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Home My WebLink About197-041CAUTION: 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: Produced Water Injector MPU K-43 (PTD# 197041) Date:Tuesday, January 10, 2023 9:25:15 AM From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Friday, December 30, 2022 11:20 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: Produced Water Injector MPU K-43 (PTD# 197041) Mr. Wallace, Produced Water Injector MPU K-43 (PTD 197041) will not be brought online due to operational constraints at this time. The well is now classified as NOT OPERABLE for missing its 2018 regulatory MIT-IA. Please respond if there are any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Tuesday, December 20, 2022 9:45 AM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: OPERABLE: Produced Water Injector MPU K-43 (PTD# 197041) Mr. Wallace, Produced Water Injector MPU K-43 (PTD# 197041) was made NOT OPERABLE due to missing the AOGCC witnessed MIT-IA April 2018. On 12/20/2021, a passing pre-injection MIT-IA was conducted. The well is now classified as OPERABLE and will be returned to injection. Once injection is stabilized, an AOGCC witnessed MIT-IA will be scheduled. Please respond if there are any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of 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 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. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Produced Water Injector MPU K-43 (PTD# 197041) Date:Tuesday, December 20, 2022 10:56:16 AM From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Tuesday, December 20, 2022 9:45 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: OPERABLE: Produced Water Injector MPU K-43 (PTD# 197041) Mr. Wallace, Produced Water Injector MPU K-43 (PTD# 197041) was made NOT OPERABLE due to missing the AOGCC witnessed MIT-IA April 2018. On 12/20/2021, a passing pre-injection MIT-IA was conducted. The well is now classified as OPERABLE and will be returned to injection. Once injection is stabilized, an AOGCC witnessed MIT-IA will be scheduled. Please respond if there are any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently 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 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. • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday,April 3, 2018 8:11 AM To: Wallace, Chris D (DOA);Alaska NS - Milne -Wellsite Supervisors;Alaska NS - Milne - Field Operator Leads;Alaska NS -Wells Foreman;Alaska NS - Milne - Foreman Cc: Regg,James B (DOA); Brooks, Phoebe L(DOA); Stan Porhola; Darci Homer- (C) Subject: Shut-In Injector MPK-43A(PTD# 1970410) Due for AOGCC MIT-IA All, Milne Point water injector MPK-43A(PTD# 1970410)was shut-in in January 2017 for reservoir management following ESP failure of offset producer MPK-38.The well is due for an AOGCC witnessed MIT-IA on 4/14/2018. The well will not be brought online in time for the test and will remain shut-in.The well will be added to the Quarterly North Slope LTSI Injector Report. Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNa XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. /¢ 7- 0 ¢// File Number of Well History File PAGES TO DELETE RESCAN [] Color items- Pages: [] GraYScale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Original- Pages: [] Other - Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED .Logs of vadous kinds Other Complete COMMEN'F~: Scanned by: ~verb, Mildred-Daretha ~)L~I TO RE-SCAN Notes: Re-Scanned by: Beve~ Mildred Daretha Nathan Lowell Date: /s/ OF THE STATE �a,� �� ±_„a d: o ter' = ,/ . trAt - — 333 Wcsi Seventh Avenue GOVERNOR: SEAQ? PAR ELL Anchorage, Alaska 99501-3572 Ma,n: 907 279 1433 'c>.: C0/.2I . 175/12 scant) JUL 2 2 2014 David Bjork Engineering Team Leader 014,1 _/ BP Exploration (Alaska), Inc. `�' P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Kuparuk River Oil Pool, MPK-43A Sundry Number: 314-105 Dear Mr. Bjork: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Chair DATED this 23 day of February, 2014. Encl. RECEIVED • STATE OF ALASKA • . ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 4 201 DTS 2126l I4- APPLICATION FOR SUNDRY APPROVAL AOGCC 20 AAC 25.280 1. Type of Request: v.,a zrza/19 ❑Abandon 0 Plug for Redrill 0 Perforate New Pool la Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate ®Pull Tubing• ❑Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. ❑Exploratory 0 Stratigraphic 197-041 • 3. Address: 6. API Number: e,Alaska 99519-6612 ❑Development ®Service . P.O. Box 196612,Anchorage, 50.029-22738-01-0 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? . MPK-43A Will planned perforations require a Spacing Exception? 0 Yes No 9. Property Designatior 10.Field/Pool(s): ADL 375133 - Milne Point/Kuparuk River Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND (ft): Plugs(measured): Junk(measured): 8100' 7525' 7994' 7422' 7757' None Casing Length Size MD ND Burst Collapse Structural Conductor 74' 20" 38'- 112' 38'- 112' 1490 470 Surface 3778' 9-5/8" 36'-3814' 36'-3556' 5750 3090 Intermediate Production 8043' 7" 34'-8077' 34'-7503' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7706'-7792' • 7142'-7225' 3-1/2",9.3# L-80 7762' Packers and SSSV Type: 7"x 3-1/2" Baker S-3 Packer; Packers and SSSV 7436'/6881'; 7"x 3-1/2" Baker SABL-3 Packer MD(ft)and ND(ft): 7748'/7183' 12. Attachments: 13.Well Class after proposed work: • ®Description Summary of Proposal 0 BOP Sketch 1:1 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development ®Service. 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation. March 9,2014 0 Oil 0 WINJ .❑WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG 0 Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Abby Warren,564-5720 Printed Name: David Bjork Title: Engineering Team Leader Email: Abigail.Warren@bp.com Signature: i�i J�� Phone: 564-5683 Date: Q��/� Commission Use Only Conditions of approval: Notify Commission so that a representative may witness �\�_ Sundry Number: \O RBD ❑Plug Integrity Lg BOP Test �J Mechanical Integrity Test ID Location Clearance MAY 1 0 Other: M 2014 0 o p t-ri-- / 0 4- 00p5 , Sfia. f c wi-71-e7 cssccJ 11 - /A- r--eq vir-cc/ Cf- Ff-z r- 5 /a 1'2 ) i 1'3tc1 1"j'.-`l-r1-)- Spacing Exception Required? 0 Yes E No Subsequent Form Required: / /, q C, 7-ii APPROVED BY �p Approved By: to 9 -- p COMMISSIONER THE COMMISSION Date: 2 -z8-/(f, Form 10-403 evised 12012 Aptrdv aip,l�tf r vit f 12 months from the date of approval 04 2/2611(1 Submit In Duplicate ISGr 2/2- 7- lit �,„JJ '' `` ��,,JJ ' v//'"'�1Lam. s/r ,0y, Sundry Request for tubing Swap on an Injector Well: MPK-43 Date: 2/20/2014 Engineer: Abby Warren MASP: 1800 psi _ Well Type: Injector Estimated Start date: March 9th, 2014 History: MPK-43 is an injector drilled and cased across the Kuparuk B&C Sands in February 1997 to support MPK- 28. When the original hole came in wet, the well was sidetracked to ensure communication with MPK-38. A straddle completion was installed during the October 1997 RWO. Both B&C Sands were open to injection up to November 2000 when a tubing tail plug was set to isolate the Kuparuk B sands making MPK-43 a C sand only injector. The well injects Ugnu source water from the local source water well on MPK-pad, MPK-34. The Ugnu source water is known to be a source of corrosion. MPK-34 underwent a RWO in 2007 to replace the tubing. As a result of the corrosion observed in MPK-34, a caliper log was run in 2008 in MPK-43 to assess the condition of the tubing, the caliper log identified holes in the tubing_in pup joint#1 and#2, directly below the wellhead. Based on the results of this MPK-43 was left SI and secured with a down hole plug isolation the Kuparuk B Sands and DGLV's isolation the Kuparuk C Sands. MPK-43A has been shut in due to TXIA communication since 8/28/08 Scope of Work: Pull the 3-1/2" tubing from prerig tubing cut. Run new 4-1/2" 13Cr stacker packer completion. Pre Rig Prep Work: Task W PPPOT-T&IC, Function LDS S Pull XXN plug at 7757', pull DGLV at 7620', SBHP, reset XXN plug at 7757', reset DGLV at 7620', CMIT — TXIA to 3600 psi. Dump bail sluggets on top of plug, set junk catcher E Perform tubing punch above proposed RCT cut depth. Perform tubing cut with the radial cutting torch 3' down from the top of the first full joint above the X nipple (intent is to leave —25' stub of 3-1/2" tubing for the overshot completion). First full joint above the X nipple is at 7383' as per tally from 10/23/1997. ✓ Set BPV O Pull well-house, flow-line, prep pad for the rig. Proposed RWO Procedure: 1. MIRU Doyon 16. ND tree. NU and test BOPE with four preventers configured top down (annular, 2- 7/8" x 5" VBRs, blind shears, mud cross and 2-7/8" x 5" VBRs). Test the VBRs to 4000 psi and the annular to 3500-psi. 2. Pull 3-1/2" L-80 tubing from pre-RWO cut—8995' MD. 3. Run 4-W 12.6#/ft 13Cr-85 VamTop tubing with HES TNT packer set at—7230' 4. Test tubing and IA to 3,600-psi. 5. Set BPV. ND BOPE. NU and test tree. RDMO. Post rig Work ✓ Pull BPV S Pull ball and Rod, Pull RHC seat, pull junk catcher, bail sluggets, pull plug, set valves to allow Csand injection Tree: 3 1/8" - 5M FMC Orig. .,B Elev. = 62.00' (N 27E) • Wellhead: 11"x 7 1/16" 5M FMC MPU K-43Ai Orig. GL Elev. = 28.02' w/ 3-1/2" FMC Tubing Hanger ,3.5" RT To Tbg. Spool = 33.65' (N 27E) nsct top lift threads, 3.1/8" CIW H BPV profile i of x 20" 91.1 ppf, H-40 115' KOP @ 900' Note:Due to T x IA leak,this well is Max. hole angle =33 deg. @ 3,200' secured with a XXN plug set and dummies set in the two SPMs. Hole angle thru' perfs = 14 deg DLS =3.7 deg./100' @ 1,850' 9 5/8", 40 ppf, L-80 Btrc. 3,814' 7" 26 ppf, L-80, NSCC production casing ( drift ID =6.151", cap. = 0.0383 bpf) ki 3.5" 9.2 ppf. , EUE Mod. L-80 tbg. ( drift ID = 2.992" , cap. = .0087 bpf) II • 3.5"HES X-Nipple(2.813"id) 7,424' .1004 7" Baker" S-3" Packer 7,436' 7"short jts from 7544'to 7586' (ELM) Three jts. 3.5" tbg. • Perforation Summary Ref log:SWS GR/CCL/CBET , 3.5"x 1 1/2"Camco"MMM" 7,558' Dated 03/19/9-d One jt, of 3.5"tbg. Size SPF Interval (TVD) Kuo. 'C' Sand 3.5"x 1 1/2"Camco"MMM" 7,620' 3 1/2" 4 7706'- 7744' 7142'-7179' Three jts. 3.5"tbg. Kuo. 'B' Sand 3 1/2" 4 7760'-7792' 7194'-7225' ,„, 7"x 3.5" Baker" SABL-3" 7,745' 1. Prod. pkr.anchor release 37 UJ HMXJet charges @ 60 deg. 3.5"HES XN-Nipple (2.750"id) 77757' phasing 0.44"EHD. 7 761' 3.5"WLEG 11/06/00-Lower zone isolated w/'XXN'plug 7"float collar (PBTD) 7,994' 7" float shoe 8,077' DATE REV. BY COMMENTS MILNE POINT UNIT 10/26/96 MDO Completion Nabors 5-S WELL K-43Ai 03-15-97 MDO Cased hole Nabors 27E API NO: 50-029-22738-01 03/21/97 Lee H. Initial Perforations BP EXPLORATION (AK) Tree: 3118"-5M FMC Orig. KB Elev. = 62.00' (N 27E) Wellhead: 11"x 7 1/16" 5M FMC MPU K-43Ai Orig. GL Elev. = 28.02' w/ 3-1/2" FP 1C Tubing Hanger ,3.5" RT To Tbg. Spool = 33.65' (N 27E) nsct top lift t treads, 3.1/8" CIW H BPV profile 20" 91.1 p)f, H-40 115' KOP @ 910' Max. hole angle =33 deg. @ 3,200' Hole angkk thru'perfs = 14 deg DLS =3.7 deg./100' @ 1,850' 9 5/8", 40 p)f, L-80 Btrc. 3,814' A , 7" 26 ppf, t-80, NSCC production casing (drift ID = 3.151", cap. =0.0383 bpf) 1 I j—4-1/2"FES x MP I 3.5"9.2 ppf. , EUE Mod. L-80 tbg. � 7"x 4-1/2"TNT Packer 7230 (driftID=2.992" , cap. = .0087 bpf) 1 1 I—4-1/2'FES XIII,' I I H4-1/2"FES XN NP / 4-1/2'TBC,,12.6#,13Cr H 7386' I 3.5"HES X-Nipple(2.813"id) 7,424' /V0 iii fa►'kvi u t c 61-, I 41111 743'- ' ,‘n we iI El I c 25 7" Baker" S 3" Packer 7,436' t-o ,,,,h1 pack(✓' 7"short jts from 7544'to 7586' (ELM) 01-0 'aO D / Three jts. 3.5"tbg. �4 5 S oZ Perforation Summary bd V CrF " ilDtl Ref log:SWS GR/CCL/CBET V 3.5"x 1 1/2"Camco"MMM" 7,558' Dated 03/19/97 _ — I-?-0 ne jt, of 3.5"tbg. Size SPF Interval (TVD) 1 Kup. 'C' Sand DV J 3.5"x 1 1/2"Camco"MMM" 7,620' 3 1/2" 4 7706' - 7744' 7142'-7179' Three jts. 3.5"tbg. Kup. 'B' Sand 3 1/2" 4 7760'-7792' 7194'-7225ur AI 7"x 3.5" Baker"SABL-3" 7,745' i 0 Prod. pkr.anchor release 37 UJ HMX Jet charges @ 60 deg. - 3.5"HES XN-Nipple(2.750"id) 7,757' phasing 0.44"EHD. / 3.5"WLEG 7,761' 11/06/00-Lower zone isolated w/'XXN'plug — — 7"float collar (PBTD) 7,994' 7" float shoe 8,077' i DATE REV. BY COMMENTS MILNE POINT UNIT 10/26/96 MDO Completion Nabors 5-S WELL K-43Ai 03-15-97 MDO Cased hole Nabors 27E API NO: 50-029-22738-01 03/21/97 Lee H. Initial Perforations BP EXPLORATION (AK) o Is 1 5 ; �«g- 0 1 .;. .: ::::1 0 t IF 1..' ao 0 0 wz G c b 20 g z a; .1, ir ..: ::. : ;: j PI zQ a 0 0 rz gg U Q <n o La 0 1 1 J N w a a g Yz > a _ 0 3 x 0- z > U S U e00000009 1-1 ,,,: §7.1. „..,I.!:: a I III III I 111 III I I II 11°Z FA D=w Alti I I I I I I I.1 I II U - H .11111•11= L a iQ. .., o Im• 141 Q . 411 0 69'-..:R.z...E1 .ON a 5a • ilrii3 Do cg r2 o W Im L a O O O l'- aID w w o q JJ o cc 0 >mV22 O O In Qb0a b sN _z m 2V U X N a Na m m -z oa m =-. aoSJGa8N $ a hG o S',2oFY § S'l ! x ' ' m ' iO WW \i o � oC7 LO0 Q Q 2 " N _ 5 2 n N W I N o S ce 0 3 a I . • ■-ii 3 7_ ax U W �S J eGg la lel"' oI* IlIlmi _ ' w Y o � � C a U- CC a II III A.\ m "1111110 o aT ' o 6 ¢a x nN ay o a WV O• m Q � n by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 r �} Anchorage, Alaska 99519 -6612 , 5 ,. ` _ D F.B ` 7 2012 December 30, 2011 Mr. Tom Maunder O Alaska Oil and Gas Conservation Commission 333 West 7 Avenue k G Anchorage, Alaska 99501 11 r yt pl‹ Subject: Corrosion Inhibitor Treatments of MPK -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPK -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) MPK 10/29/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft • al MPK -02 1960810 50029226750000 0.2 NA 0.2 NA 5.1 9/5/2011 MPK -05 1960680 50029226700000 1.9 NA 1.9 NA 17.9 8/24/2011 MPK-06 1961910 50029227250000 1.5 NA 1.5 NA 8.5 8/27/2011 MPK-09 2050140 50029232470000 1.9 NA 1.9 NA 12.8 8/24/2011 MPK -13 1960400 50029226550000 1.7 NA 1.7 NA 14.5 8/24/2011 MPK -17 1960280 50029226470000 1 NA 1 NA 2.6 8/24/2011 MPK -18A 1970270 50029227330100 4.6 NA 4.6 NA 23.8 8/27/2011 MPK -21A 2031620 50029227180100 0.4 NA 0.4 NA 6.9 10/29/2011 MPK -22 2050220 50029232490000 2 NA 2 NA 5.1 8/27/2011 MPK -25 1960320 50029226500000 4.2 NA 4.2 NA 30.6 8/24/2011 MPK -30 1961680 50029227110000 1.5 NA 1.5 NA 17.0 8/25/2011 MPK-33 1962020 50029227290000 1.7 NA 1.7 NA 15.3 8/24/2011 MPK-34 1961690 50029227120000 2.5 NA 2.5 NA 25.5 8/25/2011 MPK-37 1960760 50029226740000 2 NA 2 NA 17.0 8/24/2011 MPK-38 1960300 50029226490000 3.2 NA 3.2 NA 15.3 8/25/2011 ---- -! MPK -43A 1970410 50029227380100 1.7 NA 1.7 NA 13.6 9/16/2011 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg '-;/ 7) L P.I. Supervisor ' Wfl3r¡:;'{C<':' DATE: Tuesday, February 28, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC K-43A MILNE PT UNIT KR K-43A Src: Inspector ov\\ \ C\'1.1 Reviewed By: P.I. Suprv,5.øz-- Comm FROM: John Spaulding Petroleum Inspector NON-CONFIDENTIAL Well Name: MILNE PT UNIT KR K-43A API Well Number 50-029-22738-01-00 Inspector Name: John Spaulding Insp Num: mitlS060227115919 Permit Number: 197-041-0 Inspection Date: 2/15/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! K-43A !Type loj. ¡wi TVD 6881 I IA ! 600 2600 2600 ¡ 2600 ¡ OA I P. T. ¡ 1970410 ITypeTest ! SPT I Test psi 1720,25 i 280 520 520 í 520 Tubing ¡ -- Interval 4YRTST P/F P 1850 1850 1900 ! 1850 Notes .:;' r'o t!. .. \<\1 I!", ¡'"i ·:~)·vr't~",;\.:t:!,: ,,', Tuesday, February 28, 2006 Page 1 of 1 oN oR BEFORE W c:LO~IL,M,DOC: STATE OF ALASKA ALASK~ -'L AND GAS CONSERVATION CO ]ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate []Plugging []Perforate [] Pull Tubing I-]Alter Casing [] Repair Well [] Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3467' NSL, 2028' WEL, SEC. 3, T12N, R11E, UM At top of productive interval 1237' NSL, 1488' WEL, SEC. 3, T12N, R11E, UM At effective depth At total depth 1198' NSL, 1387' WEL, SEC. 3, T12N, R11E, UM 5. Typel_o_~ well: Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 62' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-43Ai 9. Permit Number / Approval No. 197-041 10. APl Number 50- 029-22738-01 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Pi'esent well condition summary Total depth: measured 8100 feet true vedical 7525 feet Effective depth: measured 7994 feet true vertical 7422 feet Casing Length Size Structural Conductor 112' 20" Surface 3814' 9-5/8" Intermediate Production Liner 8043' 7" Plugs (measured) Junk (measured) Cemented MD TVD 250 sx Arcticset I (Approx) 146 146 1076 sx PF 'E', 720 sx Class 'G' 3848' 3585' 250 sx Class 'G' 33'-8077' 33'-7503' Perforation depth: measured '. 7706'-7744'; 7760'-7792' true vertical 7142'-7179'; 7194'-7225' Tubing (size, grade, and measured depth) 3-/12", 9.3#, L-80 @ 7762' Packers and SSSV (type and measured depth) Packer @ 7748', 7436' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection 17' I hereby certifY that the f°reg°ing ~'tl'~e an?°r,,.rec.,~¢. ° t~-~best °f mY kn°wledgeSigned ANGEl_.& M. SORRENTINO ~~-- .~Title Surveillance Engineer Prepared By Name/Number: Michael Wiliams, 564-4657 Form 10-404 Rev. 06/15/88 Submit In Duplicate 1/13/2000 MPK-43A DESCRIPTION OF WORK COMPLETED Stimulation Operation A Acid Stimulation Treatment was performed using the following fluids: Milne Point K-43Ai is an injector which is supplied water from MPK-34 water source well out of the Ugnu formation. A stimulation was performed on K-43Ai January 13, 2000 with the flowback from an acid job on K-34. Approximately 230 bbls of acid flowback was diverted to K-43Ai at approximately 250 psi injector head pressure. Fluids Pumped r BBLS. Description 230 Acid Flowback 230 Total BBLS RECEIVED FEB 02 2000 al~sl<a 0Il & (~as Cons. Commisslo~ Anchorage AOGCC Geological Materials Inventory PERMIT 9 7-041 BP EXPLORATION Log Data Sent Recieved 7675 q"~-SCHLUM PDC FROM CBT 5/7/1997 5/9/1997 7986 ~sPERRY MPT/GR/EWR4/CNP/SLD/ROP 5/21/1997 5/21/1997 CBL ~"~ 3450-7910 ~/t~/t~7 4/24/1997 4/25/1997 DGR/CNP/SLD-MD /E~' 3842-8100 5/14/1997 5/14/1997 DGR/CNP/SLD-TVD ~3574-7575 5/14/1997 5/14/1997 DGR/EWR4-MD f 3842-8100 5/14/1997 5/14/1997 DGR/EWR4-TVD ~' 3574-7575 5/14/1997 5/14/1997 GR/CCL 7550-7746 IOil'gq[cf'[ 11/5/1997 11/5/1997 GUNSHOT ~J/' ~3450-7910 ~/1(~ /qP~ 4/24/1997 4/25/1997 IN~ j7490-7850 ~/1~ /~ 2/17/1998 2/23/1998 MWD SRVY JSPERRY 4446.13-8100. 2/2/1998 2/2/1998 P ERF j' 160-7775 '~/'2. I/{:~ ~7 4/24/1997 4/25/1997 STATPRESS ~ 160.7775 ~/tl~/~ r7 4/24/1997 4/25/1997 ~,k0--407 Completion Date [0/~/?? Daily well ops ~/~/~ ? ~ Are dry ditch samples required? yes ? no And received? ~ ....... y~e2s_~.~- ..... no Was the well cored? yes ~no Analysis_description recieved? .-¥~ no Are tests required? yes ........ ?no Received? Well is in compliance Initial Comments Box UIC Friday, October 08, 1999 Page 1 of 1 >. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REcOMPLETION REPORT AND 1. Status of Well Classification of Service'fCC. ~,;, E~] Oil [] Gas ~]Suspended []Abandoned [~]Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-41 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22738-01 4. Location of well at surface ;'-',:!-,:::::.::;i!:.:'~.;:': 9. Unit or Lease Name ~)~i ~ '..~ -"~"'~ Milne Point Unit 3467'NSL, 2028'WEL, SEC. 3, T12N, R11E, UM :;i~.l_ ....... 0,,/5 ~~'~ 10. WellNumber At top of productive interval:. "~'~-'~"~ At total depth ~_.. 11. Field and Pool 1198' NSL, 1387' WEL, SEC. 3, T12N, R11E, UM :-'~ ::::: ............ · ..-~.~. Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 62'I ADL 375133 12. Date Spudded3/7/97 I 13' Date I'D' Reached ] 14' Date c°mp" Susp" °r Aband'l15' Water depth' if Offsh°re I 16' NO' Of C°mpletiOns3/9/97 10/25/97 N/A MSLI One 17. Total Depth (MD+TVD)8100 7525 FT1118: Plug Back Depth(MD+TVD)I19' Directi°nal Survey 120' Depth where SSSV set121' Thickness °f Permafr°st7994 7422 F,I ~Yes [-1No N/A MD 1800' (approx.) 22. Type Electric or Other Logs Run MWD, LWD, eR/dB, GR'CCL/CBET /'~ i~ I /'~ ! !~ ! 23. CASING, LINER AND CEMENTING RECORDU I1; i I"J i /4 I CASING SE-I-rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 38' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 36' 3814' 12-1/4" 1076 sx PF 'E', 720 sx Class 'G' 7" 26# L-80 34' 8077' 8-1/2" _~50 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) 3-1/2" Gun Diameter, 4 spf 3-1/2", 9.3#, L-80 7762' 7748' MD TVD MD TVD 7436' 7706'-7744' 7142'-7179' 7760'-7792' 7194'-7225' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 76 bbls diesel 27. PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) December 29, 1997 ! Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure :CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form !0-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Kuparuk 7492' 6935' KC1 7705' 7141' Top Kuparuk 'B' 7744' 7179' Top Kuparuk B7 7757' 7191' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ChipAIvord (_,~'~.] OVkff)¢'/ i Title Engineerin9 Supervisor Date O~/O oO MPK-4SAi ~ 97-41 Prepared By NamelNumber: Kathy Campoamor, 564-5122 Well Number Permit No. I 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 2?': Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Performance Enquiry Report Operator BP Exploration Date 03:36, 0l Feb 98 Page 1 The analysis is from - 01:00, 03 Mar 97 - to - 01:00, 03 Mar 97 Programs in Result Table: MPK-43 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) MPK-43 Event 01:00, 03 Mar 97 01:00, 03 Mar 97 0 hr 0 min Obtained leak off 14.1 Hole Size MDR 8-1/2 Facility M Pt K Pad Progress Report Well MPK-43A Page 1 Rig Nabors 5S Date 31 January 98 Date/Time 21 Oct 97 22 Oct 97 23 Oct 97 24 Oct 97 06:00-00:00 00:00-00:30 00:30-01:30 01:30-03:00 03:00-06:00 06:00-06:30 06:30-10:30 10:30-10:45 10:45-13:30 13:30-14:30 14:30-15:30 15:30-16:45 16:45-17:15 17:15-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-22:30 22:30-02:00 02:00-06:00 06:00-06:15 06:15-09:00 09:00-10:00 10:00-12:00 12:00-14:00 14:00-15:30 15:30-16:30 16:30-19:00 19:00-20:00 20:00-03:30 03:30-06:00 Duration 18hr 1/2 hr lhr 1-1/2 hr 3hr 1/2 hr 4hr 1/4 hr 2-3/4 hr lhr lhr 1-1/4 hr 1/2 hr 3/4 hr 1/2 hr 1/2hr 1/2 hr 3hr 3-1/2 hr 4hr 1/4 hr 2-3/4 hr lhr 2hr 2hr 1-1/2 hr lhr 2-1/2 hr lhr 7-1/2 hr 2-1/2 hr Activity Rig moved 100.00 % Held safety meeting Monitor wellbore pressures Removed Hanger plug Installed Hanger plug Held safety meeting Installed BOP test plug assembly Retrieved BOP test plug assembly Installed Tubing hanger Held safety meeting Removed Swab cap Installed Tubing hanger Installed Hanger plug Installed Swab cap Tested Hanger plug Serviced Swab valve Tested Hanger plug Removed Xmas tree Installed BOP stack Held safety meeting Held safety meeting Tested All functions Retrieved Tubing hanger Circulated at 2718.0 ft Conducted slickline operations on Slickline equipment - Tool run Rat} Tubing to 350.0 fl (3-l/2in OD) Circulated at 350.0 ft Ran Tubing to 1150.0 fi (3-1/2in OD) Circulated at 1150.0 ft Ran Tubing to 7765.0 ft (3-1/2in OD) Conducted electric cable operations Progress _Report Facility M Pt K Pad Well MPK-43 Rig Nabors ~R2-rJ6 07Mar97 ~0:30-0ii~ 1 hr Repaired Top drive 01:30-04:30 3 hr R.I.H. to 4350.0 ft 04:30-06:00 1-1/2 hr Drilled cement to 4800.0 ft 06:00-06:30 1/2 hr Held safety meeting 06:30-18:00 11-1/2 hr Drilled to 5819.0 ft 18:00-18:30 1/2 hr Held safety meeting 18:30-20:30 2 hr Drilled to 6100.0 ft 20:30-21:00 1/2 hr Circulated at 6100.0 ft Page 2 Date 31 January 98 Facility Date/Time 08 Mar 97 09 Mar 97 10 Mar 97 11 Mar 97 M Pt K Pad _Progress Report Well MPK-43 Rig Nabors Page Date 21:00-22:00 22:00-23:00 23:00-03:00 03:00-06:00 06:00-06:30 06:30-09:00 09:00-10:30 10:30-15:00 15:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-08:00 08:00-08:30 08:30-18:30 18:30-19:00 19:00-20:00 20:00-21:30 21:30-22:30 22:30-00:00 00:00-01:30 01:30-06:00 06:00-06:30 06:30-08:00 08:00-10:30 10:30-11:30 11:30-13:30 13:30-14:00 14:00-20:30 20:30-22:00 22:00-23:30 23:30-00:30 00:30-02:30 02:30-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-10:00 10:00-11:00 Duration 1 hr lhr 4hr 3hr 1/2 hr 2-1/2 hr 1-1/2 hr 4-1/2 hr 3hr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 10hr 1/2 hr lhr 1-1/2 hr lhr 1-1/2 hr 1-1/2 hr 4-1/2 hr 1/2 hr 1-1/2 hr 2-1'/2 hr lhr 2hr 1/2 hr 6-1/2 hr 1-1/2 hr 1-1/2 hr lhr 2hr 1/2 hr lhr 2hr 1/2 hr 3-1/2 hr lhr Activity Pulled out of hole to 3800.0 fl R.I.H. to 6100.0 ft Drilled to 6276.0 ft Pulled out of hole to 0.0 ft Held safety meeting Downloaded MWD tool Made up BHA no. 2 R.I.H. to 6276.0 ft Drilled to 6573.0 ft Held safety meeting Drilled to 7370.0 fi .. Held safety meeting Drilled. to 7416.0 ft Circulated at 7416.0 ft Pulled out of hole to 6276.0 ft R.I.H. to 7416.0 ft Drilled to 8100.0 ft Held safety meeting Circulated at 8100.0 ft Pulled out of hole to 3814.0 ft Serviced Block line R.I.H. to 8100.0 ft Circulated at 8100.0 ft Pulled out of hole to 1100.0 ft Held safety meeting Laid down 450.0 ft of 5in OD drill pipe Downloaded MWD tool Tested Top ram Serviced Casing handling equipment Held safety meeting Ran Casing to 8077.0 ft (7in OD) Circulated at 8077.0 ft Mixed and pumped slurry - 51.000 bbl ' Tested Casing Serviced Casing handling equipment Installed Wellhead integral components Serviced Top ram Rigged down BOP stack Held safety meeting Installed Xmas tree Freeze protect well - 60.000 bbl of Diesel 3 31 January 98 MILNE POINT, ALASKA TO: Rossberg/Krieger FROM: L.M. Hinkel Well Name: I K-43ai Main Category: Drilling Sub Category: E-line Operation Date: 03/19/97 Date: 103/21/97 AFE 347059 Objective: Run GR/CCL/CBET logs. PeRorate the Kuparuk "B" sand. Record SBHP survey. PeRorate the Kuparuk "C" sand. Run Gauge Ring/Junk Basket. Summary: 03/19/97 Logged well from 7900 ft up to 3450 ft. Cement bond is good to very good across and above the Kuparuk formation. Top of cement is at 6680 ft. Perforated the Kuparuk "B" from 7760 ft (md) to 7792 ft (md). Rig down SWS (moved to F-54 to spool E-line from fishing ops and chemical cut 3 %" tubing on F-70i with Nabors 4ES). Leave well shut in for SBHP. 30/21/97 SWS rig up and run SBHP. Well has been shut-in for 40 hrs. BHP is 3694.5 psi at 7775 ft (md) with a fluid level at 160 ft (md). Continue with peroration operations and perorate the Kuparuk "C" from 7706 ft (md) to 7744 ft (md). Run (6.0") Gauge Ring/Junk Basket to a depth of 7850 ft (md). Secure well. 08:00 08:30 09:30 09:45 11:00 11:15 11:25 12:45 12:50 13:45 14:30 14:45 15:05 15:25 16:00 16:30 17:00 17:20 18:00 SWS Unit #8317 arrive on location and begin to rig up. Pick-up lubricator/BOPs. Pick-up GR/CCL/CBET. Hold safety and pre-job meeting. Start RIH using a "marked line". Stop at 7800 ft. Log up to 7400 ft. Used to lithology from the Sperry-Sun MWD dated 03/10/97 as a reference. Drop back down to 7850 ft. Log repeat pass. Drop back to 7850 ft and record CBET/GR/CCL log up to 3450 ft. End log and continue out of hole. Request radio silence. Finished out of hole. Lay down logging tools. Rig up to perorate. Arm Gun #1 ( 3 %"x 20 ft). Pick-up gun Pressure lubricator to 3000 psi. Good test. Start RIH. Stop at 7850 ft. Log up for tie-in pass. Made no corrections. Drop back down and make repeat pass. Log gun #1 into place with the top shot at 7772 ft. and the bottom shot at 7792 ft. Fire gun and log off. Start out of hole. Finish out of hole. Lay down gun. All shots fired. Pick-up gun #2 (3 ~" x 12 ft). Start in hole. Stop at 7850 ft. Log up for tie-in pass. Make a (-) 1 1/2 ft correction. Drop back down and make a repeat pass. No further corrections. Log gun into place with the top shot at 7760 ft and the bottom shot at 7772 ft. Fire gun and log off. Start out of hole. Finished out of hole. Close in well. Lay down gun. All shots fired. Rig down SWS to go to F-54 fishing ops. 03121197 07:30 08:00 09:00 09:50 10:40 Resume operations. MIRU SWS Unit # 8317. Temp -35° F. WHP 0 psi. Pick up lubricator/BOPE, and static pressure tools. Pressure test lubricator. Test failed due to "O" ring leak. Replace "O" ring and tested lubricator to 2000 psi good test. Run in hole. Found fluid level at 160 ft. Log a short tie in pass. Park tools at 7775 ft MD for static pressure build-up. Stable rate is 3694.5 psi. 11:25 12:15 12:20 13:05 13:20 13:55 14:15 15:00 15:45 t6:25 17:30 17:45 18:15 19:00 19:30 19:35 Start to pull out of hole. Finish out of hole. Lay down logging tools. Request radio silence. Hold safety meeting. Rig up for perforating operations. Arm and pick up Gun ¢ 3 (3 %" x 20 ft). Start run in hole with Gun ¢ 3. Stop at 7850 ft. Log up for tie-in pass. Make a (-)1 ft correction. Drop back down and log repeat pass. Made no further corrections. Log Gun into place with Top shot at 7724 ft and the bottom shot at 7744 ft. Fire Gun. Log off. (GR quit after gun fired). Start out of hole. Finished out of hole. Lay down Gun. All shots fired. Trouble shoot GR. Decided to leave out of tool string for final run. Arm and pick-up Gun ¢ 4 (3 %" x 18 ft). Stop at 7850 ft. Log up for tie-in pass. Made a (-) 2 ft correction. Drop back down and log repeat pass. Made no further corrections. Log Gun into place with top shot at 7706 ft and the bottom shot at 7724 ft. Finish out of hole. Lay down Gun. All shots fired. Pick up Gauge Ring/Junk Basket (GR dia 6.0"). Run in hole with GR/JB to 7850 ft. (no problems). Start out of hole. Finished out off hole. Lay down GR/JB. (recovered no trash). Secure well. SWS RDMO. Tie in log: SWS CBET/GR/CCL dated 03/19/97 TD at: Charge type: CCL to TS: 7963 ft (md) (S-line) 37J UJ HMX, Max hole dia. 0.44", Max penetration 23.9" Gun ¢1 4.3' Gun ¢2 12.0' Gun ¢3 4.4' Gun#4 4.5' .......... Interval Measured Depth ......... Top Ft. Base Ft Gun Diameter Shot Density Orientation Phasing 7760 II 7792 II 3 W' !1 4 II Random 7706 Il 7744 11 3 W' II 4 J l Random 60° 60° Note: The gun size was changed from the original size of 4 %" to 3 %" guns because Schlumberger still does not have the proper sized 7" wireline BOPs to handle 4 W' dia guns. The change in gun size was discussed with and ok'd by Anch. Eng. SPF 'f-SUN DRILLING SERVICES ANCHORAGE ALASKA ~ 7' 0~1 PAGE SHARED SERVICES DRILLING MILNE POINT / MPK-43A 500292273801 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 030997 MWD SURVEY JOB NUMBER: AK-MM-70049 KELLY BUSHING ELEV. = 62.00 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 4446.13 4097.90 4035.90 4449.11 4100.49 4038.49 4500.00 4144.77 4082.77 4543.33 4182.50 4120.50 4637.87 4264.99 4202.99 29 31 29 35 29 30 29 21 29 8 S .45 W .00 1370.13S 34.67W S .16 W 5.31 1371.60S 34.68W S .10 W .19 1396.69S 34.73W S 1.94 E 2.34 1417.98S 34.39W S 1.90 E .23 1464.15S 32.85W 464.95 465.48 474.53 482.57 500.77 4733.32 4348.38 4286.38 4827.52 4430.73 4368.73 4919.21 4511.80 4449.80 5013.84 4596.67 4534.67 5108.37 4682.02 4620.02 29 28 26 25 25 6 59 39 51 3 S 2.14 E .13 1510.57S 31.21W S 3.55 E .74 1556.24S 28.94W S 3.24 E 2.55 1598.96S 26.40W S 3.80 E .90 1640.74S 23.83W S 7.67 E 1.95 1681.14S 19.80W 519.14 537.83 555.70 573.26 591.68 5202.32 4767.24 4705.24 5299.01 4855.02 4793.02 5390.67 4938.60 4876.60 5485.61 5026.12 4964.12 5578.85 5112.92 5050.92 24 42 24 53 23 33 22 0 20 48 S 9.17 E .77 1720.24S 14.01W S 14.45 E 2.30 1759.90S 5.71W S 16.34 E 1.68 1796.16S 4.25E S 18.85 E 1.93 1831.20S 15.34E S 23.84 E 2.34 1862.89S 27.68E 611.27 633.39 655.84 678.88 701.88 5672.49 5200.50 5138.50 20 40 5767.92 5289.93 5227.93 20 9 5858.22 5374.89 5312.89 19 27 5953.34 5464.87 5402.87 18 21 6047.60 5554.47 5492.47 17 49 S 28.72 E 1.85 1892.59S 42.34E S 33.59 E 1.86 1921.06S 59.53E S 38.17 E 1.89 1945.84S 77.43E S 44.48 E 2.43 1968.98S 97.72E S 48.05 E 1.31 1989.22S 118.85E 726.33 752.68 778.35 805.65 832.68 6141.94 5644.24 5582.24 18 0 6234.15 5732.02 5670.02 17 38 6328.32 5821.73 5759.73 17 45 6422.51 5911.44 5849.44 17 45 6516.09 6000.60 5938.60 17 34 S 54.16 E 2.00 2007.41S 141.41E S 58.31 E 1.43 2023.10S 164.86E S 59.41 E .37 2037.90S 189.36E S 60.39 E .32 2052.30S 214.20E S 60.81 E .23 2066.24S 238.94E 860.30 887.85 916.06 944.43 972.54 6610.29 6090.47 6028.47 17 19 6702.21 6178.21 6116.21 17 22 6795.76 6267.49 6205.49 17 21 6889.08 6356.48 6294.48 17 42 6982.50 6445.46 6383.46 17 46 S 61.06 E .28 2079.97S 263.64E S 61.43 E .13 2093.16S 287.67E S 61.50 E .03 2106.49S 312.19E S 62.22 E .45 2119.74S 336.98E S 62.19 E .06 2133.02S 362.16E 1000.54 1027.72 1055.41 1083.31 1111.59 7076.17 6534.75 6472.75 17 22 7169.42 6623.94 6561.94 16 32 7264.36 6715.14 6653.14 15 45 7360.62 6807.92 6745.92 15 6 7456.32 6900.36 6838.36 14 53 S 61.10 E .54 2146.45S 387.05E S 60.40 E .92 2159.74S 410.79E S 60.01 E .85 2172.86S 433.71E S 61.21 E .74 2185.43S 456.02E S 61.61 E .25 2197.28S 477.77E 1139.66 1166.61 1192.72 1218.08 1242.64 Alaska Oil & i;as Oor~s. ,3ommissior~. Anchorage SPF {-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPK-43A 500292273801 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 030997 MWD SURVEY JOB NUMBER: AK-MM-70049 KELLY BUSHING ELEV. = 62.00 FT. OPERATOR: BP EXPLOR3~TION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 7549.82 6990.75 6928.75 14 45 S 61.61 E .15 2208.66S 498.81E 7643.50 7081.37 7019.37 14 37 S 61.74 E .14 2219.92S 519.71E 7737.41 7172.22 7110.22 14 43 S 62.86 E .32 2230.98S 540.77E 7830.26 7262.19 7200.19 13 53 S 62.63 E .91 2241.49S 561.18E 7924.78 7354.05 7292.05 13 20 S 63.07 E .59 2251.64S 580.97E 1266.38 1289.94 1313.58 1336.41 1358.54 8049.08 7475.19 7413.19 12 31 S 65.19 E .76 2263.79S 8100.00 7524.90 7462.90 12 31 S 65.19 E .04 2268.42S 605.99E 1386.26 616.01E 1397.28 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2350.58 FEET AT SOUTH 15 DEG. 11 MIN. EAST AT MD = 8100 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 111.28 DEG. TIE-IN SURVEY AT 4,446.13' MD WINDOW POINT AT 4,500.00' MD PROJECTED SURVEY AT 8,100.00' MD SPt ?-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPK-43A 500292273801 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 030997 JOB NUMBER: AK-MM-70049 KELLY BUSHING ELEV. = 62.00 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4446.13 4097.90 4035.90 1370.13 S 34.67 W 348.23 5446.13 4989.52 4927.52 1817.20 S 10.56 E 456.61 108.38 6446.13 5933.93 5871.93 2055.86 S 220.46 E 512.20 55.59 7446.13 6890.52 6828.52 2196.04 S 475.46 E 555.61 43.42 8100.00 7524.90 7462.90 2268.42 S 616.01 E 575.10 19.48 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE' '-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPK-43A 500292273801 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 030997 JOB NUMBER: AK-MM-70049 KELLY BUSHING ELEV. = 62.00 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 4446.13 4097.90 4035.90 4519.80 4162.00 4100.00 4634.45 4262.00 4200.00 4748.91 4362.00 4300.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 1370.13 S 34.67 W 1406.44 S 34.70 W 1462.48 S 32.90 W 1518.15 S 30.93 W MD-TVD VERTICAL DIFFERENCE CORRECTION 348.23 357.80 9.57 372.45 14.65 386.91 14.47 4863.27 4462.00 4400.00 4975.32 4562.00 4500.00 5086.27 4662.00 4600.00 5196.55 4762.00 4700.00 5306.71 4862.00 4800.00 1573.54 S 27.87 W 1623.97 S 24.95 W 1671.86 S 21.05 W 1717.86 S 14.40 W 1763.04 S 4.91 W 401.27 14.36 413.32 12.05 424.27 10.95 434.55 10.28 444.71 10.16 5416.20 4962.00 4900.00 5524.31 5062.00 5000.00 5631.35 5162.00 51-00.00 5738.17 5262.00 5200.00 5844.55 5362.00 5300.00 1805.95 S 7.12 E 1844.93 S 20.03 E 1879.86 S 35.36 E 1912.52 S 53.86 E 1942.27 S 74.62 E 454.20 9.49 462.31 8.11 469.35 7.04 476.17 6.82 482.55 6.39 5950.31 5462~00 5400.00 6055.51 5562.00 5500.00 6160.62 5662.00 5600.00 6265.61 5762.00 5700.00 6370.60 5862.00 5800.00 1968.30 S 97.05 E 1990.83 S 120.65 E 2010.79 S 146.09 E 2028.11 S 172.97 E 2044.45 S 200.46 E 488.31 5.76 493.51 5.19 498.62 5.11 503.61 5.00 508.60 4.99 6475.59 5962.00 5900.00 6580.47 6062.00 6000.00 6685.23 6162.00 6100.00 6790.00 6262.00 6200.00 6894.88 6362.00 6300.00 2060.27 S 228.26 E 2075.67 S 255.87 E 2090.73 S 283.22'E 2105.67 S 310.68 E 2120.57 S 338.54 E 513.59 4.99 518.47 4.88 523.23 4.76 528.00 4.77 532.88 4.87 6999.87 6462.00 6400.00 7104.72 6562.00 6500.00 7209.12 6662.00 6600.00 7313.04 6762.00 6700.00 7416.62 6862.00 6800.00 2135.49 S 366.85 E 2150.57 S 394.52 E 2165.32 S 420.61 E 2179.41 S 445.12 E 2192.43 S 468.79 E 537.87 5.00 542.72 4.85 547.12 4.40 551.04 3.92 554.62 3.58 7520.09 6962.00 6900.00 7623.48 7062.00 7000.00 7726.84 7162.00 7100.00 7830.07 7262.00 7200.00 7932.95 7362.00 7300.00 2205.06 S 492.15 E 2217.53 S 515.26 E 2229.76 S 538.38 E 2241.47 S 561.14 E 2252.50 S 582.65 E 558.09 3.47 561.48 3.39 564.84 3.36 568.07 3.23 570.95 2.88 8035.56 7462.00 7400.00 2262.56 S 603.33 E 573.56 2.61 SPF Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 SHARED SERVICES DRILLING MILNE POINT / MPK-43A 500292273801 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 030997 JOB NUMBER: AK-MM-70049 KELLY BUSHING ELEV. = 62.00 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8100.00 7524.90 7462.90 2268.42 S 616.01 E 575.10 1.53 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 1 1/5/97 I~'[~J~L!~it]~l=]~mi GeoQuest 500 W, International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11525 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape MPC-6 (,/[,t ~ WATER FLOW LOG/TDTP-GR/CCL 970615 I 1 MPU C-8 t ),A ~ TDT WATER FLOW LOG 970927 I 1 MPU C-10 [,t. LC.~ WATER FLOW LOG W/RST INVERTED 970911 I 1 I MPE-10 , TUBING PUNCHER 970928 I 1 MPU E-22 ~ TUBING LEAK DETECTION LOG 970702 1 1 ,,, MPU E-22 ~ TUBING PATCH RECORD 97071 9 I 1 MPU F-09 ~ PERFORATING RECORD 970712 I 1 MPU F-09, STATIC TEMP/PRESS SURVEY 970712 I 1 MPU F-09' PERFORATING RECORD 97071 9 I 1 F-41, CHEMICAL CUTTER 970820 I 1 F-41 · CHEMICAL CUTTER 970829 I 1 MPU F-73 ' PERFORATION RECORD 97081 5 I 1 MPG-09 ~ RFT 970702 I 1 MPH-11 t RFT 970903 I 1 MPU J-2 [,[ [(..,, WATER FLOW LOGfrDT-GR 970726 1 1 MPU J-09 ~ [ (.~ JET CUTTER RECORD 970807 I 1 MPK-43A · GAMMA RAY CORRELATION LOG 971 024 I 1 MPU L-9 L~[ ~ WATER FLOW LOG/TDTP-GR/CCL 97061 4 I 1 MPU L-32 ~ GAMMA RAY CCL TCP CORRELATION LOG 970515 I 1 MPL-33 ' TUBING CONVEYED PERF TIE-IN GR-CCL 971 01 0 1 1 MPL-33 ~ TIE-IN GR-CCL 971014 1 I 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: RECEIVt.: . 5 1997 Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 To: WEI,L LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - May21,1997 MPK-43 & MPK-43A AK-MM-70049 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.' Tau Gal~ Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2 LDWG formatted Discs with verification listing. ? API#: 50-029-_2708-00 & 50-029-22738-01 r 5631 Silverado Way, Suite G · Anchorage, P, Jaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska May 14, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3 001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPK-43 & MPK-43A, AK-MM-70049 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.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPK-43: ~"~- (-~[. '-~'' 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22738-00 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22738-00 2"x 5"MD Neutron and Density Logs: 50-029-22738-00 2"x 5" TVD Neutron and Density Logs: 50-029-22738-00 MPK-43A: ~5~-~. ~r-~' [ 2"x 5" MD Resistivity and Gamma Ray Logs: 50-029-22738-01 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22738-01 2"x 5" MD Neutron and Density Logs: 50-029-22738-01 2" x 5" TVD Neutron and Density Logs: 50-029-22738-01 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) May 7, 1997 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612~~1.,d~ 'ql Lcd ~"~,1 / ~~ q ¢'''~ ~fl ~ The following data of the PDC GR for wells MPK-43A & MPE;18, Job # 97193 & 97'183, was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 1 CH LIS Tape each 1 Film (MPE-18) 3 Bluelines State of Alaska Alaska Oil & Gas Conservation Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1 CH LIS Tape each 1 Blueline 1 RFolded Sepia OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 1 CH LIS Tape each 1 Blueline 1 RFolded Sepia Sent Certified Mail Z 777 937 565 PLEASE ACKNOWLEDGE RECE lNG AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska ...99519-6612 ~ -. , ~:~; . .:. ..~ ,_.: _.~.? Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 4/24/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10967 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape MPU E-14 PERFORATION RECORD 9 70 41 6 1 1 MPU E-18 PERFORATION RECORD 9 70 41 5 1 1 MPU E-19 PERFORATION RECORD 9 70 41 4 1 1 MPU F-701 L.L.t C_~ CHEMICAL CUTTER 970320 1 1 MPU F-73 GR/CCL 97031 3 1 1 MPU F-73 PERFORATING RECORD 9 70 31 3 1 1 MPU J-09 [.L.\ ~¢..L.. CHEMICAL CUTTER RECORD 9 7 0 41 7 I 1 MPU J-09 ~. CBL 97041 8 I 1 MPU J-09~ PERFRECORD 97041 8 I 1 K-21 PERF RECORD W/GR 97031 6 I 1 MPK-21 CBL 97031 6 I 1 MPK-43A H.P.G. GUNS SHOOTING RECORD 9 70 31 9 1 1 MPK-43A 'STATIC PRESSURE SURVEY W/CPLT 9 70 31 9 I 1 MPK-43A CEIL 9 70 31 9 1 1 M PK-43A H.P.G. GUNS PERFORATION RECORD 9 70 3 21 1 I 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 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received 3~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Type of Reauest:. '~ Abancior~' ' [] Suapen~l .~ Plu§glng [] Time Extension [] Peflor~te - ' [] Alter Casing [:] Repair Well [] Pull Tublr~g [] Variance ~ Other [] Chan~]e ADDrov.~d Pro, ram [] O. @aratian Slluto3wn [] Re-Enter Suspended Well [] Stimulate PIL~I. Back for Sidetrack Name of Operator 15, Type of well[ 6, Datum Elevation (DF or KB) ~ Development Plan RTE = 53' . BP Exploration (Alaska) Inc. .. [] Exploratory 7. Unit Or Property Name ' Address [] Stratigraphi¢ Milne' Point Unit P.O. Box 198812, Anchorsge, Al~sk~ g9819-8812 []Service Location of well at surface :3467' NSL, 2028' WEL, SEC. 3, T12N, R11E At top of productive interval N/A At effective depth N/A At total depth 82' NSL., 19aS' WEL, SEC, 3, T12N, RllE 8. Well Number MPK-43i 19. Permi[-J~-mber 97-13 i0. APt NUr~-b~ 50-02g-22738 i 1. FieLd ~er{~l' l~ocl " ' Milne Point Unit / Kuparuk River 8ands 12. Present well condition summary Total depLh: measured 837{3 feet true vertical 7463 fe~t Effective depth: measured N/A feet true vertical N/A fee~ Casing Structural Conductor Surface Intermediate Production Liner Length Size 80' 20' ~783' Plugs (measured) Junk (measured) Cemented 2513 sx Arcticset I (Approx.) 1076 sx PF 'E', ,720 sx Cla~s MD 112' 3814' TVD 112' 3556' Perforation depth: measured I~A true vertical Tubing (size, grade, and measured depth) N/A Packers ~nd $85V (type and measured del=th) N/A MAR 0 6 1997 Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments [] Description summa.,y of proposal [] Detailed ocerations program [] BOP ske, tch · i4, Estimated date for commencing operation March 6, t997 16. If proposal was verbally approved Blair Wendzell Name ct approver 03J05/97 Date a,oproved 15. Status of well classifications as: "' [] OII 171Gas [] Suspended Service Water & Gas Injector __ Kathy Campoamor, 564-5122 Contact Engineer Name/Numbec Lance Spencer, 564-E042 PrePared By Name/Number. 17. I hereby ceni...~that the Joregoing is true and correct to the best of my knowledge ..... ~,Tho~ Title Drilling Superintendent Date >/3'/'~ 2 Commission Usa Only ~ ,, ~ve rn?~ J Approv. al No. 3 Conditions of Approval:PlugN°tifYint d_.~[~.~__. B.O~P' C°rnm~.~st ~ I~cation 13~eamnce . -- ~mved b,y order of Fe~lO-4~ Rev, O6/1~ ~ ~ ' ' '~ ~ ' ' ' ~ - ': . Subm¢ln~pl~te ALASI OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 6, 1997 Randy Thomas Drilling Superintendent BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPK-43Ai BP Exploration (Alaska) Inc. Permit No. 97-41 Sur. Loc 3467~SL, 2028'WEL, Sec. 3, T12N, R11E, UM Btmhole Loc. 1198WSL, 1387'WEL, Sec. 3, T12N, R11E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical inte~ity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 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. David W. J~~) Chairman BY ORDER OF THE COMMISSION dlf/Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 LAC 25.005 fla. Type of work [] Drill [] Redrill lb. Type of well [] Exploratsry [] straiigra~)hic Test [] Deve'lopment Oil [] Re-Entry [] Dee. p. en [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Na~e Of Operator ......... 5~ Datum Elevation (DF or'KB) ld'. Field'and Pool BP Exploration (Alaska) Inc. . .... Plan RTE = 61.2' ... Milne Point Unit / Kuparuk River 3. Address ' ' 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 375133 4. Location of well at surface 7. Unit or Properb~ Name 11. Typ~ Bond (see 20 AAc 25.025) 3467' NSL, 2028' WEL, SEC. 3, T12N, R11E Milner .. Point Unit At top of productive interval i8. Well Number Number 2S100302630-277 1237' NSL, 1488' WEL, SEC. 3, T12N, RllE MPK-43Ai At total depth 9. Appr6'~dm'~te spud date' Amount $200,000.00 SEC. 3, T12N, R11E 03/06/97 1198,' NSL, 1387' WEL, . .... - i 2. Distance to nearest propert~'iine113. Distance to neaP-est Well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 375132, 1387'I No Close Approach 2560 8049' MD / 7446' TVD 1~6. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)1 Kick Off Depth 5000' Maximum Hole Angle 28.21° Maximum surface 2926 psig, At total depth (TVD) 7055' / 3632 psig setting Depth 18. Casing Program Specifications ,Top Bottom Quantity of Cement Size . .L. , . -. --Hol~ '"Casing Weight G'rad'~; ' COupling Length' MD TVD "M'D TVb (include stage data) 8:'i)2'" 7;" 26~ ' L-80 Btrc ." 8019' ... 30' 30'. , 8049' 744.6' 243 sx Class 'G'.. . ............ .,, .... , ..... , , ........ , , ,. · , ,, , , , _. 119. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate " , Production Liner r',,4AR 0 6 ]997 Perforation depth: measured true vertical - 20. Attachments [] Filing I~ee ' [] Property ¢1at [] BOP S~etch [] Diverter S~e(ch [] Drilling Prog~m [] Ddlling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name~Number: Lance Spen~er, 564-5042 Prepared By .N_a. me~Number: Kathy. Campoamor, 564-5122 21. I hereby Certify that the foregoing is true and 'correct to the best of my ~<'~owledge ~/~/~ Signed ~ ~'~"~ % ~;'~ " Title Drilling Superintendent Date ,. ...... Rand,/Thomas .......... , .... Commission Use Only Permit Number I Alii Numbe'r '" I Approval 'D'ate I See cover letter ?/~ _ ~4',/ 50- O ....... 2.. ~' -' ~ Z ~,~ -~' ~ "-' O / . .5,.'/~ ,t ~ "~ for other requirements cOnditiOns of APproval: Samples Required [] Yes [] NO Mud Log Requ,red [] Yes J:~ No Hydrogen Sulfide Measures I-Wes ~ No Directional Survey Required J~ Yes [] No Required Working Pressure for ROPE [] 2M; ~i!l. 3M; [] 5M; [] 10M; [] 15M Other: 0,t~ll'ial Signed By Commissioner the commission Date ~Approved By ,% .... ;r{ ~&~ ~n~ne{'nn ...... q,,krni{' In TI, inlin~fn Form 10-401 Rev. 12-01-85 MRR 06 '97 0~:06PM SHRRED SERVICES DRILLIMG BP EXPLORATION BP Exploral~ion (AlasKa) Inc. PO 13ox 196612 Anchorage, A~aska 99519-6612 TELECOPY COMMUNICATIONS CENTER TO: Name; ,~'/~.,,.- /,vo.,J~// ... , Company: h o~ ¢ c MESSAGE# F. 1/14 Location: Fax # Confirm # FROM: Name & Ext.: Department'~- ~4~,~'~ .t'c..,..,~,,~ Mail Stop: %., PAGES TO FOLLOW (Do Not Include Cover Sheet) Mb, R 0 $ 1997 .Air,ks Oii& G,~: Cons. Commiss{or; Ancho~sge, SECURITY CLASSIFICATION PRIVATE SECRET CONFIDENTIAL Telecopy # Confirm # For Communications Center Use Only Time In Time Sent Time Confirmed Confirmed By Operator Shared Services Drilling Contact: Lance J. Spencer I Type of Well I Well Name: IMP K-4_3_A.,! .... I Well Plan Summary 564-5042 (PrOducer or inje_ct_o_r):.. I KuParuk Injector Surface Location: Kuparuk Target Location: 3467 NSL 2028 WEL Sec. 03 T12N R11E UM.~ AK 1237 NSL 1488 WEL Sec. 03 T12N R11E UM., AK Bottom Hole 1198 NSL 1387 WEL Sec. 03 T12N R11E UM., AK Location: IAFE Number: 1337056 Estimated Start. Date: I-Mb.~ 18,o49 _etc.): I 16 March 97 I I va: 17,446' (conventional, slimhole, I RIg: I Nabors 27-E ...... I operatiqg_d.a.¥s to complete: i~' .... I bkbl I K E:I Milne Point Ultra Slimhole Longstring 9- 5/8;~__4_0~S_urface X 7", 26# Longstring Formation Markers: Format'i;3n Tops'- MD TVD (bkb) Pore Pressure (EMW,Psi) ..... TopHRZ .... 7~050 6496 6.6 ppg, 2905 psi l~se HRZ 72 $ q 6, .686 .8:_6. PPg,_ 29.90 psi TKLB 7303 6737 9.0 ppg, 3153 psi TKUP/UD 7460 6,.8.86 9.0 Ppg, 3.22.2. psi -rtgJC 7587 7006 9.9 ppg, 3607 psi Expected OWC 7, .7, 00 711 0 9.9 ppg, 3660 .......... TKUC1/TARGET 7703 711 6 9.9 ppg, 3663 psi TKUB 7747 .... 7158 g.g ppg, 3685 psi · TKB7 --_ 7757 7168 9.9 ppg. 3690 psi Base TKB7 7799 .... 7__2_0_8_ .... _g_:9..PPg_; 37~!1. Total Depth ..... +_1 2178 7446 9.9 ppg, 3833 psi ~aslngl i UDIng ~ro¢ ram; Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D,. . .MD./...TVD MD/TVD 6-1/2" 7" 26# L-80 btrc 8019 30/30 8049/7446 The internal yield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKC1 at +_ 7055 TVDSS In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of _+.7055 TVDSS. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3632 psi is 29:26 psi, we[[ be[ow the internal yield pressure rating of the 7" casing, Milne Point' -Pad W, ell K-43Ai (Kup) Pg I 11;40 AM 3/6/97 P.4714 Loq_q [ng. Program: Open Hole Logs: None Fi n a I IViWI~ 'Directional from 9-5/8 shoe and LWD ..(GR/EWR4/CNP/SLD/ROP} from surface shoe to TD. Real Time Cased Hole Logs: N/A Mud Logging Mud Logger's and samples are NOT required. MWD r)irectional: Inclination and Azimuth GR: Gamma Ray EWR4: Electromagnetic Wave Resistivity 4 (Four Depths of Investigation) CNP= Compensated Neutron Porosity SLD: Stabilized Litho Density ROP: Rate of penetration .Mu_d__Er~ _o. _o._r_a.~.: Production Mud -I~'roperties: I LSND'fr~'~s'hWater mud Density '~ Marsh Yield'' 10 sec 10 rain pH Fluid (PPG) , Viscosity Point gel gel Loss 8.6 3.5.. 5 2 ...... 6 8.5 6 -8 to to to to to to to . ,, 10,2 ' 50 15 10 15 10 4-6 Well Control: Well control equipment consisting of pipe rams, blind rams, and annular preventer will be installed and shall be capable of operating to 5000 psi working pressure. The BOPE and diverter systems shall be capable of handling the maximum anticipated surface pressures. The diverter, BOPE and drilling fluid system schematics are all on file with AOGCG. Bi recti o n_ .a.[; KOP: 5000' Maximum Hole Angle; 28.21 o Close Approach Well'. (No Shut Ins_) All wells may remain flowing while drilling K-43Ai. __Disposal: No "Drilling Wastes" will be injected or disposed into K-43Ai while drilling this well, Cuttings Handling'. Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations Milne Point -Pad Well K-43Ai (Kup) Pg 2 P.b/14 AND RISKS: Clo~e Approaches There are no close approaches associated with the drilling of MP K-18 however tolerance lines should be carefully monitored and deviations from the proposed wellpath minimized.. Water Injection Currently no water injection wells are present on MP K-Pad Annt~lar Injection Annular injection is not permitted on K-Pad. A total of 19,608 bbls has been injected into the K~17 annulus_ Gas; Injection Currently no gas injection wells are present on K-Pad Lost, Circulation: K-0:~:, K-05, K-06 experienced losses while circulating to condition mud while running 7" casing. K-05 and K-06 experienced lost circulation while cementing 7" csg. In every instance, losses were minimized by reducing flow rates and conditioning the mud. Stuck Pipe Potential: Watch out for formation transition intervals. Increased torque and drag have been experienced after drilling into Kuparuk, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2' production interval. Formation Pressure: KUPARUK SAI'qD 7055' TVD 3600 PSI 9.9 PPG EMW The ~leepes[ anticipated gas should occur no deeper than the oil water contact which is expected above the Kuparuk C1 sand at _+ 7055 TVD$$. in this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of ._L-7055 TVDSS. The maximum anticipated surface pressure is 2926 psi in this case assu,ming a reservoir pressure of 3632 psi,The maximum expected pore pressure for this well is 9.9 ppg EMW at the OWC - OIL WATER CONTACTis 3,632 psi @ 7065' TVDss. Ther& has been injection in this region from MP K-17, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point K-Pad Data Sheet prepared by Pete Van Dusen for information on K pad and review recent wells drilled on K Pad. Milne Point-Pad Well K-43Ai (Kup) Pg 3 11;40 AM 3/6/97 MRR 06 OZ:08PM SHRRED SERVICES D~ILLIM~ MP K-43Ai Proposed Summary of Operations Milne Pt. Well# MPK-43i was drilled by NAB3RS RIG# 27E to a depth of 8,370' md (7,463' TVDbkb). LWD logs revealed the wce]] was determined to be non-commercial due to high water saturation. Furthermore, the water contact was located at 7,072' TVDss, which is 30' above the prognosed water contact of 7110' TVDss. The high water contact, the complete absense of hydrocarbons and the complex faulting makes this bottomhcle location inappropriate for injection on a structural basis. The well is not is comunication with the Consequently the KUPARUK SANDS will be abandoned and the well will be sidetracked below the surface casing shoe at 5000' md to an alternative target. Milne Point well MP K-43A[ will be drilled to another bottom hole location and be utilized as an injection well. The surface casing, 9-5/8", 40#, L-80, BTC was set at 3,814' md/3,556 TVD while drilling MP K-43i. Verbal approval was obtained from Blair Wondzell with ~to abandon the KUPARUK Sands and spot a SIDETRACK kickoff plug as outlined below. This verbal approval was given on March $, 1997 in a phone conversation to L. J. Spencer with BPXA Shared Services Drilling. 1. POOH after TD Milne Pt. Well# MP K-43i. 2. PU mu]eshoe and 1500' of 3-1/2" drillpipe. RIH on 5" drillpipe to TD at 8,370 md (7463' TVDss). The top of KUPARUK 'D' shale is at7724' MD (6905' TVDss). Circulate and condition hole for cement plug. Spot a 107 bbl ($21 sx) balanced cement plug from 7200-8370'. Slowly pull out of cement plug. At 15 stands above the plug rig up and circulate slowly down the drillpipe 1 drillpipe volume. MONITOR RETURNS. IF LOSING FLUID SHUTDOWN. NOTE The estimated cement volume is equivalent to the 8-1/2" hole volume from TD to 500' above KUPARUK 'D' Shale 4. 30% excess. Cement Type: PREMIUM G Addititives: 0.20% HALAD 344 + 0.20% CFR3 + HR5 AS NECESSARY WT: 15.8 PPG YIELD: 1.15 FT3/SK 3. Contact AOGCC and request representitive to witness or waiver tagging of first cement plug. 4. POOH above cement and WOC then tag cement if required by AOGCC. 5. Continue POOH to 5,730' md. Spot 30 bbt high risc mud pill (weight of pill 16 ppg current mud weight). Continue PO(~to 5,300' md. Spot 55 bbl (293 sx) balanced cement plug. Slowly pull out of plug. At 15 stands above the plug rig up and circulate slowly down the drillpipe 1 drillpipe volume. MONITOR RETURNS. IF LOSING FLUID SHUTDOWN. POOH LD muleshoe. NOTE: :The estimated cement volume is equivalent to the volume from 4,700-5,@00' md plus 30% excess. Cement Type: PREMIUMG Addititives: 1% CACL2 WT: 16.0 ppg YIELD; 1.05 FT$/SK 6. Test BOPE. Prior to drilling out review RP-For Production Hole Long String Vl.0 pages 1-3. Milne Point-Pad Well K-43Ai (Kup) Pg 4 11:40 AM 3/6/97 0 G ]997 MAR 06 '97 0~:09PM SHARED SERVICES DRILLING M.~×i4 7, Contact AOGCC and request representitive to witness or waiver tagging of second cement plug. , $. POOH above cement and WOO then tag cement if required by AOGCC. 9, MU bit on a motor, with Directional MWD and LWD CDR/CDN (GRIRES/DensZNeu). P, IH to 4,500' md. Begin washing and reaming until cement is tagged. Drill cement to $,000 md. NOTE: Indicat~ on morning report "TAG WEIGHT". 10. Circulate and condition mud at 5,000' md before begin sidetrack. 11. Drill 8.5" hole to TD as per directional plan. Hold a "Pre-Reservofr" meeting approximately 24 hfs prior to penetrating the Kuparul< and the Sag Reservoir. Attendants should include Co, Rep., Too/pusher, Rig Crew on tour, Mud Engineer, MWD personnel and other key service personnel as per SSD Drilling Policy, pg, 20, Flay 2.0, March 1995. At the top of the Kuparuk (D Shale) cap rock weight up the mud system to 10.2-10.5 ppg. Drill the Kuparuk D Shale cap rock as well as the all the Kuparuk sands. Sufficient footage is required such that there is a minimum of 150' of production rat hole when the 7' casing is run between the base of the Kuparuk(+- 8,050) and the Pt~TD. 12. Run and Cement 7" Casing. Prior to running casing and cementing review RP-For Production Hole Long String Vl.0 pages 1-3. ?'he current recommendation is to Buck up two 20' marker joints to make a 40' joint and position 120' above the top of the Kuparuk Formations. Displace cement with 8.4 ppg source water and enough diesel to cover from the base of permafrost to surface (+-2100' MD) 13. Test casing to 5000 psig. 14. ND BOPE and 11" drilling spool. NU tubing spool and dry hole tree and test Tree. Install the 7-1/16 work valve at the wellhead ~ FMC 5M GEN 5A. Test Tree. Freeze protect 9-5/8" x 7" csg annulus and note on morning report. Secure well. Release rig. RDMO Nabors 27E drilling rig to drill next well. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEI2URE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED, Milne Point -Pad Well K-43Ai (Kup) Pg 5 11:40 AM 3/6~97 MP K-43Ai 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON Casing Size' 7" 26# L-80 SINGLE STAGE CEMENT JOB.;, CIRC. TEMP: 140° F BHST 170° F at 7040' TVDSS. Cement from TD to 1000' above KUPARUK INTERVAL SPACERs' 20 bbls fresh water and 70 bbls NSCI mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.gppg APPROX # SACKS; FLUID LOSS: 0.2% CFR-3, 0,1% HR-5, 0.45% Halad 344 YIELD: 1,15 cu ft/sk MIX WATER: 5.0 gal/sk 243 SACKS THICKENING TIME: 3 1/2 - 4 I/2 hrs @ 140° F < 50cc/30 rain @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: , 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the from 120' below to 120' above Any potential hydrocarbon bearing sands. Run two (2) 7" × 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing' ~hoe. CEMENT 1, VOLUME: interval 6461-8050' md Single stage cement volume is calculated to cover 1000 FT MD above the highest potential KUPARUK(TKUPD) production sand + 30% excess. OTHER CONSIDERATIONS: . Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job, Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is ,Q.q_t, necessary. Milne Point -Pad Well K-43Ai (Kup) Pg 6 O Alaska Well ......... Field ........ ; C~p~a~lon.,: U~C~ ........ ~ FEET Sur~a~ Surface ~rface ...... : 3466 Ta~et ....... B~ .......... P~OPO~I~D ~ PRC~ILH Prepered ..... r Oi Nar 19~7 Vert sect sz.: 111.28 ~ e2~a~on.: 61.20 ~t Ma~ne~i~ Deln: +28.240 I~) Scale P~ctor. l 0,999~0~12 Convergence..: +0.~4991302 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN DZR.~'~ZON VERT1CAL,-DIIgTI~ 1~, ~MUTH TVD SUB - S~ ~P~T lEO. 13 4574 ,~ 4~1] , 59 559, S3 174.55 4755.33 4694.1t COORDIKATE$-FRO~ ~I~.SK~ ~a~ne 4 ~Ob 1603,9~ S 38.23 ~ 5845L0.79 60039~8.4~ ~2L 1644.29 S 38.92 W 584510.56 6003958.07 142L 1,2~ 1692,7) 9 ~7.B~ W 584512.]7 6D03909,64 14OL 193~.72 ~ )~.6g ~ 584515.~9 6003~6).~0 137~ 2,00 S300.00 25.3? ]71.38 4845.Z2 4984.02 g19.41 S400.00 23.91 5500.0D 22,63 163.9~ 5029.03 i966.~3 g64.04 5600,00 21.&6 IS9.63 5110.72 ~059.S2 687.86 5TD0.00 20.42 154.B6 5214.12 51~2,92 ?]2.66 5308.12 5246.92 738.39 1861.42 19;0,21 S 29,33 # S8452J.71 6003~20.29 135~ 2.g0 2L.67 N S8452g.64 6Q0377~.66 lIlb 12.29 # 5~4539,6~ 60037~1,Z7 128L 2.Oe 13.17 g 594565.86 6003672.98 119L 2.0Q 29.03 P. 5845B2.07 $003642.97 1141~ 2,1]0 J '- ii :iD 11) 0 La Ig C 1997 Page 6008,00 ~lOO.O0 mm~mm~l~mlmmmm~mlmmm mmlm~mmmlm~mmmm~mml m~mm mmma DIRECTION VERT~¢.q/,-D~PrJis SL:'C'r:C~I C'~ORDI'-/~I&TE$-FRON ' ~ Zone ~ ~L D~/ ~mm~ ~mmmmm~ mmmm m &tOO,O0 18.0~ 1~2,02 5B78.:8 $8X~,98 ~1D.65 20a2.00 $ END 2/100 C'LTRV]~ Eq~l.?~ 18.22 LII.~6 5889.37 5829.~7 91~.31 2083.35 ~ t69,66 TOP ~RZ ?OSO.2O ~0.~2 111.29 ~49&.20 ~435,00 X2A2.gO ~15~.42 $ 354.~2 T~' ?~0.63 28.12 111.28 6886.20 6e2S.OD- ]240,53 2201~73 g ~3.e5 ?A~GET ~***~*&***... ?~02.6~ 1~.12 111.28 ?116.20 705~.00 13~5.~1 2229.05 S 542.99 TKCI ??02.63 . 1~.12 X1~,~9 71~6,2o 70~S.DO ~315.61 2229,05 S 543.95 TKV./15 ~7~E.9~ 18.12 111.26 7158.20 7097.00 ]32).55 2234.~e 3 S~.A0 ?~ b:NER POI]~T 9049.4~ 1~.12 1~1.2~ T~4S.~ 7304.60 ~423,67 22~8.29 S 644.50 TD S04~.4i 18.12 11~.25 7445.80 7384.~0 1423.~7 Q268.~9 S Eq4,50 ~ 56~720,~T 6003522,95 ?)~ 2.~0 B 56a724,29 600~521.44 ~ 2.DO R 5eqgtO.12 6003a51.49 ~S O,O0 B 58~968.3~ 6002429.S7 HS ~ 5849B3.E2 6003423,81 HS 0_fi0 ~ 595115_93 6a03~74.01 F.,S g 5aS128.1~ &003369.3~ ~ 0,00 C ~95Z00.94 6003342.00 0.00 g 595200.94 ~003342,00 O,O0 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY , LO rq <: m I."madrlll (¢)91 [~PI~4:Lw;,2 3.nc ]0,-$9 ~ P) Ma~._o~M_AR~ ~6 ~ ~17; xOo~l i~P~,~.SH.??E,D, ,SER,_.V. ZC...ES I)RTLL1'HG DO7 ~44 ~160 P. 11/14 u'* SHARED SER CES DRILLING .... I ~ il ]i i -- i , I r i I I I I · MPK-43Ai (PO2) <~">°- {-'- VERTICAL SECTION VIEW ~o .... Section at: 1t~.28 TVD Scale.'- ! ~nch = ~OOO [eet ~ooo DeP Scale.' ~ tach - ~000 feet t500 ........ ~ ........ ~ ~ ..... I I ~ ~er~er ld~nti/iC~tl0n HO BKB ~CTN 1NCLN ~00 ~ A) TIE=IN $URV[Y 491B 4~OB 546 ~g,43 B) TOP ~ NI~OM 4995 4575 560 29.75 c) KOP/CUR~ 2/)OO 5000 4579 560 ~.77 2500- - ..... D) E~ 2/5~ C~VE 64t2 5BBg g14 lB,J2 - E) TA~T ~~.~ 770~ 711G 1316 18.S2 ] F] ?' LINER POINT ~4~ 7446 ~4~4 ~8,~ V 3000 ....... G) lO ~4Q 7446 1424 i~.A2 , ~ .~ AN~ DRILL A~- )PC fiSO0~ ..... .. -,w: .... - ........ 6000 X , 6500- h-~75 ~ - ~ - --- _ =-_ ~= ==--,~ ............. eOOO'" [ ...... .,.,, I O 500 I000 JSO0 2000 ~500 3DOO 3500 dO00 4500 5000 5500 6000 6500 Section oepertu~e (, 3.~ 1t'. 13 ~ Pi [ ' _- _",, SHARED-' SE'RV~CES D~iLLINS , .... .... m emro i ...... --- ~ - --- ~! VERTICAL SECTION VIEW m · , i I ' ITvO Sca]e.: ~ ~nc~ = ~00 feet , ioe~ Scale.: $ ~nch ~ ~00 feet I Ora~n ..... : 06 Mar sgg7 ~orker I~entificatton ~ BKB 5ECTN INCLN 8) T~ ~ N]NOO~ 4~ q575 560 ~.7~ c} KOP/C~VE ~/Io0 5000 4579 560 ~9,77 ~ ..... ' --- --- -- D) END ~f~O0 ~URVE ~1~ 5BB9 [ ~ FI ?' LI~ POINT i ,, ........ i , i..... i 1~ADRILL A' ". . ~1 I~V v FCpR P [RMI~IFLG ~- ~ .... ~T-fl, ...... ~=,.. i::. I . ~'fl~"""'=' . . '""'""'''" I .__, ................1, ....... ....... I ~lCln~] 1¢)97 1~43AP~ 3,OC !~; ~3 A~IP)'-- 400 6oo 8oo moo s~oo s4oo teoo ssoo ;ooo ~;oo ;400 ~6oo ~8oo aooo 3~oo Section Departure _ M~-Ot~W~b '~-r U~:ii~m 5~8~ 5b~VlCb5 D~iLLiMG SHARED SERVICES I I _ _ II .... I Al TIE-IN SURVEY 49IB 1604 S 38 B) TOP OF ~INDO~ ~g~ 1642 s 3g -' C} KOP/CURVE ~/100 5000 I§44 S 3B ~ 01 ENO 8/t00 CURVE 6a~8 2oe3 $ t7o E) TARGET a,~**~ 7703 ~889 5 ~4 E FI 7' LINER POINT soag 2~B 5 615 E G) TO OO4g ~86B S $45 E ORILLING · _ III i --- -- PK-43Ai ,(PO2] PLAN V EH CLOSURE .... · ~35B feet at Azimutn ]64.14 DECLINA~ION ' +28,2a0 {E) SCALE ...... ' ~ inch = 600 feet DRAHN ' 06 ~ap ~997 ANADEILL AKA-DPC ' "' APPROVED Anadr· J., ] ] ..... rger ....... [ ....... t Anc:i orar~ ........ I 8100 ]800 1500 1~ gO0 600 300 0 300 600 ~0 l~O 15~ I~O ~00 c- ~EST ' EAST -~ (l~'a~rlll [c197 ~d~ ,~,OC 11:14 ~ PI M~_o~,MRR_,. ~6 _~_~7. _~:.I.~PM SHRRED SERVICES DRILLIMG ~PUJ ! " =S,HAR~D S'ERV-ICES- DRILILIN6 .... ~ II I I I ...... D) EH0 ~/J~ ~RVE 64]~ 2083'S t70 E CLOSURE. ' 2358 feet at Azimuth ~64 14 El T~R~T ,,~,~,~,~,, 7703 2229 S 544 E ' F) 7' LINER ~ZNT 8049 DECLINATION.' +28.240 [E) Gl TD 8049 2268 S 645 E SCALE., · ~ inch = ~00 feet DRAHN. ' 06 Hap ANADRILL A~-DPC I I AnadP~.]] Schlumberger APPROVED ~oo , FOR PER~ I~IN~ _ _ ' ~ ' ONLY ~ t700 ...... -- ...... ~-'~ .... ~.tO0 ~ ...................... ~ . ~400 --. ' I ; , 2BO0 , --- ~ ...... 400 ~0 ~00 ~00 0 lO0 ~O0 ~0 400 500 600 700 coo 900 1ooo STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill IlL' Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepeni [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 61.2' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 375133 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3467' NSL, 2028' WEL, SEC. 3, T12N, R11E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 1237' NSL, 1488' WEL, SEC. 3, T12N, R11E MPK-43Ai Attotal depth 9. Approximate spud date Amount $200,000.00 1198' NSL, 1387' WEL, SEC. 3, T12N, R11E 03/06/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 375132, 1387'I No Close Approach 2560 8049' MD / 7446' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 5000' Maximum Hole Angle 28.21 o Maximum surface 2926 psig, Attotal depth (TVD) 7055' / 3632 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 Btrc 8019' 30' 30' 8049' 7446' 243 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 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Su, ce R'EC, btvED Intermediate Production Liner MAR 0 6 1997 Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Eng/neer Name/Number: Lance Spencer, 564-5042 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~_.,,X~ ~ Title Drilling Superintendent Date Commission U~e Only Permit Number APl Number I A~!;ov~_,Date I See cover letter p~'- ~./ 50-O.2.7,. ~-- ~ .2.. ~' ~ ~!~"'"~ ,/ ~/(,o/' ) 3 for other requirements Conditions of Approval: Samples Required [] Yes '~ No Mud Log Requ'ired' i-i~ "Yes [] No Hydrogen Sulfide Measures []Yes ~ No Directional Survey Required ~ Yes [] No Required Working Pressure for BOPE [] 2M; []3M; I~ 5M; [] 10M; [] 15M Other: by order of .~' Approved By original 6igfi~t~ d~ Commissioner the commission Date Form 10-401 Rev. 12-01-85 Subrnq I ~te Shared Services Drilling Contact: Lance J. Spencer 564-5042 I Well Name: IMP K-43Ai I Well Plan Summary I Type of Well (producer or iniector): I Kuparuk Iniector Surface Location: 3467 NSL 2028 WEL Sec. 03 T12N R11E UM., AK Kuparuk Target 1237 NSL1488 WEL Sec. 03T12N R11EUM.,AK Location: Bottom Hole 1198 NSL 1387 WEL Sec. 03 T12N R11E UM., AK Location: I AFE Number: 1337056 Estimated Start Date' 16 IMD: 18,o49 I IWell Design etc.)' (conventional, I IRis: J Nabors 27-E I March 97 I I Operatin~l days to complete: 16 I TVD- 17,446' bkb I IEEE= I Milne Point Ultra Slimhole Longstring 9- I slimhole, 15/8", 40# Surface X 7", 26# Longstring Formation Markers' Formation Tops MD TVD (bkb) Pore Pressure (EMW, Psi) Top HRZ 7,05 0 6 49 6 8.6 ppg, 2905 psi Base HRZ 7 2 5 0 6 6 8 6 8.6 ppg, 2990 psi TKLB 7303 6737 9.0 ppg, 3153 psi TKUP/UD 7460 6886 9.0 ppg, 3222 psi TKUC 7587 7006 9.9 ppg, 3607 psi Expected OWC 7 7 0 0 71 1 0 9.9 ppg, 3660 TKUC1/TARGET 7703 71 16 9.9 ppg, 3663 psi TKUB 7747 7158 9.9 ppg, 3685 psi TKB7 7 75 7 71 6 8 9.9 ppg, 3690 psi Base TKB7 7 7 9 9 7 2 0 8 9.9 ppg, 3711 psi Total Depth +12178 7446 9.9 ppg, 3833 psi Casing/Tubing Pro!]ram: Hol; (~sg/ 'Wt/Ft Grade Conn Length Top Btm Size Tb~l O.D. MD/TVD MD/TVD 8-1/2" 7" 26# L-80 btrc 8019 30/30 8049/7446 The internal yield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKC1 at + 7055 TVDSS In this instance, this worst case surface pressure would occur with afull column of gas from the reservoir from a depth of +7055 TVDSS. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3632 psi is 2926 psi, well below the internal yield pressure rating of the 7" casing. Milne Point-Pad Well K-43Ai (Kup) Pg 1 Logging Program' Open Hole Logs' INone MWD Directional from 9-5/8 shoe and LWD (GR/EWR4/CNP/SLD/ROP) from surface shoe to TD. Real Time N/A Mud Loggers and samples are NOT required. Final Cased Hole Logs: Mud Lo99ing MWD Directional: GR: EWR4: CNP: SLD: ROP: Inclination and Azimuth Gamma Ray Electromagnetic Wave Resistivity 4 (Four Depths of Investigation) Compensated Neutron Porosity Stabilized Litho Density Rate of penetration Mud Program: Production Mud Properties: ILSNDfreshwatermud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel 9el Loss 8.6 35 5 2 6 8.5 6-8 to to to to to to to 10.2 50 1 5 1 0 1 5 1 0 4-6 Well Control: Well control equipment consisting of pipe rams, blind rams, and annular preventer will be installed and shall be capable of operating to 5000 psi working pressure. The BOPE and diverter systems shall be capable of handling the maximum anticipated surface pressures. The diverter, BOPE and drilling fluid system schematics are all on file with AOGCC. Directional: KOP' 5000' Maximum Hole Angle: 28.21 o Close Approach Well: (No Shut Ins) All wells may remain flowing while drilling K-43Ai. Disposal' No "Drilling Wastes" will be injected or disposed into K-43Ai while drilling this well. Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluids Handling' All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations Milne Point -Pad Well K-43Ai (Kup) Pg 2 11:40 AM 3/6/97 DRILLING HAZARDS AND RISKS: Close Approaches There are no close approaches associated with the drilling of MP K-18 however tolerance lines should be carefully monitored and deviations from the proposed wellpath minimized.. Water Injection Currently no water injection wells are present on MP K-Pad Annular Injection Annular injection is not permitted on K-Pad. A total of 19,608 bbls has been injected into the K-17 annulus. Gas Injection Currently no gas injection wells are present on K-Pad Lost Circulation: K-02 , K-05, K-06 experienced losses while circulating to condition mud while running 7" casing. K-05 and K-06 experienced lost circulation while cementing 7" csg. In every instance, losses were minimized by reducing flow rates and conditioning the mud. Stuck Pipe Potential: Watch out for formation transition intervals. Increased torque and drag have been experienced after drilling into Kuparuk, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Formation Pressure: KUPARUK SAND 7055' TVD 3600 PSI 9.9 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected above the Kuparuk C1 sand at _+ 7'055 TVDSS. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +_7055 T'VDSS. The maximum anticipated surface pressure is 2926 psi in this case assuming a reservoir pressure of 3632 psi,The maximum expected pore pressure for this well is 9.9 ppg EMW at the CWO - OIL WATER CONTACTis 3,632 psi @ 7055' TVDss. There has been injection in this region from MP K-17, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point K-Pad Data Sheet prepared by Pete Van Dusen for information on K pad and review recent wells drilled on K Pad. Milne Point -Pad Well K-43Ai (Kup) Pg 3 11:40 AM 3/6/97 MP K-43Ai Proposed Summary of Operations Milne Pt. Well# MPK-43i was drilled by NABORS RIG# 27E to adepth of 8,370' md (7,463' TVDbkb). LWD logs revealed the wcell was determined to be non-commercial due to high water saturation. Furthermore, the water contact was located at 7,072' TVDss, which is 30' above the prognosed water contact of 7110' TVDss. The high water contact, the complete absense of hydrocarbons and the complex faulting makes this bottomhole location inappropriate for injection on a structural basis. The well is not is comunication with the Consequently the KUPARUK SANDS will be abandoned and the well will be sidetracked below the surface casing shoe at 5000' md to an alternative target. Milne Point well MP K-43Ai will be drilled to another bottom hole location and be utilized as an injection well. The surface casing, 9-5/8", 40#, L-80, BTC was set at 3,814' md/3,556 TVD while drilling MP K-43i. Verbal approval was obtained from Blair Wondzell with ~to abandon the KUPARUK Sands and spot a SIDETRACK kickoff plug as outlined below. This verbal approval was given on March 5, 1997 in a phone conversation to L. J. Spencer with BPXA Shared Services Drilling. 1. POOH after TD Milne Pt. Well# MP K-43i. 2. PU muleshoe and 1500' of 3-1/2" drillpipe. RIH on 5" drillpipe to TD at 8,370 md (7463' TVDss). The top of KUPARUK 'D' shale is at7724' MD (6905' TVDss). Circulate and condition hole for cement plug. Spot a 107 bbl (521 sx) balanced cement plug from 7200-8370'. Slowly pull out of cement plug. At 15 stands above the plug rig up and circulate slowly down the drillpipe I drillpipe volume. MONITOR RETURNS. IF LOSING FLUID SHUTDOWN. NOTE: The estimated cement volume is equivalent to the 8-1/2" hole volume from TD to 500' above KUPARUK 'D' Shale + 30% excess. Cement Type: PREMIUM G Addititives: 0.20% HALAD 344 + 0.20% CFR3 + HR5 AS NECESSARY WT: 15.8 PPG YIELD: 1.15 FT3/SK 3. Contact AOGCC and request representitive to witness or waiver tagging of first cement plug. 4. POOH above cement and WOC then tag cement if required by AOGCC. 5. Continue POOH to 5,730' md. Spot 30 bbl high v/sc mud pill (weight of pill 16 ppg current mud weight). Continue POOH to 5,300' md. Spot 55 bbl (293 sx) balanced cement plug. Slowly pull out of plug. At 15 stands above the plug rig up and circulate slowly down the drillpipe I drillpipe volume. MONITOR RETURNS. IF LOSING FLUID SHUTDOWN. POOH LD muleshoe. NOTE: :The estimated cement volume is equivalent to the volume from 4,700-5,300' md plus 30% excess. Cement Type: PREMIUM G Addititives: 1% CACL2 WT: 16.0 ppg YIELD: 1.05 FT3/SK 6. Test BOPE. Prior to dr/fling out review RP-For Production Hole Long String VI.0 pages 1-3. Milne Point -Pad Well K-43Ai (Kup) Pg 4 11:40 AM 3/6/97 7. Contact AOGCC and request representitive to witness or waiver tagging of second cement plug. 8. POOH above cement and WOC then tag cement if required by AOGCC. 9. MU bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH to 4,500' md. Begin washing and reaming until cement is tagged. Drill cement to 5,000 md. NOTE: Indicate on morning report "TAG WEIGHT". 10. Circulate and condition mud at 5,000' md before begin sidetrack. 11. Drill 8.5" hole to TD as per directional plan. Hold a "Pre-Reservoir" meeting approximately 24 hrs prior to penetrating the Kuparuk and the Sag Reservoir. Attendants should include Co. Rep., Toolpusher, Rig Crew on tour, Mud Engineer, MWD personnel and other key service personnel as per SSD Drilling Policy, pg, 20, Rev 2.0, March 1995. At the top of the Kuparuk (D Shale) cap rock weight up the mud system to 10. 2- 10. 5 ppg. Drill the Kuparuk D Shale cap rock as weft as the afl the Kuparuk sands. Sufficient footage is required such that there is a minimum of 150' hole when the 7" casing is run between the base of the Kuparuk(+- PBTD. of production rat 8,050) and the 12. Run and Cement 7" Casing. Prior to running casing and cementing review RP-For Production Hole Long String VI.0 pages 1-3. The current recommendation is to Buck up two 20' marker joints to make a 40' joint and position 120' above the top of the Kuparuk Formations. Dis/a/ace cement with 8.4 ppg source water and enough diesel to cover from the base of permafrost to surface (+-2100' MD) 13. Test casing to 5000 psig. 14. ND BOPE and 11" drilling spool. NU tubing spool and dry hole tree and test Tree. Install the 7-1/16 work valve at the wellhead - FMC 5M GEN 5A. Test Tree. Freeze protect 9-5/8" x 7" csg annulus and note on morning report. Secure well. Release rig. RDMO Nabors 27E drilling rig to drill next well. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL DE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. Milne Point -Pad Well K-43Ai (Kup) Pg 5 11:40 AM 3/6/97 Casing Size' 7" 26# L-80 SINGLE STAGE CEMENT JOB: MP K-43Ai 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON CIRC. TEMP: 140° F BHST 170° F at 7040' TVDSS. Cement from TD to 1000' above KUPARUK INTERVAL SPACERs: 20 5bls '~ --' ,,e~h water and 70 bbls NSCI mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: ?remium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: FLUID LOSS: 0.2% CFR-3, 0.1% HR-5, 0.45% Halad 344 YIELD' 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 243 SACKS THICKENING TIME' 3 1/2 - 4 1/2 hrs @ 140° F < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT' , , 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the from 120' below to 1 20' above any potential hydrocarbon bearing sands. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. CEMENT VOLUME: Interval 6461-8050' md . Single stage cement volume is calculated to cover 1000 FT MD above the highest potential KUPARUK(TKUPD) production sand + 30% excess. OTHER CONSIDERATIONS: . Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. Milne Point -Pad Well K-43Ai (Kup) Pg 6 11:40 AM 3/6/97 Anadrill Schlumkerger Alaska District 1111 East 80th Avenue Anchorage, AK P9518 (907) 349-4511 Fax 344-1622 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPK-43Ai (P02) F~eld ........ : Milne Point, K-Pad Computation..: Minimum Curvature Units ........ : F£ET Surface Lat..: 70.42523328 N Surface bon~.: ]49.31118022 W Legal Description Surface ...... : 3466 FSL 2028 FEL S03 T12N R11E UM Tie-in survey: 1862 FSL 2069 FEL S03 T12N RIlE UM Target ....... : 1237 FSL 1488 FEL S03 T12N RIIE UM BHL .......... : ~198 FSL 1387 FEL S03 T12N RllE UM LOCATIONS - ALASKA Zone: X-Coord 584530.85 584510.79 585100.00 585200.94 4 Y-Coord 600~02.$4 6003998.40 6003380,00 6003~42.00 PROPOSED WELL PRCFILE Prepared ..... : 06 Mar 1997 Vert sect az.: 111.28 KB elevation.: 61.20 ft Magnetic Dcln: +28.240 {E) Scale Factor.: 0.99990812 Convergence..: +0,64901302 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN STATION MEASURED IDENTIFICATION DEPTH TIE-IN SURVEY ~'~-, 4918.32 TOP OF WINDOW -~.' KOP/CURVE 2 / 10(~? :::=. ,,,, ~54007~ .... , ~,,~ 56 o o .~bo C'r' 5700.00 INCLN DIRECTION ANGLE AZIMUT~ 29.43 181.98 29.75 180.13 29.77 180.02 28.21 177.41 26.71 174.55 VERTICAL-DEPT~S TVD SUB-SEA 4508.10 4446.90 4574.79 4513.59 4579.13 4517.93 4666.60 4605.40 4755.33 4694.13 mmemamm! SECTION DEPART 546.44 559.53 560.43 579.00 598.67 25.27 171,38 4845,22 4?84.02 619.41 23.91 167.86 4936.16 4874.96 641.21 22.63 163.96 5028.03 4966,83 664.04 21.46 15~.63 5120.72 5059.52 687.86 20,42 154.86 5214.12 5152.92 712.66 m ~m~mmmmmmm~m~mmmmmm mmmm COORDINATES-FROM ALASKA Zone 4 TOOL DL/ WELLHEAD X Y FACE 100 1603,96 S 38.23 W 584510.79 6003998.40 72L <TiE 1641.81 S 38.92 W 584510.53 6003960.55 70L 1,26 1644.29 S 38.92 W 584510.56 6003958.07 142L 1.26 1692.73 S 37.86 W 584512.17 6003909.64 140L 2.00 1738.72 S 34.66 W 584515,89 6003863.70 137b 2.00 1782.20 S 29.33 W 584521.71 6003820.29 135L 2.00 1823.11 S 21,87 W 584529.64 6003779.46 131b 2.00 1861.42 S 12.29 W S84539.65 6003741.27 128L 2.00 1897.06 S 0,60 W 584551.73 6003705.77 124L 2.00 1930.01 S 13.17 E 584565.88 6003672.98 119L 2.00 5800.00 19.51 149,63 5308.12 5246.92 738.39 1960,21 S 29.03 E S84582.07 6003642.97 114L 2,00 (Anadrill (c}97 MPK43AP2 3.0C 10:59 AM P) O MPK-43Ai STATION IDENTIFICATION MEASURED INCLN DEPTH ANGLE 5900.00 18.77 6000.00 18.21 6100.00 17.86 6200.00 17.71 6300.00 17.78 6400.00 18,07 END 2~100 CURVE 6411.78 18.12 TOP HRZ 7050.28 18.12 BASE NRZ 7250.19 18.12 TKLB 7302.80 18,12 TKUD 7460.63 18.12 TKUC 7586.89 18.12 TARGET *********+*** 7702.63 18.12 TKCl 7?02.63 18,L2 TKUB 7746.83 18.12 TKB7 7757.35 18.12 BASE 87 7799.44 18.12 7" LINER POINT 8049.44 18.12 TD 8049.44 18.12 PROPOSED WELL PROFILE 06 Mar 1997 Page 2 mum ~ DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 143.97 5402,60 5341.40 ]37.91 5497.44 5436.2~ 131.55 5592.54 5531.34 125.01 5687.79 5626.57 118.45 5783.02 5721.82 mmmmmmmm SE~TIO~ DEPART 765.02 792.54 820.69 850.05 879,98 m~mmmmmmmmmmmm{mmmmm! mmmmmmmmmmmmmmmmmmm! mmmm mmm{ COORDINATES-FROM ALASKA Zone 4 TOOb DL/ WELLHEAD X Y FACE 100 mmmmmmnm{ f~=mmmmmm~ ~= mlmm 1987.63 S 46.93 E 584600.29 6003615.75 109L 2.00 2012.24 S 66.88 E 584620.51 6003591.37 103L 2.00 2034.00 S 88.83 E 584642.70 6003569.86 97L 2.00 20~2.90 S 112.76 E 584666.85 6003551.24 91L 2.00 2068.91 S 138.65 E 584692.91 6003535.53 8SL 2.00 112.02 5878,18 5816.96 910.65 2082.00 S 166,46 R 111.28 5889,37 5828,17 914,31 2083,35 S 169,86 E 111.28 6496,.20 6435.00 1112.90 2155.42 S 354.92 E 111.28 6666.20 6625.00 1175.08 2177.98 S 412.86 E 111.28 6736.20 6675.00 119],44 2183.92 S 428.11 E 111.28 6886.20 6825.00 1240.53 2201.73 122.28 7006,20 6945.00 1279,81 2215.99 111.28 7116,20 7055,00 1315.81 2229,05 111.28 7116,20 7055.00 1315,81 2229.05 111.28 7158.20 7097.00 1329,55 2234.04 111.28 7168.20 7107.00 1332.82 2235.22 S 111.28 7208,20 7147.00 1345,91 2239.97 S 111,2~ 7445.80 7384.60 1423,67 2268.19 S 111,28 7445.80 7384.60 1423,67 2268.19 S 584720.87 6003522.75 79L 2.00 584724,28 6003521.44 HS 2,00 584910,12 6003451.48 HS 0,00 584968,31 6003429.57 HS 0.00 584983,62 6003423.81 HS 0.00 473.85 E 585029,56 6003406.52 HS 0.00 510,44 E 585066.31 6003392.68 HS 0.00 543.99 E 585100,00 6003380.00 HS 0.00 543.99 E 585100,00 6003380.00 HS 0.00 556.80 E 585112,86 6003375.16 HS 0.00 559.85 E 585115.93 6003374.01 HS 0.00 572.04 E 585128.18 6003369.39 HS 0.00 644,50 E 585200,94 6003342.00 0.00 644.50 E 585200,94 6003342.00 0.00 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN # · O (Anadrill (c) 97 MPK43AP2 3.0C 10:59 AM P) Mar-06-97 11:16A Anadr .1 DPC 907 ~4 2160 P.04 . SE V ', " SHARED ICES DRILLING i ii i i imll I,, t - VERTICAL SECTION VIEW o ...... ection at: ~11.28 · TVD Scale.' ~ inch : ~000 feet 0 , Dep Scale.' ~ inch : ~000 feet Drawn ..... · 06 HaP ~g97 /nadrJ 11 Sch]umberger 0-- ~ Han~er IOentJf~cation MD BKB ~CTN INCLN A) TIE-IN S~VEY 49~8 4508 546 29.43 B) TOP ~ WINDON 4995 4575 560 29.75 C) KOP/CURVE 2/tO0 5000 457g 560 29.77 0 ........ - .... D) END 2/tO0 CURVE 6412 5889 9t4 ~B.J2 . E) TARGET ,~~w~ 7703 7116 ~316 ]8.12 F) 7' LINER POINT ~49 7446 ~424 ~B.12 0--- ,. G) TO ~49 7446 1424 ~8.12 ~.. -~ '~ ._ ..... ' AN~,DRILL AKA-DPC . I,PPRi3VE[} ........... 1 ~ _ ~ , - FORPERIdiT1 lNG ON LY " .... 'PLAN ~ ~ , :~:~ ' _ , i J ' . "' 500 tO00 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 , Sect ion DepartUre (~nac~r~]] (c)g? 1~43AP2 3.0C ti: 13 A.~ Pi Na~-O6-97 11:17A Anad~ .1 DPC 907 $4 2160 P.O5 I SHARED SERVICES DRIL'LING I · I I I I .oo \ t' ! MPK-43Ai (P02) _~~ , VERTIC, AL SECTION VIEW ~6oo- - Section at: lii.28 TVD Scale.: I inch = 400 feet 48oa-' [, . Dep Scale.: 1 inch = 400 feet sooo ...... ! : /ln, a~rill Schlumb, ergsr ' Marker Identification ND BKB SECTN INCLN ~ A) TIE,IN SURVEY 4918 4508 546 29.43 C) KoP/cURVE 2/i00 5000 4579 560 29.77 i_.. B) TOP O~ i~INDO~ 4995 4575 550 29.75 D) END 2/100 CURVE 64t2 5889 914 18.12 . E] TARGET .,~**~,~, 7703 T J F)7" LIaR POINT 8049 7446 1424 tB.i2 I G, ID 8049 7446 t424 ,8.i2 . ~00 600 800 looo ~200 't400 t600 ~800 ~000 ~00 ~400 ~00 ~800 3000 3~00 Section De a~ture Mar-06-97 11:17A Anadr .1 DPC 907 '$4 2160 P.06 I" .., S~'AREB SERV'ICES DRILLING i Marker IUentification A) TIE-IN SURVEY B) TOP OF'WINOOW C) KOP/CURVE 2/100 D) END 2/100 CURVE E) TARGET ~~*~ F) 7' LINER POINT G) TD MD 495B 4995 5000 64~2 7703 BO4g B04g N/S 1604 S ~642 S 1644 S 2083 S 2229 S 2268 S 2268 S E/N 39 39 170 ~ 544 E 645 E 645 E MPK-43Ai (PO2) PLAN VIEW CLOSURE. · ~3~e feet at Azimuth DECLINAllON.' +28.~40 (E) SCALE · J inch = 600 feet DRAWN. · 06 Mar 1997 2100 $1100 t500 1200 §00 600 300 0 300 600 900 t200 1500 1800 2100 · <- NEST · EAST -> (Ana~r~]] lc)g7 I/I)K43AP2 3.0C Ii: ]4 /iM P) Mar-O6-97 11:17A Anadr _ ,1 DPC 907 ~4 2160 P.O7 I SHARED SERVICES DRILLING m! i i i i . MPK-43Ai (P02) "'";'" '"'"" "~'"°" "° "" PLAN VIEW ,> ToP OF WINO0. 4995 ,8~2S C) KOP/CURVE 2/100 5000 ~64~ S 3g c LosUER 2358 feet at Azimuth ~64.14 El TARGET M..~,~..M~ 7703 2229 5 544 E F) 7' LXNE~ POZNT BO,9 ~e S ~5 E DECLINATION,' +28.240 (E) G) TD 8049 ~268 S 645 E SCALE · ~ inch = 200 feet DRAWN ' 06 Mar 1997 , ,, ANAD~ILL A~-DPC Anadrj]] Schlumberger APPROVED i i ~OR P[R~ ~TTi~ ~ ' ', . i ONLY , ~oo-- ....._ . ~ ,.['LAN ~ ~. _ , , I ~ ~ ·i} ~7oo .... J ~800 , i... 2000 ~ ~00 --~[ ....... ~ , - i . / ~00 T ........... { ............... T - - . . 2600 . . I I 2700- -- 2800 400 ~00 200 ~00 0 ~00 200 ~0 400 500 600 700' 800 <-WEST ' EASf -> (~aar~ll lc)g7 ~43~2 3.06 t1:~4 ~ P) !WELL PERMIT CHECKLISTco Y INIT CLASS" GEOL AREA PROGRAM: expn dev [] redrl~serv~wellbore segn ann disp para reqn ADMINISTRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary. . N 6. Well located proper distance from other wells. N 7. Sufficient acreage available in drilling unit. i i i i N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval. . N 13. Can permit be approved before 15-day wait ....... N ENGINEERING 14. Conductor string provided ................ Y N 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf cng. . Y N 17. CMT vol adequate to tie-in long string to surf cng . . . Y N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. N 22. Adequate wellbore separation proposed ......... N 23. If diverter required, is it adequate .......... -~-Y----N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ............. .F~._.__2_.~~ ..... ~.. %~ N 26. BOPE press rating adequate; test to ~' psig. ~_~ 27. Choke manifold complies w/kPI RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~< N 29. Is presence of E2S gas probable ............ .~/ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N// _ 31. Data presented on potential overpressure zones ..... Y/N 32. Seismic analysis of shallow gas zones ......... ./~ N /~.~F-~ 33. Seabed condition survey (if off-shore) ....... /./Y N'" ~ 34. Contact name/phone for weekly progress reports . . /. . Y N [explorator~ only] REMARKS GEOLOGY: ENGINEERING: COMMISSION: JDH~ mcm ~'~ Comments/Instructions: HOW/dlf - A:\FORMS\chekiist rev 01/97 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, informati~)n 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 Tue May 13 18:20:41 1997 Reel Header Service name ............. LISTPE Date ..................... 97/05/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/05/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER MILNE POINT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING MPK-43A 500292273801 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 13-MAY-97 I~D RUN 2 MWD RUN 3 MWD RUN 4 AK-MM-70049 AK-MM-70049 AK-MM-70049 G. TOBIAS B. ZIEMKE B. ZIEMKE P. WILSON J. PYRON J. PYRON 3 12N llE 3466 2028 .00 62.00 28.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2ND STRIN$ 3RD STRING PRODUCTION STRING REI¢~ARKS: 20.000 112.0 12.250 9.625 3814.0 8.500 8100.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ~qNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2 THROUGH 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROmaGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD) . 5. THERE ARE INTERMITTENT GAPS IN GAMMA RAY DATA (SGRC) DURING MWD RUN 2 DUE TO LOSS OF COMMUNICATION WITH THE SENSOR. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8100'MD, 7525'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY (CALIPER CORRECTED). SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIROMENTAL PARAMETERS USED FOR NUCLEAR/NEUTRON LOG PROCESSING: HOLE SIZE = MUD FILTRATE SALINITY = MUD WEIGHT = FORMATION WATER SALINITY = FLUID DENSITY = MATRIX DENSITY = LITHOLOGY = $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 800 PPM. 8.6 - 10.2 PPG. 14545 PPM. 1.o G/CC 2.65 G/CC SANDSTONE Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FI LE SUMMARY PBU TOOL CODE START FCNT 3804 NCNT 3804 NPHI 3804 FET 3804 RPD 3804 RPM 3804 RPS 3804 RPX 3804 GR 3804 DRHO 3805 RHOB 3805 PEF 3806 ROP 3840 $ BAS ELINE CURVE FOR SHIFTS: .5000 DEPTH 0 0 0 0 0 0 0 0 0 5 5 0 5 CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 3804.0 3808.5 3810.5 3814.5 3817.0 3820.5 3827.0 3829.0 3835.5 3837 0 3838 5 3840 0 3841 0 3845 5 3848 5 3851 5 3853 0 3854.5 3856.0 3857.5 3859.0 3861.0 3864.0 3868 0 3876 0 3878 0 3879 5 3889 0 3891 0 3893 5 3895 0 3897 0 3898 0 3900 5 3911 0 3912 0 3935 5 3939 0 3942 5 3950 0 3953 5 GR 3810.0 3814.5 3816.0 3820.0 3823.0 3825.5 3830.5 3832.0 3837.5 3839.0 3841.0 3841.5 3843.0 3848.5 3850.0 3851.5 3854.0 3857.0 3858.5 3860.0 3861 5 3863 0 3866 5 3869 5 3876 5 3881 0 3883 5 3894 0 3895 0 3896 5 3899 5 3901 5 3903 0 3905 5 3917.0 3918 5 3938 5 3942 0 3945 5 3950 0 3954 5 STOP DEPTH 7993 0 7993 0 7993 0 8019 0 8019 0 8019 0 8019 0 8019.0 8038.5 8027.5 8027.5 8028.0 8099.5 EQUIVALENT UNSHIFTED DEPTH -- 3956 5 3958 0 3960 5 3962 0 3965 0 3968 0 3971 0 3976 0 3977 0 3979 0 3982 5 3989 5 3992 5 3994 0 4004 5 4006 0 4006 5 4007 0 4007 5 4010 5 4012 0 4013 0 4014 5 4019 0 4022 0 4024 0 4025 5 4029 5 4032 5 4038 0 4039 5 4040 0 4043 0 4049 0 4050 5 4052 0 4054 0 4057.0 4059. 0 4061.5 4068.5 4073.5 4076.0 4077.0 4077.5 4079.0 4083.5 4085.0 4088 5 4091 0 4095 0 4098 0 4099 5 4102 0 4103 5 4105 5 4107 0 4108 5 4111 0 4115 0 4118 0 4123 0 4125 0 4126 5 3958 5 3960 5 3962 0 3964 0 3966 5 3972 0 3976 5 3979 5 3980 5 3982 0 3986 0 3991 5 3995 5 3997 0 4005 5 4007 5 4009 0 4010 0 4011 5 4013 0 4014 0 4015 5 4017 0 4020 0 4023 5 4025 5 4027 0 4030 5 4032 5 4037 5 4039 5 4042 0 4046 0 4050 0 4053 5 4054 5 4056 5 4059 0 4061 5 4064 0 4073 0 4075 0 4078 0 4079 5 4080 5 4081 5 4084 5 4086 0 4090 5 4092 5 4096 5 4100.0 4102.0 4105.0 4107.0 4108.5 4110.0 4112.5 4115.0 4117.5 4121.0 4125.5 4129. 0 4130.0 4135 4137 41~o 4142 4143 4145 4147 4152 4157 4160 4170 4171 4172 4174 4178 4180 4181 4181 4183 4184 4186 4243 4245 4249 4252 4254 4284 4286 4290 4292 4294 4297 4299 4300 4304 4305 4308 4312 4316 4319 4321 4323 4328 4329 4332 4334 4335 4338 4339 4341 4343 4346 4348 4353 4355 4361 4370 4375 4380 4383 4385 4402 4404 4405 5 0 0 5 0 5 0 0 5 0 5 5 5 5 5 0 5 0 5 0 5 5 5 5 0 5 5 5 5 5 .0 .0 5 0 5 5 5 0 5 0 0 0 5 5 5 0 0 5 5 5 5 4140 0 4141 5 4142 5 4144 5 4145 0 4147 0 4150 0 4154 5 4157 5 4162 5 4172 0 4173 5 4176 0 4177 5 4180 5 4183 0 4183 5 4184 5 4186 5 4188 5 4190 5 4245 0 4246 5 4250 5 4254.0 4257.0 4286.0 4288.5 4292.0 4294.0 4296 5 4298 0 4299 0 4300 0 4303 5 4305 5 4310.0 4314 0 4318 0 4320 5 4323 5 4325 5 4328 5 4330 5 4334.5 4336.0 4336 5 4339 5 4341 5 4343 0 4345 0 4348 0 4350.0 4354.5 4356 5 4362 0 4371 5 4375 5 4381 5 4384 5 4387 0 4403 0 4405 5 4407 0 4410 5 4420 0 4422 0 4434 0 4444 0 4456 5 4465 0 4468 5 4472 5 4475 5 4479 0 4482 5 4487 0 4494 0 4499 0 4500 0 4502 0 4506 5 4509 5 4513 0 4517 5 4521 0 4522 5 4524 5 4532 0 4536 0 4538 0 4540 0 4545 0 4546 5 4557 0 4571 5 4573.5 4575 0 4578 0 4580 5 4584 0 4586 0 4588 0 4589 5 4591 5 4598 0 4613 0 4616 5 4618 0 4620 0 4621 5 4623 5 4628 0 4634 0 4636 0 4638 5 4640 0 4641 5 4651 5 4654 5 4679 5 4699 5 4711 0 4714 5 4717 5 4721 5 4805 0 4810 0 4412 5 4422 5 4425 0 4436 0 4446 0 4458 5 4467 0 4470 5 4474 5 4478 0 4481 5 4485 5 4489 5 4496 5 4501 0 4502 0 4503 5 4507 5 4512 0 4516 0 4519 0 4524 0 4526 0 4527 0 4534 5 4538 5 4540 5 4543 0 4549.5 4551 0 4560 0 4573 5 4576 0 4577 5 4580 5 4582 5 4584 5 4587.0 4590.5 4592.5 4594.0 4600.0 4615.0 4619.0 4621.0 4623.5 4624.0 4627.5 4633 0 4639 5 4641 0 4642 5 4643 5 4645 0 4654.0 4656 5 4683 5 4704 5 4712 5 4716 5 4721 5 4725 5 4808 0 4813 0 4816 5 4820 0 4822 0 4824 5 4827 5 4831 0 4837 0 4839 0 4852 0 4854 5 4857 5 4861 5 4864 5 4873 5 4877 0 4906 0 4907 5 4911 0 4919 5 4932 0 4942 5 4949 5 4955 0 4960 5 4965 0 4970 0 4985 5 4987 5 5006 0 5010 5 5012 5 5015 5 5018 0 5036.0 5039.0 5041.0 5046 0 5051 5 5054 5 5056 0 5057 0 5060 5 5062 5 5064 5 5066 5 5071 5 5073 0 5082 5 5084 5 5101 5 5107 5 5116 5 5118 0 5123 0 5124 0 5130 5 5136 5 5142 0 5146 5 5148 0 5149 0 5152 0 5159 0 5169 0 4820 0 4822 5 4825 5 4827 5 4830 0 4835 0 4841 0 4842 0 4856 0 4856 5 4861 0 4863 5 4867 0 4876 5 4879 0 4909 0 4910 5 4913 0 4920 5 4933 0 4944 0 4951 5 4957 0 4963 0 4967 0 4971 0 4987.0 4989 5 5007 0 5013 0 5015 0 5018 0 5021 5 5038 0 5040 5 5043 5 5048 0 5053 0 5056 5 5058 0 5059 5 5062.5 5064.5 5067.5 5069.5 5072.5 5074.5 5086 5 5088 0 5105 5 5108 0 5124 0 5125 0 5129 5 5131 5 5137 5 5140 5 5145 5 5150 5 5152 5 5153 5 5158 0 5165 5 5174 0 5174 5180 5188 5190 5196 5202 5203 5218 5227 5228 5232 5236 5244 5250 5252 5253 5255 5262. 5298 5302 5313 5321 5326 5328 5332 5338 5349 5359 5365 5376 5380 5382 5398 5415 5424 5428 5443 5456 5459 5483 5492 5494 5504. 5518. 5530. 5544. 5556. 5564. 5571. 5574 5575 5627 5642 5652 5653 5654 5655 5657 5659 5661 5663 5717 5727 5808 5179 5184 5193 5194 5200 5205 5207 5221 5230 5232 5234 5238 5245 5252 5254 5256 5258 5264 5298 5303 5315 5323 5329 5330 5335 5341 5351 5361 5367 5379 5382 5384 5401 5416 5426 5429 5444 5459 5461 5485 5493 5494 5504 5520 5532 5542 5555 5562 5568 5572 5574 5628 5646 5656 5658 5659 5660 5661 5663 5666 5668 5721 5730 5808 0 0 0 5 5 0 5 5 5 5 5 5 5 5 5 0 5 0 0 5 0 5 5 5 5 5 5 0 5 5 5 5 0 5 0 0 5 5 5 5 5 5 0 0 0 5 0 5 5 0 .5 0 5 0 0 0 5 5 5 5 0 0 5 0 5815 5818 5962 5971 5974 5975 6013 6026 6029 6030 6311 6313 6356 6367 6368 6596 6633 6671 6676 6702 6706 6760 6767 6774 6775 6776 6778 6782 6783 6787 6790 6791 6794 6796 6798 6800 6807 6829 6830 6833 6839 6843 6846 6849 6854 6855 6860 6864 6870 6873 6877 6881 6885 6888 6892 6896 6907 6913 6915 6917 6920 6922 6933 6941 5819 5 5821 0 5968 0 5974 5 5977 0 5978 0 6016 5 6029 5 6032 0 6033 5 6312 0 6314 5 6360 0 6368 5 6370 5 6603 0 6635 5 6674 0 6679 0 6705 5 6707 5 67 63 5 6770 0 6776 5 6777 5 6778.5 6780.5 6783.5 6786.5 6789.5 6791.5 6793.5 6795.5 6798 0 6801 0 6802 0 6809 5 6831 5 6833 0 6836 5 6841.0 6845.5 6849.0 6851.0 6859.0 6860.5 6863.0 6866 0 6875 5 6878 5 6880 5 6883 0 6887 0 6890 0 6893 0 6897 5 6909 5 6915 0 6917 0 6919 5 6921 5 6924 5 6932 5 6944 0 6945 0 6949 5 6958 5 6960 5 6966 5 6968 0 6969 5 6971 0 6990 0 6991 0 6992 5 6995 5 6999 0 7000 0 7004 0 7005 5 7008 5 7011.5 7015.0 7017. 0 7053.5 7058.0 7064.5 7071 0 7087 0 7088 0 7095 0 7100 5 7102 5 7105 5 7109 0 7110 5 7113 0 7115 5 7119 5 7121 0 7126 5 7128 5 7131 0 7135 5 7139 0 7141 5 7144 5 7147 0 7148 5 7150 0 7151 5 7154 5 7158 0 7161 0 7162 5 7164 0 7169 0 7170 5 7174 5 7175 5 7180 0 7181 5 7184 5 7186 5 7187.5 7188.5 7189.5 7191.5 6946 5 6950 5 6959 5 6962 5 6967 0 6968 5 6973 0 6974 5 6992 5 6993 5 6995 0 6998 0 7001 0 7002 0 7005 5 7007 0 7010 0 7013 0 7016.5 7018 5 7055 0 7059 0 7066 0 7071 5 7089 0 7090 0 7097 0 7102 5 7104 5 7106.5 7111 0 7112 0 7114 5 7117 5 7123 0 7124 5 7128 5 7129 5 7133 0 7137 5 7139 5 7143 0 7146 0 7148.5 7150 0 7151 5 7153 5 7157 0 7159 5 7162 0 7164 0 7167 0 7171 0 7172 5 7176 5 7178 0 7181 5 7183.0 7186 0 7188 0 7189 5 7190 0 7191 5 7193 0 7193 0 7195 5 7197 5 7200 0 7204 0 7206 5 7213 5 7220 0 7222 0 7224 0 7226 5 7228 0 7230 5 7235 5 7243 5 7253 0 7254 5 7273 0 7274 5 7312 0 7315 0 7320 0 7338 0 7339 5 7341 0 7362 5 7364 0 7380.0 7381.5 7393.0 7394.5 7421 0 7422 5 7424 5 7428 5 7430 5 7436 5 7439 0 7441 5 7444.0 7461 5 7474 5 7487 0 7489 0 7492 0 7553 0 7554 5 7585 5 7593 0 7595 0 7596 0 7597 0 7636 5 7651 5 7656 5 7702 5 7705 0 7706 0 7712 0 7714 0 7727 0 7729 0 7732 5 7741 5 7195 0 7197 7199 5 7201 5 7206 0 7209 0 7216 5 7222 5 7224 5 7226 5 7228 5 7230 0 7233 0 7239 0 7244 0 7255 5 7257 0 7276 0 7278 5 7312 0 7317 5 7322 5 7339 5 7342 0 7343 5 7364 5 7365 5 7381 5 7382 5 7394 5 7396 0 7421 5 7423 5 7425 5 7429 0 7431 5 7437 5 7439 5 7442 5 7444 5 7463 0 7475 0 7489 0 7490 5 7492 5 7554 0 7555 0 7586 0 7593 5 7596 0 7597 0 7599 0 7637 5 7653 0 7657 5 7704 0 7705 0 7709 5 7714 0 7716 5 7727 5 7729 5 7733 0 7742 5 7743 0 7747 7753 7755 7757 7757 7767 7781 7789 7880 7885 8099 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD REMARKS: 7744 0 7748 5 7752 5 7755 0 7757 0 7758 5 7767 5 7782 0 7790 0 7879 0 7886 0 8100 0 BIT RUN NO MERGE TOP MERGE BASE 2 3842.0 4800.0 3 4800.0 6276.0 4 6276.0 8100.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 RPX MWD OHM~ 4 1 68 12 4 RPS M~D OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHM~ 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD P.U. 4 1 68 32 9 NCNT MWD CNTS 4 1 68 36 10 FCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CC 4 1 68 44 12 DRHO MWD G/CC 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 Name DEPT ROP GR RPX RPS RPM RPD FET Min 3804 4 2784 10 5109 0 4486 0 4343 0 4159 0 2667 0 2014 First Max Mean Nsam Reading 8099.5 5951.75 8592 3804 954.409 204.357 8519 3840.5 477.549 87.7849 8364 3804 34.2752 3.02723 8431 3804 41.3742 3.11086 8431 3804 2000 3.80816 8431 3804 2000 3.33086 8431 3804 58.6919 1.70907 8431 3804 Last Reading 8099.5 8099.5 8038.5 8019 8019 8019 8019 8019 NPHI i6.~!36 81.7622 44.1617 8379 NCNT 2008 3745.85 2635.44 8379 FCNT 413 1286.22 619.847 8379 RHOB 1.3164 3.0893 2.29007 8445 DRHO -0.123 0.4084 0.0402825 8445 PEF 1.5748 10.8115 2.48414 8445 3804 3804 3804 3805.5 3805.5 3806 7993 7993 7993 8027.5 8027.5 8028 First Reading For Entire File .......... 3804 Last Reading For Entire File ........... 8099.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI FET RPD RPM RPS RPX GR DRHO RHOB PEF ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. 2 .5000 START DEPTH 3810.0 3810.0 3810.0 3810.0 3810.0 3810.0 3810 0 3810 0 3810 0 3811 5 3811 5 3812 0 3842 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: STOP DEPTH 4800.0 4800.0 4800.0 4800.0 4800.0 4800.0 4800.0 4800.0 4800.0 4800.0 4800.0 4800.0 4800.0 05-MAR-97 4.96 CIM 5.46 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 AJgGLE: NtAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAM~A RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABI. LITHO DENSITY $ 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MEMORY 4800.0 3842.0 4800.0 29.4 33.3 TOOL NUMBER P0661CRDGP6 P0661CRDGP6 P0661CRDGP6 P0661CRDGP6 8.500 8.5 LSND 10.20 42.0 9.7 8OO 4.6 2.600 1.529 2.200 2.800 66.1 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 RPX ~gWD 2 OHM~ 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 ! 68 FET MI,~D 2 HOUR 4 1 68 NPHI I~D 2 P.U. 4 ! 68 FCNT NK,~D 2 CNTS 4 i 68 NCNT MWD 2 CNTS 4 1 68 RHOB I4I,~D 2 G/CC 4 1 68 DRHO M?~D 2 G/CC 4 ! 68 PEF M~D 2 BARN 4 1 68 24 28 32 36 40 44 48 52 7 8 9 10 11 12 13 14 Name Min Max Mean Nsam DEPT 3810 4800 4305 1981 GR 10.5109 231.294 54.0452 1880 ROP 24.384 954.409 343.868 1916 RPX 1.0566 34.2752 5.04072 1981 RPS 1.0679 41.3742 5.30894 1981 RPM 1.0811 2000 6.14548 1981 RPD 1.095 2000 6.23699 1981 FET 0.2014 58.6919 2.19647 1981 NPHI 23.935 72.4628 43.8722 1981 FCNT 413 743 546.207 1981 NCNT 2008 3306.01 2635.75 1981 RHOB 1.3164 2.6387 2.11682 1978 DRHO -0.065 0.5372 0.0766955 1978 PEF 1.5748 5.9843 2.29722 1977 First Reading 3810 3810 3842.5 3810 3810 3810 3810 3810 3810 3810 3810 3811.5 3811.5 3812 Last Reading 4800 4800 4800 4800 4800 4800 4800 4800 4800 4800 4800 4800 4800 4800 First Reading For Entire File .......... 3810 Last Reading For Entire File ........... 4800 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUNmDXRY VENDOR TOOL COEE START DEPTH PEF 4800 5 DRHO 4800 5 RHOB 4800 5 FCNT 4800 5 NCNT 4800 5 NPHI 4800 5 FET 4800 5 RPD 4800.5 RPM 4800.5 RPS 4800.5 RPX 4800.5 GR 4800.5 ROP 4800.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM A/qGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABI. LITHO DENSITY $ BOREHOLE ]~_ND 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): Iv[UD 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: STOP DEPTH 6207 0 6206 5 6206 5 6172 0 6172 0 6172 0 6198 0 6198 0 6198 0 6198 0 6198 0 6217 5 6276 5 08-MAR-97 4.96 CIM 5.46 MEMORY 6276.0 4800.0 6276.0 17.7 29.0 TOOL NUMBER P0670CRDGP6 P0670CRDGP6 P0670CRDGP6 P0670CRDGP6 8.500 8.5 LSND 10.20 44.O 9.3 8OO 5.0 2.600 1.903 2.200 2.800 48.9 $ 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 3 AAPI 4 1 RPX MWD 3 OHMM 4 1 RPS I~D 3 OHN94 4 1 RPM MWD 3 OHMM 4 1 RPD MWD 3 OHM~ 4 1 NPHI MWD 3 P.U. 4 1 ROP MWD 3 FT/H 4 1 FET MWD 3 HOUR 4 1 FCNT MWD 3 CNTS 4 1 NCNT MWD 3 CNTS 4 1 RHOB MWD 3 G/CC 4 1 DRHO MWD 3 G/CC 4 1 PEF MWD 3 BARN 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name DEPT GR RPX RPS RPM RPD NPHI ROP FET FCNT NCNT RHOB DRHO PEF Min 4800.5 27 1161 0 4486 0 4343 0 4159 0 2667 16 8136 4 2784 0 3284 422.5 2248 1.7158 -0.066 1.8164 Max Mean Nsam 6276.5 5538.5 2953 124.296 82.2692 2835 25.8634 2.56693 2796 20.9652 2.61843 2796 2000 4.14189 2796 9.3317 2.62336 2796 67.3763 42.1747 2744 864.886 206.647 2953 3.1401 1.07262 2796 1003 621.116 2744 3605.27 2671.94 2744 2.6609 2.2942 2813 0.3191 0.0303729 2813 4.8031 2.5509 2814 First Reading 4800.5 4800.5 4800.5 4800 5 4800 5 4800 5 4800 5 4800 5 4800 5 4800 5 4800 5 4800 5 4800 5 4800 5 Last Reading 6276.5 6217.5 6198 6198 6198 6198 6172 6276.5 6198 6172 6172 6206.5 6206.5 6207 First Reading For Entire File .......... 4800.5 Last Reading For Entire File ........... 6276.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE H~ADER FILE NUMBER: 4 KAW MWD Curves and log header data for each bit r~n in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT NCNT NPHI FET RPD RPM RPS RPX PEF DRHO RHOB GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 6175 5 6175 5 6175 5 6199 0 6199 0 6199 0 6199 0 6199 0 6210 0 6210.0 6210.0 6221. 0 6280.0 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: STOP DEPTH 7993.5 7993.5 7993.5 8019.5 8019.5 8019.5 8019.5 8019.5 8028.5 8O28.0 8028.0 8039.0 8100.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABI. LITHO DENSITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS 09-MAR-97 4.96 CIM 5.46 MEMORY 8100.0 6276.0 8100.0 12.5 17.8 TOOL NUMBER P0670CRDGP6 P0670CRDGP6 P0670CRDGP6 P0670CRDGP6 8.500 8.5 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHN/{) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT IzuXX CIRCULATING TERMPERATURE: MUD FILTP_ATE 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 10.20 44.0 8.9 8OO 4.0 2.600 1.519 2.200 2.800 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 RPX MWD 4 OHMM 4 1 68 8 3 RPS MWD 4 OHMM 4 1 68 12 4 RPM MWD 4 OHMS4 4 1 68 16 5 RPD MWD 4 OHMM 4 1 68 20 6 NPHI MWD 4 P.U. 4 1 68 24 7 ROP MWD 4 FT/H 4 1 68 28 8 FET MWD 4 HOUR 4 1 68 32 9 FCNT MWD 4 CNTS 4 1 68 36 10 NCNT MWD 4 CNTS 4 t 68 40 11 RHOB MWD 4 G/CC 4 1 68 44 12 DRHO MWD 4 G/CC 4 1 68 48 13 PEF MWD 4 BARN 4 1 68 52 14 66.7 Name DEFT GR RPX RPS RPM RPD NPHI ROP FET Min 6175.5 29 5315 0 6541 0 6863 0 6551 0 7125 16 8649 8 0364 0 3604 First Max Mean Nsam Reading 8100 7137.75 3850 6175.5 477.549 109.447 3637 6221 20.0608 2.28576 3642 6199 19.8459 2.29725 3642 6199 17.8932 2.28922 3642 6199 14.7432 2.29951 3642 6199 81.7622 45.7144 3637 6175.5 612.891 129.121 3641 6280 14.8694 1.8074 3642 6199 Last Reading 8100 8039 8019.5 8019.5 8019.5 8019.5 7993.5 8100 8019.5 FCNT 449.323 - 1286.22 659.757 3637 NCNT 2072 3745.85 2608.91 3637 RHOB 2.1513 3.0893 2.38357 3637 DRHO -0.205 0.2856 0.0283294 3637 PEF 1.7593 10.8115 2.53389 3638 6175.5 7993.5 6175.5 7993.5 6210 8028 6210 8028 6210 8028.5 First Reading For Entire File .......... 6175.5 Last Reading For Entire File ........... 8100 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/05/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 97/05/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAME : MPK-43A FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22738-01 REFERENCE NO : 97193 * ALASKA COMPUTING CENTER * . . . ............................ . ....... SCHLUMBERGER . ............................ . COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAME : MPK-43A FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22738-01 REFERENCE NO : 97193 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 09:25 PAGE: **** REEL H~ER **** SERVICE NAME : EDIT DATE : 97/05/ 7 ORIGIN : FLIC REEL NABIE : 97193 CONTINUATION # : PREVIOUS REEL : CO~2~ENT : B.P. EXPLORATION, MPK-43A, MILNE POINT, API #50-029~22738-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/05/ 7 ORIGIN : FLIC TAPE NAME : 97193 CONTINUATION # : 1 PREVIOUS TAPE : COFk~ENT : B.P. EXPLORATION, MPK-43A, MILNE POINT, API #50-029-22738-01 TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NAME: MPK-43A API NUMBER: 500292273801 OPERATOR: BP Exploration (Alaska) , Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 7-MAY- 97 JOB NUMBER: 97193 LOGGING ENGINEER: DANIEL PALME OPERATOR WITNESS: LEE HINKEL SURFACE LOCATION SECTION: 3 TOWNSHIP: 12N RANGE: liE FNL: FSL: FEL: FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: 62. O0 DERRICK FLOOR: 62.00 GROUND LEVEL: 28.20 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 8077.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 09:25 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: NONE LDWG CURVE CODE: NONE RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH $ REbfARKS: THIS IS THE PDC LOG FOR THIS WELL, FROM A CBT LOGGED BY SCHLUMBERGER ON 19-MAR-97. NO DEPTH CORRECTIONS WERE MADE. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUbtBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 7886.0 3445.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUb!BER : BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH GRCH REMARKS: THIS IS THE CLIPPED DATA FROM THE PDC GR (CBT) LOGGED 19-MAR-97 BY SCHLUMBERGER. LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 09:25 PAGE: $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 553834 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GR GAPI 553834 O0 000 O0 0 1 1 1 4 68 0000000000 TENS GR LB 553834 O0 000 O0 0 1 1 1 4 68 0000000000 CCL GR V 553834 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7920.000 GRCH. GR -999.250 TENS.GR 2650.000 CCL.GR DEPT. 7000.000 GRCH. GR 75.245 TENS.GR 2975.000 CCL.GR DEPT. 6000.000 GRCH. GR 64.267 TENS.GR 2733.000 CCL.GR -999.250 -0.158 0.113 DEPT. 5000.000 GRCH. GR 51.634 TENS.GR 2248.000 CCL.GR -0.145 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 09:25 PAGE '. DEPT. 4000.000 GRCH. GR DEPT. 3445. 000 GRCH. GR 42.332 TENS.GR 14.740 TENS.GR 1766.000 CCL.GR 1621.000 CCL.GR -0.133 -0. 057 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION . O01CO1 DATE : 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH 7920.0 3445.0 GR LOG HEADER DATA DATE LOGGED: 19 -MAR- 97 SOFTWARE VERSION: 8C0 - 609 TIME LOGGER ON BOTTOM: 1200 19-MAR-97 TD DRILLER (FT) : 7963.0 TD LOGGER (FT) : 7963.0 TOP LOG INTERVAL (FT) : 3450.0 BOTTOM LOG INTERVAL (FT) : 791 O. 0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): YES LIS~ Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 09:25 PAGE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMPIA RAY $ TOOL NUMBER SGTL 1379 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 8.500 8077.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TE~IPERAT~ (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BRINE / DIESEL 10.20 10.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : FAR COUN~f RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: PRIMARY DEPTH CONTROL PROCEEDURES APPLIED CBTE RAN CENTRALIZED. BOND LOG SHOWS GOOD CEMENT TO 5600 DATN READING LOW IN SOME WELL CEMENTED ZONE DUE TO VERY LO CEMENT BOND LOG RAN TO 3600. $ LIS FORMAT DATA LISt Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 09:25 PAGE: 6 * * DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN** NARIE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553834 O0 000 O0 0 2 1 1 4 68 0000000000 GR GR GAPI 553834 O0 000 O0 0 2 1 1 4 68 0000000000 TENS GR LB 553834 O0 000 O0 0 2 1 1 4 68 0000000000 CCL GR V 553834 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7920.500 GR.GR 37.584 TENS.GR 2016.000 CCL.GR DEPT. 7000.000 GR.GR 75.245 TENS.GR 2975.000 CCL.GR DEPT. 6000.000 GR.GR 64.267 TENS. GR 2733.000 CCL.GR DEPT. 5000.000 GR.GR 51.634 TENS.GR 2248.000 CCL.GR DEPT. 4000. 000 GR. GR 42. 332 TENS. GR 1766. 000 CCL. GR DEPT. 3443.500 CR.GR 16.581 TENS.GR 1551.000 CCL.GR -0. 010 -0.158 0.113 -0.145 -0.133 -999.250 ** END OF DATA ** LIS4 Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 09:25 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 97/05/ 7 ORIGIN ' FLIC TAPE NAME : 97193 CONTINUATION # : 1 PREVIOUS TAPE : COBk4ENT ' B.P. EXPLORATION, MPK-43A, MILNE POINT, API #50-029-22738-01 **** REEL TRAILER **** SERVICE NAF~ : EDIT DATE · 97/05/ 7 ORIGIN : FLIC REEL NAME : 97193 CONTINUATION # : PREVIOUS REEL : CO~mNT : B.P. EXPLORATION, MPK-43A, MILNE POINT, API #50-029-22738-01