036'-7036' ............................................. ....... 13640'-13680' 7027'-7023' 13700'-13720' 7021'-7020' 13755'-13890' 7018'- 7009' Legal Name: MPF-83 Common Name: MPF-83 ::: T~ : : ~:;:~ : : :' 7/9/2000 FIT (fi) (ft) (PPg) (psi) (psi) (PPg) 7/10/2000 FIT 4,838.0 (ft) 4,264.0 (ft) 8.70 (ppg) 1,100 (psi) 3,027 (psi) 13.67 (ppg) 7/18/2000 FIT 10,545.0 (ft) 6,940.0 (ft) 11.50 (ppg) 900 (psi) 5,046 (psi) 14.00 (ppg) 7/26/2000 FIT (ft) (ft) (ppg) (psi) (psi) 14.00 (ppg) Printed: 8~30~2000 2:28:28 PM O:perations summa :Repo Legal Well Name: MPF-83 Common Well Name: MPF-83 Spud Date: 7/5/2000 Event Name: ORIG DRILLING Start: 7/5/2000 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: : Date : Fr°~:T° HOu~S:ACtiVi~:~d~ Phase : : oescriPiionofope~atibns ] : 7/5/2000 i00:00 - 04:30 ~ 4.50 i I PRE PJSM w~th all personnel. Disconnect all lines and move complexes off ~ ~ MPF-84. Lay herculite and mats for sub. Spot sub over MPF-83. 04:30 - 08:00 3.50 PRE Nipple up diverter system and hook up all hydraulic, air, water and electrical lines. Accept rig at 0430 hrs. 08:00 - 08:30 0.50 PRE Service top drive. 08:30 - 14:00 5.50 PRE M/U 141 jts 5" drill pipe and 20 jts hwdp and stand back in derrick: 14:00 - 15:00 1.00 PRE Rig up Schlumberger to run gyro 15:00 - 15:30 0.50 PRE Function test diverter and test accumulator. John Spaulding with AOGCC waived witnessing test. 15:30 - 18:00 2.50 DRILL SURF i M/U bit and motor. Tagged ice at 45'. Drill and clean out ice in conductor 45'-110'. 18:00 - 19:30 1.50 DRILL SURF Spud and dril 110' to 214'. art- 1.5 hrs. Stand back hwdp and jars. 19:30 - 21:00 1.50 DRILL SURF Finish picking up bha #1. M/U MVVD tools and orient. P/U flex collars, stab, and UBHO sub and orient. Take survey with Schlumberger. 21:00 - 00:00 3.00 RIGD SURF Drll 214'-445'. Art- 3.0 hrs. 00:00 - RIGD SURF ............................. 0600 hrs Update ..................... 0000-0600. Continue drilling and surveying with gyro. 7/6/2000 00:00 - 00:00 24.00 DRILL SURF Drill and slide per directional plan from 445'-2298'(1853')'. Art-10.4 hrs. Ast-5.6 hrs. 00:00 - RIGD SURF ........................ 0600 hrs update ................................. 0000-0100 Cir hole clean 0100-0230 14 stand wiper trip to 1000'. No problems. 0230-0600 Drilling ahead. 7/7/2000 00:00 - 01:00 1.00 DRILL SURF Circulate hole clean. Pump dry job. 01:00 - 02:30 1.50 DRILL SURF 14 Stand wiper trip to 1000'. No problems. 02:30 - 03:00 0.50 DRILL SURF Service top drive. 03:00 - 14:00 11.00 DRILL SURF Drill 2298'-3505'. Art-6.6 hrs; Ast-2.0 hrs. 14:00 - 15:00 1.00 DRILL SURF Circulate hole clean. 15:00 - 16:30 1.50 DRILL SURF 20 stand wiper to 1600'. No problems. 16:30 - 00:00 7.50 DRILL SURF Drill 3505'-4272'. Art-4 hrs, Ast-l.5 hrs. (Total hrs on bit=34.5.) 00:00 - DRILL SURF ................................. 0600 hrs update ................................... 0000-0600 Drilling ahead looking for casing point per geologist. All depths are coming in per well plan. Top of Schrader Bluff 4467'/3952' Top of NF 4631'/4090' Top of OA 4672'/4129'. 7/8/2000 00:00 - 06:30 6.50 SURF Drill 4272'-4850'. TD per geologist..Art-4.5 hrs Ast-.5 hrs. Total hrs on bit=39.5 hrs(14.5 hrs sliding; 25 hrs rotating) 06:30 - 08:00 1.50 DRILL SURF Circulate hole clean. Monitor well. Pump dry job. 08:00 - 10:30 2.50 DRILL SURF Pooh 45 stands to hwdp. Checking up, down, rotating wt and torque every five stands. Collecting data for future wells. No hole problems on trip to hwdp.. 10:30 - 11:00 0.50 DRILL SURF Service top drive. 11:00 - 12:30 1.50 DRILL SURF Trip in hole. No problems. 12:30 - 15:00 2.50 DRILL SURF Circulate and condition(thin) mud for casing. Add 2% lubetex 15:00 - 15:30 0.50 DRILL SURF Drop ESS and pump dry job. 15:30 - 19:30 4.00 DRILL SURF Pooh collecting data for future wells. L/D bha. 19:30 - 20:00 0.50 DRILL SURF Clear rig floor. 20:00 - 21:30 1.50 CASE SURF Rig up casing tools. 21:30 - 22:00 0.50 CASE SURF Pre job safety meeting with all personnel. 22:00 - 00:00 2.00 CASE SURF Running 9-5/8" 40# L-80 casing. Recording PU and SO WTs every 5 its. Printed: 8/10/2000 11:27:41 AM Operations :.summa : Repo i, : : Legal Well Name: MPF-83 Common Well Name: MPF-83 Spud Date: 7/5/2000 Event Name: ORIG DRILLING Start: 7/5/2000 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: ~te: :.~;~6 H6urS:ACtiVi~ ~6~eI Phase;: DescriPtion °f0P~aii~s ; ; 7/8/2000 00:00 - i ~CASE i SURF I ..................... 0600 Hrs update ........................ 0000-0230 Finish running and landing 9-5/8" casing. 0230-0300 Lay down Frank's tool and make up cement head. , 0300-0500 Break circulation slow and increase rate to 10 bpm with 675 psi. No losses. Reciprocate casing 215 up/ 145 down. 0500-0600 PJSM. Test lines and pump cement job per well plan', 7/9/2000 00:00 - 02:30 2.50 CASE SURF Finish running 117 jts 9-5/8" 40# L-80 casing. No problems. Shoe at 4838'. 02:30 - 03:00 0.50 CASE SURF Lay down Frank's tool and make up Dowell cement head. 03:00 - 05:00 2.00 CASE SURF Break circulation slow and increase rate to 10 bpm with 675 psi and no ~ losses. Circulate three bottoms up. 05:00 - 09:30 i 4.50 CASE SURF : PJSM. Test lines 3500 psi. Pump 10 bbls chemical wash, 75 bbls ~weighted spacer. Mix and pump 780 sxs(610 bbls) Artic Set Lite @10.7 ppg. Tail with 250 sxs(52 bbls) "G" @ 15.8 ppg. Pump 10 bbls water and displace with rig pumps. Lost 15 bbls when cement turned corner but no losses after this. Mixed cement at 4-6 bpm with 500 psi. Displace at 5 bpm with 1000-1500 psi. 50 bbls good cement back to surface. Cement in place at 0930 hrs. Checks floats -ok. 09:30 - 10:30 1.00 CASE SURF PJSM. Rig down cement head and lay down landing jt. 10:30 - 12:30 2.00 DIVRTR SURF Nipple down 20" diverter system. 12:30 - 14:30 2.00 VVHSUR SURF PJSM. Nipple up casing head and drilling spool. 14:30- 18:30 4.00 BOPSUF SURF PJSM. Nipple up BOP'S 18:30 - 19:00 0.50 BOPSUF SURF Rig up to test bops. Set test plug. 19:00 - 21:30 2.50 CASE SURF Test BOP'S. Test witnessed by Jeff Jones with AOGCC. 21:30 - 22:00 0.50 CASE SURF Pull test plug and install wear ring. 22:00 - 00:00 2.00 DRILL INT1 Make up 8-1/2" BHA #2. Orient and test. 00:00 - DRILL INT1 ..................... 0600 hrs update ............................ 0000-0400 Trip in hole picking up 5" drill to float collar. 0400-0500 Test casing 3500 psi for 30 minutes-ok. 0500-0600 Drill float equipment 7/10/2000 00:00 - 04:00 4.00 DRILL INT1 Trip in hole picking up 5" drill pipe to float collar. 04:00 - 05:00 1.00 DRILL INT1 Test casing 3500 psi for 30 minutes-ok. 05:00 - 07:00 2.00 DRILL INT1 Drill float equipment and 30' new formation. 07:00 - 07:30 0.50 DRILL INT1 Circulate bottoms up. 07:30 - 08:00 0.50 DRILL INT1 Perform FIT with 8.7 ppg mud. Did not break down formation with 1100 psi. EMW=13.7 PPG. 08:00 - 00:00 16.00 DRILL INT1 Drill 4880'-5963. Art-13 hrs; Ast-1 hr. 00:00 - DRILL INT1 ........................... 0600 hr update ............................. 0000-0600 Continue drilling ahead 7/11/2000 00:00 - 13:00 13.00 DRILL INT1 Directional drill 5963 to 6799' - Art 6.4 hrs, ^st 4.5 hrs - Average Rop 76 E/hr - Drill with 550 gpm, 4-6 wob, 50 rpm - Start building angle at 47/100' @ 6100' 13:00 - 14:00 1.00 DRILL INT1 Pump high vis sweep - Circulate hole clean 14:00 - 15:00 1.00 DRILL INT1 Short trip 21 stands to 9 5/8" casing shoe at 4837' - No problem 15:00 - 15:30 0.50 DRILL INT1 Service Top drive and rig 15:30 - 16:00 0.50 DRILL INT1 Cut 67' drill line 16:00 - 18:00 2.00 DRILL INT1 TIH picking up 54 its 5" 'G' drill pipe ? 1650' - Continue TIH - Precautionary wash 90' to bottom - no fill 18:00 - 00:00 6.00 DRILL INT1 Continue drilling 6799 to 7102' @ 00:00 hrs - Art 2.3 hrs, Ast 2.6 hrs - Average Rop 62 fi/hr - Build angle 4?/100' 00:00 - DRILL INT1 ................................ 0600 hrs update ........................ 0000-0600 Drilling ahead. 7/12/2000 00:00 - 00:00 24.00 DRILL INT1 Directional drill 7102 to 8592' at 00:00 hrs - Art 12.1 hrs, Ast 8.25 hrs, Printed: 8/10/2000 11:27:41 AM ;Operations:; summa Repo Legal Well Name: MPF-83 Common Well Name: MPF-83 Spud Date: 7~5~2000 Event Name: ORIG DRILLING Start: 7/5/2000 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: Date:~From:To HOUrs: ACtiVi~ Cbde pha{e' Descriptibh ope,ations 7/12/2000 00:00 - 00:00 24.00 DRILL I lINT1 ~Average Rop 73 ft/hr - Log with GPJRes - Monitor ECD with PWD tool - I i build angle 66 to 707, Turn Azimuth 252 to 270? - PDC bit walking left, slide right side to maintain direction 00:00 - DRILL INT1 .................................. 0600 hrs update ................................... Drill to 8810' - Increase mud wt. 9.2 to 9.6 ppg - Circulate around high vis sweep - Short trip at 0600 hrs 7/13/2000 00:00 - 04:00 4.00 DRILL INT1 Drill and survey from 8592'-8810'. Art-2 hrs. Ast- 1 hr. Avg rop-73 fph. Increase mud wt 9.2 ppg to 9.6 ppg 04:00 - 05:00 1.00 DRILL INT1 Pump sweep and cir hole clean. 05:00 - 07:30 2.50 DRILL INT1 25 stand wiper trip to 6465'. Max pull 10 K over p/u wt. No problems. 07:30 - 00:00 16.50 DRILL INT1 Drill, Survey & log with GPJRes 8810 to 9840' @ 00:00 hrs - Art 8.6 hrs, Ast 4.5 hrs - Average Rop 78.6 ft/hr - Build angle 70 to 85? - 00:00 - : DRILL INT1 .................................. 0600 update ............................................. i Continue drilling ahead to ? 10,100' at 0600 hrs - no probems 7/14/2000 00:00 - 21:00 21.00 DRILL INT1 Directional drill 9840 to 7" casing point at 10560' - Art 6.2 hrs, Ast 10.75 hrs, Average Rop 42.5 fi/hr - Drop angle 85 to 74?, Turn Azimuth 275 to 296? as per well plan - 21:00 - 22:30 1.50 DRILL INT1 Pump 40 bbls 11.5 ppg high vis sweep - Circ hole clean - Observe well - Pump slug 22:30 - 00:00 1.50 DRILL INT1 Pooh for wiper trip to shoe, Max drag 40K, - Take P/U, S/O, RFI' & Torq values every 5 stands - 20 stands out at 00:00 hrs 00:00 - DRILL INT1 ................................... 0600 update ............................................ Continue pooh for wiper trip to casing shoe at 4835' - total 63 stands - Drop multishot survey - TIH taking surveys every stand - Break circulation every 20 stands 7/15/2000 00:00 - 02:30 2.50 DRILL INT1 Finish wiper trip(63 stands) to casing shoe 4838'. No problems. 02:30 - 05:30 3.00 DRILL INT1 Drop ESS and trip in hole to 10,560' filling every 25 stands. No problems. 05:30 - 11:00 5.50 DRILL INT1 Pump hi-vis fibre sweep. Circulate and condition mud in preparation to run 7"casing. Reduce the yield point and thin the mud with Desco. Circulate hole clean by monitoring ECD with PWD tool. Monitor well-static. Pump dry job. 11:00 - 17:30 6.50 DRILL INT1 Pooh stand back 5" drill pipe, record P/U & S/O wt. every 5 stands - L/D BHA - no problem pooh 17:30 - 19:00 1.50 CASE INT1 Pull wear bushing - Install test plug - Change top rams to 7" - Test door seal to 1000 psi for 5 minutes - ok 19:00 - 20:30 1.50 CASE INT1 Rig up Doyon Drilling 350 ton casing tools 20:30 - 21:00 0.50 CASE INT1 Pre-Job safety meeting with drill crew on running 7" production casing 21:00 - 00:00 3.00 CASE INT1 Run 7" 26~ L-80 Btc-Mod Casing - 100 its ? 3800' in hole at 00:00 hrs - Torque 8,000 ft/# - Record p/u, s/o wt every 10 its 00:00 - CASE INT1 ................................ 0600 update .......................................... Continue running 7" casing - Circulate full circulation at 9 5/8" shoe - Continue RIH with 7" casing at 0600 hrs 7/16/2000 00:00 - 01:00 1.00 CASE INT1 Continue running 7" casing to 9-5/8" shoe. Recording pu and slack off wts every 10 its. 01:00 - 02:00 1.00 CASE INT1 Circulate casing volume at 7 bprn with 800 psi. No losses. 02:00 - 06:00 4.00 CASE INT1 Finish running 264 its 7" 26# L-80 BTC Mod casing. Land on Mandrell hanger. Casing shoe at 10,545'. 06:00 - 06:30 0.50 CASE INT1 Lay down Frank's fill up tool and rig up cement head. 06:30 - 09:00 2.50 CASE INT1 Break circulation slow and bring rate up to 7 bpm with 800 psi. no losses. Reciprocate casing. 250 K up; 150 K down. Circulated 3 bottoms up-no loses. 09:00 - 11:00 2.00 CASE INT1 PJSM.Test lines 3500 psi. Pump 10 bbls water and 50 bbls weighted Printed: 8/10/2000 11:27:41 AM Legal Well Name: MPF-83 Common Well Name: MPF-83 Spud Date: 7/5/2000 Event Name: ORIG DRILLING Start: 7~5~2000 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: ' D~te Fr°m Ac{iVi~ ~bd~l pha§e ] of OPerations : 7/16/2000 09:00 - 11:00 2.00 CASE ] INT1 spacer @10.8 ppg. Mix and pump 75 bbls, 363 sx class"G" at 15.8 I ppg, yield 1.16 cf/sx. Drop plug and pump 10 bbls water. Displace with rig pumps at 5-7 bpm with 500 psi. Reciprocate casing entire job. Bump plug 3000 psi. Floats held. ClP @ 1100 hrs. 11:00 - 12:00 1.00 CASE INT1 Lay down cement head and lay down landing jt. 12:00 - 13:00 1.00 WHSUR INT1 Nipple down & set back 13 5/8" 5000~ Bop stack 13:00 - 14:30 1.50 WHSUR INT1 Nipple down & remove 11" 5000# drilling spool - Install FMC mandrell hanger pack-off - Nipple up FMC 11" 5000 x 7 1/16 5000~ gen 5A Tubing head - Test pack-off to 5000 psi for 15 minutes - ok 14:30 - 17:00 2.50 WHSUR INT1 Nipple up 7 1/16 x 13 5/8 5000 DSA and 13 5/8" 5000 Bop stack - Install 3?" rams in bottom, install 3? x 6" varible rams in top 17:00 - 00:00 7.00 DRILL INT1 Lay down ? 10,600' of 5" drill pipe out of derrick in mouse hole 00:00 - DRILL INT1 ................................... 0600 update .......................................... ;Finish laying down drill pipe - Load pipe shed with 3?" 13.30 S-135 drill pipe and strap - Change Saver sub on top drive to 3? - Change Air slips & Iron roughneck to 3?" - Install wear bushing, Install flow line 7/17/2000 00:00 - 02:00 2.00 DRILL INT1 Finish laying down 5" drill pipe out of derrick in mouse hole 02:00 - 02:30 0.50 DRILL INT1 Install wear busing - Install flow line ~02:30 - 07:30 5.00 DRILL INT1 Load pipe shed with 3?" 13.30# S-135 drill pipe & strap - Change Top i Drive saver sub and guide to 3? - Change Iron Roughneck and Air slips 07 30 to 3?" · 15:30 8.00 DRILL INT1 Make up 3?" dp mule shoe & Float sub - TIH picking up 330jts 3?" 13.30# S-135 drill pipe 15:30 - 16:30 1.00' DRILL INT1 Slip and cut 101' drill line - Service top drive 16:30 - 18:00 1.50 DRILL INT1 Tag float collar @ 10467 dpm' - Circulate bottoms up 336 gpm, 3160 ~si - P/u wt. 160, s/o wt. 92k 18:00 - 21:00 3.00 DRILL INT1 Drop 1.9375" rabbit - Pooh stand back 110 stand drill pipe 21:00 - 00:00 3.00 DRILL INT1 TIH - pick up 129 jts 3? 13.30# S-135 ? 4106' 00:00- DRILL INT1 ...................................... 0600 hrs update ................................... Circ at 4106' 440 gpm 2300 psi - rotate & reciprocate pipe to clean out debris - drop rabbit, pooh stand back 43 stands, 153 stands in derrick - Pull wear bushing, Install test plug - Test Bop to 250 & 5000 psi 7/18/2000 00:00 - 01:00 1.00 DRILL INT1 Circulate, Rotate & Reciprocate pipe at ? 4106' to clean debris form inside drill pipe 01:00 - 02:00 1.00 DRILL INT1 Drop 1.9375" rabbit, Pooh stand back drill pipe - Total 153 stands in derrick ~ 02:00 - 06:00 4.00 DRILL INT1 Pull wear bushing - Install test plug & rig up lines - Test all rams, lines & valve to 250 & 5000 psi - Test annular to 250 / 3000 psi - Test top drive IBOP, Manual and floor valve to 250 / 5000 psi - test with water for 3 minutes each test - all ok - no failures 06:00 - 06:30 0.50 DRILL INT1 Rig down lines & install wear bushing 06:30 - 09:30 3.00 DRILL LNR1 Pre-Job safety meeting - Pick up Sperry 4? Motor w/1.157 BH & ABI - Pick up Sperry GR / Res / MWD / PWD - Surface test MWD - ok 09:30 - 13:00 3.50 DRILL LNR1 Trip in with 3?" drill pipe from derrick - fill pipe every 30 stands - Tag float collar at 10,465' 13:00 - 14:00 1.00 DRILL LNR1 Test 7" casing to 3500 psi with 9.7 ppg in hole for 30 minutes on chart - ok I . 14:00 - 16:00 2.00 DRILL LNR1 !Drdl float collar, Cement, Shoe and clean out 15' rat hole to 10,560' 250 gpm, 3500 ps, 50 rpm, 10,000 ft/# torque 16:00 - 19:00 3.00 DRILL LNR1 Displace to 11.5 ppg mud - Circulate and condition mud 19:00 - 20:30 1.50 DRILL LNR1 Drill 10,560 to 10,590 - Art 0 hrs, Ast 1.5 hrs - 30' new formation for FIT 20:30 - 21:30 1.00 DRILL LNR1 Circulate hole clean for FIT - Balance mud wt. @ 11.5 ppg 21:30 - 22:00 0.50 DRILL LNR1 Test formation to 900 psi at 6940 TVD with 11:5 ppg mud in hole EMW Printed: 8/10/2000 11:27:41 AM operationssumma Repo ::, Legal Well Name: MPF-83 Common Well Name: MPF-83 Spud Date: 7/5/2000 Event Name: ORIG DRILLING Start: 7/5/2000 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: D~te F~!T° ~S Acti~i~I~de1 ~ha~ I Des¢~i~ii~n oral,rations 7/18/2000 21:30 - 22:00 0.50 DRILL LNR1 14.0 ppg - no leak off - 122:00 - 00:00 2.00[ DRILL ! i LNR1 Directional drill 10,590 to 10,640' at 00:00 hrs - Art .25 hrs, Ast 1.5 hrs 00:00- DRILL ~LNR1 ................................ 0600 hrs update ....................................... I ' Directional drill as per directional plan and on site Geologist 10,640 to 10,959 at 0600 hrs - average rop 75 fi/hr rotating, 40-50 fi/hr sliding 7/19/2000 00:00 - 20:30 20.50 DRILL LNR1 Directional drill 10,640 to 11,470' - Art 8.7 hrs, Ast 5.0, Average Rop 60.5 ft/hr - Maintain mud wt. 11.5 ppg - Add Lubricants to maintain torque < 10,000 fi/# - Build angle to 89? - Turn Azimuth to 305? 20:30 - 21:30 1.00 DRILL LNR1 Pump high vis sweep around - Monitor well - ok 21:30 - 23:00 1.50 DRILL LNR1 Pooh to 7" shoe for wiper trip - Tight hole 11,060 to 11,020' 50k drag - Tight 10,815 - Back ream 10,815 to shoe at 10,545' - GR / Res log i tight spot through shale section - Sands ok 23:00 - 23:30 0.50 DRILL i LNR1 Service Top Drive 23:30 - 00:00 0.50 DRILL LNR1 TIH from Casing shoe - Tight at 11,020 to 11,060' - work through tight spot, did not wash or rotate 00:00 - DRILL LNR1 ................................... 0600 hrs Update .................................... Finish TIH precautionary wash 60' to bottom - Directional drill ahead 11,470 to 11,839' 7/20/2000 00:00 - 18:30 18.50 DRILL LNR1 Directional drill horizontal section 11,470 to 12,431 - Art 11.5 hrs, Ast 4.0 hrs, Average Rop 62 fi/hr - Maintain mud wt. 11.5 ppg - 238 gpm, 4100 psi on bottom 18:30 - 19:30 1.00 DRILL LNR1 Circulate around high vis sweep -Reciprocate & Rotate @ 95 rpm, 238 gpm 19:30 - 21:00 1.50 DRILL LNR1 Pooh for wiper trip - Tight at 11,940', 50k drag - Back ream 11,995 to 11,693 - continue pooh to 7" shoe w/no problem 21:00 - 21:30 0.50; DRILL LNR1 Service Top Drive 21:30 - 22:00 0.50 DRILL LNR1 TIH work through tight spot 11,757 to 11,917' - 40k drag 22:00 - 00:00 2.00 DRILL LNR1 Continue drill horizontal section 12,431 to 12,514 at 00:00 hrs - Art 1.0 hrs, Ast .5 hrs - Average Rop 55 fi/hr 00:00 - DRILL LNR1 ................................... 0600 hrs update ................................. Drill 12,514 to 12,747 at 0600 hrs 7/21/2000 00:00 - 11:00 11.00 DRILL LNR1 Directional drill 12,514 to 12,936' - Art 6.5 hrs, Ast 1.5 hrs, Average Rop 56 fi/hr - Pump 238 gpm, 4200 psi, 80 rpm, torque 7000 fi/# - ECD increasing 12.7 ppg up to 12.9 to 13.0 ppg 11:00 - 12:00 1.00 DRILL LNR1 Circulate around sweep to aid in hole cleaning, Rotate & Reciprocate pipe 95-100 rpm - Change pump liners and swabs in pump #2 to 5" 12:00 - 21:30 9.50 DRILL LNR1 Directional drill 12,936 to 13,385' -Art 5.5 hrs, Ast 1.5 hrs, Average Rop 64 ft/hr - 235 gpm, 4300 psi, 80 rpm, torque 8,000 fi/# 21:30 - 23:00 1.50 DRILL LNR1 Circulate around high vis sweep, Rotate & Reciprocate pipe - Increase in solids at shaker with sweep returns 23:00 - 00:00 1.00 DRILL LNR1 Pump out of hole for wiper trip from 13,385' - did not rotate - Tight at 12,608' - Back ream 12,608 to 12,323' - continue pumping out of hole @ 00:00 hrs i00:00 - DRILL LNR1 ..................................... 0600 hrs Update ................................. Continue pump out of hole to 11,450' - 21 stand wiper trip - TIH work through tight hole without pumping 12,332 to 12,428 & 12,811 to 12,875 -Wash and ream 60' to bottom - drill ahead 13,385 to 13,533' at 0600 hrs - Pump sweep while drilling at 13,415' to aid hole cleaning 7/22/2000 00:00 - 07:00 7.00 DRILL LNR1 Directional drill 13,385 to 13,551-Art 3.75 hrs, Ast 0 hrs, Average Rop 44 fi/hr - Maintain mud wt. 11.5 ppg - 235 gpm 4300 psi 07:00 - 11:00 4.00 DRILL TDRV LNR1 :Top drive failure. Could not rotate. Trouble shoot same and evaluate. Capacitors and diodes were blown out from high voltage. Parts will have to be flown up from Houston. Pump sweep and circulate hole Printed: 8/10/2000 11:27:41 AM oPerations Summa Repo : Legal Well Name: MPF-83 Common Well Name: MPF-83 Spud Date: 7~5~2000 Event Name: ORIG DRILLING Start: 7~5~2000 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: 'iD~te ~°~~T°I H0Ur~ ACti~i~It ~esc~ipii°n °f:O~erati°ns 7/22/2000 :07:00 - 11:00 4.00! DRILL !TDRV LNR1 clean monitoring ECD's. 11:00 - 14:30 3.501 DRILL TDRV LNR1 Break out top drive and pull out of hole to the casing shoe monitoring : ' returns for swabbing. Only one spot at 10,700' that was tight and it pulled only 15-20 K over. Maximum pulling speed was 50 fpm. 14:30 - 15:00 0.50! DRILL TDRV LNR1 Monitor well at the shoe. Well static. Actually dropped a foot below flow line. 15:00 - 16:30 1.50: DRILL TDRV LNR1 Circulate bottoms up and pump dry job. 16:30 - 21:30 5.00 DRILL ~TDRV LNR1 Continue Pooh and ? 2 minutes per stand - Proper hole fill 21:30 - 23:00 1.50 DRILL i TDRV LNR1 Lay down jars, Down load LWD, Lay down MWD - Stand back motor TDRV and bit - bit ok, no wear 23:00 - 00:00 1.00 DRILL LNR1 Pull Wear Bushing, Install test plug, Rig up to test BOP 00:00 - DRILL LNR1 .................................... 0600 hrs Update ..................................... Finish testing BOP to 250 Iow and 5000 high with water for 3 minutes each test - Test annular to 250 Iow, 2500 psi high - all ok - Make up BHA - TIH at 0600 hrs 7/23/2000 00:00 - 03:00 3.00 DRILL LNR1 Continue test BOP: Test all lines, Valves, & Rams to 250 Iow & 5000 psi high, Test annular 250 / 2500 psi - Test floor valves, Top drive manual and IBOP to 250 / 5000 psi - all ok no failures 03:00 - 03:30 0.50 DRILL LNR1 Pull test plug - Install wear bushing - Varco tech replaced top drive electrical componants while testing bop - Check out top drive- ok 03:30 - 06:00 2.50 DRILL LNR1 Make up BHA: Pick up Sperry GR / Res / PWD / MWD - Make up same 4?" Sperry motor w / ABI & 1.157 BH - orient MWD - Surface test mwd - I ok Re-ran bit #3 Security 6.125" FM2643 06:00 - 12:30 6.50 DRILL LNR1 TIH with 3? drill pipe to 13,511' - Filled pipe every 25 stands, Tight hole at 12,336 to 12,357 - Tight at 12,713'-Wash and ream tight spot 12,713 to 12,938' 12:30 - 15:30 3.00 DRILL LNR1 Circulate and condition mud at 13,511- Pump high vis sweep, ECD 14.0 ppg when sweep cleared bit - Reduce pump rate 235 to 200 gpm - Continue circ bottom up, Rotating and reciprocating pipe - Loss ? 60 bbls of mud to formation before bottoms up - Bottoms up mud wt. 13.4 ppg with 150 vis from de-hydration - Full returns with 11.6 ppg mud at surface 15:30 - 16:00 0.50 DRILL LNR1 Wash 40' to bottom at 13,551' - no problem 16:00 - 00:00 8.00 DRILL LNR1 Directional drill 13,551 to 13,877' at 00:00 hrs - Art 5.0 hrs, Ast 2.0 hrs, Average Rop 46.5 ft/hr - Maintain wt. 11.5 ppg - 230 gpm 4300 psi - 100 rpm Torque 9000 ft/# 00:00 - DRILL LNR1 .................................... 0600 hrs Update ..................................... Directional drill 13,877 to 14,089 at 0600 hrs 7/24/2000 00:00 - 07:30 7.50 DRILL LNR1 Directional drill 13,877 to TD at 14,182' - Art 4.5 hrs, Ast 0 hrs, Average Rop 67 ft/hr - 227 gpm, 4300 psi 100 rpm 8000 ft/# ECD 13.4 ppg 07:30 - 13:00 5.50 DRILL LNR1 Circulate & Condition mud, Pump high vis sweep around, Pump I weighted sweep followed by high vis sweep - Circulate hole clean at 227 gpm 4100 psi - ECD 13.1 ppg 13:00 - 16:00 3.00 DRILL LNR1 Pooh slowly 40 ft/min to 11,600' - 28 stands - back ream tight hole @ 13,993, 13,769, 13,609,& 13,354 - Pulled 40K over- no other problems - proper hole fill 16:00 - 17:30 1.50 DRILL LNR1 TIH slowly - Work though tight spot at 14,100' 17:30 - 21:00 3.50 DRILL LNR1 Circulate and Condition mud - Circulate around high vis sweep - No mud cut on bottoms up - Blend in 270 bbls of new mud to active mud system and pump down hole - Shakers clean - Rotated and reciprocated at 100 rpm, 227 gpm 4100 psi 21:00 - 23:30 2.50 DRILL LNR1 Pooh at 40 ft/min to 7" caisng shoe - 38 stands - Monitor well - static - Printed: 8/10/2000 11:27:41 AM : : oPerations summa Repo : : :' I..e§al Well Name: MPF-83 Common Well Name: MPF-83 Spud Date: 71512000 Event Name: ORIG DRIll_lNG Start: 71512000 find: Contractor Name: DO¥ON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: Date~ From!To I R?rs ActiVi~t~O~ phaSe: ~: Des~ipti~h°fOPerati°ns i 7/24/2000 21:00 - 23:30 I 2.50 DRILL LNR1 No problem - Max drag 15K - 123:30 - 00:00 0.50 DRILL LNR1 Circulate bottoms at 7" caisng shoe 227 gpm 3300 psi 00:00 - DRILL _NR1 ................................. 0600 hrs Update ....................................... Finish circulating at 7" shoe, TIH with no problem max drag 20K !-Circulate around high vis sweep - no mud cut on bottoms up - 11.6 I ppg, 52 vis in - 11.6 ppg, 56 vis out - Pooh slowly at 40 ft/m for 4? liner 7/25/2000 00:00 - 00:30 0.50 DRILL LNR1 Finished circulating bottoms up at 7" casing shoe. Circulating 227 gpm at 3300 psi. 00:30 - 02:00 1.50 DRILL LNR1 Ran in hole slowly with no problems (Maximum drag 20K). Fill pipe every 10 stands. 02:00 - 04:00 2.00 DRILL LNR1 Broke circulation slowly. Pumped high visc sweep and circulated around. No mud cut with bottoms up. 11.6 ppg, 52 vis in - 11.6 ppg, 56 vis out. 04:00 - 06:30 2.50 DRILL LNR1 Pulled out of hole slowly to 7" casing shoe. 06:30 - 08:00 1.50 DRILL LNR1 Circulated bottoms up. Monitor well. Slug drill pipe and drop rabbit. 08:00 - 13:00 5.00 DRILL LNR1 Pulled out of hole with 3-1/2" drill pipe to BH^. Hole took good fill. . 13:00 - 14:30 1.50 DRILL LNR1 Download MWD. Laid down BHA and cleared floor. 14:30 - 15:00 0.50 CASE LNR1 Rigged up 4-1/2" elevators and tongs for liner job. Made up 4-1/2" NSCT crossover on floor valve. 15:00 - 15:30 0.50 CASE LNR1 Held PJSM and discussed liner running procedures and addressed hazards associated with liner job. 15:30 - 19:00 3.50 CASE LNR1 Picked up and ran in hole with 93 joints of 4-1/2" 12.6# L-80 N$CT casing. 19:00 - 19:30 0.50 CASE LNR1 Picked up Baker Liner hanger assembly with ZXP liner top packer. 19:30 - 20:00 0.50 CASE LNR1 Picked up one stand of drill pipe and circulated liner volume of 60 bbls. Pumped 3.5 bprn at 350 psi. 20:00 - 00:00 4.00 CASE LNR1 Ran in hole with 4-1/2" liner on 3-1/2" drill pipe. Filled drill pipe every 5 stands. Recorded up and down weights every 5 stands to shoe. 00:00 - CASE LNR1 ......................... 06:00 hrs Update ............................. 00:00 - 02:00 Made up Baker cementing manifold on stand and laid in skate. Circulated complete hole volume at 3.5 bprn at 1230 psi. 02:00 - 03:30 Ran in hole with 4-1/2" liner on 3-1/2" drill pipe to 14168'. Recorded down weights every 2 stands. Made up Baker cementing head and circulating hose. 03:30 - 06:00 Attempted to run in hole and pipe was stuck 14' off ! bottom at 14168' (shoe tract 85'). Broke circulation at 1.4 bpm at 870 psi and staged pump rate slowly up to 2.8 bpm at 1320 psi. No packing Printed: 8/10/2000 11:27:41 AM i. : :Operations summa Repo Legal Well Name: MPF-83 Common Well Name: MPF-83 Spud Date: 7/5/2000 Event Name: ORIG DRILLING Start: 7/5/2000 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: 7/25/2000 ]00:00 - ] CASE i I LNR1 off. Attempting to work pipe from 60K down to 225K up. 7/26/2000 00:00- 02:00 2.00' CASE I LNR1 ! Made up Baker cementing manifold on stand and laid in skate. ' Circulated complete hole volume at 3.5 bpm at 1230 psi. 02:00 - 03:30 1.50 CASE LNR1 Ran in hole with 4-1/2" liner on 3-1/2" drill pipe to 14168'. Recorded down weights every 2 stands. Made up Baker cementing head and circulating hose. 03:30 - 11:00 7.50 CASE LNR1 Attempted to run in hole and pipe was stuck 14' off bottom at 14168' (shoe tract 85'). Broke circulation at 1.4 bpm at 870 psi and staged pump rate slowly up to 2.8 bpm at 1320 psi. No packing off. Attempting to work pipe from 60K down to 225K up. Slowly worked pump rate to 3.5 bpm at 1590 psi. Hole stable. Increased pump rate to 4.0 bpm at 1970 psi. Finished circulating 3 bottoms up. Unable to work pipe. 11:00 - 12:00 1.00 CEMT LNR1 RU Dowell and held a PJSM. Pumped 5 bbls water, tested lines to 4500 psi, pumped 15 bbls water, 51.80 bbls B-45 spacer weighted to 12.1 ppg, 435 sxs (91.2 bbls) of Class G cement + .2% D046 Antifoam + .28% D065 Dispersant + .35% D167 Fluid Loss + .2% D800 retarder mixed in 15.8 ppg slurry with a yield of 1.16 cubic ft / sack. Shut down pump and washed lines. Kicked out dart with 10 bbls of water. 12:00 - 14:00 2.00 CEMT LNR1 Displaced cement with rig pump at 4 bpm at 2000 psi. Observed dart latch up with 96% efficieny of mud pump. Bumped plug at 1235 hrs with 3000 psi. Slacked off all string weight(40K on indicator) and pressured up to 4200 psi with rig pumps. Bled off pressure and checked floats-OK. Put 1000 psi on drill pipe and picked up to 200K. Liner hanger failed to release. Slacked off all of pipe weight and had Dowell pressure up to 4400 psion drill pipe. Bled pressure to 1000 psi and picked up to 175K. Hanger failed to release. Attempted to work 2000 ftlbs of left hand torque into string and was unable to release from hanger. Rigged down cementing manifold and laid out .top joint of drill pipe. Made up top drive and put 7000 ftlbs of left hand torque in pipe and hanger released. 14:00 - 19:30 5.50 CEMT LNR1 Pulled seals out of seal bore and released setting dogs. Set total string weight (60K) down on packer to set ZXP packer. Broke circulation and circulated out at 7 bpm @ 4000 psi. Circulated out water spacer, weighted spacer and contaminated cement. Circulated and treated contaiminated cement. 19:30 - 23:30 4.00 CEMT LNR1 Broke out and laid down Baker cementing head. Laid down 135 jts of 3-1/2" drill pipe from derrick and set back 63 stands. Laid out Baker setting tool. Baker setting tool did not shear. Appears to just have mechanically released. 23:30 - 00:00 0.50 CASE ~LNR1 Cut and slip drill line. 00:00 - CASE LNR1 ........................... 06:00 hrs update ........................... 00:00-00:30 Finished cutting and slipping drill line. Service top drive. Printed: 8/10/2000 11:27:41 AM operations summa Repo i Legal Well Name: MPF-83 Common Well Name: MPF-83 Spud Date: 7/5/2000 Event Name: ORIG DRILLING Start: 7~5~2000 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: I I 00:30-02:00 Cleaning mud tanks while waiting on polish mill, drill I collars and HWDP. I 02:00-02:30 Load and strap tools in pipe shed. I 02:30-06:00 Picked up Baker Polish Mill 'and 30 joints of HWDP from 3ipe shed. Running in hole with polish mill. 7/27/2000 00:00 - 00:30 0.50 CASE LNR1 Finished cutting and slipping drill line. Service top drive. 00:30 - 02:00 1.50 CASE LNR1 Cleaning mud tanks while waiting on polish mill, drill collars and HWDP. 02:00 - 02:30 0.50 CASE i LNR1 Load and strap tools in pipe shed. 02:30 - 06:30 4.00 CASE LNR1 Picked up Baker polish mill, 30 joints of HWDP and ran in hole with 3-1/2" drill pipe. Picked up 12 joints of 4-3/4" drill collars and one stand of 3-1/2" drill pipe at surface. Tagged top of liner at 10338'. Up weight 155K Slack off weight 108K. Stack full string weight on liner top hanger to assure ZXP packer is set. No surface indication of packer set. 06:30 - 07:00 0.50. CASE LNR1 Tested 4-1/2" liner lap to 2500 psi for 30 minutes. Recorded on chart. 07:00 - 07:30 0.50 CASE LNR1 Polished liner top with Baker polish mill. 80 RPM and 4K weight on mill. 07:30 - 11:00 3.50 CASE LNR1 Displace 11.6 ppg mud in hole with 8.3 ppg water. Reciprocated and rotated 80 rpm. Monitored well for 1 hr while cleaning trip tank. 11:00 - 15:30 4.50 CASE LNR1 Pulled out of hole standing 3-1/2" drill pipe in derrick and laid down drill collars and HWDP. 15:30 - 18:30 3.00 CASE LNR1 Held PJSM on picking up 2-7/8" work string. Picked up 3-3/4" mill and 123 its of 2-7/8" 7.9# WTS6 P110 PH6 tubing from the pipe shed. Changed out handling tools. 18:30 - 21:30 3.00 CASE LNR1 Ran in hole with clean out string on 3-1/2" drill pipe to 13850'. Sat down on cement stringers. NOTE: Freeze protected 9-5/8" x 7" annulus with 10 bbls methanol, 50 bbls water and 70 bbls of dead crude. Final pumping pressure 1775 psi at 2-1/2 bpm. Shut in pressure 900 psi. 21:30 - 23:30 2.00 CASE LNR1 Washed and reamed cement strings from 13850'-latch collar at 14076' DPM. 23:30 - 00:00 0.50 CASE LNR1 Displace mud in liner with 8.3 ppg water. Displacing at 6.5 bpm at 3300 I psi. 00:00 - CASE LNR1 ........................ 06:00 hrs update ...................... 00:00 -00:30 Finished diplacing entire well bore with fresh water. Circulated hole clean at 6.5 bpm at 3300 psi. 00:30-03:00 Pumped 25 bbl caustic pill, 25 bbls of dirt magnet and 35 Printed: 8/10/2000 11:27:41 AM , _ Operations Summa Repo : ~ Legal Well Name: MPF-83 Common Well Name: MPF-83 Spud Date: 7~5~2000 Event Name: ORIG DRILLING Start: 7~5~2000 End: Contractor Name: DOYON Rig Release: Group: RIG Rig Name: DOYON 141 Rig Number: ' Date i :Fr°~TO:] Hbui§ Acti~i~ ~6~et phase:,~ :: Descdpii°nof:OPerati6ns 7/27/2000 00:00 - CASE1 LNR1 bbl high vis sweep. Displaced well with 11.1 brine at 6 bpm and 3900 psi. ! 03:00-06:00 Pulling out of hole laying down drill pipe. I .,, Printed: 8/10/2000 11:27:41 AM Legal Well Name: MPF-83 Common Well Name: MPF-83 Spud Date: 7/5/2000 Event Name: COMPLETION Start: 8/15/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES 8/15/2000 00:00 - 05:00 5.00 MOB COMP MOVE ON & RIG UP. 05:00 - 06:00 1.00 WHSUR COMP ACCEPT RIG @ 0500 HRS 8-15-00. NIPPLE DOWN X-MAS TREE. 06:00 - 09:00 3.00 BOPSUF COMP N/U BOPE. 09:00 - 12:00 3.00 BOPSUF COMP PRESSURE TEST BOPE. LP 300 PSI, HP 3500 PSI, OK. 12:00 - 13:00 1.00 WHSUR COMP PULL TEST PLUG & INSTALL WEAR BUSHING. 13:00 - 16:00 3.00 CLEAN COMP LOAD PIPE SHED. TALLY TBG & BHA. 16:00 - 17:00 1.00 CLEAN COMP MAKE UP BHA ON 2 7/8" RENTAL STRING. 17:00 - 21:00 4.00 CLEAN COMP P/U 2 7/8" RENTAL STRING & RIH. 21:00 - 22:30 1.50 CLEAN COMP MAKE UP 7" CSG SCRAPER ASSY & X-OVER TO 3 1/2" TBG. 22:30 - 00:00 1.50 CLEAN COMP P/U 3 1/2" NSCT TBG & RIH. 8/16/2000 00:00 - 03:00 3.00 CLEAN COMP P/U 3 1/2" TBG & RIH. 03:00 - 04:00 1.00 CLEAN COMP PJU & REVERSE CIRCULATE. 3 BPM @ 2100PSI. 04:00 - 10:30 6.50 CLEAN COMP CON'T P/U & RIH W/3 1/2" TBG. TAG PBTD @14085'. 10:30 - 16:30 6.00 CLEAN COMP PJU & REVERSE CIRCULATE W/11.1 PPG BRINE TO CLEAN HOLE. (3BPM @ 2300 PSI) MIX & PUMP HI-VIS SWEEP. DISPLACE HOLE TO 9.9 PPG BRINE WATER. 16:30 - 21:00 4.50 CLEAN COMP POOH & STAND BACK 3 1/2" NSCT TBG. 21:00 - 21:30 0.50 CLEAN COMP LAY DOWN 7" CSG SCRAPER. R/U TO L/D 2 7/8" TBG. 21:30 - 00:00 2.50 CLEAN COMP POOH & L/D 2 7~8" TBG 8/17/2000 00:00 - 00:30 0.50 CLEAN COMP POOH & L/D 2 7~8" TBG & 4 1/2" SCRAPER. i00:30 - 02:00 1.50 CLEAN COMP HELD SAFETY MTG & RIGGED UP LOGGERS. 102:00 08:00 6.00 CLEAN COMP I RUN USIT LOG, LOGGED FROM 8996 TO 7250'. PJD LOGGERS. 08:00 - 00:00 16.00 CLEAN COMP WAIT ON TCP EQUIP & SERVICES. 8/18/2000 00:00 - 00:30 0.50 CLEAN COMP WAIT ON TCP EQUIP & SERVICE. 00:30 - 09:30 9.00 PERF COMP P/U & RIH W/TCP EQUIP & SPACE OUT W/2 1/16" TBG. 3100 GROSS FT. 09:30 - 10:00 0.50 PERF COMP MAKE X-OVER TO 3 1/2" TBG & RUN RA TAGGED COLLAR. 10:00 - 14:00 4.00 PERF COMP RUN IN HOLE ON 3 1/2" TBG. 14:00 - 19:00 5.00 PERF COMP R/U E-LINE EQUIP, RIH & CORRELATE TCP GUNS ON DEPTH. PJD E-LINE EQUIP. 19:00 - 20:00 1.00 PERF COMP HELD SAFETY MTG. TEST LINES, PRESSURE UP TBG & F. IR.~E TCP GUNS. 20:00 - 20:30 0.50 PERF COMP OBSERVE WELL. WELL FLOWING. SI & RECORD SITP. (18C~) 20:30 - 00:00 3.50 KILL COMP CIRCULATE WELL (NO GAS) SI & WAIT ON KILL WT FLUID. 8/19/2000 00:00 - 04:30 4.50 KILL COMP CIRCULATE WELL. OBSERVE PRESSURE. SIP 180 PSI. 04:30 - 08:00 3.50: KILL COMP DISPLACE WELL TO 10.7 PPG BRINE & KILL WELL. OBSERVE WELL, WELL DEAD. 08:00 - 12:30 4.50 CLEAN COMP POOH & L/D 75 JTS OF 3 1/2" TBG. STAND BACK REMAINING TBG IN DERRICK. 12:30 - 20:30 8.00 CLEAN COMP R/U, POOH & L/D TCP ASSY. 20:30 - 21:30 1.00 CLEAN COMP CLEAR FLOOR & PJD TCP HANDLING EQUIP, 21:30 - 00:00 2.50 CLEAN COMP PJU SLICKLINE EQUIP & RUN GAUGE RING & JUNK BASKET. 8/20/2000 00:00 - 04:30 4.50 CLEAN COMP MADE 2 RUNS W/GAUGE RING & JUNK BASKET TO 8500'. RECOVERED PIECE OF RUBBER & PIPE DOPE. PJD SLICKLINE EQUIP. 04:30 - 07:00 2.50 RUNCOk COMP PJU TO RUN COMPLETION EQUIP. M/U TP & PKR ASSYS. 07:00 - 11:30 4.50 RUNCOr~ COMP RIH w/3 1/2" TBG._ il 1:30 - 12:00 0.50 WHSUR COMP 'M/OTBG HANGER. LAND HANGER & TIGHTEN LOCK DOWNS. 12:00 - 12:30 0.50 WHSUR COMP SET TVVC & TEST TO 5000 PSI, OK. DRAIN STACK. 12:30 - 14:00 1.50 BOPSUR COMP N/D BOPE. 14:00 - 15:00 1.00 WHSUR COMP N/U TREE. TEST HANGER, SEALS & BODT TO 5000 PSI, OK. 15:00- 15:30 0.50 WHSUR iCOMP PULLTWC. 15:30 - 18:00 2.50 CLEAN i COMP N/U LINES & TEST TO 3500 PSI. REVERSE CIRCULATE 260 BBLS Printed: 8/30/2000 2:14:58 PM Legal Well Name: MPF-83 Common Well Name: MPF-83 Spud Date: 7~5~2000 Event Name: COMPLETION Start: 8/15/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES 8/20/2000 15:30 - 18:00 2.50 CLEAN COMP OF CORROSION INHIBITED BRINE (10.7 PPG) FOLLOWED BY 80 BBLS DIESEL DOWN WELLBORE. 18:00 - 19:00 1.00 DHEQP COMP DROP BAR, PRESSURE UP & SET PKR. 19:00 - 00:00 5.00 RUNCOI~ COMP TEST PKR & TBG. PERFORM & RECORD MIT. 8/21/2000 00:00 - 01:00 1.00 RUNCOI~ COMP FINISH RUNNING MIT. RECORD SAME. 01:00 - 03:00 2.00 WHSUR COMP PJD LINES. CLEAN TANKS & BLOW DOWN EQUIP. SET BPV & SECURE WELL. RELEASE RIG @ 0300 HRS 8-21-00. PJD & MOVE TO MPE-22. Printed: 8/30/2000 2:14:58 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount DATE: October 1, 2000 Commissioner SUBJECT: Mechanical Integrity Tests THRU: Blair Wondzell �� BPX P.I. Supervisor I'0 F & G Pads -foF-83i, G-01 i,03i,05i,07i FROM: John Crisp -J.0 , CMilne Point Unit Petroleum Inspector Milne Point Field NOW CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. l F;BL, T` a In'. S T.V.D. 6425 Tubing 2200 2200 2200 2200 Interval E.EWe. 1030 Type test P Test psi 1606 Casing 1 1900 2660 2660 2650 1 P/F P Notes: Well G-01i Type Inj. S T.V.D. 3690 Tubing 1200 1360 1340 1340 1 Interval 4 P.T.D. 1890290 Type test P Test psi 923 Casing 0 1725 1725 1725 1 P/F P Notes:• Well G-03i Type In`. S T.N.D. 3791 Tubing 1720 1 1720 1 1720 1 1720 Interval 4 P.T.D. 1890280 1 Type testj P I Test psi 1 948 1 Casing 1 950 1 2190 1 2180 1 2175 P/F IP Notes: Well G-05i I Type In'. I S I T.V.D. 3929 Tubing 1 900 1 900 1 900 1 900 11nterval 1 4 P.T.D. 1 1890460 1 Type test P Test psi 982 1 Casing 1 0 1 1775.1 1750 1 1730 1 P/F I P Notes: Weil G-07i Type Inj. S T.V.D. 3963 Tubing 2000 2000 2000 2000 Interval 4 P.T.D. 1890450 Ty a test P Test psi 991 1 Casing 620 1 2500 1 2480 1 2480 1 P/F P Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALT WATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details I witnessed 5 successful NUT's @ BP's MPU. .I.T.'s performed: 5 Number of Failures: 0 Total Time during tests: 2 hrs. Attachments: cc: MIT report form 5/12/00 L.G. MIT MPU F. & G Pads 10-01-00jc.xls 10/3/00 North Slope Alaska Alaska State Plane 4 Milne Point MPF MPF-83 Surveyed: 24 July, 2000 ORiGiNAL SURVEY REPORT 8 August, 2000 Your Ref: API-500292296300 Surface Coordinates: 6035466.40 N, 541569.03 E (70° 30' 28.1381" N, 149° 39' 35.6102" W) Kelly Bushing: 38.85ft above Mean Sea Level Survey Ref: svy9377 Sperry-Sun Drilling Services Survey Report for MPF-83 Your Ref: AP1-$00292296300 Surveyed: 24 July, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -38.85 0.00 100.00 0.200 357.100 61.15 100.00 200.00 0.400 47.600 161.15 200.00 300.00 0.400 63.300 261.15 300.00 400.00 0.300 18.000 361.14 399.99 500.00 0.500 66.000 461.14 499.99 600.00 0.500 55.700 561.14 599.99 700.00 1.900 189.300 661.12 699.97 757.00 3.370 202.560 718.06 756.91 852.58 4.370 204.610 813.42 852.27 944.81 6.610 218.670 905.23 944.08 1039.77 9.760 226.860 999.21 1038.06 1131.25 15.030 226.370 1088.53 1127.38 1224.24 19.850 227.500 1177.22 1216.07 1317.04 21.330 229.650 1264.09 1302.94 1410.40 20.320 229.500 1351.35 1390.20 1503.09 20.710 230.180 1438.16 1477.01 1593.03 25.100 229.840 1520.99 1559,84 1687.94 28.720 234.190 1605.61 1644.46 1780.10 28.670 236.130 1686.46 1725.31 1871.97 28.230 235.850 1767.23 1806.08 1964.76 30.560 237.770 1848.07 1886.92 2059.77 35.280 238.790 1927.80 1966.65 2151.71 36.530 235.850 2002.28 2041.13 2233.70 37.610 236.350 2067.70 2106.55 0.00 N 0.00 E 0.17 N 0.01 W 0.58 N 0.24 E 0.98 N 0.81 E 1.38 N 1.20 E 1.81 N 1.68 E 2.23 N 2.44 E 0.84 N 2.53 E 1.64 S 1.74 E 7.54 S 0.86 W 14.88 S 5.64 W 24.66 S 14.93W 38.15 $ 29.18W 57.15 S 49.56W 78.72 S 74.04W 100.25 S 99.31W 121.19 S 124.13W 143.69 S 150.94W 170.03 S 184.83W 195.30 S 221.15W 219.78 S 257.43W 244.69 S 295.55W 271.80S 339.47W 300.92 S 384.83W 328.49 S 425.85W Alaska State Plane 4 Milne Point MPF Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) 6035466.40 N 541569.03 E 0.00 6035466.57N 541569.02E 0.200 0.02 6035466.99 N 541569.27 E 0.313 -0.21 6035467.38 N 541569.83 E 0.109 -0.77 6035467.79 N 541570.22 E 0.285 -1.14 6035468.22 N 541570.70 E 0.373 -1.60 6035468.65 N 541571.46 E 0.090 -2.34 6035467.26 N 541571.56 E 2.274 -2.49 6035464.77 N 541570.78 E 2.775 -1.81 6035458.85 N 541568.22 E 1.056 0.53 6035451.48 N 541563.48 E 2.816 4.98 6035441.66 N 541554.24 E 3.529 13.83 6035428.08 N 541540.06 E 5.762 27.48 6035408.97 N 541519.79 E 5.196 47.01 6035387.26 N 541495.43 E 1.791 70.52 6035365.60 N 541470.28 E 1.083 94.82 6035344.51N 541445.58 E 0.493 118.71 6035321.87 N 541418.90 E 4.883 144.50 6035295.34N 541385.15 E 4.339 177.21 6035269.86 N 541348.98 E 1.012 212.38 6035245.18 N 541312.84 E 0.500 247.55 6035220.06 N 541274.86 E 2.708 284.55 6035192.70 N 541231.08 E 5.002 327.24 6035163.33 N 541185.89 E 2.316 371.28 6035135.54 N 541145.02 E 1.368 411.06 RECEIYE ) Comment MWD Magnetic Continued... 8 August, 2000 - 23:12 -2- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPF-83 Your Ref: APi-$00292296300 Surveyed: 24 July, 2000 North Slope Alaska Measured Depth Incl. Azim. Sub-Sea Depth (ft) 2337.37 38.380 236.520 2149.40 2429.37 36.210 234.770 2222.58 2522.62 34.440 234.380 2298.66 2615.85 32.560 233.650 2376.40 2709.85 33.170 235.020 2455.36 2802.69 33.900 235.470 2532.74 2895.54 35.100 235.560 2609.26 2987.91 34.840 235.780 2684.96 3081.34 33.170 235.660 2762.40 3173.88 34.120 236.350 2839.44 3267.10 35.300 237.470 2916.07 3359.11 35.600 234.250 2991.03 3451.40 35.040 231.720 3066.34 3543.00 35.190 231.740 3141.27 3637.78 34.420 231.570 3219.09 3729.09 33.240 232.170 3294.94 3823.08 34.080 232.440 3373.17 3915.99 32.040 232.740 3451.04 4008.66 33.760 232.610 3528.84 4100.51 32.490 233.270 3605.76 4193.28 33.170 232.800 3683.71 4287.20 34.030 235.070 3761.94 4378.88 32.420 236.430 3838.64 4471.79 32.250 236.820 3917.14 4565.85 32.710 236.890 3996.49 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 2188.25 363.77S 479.03W 2261.43 395.20 S 525.06W 2337.51 426.45 S 568.99W 2415.25 456.68 S 610.63W 2494.21 486.41S 652.08W 2571.59 515.65 S 694.21W 2648.11 545.43 S 737.56W 2723.81 575.28 S 781.28W 2801.25 604.71S 824.46W 2878.29 633.38 S 866.97W 2954.92 662.35 S 911.44W 3029.88 692.29 $ 955.59W 3105.19 724.40S 998.19W 3180.12 757.04S 1039.56W 3257.94 790.60 S 1081.99W 3333.79 821.99 S 1121.97W 3412.02 853.84S 1163.20W 3489.89 884.63 S 1203.45W 3567.69 915.15 S 1243.48W 3644.61 945.41 $ 1283.53W 3722.56 975.65 S !323.71W 3800.79 1006.23 $ 1365.72W 3877.49 1034.51 $ 1407.24W 3955.99 1061.85 $ 1448.73W 4035.34 1089.47 S 1491.03W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/lOOft) Alaska State Plane 4 Milne Point MPF Vertical Section (ft) 6035099.96 N 541092.04 E 0.750 462.64 6035068.26 N 541046.19 E 2.625 507.24 6035036.77 N 541002.43 E 1.913 549.77 6035006.31N 540960.96 E 2.062 590.05 6034976.34 N 540919.69 E 1.023 630.15 6034946.87 N 540877.71 E 0.831 670.97 6034916.85 N 540834.53 E 1.294 712.97 6034886.75 N 540790.98 E 0.313 755.34 6034857.08 N 540747.97E 1.789 797.18 6034828.18 N 540705.62 E 1.107 838.40 6034798.96 N 540661.31E 1.439 881.56 6034768.77 N 540617.33 E 2.056 924.36 6034736.42 N 540574.91 E 1.697 965.51 6034703.56 N 540533.72 E 0.164 1005.41 6034669.76 N 540491.48 E 0.819 1046.33 6034638.15 N 540451.67 E 1.343 1084.90 6034606.06 N 540410.63 E 0.908 1124.69 6034575.05 N 540370.55 E 2.203 1163.55 6034544.30 N 540330.69 E 1.858 1202.20 6034513.83 N 540290.81E 1.437 1240.89 6034483.36 N 540250.80 E 0.783 1279.71 6034452.54 N 540208.96 E 1.621 1320.35 6034424.03 N 540167.61 E 1.935 1360.58 6034396.46 N 540126.26 E 0.290 1400.84 6034368.61N 540084.12 E 0.491 1441.88 Comment 8 August, 2000 - 23:13 -3- RECEIVED Continued... DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPF-83 Your Ref: API,500292296300 Surveyed: 24 July, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4658.52 32.970 237.410 4074.35 4113.20 4751.39 33.150 237.420 4152.18 4191.03 4795.72 33.090 236.850 4189.31 4228.16 4867.91 33.410 236.150 4249.68 4288.53 4962.01 30.700 235.190 4329.43 4368.28 5058.26 30.150 233.950 4412.42 4451.27 5148.53 30.000 232.150 4490.54 4529.39 5240.69 30.510 236.070 4570.16 4609.01 5334.41 30.350 237.290 4650.97 4689.82 5423.93 29.880 237.010 4728.40 4767.25 5517.30 29.640 236.010 4809.46 4848.31 5608.63 29.120 234.790 4889.04 4927.89 5701.50 30.330 236.800 4969,69 5008.54 5794.38 30.570 235.770 5049.76 5088.61 5887.82 30.460 235.030 5130.26 5169,11 5980.86 30.460 233.520 5210.46 5249.31 6074.01 30.040 232.800 5290.93 5329.78 6167.10 32.470 233.970 5370.50 5409,35 6260.58 37.220 235.070 5447.20 5486.05 6353.36 43.070 238.530 5518.10 5556.95 6445.80 44.860 242.630 5584.65 5623.50 6539.06 46.390 245.290 5649.87 5688.72 6632.02 47.130 248.450 5713.56 5752.41 6723.57 48.720 249.640 5774.91 5813.76 6815.32 51.540 252.570 5833.73 5872.58 1116.73 S 1533.25W 6034341.11N 540042.06 1144.01 $ 1575.93W 6034313.59 N 539999.52 1157.16 S 1596.28W 6034300.33 N 539979.25 1179.00 S 1629.28W 6034278.30 N · 539946.37 1207.15 $ 1670.53W 6034249.92 N 539905.28 1235.40 S 1710.25W 6034221.45 N 539865.72 1262.59 S 1746.39W 6034194.06 N 539829.73 1289.79 S 1784.00W 6034166.65 N 539792.27 1315.86 $ 1823.66W 6034140.35 N 539752.76 1340.23 $ 1861.40W 6034115.78 N 539715.16 1365.80 S 1900.05W 6034089.99 N 539676.65 1391.24 S 1936.93W 6034064.35 N 539639.91 1417.11S 1975.02W 6034038,26 N 539601.97 1443.23 S 2014.17W 6034011,92 N 539562.97 1470.18 $ 2053.22W 6033984.76 N 539524.07 1497.71 S 2091.51W 6033957.01N 539485.93 1525.85 S 2129.07W 6033928.66 N 539448.54 1554.64 S 2167.84W 6033899.66 N 539409.92 1585.60 S 2211.34W 6033868.45 N 539366.60 1618.24 S 2261.41W 6033835.53 N 539316.71 1649.72 $ 2317.30W 6033803.74 N 539261.00 1678.96 S 2377.19W 6033774.17 N 539201.27 1705.54 S 2439.46W 6033747.24 N 539139.16 1729.83 S 2502.92W 6033722.59 N 539075.83 1752.60 S 2569.53W 6033699.45 N 539009.35 -4- Dogleg Rate (°/100fi) E 0.414 E 0.194 E 0.715 E 0.692 E 2.930 E 0.867 E 1.013 E 2.213 E 0.681 E 0.548 E 0.590 E 0.868 E 1.688 E 0.619 E 0.419 E 0.823 E 0.596 E 2.690 E 5.125 E 6.746 E 3.637 E 2.617 E 2.601 E 1.987 E 3.931 RECEIVED OCT GS DO0 Alaska State Plane 4 Milne Point MPF Vertical Section (ft) Comment 1482.87 1524.32 1544.o7 1576.o9 1616.o6 1654.5o 1689.43 1725.81 1764.29 18oo.92 1838.41 1874.15 1911.o6 1949.o3 1986.87 2o23.91 2060.20 2097.68 2139.78 2188.37 2242.83 23Ol.38 2362.42 2424.76 249o.31 Continued... DrillQuest 1.05,05 8 August, 2000- 23:13 ~a$~u~ 0il & Gas Cons. C0mmissio~ Sperry-Sun Drilling Services Survey Report for MPF-83 Your Ref: APi-$00292296300 Surveyed: 24 July, 2000 North Slope Alaska Measured Depth Incl, Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 6908.96 55.590 252.880 5889.33 5928.18 7001.40 58,710 252,720 5939.47 5978.32 7094.04 61.410 252.780 5985.70 6024.55 7186.92 62.580 253,210 6029.31 6068.16 7279.27 64.540 250.830 6070.43 6109.28 7372,23 65.130 250.450 6109.96 6148.81 7466.54 65.000 249.180 6149.72 6188.57 7558.59 65.120 249.720 6188.54 6227.39 7651.84 64.720 248.520 6228.07 6266.92 7744.22 65.710 248.770 6266.79 6305.64 7836.65 67.590 249.550 6303.43 6342.28 7929.93 69.000 251.850 6337.93 6376.78 8022.51 68.970 252.250 6371.13 6409.98 8115.54 68.420 252.280 6404.93 6443.78 8208.50 68.150 252.920 6439.32 6478.17 8300.53 68.210 256.990 6473.54 6512.39 8393.96 70.300 260.340 6506.64 6545.49 8487.15 71.220 267.150 6537.38 6576.23 8579.46 71.030 271.810 6567.26 6606,11 8672.42 69.460 275.830 6598,69 6637.54 8762.45 69.850 273.390 6630.00 6668.85 8856.10 72.790 275.780 6659.99 6698.84 8951.17 78.020 278.560 6683.94 6722.79 9044.38 80.630 281.270 6701.21 6740.06 9137.41 84.390 284,480 6713.34 6752.19 Local Coordinates Northings Eastings (ft) (ft) 1774.96 $ 2641.46W 1797.92 S 2715.63W 1821.72 $ 2792.29W 1845.70 S 2870.71W 1871.24S 2949.34W 1899.13 S 3028.72W 1928.64 S 3108.99W 1957.94 S 3187.14W 1988.04S 3266.05W 2018.58 S 3344,16W 2048.76 S 3423.47W 2077.39 $ 3505.26W 2104.03 S 3587.47W 2130.43 S 3670.03W 2156,26 S 3752.44W 2178.43 S 3834.92W 2195.58 S 3920.58W 2205.14 S 4007.98W 2205,94 S 4095.29W 2200,13 $ 4182,56W 2193.34 S 4266,69W 2186.24 S 4355.11W 2174.73 S 4446.34W 2158.96 S 4536,55W 2138.40 S 4626,44W 8 August, 2000- 23:13 -5- Alaska State Plane 4 Milne Point MPF Global Coordinates Northings Eastings (ft) (ft) Dogleg Rate (°/100fi) Vertical Section (ft) Comment 6033676.69 N 538937.55 E 6033653.31N 538863.50 E 6033629.08 N 538786.98 E 6033604.66 N 538708.69 E 6033578.69 N 538630.20 E 6033550.35 N 538550.98 E 6033520.39 N 538470.88 E 6033490.66 N 538392.89 E 6033460.12 N 538314,15 E 6033429.14 N 538236.21E 6033398.51N 538157.08 E 6033369.42N 538075.45 E 6033342.33 N 537993,39 E 6033315.47 N 537910.98 E 6033289.18 N 537828.72 E 6033266.55 N 537746.36 E 6033248.92 N 537660.80 E 6033238,86 N 537573.46 E 6033237.58 N 537486.15 E 6033242.90 N 537398.85 E 6033249.22 N 537314,68 E 6033255.83 N 537226.23 E 6033266.82 N 537134.93 E 6033282.09 N 537044.63 E 6033302.15 N 536954.63 E 4.333 3.378 2,915 1.324 3.135 0.735 1.229 0,548 1.242 1.099 2.177 2.745 0,405 0,592 0.702 4.106 4.031 6.969 4,781 4.406 2,578 3.962 6.186 4.000 5.295 2561.19 2634.29 2709.83 2787.12 2864.57 2942.65 3021.54 3098,34 3175.86 3252.55 3330.46 3410.92 3491.89 3573.21 3654.41 3735.84 3820.66 3907.56 3994.75 4082.19 4166.54 4255.18 4346.84 4437.65 4528.35 RECEIVED OCT 0 S 000 Naska 0il & G~ Cons. C0mrnissl~ Continued,.. DrillQuest 1.05,05 Sperry-Sun Drilling Services Survey Report for MPF-83 Your Ref: AP1.$00292296300 Surveyed: 24 July, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 9229.58 84.880 284.370 6721.96 9323.27 84.290 283.990 6730.80 9414.95 84.800 280.070 6739.52 9508.25 84.420 278.850 6748.28 9601.24 85.170 280.600 6756.72 9694.36 85.440 276.640 6764.34 9787.31 84.140 275.640 6772.78 9880.10 85.390 276.530 6781.25 9973.18 84.670 281.190 6789.32 10067.33 83.180 282.870 6799.28 10157.64 81.250 284.450 6811.51 10250.84 78.720 288.080 6827.73 10341.58 76.480 290.390 6847.21 10434.22 74.060 296.560 6870.79 10483.64 74.110 295.530 6884.34 10571,87 74.630 296.290 6908.11 10605.30 75.570 297.040 6916.71 10638.20 76.770 300.130 6924.57 10701.44 78.410 302.290 6938.16 10764.84 78.160 302.020 6951.04 10830.93 79.350 305.030 6963.93 10861.47 79.600 304.690 6969.51 10956.55 80.540 304.280 6985.90 11023.22 80.600 303.790 6996.83 11051.00 80.440 302.830 7001.40 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) Dogleg Rate (°llOOfl) 6760.81 2115.54 S 4715.31W 6033324;51N 536865.63 E 0.545 6769.65 2092.69 S 4805.74W 6033346.85 N 536775.07 E 0.748 6778.37 2073.67 S 4894.99W 6033365.37 N 536685.72 E 4.293 6787.13 2058.41S 4986.61W 6033380.12 N 536594.02E 1.364 6795.57 2042.76 S 5077.88W 6033395.25 N 536502.66 E 2.040 6803.19 2028.86 S 5169.62W 6033408.65 N 536410.84 E 4.248 6811.63 2018.95 S 5261.65W 6033418.03 N 536318.76 E 1.762 6820.10 2009.16 S 5353.53W 6033427.31N 536226.83 E 1.651 6828.17 1994.88 $ 5445.13W 6033441.08 N 536135.15 E 5.047 6838.13 1975.37 S 5536.69W 6033460.08 N 536043.48 E 2.378 6850.36 1954.25 S 5623.63W 6033480.72 N 535956.42 E 2.752 6866.58 1928.56 S 5711.72W 6033505.91N 535868.20 E 4.699 6886.06 1899.37 S 5795.38W 6033534.63 N 535784.37 E 3.504 6909.64 1863.73 S 5877.52W 6033569.81N 535702.03 E 6.950 6923.19 1842.86 S 5920.22W 6033590.44 N 535659.21 E 2.007 6946.96 1805.74 S 5996.65W 6033627.14 N 535582.58 E 1.018 6955.56 1791.24 $ 6025.52W 6033641.47 N 535553.63 E 3.551 6963.42 1775.95 $ 6053.56W 6033656.60 N 535525.50 E 9.822 6977.01 1743.95 $ 6106.38W 6033688.31N 535472.50 E 4.225 6989.89 1710.91S 6158.94W 6033721.05 N 535419.76 E 0.574 7002.78 1675.11 $ 6212.96W 6033756.55 N 535365.54 E 4.816 7008.36 1657.95 S 6237.60W 6033773.57 N 535340.80 E 1.367 7024.75 1604.92 S 6314.80W 6033826.17 N 535263.31 E 1.076 7035.68 1568.11S 6369.30W 6033862.67 N 535208.60 E 0.731 7040.25 1553.06 S 6392.20W 6033877.59 N 535185.62 E 3.457 RECEIVED OCT 2000 Alaska State Plane 4 Milne Point MPF Vertical Section (ft) Comment 4618.14 4709.49 4799.48 4891.68 4983.55 5075.81 5168.19 5260.41 5352.54 5444.87 5532.65 5621.78 5706.64 5790.26 5833.84 5911.81 5941.29 5969.98 6024.15 6078.10 6133.64 6159.01 6238.46 6294.52 6318.05 Continued... 8 August, 2000 - 23:13 -6- N~ka 0il-& Gas Cons. C0mmissi0~ DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPF-83 Your Ref: API-500292296300 Surveyed: 24 July, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 11117.11 81.360 302.940 7011.86 7050.71 1517.62 S 6447.02 W 11145.72 83.000 303.180 7015.75 7054.60 1502.16 S 6470.77 W 11179.98 85.080 303.870 7019.31 7058.16 1483.34 S 6499.18 W 11214.08 85.570 304.340 7022.09 7060.94 1464.29 $ 6527.32 W 11242.23 85.750 305.530 7024.22 7063.07 1448.21 $ 6550.33 W 11274.60 85.930 305.410 7026.57 7065.42 1429.48 S 6576.62 W 11306.34 85.900 305.470 7028.83 7067.68 1411.12 S 6602.42 W 11336.17 86.190 304.630 7030.88 7069.73 1394,03 S 6626.78 W 11367.11 88.280 305.470 7032.38 7071.23 1376.28 S 6652.08 W 11402.63 89.380 306.360 7033.10 7071.95 1355,45 S 6680.84 W 11432.14 88.650 306.720 7033.61 7072.46 1337.89 $ 6704.54 W 11466.09 88.400 306.300 7034.48 7073.33 1317.69 S 6731.82 W 11495,79 88.650 306.650 7035.25 7074.10 1300.04 S 6755.69 W 11534.32 88.630 305.650 7036.16 7075.01 1277.32 S 6786.80 W 11564,58 89.080 305.840 7036.77 7075.62 1259.65 $ 6811.35 W 11623.17 90.000 305.870 7037.24 7076.09 1225.33 $ 6858.84 W 11676.19 90.250 305.270 7037.12 7075.97 1194.49 S 6901.96 W 11720.47 90.310 305.410 7036.90 7075.75 1168.88 S' 6938.08 W 11761.42 90.620 305.390 7036.57 7075.42 1145,16 S 6971.46 W 11815.08 91.110 304.450 7035.76 7074.61 1114.44 S 7015.46 W 11860.37 91.720 304.770 7034.64 7073.49 1088.73 S ' 7052.72 W 11960.11 88.810 305.120 7034.18 7073.03 1031.60 S 7134,47 W 12007.47 89.450 304.860 7034.90 7073.75 1004.45 S 7173.26 W 12061.31 90.310 305.240 7035.01 7073.86 973.53 $ 7217.34 W 12105.22 91.050 305.710 7034.49 7073.34 948.05 S 7253.09 W Dogleg Rate (°/lOOft) Alaska State Plane 4 Milne Point MPF Vertical Section (ft) 6033912.73 N 535130.61 E 1.401 6374.37 6033928.05 N 535106.76 E 5.792 6398.78 6033946.71 N 535078.26 E 6.393 6427.98 6033965.61 N 535050.01 E 1.988 6456.93 6033981.56 N 535026.91 E 4.263 6480.62 6034000,14 N 535000.51 E 0.668 6507.71 6034018.36 N 534974.61 E 0.211 6534.28 6034035.31 N 534950.16 E 2.973 6559.37 6034052.91 N 534924.76 E 7.279 6585.42 6034073.58 N 534895.88 E 3.983 6615.07 6034091.02 N 534872.08 E 2.758 6639.52 6034111.06 N 534844.69 E 1.439 6667.65 6034128.57 N 534820.72 E 1.448 6692.28 6034151.12 N 534789.49 E 2.595 6724.35 6034168.66 N 534764.83 E 1.614 6749.65 6034202.71 N 534717.16 E 1.571 6798.59 6034233.31 N 534673.86 E 1,226 6843.03 6034258.72 N 534637.60 E 0.344 6880.24 6034282.25 N 534604.09 E 0.759 6914,62 6034312.72 N 534559.92 E 1.975 6959.92 6034338.22 N 534522.51 E 1.521 6998.27 6034394.89 N 534440.45 E 2.939 7082.44 6034421.83 N 534401.50 E 1.459 7122.39 6034452.50 N 534357.25 E 1.746 7167.78 6034477.78 N 534321.36 E 1.996 7204.62 RECEIVED OCT C,s 8000 Comment Continued... 8 August, 2000 - 23:13 -7- 0ii & Gas Cons. C0mmissio~ Annhnrnnp, DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for MPF-83 Your Ref: AP1-$00292296300 Surveyed: 24 July, 2000 North Slope Alaska Measured Depth Incl. Azim. Sub-Sea Depth (ft) 12153.31 91.600 305.580 7033.38 12201.15 91.910 305.430 7031.92 12250.21 92.520 305.730 7030.02 12296.43 93.140 305,310 7027.74 12360.89 93.690 305.630 7023,90 12389.83 93.940 305.480 7021.97 12442.49 94.680 305.620 7018.02 12486.70 92.280 305,870 7015.33 12535.49 91,980 304.770 7013.52 12584.68 91.980 304.240 7011.82 12637.63 91.720 305.260 7010.11 12678.16 89.200 305.430 7009.78 12728.78 89,430 304,240 7010,39 12774.10 89.320 304.140 7010,88 12823.98 89.750 303.770 7011.29 12868.59 89.870 304.060 7011.44 12919.00 90.060 302,880 7011.47 12963.37 90.430 303,120 7011.28 13015.66 90,800 302.620 7010.72 13061.36 91,290 302.690 7009.88 13111.25 91.660 302.080 7008.60 13156.64 91.970 301.990 7007.16 13201.60 92,710 301.750 7005.33 13252.56 93.510 301.650 7002.56 13318.27 90.920 304.070 7000.02 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) Dogleg Rate (°/lOOff) 7072.23 920.03 S 7292.16W 6034505.58 N 534282.13 E 1.175 7070.77 892,26 S 7331.09W 6034533.13 N 534243.05 E 0.720 7068.87 863.74 $ 7370.96W 6034561.43 N 534203.02E 1.385 7066.59 836.92S 7408.53W 6034588.04 N 534165.30 E 1.620 7062.75 799.58 $ 7460.94W 6034625.08 N 534112.68 E 0.987 7060.82 782.79 S 7484.43W 6034641.74N 534089.10 E 1.007 7056,87 752.26 S 7527.15W 6034672.03 N 534046.21 E 1.430 7054.18 726.48S 7562.96W 6034697.61N 534010.25 E 5.458 7052.37 698.29 S 7602.75W 6034725,58 N 533970.31 E 2.335 7050.67 .670.44S 7643.26W 6034753.20 N 533929.64 E 1.077 7048.96 640.28 S 7686.74W 6034783.12 N 533885.99 E 1.987 7048,63 616.84 $ 7719.80W 6034806.38 N 533852,81 E 6.232 7049.24 587.92S 7761.34W 6034835.06 N 533811.10 E 2.394 7049.73 562.46 S 7798.83W 6034860.31N 533773.47 E 0.328 7050.14 534.60 S 7840.20W 6034887.94 N 533731.94 E 1.137 7050.29 509.71S 7877.22W 6034912.62 N 533694.79 E 0.704 7050.32 481.915 7919.27W 6034940.19 N 533652.58 E 2.371 7050.13 457,74S 7956.48W 6034964.14 N 533615.23 E 0.994 7049,57 429.36 S 8000~0W 6034992.27 N 533571.16 E 1.189 7048,73 404.71S 8038.87W 6035016.71 N 533532.55 E 1.083 7047.45 378.00 S 8080.98W 6035043.19 N 533490.29 E 1.430 7046.01 353.93 S 8119.44W 6035067.04 N 533451.69 E 0.711 7044.18 330.21S 8157.59W 6035090.54 N 533413.41 E 1.730 7041.41 303.48 S 8200.89W 6035117.04N 533369.97 E 1.582 7038.87 267.85 S 8256.03W 6035152.35 N 533314.63 E 5.392 RECEIVED OCT O~ 2000 Alaska State Plane 4 Milne Point MPF Vertical Section (ft) Comment 7244.87 7284.98 7326.06 7364.77 7418.76 7442.97 7486.99 7523.89 7564.87 7606.56 7651,33 7685.38 7728.15 7766.71 7809.27 7847.34 7890.57 7928.80 7973.92 8013.43 8056.68 8096.15 8135.30 8179.73 8236.38 Continued... 8 August, 2000 - 23:13 -8- Gas Cons. Commissie[~ Anchoraoe DrillQuest 1,05.05 Sperry-Sun DnTlin g Services Survey Report for MPF-83 Your Ref: AP1-$00292296300 Surveyed: 24 July, 2000 North Slope Alaska Measured Sub-Sea Depth incl. Azim. Depth (ft) (ft) Vertical Local COordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 13348.09 90.740 304.480 6999.59 13397.65 90.920 304.410 6998.87 13531.43 92.090 303.740 6995.36 13583.82 94.370 304.220 6992.41 13635.68 94.930 304.840 6988.20 13682.03 95.610 303.840 6983.94 13731.13 93.260 302.780 6980.15 13777.34 93.260 302.740 6977,52 13828.06 93.510 302.540 6974.52 13874.13 94.070 302.230 6971.48 13923.62 94.380 302.220 6967.83 14019.06 94.870 301.710 6960.14 14067.49 94.810 301.470 6956.05 14115.15 94.930 301.000 6952.01 14182.00 94.930 301.000 6946.26 7038.44 251.06 S 8280.67W 7037.72 223.03 $ 8321.54W 7034.21 148.11S 8432.31W 7031.26 118.87S 8475.68W 7027.05 89.57 $ 8518.26W 7022.79 63.54 S 8556.37W 7019.00 36.66 S 8597.28W 7016.37 11.69 S 8636.07W 7013.37 15.61N 8678.71W 7010.33 40.24 N 8717.53W 7006.68 66.55 N 8759.28W 6998.99 116.92N 8839.99W 6994.90 142.19 N 8881.09W 6990.86 166.82N 8921.70W 6985.11 201.12 N 8978.79W 6035169.01N 533289.89 E 6035196.81N 533248.87 E 6035271.11N 533137.68 E 6035300.10 N 533094.15 E 6035329.16 N 533051.40 E 6035354.98 N 533013.15 E 6035381.63 N 532972.09 E 6035406.38 N 532933.16 E 6035433.45 N 532890.37 E 6035457.85 N 532851.41 E 6035483.94 N 532809.51E 6035533.85 N 532728.53 E 6035558.90 N 532687.28 E 6035583.29 N 532646.54 E 6035617.28 N 532589.26 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. Dogleg Rate (°ll00ff) 1.501 0.390 1.008 4.447 1.608 2.602 5.248 0.086 0.631 1.389 0.627 0.740 0.509 1.014 0.000 Alaska State Plane 4 Milne Point MPF Vertical Section (ft) Comment 8261.73 8303.79 8417.73 8462.34 8506.17 8545.38 8587.42 8627.28 8671.o7 8710.93 8753.79 8836.63 8878.80 8920.44 8978.98 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 272.510° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14182.00ft., The Bottom Hole Displacement is 8981.04ft., in the Direction of 271.283° (True). RECEIVED 0 CT C, $ 2000 8 Augus~ 2000-23:13 -9- Gas Cons. C0mmissi~ Continued... Dr#lQuest 1.05.05 Anchorage Sperry-Sun Drilling Services Survey Report for MPF-83 Your Reh AP1.$00292296300 Surveyed: 24 July, 2000 North Slope Alaska Alaska State Plane 4 Milne Point MPF Comments Measured Depth (~t) 14182,00 Station Coordinates TVD Northings Eastings (~t) (~t) (~t) 6985.11 201.12 N 8978.79 W Comment Projected Survey Survey tool program. From Measured Vertical Depth Depth (~t) 0.00 0.00 757.00 756.91 To Measured Vertical Depth Depth (~t) (ft) 757.00 756.91 14182.00 6985.11 Survey Tool DesCription AK-2 BP_CG MWD Magnetic .10- RECEIVED OCT ~ S ~000 0il & G~s Cons. Commission DrillQuest 1.05.05 8 August, 2000 - 23:13 Anchora~je 8/30/00 GeoQuest 3940 Arctic Bird Anchorage, AK 99503 ATrN: Sherrie NO. 465 Company Alaska Oil & Gas Cons Camm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) Well Job # Log Description Date BL Sepia Color :MPI-09 20350 USIT 000812 1 MPF-83 20354 USIT 000817 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNINGONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson BIvd. Anchorage, Alaska 99519~6612 Date Delivered: RECE VED SEP 0 8 2000 Alaska Oil & Gas Cons. Commission Anchorage Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99~3 All'N: Sherrie I \ _..,,,,-z--------' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Commissioner DATE: July 9, 2000 THRU: Blair Wondzell ~ P.I. Supervisor 7'[ I';~r~(3 FROM' Jeff Oone~/~ Petroleurd,4nsl:fd'ctor NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Doyon 141 BPX/F-Pad MPF-83i 200-093 MPF/MPU Operator Rep.: Jim Pyrone Contractor Rep.: Pat Krupa Test Pressures Rams: 250/5000 MISC. INSPECTIONS: P/F Location Gen.: P Sign: Housekeeping: P Rig cond: __ PTD On Location P Hazard: Standing Order: P Op. phone: 670-3366 Rig phone: 670-3483 P/F P Op. E-Mail: Rig E-Mail: Annular: 250/2500 Choke: 250/5000 TEST DATA FLOOR VALVES: MUD SYSTEM: Quantity P/F Trip Tank Upper Kelly 1 P Pit Level Indicators Lower Kelly 1 P Flow Indicator Ball Type 1 P Meth Gas Detector Inside BOP 1 P H2S Gas Detector BOP STACK: Quantity Size P/F Annular Preventer 1 13 5/8 P Pipe Rams 1 3.5 X 6 P Lower Pipe Rams 1 5 P Blind Rams 1 13 5/8 P Choke Ln. Valves 1 3 1/8 P HCR Valves 2 3 1/8 P Kill Line Valves 1 3 1/8 P Check Valve 0 CHOKE MANIFOLD: Quantity P/F No. Valves 14 P Man. Chokes 1 P Hyd. Chokes 1 P Visual Alarm P P P P P P P P P P ACCUMULATOR SYSTEM: Time/Psi P/F System Pressure 3000 P After Closure 1500 -P 200 psi Attained 38 sec. P Full Pressure 3.7 min. P Blind Covers (All Stations): P N2 Bottles (avg): 5 @ 2300 P Test's Details On July 9, 2000 I traveled to BPX's F-Pad to perform an initial BOPE test on Doyon rig #141. The testing was performed in a safe and proficient manner by Doyon personnel with no failures. The drilling rig and its equipment appeared clean, in good condition and the pad well organized. While on location, I witnessed a random test of the H2s and methane gas detection alarm system with no failures. Total Test Time:_-..--_4 Number of failures: (~ Attachments: 0 cc.' BOP Doyon 141 7-9-00 JJ2 7/13/00 Re:'MP F-83i Permit to Ddll (PTD 200-093). Subject: Re: MP F-83i Permit to Drill (P'ID 200-093) Date: Tue, 27 Jun 2000 08:03:28 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "Johnson, Frederick C (ARCO)" <JohnsoFC@BP.com> Thanks Fred, I'll move the application on this morning. Tom "Johnson, Frederick C (ARCO)" wrote: In response to your questions: (1) Is this planned a drill out test? Answer: After setting 7" intermediate we plan to do a "conventional" FIT. By conventional we mean drill out the casing, circulate and condition mud, close the BOP, pressure up to give the EMW at bottom of the hole, etc. (2) Does an FIT of 12.2 provide sufficient cushion over the 1/2# requirement for drilling ahead if it is necessary to increase the mud weight? Answer: We've got pressure data from F-81 which indicates that the F-83i reservoir pressure will be at the lower part of the range given in the permit application (F-81 came in at about 10.9 ppg). An FIT of 12.2 ppg FIT is high enough to cover the anticipated ECD load the shoe will see as we drill ~th 11.5 ppg mud. From: Tom Maunder[SMTP:tom_maunder@admin. state, ak. us] Sent: IVbnday, June 26, 2000 12:26 PM To: Johnson, Frederick C (ARCO) Subject: Re: MP F-83i Permit to Drill (PTD 200-093) <<File: torn_maunder, vcf>> Thanks Fred/. I wi//check, but I think these plans answer my question about isolation/cement quality logs. I will include this email in the file so there should not be any need to submit a modification. I do have one other question though.., with regard to the FITs. It is stated that a 12.2 FIT is planned at both the 9-5/8" and 7" shoes. There is one mention of "Drill out" FITs at the top of page 6, but no uhere e/se. A conventional procedure will be employed at the surface casing shoe. 12.2 should be fine there. With the attention given to avoiding breathing, ECDs are planned to be kept below 11.5 with a static mud weight of 9.6 max. For the lower hole section it is planned to drill out with 11.5 and perform the FIT to 12.2. This gives you 2/10 cushion over the 1/2 # minimum difference requirement. Is this test planned as a drill out test? I am curious of what the modeling for ECD at 1 of 2 6/27/00 8:23 AM Re:WtP F-83i Permit to Ddll (PTD 200-093) > the shoe has shown as drilling proceeds. Does an FIT of 12.2 provide > sufficient > cushion over the 1/2 # requirement for drilling ahead if it is necessary >to > increase the mud weight? Look forward to your reply. > Tom . "Johnson, Frederick C (ARCO)" wrote: > Tom Maunder AOGCC > In response to your question on what the plans were to obtain the required > cement bond log on MP F-83i: > The permit application does not include running the bond log. The cement > bond log is required on injection wells. The bond log is part of the > program but was inadvertently missed in the application. > > The plan is to run the cement bond log in the period after the drilling rig > is moved off the well and before the completion rig is moved on. The bond > log v~ll be run over an interval of the 7" casing to prove adequate zonal > isOlation across the upper confining zones. The HRZ and Kalubik ,intervals > are indentified as upper confining zones. > Please advise if a revision to the Permit application is required or if you > have additional questions. Thanks Tom Maunder <tom maunder.~,admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 6/27/00 8:23 AM Re: MP F-83i Permit to Ddll (PTD 200-093) Subject: Re: MP F.83i Permit to Drill (P1D 200-093) Date: Mon, 26 Jun 2000 12:26:44-0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "Johnson, Frederick C (ARCO)" <JohnsoFC@BP.com> Thanks Fred! I will check, but I thinkthese plans answer my question about isolation/cement quality logs. I will include this email in the file so there should not be any need to submit a modification. I do have one other question though...with regard to the FITs. It is stated that a 12.2 FIT is planned at both the 9-5/8" and 7" shoes. There is one mention of "Drill out" FITs at the top of page 6, but no where else. A conventional procedure will be employed at the surface casing shoe. 12.2 should be fine there. VVith the attention given to avoiding breathing, ECDsare planned to be kept below 11.5 with a static mud weight of 9.6 max. For the lower hole section it is planned to drill out with 11.5 and perform the FIT to 12.2. This gives you 2/10 cushion over the 1/2 # minimum difference requirement. Isthis test planned as a drill out test? I am curious of what the modeling for ECD at the shoe has shown as drilling proceeds. Does an FIT of 12.2 provide sufficient cushion over the 1/2 # requirement for drilling ahead if it is necessary to increase the mud weight? Look forward to your reply. Tom "Johnson, Frederick C (ARCO)" wrote: Tom Maunder AOGCC In response to your question on what the plans were to obtain the required cement bond log on MP F-83i: The permit application does not include running the bond log. The cement bond log is required on injection wells. The bond log is part of the program but was inadvertently missed in the application. The plan is to run the cement bond log in the period after the drifting rig is moved off the well and before the completion rig is moved on. The bond log v~ll be run over an interval of the 7" casing to prove adequate zonal isolation across the upper confining zones. The HRZ and Kalubik intervals are indentified as upper confining zones. Please advise if a revision to the Permit application is required or if you have additional questions. Thanks Tom Maunder <tom maunder~admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 2 6/26/00 1:03 PM ALASitA OIL AND GAS CONSERVATION CO~ISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7,542 Chuck Mallary Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 AnChorage, AK 99519-6612 Re~ Milne Point Unit MPF-83i BP EXploration (Alaska), Inc. Permit No: 200-093 Sur Loc: 2016'NSL, 2993'WEL, Sec. 06, T13N, R10E, UM Btmhole Loc. 2333'NSL, 1689'WEL, Sec. 02, T13N, R09E, UM Dear Mr. Mallary: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required 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 performed before drilling below the surface casing shoe, 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. aniel T. seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~', ?"'~'~ day of June, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALAS ,LAND GAS CONSERVATION COM .,SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Iia Drill [] Redrill 11 b. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen . [] 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 ADL 388235 4~ Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2016' NSL, 2993' WEL, SEC. 06, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 5137' NSL, 3786' WEL, SEC. 12, T13N, R09E, UM MPF-83i Number 2S100302630-277 At total depth 9. Approximate Spud date 2333' NSL, 1689' WEL, SEC. 02, T13N, R09E, UM 07/01/00 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 355023, 949' MDI No Close Approach 1920 14546' MD / 6970' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 500' MD Maximum Hole Angle 94 ° Maximum surface 3417 psi~l, At total depth (TVD) 6943' / 4215 psig 118. Casing Program Specifications Setting Depth ~ize , T(~D Bot' om Quantitv of Cement Hole Casin_o W~.io_ht Grade Couolino Lenoth MD TVD MD TVD finclude staoe data~ 26" 20" 54.5# K-55 Welded 78' Surface Surface 78' 78' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 4805' 30' 30' 4835' 4261' 686 sx Arcticset 3 ~ 202 sx Class 'G' 8-1/2" 7" 26# L-80 BTC 10510' 30' 30' 10540' 6946' 361 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 NSCC 4206' 10340' 6895' 14546' 6970' 465 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feetORIGINAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Liner Perforation depth: measured A~chorage true vertical !20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Brilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements , Contact Engineer Name/Number: Michael Triolo, 56¢-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the/fbrecloing irCt~ue/~l~/~ ~ /~/c°rr~'~'/tr~the best of my knowledge Signed Chuck Mallary ~/~~.~/f~itle Senior Drilling Engineer Date permit Number' ~ - I APl Number _ ~-,-- __v A~)r(:~val Date__ See cover letter Conditions of Approval: Samples Required [] Yes ,~No Mud Log I~equir~'d [] Yes j~No Sulfide Measures '~Yes r-! No Directional Survey Required ,~Yes r-I No Hydrogen Required Working Pressure for BOPE [] 2K; r'l 3K; [] 4K; ]~5K; [] 10K; [] 15K by order of Approved By r',,-,,,-',~,~ ~, o~r-,~,,~-,'-, r~v Commissioner the commission Date ....... Form 10-401 Rev. 12-01-85 D Taylor Seamount Submit In Triplicate [ _~~hare. d ~ ~e~.ces ~a ~r, ll,ng BP' I:xploration / P'i~illips Alaska Inc. (. RECEIVED ',.'.,~J,',, 1 5 2.000 A~aska Oil & Gas C0~'t,~., C0ril~is~10rl ,A~chorage MPF-83i Grassroots Injector Permit Endors,~ed By~ ../, t Ops.- D rJllTng' Enginee? Senior Drilling Engineer (~' ( Date Version #1, 6/15/00 1 MPF-83i Rigsite Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control A. Abnormal pressures are present both in and sometimes above the Kuparuk reservoir zone and have required significantly higher mud weights then originally expected. II. Hydrates and Shallow gas A. There has never been any hydrates, shallow gas, or unexpected shallow hydrocarbon problems on F- pad. III. Lost Circulation/Breathing A. Lost circulation is unlikely. B. Breathing is well documented at Milne Point between the Schrader Bluff and the HRZ when ECD's reach 11.5 ppg. IV. Stuck Pipe A. We do not expect stuck pipe. V. Hydrogen Sulfide ^. MPF-Pad is not a designated H2S Pad. VI. Faults A. The planned directional trajectory crosses five faults. The two major faults have been previously crossed in MPF-81 with no problems associated with them. We expect no problems from the other three smaller faults from a drilling standpoint. CONSULT THE F PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 MPF-83i Hazards and Contingencies IWell Name: IMPF-83i Well Plan Summary Type of Well (producer or injector): I U-shaped Injector Surface Location: Target Start: 200' Radius Intermediate Bottom Hole Location: 2016' FSL (3263' FNL), 2993' FEL (2165' FWL), SEC. 06, T13N, R10E X = 541,569.03 Y - 6,035,466.40 5137' FSL (142' FNL), 3786' FEL (1492' FWL), SEC. 12, T13N, R09E X - 535,629 Y = 6,033,277 Z = 6,950' TVDss 2333' NSL (2946' FNL), 1689' FEL (3589 FWL), SEC. 02, -r13N, R09E X = 532,433 Y - 6,035,738 Z - 6,940' TVDss I AFE Number: I 337184 I I Rig: I Doyon 141 I Estimated Start Date: I July 1, 2000 I I Operating days to complete: I 31.58 I MD I 14,546' I I-rvDrkb: 16,970' I I KBE: 129.5' I Well Design (conventional, slim hole, etc.): I U-Shaped Injector (grass roots well) ! Objective: Drill 12-1/4" hole out of 20" conductor, build angle to 35° hold tangent for 2,900' to 15' TVD below the base of the Schrader Bluff Reservoir (4,817' MD; 4,205' TVDss). Run and cement 9-5/8" surface pipe to surface, drill out with 8-1/2" hole, drop angle to 30°, hold tangent for 1,200', at which time start building angle to 66°, hold tangent for 1,000', then continue to build to 70°, hold tangent for 400', continue building angle to 85°, hold tangent for 1,062', then drop angle to 75° to be lined out above the top Kuparuk B-sand (10,540' MD; 6,905' TVDss). Run and cement 7" Intermediate casing. Drill out with 6-1/8" bit, build to 90°, geosteer through the reservoir for 1,800', build up to 94°, continuing to geosteer through the reservoir to TD 14,546' MD; 6,929 TVDss, run and cement 4-1/2" production liner. The well will be left with 11.5 ppg brine. 4ES will later move onto the well to perforate and complete. The well is designed for injection support for two Tract-22 producers in the Kuparuk A sands. Asset Production/Injection Forecast: Estimated Reserves: 2.79 MMSTBO Expected Initial Rate: 3,000 BWPD Expected 6 month avg: 3,000 BWPD Well Information: Well Name: APl Number: Well Type (proposed): BHP: EMW BHT: Mechanical Condition: MPF-81 Cellar box: RKB to Cellar box: Rig Elevation: Conductor: MPF-83i U-Shaped Injector 4,215 psi @ 6,943' TVDss, top Kuparuk A sands (est. from offset wells) ~11.7ppg 165°F @ 7,000' TVDss Elevation above MSL = 11.1' 29.5' (Estimated) RKB + MSL - 40.6' 78' of 20", 54.5#, K-55 '15 2000 Alaska 0{~ & G~s Co~s, Cor~missio~ A~chccr~e Version #1, 6/15/00 2 Drilling Program Overview Surface and Anti-Collision Issues: Surface Shut-in Wells: None required. Close Approach Wells: I W ell Name None NONE - All wells may flow. I Current Status I Production P~iority I Precautions Well Control: Expected Formation Pressures & BOPE Test Pressures Expected BHP 4,215 psi, 6,943' TVDss (estimated) 11.7 ppg Max Exp Surface Pressure 3,417psl (. 115 psi/ft gas gradient) BOPE Rating 5,000 psi WP (Entire stack & valves) Planned BOPE Test Pres. 5,000/250 psi Rams and Valves 5,000/250 psi Annular Note: The wellbore will be drilled from surface to the Base Schrader Bluff through a 21-1/4", 2,000 psi surface diverter stack (expected Schrader reservoir pressure: 1,755-1,882 psi). The diverter will be removed and an 13- 5/8", 5M BOP stack will be installed and tested prior to running in the hole with the 8-1/2" drilling assembly. Mud Program: A detailed Baroid mud program is included with the well plan. In summary, an LSND water based mud system will be used for this well. Follow the attached LCM Decision Matrix for this well in the event losses occur. Surface Hole: 12 114" Hole to 4,835' MD (9 518" Casing) (Deep Set Surface - No Gas Hydrates Anticipated) Suggested Mud Properties Ranqes Density Funnel Yield 10 Sec 10 Min pH APl (ppg) Viscosity Point Gels Gels Filtrate 8.6 50 15 8 10 9 8 to to to to to to to 9.6 150 35 15 30 10 15 Intermediate Hole: 8 112" Hole to 10,540' MD (7" Casing) Suggested Mud Properties Ranqes Density Funnel Yield 10 Sec 10 Min pH (ppg) Viscosity Point Gels Gels 8.6 35 6 3 7 8.5 to to to to to to 9.6 45 20 10 20 9.5 Solids (% LGS) <9 5 2000 Alaska ~ & Gas Cons, Al~chora~e APl HTHP Solids Filtrate Filt. (cc's) (% LGS) 6-12 <6 to 4-6 10-12 (fi top HRZ) Production Hole: 6 118" Hole to 14,545' MD (4 112" Liner) Suq_qested Mud Properties Ranqes Density Funnel Yield 10 Sec 10 Min pH APl HTHP (ppg) Viscosity Point Gels Gels Filtrate Filt. (cc's) 11.5 45 20 6 7 8.5 4 10 to to to to to to to to 12.1 55 30 10 12 9.5 6 12 (200 deg. F) Solids (% LGS) <6 As the plan is currently, we will drill out of the 7" casing with an 11.5 ppg mud weight and adjust that mud weight as required by actual open hole conditions. Version #1, 6/15/00 3 Waste Disposal: No annular injection is allowed at Milne point. All drilling waste will be hauled to KRU 'IR' pad or PBU Drillsite 4. Call the Pad 4 waste disposal site prior to truck leaving location so the site can be prepared. ~.%-~, ~,~ Formation Markers: Formation Tops MD TVDss Pore EMW (ppg) Comments Pressure (psi) Base Permafrost 1906 1800 Top Schrader 4467 3915 1755 8.65 Base Schrader 4817 4205 1882 8.65 Top H RZJTU DZ 8662 6615 .~ -.~'_ C,4 ~' Base HRZ 8749 ~ ~3 KLGM 8894 TKUD (Kup Caprock) 9687 380 9.6 Pick 7" casing point by depth or LWD evaluation when at bottom of D shale, top of B sand interface. May need to nose into B sand to drill past fault. Kuparuk C NP This zone is not expected to be present. Kuparuk B 10540 6905 3447 9.6 Do not enter more than 10'-15' TVD into B sand, there may be silts that could be over-pressured to the same pressure as expected in the A sand.. Kuparuk A 10733 6943 3975-4215 11.0-11.7 TKA3 10772 6950 3980-4222 11.0-11.7 TKA2 10867 6967 3988-4230 11.0-11.7 TKA1 11011 6993 4005-4249 11.0-11.7 Miluveach NR TKA1 13671 6993 TKA2 13743 6988 TKA3 14300 6948 TKUA 14396 6940 TD 14546 6929 TKA3+ 200' MD OWC 6950 Casing/Tubing Program: Hole Size Csgl Wt/Ft Grade : Conn Casing Casing Top Hole Btm Tbg O.D. Length MD/TVDrkb MD/TVDrkb 12-1/4" 9-5/8" 40# L-80 BTC 4,830' 30?30' 4,835'/4,261' 8-1/2" 7" 26# L-80 BTC 10,540' 30?30' 10,54076,946' 6-1/8" 4-1/2" 12.6# L-80 NSCC 4,210' 10,34076,895' 14,54676,970' Cement Calculations: Icasing Size 1 9-5/8", 40#, BTC I Basis I 80' shoe jts, 30% excess ~n open hole, 250% ~n permafrost (12-1/4" hole), cement to surtace. I Shoe Depth: 4,835' MD (4,261' TVDrkb), I Total Cement Volume: I Spacer I 75 bbls of'B45 Viscosified (1.5%) Spacer Weighted to 10 ppg. I Lead I 686 sxs (540.9 bbls), ArcticSet 3 - Lite, Yield 4.43 ft3/sx, mix fluid 20.667 I ! gps, 10.7 ppg o o I Tail I 202 sxs (42.1 bbls), Class 'G' + 0.35 Yo D65 + 0.4 Yo S001 + 0.45% D167 + I I 0.2% D04~ + 0.5% D020, Yield 1.1~7 ft3/sx, mix fluid 5.1 gps, 15.8 ppg I Temp I BHST'-90 F from SOR, BHCT65 F estimated by D°well Version #1, 6/15/00 ICasing Size I 7", 26~, BTC I Basis I 80' shoe jts, 30% excess ~n open hole, cement to 1,000' above shoe. I Shoe Depth: 10,540' MD (6,946'-I-VDrkb), Total Cement Volume: I Spacer I 50 bbls of B45 Viscosifled Spacer Weighted to 1.0 ppg over MW. I Tail I 361 sxs (74.7 bbls), Class '(3' + 0.27% D065 + 0.25% D167 + 0.25% 13800 I I + 0.2% D046, Yield 1.16 ft3/sx, mix flouid 5.085 gps, 15.8 ppg I Temp I BHST ~170° F from SOR, BHCT 140 F estimated by Dowell ILiner Size 1 4-1/2", 12.6#, BTC I Basis1 80' shoe jts, 30% excess in open hole, cement to above LTPkr. I TD: 14,545' MD (6,970' TVDrkb), Liner Top Paker: 10,340' MD (6,895' TVDrkb) Total Cement Volume: Spacer I 50 bbls of B45 Viscosified Spacer Weighted to 1.0 ppg over MW. Tail1 465 sxs (96.6 bbls), Class '{3' + 0.27% D065 + 0.42% D167 + 0.22% DS00 + 0.2% D046 + 0.5% D020, Yield 1.16 ft3/sx, mix fluid 4.991 gps, 15.8 ppg Temp BHST ~170° F from SOR, BHCT 140° F estimated by Dowell 9-518" Centralizer Placement: 1. Run (1) rigid straight blade centralizer per joint on the first 28 joints. 2. Centralizers should be attached to float between the tool joints. 3. Run 1 Bow Spring centralizer on either side of the Port collar with stop collars. 7" Centralizer Placement: 4-112" Centralizer Placement: 1. Run (1) rigid straight vane centralizer per joint on the first 25 joints. 2. Centralizers should be attached to float between the tool joints. 1. Run (1) rigid straight vane centralizer per joint, do not run any in the liner lap. 2. Cent. should be run to float in the top half of the joint between a stop collar and the upper tool joint. Other Cement Considerations: 1. Mix the slurries on the fly (Batch mix if < 100 bbl). 2. Confirm blends and calculations at the rig site. .,,,;"~,~ i ,, ,.,~.~ ,~ #~ ~-~ 3. There will be a TAM Port Collar in the 9-5/8" casing at 1,000' MD for a surface ~ ~ .~ = ~ ~~, ~:,?. cement contingency plan in the event cement does not reach surface on the primary job. If cement does not reach surface, an inner-string will be run with a port collar shifting tool to engage the port collar and pump the second stage ~,!U~ '~ 5 ~000 cement job to obtain cement to surface. Survey and Logging Program: Surface Hole LWD: Surface Hole Survey: Intermediate Hole: Production Hole: Dirl{3R Drop ESS, Photo {3yro if necessary, SA{3 correction throughout entire well. DirlGRIReslPWD(real time), drop ESS. DirI{3RIReslPWD, ABI, drop ESS. Perforating: Will be perforated Post-Rig via DP- conveyed 2-7~8" guns by Nabors 4ES. Locations Kuparuk A Sands Perf Interval: Approximately 500' of perfs spread over 2,500' of wellbore {3un Size I Type: 2-7~8" (SWS), 6 SPF, 60° phasing, deep penetrating charges Delivery: Nabors 4ES DP-conveyed Under Balance: Balanced BHP: 4,215 @ 6,943' TVDss BHT: 165°F Version #1, 6/15/00 5 "Drill-Out" FIT's will be specified in the well plan. MPF-83i Operations Snapshot Summary Drill and Case Program: 1. MIRU Doyon 141. 2. NU 21-1/4" diverter, pick up 5" DP 3. MU 12-1/4" BHA, spud in drill to planned Surface hole TD (4,835' md). 4. Run 9-5~8", 40#, L-80, BTC casing and cement to surface. 5. ND diverter, NU Gen 5a wellhead & 13-5/8" BOP, test. 6. MU 8-1/2" BHA, drill out float equipment plus 30' of new formation, perform FIT (minimum 12.2 ppg EMVV). 7. Drill to planned Intermediate hole TD (10,540' md). 8. Run 7", 26~, L-80, BTC casing and cement to 1,000' above the shoe. 9. MU 6-1/8" BHA, drill out float equipment plus 30' of new formation, perform FIT (minimum 12.2 ppg EMVV). 10. Geosteer to planned Production hole TD (14,545' md). 11. Run 4-1/2", 12.6#, L-80, NSCC casing and cement (bring cement over Liner Top Paker). 12. Displace well over to 11.5 ppg brine. 13. Set TWC 14. ND BOP, NU tree, test to 5,000 15. Remove TWC, install BPV, freeze protect. 16. RD, move offweil. 4ES Completion Program: 1. MIRU Nabors 4ES 2.. RIH with perforation assembly on DP, perf, POH. 3. RIH with casing scraper on DP, POH. 4. Run injection completion on 3-1/2", NSCT tubing. 5. Land tubing, setTWC 6. ND BOP/NU Tree and test 7. Set packer,freeze protect 8. Release Rig Post Rig Work Program: 1. Pull RHC ball and rod. Formation Integrity Test Procedure: 1. Determine the required surface pressure. 2. In the case of a surface casing shoe, a PPG EMW should be sufficient unless the well plan notes differently. 3. Test the casing prior to drilling out the float collar. 3.1.].Run the mud pump at a constant 0.25m0.5 bpm and record results. One-stroke pressure readings are recommended, but in all cases record pressures in at least five-stroke increments. If the pressures are increasing rapidly enough to make this reading too large, take pressure readings at 30-second intervals. Plot the results for reference during the following LOT. 3.1.2.When the required test pressure is reached, suspend pumping and hold the test pressure for thirty minutes. Check that the test is being accurately recorded on a chart. 4. Drill remaining cement, float collar, float shoe and 20-ft to 50-ft of new hole. 4.1.1.Note: In cases where mud weight will be reduced at a minimum of 0.5 PPG after drilling out for the next hole interval, a drill out formation integrity test may be used. In this case, the 20-ft to 50-ft of new hole will be exposed to the higher mud weight and a flow check performed for a minimum of 10 minutes. If no losses are observed during the flow check, a conventional FIT is not required. The drill out FIT may only be used if stated as such in the drilling permit for the respective well Circulate and condition mud to a constant mud weight and rheology. Pull into the casing shoe. Close a blowout preventer. . 6. 7. Version #1, 6/15/00 2000 8. Run the mud pump at a constant 0.25 to 0.5 bpm. 9. Match the pump rate to the one used during the previous casing pressure test. 10. Stop the pump when the required test pressure is reached. 11. Close appropriate valves if surface leaks are suspected. 12. Hold and record the pressure every 30 seconds for 10 minutes minimum. 13. In the event that the pressure continues to bleed off without becoming constant continue to hold and record the pressures at 30 second intervals for another 5 minutes. Surface equipment should be checked for leaks and if any found the test redone. 14. Check to ensure that the chart recorder is accurately recording the test. 15. Bleed back mud from the well and compare with the volume pumped. Record volume in trip tank or cement tanks. 16. Document the FIT results on the IADC sheet and on next morning report. For consistency among rigs, use the Excel spreadsheet LOT Version 5.0 (on the Drilling File Server in the LOT folder) to plot the casing and leak off tests. Immediately send the leak-off test plot and pressure recorder charts to the office to be stored with the rest of the reports in the well file. If there is any question about the interpretation of the FIT results, inform the drilling superintendent before drilling ahead Version #1, 6/15/00 '"... ,~.,",,, 7 5 2000 7 ~.taska ~t & Gas Cmos. Co;'~r~i~ion Proposed Completion MPU F-83i TREE: 3-1/8" Cameron 5M Rev. B Based on Well Plan # 9 WELLHEAD: FMC Gen 5A 5M i i DOYEN 141 Tubing hanger: 11"X 3-1/2" Orig. KB Elev. = 29.5' i ! i ~ Orig. GLElev.= 11.1' Conductor CaingI -78' I i' '! 2o" 9,.lppf, I I i ! Ii': ii 3-1/2"X Nipple (2.813" ID) I-=0o, I · KOP @ -500' t i MAX HOLE Angle -84 to 94' AT -8,900 to 14,545' MD Surface Casing 1_4835, MD 9_5,8"140 ppf, L_80 ; ,. 3-112" ~.3 ppf, k-80, NSCT tbg. . I';;I ]1 3-1/2" X Nipple (2.813" ID) 7"x 3-1/2" Baker Packer ~10,200' ; I ~:I '3-1/2"XN Nipple (2.75" Min ID) : I Stimulation Summary ,~ none I I 7,,shoe i ~10,540, MDI ' 7" 26 ppf, L-80, Mod. Btrc. prod. casing Perforation Summary , Size SPF Interval (TVD) "U" Shapped Well Kup 'A' Sand ~_-7/8 6 500' total Drill Pipe Conveyed Heel perfs between 10,200' and 11,100' 4.5" 12.6 ppf, L-80, NSCC Toe perfs between 13,000' and 14,500' 4.5" Landing Collar (PBTD) 4.5" float collar 4.5" shoe 1~14,545' MD DATE REV. BY COMMENTS MILNE POINT UNIT 3-1-00 TC Proposed Initial Completion WELL No.: F-83i 6-15-00 MTT Proposed Completion (4ES) APl' 50-029-XXXXX BP EXPLORATION IAKI MPL~8 MPF-0.1 MPF-13 MPF-84AI M~33 MPL-19 M~3 MPL-28A MPF~5 · PF-80 IMPF-8-3~ MPL-03 KRU MPF-81 MPL-40 D. Urban 5/00 .6300 -6400 .6500 ' n 45' Fault 5' Fault 5' Fault 25' Fault NW THRZ BHRZ KLGM .6600 -6700 -6800 .6900 -7000 -7~00 TI 3'4 TKUD TKUB TKUA TMLV ~100 1250 25O0 3750 5OOO ~ 6250 II ,-- Dir @ 1.000°/100ft' 500.00ft MD, 500.00ft TVD , in Dir Rate @ 2.000°/100ft' 700.00ft MD, 699.96ft TVD 0 Scale: 1 inch: 1250ft Dir' 1935.33ft MD, 1864.91ff TVD ¢/~,,m,/~o~.f -/'~4¢U~b' f'~'~ ..... Shared ~ervices Drilling MPF-83 Wp09 in Dir Rate @ 3.000°/100ft · 1100.00fa MD, 1097.45ft TVD Current Well Properties Well: MPFo83 WPS Horizontal Coordinates: Ref. Global Coordinates: 6035466.40 N, 54 t$69.03 E Raf. Slructure Reference : 5453.24 N, 9785.26 E Ref. Geographical Coordinates: 7'0' 30' 28.1381" N, 149~ 39' 35.6102" W RKB Elevation: 40.60ff above Mean Sea Level 40.60fa above Structure Reference NOdh Reference; True North Units: Feet I .DrillQ'u. est" Proposal Data for MPF-83 WP09 Dir @ 4.000°/100ft: 3367.58ft MD, 3044.10ft TVD Dir: 3382.80ft MD, 3056.67ft TVD Vertical Origin:Well Horizontal Origin: Well Measurement Units: ff North Reference:True North ~. ~ ~ Dogleg seventy: Degrees p~l~p0ft~ ~ Vertical Section Azlmulh: 272.513~1t~'~"..~. "~[[/~. - Vertical Section Description:Well l~[ ~. ~ ~1~ Vertical Section Origin: 0.00 N,OU[~ '~ TM Measured Incl. Azlm. ~'~ertlc~l"Northlnga Eastlnga VerticalDogleg Depth ~ ~l~/ip t h Section Rate o.oo o.ooo . ~[.92i 1~ o.oo o.oo N 0.00 £ 0.00 ~oo.oo o.ooo ~2~O~F~.'xx~[II~ ~oo.oo o.oo N 0.00 F. 0.00 0.000 700.00 699.96 2.67S 2.24 W 2.12 1.000 220.000 1097.45 34.685 29.10 W 27.55 1864.90 228.23 S 274.58 W 264.31 3.000 3044.10 690.83 S 943.05 W 911.85 0.000 3056.67 695.72 S 950.08 W 918.67 4.000 235.000 4231.59 1150.28 S 1599.25 W IS47.28 0.000 23~.000 440,.,6 ,2,,.0,~ ,686.0~w ,6... 2.o00 70.000270.321 6616.27 2168.81 S 4043.16 W 3944.18 4.000 70.000270.321 6655.60 2168.20 S 4151.23 W 40~2.17 0.000 70.000270.321 6710.60 2167.36 S 4302.34 W 4203.17 0.000 84.484277.999 6740.55 2157.53 S 4433.g$ W 4335.08 12.000 84.484277.999 6842.82 2010.18 S 5482.62 W 5389.20 0.000 75.000300.321 6914.54 1883.65 S 5850.28 W 5762.06 6.000 10540.5075.000300.321 6945.60 1825.13 S 5950.34 W $864.~g 0.000 10614.557g.526304.241 6961.93 1786.56 S 6011.36 W 5927.24 8.000 11082.127g.$26304.241 7046.93 1527.86 S 6391.45 W 6318.31 0.000 11367.8gg0.g55304.020 7070.60 1368.34 S 6626.7g W 6560.42 4.000 11395~2389.861304.021 7070.41 1353.04 S 6649.46 W 6583.74 4.000 ~ 3059.91 89.861304.021 7074.45 421.65 S 8029.18 W 8002.97 0.000 13168.54g4.206303.959 7070.60 360.97 S 8119.18 W 80g$.54 4.000 14395.7994.206303.95g 6980.60 322.72 N 9134.37 W g13g.73 0.000 14545.7gg4.206303.959 6969.60 406.28 N 9258.45 W 9267.36 Single Well Target Data for MPF-83 WPS Meeaurement Untl~: fl Eaetle~a ASP Y ASP X Target Shapa 5952.19W ~t33277.t#! N J3~629.IX'iE Coordinate Target Paint TVDI~b Tt/Oea Nol~fllnga Nama Type MPFTR22#2PolyEnltyPuinl 69~X1.~1 6950.(~J 2156.1)S 9 5/8" Casing 4834.85 MD 4260,60 TVD Point A69gg.~O 69~0.1XI 21~6.13 S 5952.19 W ~13)277.al N S3S629.(Kl E n 6~.~ 6950.(~ 132).?S S 726?.55 W Nl34102.1~ N 534]IR.lEI E C 6WO.~ 6950.1Ml 173.23 N ~.21 W ~1355MT.IM) N 5321M.IMI g 6~LN) 69~().~ 833.22 N ~.SI W ~3624?.~1N 5321~.(,)E 69~.60 6950.~ I.?TN 8250.1SW ~5422.~N 6~1.~) 69~0.~ 1~2.9gS 5619A2W ~33772.(~N En~Pulm ~JS.fll ~I5.(MI 216A.2OS 4151,23W ~I~3275.(RIN Ent~Po~t 6945.~) 6~IS.IMI 1~2~.13S 5g~.34W fll))6llg.~lN ~n~ Poin~~(I.M) ~13(I.{~1 136R.34 s 6626.79 W ~134061.~RI N 53495~).1~1E fin~ Point N)?().~) ?(I)l).(KI )~.97 S M 119,18 W MI)5(I~I.IMI N ~33452.lKI E Ea~Poiflt69A0.~) 6~0.(KI 322.72N 9134.37W NI)~?3R.(MIN 532433.1HIE · ~,/Begin Dir @ 2.000°/100ft: 4800.00fa, ~'~Y,,.~,End Db.' 5000 OQf~MD, 4 ~,0.1 'JJ~ft.'L5 .... · ,~490~O~T ......... Base Schrader = 424~.60 ~ :~ MPF TR22W2 TOI P,,in, ~ Begin Dir ~ ~0~00ff: ~06 · .~ k/6200.00ff ~,%~4~9ff ~0,~ 9~%¢~'- '0 ....................... · ~;-4. -- ~ ......... /~/--- -~-- ~e~¢~ ....................... ;;;; :::::::::::::::::::::::::: '~.~* oo~a. W ' 6945. 60 TVD 7070.60 TVD 707&60 TFD oy~.eu z r~ , w ~T~ 2 - 7007, O0 TYD · ~ 2168.20 S, 4151.23 6~5.~0 ~D 1825.13 S~ 5950.34 W l ~ss. *~ .C. ss~S. ~e W 360.97S, 8119.1~ W 322. 72 N~ 913&37 W T~ l - 7033,60 TYD I I I I I I I 1250 2500 3750 5000 6250 7500 8750 ve~ic~l Sectio~ Section ~im~th: 272.513~ (True No~h) rrepared: ~hecked: ~ppro~ed: Shared Services Drilling MPF-83 Wp09 I .DrillQuest" Single Well Target Data for MPF-83 WPS Measurement UnRs: ft Coordinate Target Point TVDrkb TVDaI Northlnga Eaatlnga ASP Y ASP X Target Name Type Shape MPFTR22~21,,,ly Entryl't,im 69VlL6(1695(LO(I 2156.13S 5952.19W 60)3277.1~1N ~35629.1~lE rt,lygun ]h~unda~PuimA 69U0.60 695(1.(EI 21~6.135 5952.19W 6033277.1XIN ~35629.(R1~ 6U9(I.6ll 6US0.(RI 1323.75 S 7267.5~ W 6()341(12JgJ N 5343119.(R1~ [ 6990.6tl 6950.(KI 173.23 N 94(M.21 W 6()35~87.(81N ~32164.(NI]~ ~,)9(L61) 6,)50.(~1 X33.22 N 94(~].51 W 6036247.(~) N ~32164Jm1~ F bug(L60 6'75(L(EI 66].76 R 726),86 W ~134762.(~) N ~343(~),IHI E MPI'TR22e2T~JEnlryPoi. I ~5.6(J 6615.(10 2168.2[)~ 41~1.23W 61133275.(NIN ~7430.(~11~ ~uim MI'F TR22a'2 T,I Entry [ttlJl)l 6945.61) 6UOSA~) 1~25.]3 S 5U5(1.34 W 6033608.(Jll N 53~629.(~1E Point MPF TR22t~2 T(]2 Entry I%illl 7(170 ~(I ?030.~m 1~6n.34 S 6~26.7') W 6034061.~H~ N ~34'7~1.~m E Point Current Well Properties Well: Horizontal Coo~inates: Ref. Global Cooedinate$: Ref. Structure Reference : Re[ Geographical Coordinates: RKB Elevation: MPF-83 WPS 603~466,40 N, $41569.03 E 5453.24 N, 9785.26 E 70° 30' 28.1381" N, 149' 39' 35.8102' W 40.6Oft above Mean Sea Lavas 40,60fa above :Structure Reference NOrth Reference: True No,Ih Units: Feet o Z MPF TR22#2 6980.60 TVD 322, 72 N, -1250 -2500 -7500 -6250 -5000 -3750 -2500 -1250 0 Scale: linch = 1250ft Eastings Reference is True North -1250 -2500 1;:: 0 Z Frepared: IChecked: rPproved? North Slope Alaska Alaska State Plane 4 Milne Point MPF, Slot MPF-8~ MPF-83 WPS- MPF-83 Revised: 25 April, 2000 PROPOSAE' RT 2000 Surface Coordinates: E (70° 30' 28.1381" N, ~49° 39' 35.6~02" W) Ke~i~shing: 40.60fl aboVe Mean Sea Level Proposal Reft pro9067 2000 North Slope Alaska Measured Depth Incl. Azim. (~) 0.00 0.000 0.000 100.00 0.000 0.000 200.00 0.000 0.000 300.00 0.000 0.000 400.00 0.000 0.000 500.00 0.000 600.00 1.000 700.00 2.000 800.00 4.O00 900.00 6.000 1000.00 8.000 1100.00 10.000 1200.00 12.849 1300.00 15.754 1400.00 18.688 1500.00 21.640 1600.00 24.603 1700.00 27.573 1800.00 30.549 1900.00 33.529 1905.96 33.706 1935.33 34.582 2000.00 34.582 2100.00 34.582 2200.00 34.582 Sub-Sea Depth (ft) -40.60 59.40 159.40 259.40 359.40 Sperry-Sun Drilling Services Proposal Report for MPF-83 WPS- MPF-83 WP09 ~ ~~ Revised: 25 Apri,, 2000 ~ ~' n O Pla e 4Alaska State Milne Point MPF Vertical Local Coordinates Global Co~ordina~t~,~s Dogleg Vertical Depth Northings Eastings Northings ~ Eastings Rate Section Comment (ft) (ft) (ft) (ft) ~~ (ft) (°/100ft) (ft) 0.00 0.00 N 0.00 E ~ 541569.03 S 0.00 100.00 0.00 N 0.00 E 541569.03 E 0.000 0.00 200.00 0.00 N 0.00 E N 541569.03 E 0.000 0.00 300.00 0.00 N 0.00 N 541569.03 E 0.000 0.00 400.00 0.00 N L40 N 541569.03 E 0.000 0.00 0.000 459.40 500.00 0.00 N 220.000 559.39 599.99 0.67 S 220.000 659.36 699.96 2.67 S 220.000 759.22 799.82 6.68~S~ 5.61W 220.000 858.83 899.43 : .~ ~ 11.21W 220.000 958.08 990.68 !~2~.~ 19.04W 220.000 1056.85 1097.45 ~..~ §~ 29.10W 224.778 1154.86 1195.46 ~.~'~9.22 S 42.51W 227.832 1251.75 1292.35~~66.23 S 60.41W 229.951 1347.26 .1387.86~ 85.66 S 82.74W 231.511 1441.12 1~2= ' 107.45S 109.44W 232.712 1533.07 ~~¥' 131.54S 140.45W ,75. w 234.452 1710.28~ ~0.88 186.36 S 214.99W 235.108 1~?~ 1835.64 216.94S 258.33W 235.316 ~.82~30 1864.90 228.23 S 274.58 W 23~,.~6 ' ~77.55 1918.15 249.12 S 304.76 W 2~;6.~*~959.88 2000.48 281.42S 351.43W 6 2042.21 2082.81 313.72S 398.11W L40 N 541569.03 E 0.000 0.00 Beain Dir ~ 1.000°/100ft: 500.00ft MD, 500.00ft TVD 6035465.73 N 541568.47 E 1.000 0.53 6035463.71 N 541566.80 E 1.000 2.12 Increase in Dir Rate ~ 2.000°/100ft: 700.00~ MD, 699.96ft TVD 6035459.69 N 541563.46 E 2.000 5.31 6035452.98 N 541557.90 E 2.000 10.61 6035443.60 N 541550.11E 2.000 18.03 6035431.56 N 541540.13 E 2.000 27.55 6035416.94 N 541526.79 E 3.000 40.31 6035399.83 N 541508.99 E 3.000 57.45 6035380.28 N 541486.77 E 3.000 78.91 6035358.34 N 541460.19 E 3.000 104.63 6035334.08 N 541429.32 E 3.000 134.54 6035307.55 N 541394.26 E 3.000 168.57 6035278.84 N 541355.09 E 3.000 206.61 6035248.01 N 541311.92 E 3.000 248.57 6035246.11N 541309.22 E 3.000 251.19 6035236.64 N 541295.73 E 3.000 264.31 6035215.58 N 541265.67 E 0.000 293.55 6035183.02 N 541219.18 E 0.000 338.76 6035150.46 N 541172.68 E 0.000 383.97 Increase In Dir Rate ~ 3.000°/100ft: 1100.0'0'ft MD, 1097.45ft TVD B permafrost End Dir: 1935.33ft MD, 1864.91ff TVD Continued... ~2 May, 2000.9:27 - 2 - DrillQuest ~.05.04c North Slope Alaska Measured Depth Incl. Azim, (fi) 2300.00 34.582 235.316 2400.00 34.582 235.316 2500.00 34.582 235.316 2600.00 34.582 235.316 2700.00 34.582 235.316 2800.00 34.582 235.316 2900.00 34.582 235.316 3000.00 34.582 235.316 3100.00 34.582 235.316 3200.00 34.582 235.316 3300.00 34.582 235.316 3367.58 34.582 235.316 3382.80 34.000 3400.00 34.000 3500.00 34.000 3600.00 34.000 3700.00 34.000 3800.00 34.000 3900.00 34.000 4000.00 34.000 4100.00 34.000 4200.00 34.000 4300.00 34.000 4400.00 34.000 4467.10 34.000 Sub-Sea Depth (fi) 2124.55 2206.88 2289.21 2371.54 2453.87 Sperry-Sun Drilling Services Proposal Report for MPF-83 WPS' MPF-83 WP09 Revised: 25 April, 2000 O Alaska State Plane 4 din~~s Milne Point MPF le Vertical Vertical Local Coordinates Global Coor g g Depth Northings Eastings N ° i~t~ng s "i~ Ea ~in gs~~ (ft) (°Rate/100ft Section Comment (ft) (f~) (ft) ) (ft) 2165.15 346.01 S 444.78 W 6035 _~.,9p ~ 541126.19 E 0.000 429.18 2247.48 378.31 S 491.45 W 6035~85 ~l!i;. · ~i~ 541079.70 E 0.000 474.39 2536.20 2576.80 2618.53 2659.13 2700.87 2741.47 2783.20 2823.80 2865.53 2906.13 2329.81 410.61S 538.13W 6~35~78 N 541033.21E 0.000 519.60 2412.14 442,91S 584.80W¢ ~03~.~2~.23N 540986.72E 0,000 564.82 2494.47 475.21 S 631.47~~03~1~87.67 N 540940.23 E 0.000 610.03 678..~,~~034955.11N 0.000 655.24 o.ooo oo.4 ~ 6034889.99N 0.000 745.66 0.000 790.87 0.000 836.09 507.51S 539.80 S 72~ 604.40 S 636.70~ ' , ~0~8'3~8~ ~ 943.05 W ~~ 950.08 W 957.96 W 1003.77 W 1049.58W 1095.38W 1141.19W 1187.00W 1232.80W 1278.61 W 1324.42 W 1370.22 W i416.03 W 1446.76 W 2947.86 2988.46 3003.50 3044.10 235.000 3016.07 3056.67 6! 235.000 3030.33 3070.93 ~701.24 S 235.000 3113.24 3153~84 ¢~33.31 S 235.000 3196.14 3236.74~¢~~ 765.39 S 235.000 3279.05 3319!~~ 797.46 S 235.000 3361.95 3~02;~5 829.54 S 235.000 3444.85 ~~8' 861.61 S 235.000 3527.76 E ~$88.36 893.68 S 235.000 3610.8~. -'3651.26 925. 6 235.000 ~9~..5.¢~ 3734.16 957.83 S 235.000 ~_ _'~ 3817.07 989.91 S 235.000 2':~,3.¢§~ 3899.97 1021.98 S 23~00'~.,~ 1~0 3955.60 1043.50 S 540893.74 E 540847.25 E 540800.75 E 6034857.43 N 540754.26 E 6034824.87 N 540707.77 E 6034792.31 N 540661,28 E 0.000 881.30 6034770.31 N 540629.86 E 0.000 911.85 6034765.37 N 540622.85 E 4.000 918.67 6034759.81 N 540615.00 E 0.000 926.30 6034727.48 N 540569.38 E 0.000 970.65 Bealn Dir~4.000°/100ff: 3367.58fflV3D, 3044,10ffTVD End Dir:3382,80ftMD, 3056.67ffTVD 6034695.15 N 540523.75 E 0.000 1015.01 6034662.82 N 540478.13 E 0.000 1059.37 6034630.49 N 540432.50 E 0.000 1103.72 6034598.16 N 540386.87 E 0.000 1148.08 6034565.83 N 540341.25 E 0,000 1192.43 6034533.50 N 540295.62 E 0.000 1236.79 6034501.17 N 540249.99 E 0.000 1281.15 6034468.84 N 540204.37 E 0.000 1325.50 6034436.51 N 540158.74 E 0.000 1369.86 6034414.82 N 540128.13 E 0.000 1399.62 Schrader NA Continued.,. ~2 May, 2000.9:27 - 3 - DrillQuest ~.05,04c North Slope Alaska Measured Depth Incl, (fi) 4500.00 34.000 4600,00 34,000 4700,00 34,000 4800,00 34,000 4816,87 33,663 4834,85 33,303 4900,00 32,000 5000,00 30.000 5100.00 30.000 5200,00 30.000 5300.00 30.000 5400.00 30.000 5500.00 30.000 5600.00 30.000 5700.00 30.000 5800.00 30.000 5900.00 30.000 6000.00 30.000 6100.00 30.000 6200.00 30.000 6300.00 33.645 6400.00 37.355 6500.00 41.112 6600.00 44.904 6700.00 48.723 Sub-Sea Azim, Depth (fi) 235.000 3942,28 235,000 4025,18 235,000 4108,08 235,000 4190,99 235,000 4205.00 235,000 4220,00 235,000 4274,85 235,000 4360,56 Sperry-Sun Drilling Services Proposal Report for MPF-83 WPS - MPF-83 WP09 Revised: 25 April, 2000 ~ji~~~ Alaska State Plane 4 '~' Milne Point MPF Vertical Local Coordinates Global C~oordin~{~s ' Dogleg Vertical Depth Northings Eastings Northings ~ Eastings Rate Section Comment (ft) (m (ft) 3982,88 1054,05 S 1461,84 W I1~ 540113,12 E 0,000 1414.21 4065.78 1086.13 S 1507.64W 540067.49 E 0.000 1458.57 4148.68 1118.20 S 1553.45W N 540021.86 E 0.000 1502.93 4231.59 1150.28 S 1599.25W~ N 539976.24 E 0.000 1547.28 4245.60 1155.66 S ~01.76 N 539968.57 E 2.000 1554.73 4260.60 1161.35 S 6034296.03 N 539960.48 E 2.000 1562.60 4315.45 1181.51S 6034275.71N 539931.80 E 2.000 1590.48 4401,16 1211.05 S 6034245.93 N 539889.78 E 2.000 1631.33 235.000 4447.16 4487.76 235.000 4533.77 4574.37 235.000 4620.37 4660.97 235.000 4706.97 4747.57 235.000 4793.57 4834.17 235.000 4880.18 4920.78 235.000 4966.78 5007.38 235,000 5053,38 5093,98? 235,000 5139,98 235.000 5226.59 52~.~9 235,000 5313,19 235.000 5399.79 238,129 54_._~:8~_~5% 5525,35 240,707 55~i~ '~ 5606,75 242,879 ~', 6~ 5684,20 244,746~:~ i'~ 5757,32 W 6034217.02 N 539848.98 E 0.000 1670.99 1767.97W 6034188.12 N 539808.19 E 0.000 1710.65 1808.93W 6034159.21N 539767.39 E 0.000 1750.31 1849.88W 6034130.30 N 539726.59 E 0.000 1789.98 1890.84W 6034101.39 N 539685.80 E 0.000 1829.64 ~83.13 S 1931.80W 6034072.48 N 539645.00 E 0.000 1869.30 .81 S 1972.76W 6034043.58 N 539604.20 E 0.000 1908.96 1440.48 S 2013.71W 6034014.67 N 539563.41 E 0.000 1948.62 1469.16 S 2054.67W 6033985.76 N 539522.61 E 0.000 1988.28 1497.84 S 2095.63W 6033956.85 N 539481.81 E 0.000 2027.94 1526.52 S 2136.59W 6033927.95 N 539441.02 E 0.000 2067.60 1555.20 S 2177.55W 6033899.04 N 539400.22 E 0.000 2107.26 1584.18 S 2221.57W 6033869.82 N 539356.36 E 4.000 2149.97 1613.66 S 2271.57W 6033840.05 N 539306.52 E 4.000 2198.64 1643.50 S 2327.32W 6033809.90 N 539250.95 E 4.000 2253.02 1673.56 S 2388.53W 6033779.50 N 539189.91E 4.000 2312.85 1703.69 S 2454.90W 6033749.00 N 539123.70 E 4.000 2377.84 Beatn Dtr ~. 2 000°/100ft: 480'0.00ft IV3D, ~,231.59ft TVD Base Schrader 9 5/8" Casing End Dir: 5000.00ft MD, 4401.16ft TVD Beeln Dir ~ 4.000°/100ft: 6200.00ft rv3D, 5440.39ft TVD Continued... 12 May, 2000 - 9:27 - 4. DrillQuest f.05.04c North Slope Alaska Measured Sub-Sea Depth Incl. Azim, Depth (~) (~) 6800.00 52,563 247,832 5848.55 6900.00 56.418 249,142 5906.62 7000.00 60,286 250.339 5959.08 7100,00 64.164 251,448 6005.68 7155.95 66.337 252,036 6029.10 7200.00 66.337 252.036 6046.78 7300.00 66.337 252.036 6086.91 7400.00 66,337 252.036 6127.05 7500.00 66.337 252,036 6167,18 7600,00 66.337 252,036 6207.32 7700,00 66.337 252,036 6247.45 7800,00 66.337 252.036 6287.59 7900.00 66.337 252,036 6327.72 8000.00 66,337 252.036 6367.86 8100.00 66.337 252,036 6407.99 8112.98 66,337 252.036 6413.20 8200.00 66.906 8300.00 67.666 8400.00 68.536 8500.00 69.511 8546.74 70.000 8600.00 70.000 8661.74 70.000 8700,00 70,000 8749.45 70.000 Sperry-Sun Drilling Services Proposal RePort for MPF-83 WPS - MPF-83 WP09 ~ ~~ ' 0 ~ Revised: 25 April, 200 ~1~O.~ Alaska State Plane 4 ~ Milne Point MPF Vertical Local Coordinates Global Qoordin~i~,e~s Dogleg Vertical Depth Northings Eastings Northings ~ Eastings Rate Section Comment (ft) (ft) (ft) (ft) ~ii> (ft) (o/looft) (ft) 5889.15 ' 1733.74 S 2526.13 W ~ 539052,64 S 4,000 2447.68 5947.22 1763.56 S 2601.85 VV 538977.09 E 4,000 2522.02 5999.68 1793.01 S 2681.70 VV N 538897.40 E 4,000 2600,50 6046.28 1821.95 S 2765.29 VV~ N 538813.98 E 4,000 2682,75 6069.70 1837.87 S N 538765.82 E 4,000 2730.25 End Dir: 7155.95ft MD, 6069.70ft TVD 255,777 6447.74 260,035 6486.37 6526:9~ 264.243 6523.68 ~.656~- 268.398 6559.49 '~¢~861627 270.321 6575.'8; . 270,321'6~9~3''~6634.48 2~0.321~§628.09 6668.69 2~'!~2~,i '~45,00 6685.60 6087.38 1850.31S 6033600.16 N 538727.51 E 0.000 2768.05 6127.51 1878.56 S 6033571.42 N 538640.54 E 0.000 2853.86 6167.65 1906.81 S 6033542.68 N 538553.57 E 0.000 2939.66 6207.78 1935.06 S ~.¢. W 6033513.95 N 538466.60 E 0.000 3025.47 6247.92 1963.31~S%~,;~,,~ '~.'~, 43 W 6033485.21 N 538379.64 E 0.000 3111.27 6288.05 19,9~5~S~ 3287.56 W 6033456.48 N 538292.67 E 0.000 3197.08 6328.19 2'~9.81'~ TM 3374.69 W 6033427.74 N 538205.70 E 0.000 3282.88 20~!0,6¢~¢_ -'*~ -- 3461.81 W 6033399.00 N 538118.73 E 0.000 3368.68 6368.32 6408.46 ~¢= 2076~%~ 3548.94 W 6033370.27 N 538031.76 E 0.000 3454.49 ,,d'~ ~:2~104.56 S 3636.07 W 6033341.53 N 537944.80 E 6448,59 ~ ~; 0,000 3540.29 ¢~ ~2108.22 S 3647,38 W 6453.8~ 6033337.80 N 537933.51 E 0.000 3551.43 6488~3~ 2130,35 S 3724.11 W 6033315.24 N 537856.90 E 4.000 3627.12 2149.66 S 3814.28 W 6033295.43 N 537766.84 E 4.000 3716.36 2162.34 S 3906.16 W 6033282.23 N 537675.03 E 4.000 3807.60 2168.32 S 3999.32 W 6033275.73 N 537S81.91 E 4.000 3900.40 2168.81 S 4043.16 W 6033275.00 N 537538.06 E 4.000 3944.18 2168.53 S 4093.21 W 6033275.00 N 537488.02 E 0.000 3994.19 2168.20 S 4151.23 W 6033275.00 N 537430.00 E 0.000 4052.17 2168.00 S 4187.18 W 6033275.00 N 537394.05 E 0.000 4088.10 2167.74 S 4233.65 W 6033275.00 N 537347.58 E 0.000 4134.~3 Becin Dir ~ 4.000°/100ft: 81 f2.98ft IV'E), 6453.80ft TVD End Dir: 8546.74ft MD, 6616.27ft TVD THRZ/TUDZ Target - MPF TR22#2 TOO BHRZ Continued.., ~2 May, 2000 - 9:27 - 5 - DrillQuest ~.05.04c North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 8800.00 70.000 270.321 6662.29 6702.89 8822.55 70.000 270.321 6670.00 6710.60 8894.32 77.628 274.488 6690.00 6730.60 8900.00 78.235 274.805 6691.19 6731.79 8958.34 84.484 277.999 6699.95 6740.55 9000.00 84.484 277.999 6703.95 6744.55 9100.00 84.484 277.999 6713.57 6754.17 9200.00 84.484 277.999 6723.18 6763.78 9300.00 84.484 277.999 6732.79 6773.39 9400.00 84.484 277.999 6742.40 6783.00 9500.00 84.484 277.999 6752.02 9600.00 84.484 277.999 6761.63 9687.07 84.484 277.999 6770.00 9700.00 84.484 277,999 6771,24 9800.00 84.484 277.999 6780.86 9900.00 84.484 277.999 10000.00 84.484 277.999 10022.24 84.484 277.999 10100.00 82.523 282.260 10200.00 80.063 287.797 10300.00 77.696 10400.00 75.445 10420.50 75.000 10500.00 75.000 10540.50 75.000 293.416 299.135 300 321 ;~¢~j;~ '~,~. 300.321 ~ ........8~94.~2 3 ..... 05.00 6790.47 6800.08 6914.54 Nothings Eastings Nothings ~ Eastings (~) (~) (~) ~~ (~) (°/~00~) 2167.48S 4281.15W 6033~~- 537300.08E 0.000 2167.36 S 4302.34W 603~~ 537278.89 E 0.000 2164.42 S 4371.13W~ ~27~."55 N 537210,08 E 12.000 2163.97S 4376.67,~.~'~77.97N 537204.54E 12.000 2157 53S 4433.9 ~ ~ .~60~284.09 N 537147.23 E 12.000 6033289.63 N 537106.13 E 0.000 2151,76 S 447 2137.91S ,4~8~V~' 6033302.93 N 537007.48 E 0.000 2124.06S ~'...¢~15W 6033316.23N 536908.84E 0.000 2110.2l.S ~~2W 6033329.53N 536810.19 E 0.000 209636~S~,~.~486929W 6033342.83N 536711.55 E 0.000 6802.23 2~6~ 5066.42W 6033369.42N 536514.26E 0.000 6810.60 ~ 205~0~ 5152.25W 6033381.00 N 536428.37 E 0.000 6811.84 ,;~_~54.8~ S 5164.99W 6033382.72 N 536415.62 E 0.000 6821.46 ~, 2~0.96 S 5263.56W 6033396.02 N 536316.97 E 0.000 6831.0~ ~., 2027.11S 6840~6~r 2013.25 S 2010.18 S 6935.12 6945.60 Rate Section Comment 1996.60 S 1970.99 S 1936.49 S 1893.48 S 1883.65 S 1844.88 S 1825,13 S 5362.13W 6033409.32 N 536218.33 E 0.000 5460.70W 6033422.62 N 536119.68 E 0.000 5482.62W 6033425.58 N 536097.75 E 0.000 5558.66W 6033438.73 N 536021.63 E 6.000 5654.08W 6033463.80 N 535926.07 E 6.000 5745.89W 6033497.78 N 535834.07 E 6.000 5833.07W 6033540.31 N 535746.65 E 6.000 5850.28W 6033550.04 N 535729.38 E 6.000 5916.57W 6033588.44 N 535662.88 E 0.000 5950.34W 6033608.00 N 535629.00 E 0.000 4182.00 4203.17 4272.03 4277.58 4335.08 4376.36 4475.44 4574.53 4673.61 4772.69 4871.77 4970.85 5057.12 5069.93 5169.01 5268.09 5367.17 5389.20 5465.77 5562.22 5655.45 5744.43 5762.06 5829.98 5864.59 Be_~in Dir (~. 12.000°/100ft: 8822.55ft tv3D, 6710.60ft TVD KLGM End Dir: 8958,34ft MD, 6740.55ft TVD TKUD Bealn Dir C~. 6.000°/100ft: 10022.24ft'E,1D, 6842.82ft TVD End Dir: 10420,50ft MD, 6914.54ft TVD Beain Dir (~. 8,000°/100ft: 10540.50ftTvlD, 6945.60ft TVD 7" Liner TKup ~ arget - MPF T~.f~uTe(~...' ~ 2 May, 2000 - 9:27 - 6 - DrillQuest '1.05.04c North Slope Alaska Measured Depth Incl. (fi) 10600.00 78.632 10614.55 79.526 10700.00 79.526 10800.00 79,526 10900.00 79.526 11000.00 79.526 11082,12 79.526 11100.00 80,241 11200.00 84.240 11300.00 88,240 11367.89 90.955 11395.23 89.861 11400.00 89.861 11500.00 89.861 11600.00 89.861 11700.00 89.861 11800.00 89.861 11900.00 89,861 12000.00 89.861 12100.00 89.861 12200.00 89.861 12300.00 89.861 12400.00 89,861 12500.00 89.861 12600.00 89.861 Sperry-Sun Drilling Services Proposal Report for MPF-83 WPS- MPF-83 WP09 .~ ~~ Revised: 25 April, 2000 O Alaska State Plane 4 · ~ Milne Point MPF ~ le Vertical Sub-Sea Vertical Local Coordinates Global ,r Dog g Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 303.481 6918.57 6959.17 1794.52 S 5999.49 W 6033( t l 535579.67 E 8.000 5915.04 304.241 6921.33 6961.93 1786.56 S 6011.36 W 535567.76 E 8.000 5927.24 End Dir: 10614.55ft MD, 6961.93ft TVD 304.241 6936.86 6977.46 1739.28 S 6080.82W ~2 N 535498.04 E 0.000 5998.71 304.241 6955.04 6995.64 1683.95 S 6162.11 L00 N 535416.44 E 0.000 6082.35 304.241 6973.22 7013.82 1628.62 S 3802.87 N 535334.84 E 0.000 6165.99 304.241 6991.40 7032.00 1573.29 S 6033857.74 N 535253.24 E 0.000 6249.63 304.241 7006.33 7046.93 1527.86 S 6033902.80 N 535186.23 E 0.000 6318.31 304.227 7009.47 7050.07 1517.95 S ..~ )OW 304.149 7022.97 7063,57 1462.29~S .~¢ W 304.072 7029.52 7070.12 1406.34*¢Sj~6570.55w 304.020 7030.00 7070.60 1368.34 $~ ~ 6626.79w 304,021 7029.81 7070.41 1~:~.04.~ 6649.46w 0.3~ 304.021 7029,82 7070.42 ~:135 s 6653.41w 304.02t 7030.06 7070.66 .~.~,.-~!~294.42 s 6736.29w 304.021 7030.30 7070.90~,.~38.47s 6819.17w 304,021 7030.55 707~~ 1182.52 s 6902.06w 304.021 7030,79 ~0~.1~39~ 1126.57s 6984.94w 304.021 7031.03 .¢b~4ii~ 1070.62s 7067.82w 304.021 7031.28 ~?¢~71.8~ 1014.67s 7150.70w 304.021 7031.52~.~2,12 958.72s 7233.59w 304.021 7~.~6~ 7072.36 902.77s 7316.47w 304.021 .,.[¢2~: 7072.61 846.82s 7399.35w 304.021 ~,,~7~2~ 7072.85 790.87 s 7482.23w 304.021~'~:~3~9 7073,09 734.92s 7565.12w 304,02~¢~32.73 7073.33 678.97S 7648.00W 6033912.63 N 535171.62 E 4.000 6333.28 6033967.83 N 535089.37 E 4.000 6417.59 6034023.31 N 535006.45 E 4.000 6502.57 6034061.00 N 534950.00 E 4.000 6560.42 6034076.17 N 534927.25 E 4.000 6583.74 6034078.82 N 534923.28 E 0.000 6687.80 6034134.30 N 534840.09 E 0.000 6673.06 6034189.79 N 534756.89 E 0.000 6758.31 6034245.27 N 534673.70 E 0.000 6843.57 6034300.76 N 534590.51 E 0.000 6928.82 6034356.25 N 534507.31 E 0.000 7014.08 6034411.73 N 534424.12 E 0.000 7099.34 6034467.22 N 534340.92 E 0.000 7184.59 6034522.70 N 534257.73 E 0.000 7269.85 6034578.19 N 534174.53 E 0.000 7355.11 6034633.67 N 534091.34 E 0.000 7440.36 6034689.16 N 534008.14 E 0.000 7525.62 6034744.64 N 533924.95 E 0.000 7610.87 Be~tn Dtr(~.4,000°/100ff: 11082.12ffTvlD, 7046.93ffTVD Target - MPF TR22#2 T02 End Dir: 11395.23ff MD, 7070.41ft TVD Continued... ~2 May, 2000 - 9:27 - 7 - DrillQuest ~.05.04c North Slope Alaska Measured Sub-Sea Depth Incl. Azim, Depth (~) (~) 12700.00 89.861 304.021 7032.98 12800.00 89.861 304.021 7033.22 12900.00 89.861 304.021 7033.46 13000.00 89.861 304.021 7033.71 13059.91 89.861 304.021 7033.85 13100.00 91.464 303,998 7033.39 13168.54 94.206 303.959 7030.00 13200.00 94.206 303.959 7027.69 13300.00 94.206 303.959 7020.36 13400.00 94.206 303.959 7013.03 13500.00 94.206 303.959 7005.69 13600.00 94.206 303.959 6998.36 13700.00 94.206 303.959 6991.03 13800.00 94.206 303.959 6983.69 13900.00 94.206 303.959 6976.36 14000.00 94.206 303.959 6969.03 14100.00 94.206 303.959 6961.69 14200,00 94.206 303.959 6954.36 14300.00 94.206 303.959 14395.79 94.206 303.959 14400.00 94.206 14500.00 94.206 14545.79 94.206 303.959 303.959 303.959 ~,692~00 6947.02 ¢' '¢~'6='987.62 6940.0Q~ ~80.60 6939~69~ 6980.29 6~i~'2'~" 6972.96 6969.60 Sperry-Sun Drilling Services ,, Proposal Report for MPF-83 WPS - MPF-83 WP09 ~*~~ Revised: 25 April, 2000 ~%~ ~O.,~,,.. Alaska State Plane 4 '~t~~ Milne Point MPF Vertical Local Coordinates Global Cp. ordin~t~s Dogleg Vertical Depth Northings Eastings Northings ~Eastings Rate Section Comment (ft) (ft) (ft) (ft) ~}~%- (ft) (o/~ooft) (ft) 7073,58 623.02 S 7730.88 W 6034800;~3~ 533841,76 E 0,000 7696.13 7073,82 567,07 S 7813.76 W 6034855.61~ 533758.56 E 0.000 7781.39 7074.06 511.12 S 7896.65 W 6~9~ 0 N 533675.37 E 0.000 7866.64 7074.31 455.17 S 7979.53 V~¢ ~0~-~6~58 N 533592.17 E 0.000 7951.90 7074.45 421.65 S 8029.18.,YV ~. "~034~99.83 N 533542.33 E 0.000 8002.97 8062rt~:i~VV~.~¢O' 6035022.06 N 7073.99 399.23 S 7070.60 360.97 S ~1..1~8~ 6035060.00 N 343 45 S 0 ~14.~20W 6035077.38 N 7068.29 · , 7060.96 287.74'~S~.=~.%~ 8227.92W 6035132.62 N 7053.63 232:,03~x~ '~'8310.64W 6035187.87N 7046.29 ~¢32 S~ 8393.36W 6035243.12 U 7038.96 . 12~{~' 8476.08W 6035298.36N 7031.63 '%~ 64.~8S 8558.80w 6035353.61N 7024 29 ¢ii?%i~ 9.19 S 8641.52 W 6035408.85 N 7016.96 ¢~ ~,~ 46.52 N 8724.24W 6035464.10 N 7009;6~:~?~i 102.23 N 8806.96W 6035519.34 N 700~9~*~"~ 157.93 N 8889.68W 6035574.59 N ...... ~994;9¢ 213.64 N 8972.41W 6035629.83 N 269.35 N 9055.13W 6035685.08 N 322.72 N 9134.37W 6035738.00 N 533508.98 E 4.000 8037.16 533452.00 E 4.000 8095.54 533425.88 E 0.000 8122.31 533342.85 E 0.000 8207.39 533259.82 E 0,000 8292.47 533176.79 E 0.000 8377.56 533093.76 E 0.000 8462.64 533010.73 E 0.000 8547.73 532927.69 E 0.000 8632.81 532844.66 E 0.000 8717.89 532761.63 E 0.000 8802.98 532678.60 E 0.000 8888.06 532595.57 E 0.000 8973.14 532512.54 E 0,000 9058.23 532433.00 E 0.000 9139.73 Beein Dtr(~.4.000°/100ft 13059.91ff'I~ID, 7074.45ff;rVD End Dir: 13168.54ff MD, 7070 60ft TVD Target - MPF TR22#2 T03 Target - MPF TR22#2 T04 325.06 N 9137.85W 6035740,32 N 380.77 N 9220.57W 6035795.57 N 406.28 N 9258.45W 6035820.87 N 532429.51 E 0.000 9143.31 532346.48 E 0.000 9228,40 532308.46 E 0.000 9267.36 Total Depth: 14545,79ft MD, 6969.60ft TVD 4 1/2" Liner Continued... ~ 2 May, 2000 - 9:27 - 8 - DrillQuest ~.05,04c Sperry-Sun Drilling Services Proposal Report for MPF-83 WPS - MPF-83 WP09 Revised: 25April, 2000 ~ X~~%~ North Slope Alaska All data is in feet unless otherwise stated. Directions and coordinates are relative to True NoAh. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Alaska State Plane 4 Milne Point MPF The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 272.513° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 1 The Bottom Hole Displacement is 9267.36ft., in the Direction of 272.513° Comments Measured Depth (fi) 5O0.OO 700.00 1100.00 1935.33 3367.58 3382.80 480O.0O 5000.00 6200.00 7155.95 8112.98 8546.74 8822.55 8958.34 10022.24 Station Coordinates ~ ~..~ TVD Northings Eastings C~omme~t (ft) (ft) (ft) <a, '~ 500.00 0.00 N 0.00 E~Begin Dir @ 1.000°/100ft: 500.00ft MD, 500.00ft TVD 699.96 2.67 S 2.24 W~...~f~rease in Dir Rate @ 2.000°/100ft: 700.00ft MD, 699.96ft TVD 1097.45 34.68 S 29. ~0~~increase in Dir Rate @ 3.000°/100ft: 1100.00ft MD, 1097.45ft TVD 1864.91 228.23 S 2~4.~ End Dir: 1935.33ft MD, 1864.91ft TVD 3044.10 690.83 S 94~.0~'~~' Begin Dir @ 4.000°/100ft: 3367.58ft MD, 3044.10ft TVD 3056.67 695.72 S ~95~9 W End Dir: 3382.80ft MD, 3056.67ft TVD 4231.59 1150.28 S~ ~.. _~99.25 W Begin Dir @ 2.000°/100ft: 4800.00ft MD, 4231.59ft TVD 4401.16 1211.05 S:~. ~686.05 W End Dir: 5000.00ft MD, 4401.16ft TVD 5440.39 1555,~% 2177.55 W Begin Dir @ 4.000°/100ft: 6200.00ft MD, 5440.39ft 'I'VD 6069.70 183~"~ ' 2813.54 W End Dir: 7155.95ft MD, 6069.70ft TVD 6453.80 ,;~'~08,-~¢ 3647.38 W Begin DJ, @ 4.000°/100ff: 8112.98ft MD, 6453.80ft TVD 6616.27 ~ ~;~1,6'~8~81 ',§e 4043.17 W End Dir: 8546.74ft MD, 6616.27ft TVD 6710 60~::~. "~6~ 36 S 4302.34 W Beg n Dir @ 12.000°I100ft: 8822.55ft MD, 6710.60ft TVD 6740155 ~~1~153 S 4433.95 W End Dir: 8958.34ft MD, 6740.55ft TVD 6842.82 ~ 2010.17 S 5482.62 W Begin Dir @ 6.000°/100ft: 10022.24ft MD, 6842.82ft TVD Continued... ~2 May, 2000 - 9:27 - 9. DrillQuest ~.05.04c Sperry-Sun Drilling Services :,,~:~,,~ ~,~';~ ~-~ ~ 4~-~ :~:¥~,~ ~'~,~:~ Proposal Repo~ for MPF-83 WPS - MPF-83 WP09 ::~ ~'~:~?~ Revised: 25 April, 2000 0 Alaska State Plane 4 No~h Slope Alaska ~~ Milne Point MPF Measured Station Coordinates Depth ~D Northings Eastings Comment (~) (fi) (~) (~) Comments (Continued) ~ 0420.50 6914.54 1883.65 s 5850.28 w End Dir: 10420.50E MD, 69~4~5~~ 10540.50 6945.60 ~825.13 S 5950.33 W Begin Dir ~ 8,000°/100~~D, 6945.60~ ~D ~0~4.~ ~,~3 ~7~6.56 s ~0~.3~ w En~ D~r: ~06~4.5~ MD, ~:93~D 11082.12 7046.93 1527.85 S 6391.45 W Begin Dir ~ 4.000°/100~: 1~8~2.12~ MD, 7046.93E ~D ~ ~3~5.23 7070.4~ ~353.04 S ~40.45 W End Dir: ~ ~3~5.23~ ~0,4~ W ~305~.~ 7074.45 42~.~5 S 8020.~8 W ~o~in ~ir ~ ~0~0~: ~3050.0~ W *otal D~p~45.70~ MD, ~0~0.~0~ ~4545.7~ ~.~0 40~,28 ~ ~258.45 ~" ~. Nothings ~ings Formation Name (~) '~(~) Formation Tops Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) 1905.96 1840,60 1800.00 21 261,04 W B permafrost 4467,10 3955.60 3915.00 104; 1446,76 W Schrader NA 4816,87 4245.60 4205.00 1606,95 W Base Schrader 8661.74 6655.60 6615.00 .~ S 4151,23 W THRZ/TUDZ 8749.45 6685.60 6645,00 S 4233,65 VV BHRZ 8894,32 6730,60 6690.00 S 4371,13 VV KLGM 9687,07 6810,60 2056,60 S 5152,25 W TKUD 10540.50 6945,60 69~ 1825,13 S 5950.34 W Kup B Continued,,, 12 May, 2000 - 9:27 - 10 - DrillQuest f.05.04c North Slope Alaska Sperry-Sun Drilling Services Proposal Report for MPF-83 WPS - MPF-83 WP09 Revised: 25 April, 2000 Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) <Surface> <Surface> 4834.85 4260,60 <Surface> <Surface> 10540.50 6945.60 <Surface> <Surface> 14545.79 6969.60 Targets associated with this wellpath Target Name MPF TR22#2 Poly MPF TR22#2 TOO MPF TR22#2 T01 MPF TR22#2 T02 MPF TR22#2 T03 Casing Detail 5/8" Casing 7" Liner 1/2" Liner Me;!'~~ob 'ii Coordinates: ~ ~Geographical Coordinates: '~:, ~i~n Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 6990.60 2156.13 S 5952.19W 6950.00 6033277.00 N 535~29.00 E 70° 30'06.9077"N 149° 42'30.8762"W 6655.60 2168.20 S 4151,23W 6615.00 6033275.00 N 537430.00 E 70° 30'06.8009"N 149° 41' 37.8466"W 6945.60 1825.13 S 5950.34W 6905.00 6033608.00 N 535629.00 E 70° 30'10,1632"N 149° 42'30,8295"W 7070.60 1368.34 S 6626.79W 7030.00 6034061,00 N 534950.00 E 70° 30'14.6505"N 149° 42'50.7610"W 7070.60 360.97 S 8119.18W 7030.00 6035060.00 N 533452.00 E 70° 30'24.5440"N 149°43'34.7423"W Alaska State Plane 4 Milne Point MPF Target Target Shape Type Polygon Point Point Point Point Continued... 12 May, 2000.9:27 - '1~ - DrillQuest 'h05.04c North Slope Alaska Target Name Sperry-Sun Drilling Services Proposal Report for MPF-83 WPS - MPF-83 WP09 .~ ~~ Revised: 25 April, 2000 Target oordinate~ TVD ~rthings Eastings (ft) (ft) Alaska State Plane 4 Milne Point MPF Target Target Shape Type Targets associated with this wellpath (Continued) MPF TR22#2 T04 Mean Sea Level/Global Geograr 322.72 N 6035738.00 N 70° 30' 31.2570" N 9134.37 W 532433.00 E 149° 44' 04.6672" W Point May, 2000 - 9:27 . f2 - DrillQuest 1.05.04c 10016~4~4 I H 169424 VENDOR AL ~,~KA~;TAT 10 DATE INVOICE / CREOIT MEMO DESCRIPTION GROSS DISCOUNT NET )52&00 CKO52&O0 100. O0 100. O0 HANDLING INST: s/h tea-rte x 462EI : CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. AI'rACHED ANCHORAGE: AK: ~50:1 FIELD & POOL ;~"2-- '~'¢/(~(~ INIT CLASS ADMINISTRATION 1. 2. APPR . 4. 5. 6. 7. 8. 9. 10. 11. DATE 12. ~ .~-~, '~ 13. WELL NAME ~ PROGRAM: exp ~ ENGINEERING pATE Permit fee attached ....... Lease number appropriate.'~. ~ ~.'~.," '.~ ~." i ~'~. !'~.~. ~ 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 ........... 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 ................ 26. BOPE press rating appropriate; test to ~ . _psig. 27~.Choke manifold complies w/APl RP~53 (May 84) ........ 28.' Work.~ll occur without operation shutdown ........... dev v/' redrll ~ serv I,/' wellbore sag GEOL AREA ~(~ ' UNIT#, ('~///~ ~_._~"' ON/OFF SHORE 29. GEOLOGY 30.' ~ 31. 32. IIAPRR DATE 33. II 34. ann. disposal para req ~ .N Y N N Is presence of H2S gas probable ................. ~,3'~.~,~~\~x.~ ~%~'~, ~,~,,.;,~,'~\~=, ~ _~,~ ~ ,~,,~.~ ~ ~,~,;'-~~-~ ~,,~, Permit can be issued w/o hydrogen sulfide measures ..... Data presented on potential overpressure zones .... . . . Seismic analysis of shallow gas zones ......... ' · r/I~ ~ Y N Seabed condition survey (if off-shore) ...... , . . ~,,,~ £~ Y N Contact name/phone for weekly progress reports/e~x.f~of'atory only] Y N With proper cementing records, this plan Y N Y N (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste.... to surface; (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' G E O L O.C,-,-,-~: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: IZ Z ---I -I" c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX, No special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Oct 27 16:03:42 2000 Reel Header Service name ............. LISTPE Date ..................... 00/10/27 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 00/10/27 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: MWD RUN 1 AK-MM-00092 J. FOLEY J. PYRON MPF-83 500292296300 BP EXPLORATION, ALASKA Sperry Sun 27-OCT-00 MWD RUN 2 'MWD RUN 3 AK-MM-00092 AK-MM-00092 J. FOLEY R. FRENCH J. PYRON J. PYRON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 4 AK-MM-00092 R. FRENCH J. PYRON 6 13N 10E FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: $ File Header SerVice name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 2016 2993 .00 27.75 11.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 120.0 8.500 9.625 4838.0 6.125 7.000 10545.0 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 235 0 14136.5 ROP 273 5 14188.5 FET 4837 0 14143.5 RPX 4837 0 14143.5 RPS 4837 0 14143.5 RPM 4837 0 14143.5 RPD 4837 0 14143.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 235.0 7245.0 7268.0 7291.0 7314.0 7340.5 7389.0 GR 226 0 7236 0 7257 5 7280 0 7301 5 7328 5 7377 5 EQUIVALENT UNSHIFTED DEPTH 7425.0 7445.5 7566.0 7573.5 7582 5 7597 0 7605 0 7655 0 7665 5 7684 0 7688 5 7698 5 7713 0 7751 0 7769 0 7771 0 7780 5 7805 5 7827 0 7836 0 7857 5 7861 5 7880 0 7914 0 7921 5 7962 0 8009 5 8022 5 8032 0 8049.0 8065 5 8073 0 8080 5 8090 5 8097 5 8114 5 8116 5 8121 0 8130 5 8137 0 8163 5 8172 0 8183 5 8222 0 8292 5 8302 0 8309 0 8320 0 8323 0 8344 5 8354 0 8365 0 8377 0 8379 0 8389 0 8416 5 8418 0 7414.5 7436.5 7557.0 7560.5 7571.0 7583.0 7589.5 7641.5 7654.0 7673 0 7679 0 7687 5 7703 5 7740 0 7759 5 7763 0 7771 0 7793 0 7814 0 7823 5 7844 5 7848 5 7866 5 7901 0 7908 0 7950 5 8002 0 8014 0 8022 0 8039 0 8051 5 8059 0 8068 0 8078 0 8085 5 8103 5 8105 5 8108 0 8118 0 8125 0 8151 5 8160 5 8172 0 8213 0 8282 5 8291 5 8297 0 8308 0 8311 5 8334 0 8342 0 8352 0 8364 0 8367 0 8377 0 8403 5 8405 0 8429 8437 8442 8444 8458 8465 8467 8475 8483 8485 8502 8506 8513 8537 8543 8548 8561 8571 8582 8591 8597 8605 8612 8623 8639 8643 8654 8657 8663 8668 8671 8701 8706 8720 8727 8734 8739 8740 8749 8756 8762 8783 8787 8806 8823 8835 8842 8857 8859 8871 8873 8880 8885 8915 8920 8925 8930 .5 .5 .5 .0 .0 .5 .0 .5 0 0 5 5 5 5 0 0 0 5 0 0 0 5 0 5 0 5 0 0 5 0 0 0 0 5 0 0 5 5 5 0 0 0 0 0 0 5 5 5 5 5 0 5 5 5 0 5 0 8416 8424 8430 8431 8446 8453 8455 8463 8470 8472 8488 8494 8502 8526 8531 8536 8549 8559 8572 8579 8586 8596 8602 8611 8625 8629 8640 8645 8651 8658 8661 8690 8696 8711 8718 8725 8732 8733 8740 8746 8752 8773 8777 8793 8810 8824 8831 8845 8847 8859 8861 8869 8875 8904 8908 8914 8919 .0 .5 .0 .5 .5 0 0 5 5 5 5 5 5 0 5 0 .0 5 5 5 0 0 5 0 0 0 0 0 5 0 0 .5 .5 .5 .0 5 0 0 5 0 0 0 0 5 5 5 5 5 5 5 5 0 5 0 5 5 0 8946.5 8938.5 8958.0 8951.5 14188 . 5 14182 . 0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 3 MWD 4 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP 226.0 4851.0 10560.0 13553.0 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 MERGE BASE 4851.0 10560.0 13553.0 14182.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 235 14188.5 ROP MWD FT/H 0.7 584.36 GR MWD API 16.8 300.14 RPX MWD OHMM 0.82 1116.22 RPS MWD OHMM 0.79 1103.74 RPM MWD OHMM 0.15 2000 RPD MWD OHMM 0.59 2000 FET MWD HOUR 0.27 98.11 Mean Nsam 7211.75 27908 107.532 27765 93.3805 27781 3.86882 18589 3.999 18589 9.49412 18589 10.493 18589 1.83883 18589 First Reading 235 273.5 235 4837 4837 4837 4837 4837 Last Readinc_ 14188 14188 14136 14143 14143 14143 14143 14143 First Reading For Entire File .......... 235 Last Reading For Entire File ........... 14188.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE STARTDEPTH STOP DEPTH GR 226.0 4810.0 ROP 264.5 4851.5 $ LOG HEADER DATA DATE LOGGED: 08-JUL-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): recorded TD DRILLER (FT) : 4850.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .3 MAXIMUM ANGLE: 38.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01561CG8 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT) : 120.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Water Based 9.40 71.0 9.7 1800 6.0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 76.5 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 226 4851.5 2538.75 9252 ROP MWD010 FT/H 0.74 439.32 ,154.692 9139 GR MWD010 API 16.8 136.36 71.278 9169 First Reading 226 264.5 226 Last Reading 4851.5 4851.5 4810 First Reading For Entire File .......... 226 Last Reading For Entire File ........... 4851.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPX RPS RPM RPD FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 4810 5 4828 0 4828 0 4828 0 4828 0 4828 0 4852.0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 10511 10511 10560 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 STOP DEPTH 10503 0 10511 5 10511 5 10511 5 5 5 0 14-JUL-00 Insite 65.41 recorded 10560.0 29.1 84.9 TOOL NUMBER PB01559HWGR6 PB01559HWGR6 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 4838.0 LSND 9.70 44.0 8.8 400 2.8 1.400 .903 2.400 1.150 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 75.0 120.0 75.0 75.0 Name Service Unit Min Max Mean Nsam DEPT FT 4810.5 10560 7685.25 11500 First Reading 4810.5 Last Reading 10560 ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR 0.7 584.36 39.79 300.14 0.83 1116.22 0.79 346.5 0.19 1352.45 0.59 2000 0.27 49.78 93.0743 11387 119.818 11363 3.40881 11343 3.40663 11343 4.39528 11343 6.88513 11343 1.12842 11343 4852 4810.5 4828 4828 4828 4828 4828 10560 10503 10511.5 10511.5 10511.5 10511.5 10511.5 First Reading For Entire File .......... 4810.5 Last Reading For Entire File ........... 10560 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RJkW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPD RPM RPS RPX FET ROP $ 10503 5 10512 0 10512 0 10512 0 10512 0 10512 0 10560 5 LOG HEADER DATA DATE LOGGED: SOFTWARE STOP DEPTH 13500 0 13507 5 13507 5 13507 5 13507 5 13507 5 13552 5 22-JUL-00 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 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 Insite 65.44 recorded 13553.0 78.2 94.7 TOOL NUMBER PB1552FGR4 PB1552FGR4 6.250 10545.0 LSND 11.50 50.0 9.4 450 9.4 1.900 .866 1.100 1.700 67.0 155.0 75.0 75.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR Min 10503.5 1.01 32 88 0 82 0' 97 0 15 1 16 0 45 Max Mean Nsam 13552.5 12028 6099 436.92 74.0701 5985 134.31 78.1065 5994 17.59 4.57079 5992 1103.74 4.94109 5992 2000 20.0089 5992 2000 18.3957 5992 98.11 2.81746 5992 First Reading 10503.5 10560.5 10503.5 10512 10512 10512 10512 10512 Last Reading 13552.5 13552.5 13500 13507.5 13507.5 13507.5 13507.5 13507.5 First Reading For Entire File .......... 10503.5 Last Reading For Entire File ........... 13552.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/27 Maximum Physical Record..65535 File Type.~ .............. LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13500.5 FET 13508.0 RPD 13508.0 RPM 13508.0 RPS 13508.0 RPX 13508.0 ROP 13553.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 14130 0 14137 0 14137 0 14137 0 14137 0 14137 0 14182 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 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): 24-JUL-00 Insite 65.44 recorded 14182.0 93.3 94.9 TOOL NUMBER PB1552FGR4 PB1552FGR4 6.250 10545.0 LSND 11.50 54.0 9.5 300 2.0 1.900 .731 1.100 1.700 67.0 185.0 75.0 75.0 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HOUR Min 13500.5 4 02 37 94 2 83 2 76 2 75 2 94 0.65 Max Mean Nsam 14182 13841.3 1364 269.5 55.0639 1259 137.09 88.8935 1260 13.4 4.66473 1259 15.95 4.85483 1259 25.21 5.40416 1259 18.48 5.3923 1259 34.45 3.57145 1259 First Reading 13500.5 13553 13500.5 13508 13508 13508 13508 13508 Last Reading 14182 14182 14130 14137 14137 14137 14137 14137 First Reading For Entire File .......... 13500.5 Last Reading For Entire File ........... 14182 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/10/27 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name .............. LISTPE Date ..................... 00/10/27 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File