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201-010
MEMORANDUM TO: Jim Regg 'Re 5-/7'Z(TLI P. I. Supervisor yC FROM: JeffJones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 13, 2021 SUBJECT: Mechanical Integrity Tests Hilcom North Slope, LLC 16-05A PRUDHOE BAY UNIT 16-05A Src: Inspector Reviewed By,�:{�� P.I.Supry �_ Comm Well Name PRUDHOE BAY UNIT 16-05A API Well Number 50-029-20574-01-00 Inspector Name: JeffJones Permit Number: 201-010-0 Inspection Date: 4/3/2021 . Insp Num: miU1210403134925 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 16-05A Type 11 j w 'pyD 1 8861 Tubing 1846 1887 - 1584 - 1583 PTD 2010100 - Type Test SPT' Test psi 2140 IA 344 2274 ' 2264 2258 ' BBL Pumped: 1.9 BBL Returned: 19 OA a1 z7a - z81 z79 - Interval 4YRTST P/F P Notes: I well inspected, no exceptions noted. Tuesday, April 13, 2021 Paye I of I Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Thursday, March 25, 2021 3:22 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Bo York; Stan Golis; Worthington, Aras J; Oliver Sternicki; John Condio - (C) Subject: OPERABLE: Injector 16-05 (PTD #2010100) AOGCC MIT -IA required Mr. Wallace, Injector 16-05 (PTD #2010100) surface kit repair is complete and the well is ready to be put on injection. An AOGCC witnessed MIT -IA will be performed once the well is thermally stable. The well is now classed as OPERABLE. Please respond with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan. Holt(& H ilcoro.com P:(907)659-5102 M:(907)232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Friday, February 9, 2018 8:14 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOpsLead@bp.com>; AK, OPS FS2 Facility OTL <AKOPSFS2FacilityOTL@bp.com>; AK, OPS FS2 Field OTL <AKOPSFS2FieldOTL@bp.com>; AK, OPS FS2 OSM <AKOPSFS20SM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; Ohms, Danielle H <Danielle.Ohms@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempseyl@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'Connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>;'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: NOT OPERABLE: Injector 16-05 (PTD #2010100) AOGCC MIT -IA will lapse All, Injector 16-05 (PTD #2010100) is currently shut in for surface kit issues and will not be brought online before its 4 year AOGCC witnessed MIT -IA is due in April 2018. At this time the well is reclassified as NOT OPERABLE and will remain shut in and secured until the surface issues are resolved. Please respond with any questions, • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, February 9, 2018 8:14 AM To: AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OIL;AK, OPS FS2 Field OTL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; G GPB FS2 Drillsites; Ohms, Danielle H;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK,GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel,Joshua;Worthington,Aras J; Regg,James B (DOA) Subject: NOT OPERABLE: Injector 16-05 (PTD#2010100)AOGCC MIT-IA will lapse All, Injector 16-05 (PTD#2010100) is currently shut in for surface kit issues and will not be brought online before its 4 year AOGCC witnessed MIT-IA is due in April 2018. At this time the well is reclassified as NOT OPERABLE and will remain shut in and secured until the surface issues are resolved. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED 1 • r * 6,1' \. I'/7j%e,?, i E STATE A .5T, C i'.. C:'� GEE. U. t =_:::-:-=A-'-'4., 333 West $PVE nl l Avenue {{" ( OV'ERN::OR SEAN PA RN EI Anchorage PIOKO 9950 572 �' Main 907_97y 1433 Dave Bjork SOWED JUL 2 ZDj4 Engineering Team Leader BP Exploration (Alaska), Inc. aoi_ OI0 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 16-05A Sundry Number: 314-015 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, def4/1 p 9:x_ i,54..,..._Cathy Poerster J- Chair J DATED this I4 day of January, 2014. Encl. • STATE OF ALASKA & R F - _ ALASKA OIL AND GAS CONSERVATION COMMISSION 1,,.!(', / / APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 '���� f � 1. Type of Request: ❑Abandon 0 Plug for Redrill 0 Perforate New Pool ®Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate ®Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing ®Other 7"Scab Liner 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. ❑Exploratory ❑Stratigraphic 201-010 ' 3. Address: ❑Development ®Service • 6. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-20574-01-00 . 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 16-05A Will planned perforations require a Spacing Exception? ❑Yes ®No 9. Property Designatior 10.Field/Pool(s): ADL 028332&028346 • Prudhoe Bay/Prudhoe Bay • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12320' - 9070' • 12277' 9062' 9542' None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1530 520 Surface 2669' 13-3/8" 2669' 2669' 4930 2670 Intermediate 9878' 9-5/8" 9878' 8891' 6870 4760 Production Liner 414' 7" 9567-9981' 8603'-8987' 8160 7020 Liner 3770' 3-1/2"x 3-3/16"x 2-7/8" 9445'- 13215' 8492'-9069' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9995'- 12215' 9000'-9050' 5-1/2", 17#x 4-1/2", 12.6# L-80 9616' Packers and SSSV Type: 9-5/8"x 5-1/2" Baker SAB Packer Packers and SSSV 9520'/8560' MD(ft)and ND(ft): 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service 14. Estimated Date forFzLro� 15. Well Status after proposed work: Commencing Operation: t' Afffif 16,2014 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: ®WAG ❑SPLUG 0 Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Carolyn Kirchner,564-4190 Printed Name: Dave Bjoorrk• 5e,, M`L c,, .c..rTitle: Engineering Team Leader Email: Carolyn.Kirchner@bp.com Signature: am , ( Phone: 564-5683 Date: 1 l 7 / 1 '-1 /\j Commission Use Only / Conditions of approval: Notify Commission so that a representativewit 2 10 2014 Sundry Number: Jt 15 RBDM • ❑Plug Integrity\• BOP Test 0 Mechanical Integrity Test 0 Location earance Other:30p re 5 f 7---0- .3 5---6 0 p 5/ Ai 1i t v, rea 41/-ter _5 fa' i �� e(.4 iel e ch90 (Sfw/e fri/r11) 6'Ci Spacing Exception Required? ❑Yes Di No Subsequent Form Required: / 0 _,-4 O/l, APPROVED BY Approved By: ot/ ,9u.ait____ COMMISSIONER THE COMMISSION Date: /-/4-'/ (-( Form 10-403 Revised 1f/2012 Appro a I 12...months from the date of approvalSubmit In Duplicate V1-F I /I/0ln' R'�Q �`'I / .1 by 0 Sundry Request for casing repair Well: 16-05a Date: 12/19/13 Engineer: Carolyn Kirchner MASP: 2605 psi Well Type: WAG Injector Estimated Start date: 15, 2014 cz History: Well 16-05 (parent) is a pre-produced injector that was drilled and completed in April 1981. It was not produced for very long before being converted to a seawater injector in November of 1984. In 1994 the well was swapped to produced water injection. Zone 2 and Zone 3 perfs were added in 1996. On May 12, 1998 the well was isolated back up to only Zone 4 perfs with a sand dump. It continued to inject produced water in only Zone 4 until it was later sidetracked as part of an injector/producer pair with 16-06A, which has since been sidetracked. On March 9, 2001 16-05 was sidetracked to be 16-05A. It was completed as a horizontal well undulating from the 45P up to the 46P and then back down into the 45P. The well has a 2-7/8" liner which is cemented and perforated. It crosses over two faults with the perfs in the 45P being in the HOT and the central 46P perfs being in a swept section between the faults above the HOT. Due to the completion location the well has had very poor injectivity since being put on produced water in 2001. Immediately following initial perfs it was realized that the well would not take water so an acid stimulation was completed which was relatively successful. The rates desired were not attainable after only a couple months of injection, so perforations were added to the entirety of the lateral. This section of the field borders the periphery and wells completed in the area have productivity/injectivity issues mostly caused by the presence of HOT in the area. 16-05A continued to inject at very low rates and was never proven to have communication with the offset producers except when on MI. The well had two bulbs of MI to which some brief response was seen in 16-25 and 16-23A. This would seem to indicate the majority of injection was entering the heel perfs which were located on the west side of the fault in the HOT. In February 2006 the well was finally shut-in for low injectivity and the well was placed on the LTSI list. In 2009 a static run tagged at 10018' MD above all the perfs and recovered schmoo. A SBG was completed, but immediately after the well was put back on injection it was shut-in again due to a failing MIT-IA (10/29/2009). A LLR of 0.5bpm at 3000psi was established. In September 2010 another MIT-T was completed and passed to 3000psi proving good tubing integrity, but the MIT-IA failed with a LLR of 3.5bpm at 1750psi. Reservoir Management has a new subsurface injection target (AYS) in this area to support producers 16- 23A, 16-08A, and 16-26A; the only other offset injector, 16-10A, is far to the southwest. There was a plan to drill an injector in close proximity to the heel of 16-05A to sweep this target. Base management suggested utilizing the pre-existing 16-05A wellbore and adding and add perfs at the heel. This option would provide the desired sweep of the target without the cost of a new well. The perfs were added November 2011 and the well was waivered put on injection for a two week test period to confirm heel is above the HOTS and the injectivity around the heel is adequate enough to attain the injection target of 5000 bwpd. The well was able to obtain targeted injection rates confirming 16-05A will be able to provide the sweep for the AYS target. Scope of Work: Pull 5-1/2" L-80 completion. Run 7"scab liner. Run 4-1/2"x5-1/2" L-80 completion. Pre Rig Prep Work: S 1 Pull WRP, SBHP, run 5-1/2" RBP at—9428' MD in pup joint above GLM #12. Cover with sand to 9400' MD. Drift for jet cut. F 2 MIT-T to 3,000 psi, MIT-OA to 2,000 psi. E 3 Jet cut tubing @ —9,380'. Reference SLB Perforating Depth Control Memory GR/CCL log March 7, 2001. Cut desired to be 2' from the top, in first full joint above the CT liner top. F 4 Circulate well through the cut with 8.5 ppg seawater and diesel freeze protect to 2,500' MD. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T& IC. ✓ 6 Set BPV. O 7 Remove the wellhouse&flow line. Level the pad as needed for the rig. Proposed RWO Procedure: 1. MIRU Doyon 14. ND tree. NU and test BOPE with four preventers configured top down (annular, 7" fixed, blind shears, mud cross' and 3-1/2"x 6"VBR's). Test the VBR's and annular to 3,500 psi. 2. Pull and lay down tubing to the jet cut. 3. Scrape 9-5/8" casing and dress-off 5-1/2"tubing stub. +{ 4. Run 9-5/8"test packer to 3,600' and test casing to 3,500 psi A1 5. Run 5-1/2" overshot, 7"scab liner, liner hanger, and liner top packer. �S r 6. Cement 7" scab liner to 3,500'. '' 7. Drill out shoe track. Pressure test casing to 3,500 psi. 8. Change-out inner casing pack-off. 9. Run new 5.5" x 4.5" 13Cr completion with 7"x 4-1/2" packer. MIT-T& MIT-IA to 3,500 psi. 10. Set a BPV and RDMO. Post ri Work ✓ 1 Pull BPV S 2 Pull B&R, pull RHC seat TREE_• FMC -WELLHEAD FMC SAFETY NOTES:H2S READINGS AVERAGE 125 ppm __.._ __.. _______.__ WHEN ON MI.WELL REQUIRES A SSSV WHEN ON 'ACTUATOR= AXELSON -O 5A MI. WELL ANGLE>—70°@ 1009W. KB ELEV= 72' BF ELEV= KOP= 9974' 2313' -15-1/2"OTIS RQM SSSV NIP,ID=4.562" Max Angle= 100°@ 10577' r.. Datum MD= 9857' GAS LIFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2977 2976 7 OTIS DMY R0-3 RK 04/24/81 2 5159 4888 36 OTIS DMY R0-3 RK 04/24/81 13-3/8"CSG,72#,L-80, ID=12.347" H 2669' 3 6792 6205 34 OTIS DMY R0-3 RK 0424/81 4 7798 7064 33 OTIS DMY RO-3 RK 04/24/81 Minimum ID = 2.441" @ 10004' 5 8455 7618 31 OTIS DMY RO-3 RK 04/24/81 6 8529 7682 30 OTIS DMY R0-3 RK 04/24/81 3-3116" X2-718" X0I L 7 8878 7986 28 OTIS DMY R0-3 RK 0424/81 8 8953 8052 28 OTIS DMY RO-3 RK 04/24/81 9 9222 8292 26 OTIS DMY R0-3 RK 04/24/81 BAKER 4-3/8"X 4"TIEBACK, ID=4.00" -1 9445' 1 10 9296 8357 26 OTIS DMY R0-3 RK 04/24/81 11 9369 8424 26 OTIS DMY RO-5 RK 12/26/93 BAKERDEPLOYMENTSLV, ID-3.00" 9452' 12 9444 8491 25 OTIS DMY RO-3 RK 04/24/81 3-1/2"FL4S X 3-3/16"TCII XO, ID-2.80" -{ 9494' 9505' H5-1/2"BKRPBRASSY,ID= 4.875' ►tet 9520' -19-5/8"X 5-1/2"BKR SAB PKR 5-1/2"TBG-PC, 17#, L-80,0.0232 bpf,ID=4.892" -1 9531' 9531' -5-1/2"X 4-1/2"XO, ID=3,958" TOP OF 7"LNR ---I 9567' i 9543' 3-3/16"WRP(12114!11) 4-12"TBG-PC, 12.6#,L-80,0.0152 bpf, ID=3.958" --r 9616' 9614' J 4-1/7'OTIS XN NIP,ID=3.725" 9-5/8"CSG,47#,L-80, ID=8.681" J 9878' 9616' -14-1/2"BKR S/O SUB TOP OF WHIPSTOCK(02/04/01) - 9974' ► . i w/RA TAG @ 9985' .•� ►•• 9617' 41/2"WLEG,ID=3.958" .j. 14.j. 9603' --I ELMD TT LOGGED 03/22/82 7"LNR,29#,L-80,ID=6.184" --1 -9981 '4. ���� m ♦♦ ►•4 PERFORATION SUMMARY .•i •�•i REF LOG:BHCS ON 04/12/81 •••• •�•� ••i •�i•i • ANGLE AT TOP PERF 27°@ 9995' .•• •�•� 7"MLLOUT WINDOW(16-05A) 9981'-9986' • Note: Refer to Production DB for historical perf data •�• ►�•4 SIZE SPF INTERVAL Opn/Sqz DATE �. 4' 2" 4 9995- 10020 C 11/18/11 ���`� 10004' -�3-3116 X 2-7/8 XO,1D=2.441" r 2" 4 10030- 10055 C 11/18/11 2" 4 10075- 10130 C 11/18/11 110004' -13-3116"LNR,6.2#,L-80 TCII, ID=2 80" 2" 4 10142- 10310 C 08/15/01 2" 4 10340- 10536 C 08/15/01 2" 4 10700-10749 C 08/14/01 2" 4 10844- 10864 C 08/14/01 ` 122771- PBTDJ 2" 4 10914- 10962 C 08/14/01 2" 4 11136- 11178 C 08/14/01 . 2" 4 11464- 11488 C 08/14/01 2" 4 11370- 11390 C 08/14/01 2" 4 11542- 11612 C 08/13/01 I 2-7/8"LNR,6.16#,L-80 STL,ID=2.44" 12315', 2" 4 11844- 11864 C 08/13/01 2" 6 12040- 12090 C 03/07/01 2" 6 12055- 12075 C 05/27/01 2' 6 12192- 12212 C 03/07/01 2" 6 12195- 12215 C 05/26/01 DATE REV BY COMMENTS REV BY COMMENTS PRUDHOE BAY UNIT 04124/81 ORIGINAL COMPLETION 12/16/11 RMWPJC PERFORATE(11/18/11) WELL: 16-05A 03/09/01 ADK CTD SIDETRACK(16-05A) 12/16/11 LEC/PJC SET WRP(12/14/11) PERMITNo:"2010100 12/08/10 KAUPJC GLV CORRECTIONS 12/16/11 JNU PJC PERMIT NO CORRECTION API No 50-029-20574-01 02/14/11 MB/JMD ADDED SSSV SAFETY NOTE 01/17/12 TMWJMD ADDED H2S SAFETY NOTE SEC 24,T1 ON. R15E, 1775'FNL&1100'FWL 10/12/11 TA/PJC PULL WRP(09/27/11) 10/25/11 ADWJMD WS RA TAG(02/04/01) BP Exploration (Alaska) TREE= , FMC I.WB_.u-FAp= FMC 16-05A COr A SAFETY NOTES:H2S READINGS AVERAGE 125 ppm -ACTUATOR= AXELSON PROPOSED WHEN ON MI.WELL REQUIRES A SSSV WHEN ON OKB.ELEV= 72' MI. WELL ANGLE>—70°@ 10099'. BF REV=KOP= 9974' Max Angle= 100"@ 10577' 2300' --I5-1/2"FSS X NP,D=4.562" Datum MD= 9857' , Datum T/D= 8800'SS13-3/8"CSG,72#,L-80,D=12.347" — 2669' 3000' 5 1/2"X 4-1i2'XO,D=3.958" 3500' —9-5/8"X 7"LTP,D=l5 112"TBG. #' -' bpf'D= J 3000' �, ' —I4-1/2"H X NP,D=3.812" Minimum ID =2.441" @ 10004' R -7"X4-1/2"FESTNTFKR,D=3-3/16" X 2-7/8" XO ILI 1 ' --{4-1/2"I• 'S XN NP,D=3.725" 14-1/2"TBG._#.—_, _bpf,D= " xi—___ _ —i4-1/2"WLEG,D=3.958' CUT TBG(_/ / ) 9380' 9380' —19-5/8"X 5-1/2"UNIQUE OVERSHOT BAKER 4-3/8"X 4"TIE33ACK,D=4.00" H 9445' ' PI ill 9428' -15-112"MR BAKER DEPLOY OY MEM SLV,D-3.00" 9452' ori I, 3-1/2'FL4S X 3-3/16"TCI XO,D-2.80" —1 9494' IL giffilS 9505' --15-1/2"BKR PBR ASSY,D= 4.875" 17"SCAB LNR,26#.VAM-HC,.0383 bpf,D 6.726"—1 10101 9520' 9-5/8"X 5-1/2"BKR SAB PKR 5-1/2"TBG-PC, 17#,L-80,0.0232 bpf,D=4.892" 9531' ► TOP OF 7"LNR 9567' 9531' —5-1/2"X 4-1/2"XO,D=3.958" 4-1/2"TBG-M,12.6#,L-80,0.0152 bpf,D=3.958" 9616' 1 '' t i 9-5/8"CSG,47#,L-80,13=8.681" 9878' 9614' -1 4-1/2"OTIS XN NP,ID=3.725" TOP OF W-FSTOCK(02/04/01) 9974' h. ! ► w/RA TAG @ 9985' .G 4 ••��� 9616' —14-1/2'BKR S/O SUB .•� • 4i4 •i 9617' —14-1/2"WLG,13=3.958" 7"LNR 29#,L-80,D=6.184' —I 9981 .� ��•4 •• ':. W 9603' —I LKO TT LOGGED 03/22/82 82 •4 4 PERFORATION SUMMARY �•••4 •�•� REF LOG:BFECS ON 04/12/81 . *II 1 ,,1 %•. •►���4 T MLLOUT WENDOW(16-05A) 9981'-9986' ANGLE AT TOP PERF:27"@ 9995' .•4 ►•�•4 i♦ 0M Note:Refer to Roduction DB for historical perf data • •" •�4. SIZE SW MER1/AL Opn/Sqz SHOT SOZ �•.,, ` 10004' -13-3/16-X 2-7/8" XO,D=2.441" 2" 4 9995- 10020 C 11/18/11 sl 2' 4 10030-10055 C 11/18/11 2" 4 10075-10130 C 11/18/11 `0004' —13-3/16"LNR 6.2#,L-80 TOL D=2.80" 2" 4 10142-10310 C 08/15/01 2" 4 10340-10536 C 08/15/01 2" 4 10700-10749 C 08/14/01 2" 4 10844-10864 C 08/14/01 12277 —1 PBTD 2" 4 10914- 10962 C 08/14/01 2" 4 11136-11178 C 08/14/01 . 2" 4 11464-11488 C 08/14/01 2" 4 11370-11390 C 08/14/0111 2-7/8"LW,6.16#,L-80 STL,D=2.44" -I 12315' 2" 4 11542-11612 C 08/13/01 2" 4 11844-11864 C 08/13/01 2" 6 12040-12090 C 03/07/01 2" 6 12055-12075 C 05/27/01 2" 6 12192-12212 C 03/07/01 2" 6 12195-12215 C 05/26/01 DATE REV BY COMMENTS NITS REV BY COARVDITS PRIDHOE BAY UNIT 04/24/81 ORIGINAL COMPLETION W91: 16-05A • 03/09/01 ADK CTD SIDETRACK(16-05A) PERMFT No: 2010100 01/03/14 JMD BOLT FROFOSED API No: 50-029-20574-01 01/07/14 CK/JMD ADD®RBP SEC 24,T10N,R15E,1775'Flk1&1100'FW.. BP Exploration(Alaska) . g g Si S 0 : I: i.4 0 i;6 s 0 1 t ,,,4 Er,,i gl b o g m< iNw p6 � IwN O • J C C i w1- iazW ¢ JJ o a JJ m Y U m mfa) ~! " " "! g o M a= C h iOa •g �rzn o a g I Rills S oz 111111 oa N co - g Kill €0 I--' -, 2 4 1 Ex� >J a s a s Nu]Z ^ - V V J6' i C p aticq CV Q m 5aa Z ,c-Z_,,, C J �- J{- S s — p . , ,eilor A il w W o rri ,e rn ______ . __I 0 re CCS O — - L a i \ IW 1 I AM T R __ fplilillAMil___ i u i I i Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Friday,January 10, 2014 9:49 AM To: 'carolyn.kirchner@bp.com' Subject: FW: PBU 16-05A(PTD 201-010, Sundry 314-015) From: Ferguson, Victoria L(DOA) Sent: Friday,January 10, 2014 9:48 AM To: 'carolyn.kirchne@bp.com' Subject: PBU 16-05A(PTD 201-010, Sundry 314-015) In the procedure where is running the RBP? Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave, Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusonaalaska.gov 1 Monthly Injection Report for GPBoPMA, Northstar, Milne Point & Endiii for Decem... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Tuesday, January 17, 2012 8:52 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Sauve, Mark A Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for December 2011 Attachments: AOGCC Inj Report 01- 12.ZIP Tom, Jim, Phoebe, and Guy, Attached is the December 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 01- 12.ZIP» Notes on wells: SLe' Nj) F F Added to Report: NGI -11 (PTD #1770800) Under evaluation for IA repressurization. MPC -10 (PTD #1850150) Under evaluation for IA repressurization. Taken off Report: 16 -05A (PTD #2010100) Economic evaluation completed and well returned to Not Operable status. NGI -03 (PTD #1750610) Under Evaluation for IA repressurization in October 2011. No repressurization observed post SSSV change out WGI -03 (PTD #1790490) AA 4E.027 for TxIA communication cancelled post RWO. Please call with any questions or concerns. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 1/31/2012 Monthly Injection Report for GPIPMA, Northstar, Milne Point & Endiii for Novem... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Tuesday, December 20, 2011 2:02 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Sauve, Mark A Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for November 2011 Attachments: AOGCC Inj Report 12- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the November 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 12- 11.zip)> Notes on wells: Added to Report: NS27 (PTD #2010270) Under evaluation for IA repressurization END3 -49A (PTD #1970570) Under evaluation for IA pressurization while on gas injection 16 -05 (PTD #2010100) Under evaluation to evaluate Injectivity to evaluate rig workover opportunities "k(0 -05 Taken off Report: None Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 12/20/2011 Well 16 -05A Injection Plot 0 Pressure vs. Rate o TIO Plot PTD' 20101 0 0 0 o co r - Tbg IA Failed MIT - IA 10/29/09 OA o Placed Under Evaluation to o o evaluate if injection is possible .a N • £ • N prior to a RWO to replace the 0 0: tubing. 8 3 O o • o • Last 90 days • Last Month 1, o A , , ■ o 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 5/12/11 8/2/11 10/23/11 1/13/12 Injection Rate, MCFPD • Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 12/01/11 6,160 1,877 12/01/11 1,877 300 680 11/30/11 6,260 1,901 11/29/11 1,916 300 680 11/29/11 6,390 1,916 11/28/11 1,682 300 550 11/28/11 4,910 1,682 11/27/11 1,909 320 640 11/27/11 6,390 1,909 11/26/11 1,718 310 600 11/26/11 5,450 1,718 11/25/11 1,588 300 480 11/25/11 5,380 1,588 11/23/11 1,337 300 160 11/24/11 5,500 1,593 11/22/11 810 480 50 11/23/11 672 1,337 11/21/11 0 220 50 11/22/11 0 810 11/20/11 0 220 50 11/21/11 0 0 11/19/11 0 260 160 11/20/11 0 0 11/18/11 0 260 160 11/19/11 0 0 11/17/11 0 260 160 11/18/11 0 0 11/16/11 0 260 160 11/17/11 0 0 11/15/11 0 260 160 • 11/16/11 0 0 11/14/11 0 240 180 11/15/11 0 0 11/13/11 0 240 180 11/14/11 0 0 11/12/11 0 240 180 11/13/11 0 0 11/11/11 0 240 180 11/12/11 0 0 11/09/11 0 240 180 11/11/11 0 0 11/08/11 0 240 180 11/10/11 0 0 11/07/11 0 240 180 11/09/11 0 0 11/06/11 0 240 180 11/08/11 0 0 11/05/11 0 240 180 11/07/11 0 0 11/04/11 0 240 180 11/06/11 0 0 11/03/11 0 240 180 11/05/11 0 0 11/02/11 0 240 180 11/04/11 0 0 11/01/11 0 220 160 11/03/11 0 0 10/31/11 0 240 160 11/02/11 0 0 10/30/11 1 240 160 11/01/11 0 0 10/29/11 2 240 160 NOT OPERABLE: Injector 16- 051PTD #2010100) Well Secured With Tiling Tail Plug Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @ bp.com] Sent: Thursday, December 15, 2011 8:57 AM To: Maunder, Thomas E (DOA) Subject: RE: NOT OPERABLE: Injector 16 -05A (PTD #2010100) Well Secured With Tubing Tail Plug Attachments: Injector 16 -05A (PTD #2010100) TIO and Injection Plot.doc Hi Tom, The injection was from 11/23 to 12/5 with the injection rate running averaging —5000 bpd of water. The reservoir engineers were happy. I've included a TIO and injection plot for you. No logs were run during the injection. Let me know if I can answer anything further. Jerry Murphy BPXA Well Integrity Coordinator From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, December 15, 2011 7:58 AM To: AK, D &C Well Integrity Coordinator Subject: RE: NOT OPERABLE: Injector 16 -05A (PTD #2010100) Well Secured With Tubing Tail Plug Hi Jerry, How long was the well on injection? Were there any logs run? I guess the results were favorable since a workover is planned. Regards, Tom Maunder, PE AOGCC From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIlntegrityCoordinator @bp.com] Sent: Thursday, December 15, 2011 7:36 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS2 DS; Mcconkey, Anthony Cc: AK, D &C Well Integrity Coordinator; Clingingsmith, Mike J; LeBaron, Michael 3; Walker, Greg (D &C) Subject: NOT OPERABLE: Injector 16 -05A (PTD #2010100) Well Secured With Tubing Tail Plug All, Injector 16 -05A (PTD #2010100) has been secured with a tubing tail plug after completion of a successful injection test. The well is reclassified as Not Operable. The plan forward will be to pursue a rig workover. Please call if you have any questions. Thank you, Gerald Muiphy (alt. Mehreen Vazir) 12/29/2011 NOT OPERABLE: Injector 16- 051PTD #2010100) Well Secured With Tiling Tail Plug Page 2 of 2 Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Sunday, November 20, 2011 3:57 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS2 DS; Mcconkey, Anthony Cc: AK, D &C Well Integrity Coordinator; Clingingsmith, Mike 3; LeBaron, Michael 3; King, Whitney Subject: UNDER EVALUATION: Injector 16 -05A (PTD #2010100) Begin Water Injection To Evaluate Rig Workover versus a Rig Sidetrack Repair All, Injector 16 -05A (PTD #2010100) has been shut in for injection since 2006 for failure to take injection fluids. The well failed an MIT -IA in September, 2010 during a rig workover screen, and a subsequent leak detect log found a possible production casing leak at 6130' in June of 2011. The well passed an MIT -T to 3000 psi on both 09/15/2010 and 09/18/2011 and a MIT -OA to 2000 psi on 08/25/2011. New perforations were placed in the liner with a coiled tubing unit from 11/17- 19/2011 to evaluate whether the well is capable of injection, prior to a proposed rig workover. Tom Maunder, with the AOGCC, agreed to allow temporary water injection for evaluation for the rig workover, in a conversation on 09/02/2011. The well is reclassified as Under Evaluation and may operate under a 28 day clock, and may begin water injection to evaluate the new perforations in the wellbore, and the determination of a rig workover versus a rig sidetrack repair. The well will be placed on the AOGCC monthly injection report for monitoring while on injection. Due to the fluid packed annulus, please be aware of the possibility of annular fluid expansion when beginning injection on the well. A copy of the wellbore schematic is included for reference. Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 12/29/2011 • I njector 16 -05A (PTD #2010100) TIO Plot 12/15/2011 HMIS 4,000 3,000 — T6y —11— IA 2,000 —,� OA 00A �— 0064 —On 1,000 • `!! 09/17/11 09/24/11 10/01/11 10/08/11 10/15/11 10/22/11 10729/11 11/05/11 11/12/11 11/19/11 11/26/11 12/03/11 12/10/11 Injector 16 -05A (PTD #2010100) Injection Plot Wel 1605 6,500 1,900 1,100 6,000 1,700 5,500 1,600 1,500 5.000 1,400 1,50D 1,300 1,200 4 ,0 00 - WHIP 1,100 SW 3.500 - PW 1,009 3.00 - GI B - OUw 2,500 On 700 600 2000 500 000 400 300 1000 200 500 00 09/17/11 03/2441 10/01/11 10/06/11 10/15/11 10/22/11 10/29/11 11/05/11 11/12/11 11/19111 1126/11 12/03/11 12/10/11 TE OF ALASKA ALASKA OIL AND CONSERVATION COMMISSION • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 12 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ 4 201 -0100 3. Address: P.O. Box 196612 Stratigraphic0 Service El 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 20574 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028346 PBU 16 -05A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12320 feet Plugs (measured) None feet true vertical 9069.99 feet Junk (measured) None feet Effective Depth measured 12277 feet Packer (measured) 9520 feet true vertical 9062.01 feet (true vertical) 8560 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 94# H-40 32 - 112 32 - 112 1530 520 Surface 2638' 13 -3/8" 72# L -80 31 - 2669 31 - 2669 4930 2670 Production 9858' 9 -5/8" 47# L -80 30 - 9878 30 - 8891 6870 4760 Liner 414' 7" 29# L -80 9567 - 9981 8603 - 8987 8160 7020 Liner 49' 3 -1/2" 9.3# L -80 9445 - 9494 8492 - 8537 10160 10530 Liner 510' 3- 3/16" 6.2# L -80 9494 - 10004 8537 - 9008 Liner 2311' 2 -7/8" 6.16# L -80 10004 - 12315 9008 - 9069 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - tab t - True Vertical depth: ' ; ' >''-" 4 (_ r t 8 Z U l d Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# L -80 29 - 9531 29 - 8571 4 -1/2" 12.6# L -80 9531 - 9616 8571 - 8649 Packers and SSSV (type, measured and true vertical depth) 5 -1/2" Baker SAB Packer 9520 8560 . OP 1V ED 12. Stimulation or cement squeeze summary: Intervals treated (measured): DEC 0 6 2011 Treatment descriptions including volumes used and final pressure: CQa CM5s" 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 5500 1593 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ❑ Service IO Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: a Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE/ GINJ ❑ SUSPE SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Nany oe Lastu iif\ Title Petrotechnical Data Technologist 1 Signatur- Phone 564 -4091 Date 12/2/2011 Form 10-404 Revised 10/201 RBDAIIS DEC 0 7 2011 r 12 ' ?' r t it Original Only 16 -05A . 201 -010 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 16 -05A 3/7/01 PER 12,040. 12,090. 9,024.67 9,029.28 16 -05A 3/7/01 PER 12,192. 12,212. 9,045.66 9,049.82 16 -05A 5/26/01 APF 12,195. 12,215. 9,046.3 9,050.42 16 -05A 5/27/01 APF 12,055. 12,075. 9,025.93 9,027.75 16 -05A 8/12/01 APF 11,844. 11,864. 9,015.84 9,016.74 16 -05A 8/13/01 APF 11,542. _ 11,612. 9,006.07 9,006.66 16 -05A 8/13/01 APF 11,370. 11,390. 9,005.46 9,004.96 16 -05A 8/13/01 APF 11,464. 11,488. 9,005.38 9,005.69 16 -05A 8/14/01 APF 10,914. 10,962. 9,019.54 9,017.51 16 -05A 8/14/01 APF 11,136. 11,178. 9,006.84 9,007.34 16 -05A 8/14/01 APF 10,844. 10,864. 9,024.4 9,022.81 16 -05A 8/14/01 APF 10,340. 10,536. 9,069.52 9,050.78 16 -05A 8/14/01 APF 10,142. 10,310. 9,073.43 9,070.89 16 -05A 8/14/01 APF 10,700. 10,749. 9,032.25 9,029.88 16 -05A 9/16/10 BPS 9,542. 10,142. 8,580.58 9,073.43 • 16 -05A 9/27/11 BPP 9,542. 10,142. 8,580.58 9,073.43 16 -05A 11/19/11 APF 10,030._ 10,055. 9,029.01 9,046.01 16 -05A 11/19/11 APF ✓ 9,995. 10,020. 9,000.1 9,021.29 16 -05A 11/19/11 APF ,,/ 10,075. 10,130. 9,056.89 9,072.58 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED _ FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 16 -05A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/15/2011 Coil 8 Drive location. In progress. Continued on 11/16/11 WSR. 11/16/2011 ;Continued from 11/15/2011 WSR. Perform weekly BOP test. Job Scope: I FCO /Log /Adperf. Change packoffs, perform chain inspection. Valve crew repair ssv. RIH w/ BHA: 1.9" no -go CC. 1.75" checks, 2- 1.75" stingers, 1.75" DJ nozzle (w/ Jet swirl pattern). OAL =8.6', 'Start RIH while pumping SBG. * *job continued on WSR 11- 17 -11 ** 11/17/2011 continued from WSR 11- 16 -11. CTU 8 w/ 1.75" CT. Scope; SBG/ Adperf RIH w/ BHA: 1.9" no -go CC. 1.75" checks, 2- 1.75" stingers, 1.75" DJ nozzle (w/ Jet ;swirl pattern). OAL =8.6' (Choke closed) Bullhead/ jet with SBG tag hard @ 11396 and 11518. Continued `down to and stop at 11 6b!. While weight check, well would briefly pack off and then break free. continued to puh while bullheading SBG into perfs. pooh. FP CTBS w/ 12 :bbls meth.let SBG soak.. Displace SBG w/290 bbl 1% KCL. MU Weatherford MHA PDS GR/CCL in carrier w/ 2.2" JSN. Log interval 10600' -9400' @ 45 fpm. Flag CT @ 10,000'. POOH. good data. +10' correction MU and Rtl w7 MU BHA; MHA is 1.9" no -go dimple, 1 11/16" MHA w/ dual cks, :9/16" ball disco, blank rupture sub, 1." MT X 1.5" MT X0, 2" x30' HSD 2006PJ 6 spf perf cgun (oa198.72') * *job continued on WSR 11-18-11** j 11/18/2011 Continued from WSR 11 -17 -11 CTU 8 w/ 1.75" CT. Scope; SBG/ Adperf.RIH w/ 1.9" no -go dimple, 1 11/16" MHA w/ dual cks, 9/16" ball disco, blank rupture sub, 1." MT X I 1.5" MT X0, 2 "x30' HSD 2006PJ 6 spf pert gun (oal= 38.72'). Shoot pert interval , Yr . ooh. all shots fired. recovered ball. MU and RIHe/ gun #2; 25' of 2" 6 , Ispf. Correct to tops of @ flag. Shoot interval 10075'- 10100'POOH. Cut 151' of ;coil, re -head. MU /RIH w/ PDS 2.2" carrier w/ GR/CCL. & 2.2" JSN to 10600'. Log 45 I fpm, flag pipe at 9950 and log to 9400' pooh_ * *Job continued on WSR 11- 19 -11 ** 11/19/2011; Continued from WSR 11 -18 -11 CTU 8 w/ 1.75" CT. Scope; SBG /Adperf.. * *Held ER Drill, pinhole leak in coil ** Confirmed data good. MU and RIH w/ BHA:1.9" dimple, 1 11/16" MHA w/ 9/16" disco, . °blank rupture sub, 1" mt X 1.5" mt xo, 2.13" firing head, 2 "x 25', 6 spf, PJ2006 HMX iperf gun. (oat= 33.69') Shoot interval 10030 - 10055' Pooh. PT MHA. MU Gun #4, 25' .� of 2" 6 spf gun. Tie in to flag. Shoot interval 9995' - 10020'. POOH. * *ER Drill, Fire in field triplex. Perform SRT w/ 280 bbl KCI . : Freeze protect well with 60 bbls 60/40 McOH * *job complete ** (DSO to POI after valve crew repairs hose to SSV) FLUIDS PUMPED BBLS 240 60/40 METH 288 SBG 569 1% KCL 1097 TOTAL . _ 1 • = TREE FMC WELLHEAD = FMC 16 5A ill. NOTE: WELL REQUIRES A SSSV WHEN ON ACTUATOR = AXELSON KB. ELEV = 72' BF. ELEV = KOP = 9974' • I 2313' H5-1 /2" OTIS ROM SSSV NIP, ID = 4.562" 1 Max Angle = 100 @1057T GAS LIFT MANDRELS Datum MD = 9857' ST MD WD DEV TYPE VLV LATCH PORT DATE Datum WD = 8800' SS 1 2977 2976 7 OTIS DMY R0-3 RK 04/24/81 113 -318" CSG, 72#, L -80, ID = 12.347" H 2669' 2 5159 4888 36 OTIS DMY RO-3 RK 04/24/81 3 6792 6205 34 OTIS DMY RO-3 RK 04/24/81 4 7798 7064 33 OTIS DMY RO-3 RK 04/24/81 Minimum ID = 2.441" 10004' 5 8455 7618 31 OTIS DAY R0-3 RK 04/24/81 6 8529 7682 30 OTIS DMY RO-3 RK 04/24/81 3 -3/16" X 2 -718" XO 7 8878 7986 28 OTIS DMY RO-3 RK 04 /24/81 8 8953 8052 28 OTIS DMY RO-3 RK 04/24/81 9 9222 8292 26 OTIS DMY R0-3 RK 04 /24/81 'BAKER 43/8" X 4" TIEBACK, ID = 4.00" H 9445' 10 9296 8357 26 OTIS DM' RO-3 RK 04/24/81 'BAKER DEPLOYMENT SLV, ID - 3.00" H 9452' ■, 11 9369 8424 26 OTIS DMY RO-5 RK 12/26/93 I 12 9444 8491 25 OTIS DMY RO-3 RK 04/24/81 13-1/2" FL4S X 3 -3/16" TCI X0, ID - 2.80" H 9494' 1 ' 9585' H5-1/2" BKR PBR ASSY, ID = 4.875 "' ►Z ►�� 9520' —19 -5/8" X 5-112" BKR SAB PKR 1 15-1/7 TBG -PC, 17 #, L -80, 0.0232 bpf, ID = 4.892" H 9531' ( 9531' J- i5-1 /2" X 4117' XO, ID = 3.958" 1 'TOP OF 7" LNR H 956T ' 9614' 1-14-1/2" OTIS XN NP, ID = 3.725" ' 141/2" TBG -PC, 12.6#, L -80, 0.0152 bpf, ID = 3.958" H 9616' 1 ' 9616' H4 -1/2" BKR S/0 SUB' 1 � 1 19 -5/8" CSG, 47#, L -80, ID = 8.681" H 9878' • > ! i ( 961T ' 41/2" WLEG, D = 3.958 "' TOP OF WHIPSTOCK (02/04/01) — 9974 ■4 •.i • ( 9603' H ELMD TT LOGGED 03/22/82 ' w/ RA TAG ® 9985' �� ►� �� ∎ • • 4 ► (7" LNR, 29#, L -80, ID = 6.184" H — 9981 ,•4 • ►,• 1 •• ►•4 i ► 7" MILLOUT WINDOW (16 -05A) 9981' - 9986' PERFORATION SUMMARY • �•� ► REF LOG: • BRCS ON 04/12/81 • • ►.'� ANGLE AT TOP PERF: 87° @ 10142' � ` `, Note: Refer to Production OB for historical pert data `` \ ko4 . 4,, -- 10004• 3 -3 /16" TCII X 2 -7/8" STL X0, ID = 2.441" ' 7, SIZE SPF INTERVAL Opn/Sgz DATE O,. .�. 2" 4 10142 - 10310 0 08/15/01 •..•:,.♦ °• 1 0004' 1 3 -3/16" LNR, 6.2#, L -80 TCII, ID = 2.80" ' 2" 4 10340 - 10536 0 08/15/01 .4 2" 4 10700 - 10749 0 08/14/01 ` ���. � ,� ��.`� • 2 4 10844 - 10864 0 08/14/01 Vii•. b.. 12277 I 2" 4 10914 - 10962 0 08/14/01 ■ •4 . � 11 im .•` ... I 7 4 11136 -11178 0 0 ,�•`:• ��`- 2" 4 11464 - 11488 0 08/14/01 ��" O `4►• 4 2" 4 11370 - 11390 0 08 /14/01 2" 4 11542 - 11612 0 08 /13/01 ( 2 -7 /8" LNR, 6.16#, L -80 STL, ID = 2.44" 12315'1 2" 4 11844 - 11864 0 08/13/01 2" 6 12040 - 12090 0 03/07/01 2" 6 12055 - 12075 0 05/27/01 2" 6 12192 - 12212 0 03/07/01 2" 6 12195 - 12215 0 05/26/01 DATE ' REV BY COMMENTS REV BY COMMENTS PRUDHOE BAY UNIT 04/24181 ORIGINAL COMPLETION 12/08/10 KAUPJC GLV CORRECTIONS WELL: 16-05A 03/09/01 ADK CTD SIDETRACK (18 -05A) 02/14/11 MB /J11D ADDED SSSV SAFETY NOTE PERMIT No: 1810370 03/28/01 CFUTP/KK CORRECTIONS 10/12/11 TA/ PJC PULL WRP (09 /27/11) API No: 50-029-20574-01 05 /27/01 DYK/TLH ADD PERFS 10/25/11 A DM/JMD WS RA TAG (02104/01) SEC 24, Ti ON, R15E, 1775' FNL & 1100' FWL 08 /25/01 DCR/KAK PERFS 09 /22/10 MSS /PJC SET WRP (09116/10) BP Exploration (Alaska) Possibility of Placing Not Operable Injector 16 -05A (PTD #2010100) Under Evaluation t... Page 1 of 2 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, September 02, 2011 12:48 PM To: 'AK, D &C Well Integrity Coordinator' Subject: RE: Possibility of Placing Not Operable Injector 16-05A (PTD #2010100) Under Evaluation to Qualify Rig Workover Thanks Jerry. The only other item is that the well should likely go on the monthly report when you start the evaluations. Tom Maunder, PE AOGCC From: AK, D &C Well Integrity Coordinator [ mailto :AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, September 02, 2011 11:31 AM To: Maunder, Thomas E (DOA) Subject: RE: Possibility of Placing Not Operable Injector 16 -05A (PTD #2010100) Under Evaluation to Qualify Rig Workover Tom, The plug is still in place for securing the well. We wanted to have the AOGCC blessing on the possibility before initiating any procedural plans. I agree that a MIT -T closer to start of injection would be pertinent to prove the barrier. I've enclosed a TIO and Injection Plot back to 09/2008 for your review. Pressures listed on 08/25/2011 during the MIT -OA were T /I /O = 280/215/0 psi. Thanks for your time, Jerry Murphy BPXA Well Integrity Coordinator "i ��� From: Maunder, Thomas E (DOA) [mailto:tom.maunder©alaska.gov] Sent: Friday, September 02, 2011 10:58 AM To: AK, D &C Well Integrity Coordinator Subject: RE: Possibility of Placing Not Operable Injector 16 -05A (PTD #2010100) Under Evaluation to Qualify Rig Workover Hi Jerry, It appears that the well passes MIT -Ts with the last one May 5. Is the plug still set? It may be appropriate to conduct another MIT -T prior to entering the evaluation stage. What sort of pressure is there on the IA? Do you have a TIO? Thanks in advance, Tom Maunder, PE AGOCC From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWeIIIntegrityCoordinator @bp.com] Sent: Friday, September 02, 2011 10:51 AM To: Maunder, Thomas E (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: Possibility of Placing Not Operable Injector 16 -05A (PTD #2010100) Under Evaluation to Qualify Rig Workover 9/2/2011 Possibility of Placing Not Operable Injector 16 -05A (PTD #2010100) Under Evaluation t... Page 2 of 2 Tom, Injector 16 -05A (PTD #1880320) is a Not Operable WAG injector that is being considered for either a rig workover or sidetrack. An leak detect log performed on 6/27/2011 identified a leak in the production casing at 6130'. Well Events: 10/29/2009 Failed MIT -IA (Liquid Leak rate at 0.5 bpm at 3000 psi) 09/16/2010 Set wireline retrievable plug at 9642', MIT -T passed, MIT -IA failed at 3.5 bpm © 1750 psi 05/05/2011 Passed MIT -T to 3000 psi 06/27/2011 LDL found possible PC leak at 6130' 08/25/2011 MIT -OA passed to 2000 psi 09/01/2011 PPPOT -IC passed The question is: would it be possible to place the well Under Evaluation (28 -day clock) to perforate from 9987' to 10130' and place the well on water injection to identify if the proposed injection zone will take water at 5000 bbls per day injection rate? if so, would you want us to perform any further tests? If the well does not take the fluid, a sidetrack will be planned. If the well will take the injection, a rig workover to repair the PC leak would be planned. The intent would be to keep from doing the rig workover and finding that a sidetrack is immediately required, and could accomplish the same repair during the workover /sidetrack. I'm including a copy of the schematic for reference. «16 -05A wellbore schematic.pdf» Thank you in advance for the consideration, Jerry Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 9/2/2011 w • 16 -05A (PTD #2010100) TIO Plot 09 -02 -2011 w1 16-05 4,000 - • • • • 3000 t Th0 -4t w 2.000 - . - OA 004 -a 0005 On 1.000 10/21/08 12/22/00 02/22/09 0425/09 05/26/09 00127/09 10/20/09 12/29/09 03/01/10 05/02/10 07/03/10 09/03/10 11/04,10 01/05/11 03/0801 05/09/11 07/10/11 16 -05A (PTD #2010100) Injection Plot We116-05 2200 - 1 - 2,007 2.000 - - 1.800 1.800 - j - - 1,600 1600 -1.400 1400- (111 11 - 1.200 -WHIP - SW x 1,200- - - PW - 1 000 r - MI 1,000 - - GI - 800 - 800. On 600 - 600 00 I - 400 • 200 W - 200 moms 12/22/08 0325/09 0626/09 09/27/09 1229/09 04/01/10 07/03/10 10/04 /10 01/05 /11 04/08/11 07/10/11 NOT OPERABLE: 16-OS (PTD ~10100) Failed MITIA • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, October 29, 2009 4:01 PM ~~~ ~~~~~~ ~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, EOC Specialists; Engel, Harry R; Rossberg, R Steven Cc: Phillips, Patti J; Holt, Ryan P(ASRC); NSU, ADW Well Integrity Engineer; Williams, Carrie Subject: NOT OPERABLE: 16-05 (PTD #2010100) Failed MITIA Attachments: MIT PBU 16-05A 10-29-09.x1s ~ All, Well 16-05A (PTD #2010100) failed a pre-AOGCC MITIA on 10/29/09. The well has been reclassified as Not Operable. Please ensure the well is shut-in and freeze protected as soon as safely possible. The well will remain shut-in until repaired. "- An AOGCC MITIA test form is attached for reference. «MIT PBU 16-05A 10-29-09.x1s» `~ Please let us know if there are any questions. Thank you, Anna ~Du6e, ~.~. ~alt Torin Roschinger) VO/ell Integrity Caordinatar GPB Wells Graup Phone: (907) 659-5102 ~a~e~: ~~07~ sss-s~ao x77~a ~~~~~li~~~ 1~` ~f ~~r ~~rS~~. , , ~_~ From: NSU, ADW Well Integrity Engineer Sent: Sunday, September 27, 2009 7:21 PM ~ To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; 'Schwar~, Guy L(DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; GPB, FS2 DS Ops Lead; GPB, F52/COTU OTL; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, EOC Specialists; Engel, Harry R; Rossberg, R Steven Cc: Holt, Ryan P(ASRC); Phillips, Patti J; Winslow, ]ack L.; NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: 16-05 (PTD #2010100) REady to return well to injection for UIC MITIA All, The Drill Site 16 water injection header has been repaired. Well 16-05 (PTD #2010100) has been reclassified as Under Evaluation so that it may be returned to iniection and a 4-year MITIA may be conducted for UIC compliance. Please let us know if there are any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Coardinator GPB Well~ Group 11/5/2009 NOT OPERABLE: 16-OS (PTD #~10100) Failed MITIA Page 2 of 2 ~ Phone: (907) 659-5102 Pager: {907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, October 26, 2008 1:11 PM To: GPB, Area Mgr East (FSl/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, EOC Specialists; Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: Holt, Ryan P(ASRC); Engel, Harry R; Phillips, Patti J; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: 16-05 (PTD #2010100) Waiting to return well to injection for UIC MITIA Hi all, Well 16-05 (PTD #2010100) has been reclassified to Not Operable due to being due for UIC MITIA testing. This well is currently shut-in due to a leak in the water injection header. When the line is ready to return the well to water injection, please notify the Well Integrity Coordinator. The WIC will then notify the AOGCC that the well is being placed online for compliance testing. If a decision is made to return the well to MI injection, the well wi-I be tested with a plug downhole to hold backpressure before placing the well on injection. Please let us know if you have any questions. Thank you, ,~nna ~Dude, ~P. E. Wetl Integrity Coordinatt~r GPB Welfs Group Phone~ {907} 659-51~2 Pager. {907) 659-5100 x1154 11/5/2009 ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD / UNIT / PAD DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / DS 16 10/29/09 Anna Dube Packer Depth Pretest Initial 15 Min. 30 Min. Well 16-05A Type Inj. W TVD ~8,560' Tubing 2,000 2,000 2,000 Interval 4 P.T.D. 2010100 Type test P Test psi 4000 Casing ~~ 3,800 1,000 ~ P/F F Notes: Before reaching test pressure of 4000 psi, pressure ~ OA 40 40 40 started falling. Shut down pumps and monitored for 15 mins. Test failed. Leak rate of 0.5 bpm at 3000 psi. '~ Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R= Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU 16-05A 10-29-09.xis NOT OPERABLE: 16-OS (PTD #2010100) Waiting to return well to injection for UIC MITIA Page 1 of 1 • i Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer[NSUADWWeIIlntegrityEngineer@BP.com] `1~~ tC~Z-f~~Z~kl~ Sent: Sunday, October 26, 2008 1:11 PM "'~ To: GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, EOC Specialists; Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Holt, Ryan P (ASRC); Engel, Harry R; Phillips, Patti J; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: 16-05 (PTD #2010100) Waiting to return well to injection for UIC MITIA Hi all, Well 16-05 (PTD #2010100) has been reclassified to Not Operable due to being due for UIC MITIA testing. This well is currently shut-in due to a leak in the water infection header. When the line is ready to return the well to water injection, please notify the Well Integrity Coordinator. The WIC will then notify the AOGCC that the well is being placed online for compliance testing. If a decision is made to return the well to MI injection, the well will be tested with a plug downhole to hold backpressure before placing the well on injection. Please let us know if you have any questions. Thank you, Anna 1~u6e, ~'. E. Well Integrity Coordinatar GPB Wells Graup Phane: {907) 659-5102 Pager: {907) 659-5100 x1154 _. . 11/28/2008 e e .. ':......··....r·...................................'.. -",'r '",";1""'"'' .. ",' ",,' 11'," .. ,"'" 10< .'.... __"," .... ", ~.. i TO. <', Þ' ,,.:. MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MEMORANDUM TO: Jim Regg r 01 - ID{7/8btr P.I. Supervisor \'\L(t I~ FROM: Chuck Scheve Petroleum Inspector Well Name: PRUDHOE BAY UNIT 16-05A Insp Num: mitCS041 027073349 ReI Insp Num: ) State of Alaska ') Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 27, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 16-05A PRUDHOE BAY UNIT 16-05A Src: Inspector NON-CONFIDENTIAL API Well Number: 50-029-20574-01-00 Permit Number: 201-010-0 Packer Depth Pretest Initial Well 16-05A Type Inj. P TVD 8560 IA 280 4000 P.T. 2010100 TypeTest SPT Test psi 2140 OA 250 600 Interval OTHER P/F P Tubing 2000 2000 Notes: Test performed prior to converting well to MI injection. SCANNED NOV (I ~ 2004 Wednesday, October 27,2004 ~Ol- OiO Reviewed By: P.I. Suprv-:f'Ø2- Comm Inspector Name: Chuck Scheve Inspection Date: 10/26/2004 15 Min. 30 Min. 45 Min. 60 Min. 3950 3950 600 600 2000 2000 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission r! \b ,() tr TO: Jim Regg \~e¿lq \ , .\ P.I. Supervisor \. DATE: January 4, 2004 FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Test BPX 0516 16-05A PBU Packer Depth Pretest Initial 15 Min. 30 Min. Well 16-05A Type Inj. S TV.D. 8560 Tubing 1840 1840 1840 1840 Interval 4 P.TD. 201-010 Type test P Test psi 2140 Casing 700 2300 2280 2280 P/F P Notes: Well Type Injo ToV.D. Tubing Interval P.TDo Type test Test psi Casing P/F Notes: Well Type Injo ToV.D. Tubing Interval PoT Do Type test Test psi Casing P/F Notes: , Well Type Inj. TV.D. Tubing Interval PoT Do Type test Test psi Casing P/F Notes: Well Type Injo TV.D. Tubing Interval P.TD. Type test Test psi Casing P/F Notes: / Type I NJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I traveled to BPXs DS 16 in the Prudhoe Bay Field and witnessed the routine 4 year MIT on well 16-05A. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then perfonned with, the well demonstrating good mechanical integrity. M.LT.'s performed: 1 Attachments: Number of Failures: Q Total Time during tests: 1 hour f£ , ,,~_. 'I' r-:\ Th°"-: ~ ~!"In' ~ (,-,~.,.,!.~¡'D,í'I,;I'E"I'--' ;",\,..,,11",;,1,,'11[",""'/',', '~ '\ .,1,,\, ,"" " "," ',' \ . .':'j)~)I'\hji!'i:lL."i'.. ,,)niü\ <~, -;e.,,'vv u MIT report form 5/12/00 L. G. MIT PBU 16-Q5A 1-4-04 CS.xls 1/6/2004 Permit to Drill 2010100 MD 12320" 'rVD DATA SUBMITTAL COMPLIANCE REPORT 61312003 Well Name/No. PRUDHOE BAY UNIT 16-05A Operator BP EXPLORATION (ALASKA) INC 9070 '"" Completion Dat 5/28/2001 " Completion Statu WAGIN Current Status WAGIN APl No. 50-029-20574-01-00 UIC Y REQUIRED INFORMATION Mud Log No Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval Start Stop OH I Dataset CH Received Number Comments R ~.D.~' I:~~'~ Ver LIS Verification , Rpt Ver LIS Verification E~,~I~ ~"~:' Cn See Notes ,Di~'~tion al Survey FINAL ._J~ectional Survey FINAL 9963 12275 Open 9963 12275 Open 9965 12320 Case 3/27/2001 Directional Survey Paper Copy 3/27/2001 Directional Survey Digital Data 7/2/2002 ct'0948 7/2/2002 1121/2003 clA'491 digital well logging data Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? -Y-hN Analysis Daily History Received? ~ N Formation Tops ~Y~ N Comments: Compliance Reviewed By: Date: To~ WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 16, 2003 MWD Formation Evaluation Logs · 16-05A, AK-MW-10071 !6-05A: Digital Log Images 50-029-20574-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED JA /g. ] 200 ~a~ 0/t & Bas Cons. Commta~o~ ,,i WELl, LOG TRANSMITYAL To: State of Alaska June 26, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 16-05A, AK-MW-10071 1 LDWG formatted Disc with verification listing. API#: 50-029-20574-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING. A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska)Inc. Petro-Technical Data Cemer LR2-1 900 E. Benson 'Blvd. Anchorage, Alaska 99508 Date: RECEII/ED Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1638 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay,Niakuk Color Well Job # Log Description Date Blueline Sepia Prints CD G-19A /~C~-/O~ MEM PROD PROFILE 11/07/01 1 1 N-4A ! ~/_~'/~'7 PROD PROFILE/DEFT/GHOST 11/16/01 1 1 D-04A / ~'7-/<~ 21461 EST 10/~01 1 1 1 D.S. 15~1B ~0)-/~ 21471 MCNL 10/08/01 1 1 1 D.S. 16~5A ~ ~)- (~ j ~ 21475 MCCL (PDC) 03/07/01 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 11/21/01 BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEt ED . Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATrN: Sherrie STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development __ Explorato~__ Stratigraphic__ Service__X 4. Location of well at surface 1771' FNL, 4180' FEL, Sec. 24, T10N, R15E, UM At top of productive interval 4090' FNL, 1521' FEL, Sec. 24, T10N, R15E, UM At effective depth (asp's 719887, 5929172) (asp's 722613,5926936) At total depth 3502' FNL, 4523' FEL, SEC 19, T10N, R16E, UM (asp's 724689, 5927585) 6. Datum elevation (DF or KB feet) RKB 72 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 16-05Ai 9. Permit number / approval number 10 ~ -~15i--~.?~ 50-029-20574-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2597' Production 9806' Liner 407' Liner 2870' 12320 feet Plugs (measured) 9070 feet 12277 feet Junk (measured) 9062 feet Size Cemented Measured Depth True Vertical Depth 20" 345 Sx AS II 80' 80' 13-3/8" 300 Sx Fondu & 650 Sx PF 2669' 2669' 9-5/8" 500 Sx Class G 9878' 8891' 7" 375 Sx Class G 9974' 8981' 3-1/2" x 3-3/16" x 2-7/8" 33 bbls 15.8 ppg Class G 12315' 9069' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" Baker SAB PACKER @ 9520' MD. 5-1/2" Otis RQM SSSV Nipple @ 2313' MD. 10142'- 10310'; 10340'- 10536'; 10700'- 10749'; 10844'- 10864'; 10914'- 10962'; 11136'- 11178'; 11370'- 11390'; 11464'- 11488'; 11542'- 11612'; 11844'- 11864'; 12040'- 12090'; 12192'- 12215'. 9073'- 9071'; 9070'- 9051'; 9032'- 9030'; 9024' - 9023'; 9020'- 9017.5'; 9007' - 9007'; 9005'-9005'; 9005'-9006'; 9006'-9007'; 9016'-9017'; 9024'-9029';~0~'~9~(~'.V FD 5-1/2", 17¢, L-80 PC Tubing ~ 9531' MD; 4-1/2", 12.6¢, L-80 PC Tubing ~ ' AUG 24 2001 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure ....... n:, ~ eo~ C. nns. Oommissior~ Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure (Shut in) 489 Tubing Pressure 1810 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil _ Gas_ Suspended_ Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,%_ ¢.~ Title: DS 16 Surveillance Engineer Christopher J ~,r" t~&/,,,~f~¢ d~¢~-'~ Form 10-404 Rev 06/15/88 · ORIGIN/ I Date August 21, 2001 Prepared b~/Paul Rauf 564-5799 SUBMIT IN DUPLICATE 16-05Ai DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 5/27/2001' 8/11/2001' 8/12/2001 - 8/15/2001: RIH & tagged PBTD @ 12277' MD (during Acid Stimulation). MIRU CTU. PT'd BOPE. RIH & attempted to kill well w/KCI Water but well tight. Logged well w/CCL & POOH. RIH w/ CT conveyed perforating guns & shot 657' (while laying in FIo Pro) of add perforations from: 8/18/2001: 10142' - 10310' MD (Zone 4) 10340' - 10536' MD (Zone 4) 10700' - 10749' MD (Zone 4) 10844'- 10864' MD (Zone 4) 10914' - 10962' MD (Zone 4) 11136' - 11178' MD (Zone 4) 11370'- 11390' MD (Zone 4) 11464'- 11488' MD (Zone 4) 11542' - 11612' MD (Zone 4) 11844'- 11864' MD (Zone 4) Reference Log: Sperry MWD 3/05/2001. Used 2" PJ carriers & all shots @ 4 SPF, random orientation, & overbalanced press. POOH w/guns - ASF. RIH w/CT stinger & circulated out FIo Pro w/47 bbls of Bleach. POOH w/ CT. FP'd well. Placed well on initial Water Injection & obtained representative injection data. Well continues to be very tight and not taking the injection anticipated. Options are currently being evaluated. Page 1 (,i 3TATE OF ALASKA (' REVISED: 10109101 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well OIL E] GAS E] SUSPENDED r'=l ABANDONED I~l SERVICE I~] ;~,..~'~ Water Iniector 2. Name of Operator " 7. Permit Number BP Exploration (Alaska), Inc. .-.~ 201-010 3. Address ~~ 8. APlNumber P. O. Box 196612 Anchorage, AK 99519-6612 "' 50-029-20574-01 4. Location of well at surface 9. Unit or Lease Name 1771' FNL, 4180' FEL, Sec. 24, T10N, R15E, UM (asp's 719887, 5929172) ;= ~...,.'.,,~: ~, .~,, · Prudhoe Bay Unit At Top Producing Interval i :-:.~'.: ;: . ; 10. Well Number ~ S"; 2.-~' (3! ; 16-05Ai 4090' FNL, 1521' FEL, Sec. 24, T10N, R15E, UM (asp's 722613, 5926936) At Total Depth:~ L'Fci~=F[[: '.~'~ i 11. Field and Pool 3502' FNL, 4523' EEL, SEC 19, T10N, R16E, UM (asp's 724689, 5927585) ~F'''~-g'~- ."~' ~': Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 72 feetI ADL 28346 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions February 28, 2001 March 4, 2001 May 28, 2001 I N/A feet MSL 1 ! 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 12320' MD / 9070' TVD 12277' MD / 9062' TVD YES r~ No E]'1 2313, (Nipple) feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD GR, Mem GR/CCL, GR/Resistivity 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-I-OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 94# H-40 Surface 80' 32" 345 Sx AS II 13-3/8" 72# L-80 Surface 2669' 17-1/2" 300 Sx Fondu & 650 Sx PF 9-5/8" 47# L-80 / S00-95 Surface 9878' 12-1/4" 500 Sx Class G 7" 29# L-80 9567' 9974' 8-1/2" 375 Sx C lass G 3-1/2" x 3-3/16" 9.3#/6.2#/ L-80 9445' 12315' 3-3/4" 33 bbls 15.8 ppg Class G x 2-7/8" 6.16# 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 5-1/2" 9531' 9520' 12040'- 12090' MD; 9025'- 9029' TVD; 4-1/2" 9616' 12192'- 12215' MD; 9046' - 9050' TVD; 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Added 10 Intervals, See Attached Post Rig Summary for Details 2" Gun Diameter, 4 spf (See Sidetrack Summary for details) 10142' - 11864' MD; 9073' - 9017' TVD; (10 Intervals) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) August 18, 2001 Water Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. · This 10-407 is submitted as directed per the 10-401 form approved January 30, 2001 (Permit #201-010) RECEIVED OCT 1 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Naska 0,1 & Gas Cons. ComlaissionAnchorage GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and MEAS. DEPTH TRUE VERT. DEPTH gravity, GOR, and time of each phase. Top of Sadlerochit (Zone 4) 9956' 8964' 31. LIST OF ATTACHMENTS 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ~'"'~ ~,,~~- Title Technical Assistant Date Terrie Hubble INSTRUCTIONS Prepared by Paul Rauf 564-5799. 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". RECEIVED Form 10-407 ORI IKIAL OCT 1 0 200t Alaska Oil & Gas Cons, Commission Anchorage Well: 16-05Ai Rig Accept: 02/26/01 Field: Prudhoe Bay Unit Rig Spud: 02/28/01 APl: 50-029-20574-01 Rig Release: 03/09/01 Permit: 201-010 Drilling Ri~]: Nabors 3S POST - RIG WORK 08/12/01 Complete BOP test. Run in hole with wireless CCL, firing head and memory tools. Make logging passes 9300' - 11300'. Pull out of hole and check data. -30' correction. Run in hole with gun #1,20' of 2" powerjets. Perf 11844' - 11864'. Pull out of hole with gun #1, laying rio-pro in liner. Lay down spent guns. Pick up 70' guns and run in hole with gun #2. 08113101 Peri 11542' - 11612', spot flo pro and pull out of hole. Lay down gun #2 and pick up 20' and 24' guns and run in hole with gun #3. Perforate 11370' - 11390', 11464' - 11488'. Spot rio-pro, pulling out of hole. Lay down gun #3, all shots fired. Make up memory tools and wireless CCL. Run in hole with memory logs and wireless CCL and log interval. 08114/01 Lay in rio-pro in liner, log up and flag pipe twice. Pull out of hole keeping hole full. Pick up gun #4, 42' and run in hole. Perf 11136' - 11178'. Pull out of hole laying in rio-pro. Lay down gun #4. Run in hole with gun #5. Perf 10700' - 10749', 10844' - 10864' and 10914' - 10962'. Pull out of hole, laying in rio- pro. Lay down gun #5. Pick up gun #6, 168' and 196' guns. Run in hole and perforate 10142' - 10310' and 10340' - 10536'. Pull out of hole laying in rio-pro. 08115/01 Lay down gun #6. Make up 2" nozzle with stinger. Run in hole and jet out flo-pro. Jet 47 bbls bleach across perfs. Chase remaining flo-pro to surface. Freeze protect well with 60 bbls of 50/50 MeOH / Water. 08128/01 MITIA passed, MITOA passed, PPPOT-T passed. Summary of All Perf'd Intervals MD TVD 10142' - 10310' 9073' - 9071' 10340' - 10536' 9070' - 9051' 10700' - 10749' 9032' - 9030' 10844' - 10864' 9024' - 9023' 10914' - 10962' 9020' - 9018' 11136' - 11178' 9007' - 9007' 11370' - 11390' 9005' - 9005' 11464' - 11488' 9005' - 9006' 11542' - 11612' 9006' - 9007' 11844' - 11864' 9016' - 9017' 12040' - 12090' 9025' - 9029' 12192' - 12215' 9046' - 9050' TREE = FMC WFI LI-EAD= FMC ACTUATOR= AXELSON KB. ELEV = 72' BF. ELEV = KOP = 9974' Max Angle = 100 @ 10577' Datum MD = 12320' Datum TVD= 8998' SS 13-3/8" CSG, 72~, L-80, ID = 12.347" H 2669' 16-05A 2313' H SAFED¢' I'OI'EB: VVMVB;ED'v~J_ Tx IA O3VfVt.NCA"IiCN 5-1/2" OTIS RQM SSSV hiP, ID =4.562'1 GAS LIFT MANDRELS TYPE VLV IMinimum ID =2.441"@ 10,004' I 3-3116" x 2-718" XO IBAKI~4-3/8"X4"TIEBACK, ID=4.00" H 9445' IBAKERDEPLOYIVENT SLV,ID- 3.00"H 9452' 3-1/2" FL4SX 3-3/16" TCIIXO, ID - 2.80" H 9494' 5-1/2"'rBG-PC, 17#, L-80, 0.0232 bpf, D =4.892" H 9531' ITOPOF 4-1/2" TBG-PC H 9531' ITOPOF 7" LNR, 29# Id 9567' 4-1/2"TBG-PC, 12.6#,L-80,0.0152bpf, ID=3.958" H 19-5/8" CSG, 47#, L-80, ID = 8.681" H 9878' PERFORATION SUIVIVIARY REF LOG: BHCS ON 04/12/81 ANGLEATTOP PERF: 85 @ 12040' Note: Refer to Production DB for historical perf data SIZE SPF II~rrERVAL I Opn/Sqz DATE 2" 4 10142 - 10310 O 08/15/01 2" 4 10340 - 10536 O 08/15/01 2" 4 10700 - 10749 O 08/14/01 2" 4 10844 - 10864 O 08/14/01 2" 4 10914 - 10962 O 08/14/01 2" 4 11136 - 11178 O 08/14/01 2" 4 11464 - 11488 O 08/14/01 2" 4 11370 - 11390 O 08/14/01 2" 4 11542 - 11612 O 08/13/01 2" 4 11844 - 11864 O 08/13/01 2" 6 12040 - 12090 O 03/07/01 2" 6 12055 - 12075 O 05/27/01 2" 6 12192 - 12212 O 03/07/01 2" 6 12195 - 12215 O 05/26/01 7"LNR, 29#, L-80, ID:6.184" H 10636' I H 9505' 9520' 9531' H 5-1/2" BKRPBRASSY, ID= 4.875"I H 9-5/8 " X 5-1/2" BKR SAB PKR I 5_1/2,, X 4.1/Z, XO, iD = 3.958,, i 9614' H 4'l/2"OTISXNNP'ID=3'725"I 9616' H 4-1/2"BAKERS/OSUB, D= "1 9617' H 4'1/2" TUBING TAIL I 9603' H ELMDTT- LOGGED03/22/82 I 9974' H TOP OF W~PSTOCK I I 7" MILLOUT WINDOW 9981' - 9986'I 10004' H 3-3/1~'TCII X2-7/8"STL XO, ID:2.441" I 3-3/16" LNR, 6.2#, L-80 TCI, ID= 2.80" I I2-7/8" LNR, 6.16#, L-80 STL, ID = PERFORATIONS P&A'd w/15.7 ppg CEMENT DATE REV BY COIVIVIENTS REV BY COIVIVlENTS 04/24/81 ORIGINAL COMFLETION 05/27/01 DYK/IIh ADD PERFS 01/02/01 SIS-QAA CONVERTEDTOCANVAS 08/25/01 DCR/KAI< PERFS 01/04/01 PCR PROPOSED SIDETRACK 03/09/01 adk CT Sidetrack- LTD ENGINEER 03/28/01 CH/TP/KK CORRECTIONS PRUDHOE BAY UNIT WELL: 16-05Ai PERIVIT No: 181-037 APl No: 50-029-20574-01 10N15E24 1327.1 FEL 4255.36 FNL BP E~ploration (Alaska) STATE OF ALASKA ~i" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL B GAS r-~ SUSPENDED D ABANDONED BI SERVICE B~ , Water lniector 2. Name of Operator ~.~'~1~ . 7. Permit Number BP Exploration (Alaska), Inc. _ ~~ 201-010 3. Address .~B,~ 8. APl Number P. O. Box 196612 Anchorage, AK 99519-6612 50-029-20574-01 4. Location of well at surface 9. Unit or Lease Name ¢~'.~"'%~; _'-'2~_~ '*7,' ~ 1771' FNL, 4180' FEL, Sec. 24, TION, R15E, UM (asp's 719887, 5929172); '.-,'.,~..;.:',.b; iS, il; I Prudhoe Bay Unit At Top Producing Interval t [i :.',';~. 10. Well Number . -- ......... 16-05Ai 4090' FNL, 1521' FEL, Sec. 24, T10N, R15E, UM (asp's 722613, 5926936) ~ At Total Depth ! ¢~/"") ! 11. Field and Pool 3502' FNL, 4523' FEL, SEC 19, T10N, R16E, UM (asp's 724689, 5927585)" --'. ..................../""' ........... ' Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 72 feetI ADL 28346 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. I15. Water Depth, if offshore 16. No. of Completions February 28, 2001 March 4, 2001 May 28, 2001 [ N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 12o. Depth where SSSV set 21. Thickness of Permafrost 12320' MD / 9070' TVD 12277' MD / 9062' TVD YES r~! No F~'1 2313' (Nipple) feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD GR, Mere GR/CCL, GR/Resistivity 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 80' 32" 345 sx AS II 13-3/8" 72# L-80 Surface 2669' 17-1/2" 3oo Sx Fondu & 65O Sx PF 9-5/8" 47# L-80 / S00-95 Surface 9878' 12-1/4" 500 Sx Class G 7" 29# L-80 9567' 9974' 8-1/2" 375 Sx Class G 3-1/2" x 3-3/16" 9.3#/6.2#/ L-80 9445' 12315' 3-3/4" 33 bbls 15.8 ppg Class G x 2- 7/8" 6.16# 24. Pedorations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) (2" carriers, 6 SPF, 60° phasing, & all perfs in Zone 4) 5-1/2" 9531' 9520' 12040'- 12090' MD; 9024'- 9029' TVD; 4-1/2" 9616' 12192'- 12215' MD; 9046'- 9050' TVD; 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary for details) ~27. PRODUCTION TEST Date First Production Method o! Operation (Flowing, gas lift, etc.) (well will not take injection) Water Injector 'Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA 'Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips, r'~ * This 10-407 is submitted as directed per the 10-401 form approved January 30, 2001 (Permit #201-010) O Form 10-407 !~ubmit in duplic_,¢~ Rev. 7-1-80 CONTINUED ON REVERSE SIDE (.2 ¢ ~ GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and MEAS. DEPTH TRUE VERT. DEPTH gravity, GOR, and time of each phase. Top of Sadlerochit (Zone 4)9956' 8964' RECEIVED JUL 1 ?.001 Alaska Oil & Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS Summary of 16-05A CT Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Dan Kara INSTRUCTIONS Prepared by Paul Raut 564-5799. 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 O iGiNAL DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 2/04/2001: 2/05/2001 - 2/07/2001: 2/26/2001 - 3/09/2001: 3/22/2001: 3/23/2001: 3/25/2001 - 3/26/2001: 5/26/2001 - 5/28/2001: MIRU CTU. PT'd BOP's. P&A'd well w/17 bbls of 15.6 ppg Class G Cement. WOC. PT'd cement plug to 1500 psi. Milled XN Nipple @ 9600'. Milled cement stringers & tagged ,TOC @ 9945'. Drilled cement to Whipstock & milled window f/9981' - 9984' CTM. Drilled 11 of FM. Dressed window interval. Pumped Biozan sweep. RD CTU. Nabors 3S CTD Unit drills sidetrack (see attached DIMS Report). MIRU CTU. PT'd equip. RIH w/CT & performed FCO to landing collar @ 12277'. POOH w/ CT. Attempted a surface injectivity test to 2000 psi - slowly bled to FM & no rate. FP'd well. RDMOL CTU. MIRU. Performed injectivity test (.05 bpm @ 3000 psi). RD. Performed a CT Acid Stim to increase injectivity as follows: MIRU CTU. PT'd equip. Opene¢ return line to Well 16-04. RIH w/CT & jetted perfs w/130° F 1% SL KCI Water. Tagged PBTD. Reciprocated across perfs an additional 150 bbls of 130° F 1% SL KCI Water. Performed injection test - 0 rate @ 2000 psi. Held safety meeting. Pumped the following flui¢ schedule across the open perforations listed below: 12040' - 12090' MD (Zone 4) Reference Log: Sperry Resistivity 3/5/2001. 12192' - 12212' MD (Zone 4) Pumped: (a) 10 bbls of 7.5% HCI w/additives @ 1.8 - 2.0 bpm, followed by (b) Displaced w/2 bbls of 1% SL KCI Water @ 0.5 bpm, followed by (c) Shutdown. Soaked. (d) Pumped 42 bbls of 7.5% HCI w/additives @ 0.5 - 0.4 bpm, followed by (e) Overflush of 100 bbls of 1% SL KCI Water @ 0.4 bpm, followed by (f) Shutdown. Saw no increase in injectivity. POOH w/CT. FP'd well. RD CTU. MIRU CTU. PT'd BOP. RIH w/CT to PBTD & spotted 10 bbls of 3% NI~,CI w/additives. Logged well for tie-in to Sperry Resistivity dated 3/5/2001. POOH w/logging tools. RIH w/2" CT conveyed Perforating guns & shot 40' of Reperfs (in 2 runs) from: 12055' - 12075' MD (Zone 4) 12195' - 12215' MD (Zone 4) All perfs shot @ 6 SPF, 60° phasing, & random orientation. POOH w/guns - ASF. Performed a Mud Acid Stim as follows: Pressured up the 5~1/2" x 9-5/8" IA to 1500 psi. RIH w/CT & tagged PBTD @ 12277'. Held safety meeting. Pumped across the open perforation,, (listed above) the following fluid schedule: Pumped: (a) 25 bbls of 3% NH,~CI w/additives @ 0.9 bpm, followed by (b) 50 bbls of 7.5% HCI w/additives @ 0.9 - 0.7 bpm, followed by (c) 50 bbls of 9% HCI - 1% HF @ 0.8 - 0.3 bpm, followed by (d) 150 bbls of 3% NH4CI w/additives @ 0.5 bpm, followed by (e) FP of 50 bbls of 60/40 Methanol Water @ 0.5 bpm, followed by. (f) Shutdown. POOH w/CT. RDMOL CTU. Well would not take injection. Well 16-05Ai is currently shut in. Wellwork options are being evaluated to bring this well on injection. Sidetrack Summary Page 1 BP EXPLORATION Page 1 of 1 Final Well ! Event Summary Legal Well Name: 16-05 Common Well Name: 16-05A Event Name: DRILL+COMPLETE Start Date: 2/27/2001 End Date: 3/9/2001 DATE TMD 24 HOUR SUMMARY 2/26/2001 9,985.0 (ft) MIRU f/16-06A. Test BOPE 2/27/2001 9,985.0 (ft) Finish BOP test. Swap to mud. Unable to pass 9556'. 2/28/2001 10,065.0 (ft) Change motor config, to pass 4.5" csg. Drill build section. 3/1/2001 10,680.0 (ft) Finished buiild section. Trip f/laterial BHA. Drill ahead. 3/2/2001 11,281.0 (ft) Chg out orienter. TIH. DD f/10680' to 11281'. Swap mud. 3/3/2001 11,980.0 (ft) Directionally drilled f/11281' to 11980' with wiper trips to window. 3/4/2001 12,300.0 (ft) Directional drill f/11980' to 12300. Make MAD pass and tie-in log. 3/5/2001 12,320.0 (ft) Corrected TD 12320'. P/U liner RIH tagged 9545'. Standback liner. 3/6/2001 12,320.0 (ft) Ran and cemented 2-7/8 liner. Bumped plug floats held. 3/7/2001 12,320.0 (ft) GR/CCL log 9,350 - 12280. spot 30 bbl Flowpro in liner 3/8/2001 12,320.0 (ft) POH with logging tool, RIH and perforate 70'. POH LD perforating assy 3/9/2001 12,320.0 (ft) Lay down CS hydril/perf guns. FP 2000'. N/D, R/D. Printed: 7/10/2001 4:42:35 PM , , BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name: 16-05 ~Common Well Name: 16-05A Spud Date: 4/1/1981 Event Name: DRILL+COMPLETE Start: 2/27/2001 End: 3/9/2001 Contractor Name: NABORS Rig Release: 3/9/2001 Rig Name: NABORS 3S Rig Number: 4 Date From-To Hours Activity Code NPT Phase Description of Operations 2/26/2001 ,00:00 - 06:00 6.00 RIGU = PRE MIRU Nabors 3S from 16-06A. Weather -40's F during move warming to -30 to raise derrick in the early morning hrs. Dowell CT and ROC units currently in Deadhorse. ROC needs some minor repairs. CT ready to arrive this morning and start RU. 06:00 - 22:30 16.50 RIGU ~ PRE Start daywork at 0600 hrs 2-26-01 for Nabors 3S. Start N/U BOPE. Installed barrier around 16-06A wellhead. ( AOGCC commissioner Julie Heusser and BP eng Ted Stagg toured rig) Install berm and spot upright tanks. Spot CT unit @ 1000 hrs. Pull BPV and install test plug. ROC arrive @ 1800 hrs (ROC late arriving due to lack of haul trucks available). M/U coil connector and pull test. 22:30 - 23:00 0.50 BOPSUF.P PROD1 PT all surface lines f/CT pump - rig pump back to ROC to 4000 psi. 23:00 - 23:59 0.98 BOPSUF:P PROD1 Start BOPE testing 500 psi/5 min, 4000 psi / 10 min. AOGCC ~nspector John Crisp waived witnessing test. 2/27/2001 00:00 - 06:00 6.00 BOPSUF:P PROD1 Finish testing BOPE 500 psi/5 min, 4000 psi / 10 min. AOGCC insp. John Crisp wavied witnessing. 06:00 - 07:55 1.92 DRILL P PROD1 P/U MHA and bullnose nozzle. 07:55 - 10:00 2.08 DRILL P PROD1 TIH to displace tbg w/9.5 ppg FIo-Pro. Tagged at 9534'. Unable to work past. 10:00- 11:45 1.75 DRILL P : PROD1 TOH laying in new mud. 11:45 - 13:30 1.75 DRILL P PROD1 Weekly safety meeting and pre-spud meeting with daylight crews. HSE rep. Paul Johnson attending. 13:30 - 15:00 1.50 DRILL P PROD1 M/U BHA #2 total length 66.07'. Orienter fitted with 11/32" bleed port. 15:00 - 17:30 2.50 DRILL P PROD1 TIH surface test MWD at 500', orienter at 3000'. Tagged at 9542'. Work through with pump on. RIH tag at 9556'. (uncorrected) 17:30 - 20:50 3.33 DRILL N DPRB PROD1 Attempting to work through at 9556'. No motor work indication while on bottom. Orient toolface around the clock twice. No overpull with complete setdown. Working with pump on - off. 20:50 - 21:50 1.00 DRILL N DPRB PROD1 Tie-in w/Sperry GR -7' correction to PDC (Need to apply to above depths) 21:50- 23:59 2.15 DRILL N DPRB PROD1 TOH 2/28/2001 00:00- 00:30 0.50 DRILL N DPRB PROD1 Finish TOH. 00:30 - 01:00 0.50 DRILL N DPRB PROD1 L/D 3.28 AKO motor and shock sub.. Motor appears weak, able to turn by hand to drain. Bit #1 shows gauge wear from contact w/casing but no major damage, re-runable only in lateral.. No junk marks on any BHA componet. 01:00 - 02:30 1.50 DRILL N PROD1 Replace load cell on CT unit. WO taper mill. 02:30 - 03:30 1.00 DRILL N DPRB PROD1 M/U BHA #2. (T~per mill and straight motor.) ~, 03:30 - 06:00 2.50 DRILL N DPRB PROD1 TIH. Mill passes through to top of whipstock without problems.~ Worked mill f/9610'-9500 several times. No motor work seen. 06:00- 08:00 2.00 DRILL N DPRB PROD1 TOH 08:00 - 09:00 1.00 DRILL N DPRB PROD1 L/D mill and straight motor. P/U BHA #3 w/3.28 deg motor. 09:00 - 10:30 1.50 DRILL N DPRB PROD1 TIH. Tag up at 3550' (no tie-in, uncorrected). Stall motor at .6 bpm rate. Attempt to work several times without gain. Bit and motor within the 4.5" tbg and above the XN nipple. Appears that motor geometry is hanging up. 10:30 - 13:00 2.50; DRILL N DPRB PROD1 TOH 13:00 - 14:00 1.00 DRILL N DPRB PROD1 Adjust AKO motor to 3.06 deg. Install 12/3~)'' nozzle in equalizer sub. No wear on bit #2. 14:00 - 16:30 2.50 DRILL N DPRB PROD1 RIH w/BHA #4. Slight bobble entering 4.5" tbg then took 5k Printed: 7/10/2001 8:04:30 PM BP EXPLORATION Page 2 of 4 Operations Summa Report Legal Well Name: 16-05 Common Well Name: 16-05A Spud Date: 4/1/1981 Event Name: DRILL+COMPLETE Start: 2/27/2001 End: 3/9/2001 Contractor Name: NABORS Rig Release: 3/9/2001 Rig Name: NABORS 3S Rig Number: 4 Date From -To Hours Activity Code NPT Phase Description of Operations 2/28/2001 14:00 - 16:30 2.50 DRILL N DPRB PROD1 going through to tubing tail. Continue RIH to 9840'. 16:30 - 17:00 0.50 DRILL P PROD1 Tie-in log at 9804' -14' correction. 17:00 - 17:30 0.50 DRILL P PROD1 Orient to high side. 17:30 - 23:59 6.48 DRILL P PROD1 Directional drilling ahead to 10065'. 3/1/2001 00:00 - 04:05 4.08 DRILL P PROD1 Continue and finish drilling build section f/10065' to 10187' MD (9002' TVD)_ 04:05 - 06:30 2.42 DRILL P PROD1 TOH 06:30 - 07:00 0.50 DRILL P PROD1 L/D BHA ~4 (3.06 deg motor asbly.) 07:00 - 09:50 2.83 DRILL ~ PROD1 M/U BHA #5 length 91.57' w/1.0 deg motor, MWD/Res-GR, orienter dressed with 14/32" nozzle. Bit to survey 22.0'. Bit to GR 46.64'. 09:50 - 11:50 2.00 DRILL ~ PRODI TIH suface test MWD/Orienter. Continue TIH tag at 9548' (uncorrected). Bring pump up to 1.5 bpm and went through. Continue RIH 11:50 - 13:40 1.83 DRILL ~ PROD1 Log tie-in -16 correction. 13:40 - 14:00 0.33 DRILL ~ PROD1 Orient TF 90L. 14:00 - 18:30 4.50 DRILL ~ PROD1 Directional drilling ahead f/10186' to 10423. 18:30 - 19:05 0.58 DRILL ~ PROD1 Wiper trip to window. 19:05 - 20:27 1.37 DRILL ~ PROD1 Directional drilling ahead f/10423' to 10516'. 20:27-20:35 0.13 DRILL ~ PROD1 Wipertrip 100'. 20:35 - 21:40 1.08 DRILL ~ PROD1 Directional drilling ahead f/10516' to 10587'. 21:40 - 22:35 0.92 DRILL P PROD1 Orient. 2 for 1 clicks. 22:35 - 23:59 1.40 DRILL P PROD1 Directional drilling ahead f/10587' to 10680'. 3/2/2001 00:00 - 01:25 1.42 DRILL = PROD1 Wiper trip to window. Slight overpull at 10480'. 01:25 - 02:43 1.30 DRILL P ~ PROD1 ' Directional drill from 10680' to 10840'. Orienter not responding well. 02:43 - 03:50 1.12 DRILL P PROD1 Wiper trip to window. 03:50 - 04:55 1.08; DRILL P PROD1 Directional drill from 10840' to 10854'. Unable to orient. 04:55 - 07:30 2.58 DRILL P PROD1 TOH f/orienter and download resistivity tool. 07:30 - 08:30 1.00 DRILL P PROD1 M/U BHA #6 w/new orienter and equalizer sub with 13/32" nozzle. 08:30 - 09:15 0.75 DRILL P PROD1 Download resistivity info. 09:15 - 11:10 1.92 DRILL P PROD1 TIH to 3000' surface test orienter and MWD. Continue TIH. 11:10 - 11:30 0.33 DRILL P PROD1 Tie-in log -18' correction. 11:30 - 12:20 0.83 DRILL P PROD1 Continue TIH orient and tag at 10854'. 12:20 - 15:00 2.67 DRILL P PROD1 Directional drill f/10854' to 10972'. 15:00- 15:45 0.75 DRILL :P PROD1 Wiper trip to 10000'. 15:45 - 19:00 3.25 DRILL P PROD1 Directional drill f/10972' to 11127'. 19:00 - 20:35 1.58 DRILL P PROD1 Wiper trip to window. 20:35 - 22:45 2.17 DRILL P PROD1 Directional drill f/11127' to 11281'. :22:45 - 23:59 1.23 DRILL P PROD1 Wiper trip to window. Overpull @ 11195', 10599'. Start swap to new Fie-Pro mud system. 3/3/2001 00:00 - 00:25 ' 0.42 DRILL P PROD1 Continue RIH from wiper trip to window. 00:25 - 03:20 2.92 DRILL P PROD1 Directional drill f/11281' to 11454'. 03:20 - 05:10 1.83 DRILL P PROD1 Wiper trip to window. 05:10 - 09:10 4.00 DRILL P PROD1 Directional drill f/11454' to 11668'. ' 09:10 - 11:15 2.08 DRILL P PROD1 Wiper trip /tie-in log +19' correction continue RIH. Tight at 10559'. Backream tight zone twice. 11:15 - 16:20 5.08 DRILL P PROD1 Directional drill f/11684' to 11836'. Stacking weight hard to get WeB 16:20 - 18:10 1.83 DRILL P PROD1 Wiper trip to window. 18:10 - 19:45 1.58 DRILL P PROD1 Directional drill f/11836' to 11844'. Stacking weight. Working through shale stringer. Considering dropping resistivity tool. ,, Printed: 7/10/2001 8:04:30PM BP EXPLORATION Page 3 of 4 Operations Summa Report Legal Well Name: 16-05 Common Well Name: 16-05A Spud Date: 4/1/1981 Event Name: DRILL+COMPLETE Start: 2/27/2001 End: 3/9/2001 Contractor Name: NABORS Rig Release: 3/9/2001 Rig Name: NABORS 3S Rig Number: 4 Date From -To Hours :Activity Code NPT Phase Description of Operations 3/3/2001 19:45 - 23:59 4.23 DRILL P PROD1 Directional drill f/11844' to 11980'. Shale still giving problems. ROP improving. 3/4/2001 00:00 - 02:20 2.33 DRILL P 'PROD1 Wiper to window. 02:20 - 03:50 1.50 DRILL P PROD1 Directional drill f/11890' to 12010'. Still fighting weight transfer. Short wiper trip intervals during drilling. 03:50 - 04:10 0.33 DRILL P PROD1 Wiper 100'. 04:10 - 08:00 3.83 DRILL P PROD1 Directional drill f/12010' to 12149'. Hard to get started, stacking weight, short wiper trips. 08:00 - 11:00 3.00 DRILL iR PROD1 Wiper trip to window. 11:00 - 11:35 0.58 DRILL P PROD1 Washed out seat in Nabors pump. Switched to Dowell pump. 11:35 - 14:00 2.42 DRILL P PROD1 Directional drill f/12149' to 12194' using Dowell pump. I Replaced all valves/seats on Nabors pump. 14:00 - 15:15 1,25 DRILL P PROD1 Switch over to Nabors pump. 15:15 - 18:50 3.58 DRILL P PROD1 Directional drill f/12194' to TD of 12300'. ~18:50 - 19:15 0.42 DRILL ~ PROD1 Short trip 200' in preparation of MAD pass. 19:15 - 23:00 3.75 DRILL ~ PROD1 Make MAD pass with resistivity from TD to window. 23:00 - 23:59 0.98 DRILL ~ PROD1 Log GR tie-in. 3/5/2001 00:00 - 00:15 0.25 DRILL ~ PROD1 Finish log tie-in. +25' correction. 00:15 - 01:40 1.42 DRILL ~ PROD1 TIH. Wash and ream to bottom. Tagged at 12320'. Corrected TD to 12320' MD (+20' correction) 01:40 - 05:30 3.83 DRILL ~ PROD1 TOH. Lay in 40 bbl new FIo-Pro mud in openhole. Flag EOP at 9500' and 7000'. Pump 60/40 methanol to freeze protect coil while TOH. 05:30 - 07:30 2.00 DRILL ~ PROD1 Setback injector, lay down BHA. 07:30 o 07:50 0,33 CASE ~ PROD1 Hold PJSM for running liner. 07:50 - 08:20 0.50 CASE ~ PROD1 Prepare rig floor for running liner. 08:20 - 15:20 7.00 CASE ~ PROD1 Make up 2-7/8" x 3-3/16" x 3-1/2" liner. Add (6) 3.5" drill collars. 15:20 - 15:45 0.42 CASE ~ PROD1 Make up and pull test coil connector. 15:45 - 18:00 2.25 CASE ~ PROD1 RIH with liner BHA #7. OAL = 2937.79'. 18:00 - 18:45 0.75 CASE P PROD1 Set down @ 7" x 4-1/2" cross over @ 9545'. Try various techniques and speeds without success. 18:45- 21:00 2.25 CASE N DPRB PROD1 POH with liner. 21:00 - 21:15 0.25 CASE N DPRB PROD1 PJSM for standing back liner. 21:15 - 23:59 2.73 CASE N DPRB PROD1 Standback back drill collars and liner. Take LRT to Baker shop to fix for setting in 5-1/2" tubing above problem area. 3/6/2001 00:00 - 01:30 1.50 CASE N DPRB PROD1 Continue and finish standback 2 7/8" liner. The 2 7/8" dia. aluminum guide shoe shows 1" long arc like impression 1/2" in from circumference. 01:30 - 08:20 6.83 CASE N DPRB PROD1 M/U 2 7/8" liner (BHA #8 3044.81') 08:20- 10:00 1.67 CASE N DPRB PROD1 RIHw/BHA#8. 10:00 - 11:30 1.50 CASE P PROD1 Do not see cross over with shoe. Do see every turbolator though. Set down @ 11200'. RIH @ 60 fpm. Set down @ 11829', and every +/- 31 feet after. Work past fault area @ 12010'. Work down to 12321'. Looks like bottom. Call out cementing equipment. Up weight sticky but 56k#. 11:30 - 13:20 1.83 CASE P PROD1 Circulate 5/8" ball to release liner. Ball on seat 49 Bbls. Shear and release from liner. MIRU Dowell cementers. ~13:20 - 13:45 0.42 CASE P PROD1 Hold PJSM with all on location. DS=9, NAD=4, PRA=2, Baker=2, BP=I. 13:45 - 14:00 0.25 CASE P PROD1 Mix cement and 1.5 ppb biozan. Cement to weight at 14:00. 14:00 - 15:55 1.92 CEMT P PROD1 PT cementers to 4500#. Pump 33 Bbls 15.8 ppb latex cement into coil, 2.2 bpm, 3100# ctp. Clean up cementing iron. Printed: 7/10/2001 8:04:30 PM .,, BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: 16-05 Common Well Name: 16-05A Spud Date: 4/1/1981 Event Name: DRILL+COMPLETE Start: 2/27/2001 End: 3/9/2001 Contractor Name: NABORS Rig Release: 3/9/2001 Rig Name: NABORS 3S Rig Number: 4 Date From- To Hours Activity Code NPT Phase Description of Operations ,. 3/6/2001 14:00 - 15:55 1.92 CEMT = PROD1 Launch Pee Wee plug. Chase with 1.5 ppb Biozan. Getting 1 for 1 returns. Zero return MMM and divert to pit #1 when cement at shoe. Plug lands on calculated displacement in LWP. LWP shears at 3600#. Displace cement from liner. LWP lands in collar at calculated displacement. Bump 3ressure 1000#. Bleed off pressure, floats holding. Pick up free of liner while pumping Biozan. Cement in place @ 15:45. 15:55 - 19:30 3.58 CEMT P PROD1 Circulate liner top clean with Biozan and chase cement out of hole with 1% KCL. 19:30 - 19:45 0.25 CEMT P PROD1 PJSM w/new crew to lay down collars. 19:45 - 22:15 2.50 CEMT P PROD1 Lay down collars and LRT. 22:15 - 22:25 0.17 CEMT P PROD1 PJSM for BOP test. 22:25 - 00:00 1.58 CEMT P PROD1 Change out 3-1/2" pipe rams for 2-7/8". Test BOP. 3/7/2001 00:00 - 03:00 3.00 BOPSUR P COMP Set test plug to get body test. Master valve leaking. 03:00 - 09:30 6.50 BOPSUR P COMP Test BOP equipment. All pass. Test witness waived by AOGCC inspector Jeff Jones. 09:30 - 10:15 0.75 BOPSUI; 3 COMP Pull test plug. 10:15 - 10:25 0.17 EVAL 3 COMP PJSM for logging tool make up. ;10:25 - 17:40 7.25 EVAL ~ COMP M/U Schlumberger Memory GR/CCL logging tool and 1-1/4" CSH. 17:40 - 21:30 3.83 EVAL 3 COMP RIh pick up 93 joints 1-1/4 CS Hydril. BHA= 3008.45. RIH to 9350'. UCA cement test results = 3200 psi. 21:30 - 00:00 2.50 EVAL 3 COMP Log GR/CCL 9,350' to 12,280' bottom perf at 12,212. Lay in 100 klsrv new FIoPro for perforating. 3/8/2001 00:00 ~ 01:30 1.50 EVAL = COMP POH to 4980 pump methanol to freeze protect coil. 01:30 - 02:00 0.50 EVAL ~ COMP POH to 2993. 02:00 - 02:30 0.50 EVAL ~ COMP Test liner lap to 2000 psi. Held 2000psi for 30 min 02:30 - 06:00 3.50 EVAL P COMP RIH 600' to thaw coil. Set back injector. 06:00 - 08:20 2.33 EVAL P COMP Standback Hydril work string. 08:20 - 09:30 1.17 EVAL P COMP Lay down Memory logging tools. 09:30 - 09:45 0.25 PERF P COMP PJSM for perf. guns. 09:45 - 10:30 0.75 PERF P COMP Pick up 70' of 2" perf. guns. 10:30 - 13:45 3.25 PERF P COMP Pick up 1-1/4" CS hydril. 13:45 - 14:00 0.25 PERF P COMP M/U coil to BHA. 14:00 - 17:30 3.50 PERF P COMP RIH with perf gun assembly. Tag landing collar and correct depth on up weight to 12277'. Pull up hole to place bottom shot at 12212'. 17:30 - 18:30 1.00 PERF P COMP Circulate 5/8" steel ball around with 1% KCL. Guns fire @ 58.4 Bbls away, 3950 psi. See no fluid loss. Pick up clean. 18:30 - 22:00 3.50 PERF P COMP POH with BHA. 22:00 - 22:15 0.25 PERF P COMP PJSM lay down 1-1/4" Hydril 22:15 - 00:00 1.75 PERF P COMP Laydown 1-1/4" Hydril work string 95 joints 3/9/2001 00:00 - 05:00 5.00 PERF P COMP Laydown 1-1/4" Hydril and perforating guns. All guns fired. 05:00 - 06:30 1.50 PERF P COMP RIH to 2000'. Freeze protect well with 60/40 methanol water. 06:30 - 07:30 1.00 BOPSUR P COMP Well static. Set BPV. 07:30 - 12:00 4.50 RIGD P POST Blow down all lines. Rig down coil unit. 12:00 - 14:00 2.00 RIGD P POST Clean pits, nipple down BOP stack. Rig Released at 14:00 hrs, 03/09/2001. 14:00 - 00:00 10.00 RIGD P POST Rig down process. Printed: 7/10/2001 8:04:30 PM April 5, 2001 ONLY ..... CommI I~ UU.I c2 o/-O/o BP Exploration (Alas~) Inc. 900 Eas! B~nson Boulevard P.O, Box 196612 Anchorage, Alaska 995 ! 9-66 ! 2 (907) 561-5111 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Pmdhoe-EOA_~ Pt. Mac, & Lisbume Well Work, This listing is provided as requh'ed under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for April 2 - 9, 2001: ' Well work Planned, 02-19 ADD PERFORATION 02-21 05-17B 06-21A 07-08A 11-22A 15-43 1'8-04A ADD PERFORATION ADD PERFORATION CTE PERFORATION CT REMOVE 2-3/8" GL COIL ADD PERFORATION SET crop w/CT CT REPERFORATION / ACID STIMULATION CT REMOVE 2-3/8" GL COIL , 18-13A CT SET CIBP FOR GSO 18-18A SET CIBP W/CT Starting next week, I will be including WOA, Milne Pt, & Endicott wellwork. If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at .raufpc@bp.com. Sincerely, ,,~ ~ Paul C. Rauf Technical Assistant, BPXA Alaska Drilling & Wells 14-Mar-01 AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Definitive Surveys Re: Distribution of Survey Data for Well 16-05A o2o/--I O Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: prOjected Survey: 9,850.00' MD 9,974.00' MD 12,320.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED ~AR 2'7 Naska Oil, & Gas Cons. Co~missio~ Anchorage North Slope Alaska Alaska Drilling & Wells PBU_EOA DS ~ 6, Slot 16-05 16-05A Surveyed: 4 March, 2001 S UR VEY REPORT March, 200~ Your Ref: 500292057401 Surface Coordinates: 5929172.41 N, 719886.49 E (70° 12' 32.1797" N, 148° 13' 36.5688" W) Kelly Bushing: 72.0Oft above Mean Sea Level DRILLING SERVICES A Halliburton Company Survey Ref: svy10773 Sperry-Sun Drilling Services Survey Report for 16.05A Your Reft 500292057401 Surveyed: 4 March, 2001 North Slope Alaska Measure d Depth (ft) 9850.00 Incl. Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) 21.370 139.700 8793.22 8865.22 2286.73 S 2634.22 E 9974.00 21.080 135.460 8908.82 8980.82 9990.43 24.410 135.000 8923.97 8995.97 10021.63 38.060 134.130 8950.58 9022.58 10052.13 51.240 133.280 8972.23 9044.23 10068.43 58.550 132.840 8981.60 9053.60 10098.83 71.720 130,300 8994.36 9066.36 10129.83 85.170 121.870 9000.56 9072.56 10158.23 88.680 109.910 9002.09 9074.09 10185.50 91.370 105.360 9002.08 9074.08 10215.50 91.370 99.900 9001.36 9073.36 10244.30 91.100 96.720 9000.74 9072.74 10279.30 91.720 93.020 8999.88 9071.88 10311.70 91.980 90.200 8998.83 9070.83 10344.30 93.570 86.150 8997.25 9069.25 10378.30 94.270 83.510 8994.93 9066.93 10410.10 94.270 80.860 8992.56 9064.56 10445.70 95.150 77.520 8989.64 9061.64 10477.70 96.650 74.340 8986.35 9058.35 10514.10 97.710 69.230 8981.79 9053.79 2319.86 S 2664.47 E 2324.36 S 2668.95 E 2335.67 S 2680.46 E 2350.44 S 2695.94 E 2359.53 S 2705.67 E 2377.77 S 2726.28 E 2395.55 S 2750.78 E 2407.91S 2776.24 E 2416.17 S 2802.22 E 2422.72 S 2831.48 E 2426.88 S 2859.97 E 2429.85 S 2894.82 E 2430.76 S 2927.19 E 2429.73 S 2959.73 E 2426.67 S 2993.51E 2422.36 S 3024.92E 2415.71S 3059.77 E 2407.97 S 3090.64E 2396.69 S 3124.93 E 65.890 8977.24 9049.24 2364.37 S 3154.76 E 61.310 8972.32 9044.32 2370.95 S 3181.81 E 59.540 8967.48 9039.48 2355.83 S 3208.43 E 60.070 8963.90 9035.90 2338.33 S 3238.52 E 56.550 8961.47 9033.47 2319.25 S 3269.42 E 10546.70 98.330 10577.30 100.180 10608.30 97.800 10643.30 93.920 10679.70 93.740 5926963.35 N 722586.17 E 5926931.12 N 722617.38 E 5926926.74 N 722621.98 E 5926915.77 N 722633.82 E 5926901.47 N 722649.72 E 5926892.66 N 722659.72 E 5926875.03 N 722680.85 E 5926857.97 N 722705.85 E 5926846.36 N 722731.67 E 5926838.86 N 722757.88 E 5926833.16 N 722787.31 E 5926829.83 N 722815.91 E 5926827.88 N 722850.83 E 5926827.91 N 722883.21 E 5926829.89 N 722915.71E 5926833.93 N 722949.38 E 5926839.15 N 722980.66 E 5926846.82 N 723015.30 E 5926855.45 N 723045.93 E 5926867.73 N 723079.88 E 5926880.91N 723109.34E 5926895.11N 723135.98 E 5926910.99 N 723162.16 E 5926929.37 N 723191.72 E 5926949.34N 723222.05 E Alaska Drilling & Wells PBU_EOA DS 16 Dogleg Vertical Rate Section Comment (°/'~OOft) 1.26 20,30 43.77 43.26 44.90 43.98 50.88 43.82 19,38 18.19 11.08 10.72 8.74 13.33 8.02 8.31 9.67 10.94 14.23 10.32 15.96 9.53 11.19 9.66 1693.25 1710.35 1713.01 1719.96 1729.46 1735.50 1748.62 1765.56 1785.26 1806.85 1832.10 1857.45 1889.19 1919.29 1950.22 1983.01 2014.00 2049.02 2080.67 2116.76 2149.01 2179.01 2209.20 2243.46 2279.02 Tie on point MWD Magnetic Window point 14 March, 2001.18:48 Page 2 of 7 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for 16-05A Your Reft 500292057401 Surveyed: 4 March, 2001 North Slope Alaska Measure d Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 10714.10 92.780 60.950 8959.51 9031.51 10750.10 92.600 64.650 8957.82 9029.82 10787.30 92.780 70,640 8956.08 9028.08 10816.70 93,660 73.460 8954.43 9026.43 10840.45 94.710 74.340 8952.69 9024.69 10872.75 94.360 77.870 8950.14 9022.14 10901.25 93.300 81.040 8948.23 9020.23 10938.25 92.160 87.380 8946.47 9018.47 10969.95 92.600 84,920 8945.15 9017.15 10997.65 94,360 82.100 8943.47 9015.47 11034.05 95.070 77.870 8940.48 9012.48 11063.45 95.150 75,580 8937.86 9009.86 11091.65 93.920 74.170 8935.63 9007.63 11123,45 89.430 72.940 8934.70 9006.70 11155.25 89.070 71,000 8935.12 9007.12 11184.05 90,040 68.710 8935.34 9007.34 11213.85 90,220 66.240 8935.27 9007.27 11245.65 90.750 63,600 8935.00 9007.00 11275.75 91.100 59.370 8934.52 9006.52 11304.45 89,870 56.200 8934.27 9006.27 2301.44 S 3298.77 E 5926968.00 N 723250.88 E 2285.00 S 3330.75 E 5926985.36 N 723282.36 E 2270.88 S 3365.10 E 5927000.48 N 723316.29 E 2261.83 S 3393.02 E 5927010.33 N 723343.93 E 2255.26 S 3415.78 E 5927017.56 N 723366.49 E 2247.53 S 3447.03 E 5927026.20 N 723397.50 E 2242.33 S 3474.98 E 5927032.21N 723425.29 E 2238.60 S 3511.74 E 5927037.01N 723461.92 E 2236.48 S 3543.33 E 5927040.05 N 723493.44E 2233.35 S 3570.80 E 5927043.97 N 723520.81E 2227.05 S 3606.52 E 5927051.32 N 723556.32 E 2220,32 S 3635.02 E 5927058.87 N 723584.61E 2212.99 S 3662.15 E 5927066.99 N 723611.53 E 2203,99 S 3692.63 E 5927076.87 N 723641,73 E 2194.15 S 3722.86 E 5927087,59 N 723671.66 E 2184.23 S 3749.90 E 5927098.29 N 723698.40 E 2172.82 S 3777.42 E 5927110.50 N 723725.58 E 2159.34 S 3806.22 E 5927124.81N 723753.97 E 2144.98 S 3832.66 E 5927139.94N 723779.98 E 2129.68 S 3856.94 E 5927155.94N 723803.80 E 2111.65 S 3882.65 E 5927174,70 N 723828.98 E 2092.64S 3907.12 E 5927194.42 N 723852.88 E 2072.25 S 3929.91 E 5927215.47 N 723875.07 E 2048.67 S 3952.70 E 5927239.70 N 723897.17 E 2026.00 S 3973.25 E 5927262.96 N 723917.04 E 11335.85 90.480 53.730 8934.18 9006.18 11366.85 91.810 50.560 8933.56 9005.56 11397.45 90.930 45.800 8932.83 9004.83 11430.25 89.070 42.270 8932.83 9004.83 11460.85 89.070 42.100 8933.32 9005.32 Dogleg Rate (o/looft) 13.07 10.28 16.09 10.03 5.76 10.95 11.70 17.39 7.88 11.98 11.74 7.76 6.62 14.64 6.20 8.63 8.31 8.47 14.10 11.85 8.10 11.09 15.81 12.16 0.56 Alaska Drilling & Wells PBU_EOA DS 16 Vertical Section Comment 2312.69 2348,37 2385.48 2414.81 2438.44 2470.45 2498.50 2534.30 2564.72 2591.60 2627.32 2656.40 2684.41 2716.13 2747.90 2776.70 2806.47 2838.14 2867.90 2895.94 2926.27 2955.76 2984.15 3013.64 3040.70 14 March, 2001. ~8:48 Page 3 of 7 DrillQuest 2,00,06 Sperry-Sun Drilling Services Survey Report for 16-05A Your Reft 500292057401 Surveyed: 4 March, 2001 North Slope Alaska Measure d Depth (ft) Incl. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) 11493,25 89.430 44.390 8933.75 9005.75 11524.05 89.690 47.030 8933.98 9005.98 11555.45 89.780 51.080 8934.13 9006.13 11586.85 89.250 54.960 8934.39 9006.39 11618.05 89.600 57.960 8934.71 9006.71 11644.05 89.690 60.070 8934.87 9006.87 11672.85 89.520 62.010 8935.07 9007.07 11701.05 89.520 65.180 8935.30 9007.30 11725.65 86.960 67.300 8936.06 9008.06 11758.05 86.170 69.940 8938.00 9010.00 11787.85 85.990 11821.05 85.810 11852.65 87.580 11885.05 87.050 11915.65 87.490 9012.04 9014.41 9016.24 9017.75 9019,21 73.290 78.050 76.280 72.580 70.470 8940.04 8942.41 8944,24 8945.75 8947.21 11945.85 88.190 67.650 8948.35 9020.35 11975.15 88.280 64.650 8949.25 9021.25 12005.05 87.220 68,000 8950.43 9022.43 12044.65 85.200 71.350 8953.05 9025.05 12074.45 84.580 70.290 8955.70 9027.70 2002.40 S 3995.44 E 5927287.19 N 723938,54E 1980.90 S 4017,49 E 5927309.33 N 723959.95 E 1960,32 S 4041.20 E 5927330.58 N 723983.05 E 1941.44 S 4066.28 E 5927350.19 N 724007.57 E 1924.20 S 4092.28 E 5927368.18 N 724033.06 E 1910.82 S 4114.57 E 5927382.20 N 724054.95 E 1896.88 S 4139.76 E 5927396.87 N 724079.73 E 1884.34 S 4165.02 E 5927410.14 N 724104.61 E 1874.43 S 4187.52 E 5927420.70 N 724126.81 E 1862.64S 4217.63 E 5927433.36 N 724156.57 E 1853.27 S 4245.84E 5927443.55 N 724184.49 E 1845.07 S 4277.91 E 5927452.68 N 724216,31 E 1838.06 $ 4308.67 E 5927460.58 N 724246.85 E 1829.38 S 4339.84E 5927470.17 N 724277.76 E 1819.69 S 4368.83 E 5927480.69 N 724306.45 E 1808.91S 4397.01 E 5927492.29 N 724334.31 E 1797.07 S 4423.79 E 5927504.91N 724360.73 E 1785.07 S 4451.15 E 5927517.70 N 724387.73 E 1771.35 S 4488.20 E 5927532.49 N 724424.36 E 1761.60 S 4516.23 E 5927543.06 N 724452.10 E 1752.59 S 4543.62 E 5927552.86 N 724479.21 E 1745.01S 4569.89 E 5927561.20 N 724505.25 E 1738.35 S 4599.30 E 5927568.72 N 724534.46 E 1733.20 S 4631.62 E 5927574.80 N 724566.61E 1729.59 S 4660.19 E 5927579.24N 724595.06 E 12103.45 83.080 73.290 8958.82 9030.82 12131.05 81.410 74.520 8962,54 9034.54 12161.65 79.380 79.980 8967.65 9039.65 12195.05 77.620 81.920 8974.31 9046.31 12224.45 79.120 83.680 8980.24 9052.24 Dogleg Rate (o/100ft) 7.15 8.61 12.90 12,47 9.68 8.12 6.76 11,24 13.51 8.49 11.23 14.31 7.91 11.52 7.04 9,61 10.24 11.74 9.86 4,11 11.51 7.49 18.80 7.76 7.77 Alaska Drilling & Wells PBU_EOA DS 16 Vertical Section Comment 3069.63 3O97.70 3127.01 3157.04 3187.37 3212.89 3241.33 3269.35 3293.89 3326.21 3355.93 3388.87 3420.17 3452.43 3482.99 3513.16 3542.37 3572.18 3611.69 3641.37 3670.18 3697.46 3727.38 3759.51 3787.59 14 March, 2001 - 18:48 Page 4 of 7 DrillQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for 16-05A Your Ref: 50029205740~ Surveyed: 4 March, 200~ North Slope Alaska Measure Sub-Sea Vertical Local Coordinates d Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 12254.65 79.380 86.860 8985.87 9057.87 1727.14 S 4689.75 E 12275.65 79.300 89.850 8989.76 9061.76 1726.55 $ 4710.38 E 12320.00 79.300 89.850 8997.99 9069.99 1726.44 S 4753.96 E Global Coordinates Northings Eastings (ft) (ft) 5927582.55 N 724624.54E 5927583.74 N 724645.14 E 5927585.12 N 724688.70 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 70.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12320.00ft., The Bottom Hole Displacement is 5057.74ff., in the Direction of 109.959° (True). Dogleg Rate (°/lOOft) 10.38 14.00 0.00 Alaska Drilling & Wells PBU_EOA DS 16 Vertical Section Comment 3816.21 3835.79 3876.78 Projected survey Comments Measure Station Coordinates d Depth TVD Northings Eastings (ft) (ft) (ft) (ft) Comment 9850.00 8865.22 2286.73 S 2634.22 E Re on point 9974.00 8980.82 2319.86 S 2664.47 E Window point 12320.00 9069.99 1726.44S 4753.96 E Projected survey 14 March, 2001 - 18:48 Page 5 of 7 DriilQuest 2.00.06 Sperry-Sun Drilling Services Survey Report for 16-05A Your Ref: 500292057401 Surveyed: 4 March, 2001 North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 16 Survey tool program for 16-05A From To Measure Vertical Measure d d Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 9850.00 8865.22 9850.00 8865.22 12320.00 9069.99 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro (16-05) MWD Magnetic (16-05A) March, 2001 - 18:48 Page 6 of 7 DrillOuest 2.00.06 Sperry-Sun Drilling Services North Reference Sheet for 16-05 North Slope Alaska Coordinate System is NAD27 Alaska State Planes, Zone 4, US Foot Grid Coordinates of Well: 5929172.41 N, 719886.49 E Geographical Coordinates of Well: 70° 12' 32.1797" N, 148° 13' 36.5688" W Grid Convergence at SurfaCe is 1.669°. Magnetic Declination at Surface is 26.943° (27 February, 2001) Grid North True North Magnetic North 274 I Magnetic Model: IGBGCF00 Date: 27-Feb-01 Declination: 26.943 Inclination/Dip: 80.776 Horizontal Component: 9216 nT Northerly Component: 8216 nT Eastedy Component: 4176 nT Vertical Component: 56753 nT Total Field Strength: 57496 nT Hole Direction Grid North is 1:.669° East~of True North (Grid Convergence) Magnetic North is. 26~943° East of True North (Magnetic Declination) MagnetiC North is 25.274° East of Grid North (Magnetic Convergence)' To: convert a :True Direction to:a Grid Direction, Subtract 1.669 degrees To conveA'a Magnetic Direction to a True DireCtion, Add 26,943:degrees To conveA aMagnetic Direction to a Gdd Direction, Add 25~274 degrees Alaska Drilling & Wells PBU_EOA DS '16 14 March, 2001 - 18:48 Page 7 of 7 DrillQuest 2.00.06 TRF__~.. = FMC WELLHEAD= FMC ACTUATOR= AXELSON KB. ELEV = ' 72' BI=. ELEV = KOP = 9974' Max Angle = 100 @ 10577' Datum MD = 12320' Datum 'I'V D= 8998' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" Id 2669' 16-05Ai 2313' Id 5-1/2" OTIS RQMSSSV NIP, ID=4.562"I GAS LIFT MANDRELS TYPE VLV IMinimum ID = 2.441" @ 10,004' 3-3/16" x 2-7/8" XO IBAKER 4-3/8" x 4'' TIEBACK' ID = 4'00'' I~ 9445' IBAKERDEPLOYMENTSLV, ID- 3.00" 9452' 13-1/2'' FL4S x 3'3/16'' TCII xO' ID ' 2'80'' I-I 9494' 5-1/2" TBG-PC, 17#, L-80, 0.0232 bpf, ID=4.892" Id 9531' ITOPOF 4-1/2" TBG-PC I-t 9531' ITOPOF 7" LNR, 29# I-I 9567" 4-1/2" TBG-PC, 12.6#, L-80, 0.0152 bpf, ID = 3.958" Id 9616' 19-5/8'' CSG, 47#, L-80, ID = 8.681" Id 9878' 9505' 9520' 9531' 9614' I 9616' 9616' I 9603' I-I I-I I-I I-i I-I I-I I-I 5-1/2" BKR PBRASSY, ID = 4.875"I 9-5/8" X 5-1/2" BKR SAB PKR I 5-1/2" X 4-1/2" XO, ID = 3.958" 4-1/2" OTIS XN NIP, ID = 3.725" 4-1/2" BAKER S/O SUB, ID = " I 4-1/2" TUBING TAIL I ELMD 'FI' - LOGGED 03/22/82 I PERFORATION SUMMARY REF LOG: BHCS ON 04/12/81 ANGLE AT TOP PERF: 85 @ 12040' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12040 - 12090 O 03/07/01 2" 6 12055- 12075 O 05/27/01 2" 6 12192- 12212 O 03/07/01 2" 6 12195- 12215 O 05/26/01 Milled Window off Mech Whipstock I 3-3/16" LNR, 6.2#, L-80 TCII, ID -- 2.80" I 3-3/16" TCII X 2-7/8" STL XO, ID = 2.441" I lTD@ 12320'I 17,, LNR, 29#, 1-80, ID = 6.184" 10636' IPBTD I-I 10641' I 2-7/8" LNR, 6.16#, L-80 STL, ID= 2.44" I-~ 12315' I PERFS P&A'd w/15.6 ppg CEMENT 2/4/2001 DATE REV BY COMMENTS REV BY COMMENTS 04/24/81 ORIGINAL COMPLETION 05/27/01 DYK/tlh ADD PERFS 01/02/01 SlS-QAA CONVERTED TO CANVAS 07/10/01 pcr corrections for 10-407 01/04/01 PCR PROPOSED SlDETRACK 03/09/01 adk CT Sidetrack - LTD ENGINEER 03/28/01 CH/TP/KK CORRECTIONS PRUDHOE BAY UNIT WELL: 16-05Ai PERMIT No: 201-010 APl No: 50-029-20574-01 10N 15E24 1327.1 FEL 4255.36 FNL BP Exploration (Alaska) 03/08/200~ 15:43 FAX 907 564 4264 BP EXPLORATION bp March 7, 2001 ~ UU.I BP Exploration (Alaska) Inc. 900 East B~nson Boulevard P.O. Box 196612 Anchorage, Alaska 995194612 (907) 561-5111 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7"~ Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Pmdhoe-EOA, Pt. Mac, & Lisburne Well Work This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for March 5 - 12, 2001' Wel._._li 03-08 03-25A 03-27 03-28 06-18 13-27A ,~ ,~ &' 16-21 NK-22 S-101 S-103 Work Planned REPERFORATION REPERFORATION REPERFORATION / HYDRAULIC FRACTURE TREATMENT REPERFORATION CT ACID WASH - GEL CEME~ SQUEEZE CT ADD PERFORATION W/WORK PLATFORM CTD SIDETRACK (NABORS 3S) REPERFORATION ADD PERFORATION ADD PERFORATION INITIAL PERFORATION S-105 INITIAL PERFORATION If additional data or scheduling information is needed, please cai1 me at 564-5799 or E-mail me at raufpc@bp, com~ Sincerely, //~//~ Alaska Drilling & Wells RECEIVED MAR 0 8 2001 Alaska Oil & Gas Cons. Commission Anchorage FEB 86 '01 09:0~PM BP MILME POIMT 6ROUP P.2 BP Exploration Endicott Well Operations Sunday ll_Et'Slickline: :i~ne: Other: 2/25 4-10 1-47 Dummy off GLV~s a~d ddft tul~i~ to 3.625' Leak detection water flow log.. Mond~ lISlickline: Oth_er: 2/26 3-25 2-14 Pull SSSV, drift ~v)t_h dumr~y w.h.!pstock Water flow Io~l Tuesd?¥ Slickline; Eqine: Other: 2/27 3:25 Run static pressure survey 3-39 gas-lift survey & FSPL 1-05L2-12; 3-45,~ ..4-10~ 5-01 & 5-02 MIT's w/AOGCC witness Wednesday 2/28 ISlickline: 1-25 Other: _ -. ,..:_. Brush, Flush & pull .S. SSV,'~lhff'tubing _Thursday 3/01 tSlickline: 1-25 .Other: 2~5e Caliper s~rvey tubin{t & liner PFO ,... ........ ...... .F.r.!.d..ay IISlicl<line: 3/O2 1-25 Static pressure Saturday 3/04 Slbkline; 1-21 ' '~alil~r_s~vey of tubing. ~-t. t.~ ............. 1-25 InJectivlty test February 28,2001 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) $61-$111 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 ~ ~... Dear Commissioners: .:, . ., Re: Prudhoe-EOA, Pt. Mac, & Lisburne Well Work This listing is provided as required under the terms of Conservation Order No. 34 lC (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for February 26 - March 4,. 2001' Well O3-28 02-34A 15-41A ~~~!:~?~..:,'.'., ~'~' 13-27A 11-32 15-35 16-21 S-101 Work Planned REPERFORATION CT SET CIBP FOR GSO CTD SIDETRACK (NABORS CDR1) CTD SIDETRACK (NABORS 3S) CT ADD PERFORATION W/WORK PLATFORM ADD PERFORATION ADD PERFORATION REPERFORATION ADD PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc @bp.c°m. Sincerely, y~ ~~ Paul C. Ra~uf Technical Assistant, BPXA Alaska Drilling & Wells RECEIVED I~A ,r? 0 1 2001 Alaska 0il & Gas Con's. ~ Anchorage Commission ALASKA OIL AND GAS CONSERVATION COPlPl~SSION TONY KNOWLES, GOVERNOR 333 W. 'F" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 16-05A BP Exploration (Alaska) Inc. permit No: 201-010 SurLoc: 1775'SNL, l100'EWL, Sec. 24, T10N, R15E, UM Btmhole Loc. 3570'SNL, 600'EWL, Sec. 19, T10N, R16E, UM Dear Mr. Kara: 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~jr Commissioner BY ORDER OF THE COMMISSION DATED this ~a ~ day of January, 2001 dlf/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASI~ .)IL AND GAS CONSERVATION PERMIT TO DRILL 20 AAC 25.005 [] Drill 5tl Redrill 1 lb. Type of well [~Servicp.,. [] Exploratory ~ Stratigraphic Test [] Development Oil a. Type of work [] Re-Entry [] Deepen [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. RKB = 72' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ~.~52.~ADL 028346 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AA(:; 25.025) 1775' SNL, 1100' EWL, SEC. 24, T10N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 4090' SNL, 3758' EWL, SEC. 24, T10N, R15E, UM 16-05A~. Number 2S100302630-277 At total depth 9. Approximate spud date 3570' SNL, 600' EWL, SEC. 19, T10N, R16E, UM 02/10/01 Amount $200,000.00 2. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVDi' ADL 028332, 600' MDI No Close Approach 2560 12259' MD / 8998' TVDss 6. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9970' MD Maximum Hole Angle 95 ° Maximum surface 3200 psig, At total depth (TVD) 8900' / 4100 psig 8. Casing Program Specifications Setting Depth Size To:) Bottom Quantity of Cement Hole Casin,q Wei,qht Grade Couplin,q Len,qth MD TVD MD TVD (include sta,qe data) 3-3/4" 3-s/~6×~-?/8,, 6.2# / 6.4# L-80 ST-L / FL4S 2729' 9530' 8498' 12259' 8998' 137 sx Cla..~s 'G' ECEi'v' '"' , , , 19. To be completed for Redrill, Re-entry, and Deepen Operations. A/aska Oil & Gas Cons. Present well condition summary Commission Total depth: measured 10641 feet Plugs (measured) PBTD Tagged at 10436' (10/96) Anchorage true vertical 9599 feet Effective depth: measured 10436 feet Junk (measured) true vertical 9410 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 345 sx Arcticset II 80' 80' Surface 2597' 13-3/8" 3000 sx Fondu, 650 sx Permafrost 2669' 2669' Intermediate Production 9806' 9-5/8" 500 sx Class 'G' 9878' 8891' Liner 1069' 7" 375 sx Class 'G' 9567' - 10636' 8603' - 9595' Perforation depth: measured 9960' - 10015', 10026' - 10043', 10057' - 10087', 10160' - 10170', 10190' - 10260', 10375' - 10425' true vertical 8968' - 9019', 9029' - 9045', 9058' - 9086', 9154' - 9164', 9182' - 9247', 9354' - 9400' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements , , Contact Engineer Name/Numbec Dan Kara, 564-5667 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoigg..L~ true and correct to the best of '~y knowledge :". :.=' )' ".. ":=': i' ('.".: :;i~'.'~ ':' .". "= i.: :.:. ':..:,=:'".~..!,': ..'.(:=. !' .=.=.... i.: != !:..' ,::~ i j'i'~,,.:;i..:;CO'm'rni~'siOn .U'S~Only~ '=.==i' .~'.:.'~.' :.i .~?.. ?.~i '.i:: .'...i.?= .... '"i, '""':"' ~' ""'.".=i.= ,',.; )."i'.?.i .' :?i'.' .::'.'~.;' '~:.. :'.".' .' .' ':i ~ ~ {.-, (2.~[t~ 50- 029-20574-01 for other requirements Conditions of Approval: Samples Flequirod [] Yes ~ No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures ffi Yes [] No Directional Survey Required [] Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] IOK [] 15K ,~.SK psi for CTU Other: .. by order of Al)proved By ~ ..... Commissioner the commission Date ~t/~./6. I Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX Prudhoe Bay Injector 16-05Ai Sidetrack Summary of Operations: 16-05i is being sidetracked to improve Zone 4 waterflood sweep. This sidetrack will be conducted in two phases. Phase 1 Prep Work: Install mechanical whipstock, P&A well, mill window Drift tubing, perform integrity test of inner annulus. · Run a caliper log in 7" liner. · Measure static bottom hole pressure. · Install mechanical whipstock at 9970' · RU service CTU, pump 15.8 ppg cement to isolate existing perfs. · Mill 3.80" window at 9970' (Zone 4 KOP) Phase 2: Drill and Complete sidetrack: Planned for approx. Feb 10, 2001. Coiled tubing drilling will be used to drill and complete the directional hole as per attached plan. Mud Program: · Phase 1: Weighted brine (9.0-9.5 ppg) for window milling · Phase 2: Flo-Pro (9.0-9.5 ppg) for drilling operations. Disposal: · No annular injection on this well. All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. All Class I wastes will go to Pad 3 for disposal. Casing Program: · 3-3/16", 6.2# STL L-80 x 2 7/8", 6.4#, L-80 FL4S liner will be run from TD to approx. 9530' MD (into tubing tail) and cemented with approximately 28 bbls. Top of cement is planned to be at the liner top. The liner will be pressure tested to 2000 psi and perforated with coiled tubing conveyed guns. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run in the open hole section. · A Memory CNL may be run in cased hole. Hazards · Lost circulation risk is Iow. Faults will be crossed and are expected to be sealing · H2S has not been measured from this injection well. Adjacent wells at the surface are 16-05 which has 136 ppm H2S (3-26-99) and 16-04 with 43 ppm (11-06-00). DS 16 is designated as an H2S drillsite. Reservoir Pressure · Res. pressure is approx. 4100 psi @ 8900 tvd. · Max. surface pressure with gas (0.1 psi/fO to surface is 3200 psi. · Reservoir pressure will be measured prior to sidetracking. JAN .l 3 2001 Alas/~a Oil ~ ~s con° c ,ni io 16-05Ai Potential Drilling Hazards Post on Rig . Please perform pre-job Hazard ID and Safety meetings prior to every change in work scope during the operation. Also, if things don't feel right shut-down the operation and discuss the situation before making the next operational move. SAFETY FIRST. H2S has not been measured from this injection well. Adjacent wells at the surface are 16-05 which has 136 ppm H2S (3-26-99) and 16-04 with 43 ppm H2S (11-06-00). DS 16 is designated as an H2S drillsite.. Ensure H2S pit monitors and personal monitors are operational. Reservoir pressure is approx. 4100 psi @ 8900 tvd, or -8.9 ppg EMW. Bottom hole pressure will be measured prior to sidetracking. 4. Maximum anticipated well head pressure w/full column of gas 3200 psi. o Two mapped faults will be crossed. However, risk of lost circulation is low. Offset faults in this area are sealing faults. . JAN 1 2 2001 ARCO ALASKA, INC. SSSVNIP Tubing-PC Casing ....... Casing Gas Lift Mandrel/Dummy Valve 1 Gas Lift Mandrel/Dummy Valve 2 Gas Lift Mandrel/Dummy Valve 3 Gas Lift Mandrel/Dummy Valve 4 Gas Lift Mandrel/Dummy Valve 5 Gas Lift Mandrel/Dummy Valve 6 Gas Lift Mandrel/Dummy Valve 7 Gas Lift Mandrel/Dummy Valve 8 Gas Lift Mandrel/Dummy Valve 9 Gas Lift Mandrel/Dummy Valve 10 Gas Lift Mandrel/Dummy Valve 11 Gas Lift Mandrel/Dummy Valve 12 PBR PKR XO Tubing-PC i 96i4' M N D = 3.7~5" ...(d-.,,:!,/:KO...,~!~..~,N..,,,,~,ip) .................. NOGO Liner SOSUB ........ TTL Pen' ...... ., Ped ... Perf ,' Perf "' SAND A Prudhoe Bay 16-05 APl: 500292057400 SSSV Type: Annular Fluid: Diesel/9.6 NaCI Reference Log: BHCS Last Tag: 10093 Last Tag Date: 5/14/98 Well Type: INJ Depth Annotations Depth Comment 9614 9614' MIN ID = 3.725" (4-1/2" Otis XN Nip) Safety Notes Date Note 2/23/00 WAIVERED WELL - T x IA Communication. General Notes Date Note TTL ELM @ 9603: ELM Tubing Tail (Logged 03/22/82) Daterun: 1981-04-24 Other (plugs, equip., etc.) - JEWELRY Depth TVD Type Description 2313 2313 SSSVNIP 5-1/2" Otis RQM SSSV Nipple 9505 8547 PBR 5-1/2" Baker PBR Assembly 9520 8561 PKR 9-5/8" x 5-1/2" Baker SAB Packer 9531 8571 XO Crossover 5-1/2" x 4-1/2" 9614 8647 NOGO 4-1/2" Otis XN Nipple 9616 8649 SOSUB 4-1/2" Baker Shearout Sub 9617 8649 TTL Casing Strings. All Size Weight Grade 13.375 72.00 L-80 9.625 47.00 L-80 7.000 29.00 L-80 Tubing Strings- All Size Weight Grade Top 5.500 17.00 L-80 0 4.500 12,60 L-80 9531 4-1/2" Tubing Tail Orig Compltn: 4/24/81 Last W/O: 4/18/81 Ref Log Date: 4/17./81 RKB: 72 ft TD: 10641 ftKB Max Hole 37 deg @ 5600 Angle: Angle @ TS: 21 deg @ 9956 Btm Feet Description 2669 2669 Casing 9878 9878 Casing 10636 1069 Liner Top 0 0 9567 Btm Feet Description 9531 9531 Tubing-PC 9616 85Tubing-PC V Type V OD Latch Port TRO R0-3 0.000 R0-3 0.000 R0-3 0.000 R0-3 0.000 R0-3 0.000 R0-3 0.000 R0-3 0.000 R0-3 0.000 R0-3 0.000 R0-3 0.000 RO-5 0.000 6-os Gas Lift Mandrels/Valves Stn MD TVD Man Man V Mfr Mfr Type 1 2977 2976 -211RL55 OT RD-l.5 1.5 2 5159 4888.211RL55 OT RD-I.5 1,5 3 6792 6204 -211RL55 OT RD-I.5 1.5 4 7798 7064 -211RL55 OT RD-I.5 1,5 5 8455 7618-211RL55 OT RD-I.5 1.5 6 8529 7682-211RL55 OT RD-I.5 1.5 7 8878 7986 -211RL55 OT RD-1.5 1.5 8 8953 8052 -211RL55 OT RD-1.5 1,5 9 9222 8291 -211RL55 OT RD-I.5 1.5 10 9296 8358-211RL55 OT RD-I.5 1,5 11 9369 6423-211RL55 OM D-14R 1.5 12 9444 8491-211RL55 OT RED-1.5 1.5 perforations:;:::: ::::: : : :;:;:: :::: : 10160-10170 9154-9164 10 10190-10220 9182-9210 30 10220-10260 9210-9247 10375-10425 9354-9400 stimulatiOns & Treatments Interval Date Type 10093-10425 5/14/98 SAND Interval TVD Zone Status Feet ~PF 9960 - 10010 8968 - 9014 ZONE 4 O 50 4 9960 - 10015 8968 - 9019 ZONE 4 O 55 6 10026 - 10042 9029 - 9044 ZONE 4 O 16 4 10026 - 10043 9029 - 9045 ZONE 4 O 17 6 10057 - 10087 9058 - 9086 ZONE O 30 4 4,HOT ZONE 3 O ZONE O 3,ZONE 2 ZONE 2 O ZONE 2 O Angle @ TD: 23 deg @ 10641 Rev Reason: Safety Note (kak) Last Update: 2/23/00 Date Run 1/1/60 1/1/60 1/1/60 1/1/60 0 1/1/60 0 1/1/60 0 1/1/60 0 1/1/60 0 1/1/60 0 1/1/60 0 12/26/93 Comment R0-3 0.000 0 !!1/60 Date Type 3/22/82 IPERF 11/11/95 RPERF 3/11/84 APERF 11/11/95 RPERF 3/11/84 APERF 6 10/6/96 APERF 6 10/6/96 APERF 40 610/22/96 APERF 50 6 5/4/96 APERF : ID 4.562 0.000 0.000 0.000 3.725 0.000 0,000 Vlv Commenl Comment RECEIVED J/ N .[ 2, ZOO1 Alaska Oil &.Gas Cons. Commissic~ Anchorage TREE = ? WELLHEAD: ACTUATOR= FMc AXEL KBi' ELEv: BF. ELEv 72 K0P = .? Max Angle: 3? @ 560O D~tUm MD~ ? Datum TV'D= ?! 113-3/8" CSG 72# L-80 0.1481bpf ID:12.347 Id ir 16-05Ai PROPOSED HORIZONTAL SIDI~ IMinimum ID = 3.725" @ 9614' 4-1/2" OTIS XN NIPPLE I PROPOSEDTOPOF 3-3/16" Liner Id 9530' 15-1/2" TBG-PC 17#, L80, 0.0232bpf ID=4.892 Id 9531' ITOPOF 4-1/2" TBG-PC Id 9531' ITOPOF 7" LNR Id 9567' 2669' ~ 14-1/2" TBG-PC 12.6# L80 0.0152bpf ID=3.958 Id 9616' 19-5/8'' csg 47#, L-80 0.0732bpf ID:8.681 Id 9878' I-.--J 2313' Id 5-1/2" OTIS RQM SSSV NIP, ID= 4.562 GAS LIFT MANDRELS 1 I 2977l 2976l Zl RO-3 2 I 51591 4888l 36l R0-3 3 I 67921 62041 341 R0-3 4 I ~981 ~°6~1 331 RO-~ 5 I 8455l 76181 311 R0-3 6 I 8529l 7682l 31l RO-3 7 I 88781 7986l 291 Ro-3 ~ I 8953l 8°521 29l R0-3 9 19222182elI271 R0-3 10 I 92961 83581 271 R0-3 11 I 93691 84231 26l RO-5 12 19444184911 251 BO-3 9505' H 5-1/2"BKRP~RASSY I 9520' H 9-5/8"x 5-1/2" BKR SAB PKR 9531' l-t xo 5-1/2"x 4-1/2"I 9603' H ~'~ I 9614' l"t 4-1/2" OTIS XN NIP, 18=3.725 I 96~6' H 4-~,, ~.s~os~ I 9617' I--~4-1/2" TUBING TAIL I RECEIVED JAN ~ 2 ZOO1 PERFORATION SUMMARY REF LOG: BHCS on 4/12/1981 ANGLE AT TOP PERF: 121 @ 9956 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 6 9960-10015 O 11/11/1995 6 10026-10043 O 11/11/1995 6 10160-10170 O 10/06/1996 6 10190-10220 O 10/06/1996 6 10220-10260 O 10/22/1996 6 10375-10425 O 05/04/1996 4 10057-10087 O 03/11/1984 4 10026-10042 O 03/11/1984 4 9960-10010 O 03/22/1982 ]7" LNR 29# 1-80 0.0371bpf ID=6.1841d 10636' Alaska Oil & Gas Cons. Commission Anchorage 9970' I I Mill Window off W/S I 10030' ] I I I3-3/4" Open Hole I r 12260'1 I 2-7/8" Liner Cemented & Perforated I PERFORATIONS P&A'd w/15.7 ppg CEMENT I DATE REV BY COMMENTS 04/24/81 ORIGINAL COMPLETION 01/02/01 SIS-QAA CONVERTED TO CANVAS 01/04/2001 PCR PROPOSED SIDETRACK PRUDHOE BAY UNIT CO,,. '~,~ WELL: 16-05Ai ~.h PERMIT No: 181-037 APl No: 50-029-20574-01 10N 15E24 1327.1 FEL 4255.36 FNL BP Exploration (Alas ka) BP Amoco Baker Hughes INTEQ Planning Report Colnp~Jlt~: BP A,~OC.~ Field: Prudhoe -3ay ,git,,: PB DS 16 Well: 16-(]5 ~:ellp~th: ~an¢l 16-05A · -,. % , ,. .. · . Field: Prudhoe Bay North Slope UNITED STATES M'ap ~ystem:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) ~ys Datum: Mean Sea Level Date: i..9:2001 '1 ime: 1 ?:5.'4:22 Pa~zt': ! (..'o-ordlmlte(Ni...) R[,fcrence: Well: 16-05. True No'!q Verlieal (13,'i)) Referem.'t,: System: Mean Sea LOVe! Sretihn O,'S) Referent'e: Well {0.00E.(}.90N.70 Sur~,..,'~ (':almdHtion Melhml: Minin',lurr. i ClJrv&¥'.lJr(} Db: Oracle .... ,.. · Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: PB DS 16 TR-10-15 UNITED STATES: North Slope Site Position: Nor!hiag: From: Map Easting: Position Uucertaiuty: 0.00 ft Ground 'Level: 0.00 ft 5927441.99 ft Latitude: 70 12 15.545 N 718969.88 ft Longitude: 148 14 4.567 W North Reference: True Grid Convergence: 1,66 deg Well: 16-05 Slot Name: 05 16-05 Well Position: +N/-S 1702.47 ft Northing: 5929171.69 ft Latitude: 70 12 32.289 N +E/-W 966.89 ft Eastin~: 719886.97 ft Longitude: 148 13 36,504 W Position Uncertainty: 0.00 ft Wellpath: Plan#1 16-05A Drilled From: 16-05 500292057401 Tie-on Depth: 9970.00 ft Cra'rent Datum: 6: 05 3/28/1981 00:00 lteiCht 72.00 ft Above System Datum: Mean Sea Level Magnetic Data: 1/9/2001 Declination: 26.98 deg iField St,'en~th: 57495 nT Mag Dip Ansle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0,00 0.00 0.00 70.00 Plan: Pla n #1 Date Composed: 1/9/2001 Lamar's Plan #6 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets ~; amc l)e.criln im~ 'rv !') ...................................... Mai} ......... Map < .... l.atiltule---4,, i;:asHng Deg Min ,qec .:'.--- t.on~imfle--:'> De.,., Min Sec Annotation MD I'VD f'. ft ............................................ 9850.00 8793.22 Tie.a'l Po,or 9970.00 8905.09 Kick-off Point 9980.00 8914.35 1 10153.88 9005.71 2 10190.79 9004.09 3 10529.10 8976.29 4 10879.10 8948.89 5 11210.35 8935.38 6 11466.83 8935.38 7 11666.83 8938.39 8 11966.83 8953.62 9 12259.47 8998.01 TD 'RECEIVED ..... JAN 1 2 2001 Alaska Oil & Gas Cons. Commission Anchorage Plan Section Information M D loci ff dog ........... 9850.00 21.37 9970.00 21.08 9980.00 23,29 10153.88 90.00 10190.79 95.00 de~ ft 'ft 139.70 '' '~'~93.22 .... -2:~86,59 135,60 8905.09 -2318.68 130.23 8914,35 -2321,25 102,29 9005.71 -2367.83 88.39 9004.09 -2371,26 'kL~-W I.)I.S Build 'l'm'n 'l¥'i'i .... l'arget ft deg;1O0rt deg., 100fi deg"~ 00f~ deg ~634.~ ........0.00 0.0~' 0.o0"' 0.o0 " 2663.50 1,26 -0.24 -3.42 257.04 2666.27 30.00 22.14 -53.70 315.00 2793.48 40,00 38.36 -16.07 330.00 2830.10 40.00 13.55 -37.68 290.00 BP Amoco Baker Hughes INTEQ Planning Report Compan.~: BP Arp. oc',~ Field: Prudhoe giie: PB DS ~'ellpath: ~a~l 16-05A .... Platt Section Information M D in¢! Azim llale: i;9'2001 Time: i t:53:2;~ Pa~e: Ce-ordinate(NE) Refertmee: We~l: IE-05. True Yerlical ('1'~' I.)) Refereot~: S'yst(~m: Mean Sea Levo~ Section (V S) Rt.i~rence: Wo~l {0.00E.0.Dt')N.70 {",~')Az0 5.r~e~ Cah'nlation Melh.d: MJnJmom C,,, ;~.:1.,(. Db: Oracle ................. 'I'VD -'.-.N,'-S -+E"-W DI.S BuihJ '1 m'n ;l"'l]~O'''I'araet ft ',rt fl oeg:'. ' 1 ~a:,," de<vv i OOft deg..' 109'.'tdeg 1'~529.;1'0' 94.1~5 .... 54.,~'5' "8976.29 "-2265.33 3145.01 .... 10.00 -0.25 -10.03 '" 270.00 10879.10 94.55 89.56 8948.89 -2159,18 3471.69 10.00 0.11 10.03 88.00 11210.35 90.00 56.71 8935.38 -2064.33 3783.98 10.00 -1.37 -9.92 263.00 11466.83 90.00 82.36 8935.38 -1975.39 4022.27 10.00 0.00 10.00 90.00 11666.83 88.29 62.43 8938.39 -1915.21 4211.91 10.00 -0.85 -9.96 265.00 11966.83 86.02 92.38 8953.62 -1850.54 4500.96 10.00 -0.76 9.98 95.00 12259.48 76.86 64.23 8998.00 -1793.42 4781.26 10.00 -3.13 -9.62 250.00 Slll-¥ey .... ~,I!) Incl .&tim SS I S,:D N.'S E.%~ ~TapN 51ape I)I.S ~'S '!'1:{) Tool 9850.00 2~37 139.70 8793.22 '-2286.59 26~4,26 592~962.87 7225'86.57 0.0~ 1693.33 0.00 MWD 9875.00 21.30 138.85 8816.51 -2293,48 2640.19 5926956.16 722592.70 1.26 1696.55 257.04 MWD 9900.00 21.24 ~38.00 8839.80 -2300.27 2646,21 5926949.55 722598.91 ~.26 1699.89 257.83 MWD 9925.00 21.18 137A5 8863.11 -2306.94 2652.31 5926943.06 722605.20 1.26 1703.34 258.62 MWD 9950.00 21.12 136.29 8886.43 -2313.51 2658.50 5926936.67 722611.58 1.26 1706.90 259.41 MWD 9970.00 21,08 135.60 8905,09 -2318.68 2663.50 5926931.65 722616.73 1.26 1709.84 260.22 MWD 9975,00 22.16 132,79 8909.74 -2319.96 2664,82 5926930.41 722618.09 29.97 1710,64 314.95 MWD 9980.00 23,29 130.23 8914.35 -2321.25 2666,27 5926929.16 722619.57 29.97 1711.56 317.57 MWD 10000.00 30.47 122.34 8932.18 -2326.52 2673.58 5926924.10 722627.04 40,00 1716,63 330.00 MWD 10025.00 39,85 116.28 8952.61 -2333,48 2686.15 5926917.52 722639.80 40.00 1726.06 337.05 MWD 10050.00 49.44 112.23 8970.38 -2340.64 2702.17 5926910.83 722656.02 40.00 1738.66 342.03 MWD 10075.00 59.14 109.22 8984.95 -2347.78 2721.14 5926904.24 722675.19 40.00 1754.04 344.92 MWD 10100.00 68.89 106.76 8995.90 -2354,69 2742.49 5926897.96 722696.73 40.00 1771.75 346.68 MWD 10125.00 78.68 104.61 9002.87 -2361.16 2765.57 5926892.16 722719.99 40.00 1791.23 347.77 MWD 10150.00 88.48 102.60 9005.66 -2366.99 2789.69 5926887.04 722744.27 40.00 1811.89 348.37 MWD 10153.88 90.00 102.29 9005.71 -2367.83 2793.48 5926886.31 722748.08 40.09 1815.17 348.49 MWD 10175.00 92.88 94.34 9005.18 -2370.88 2814.35 5926883.87 722769.03 40.00 1833.74 290.00 MWD 10190.79 95.00 88.39 9004.09 -2371.26 2830.10 5926883.95 722784.78 39.94 1848.41 289.83 MWD 10200.00 95.00 87.47 9003.29 -2370.93 2839.27 5926884.54 722793.94 10.00 1857.13 270.00 MWD 10225.00 94.99 84.96 9001.11 -2369.28 2864.12 5926886.91 722818.73 10.00 1881.05 269.92 MWD 10250.00 94.97 82.45 8998.94 -2366.55 2888.87 5926890.37 722843.39 10.00 1905.24 269.70 MWD 10275.00 94.95 79.94 8996.78 -2362.74 2913.48 5926894.89 722867.88 10.00 1929.67 269.48 MWD 10300.00 94.91 77.43 8994.63 -2357.85 2937.90 5926900.49 722892.14 10,00 1954.29 269.27 MWD 10325.00 94.86 74.92 8992.50 -2351.90 2962.09 5926907.14 722916.14 10.00 1979.06 269.05 MWD 10350.00 94.81 72.41 8990.39 -2344.89 2985.99 5926914.84 722939.83 10.00 2003.91 268.84 MWD 10375.00 94.74 69,90 8988.31 -2336.85 3009,57 5926923.57 722963,16 10.00 2028.82 268.63 MWD 10400.00 94.67 67.40 8986,26 -2327,78 3032.77 5926933,31 722986.09 10.00 2053.73 268.42 MWD 10425.00 94.59 64.89 8984.24 -2317.70 3055.56 5926944.05 723008,58 10.00 2078.59 268.21 MWD 10450.00 94.50 62.38 8982,26 -2306.63 3077.89 5926955,76 723030.57 10.00 2103.35 268.01 MWD 10475.00 94.40 59.88 8980.32 -2294.60 3099.71 5926968.42 723052,04 10.00 2127.98 267.81 MWD 10500.00 94.29 57.37 8978,43 -2281.62 3120.99 5926982.01 723072.93 10.00 2152.41 267.62 MWD 10525.00 94.17 54.86 8976.59 -2267.72 3141,69 5926996.51 723093.21 10.03 2176.62 267.40 MWD 10529.10 94.15 54.45 8976,29 -2265.33 3145.01 5926999.00 723096.46 10.03 2180.55 267.21 MWD 10550.00 94.22 56.54 8974.76 -2253.52 3162.19 5927011.30 723113,28 10.00 2200.73 88.00 MWD 10575.00 94.30 59.05 8972,91 -2240.24 3183.28 5927025,19 723133.98 10.00 2225.10 88.15 MWD 10600.00 94.37 61.56 8971.02 -2227.89 3204.93 5927038.16 723155.27 10.00 2249.67 88,34 MWD 10625.00 94.43 64.06 8969.10 -2216.50 3227,10 5927050.19 723177,09 10.00 2274.40 88,53 MWD 10650.00 94.48 66.57 8967~16 -2206,09 3249.75 5927061,25 723199.43 10.00 2299.24 88.72 MWD 10675,00 94,52 69.08 8965,20 -2196,69 3272.83 5927071.33 723222.22 10.00 2324,14 88.91 MWD 10700.00 94,55 71.59 8963,22 -2188.30 3296,29 5927080.40 723245.43 10.00 2349.06 89.11 MWD 10725.00 94,58 74.09 8961.23 -2180.95 3320,10 5927088.44 723269.01 10.00 2373.95 89.31 MWD 10750.00 94,60 76.60 8959,23 -2174,64 3344.21 5927095.44 723292.92 10.00 2398,76 89.51 MWD 10775.00 94,61 79,11 8957,23 -2169.40 3368,57 5927101.39 723317.12 10.00 2423.44 89,71 MWD I\I._Vi._! V E.T.L,/ JAN 1 2 Z001 Alaska Oil & Gas Cons. Commission . . BP Amoco .~::~:: '.'.::!?.,g. ~' :: Baker Hughes INTEQ Planning Report i:~:;'i:~i¢;~'~ .............. Cutup:my: BP Amoco tlate; 1;9,.'20.31 I'im¢: 1 ?:53.22 Page: Field: Prudhoe Bay' ('.:o-ordinate(NE} Reference: Well: 1,r',,-05. True No:th ,Rile.: PB DS 16 X'erlieal (i"¢l)) Reference: System: Mean Sea Level Well: 16-05 ,%¢don {V,%) Rel~'rence; We!; (0 00E.0.30N 7(').00Az0 Wellpath: Planet1 16-05A .~m'~r3 Calc~dation %lelh.d: Minffnum Cl;;¥a.'.iJre Db: ............................... S,rve3. ............................................................................................................................ MI) lm',l .~ ~.im ~$'I"~ i) N,'S i,'.,'"~,~,' MapN MapE !}1 .~ ~'$ 1'!"O 'l'cml ff dog de'.j ft ft f! ft ft deg.." 10.3fi f.'. deg 10~007;0 94,60 81.628~gg;22-2165.23 339~ii~5927106.2Z'"723341.55 "10.00 24,it'.~5 89.91' MWb' 10825.00 94.60 84.138953.21-2162,14 ~17.86 5927110.08 723366.16 10.002472,24 90.11MWD 10850.00 94.58 86.638951,22-2160,13 3442.705927112.81 723390.94 10.002496,2790.31MWD 10875.00 94.55 89.1589~9.22-2159.21 ~6Z.S0 ~92Z~,.~6Z2~,~.~ ~0.0S~9.~S ~0.~2MWD ~0~zg.~0 S,,SS S9.S~~9,~.~9-2~59.~3,Z~.~,5~2Z~,.~ Z2~,~.~0~0.0~~2~.~ ~0.~2MW~ ~0~00.00 ~,29 ~Z.~ ~Z.2~ -2~S~,~~2.52 S~2Z~5.ZSZ2S~0.Z0~0.0025~,~0 2~.00MWP ~0~25.00 9~,~ ~,.9~~9,S.~S-2~SZ.0~ ~Z,,0 ~2Z~.~ Z2~,65.52 ~0.00~SZ.S~ 262.~MWD ~0~S0.00 9~,~S ~2.S~~9~.~ -2~S~.29 ~S~2,~ 5~2Z~2~.SS Z2~,~0.22 ~0.00~S~.Z~ 2~2.~6 MW~ ~0~ZS.00 ~,~2 ~0.0~~2,2~ -2~S0,S0 ~6~.~ S~2Z~26.05 Z2~S~.Z6~0.002~,2~ 2~.~ MWP ~000,0092,~ ZZ.S~~9,0.9~-2~,S.~5 ~SS~,~ ~92Z~.62 Z2~S~.0~~0.00~0.~0 2~2.~MWB ~025.00~2,65 ~S.0Z~,~,~ -2~9,Z~~S.60 S~2Z~.2~ Z2~SS~.~Z ~0.002~S,Z2 2~2.2~ MWD ~050.00~2,~0 Z2.S,~.~ -2~2.Z~~,S~ 5~2Z~S.S~Z2~S~.~,~0.00. ~0.~ 2~2.0~ MWD 11075.00 91.95 70.11 8937,68 -2124,79 3663.25 5927154.56 723610.37 10.00 2715,61 261.98 MWD 11100.00 91.59 67,63 8936,91 -2115.78 3686,56 5927164.24 723633.40 10.00 2740.59 261.89 MWD 11125.00 91.24 65.16 8936.29 -2105,78 3709.46 5927174.91 723656.00 10.00 2765.53 261.81 MWD 11150.00 90.88 62,68 8935.83 -2094,79 3731.91 5927186.54 723678.12 10,00 2790.39 261,75 MWD 11175.00 90.52 60.21 8935.52 -2082.84 3753.86 5927199.12 723699.71 10.00 2815.10 261.70 MWD 11200.00 90,15 57.74 8935.38 -2069.96 3775,29 5927212.63 723720.75 10.00 2839.64 261.67 MWD 11210.35 90.00 56.71 8935,38 -2064.33 3783,98 5927218.51 723729.28 10.03 2849,74 261.53 MWD 11225.00 90,00 58.18 8935.38 -2056.45 3796,33 5927226.75 723741.39 10.00 2864.03 90.00 MWD 11250.00 90.00 60.68 8935.38 -2043.73 3817.85 5927240.08 723762.53 10.00 2888,61 90.00 MWD 11275.00 90.00 63,18 8935.38 -2031.97 3839.91 5927252.48 723784.24 10.00 2913.36 90.00 MWD 11300.00 90.00 65.68 8935.38 -2021.17 3862.46 5927263.93 723806.46 10.00 2938.24 90.00 MWD 11325.00 90.00 68.18 8935.38 -2011.38 3885.45 5927274.39 723829.16 10.00 2963.20 90.00 MWD 11350.00 90.00 70.68 8935.38 -2002.59 3908.86 5927283.85 723852.30 10.00 2988.20 90.00 MWD 11375.00 90.00 73.18 8935.38 -1994.84 3932.62 5927292.30 723875.83 10.00 3013.18 90.00 MWD 11400.00 90.00 75.68 8935.38 -t988.12 3956.70 5927299.71 723899.70 10.00 3038.10 90.00 MWD 11425.00 90.00 78.18 8935.38 -1982.47 3981.05 5927306.07 723923.87 10.00 3062,92 90.00 MWD 11450.00 90.00 80.68 8935.38 -1977.88 4005.62 5927311.37 723948.30 10.00 3087.58 90.00 MWD 11466.83 90.00 82.36 8935.38 -1975.39 4022.27 5927314.34 723964.87 10.01 3104.07 90.00 MWD 11475.00 89.93 81.55 8935.39 -1974.25 4030.36 5927315.72 723972.92 10.00 3112.07 265.00 MWD 11500.00 89.71 79.06 8935.46 -1970.03 4055.00 5927320.65 723997.43 10.00 3136.66 265.00 MWD 11525.00 89.49 76.56 8935.64 -1964.76 4079.43 5927326.63 724021.69 10.00 3161.43 265.01 MWD 11550.00 89.28 74.07 8935.91 -1958.42 4103.61 5927333.67 724045.68 10.00 3186.32 265.03 MWD 11575.00 89.06 71.58 8936.27 -1951.04 4127.50 5927341.74 724069.33 10.00 3211.28 265.05 MWD 11600.00 88.85 69.09 8936.72 -1942.63 4151.03 5927350.83 724092.61 10.00 3236.27 265.09 MWD 11625.00 88.64 66.60 8937.27 -1933.21 4174.18 5927360.93 724115.48 10.00 3261.25 265.13 MWD 11650.00 88.43 64.11 8937.91 -1922.79 4196.89 5927372.00 724137.88 10.00 3286.16 265.19 MWD 11666.83 88.29 62,43 8938.39 -1915.21 4211.91 5927380.02 724152.67 10.00 3302.86 265.19 MWD 11675.00 88.22 63.24 8938,64 -1911.48 4219.18 5927383.95 724159.82 10.00 3310.96 95.00 MWD 11700.00 88.00 65.74 8939.46 -1900.72 4241.72 5927395.36 724182.04 10.00 3335.83 94.98 MWD 11725.00 87.79 68.23 8940.38 -1890.95 4264.72 5927405.80 724204.74 10.00 3360.78 94.89 MWD 11750.00 87.59 70.72 8941.39 -1882.20 4288.11 5927415.23 724227.87 10.00 3385.75 94.80 MWD 11775.00 87.38 73.22 ' 8942.49 ~1874.47 4311,86 5927423.65 724251.38 10.00 3410.71 94.70 MWD 11800.00 87.19 75.71 8943.67 -1867,78 4335.91 5927431.03 724275.23 10.00 3435.61 94.59 MWD 11825.00 86.99 78.21 8944.94 -1862.15 4360.24 5927437.37 724299.38 10.00 3460.39 94.47 MWD 11850,00 86,81 80.70 8946.29 -1857.58 4384,78 5927442.65 724323.77 10.00 3485.01 94.35 MWD 11875.00 86,63 83.20 8947.72 -1854.08 4409,49 5927446.87 724348.37 10.00 3509.43 94.21 MWD 11900.00 86,45 85.70 8949,23 -1851,67 4434.32 5927450.00 724373.12 10.00 3533,59 94.07 MWD 11925.00 86,28 88.20 8950.82 -1850.34 4459,23 5927452.05 724397.99 10.00 3557.46 93.92 MWD 11950.00 86,12 90.70 8952,47 -1850,10 4484.18 5927453.02 724422.91 10.00 3580,97 93.76 MWD 11966.83 86,02 92.38 8953.62 -1850.54 4500,96 5927453.07 724439.70 9.98 3596.60 93.62 MWD RECEIVED JAN 1 2 Z001 BP Amoco Baker Hughes INTEQ Planning Report Comp:sfl.~: BP An3o&o I-'i~:ld: Ptudi'oe Bay ~il~,: PS DS 16 V,'cll: 16-05 V~'t'llpatt~: Plan~l 16-05A ........... Date: t;9"2091 Time: 7?:53:22 t'a~c: 4 C,~-,~rdinate(:Nl-:.~ i;[el'm'ence: We:l: 16-05 True Nodh Verlical ('l'~' I)~ Referents,: Sys't6m: Mean Sea Level Section {VS) Rel~rence: Well Sm-~c). Caiculalinn Mclh,d: Mimmum CuP~ature I)b: C. racle ........ MD ~ deg 11975.~ 8517'4' 12000.00 84.89 12025.00 84,05 12050.00 83.22 12075.00 82,40 12100.00 81.60 12125.00 80,81 12150.00 80.03 12175.00 79,27 12200.00 78.53 12225.00 77,81 12250.00 77,12 12259.48 76,86 Atim .. 91.61 89.25 86.89 84.51 82.13 79.74 77.34 74.93 72.51 70.08 67.63 65.17 64.23 S~'I'YD ft 8954121 8956,25 8958.66 8961,43 8964.56 8968.04 8971.86 8976,02 8980.51 8985.33 899O,45 8995.88 8998.OO -1~3~0.82 -1851,01 -1850.17 -1848,31 -1845.43 - 1841.53 - 1836.62 -1830.71 -1823.82 -1815,95 -1807,13 -1797.36 -1793,42 4509,1 ~ 4534.02 4558,89 4583.66 4608.29 4632.74 4656.95 4680.88 4704.49 4727.72 4750.54 4772,9O 4781.26 MapN MapE I.H .~ ~ S TFO 'l'rml ft fi deg;10Of: ft de§ 59274531~ 724447.85 10.00" ~)4.15 "250.00 MWD 5927453.56 724472.75 10.00 3627.50 250.06 MWD 5927455.12 724497.58 10.00 3651.15 250,25 MWD 5927457.71 724522.29 10.00 3675.07 250.48 MWD 5927461.31 724546.83 10.00 3699.21 250.74 MWD 5927465.92 724571.15 10.00 3723.51 251.04 MWD 5927471.53 724595.21 10.00 3747.94 251.37 MWD 5927478.13 724618.96 10.00 3772,45 251.74 MWD 5927485.70 724642.35 10.00 3796.99 252.14 MWD 5927494.24 724665.34 10.00 3821.51 252.57 MWD 5927503.73 724687.90 10.00 3845.97 253.04 MWD 5927514.14 724709.96 10.00 3870.33 253.54 MWD 5927518.33 724718.20 10.04 3879.53 254.18 MWD ,JAN 1 ~ 2001 Alaska Oil & Gas Cons. Commission Anchorage BP Amoco WELLPATH DETAILS Plan~l 16-05A 5~0292057401 Parent Wellpath: 16-05 Tie on MD: 997'0.00 Vertical Section Origin: Slot- 0.5 (0.00,0.00) Vertical Section Angle: 70.00~ Rig: Depth Reference: 6: REFERENCE INFORMATION Co-ordinate (N/E) Reference.: Well Cart[re: 16-05, True Nodh VP. rtic. al (TVD) ReterP. nce: SystP. m: Mean Sea L~vel Section tVS) Refere~lce: Slot - 05 (0.00,0.00) Measured Depth Refem~ce: 6: 05 3/28/19~1 O0:00 72.0 Calculation Method: Minimum Curvature 8000- 8100' 9100- · :.. : . LEGEf(D 72.00ft -150~ - ' - .:_. -1600' :'-' . :.. .... ~.q- 1800 '.'.' .............. : ...... ' .............. ' ......... 'iV r...,,...>:r ~ r.J[ $ ~ ' · . ..... 'i'.' '~'~ -2100 '.': ' ' ' "%'.~' ................... : ..... :: ' ' mm ...... -230ff'. i ~----~'-2400".; ................. "'-1 ......-: '-:- ........ :i"'{'." .... :~ . ':'.. : ':.v .' .. : ;. ............. : ......... : ........ : ........ d I:-'-. ~ '.! : ... d~:(;; J' '.'. : ...... i. ·· ~ : -- , -. .... : .,' ~ · ~-:-",; 2-"~~ 2:-J.. .',,:..~ "100 .~ [.'".; ·. '~, ,,;.,.' :..-: ..p. ................... :.~ ............. ~.....'P...~..~ .... ;.. ~ ,~ .... ..!i.. _ ;ii..-: . Azimt(fl]s to True North Magnetic No~h: 26 98' Magnetic Field Stren Ch 57495nT Dip Angle: 80. ~' Date: 11gI2~1 M~el; 8GGM20~ West(-)/E t [lOOft/in] i :' ~ ~*. .~:=..:::-: :. ...... :----.: ................. i,,r.z., : . : ............................ ... .'.'.'.'.'.3';'.:-'; -: -.::- .... ....:. ---.-- ..-:-:.: ':'"' :':':u ':'";u'.': .:...:.:...: '.' :- '.; -:' i ':' . ....: ..: . ':' i':' .':' F:' ..... .: v-..- ......-.u i.: ......... ... "'" 'i' ':' :': .:... :.:.: - :...:.:...: ................ . .... A':'.:.' :.'.'.'.'.'A'.'.'.'.'.'.'.'.'.'.'. ....-, . ':' i ':' "': "': ':' ' · ·; "- i" .... yFi'imP" .'Fi' .;.'!'.im'.:.V.'m':'.?:'.:.':'.X.'.':'. i'.:.'?.:.'!'.i';.'.'.'.'.':.' 4500 4600 4700 48O0 4.900 5000 5100 4500 4600 4700 · ;t~: 1';;:,; I;¢2-~ '.!;.;: ;','ii ',,I;7;~ ;-'?;-.'; 73;,~: ),lO; ;;'::~) 21.;:;; -','.-';~: 2;,.'."i '.-.-'.',k'l 3000 .:'...-_ _;_J 3300 3400 3:,;'~') .:i.:'f; {-,-'--.': .'.':-C i .[:k:;; 4000 41rJo 42'f:4' 41:,:{' 4.1-,0 Vertical Section at 70.00° [lOOft/in] Z m Plot 1/9/2001 6:09 PM Drilling Wellhead Detail ~ CT Injector Head Methanol Injection Otis 7" WLA Quick Connect----- I I Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE ~ Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure JI - 7" Riser I Annular BOP (Hydril),7-1/16" ID 5000 psi WP Combination Cutter/Blinds 2-3/8" Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with 2-7/8" Pipe & Slip Rams 2-3/8" Pipe & Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In ~Tubing Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold ri Upper Annulus Lower Annulus J/iN 2, 001 Alaska Oil & Gas Cons. Commission Anchorage DATE I CHECK NO. ] H 18091 0 VENDOR ALASKAO I LA O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 122100 CK122100 100. O0 100. O0 PYMT :OMMENTS' Pea:nit To D~ill -ee HANDL[NC INST' S/H - Tee~ie Hub ~le X4&28 ATTACHED CHECK IS I. PAYMENT FOR ITEMS DESCRIBED ABOVE. ~ 100r 00 100, 00 ~IE ?i,.RST'~TIO,'~[,BANK':~F ASHLAND ].".>.ii . ":."i; .:AN AI~E~i.~IATE' O'F.. .:i::i' '. ::': .. ':::;!:::.'i ::...:.' ' NA~ION~.:i~ITY B,~IK ;': '..i :'...: :; .::.:.."::' ........ "C.~EVEL~,~D OHio ' ' · .. '"'" :" ..:':' :i:: ,, '" ': :' ''':! '. :,: .'ii:. ::56-389 ::":':" Ne..H :.:........ ..: · "'001809&0 PAY RE: Well B-29A BOP Configuration Subject: RE: Well B-29A BOP Configuration Date: Fri, 26 Jan 2001 23:21:14-0000 From: "Kara, Danny T" <KaraDT@BP.com> To: "'Tom Maunder'" <tom_maunder@admin.state.ak.us> CC: "Prudhoe AOGCC (E-mail)" <aogcc_prudhoe_bay(~admin.state.ak.us>, "GPB, 3S Supervisor" <GPB3SSupervisor@BP.com>, "Stanley, Mark J (ANC)" <StanleMJ@BP.com> Tom, Attached is a schematic of the agreed upon BOPE configuration for Nabors 3S, Prudhoe well B-29A. The 2-7/8" pipe rams will be installed during the next weekly BOP test, probably tonight/tomorrow. As discussed on the phone, this same BOP configuration will also be used for Prudhoe well 16-05A and 16-06A. Both the DS16 well will have tapered liners. The longer term solution will be to replace the Hyddl D stack with a TOT. This will allow us to install both 2-7~8" pipe/slips and 3-112" pipe/slips (TOT configuration top to btm: B/S, 3.1/2" P/S, mud cross, 2-7/8" P/S, 2-3~8" P/S). The 3-1/2" PIS have been ordered and will arrive in 8 weeks. Please let me know if I can provide additional information. Thanks. <<B-29A BOPE Tapered Liner. doc>> Dan Kara BP Coiled Tubing Drilling 564-5667 (office) 240,8047 (cell) 564-5193 (Fax) karadt@bp.com ..... Original Message---- From: Tom Maunder[mailto:tom maunder~.admin.state.ak, us] Sent: Thursday, January 25, 2001 4:30 PM To: Kara, Danny T Cc: AOGCC North Slope Office Subject: Re: Well B-29A BOP Configuration << File: Card for Tom Maunder >> Dan, This note confirms our conversations regarding the proposed ram arrangement when you are running the 2-7/8" x 3-3/16" liner with a 3-1/2" deployment joint. ! forwarded your note to JOhn Spaulding and discussed it with both he and Chuck Scheve. The new proposed stack arrangement does not provide any ram coverage for the 2-7/8" section of your liner which comprises the majority of the string. Sealing ram coverage for the 3-3/16" and 3-112" Sections is not strictly required due to the much shorter length of these sections. They are in essence treated as "stingers". You indicated you do require 3-1/2" slip rams to hold the liner while NU the injector since the injector trolley cannot simultaneously support the hanging liner and the injector. I of 3 ' lj27101 6:21 AM HI-: Well B-2~tA EIt~I~ [.;ontlguratlon In our discussion you indicated that combi rams have been ordered to outfit a new TOT stack for 3S. Such a stack would be a significant improvement to the rig equipment and provide the necessary multiple diameter capabilities your coil and liner combinations need. You proposed that until the new stack is available, at your earliest opportunity you would install a set of 2-7/8" pipe rams above your mud cross to provide sealing ability when .. running the 2-7/8" portion of the liner. I discussed your 2-7/8" ram proposal with John. He and I are in agreement that your proposal is an acceptable interim solution. We hope the combi rams are available shortly to provide a better equipped stack. Please provide us with an update on the scheduled delivery of the new rams. Please contact either John or myself with any questions. Tom Maunder Petroleum Engineer "Kara, Danny T" wrote: > Tom, > The Nabors 3S. BOP configuration on well B.29 is different than what is on > the Permit to Drill application. As we discussed on the phone, Prudhoe well > B-29A was permitted for a 2-7/8" liner (Permit #200-209). The BOP stack in > the application included the following (top to btm): annular, blind/shears, > 2-3/8" pipe/slips, fidw cross, 2-7/8" pipes and 2-7/8" slips. We would like > to install a tapered liner of 3-1/2" FL4S x 3-3/16" TCll x 2.7/8" FL4S. A > tapered liner allows for future sidetracking options in this well. The > current BOP stack arrangement is.as follows (top to btm): annular, 3-1/2" > slips, 3-1/2" pipes, flow cross, blind/shears, 2-3/8" pipe/slips. > Attached are drawings of both BOP arrangements; the configuration that was > included in the permit to drill (B-29A BOPE Permit to Drill) and the > configuration that is currently on the rig (B-2gA Tapered Liner). > In addition to B-29A Prudhoe wells 16-05A and 16-06A will both have tapered > liners and a similar BOP arrangement. I would appreciate it if you could > make reference to this on both 16.05A and 16-06A application for permit to > drill. > Thanks for your help Tom. Please call me with questions. > <<B-29A BOPE Permit to Drill. doc>> <<B-29A BOPE Tapered Liner. doc>> 2 of 3 1[27101 6:21 AM Well B-29A BOP Configuration Dan Kara BP Coiled Tubing Drilling 564-5667 (office) 240-8047 (cell) 564-5193 (Fax) karadt@bp.com Name: B-29A BOPE Permit to Drill. doc B-2gA BOPE Permit to Drill. doc Type: Microsoft Word Document (application/msword) > Encoding: base64 > > Name: B-29A BOPE Tapered Liner. doc > B-29A BOPE Tapered Liner. doc Type: Microsoft Word Document (application/msword) > Encoding: base64 t Name: B-29A BOPE Tapered Liner. doc ~B-29A BOPE Tapered Liner. doc1 Type: Microsoft Word Document (application/msword) IEncoding: base64 3 of 3 lj27/01 6:21 AM Nabors 3S BOP Stack for Running 3-3/16" x 2-7/8" Tapered Liners Methanol Injection ~ Otis 7" WLA Quick Connect----- stufr~g Box (Pack-Off), 10,0OO psi Working Pressure 7" Ri~r Annular BOP (Hydfil),7-1116" ID 5000 psi WP Alignment Guide Flange 7-1116", 5M Ram Type Dual Gate BOPE -'"' HCR 7-1116", 5M Ram Type Dual Gate BOPE Manual Master Valve 0.458' (5.5") 2' Pump-In 3-112" Slip Rams 2-718" Pipe Rams Manual Valves Ddlling spool 7-1116", 5M by 7-1116", 5M Blind/Shears ~ 2-318" Pipe/Slip Rams Fire resistant Kelly Hose to Flange by Hammer up 114 Turn Hanger Valve on DS Hardline to Standpipe manifold 'i.~ Lower Annulus FIELD & POOL COMPANY 6P ADMINISTRATION APPR .DATE ,~ t,/7.ol WELL NAME/~. -C~_S--,~ PROGRAM: exp INIT CLASS ~_J~, ~" V (~. d.. ~,~/-1/ 1. Permit fee attached. 2. Lease numberapprol:;d;t;.~;. ~.~. '.~.~'i'~i/i './~. i" './-/~'./ 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... , , dev redril ,,' serv ~/' wellbore seg . .ann. disposal para req GEOL. AREA ~,~ UNIT# ~//~-~ ~ ON/OFF SHORE C.~,,~ N N )N 7. Sufficient acreage available' in drilling unit ............ ~ 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 II~EOLOGY II'APPR~ ! D~T 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ NNNNN ~ %~'"~'~-'~vx'-t:x~'"(~ . N N · 18. CMT will cover all known productive hodzons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. Y Y Y 23. If diverter required, does it meet regulations .......... ~ ~ t~ 24. Drilling fluid program schematic & equip list adequate ..... (~ N . -- \ ~ t-.,, . 25. BOPEs, do they meet regulation ......... ~) N 26. BOPE press rating appropriate; t~st' t;' '~.,~(~(~) I~sigl r~ N ~,1~'~ ~L.~\ w,.c~--~-.~ '"~.~.(~.~. c--~, ~. X~¢_~--~ "C~ cx.,~<."~,~\~~-, 27. Choke manifold complies w/APl RP-53 (May 84) k.Y_.J N 28. ' ' ........ ' .Work will occur w,thout operation shutdown... ........ (~ N 29. m presence of H2S gas probable ........ . ......... ~ N 30. Permit can be issued w/o hydrogen sulfide measures ..... Y~/'~") /~. - 31. Data presented on potential overpressure zones ....... ~ 32. Seismic analysis of shallow gas zones .... ......... / ~,-'"'Y N 33. seabed condition survey (if off-shore) ........... .~' ~[ r, Y 'N . 34. Contact name/phone for weekly progress reports [exp_l~tory only] Y N DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage pro. ducing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Ah~Iar COMMISSION: TEM~ ~. '1.),.,1. ~ JMH ~.z-?4,~ Comments/Instructions: O Z O --I I c:\msoffice\wordian\diana\checklist (rev. 11101//00) Well Histo.ry 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 informati°n, information, of this nature is accumulated at the end of the file under APPENDlXl No'special'effort has been made to chronologically organize this category of information. Smerrv-Sun Dril!inc Serv:ces LiS Ssan Utility SRevlszon: 3 S LisLzb SRevision: 4 Fri Jun 14 27:09:47 Reel Header Service name ............. LISTPE Dase ..................... 02/06/14 Origln ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/06/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER prudhoe Bay Unit MWD/MAD LOGS .,WELL NAME: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: 16-.05A 500292057401 BP 'Exploration (Alaska), Inc. Sperry Sun 14-JUN-02 MWD RUN 4 MWD RUN 5 MWD RUN 6 AK-MW-10071 AK-MW-10071 AK-MW-10071 S. LATZ S. LATZ S. LATZ MIKE FEKETI MIKE FEKETI MIKE FEKETI JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FELt FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MAD RUN 6 AK-MW-10071 S. LATZ MIKE FEKETI 24 i0N 1SE 1775 1100 72.00 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 13.375 2669.0 2ND STRING 9.625 9878.0 3RD STRING 7.000 9974.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE 2. ~W2 RU:{S i - 3 ARE :{ST PRESE:{TEi' AND NC FOOTAGE WAS DRi LLEi. MWE RU:{ 4 iS £iRES?iONAL ;,:iTH NATURAL GAM/V~. PROBE ii NGP' UTiLi£iNG A SCiNTiLLATiON 2. ETECTOR. 4 . MWD RUNS 5 AND 6 ARE DiRECTiONAL WiTH DUAL GAMMA RAY DGR~ UTILiZiNG GEiGER MUELLER TUBE DETECTORS AND ELECTROF~GNETiC WAVE RESISTIVITY PHASE 4 ~EWR4) . 5. GAMMA RAY (SGRD) LOGGED BEHIND CASING FROM 9965' MD, 8900' SSTVD TO 9974' MD, 8909' SSTVD. ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) DATA FROM 9984' MD, 8918' SSTVD TO 10159' MD, 9002' SSTVD WAS OBTAINED ON A MADPASS WHILE PULLING OUT OF THE HOLE AFTER DRILLING MWD RUN 6 AND IS APPENDED TO MWD RUN 5 DATA TO COMPLETE THE RESISTIVITY DATA. 7. A MADPASS WAS PERFORMED WHILE PULLING OUT OF THE HOLE AFTER DRILLING MWD RUN 6 AND IS PRESENTED AS A TAIL TO THIS LOG. 8. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC GR LOG OF 03/07/01 WITH KBE = 72.0' A.M.S.L.. THIS WELL KICKS OFF FROM 16-05 AT 9974' MD, 8909' SSTVD (TOP OF WHIPSTOCK) ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 9. MWD RUNS 4 - 6 REPRESENT WELL 16-05A WITH API # 50-029-20574-01. THIS WELL REACHED A TOTAL DEPTH OF 12320' MD, 8998' SSTVD. SROP = SMOOTHED RATE OF PENETRATION SGRD = SMOOTHED GAMMA RAY 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 $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; all. bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PB~ TO3L CODE START DEPTH RPM 99~4.5 RPi 9984.5 ROP 096- $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASUREi' DEPTH) BASELINE DEPTH 9963 5 9966 9977 9985 9990 10005 10008 10021 10023 10034 10039 10044 10057 10060 10062 10069 10071 10073 10082 10098. 10114 "'10134 10155 10159 10178 10185 10187 10195 10208 10214. 10222. 10225. 10232. 10244. 10246. 10251. 10254. 10266. 10269. 10281. 10303 10311 10322 10328 10333 10337 10356. 10408 10423 10437 10441 10448 10454 10464 10475 10492 10494 10498 10517 10529 10532 10538 GR 9965.0 9966.5 9977.5 9985.0 9990.5 10004.0 10008.5 10021.5 10023.0 10034.5 10039.5 10043.5 10055.5 10056.5 10058.5 10068.0 10069.5 10071.5 10081.0 10096.5 10113.0 10132.5 10152.5 10157.0 10175.0 10184.5 10186.0 10192.5 10205.0 10211.0 10220.0 10224.5 10230.0 10242.0 10245.0 10249.0 10252 5 10265 0 10268 5 10279 0 10300 0 10307 5 10321 0 10326 0 10331 0 10335 5 10354 0 10407 0 10422 0 10437.0 10440.5 10446.0 10451.5 10460.5 10473.0 10487.5 10490.5 10493.0 10513.0 10526.0 10529.0 10538.0 STOP DEPTH 12286 C 12286 O 12286 0 12286 0 12321 5 EQUIVALENT UNSHIFTED DEPTH 10542.~ i0~44.~ i054~.~ lO~5~.C 1056- ~ 10578 ~ 10592 ~ 10601 C 10631 t 10644.5 10655 5 10657 5 10668 0 10677 5 10685 0 10690 0 10704 0 10709 0 10716 5 10726 5 10740 0 10752 5 10760 5 10770 0 10794 0 10804 0 · 10815 0 10827 5 10833 5 10842 5 1'0854 5 10877 5 10915 0 10938.0 10943.0 10957.5 10970.0 10979.5 10984.0 10991.0 10993.0 11002.0 11019.5 11040.5 11048.0 11056.0 11060.0 11079.5 11083.5 11094.0 11104.5 11106.5 11113.0 11115.5 11126.5 11133 5 11145 0 11158 0 11161 5 11164 5 11176 0 11193 5 11199 5 11210 0 11222 0 11234 5 11251 0 11262 5 11292 0 11306 5 11341 0 11350 0 11355 0 11359 5 1054].~ !T546.~ I055~ ~ 10564 5 10575 5 10589 5 10596 5 10625 5 10644 5 10655 0 10656 5 10668 0 10677 0 10684 0 10689 0 10700 5 10708 0 10714 5 10723 0 10737 5 10750 5 10760 5 10769.5 10793.5 10803.5 10816.5 10828.5 10832.5 10842.5 10851.5 10876.5 10912.5 10936.0 10940.5 10956.0 10965.5 10976.0 10980.5 10992.0 10994.0 11000.0 11017.0 11035.5 11043.5 11051.5 11056.5 11076.5 11081.0 11091.0 11099.0 11101.5 11109.0 11112.0 11123.0 11130.0 11142.0 11155.0 11158.5 11161.0 11171.5 11189.0 11196.0 11206.0 11220 0 11234 5 11250 0 11261 5 11290 0 11304 0 11339 0 11348 0 11356.0 11360.5 11366 '~ 11368 ' i138C C !~39f C 11400 ' '1404 f 11411 0 11429.5 11432 0 11437 5 11443 5 11455 0 11463 0 11470 5 11490 5 11498 0 11503 0 11507 0 11513 0 11526.0 11538.0 11539.5 11546.0 11557.0 11559.0 11560.5 .11566.5 11572.5 11585.5 11593.5 11603.0 11605.0 11610.0 11614.0 11616.0 11630 5 11634 0 11638 0 11642 0 11647 0 11648 5 11650 5 11656.0 11661 0 11665 5 11668 0 11673 0 11676 5 11678 5 11682 0 11732 0 11741 5 11761 0 11779 0 11787 5 11803 0 11849 5 11859 5 11867 0 11877 0 11879 5 11892 0 11897 5 11903 5 11911 0 11946 5 11963 0 11994 0 12002 5 12008 5 12016 5 12027 5 12038 5 12044 0 Ii366.C !136E.0 'i352.C, 'i3E~.C '139- f 11399 C 11403 5 ii4~ ~ 11414 g 11423 5 11426 ~ !i433.C 11438 5 11451 5 11459 0 11466 0 11484 0 11490 5 11495 0 11501 5 11509 5 11520 5 11533 5 11535 5 11544.0 11555.5 11557.5 11560.0 11564.0 11568.5 11582.5 11593.5 11601.0 11603.5 11606.5 11610.0 11613.5 11628.0 11632.0 11635.5 11640.0 11645.0 11647.0 11648.5 11654.0 11658.5 11662.5 11669.5 11672 0 11674 5 11677 0 11680 0 11731 0 11743 0 11762 0 11780 5 11789 0 11803 0 11849 5 11859 0 11867 5 11878 0 11880 0 11891 0 11896 0 11902 0 11909 5 11947.5 11962.0 11994.0 12002.0 12007.5 12015.5 12026.5 12038.0 12043.5 12102 C 12111 5 12118 O 12127 5 12135 C 12141 0 12146.0 12157 C 12165 0 12176 0 12181 5 12191 5 12194 0 12197 0 12210 5 12215 5 12225 0 12234.0 12238.5 12245.0 12250.5 12253.5 12255.5 12258.5 12262.0 12321.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: 12049.5 1206C. 0 !20V8.5 12086.5 12091.0 12095.0 12098.5 12109,5 12117.0 12126.5 ' 2134 0 12141 0 12145 5 12153 5 12162 5 12172 0 12177 0 12186.0 12188.5 12192.5 12203.5 12209.0 12219.0 12228 5 12233 0 12239 5 12248 5 12252 5 12254 5 12257 5 12260 5 12320 0 BIT RUN NO MERGE TOP MERGE BASE 4 9965.0 10195.0 5 10195.5 10854.0 6 10854.5 12320.0 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 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 API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 t 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 9963.5 12321.5 ROP MWD FT/H 0.34 1779.54 GR MWD API 22.21 541.34 RPX MWD OHMM 0.67 1814.85 RPS MWD OHMM 0.96 1899.32 RPM MWD OHMM 1.27 2000 Mean 11142.5 90.1502 48.281 9.84467 10.5749 11.8074 Nsam 4717 4669 4624 4604 4604 4604 First Reading 9963 5 9987 5 9963 5 9984 5 9984 5 9984 5 Last Reading 12321.'5 12321.5 12275 12286 12286 12286 Firs- ReaJzng F£r £nz/re File .......... 9962.: Last Reaa:nc Fcr £n~ire File ........... 12321.5 4604 4604 9984.5 9984.5 12286 12286 File Trailer Service name ............. STSLIB.00! Service Sub Level Name... Version N"~nber ........... !.0.0 Date of Generasion ....... 02/06/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number..~ ........ 1.0.0 Date of Generation ....... 02/06/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10151.5 12275.0 FET 10162.5 12290.0 RPX 10162.5 12290.0 RPS 10162.5 12290.0 RPM 10162.5 12290.0 RPD 10162.5 12290.0 RAT 10199.0 12321.5 $ MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MWD 6 0 10149.0 12320.0 $ REMARKS: MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FEi b'~r HR 4 i 66 Name Service Unlt Min Max DEPT FT 10151.5 12321.5 RAT M~ Fi/H 490.99 !118.08 GR MAE, APl 18.4 161.19 RPX ~P OHM/~. 1.34 264.95 RPS b~i ~H.~M 2.13 RPM MAE OHI~M 2.51 2000 RPD ~£ OH~< 3.18 27.53 FET Y~D HR 1.67 91.24 Mean 1123~.5 869.849 47.3108 5.6893~ 8.21883 ~ =701~ 9.62074 47.3762 First Reading For Entire File .......... 10151.5 Last Reading For Entire File ........... 12321.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Nsam 4341 4246 4248 4256 4256 4256 4256 4256 First Reading !0!51.~ 10199 10151.5 10162.5 10162.5 10162.5 10162.5 10162.5 Last Reading 1232~.5 12321.5 12275 12290 '2290 12290 12290 12290 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Com~ent Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9965.0 ROP 9987.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING {TOP TO BOTTOM) VENDOB TOOL CODE TOOL TYPE STOP DEPTH 10169.0 10195.0 NGP $ NATURAL GAMMA PROBE BOREHOLE AND CASING DATA 01-MAR-01 Insite 4.05.5 1.22 Memory 10195.0 21.1 88.7 TOOL NUMBER 017 OPEN HSLE EiT SiZE ilN!: DRILLER'S CASING DEPTH iFT} : BCREH3LE CON2iTiDNS MUi TYPE: MU2 DENSITY MUE ViSCOSiTY S~ : MUD PH: MU~ CHLORIDES PPM): FLUID LOSS {C3 : RESiSTiViTY {OHNLM) AT TEMPEPATURE ,2EGF MUD AT MEASURED TEMPERATURE {MT}: MUD AT .MAX, CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ......... ............. -999 Depth Units ....................... Datum Specification Block sub-type...0 3.750 Fie Pfc 9.50 65.0 9.1 78000 6.6 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 .0 129.0 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 9965 10195 10080 461 ROP MWD040 FT/H 0.34 891.23 73.4116 417 GR MWD040 API 26.34 541.34 58.1304 409 First Reading For Entire File .......... 9965 Last Reading For Entire File ........... 10195 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 First Reading 9965 9987 9965 Last Reading 10195 10195 10169 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/14 Maximum Physical Record..65535 File Type ................ LC Previous E~le Name ....... STSLiS.~C'2 Comment Restr3 FiLE HEADE~ FILE NUMBER: 4 RAW NfWD Curves and los header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH !NCREME~Z: .5000 FILE SU~RY VENDOR T02i £DDE START DEPTH STOP DEPTH FET 9984 0 10819.0 RPD 9984 0 10819.0 RPM 9984 0 10819.0 RPX 9984 0 10819.0 RPS 9984 0 10819.0 GR 10169 5 10809.0 ROP 10195 5 10854.0 $ # LOG HEADER DATA DATE LOGGED: 02-MAR-01 'SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.5 DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory · TD DRILLER (FT): 10854.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 91.4 MAXIMUM ANGLE: 100.2 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01853RF3 EWR4 ELECTROMAG. RESIS. 4 PB01853RF3 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S): 65.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 78000 FLUID LOSS (C3): 4.4 RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .100 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .053 135.0 MUD FILTRATE AT MT: .080 70.0 MUD CAKE AT MT: .080 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacln~ ..................... ~ .lin Ma>: frames per record ............. Undefined Absent value ...................... -P99 Depth Un±rs ....................... Datum S~eczfz:aticn Block su~-~v~e...[ Name Service 3rder Units Size Nsam ReF Co~e Offset Channel DEPT FT 4 i 68 ROP MWD050 FT/H 4 i 68 GR MWD050 AP1 4 ! 68 RPX MWD05C OH~ 4 . 68 RPS MWD050 OHM~ 4 i 68 RPM ~WD050 OHMH 4 ! 68 RPD MWD05C OHM~ 4 i 68 FET MWD050 HR 4 i 68 0 ! 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 9984 10854 ROP MWD050 FT/H 2.58 1365.28 GR MWD050 API 22.42 157.43 RPX MWD050 OHM}4 0.67 1814.85 RPS MWD050 OHMM 0.96 1899.32 RPM MWD050 OHMM 1.27 2000 RPD MWD050 OHMM 2.17 1849.49 FET MWD050 HR 0.25 102.89 First Reading For Entire File .......... 9984 Last Reading For Entire File ........... 10854 File Trailer Service name ......... ' .... STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB,005 Mean 10419 107.901 38.1586 12.3668 13.6314 15.5477 13.7346 21.286 Nsam 1741 1318 1280 1671 1671 1671 1671 1671 First Reading 9984 10195.5 10169.5 9984 9984 9984 9984 9984 Last Reading 10854 10854 10809 10819 10819 10819 10819 10819 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW M~D Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMU~RY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA 6 .5000 START DEPTH 10809.5 10819 5 10819 5 10819 5 10819 5 10819 5 10854 5 STOP DEPTH 12273.5 12284.5 12284.5 12284.5 12284.5 12284.5 12320.0 DATE LOGGEE: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE S3FTWARE \:.~ ...... : DATA TYPE .ME?.ORY OR REAL-T-.ME : TE DRILLER .FT.' : TOP LOS iNTERVAL FT' : BOTTOM LOS iNTERVAL .~Fi. : BIT ROTATING SPEED HOLE INCLiNATiON .'DEG ~:i :'~ iMU~:.-.~.' "'-'~ __ ~: MAXIMUM ANSLE: 04-MAR-Ol insi:e 4.C~..f 4.3C Memory - i232~.C 78.0 95.2 TOOL STRING ,TOP TO BOTTOM/ VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GA~ RAY PB01853RF3 EWR4 ELECTROMAG. RESIS. 4 PB01853RF3 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S): 65.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 78000 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .060 MUD AT MAX CIRCULATING TERMPERATURE: .027 MUD FILTRATE AT MT: .060 MUD CAKE AT MT: .080 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 68.0 159.0 68.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP M~D060 FT/H 4 1 68 GR MWD060 API 4 1 68 RPX MWD060 OHMM 4 1 68 RPS MWD060 OHMM 4 1 68 RPM MWD060 OHMM 4 1 68 RPD MWD060 OHMM 4 1 68 FET MWD060 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unil Min Max DEPT FT 10809.5 12320 ROP MWD060 FT/H 0.87 1779.54 GR MWD060 API 22.21 146.72 Mean 11564.8 84.7867 51.1181 Nsam 3022 2932 2929 First Reading 10809.5 10854.5 10809.5 Last Reading 12320 12320 12273.5 8.80924 8.99604 9.21941 1.86941 First Readinc Ycr Enz2re File .......... 10809.5, Last Readinc For Entire File ........... 12320 File Trailer Service name ............. STSLIB.005 Service Suk Level Name... Version Number ........... i.0.0 Date of Generation ....... 02/06/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 2931 2931 2931 2931 10819.5 10819.5 12284.5 12284.5 '~84 : 12284.5 12284.5 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Nun%her ........... 1.0.0 .Date of Generation ....... 02/06/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER 'FILE NUMBER: 6 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 6 MAD PASS NUMBER: 0 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10149.0 12273.5 FET 10160.0 12288.5 RPX 10160.0 12288.5 RPS 10160.0 12288.5 RPM 10160.0 12288.5 RPD 10160.0 12288.5 RAT 10196.0 12320.0 $ LOG HEADER DATA DATE LOGGED: 04-MAR-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05..5 DOWNHOLE SOFTWARE VERSION: 4.30 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12320.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 78.0 NLAXIMUM ANGLE: 95.2 TOOL STRING ITOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMI4A RAY PB01853RF3 PB01853RF3 EWR4 $ ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 ~U~ ?YPE: T~¢ Pfc MUT ViSCCSiTY S : 65.[, M, Ui PH: 9.1 MUE CHLORIDES ,.PPM." : 78000 FLUID LOSS ('C3) : 4.0 RESiSTiViTY (OH.MM) AT TEMPERATURE (DEGFi MU? AT .U. EASURED TEMPERATURE (MTi'' .060 MUD AT !,',~,X CiRCULATiNG TE~MPE?J-.TURE: .027 MUD FiLTP~.TE AT MT: .060 MUD CAKE AT MT: .080 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 RAT MAD060 FT/H 4 1 68 GR MAD060 API 4 1 68 RPX MAD060 OHMM 4 1 68 RPS MAD060 OHMM 4 1 68 RPM MAD060 OHMM 4 1 68 RPD MAD060 OHMM 4 1 68 FET MAD060 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 68.0 159.0 68.0 70.0 Name Service Unit Min Max DEPT FT 10149 12320 RAT MAD060 FT/H 490.99 1118.08 GR MAD060 API 17.13 161.19 RPX MAD060 OHM~ 1.34 264.95 RPS MAD060 OHM~ 2.13 2000 RPM MAD060 OHMM 2.51 2000 RPD MAD060 OHM~ 3.18 27.53 FET MAD060 HR 1.67 91.24 First Reading For Entire File .......... 10149 Last Reading For Entire File ........... 12320 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Mean 11234.5 868.128 47.1826 5.70707 8.22664 9.27341 9.61949 47.3662 Nsam 4343 4249 4250 4258 4258 4258 4258 4258 First Reading 10149 10196 10149 10160 10160 10160 10160 10160 Last Reading 12320 12320 12273 5 12288 5 12288 5 12288 5 12288 5 12288 5 Tape Tra~ier Service name ............. LZSTF£ Daze ..................... C£.~O~ 14 Cr!cln ................... STS Tape Name ................ UNKNOW}; Continuation Nu~uber ...... 01 Next Tape Name ........... UNKNOWN Sc.mmen~s ................. STS LiS Wri~in~ Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/06/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Nun~ber ...... 01 Next Reel Name ........... UNKNOWN Conunents ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
