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Home My WebLink About203-1717. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU Z-100 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 203-171 50-029-23182-00-00 7163 Conductor Surface Intermediate Production Liner 6939 80 2000 7120 7061 20" 9-5/8" 7" 6839 30 - 110 29 - 2929 26 - 7146 30 - 110 29 - 2878 26 - 6922 None 3090 5410 None 5750 7240 6884 - 6971 3-1/2" 9.2# L80 24 - 6798 6665 - 6750 Structural 3-1/2" Baker Premier Packer 6676 6461 Torin Roschinger Area Operations Manager Josh Stephens Josh.Stephens@hilcorp.com 907.777.8420 PRUDHOE BAY, BOREALIS OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028262 24 - 6581 N/A N/A 238 716 3334 5247 1543 1263 1181 1100 305 320 N/A 13b. Pools active after work:BOREALIS OIL No SSSV Installed 6676, 6461 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 9:50 am, Jul 12, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.07.12 06:12:21 -08'00' Torin Roschinger (4662) DSR-7/12/23 RBDMS JSB 071323 ACTIVITY DATE SUMMARY 7/3/2023 CTU 9, 1.75" 0.156" Job Scope: Drift/Log. FCO w/PTS assist Travel to Z pad, start BOP Test ***Continue to WSR on 7/4/23*** 7/4/2023 LRS Test Unit # 1, Begin WSR, IL Well Z-100 / OL Well Z-21, Assist CTU Perf/ Clean out, Unit move, RU, PT, Flow Back, Continue to 7/5/23 WSR 7/4/2023 CTU 9, 1.75" 0.156" Job Scope: FCO w/PTS assist Finish BOP Test. MIRU LRS 1 Testers. MI CTU 9. PT Testers 3" pump lines. MU slb BHA w/ 2.73" JSN. Start flow well - Gas LIft Not on. Turn on Gas Lift monitor well as RIH. ***Job in progress*** 7/5/2023 CTU 9, 1.75" 0.156" Job Scope: FCO w/PTS assist Monitor well for stabilization as RIH. Attempt to get sufficient returns with AL but unsuccessful. POOH for slim BHA to perform fluff and stuff. L/D SLB BHA, M/U slim BHA w/JSN. RIH, bleed IA. Load well w/KCL. RIH with YJ Tools, Baker UReamer/YJ 2.75" Mill. Work down to 6950' CTMD. ***Continue WSR on 7/6/23*** 7/5/2023 LRS Test Unit # 1, Continued from 7/4/23 WSR, IL Well Z-100 / OL Well Z-21, Assist CTU Perf/ Clean out, Flow Back, Continue to 7/6/23 WSR 7/6/2023 LRS Test Unit # 1, Continued from 7/5/23 WSR, IL Well Z-100 / OL Well Z-21, Assist CTU Perf/ Clean out, Assist CTU as needed, Continue to 7/7/23 WSR 7/6/2023 T/I/O = 0/215/620 (PERFORATING) Assist Coil. Pumped 220 bbls 150* diesel into Coils down TBG FWHP=600/220/621. Left well in Coils Control. 7/6/2023 CTU 9, 1.75" 0.156" Job Scope: FCO w/PTS assist RIH with YJ Tools, Baker UReamer/YJ 2.75" Mill. Work down to 7043' CTMD. Pump BH Kill again, Cannot Mill in Perfs again. POOH to check BHA. Found mill completely packed off, L/D YJ milling BHA and make up Y/J MHA to 2.75JSN. RIH. SLB electronic counter stopped working, POOH to inspect, found parafin in counter. RBIH, tag fill at 6911, pick up to tubing tail come online with Hot oil 150 degree diesel, Jet down to PBTD. Dry tag @ 7042' CTM. ***Continue WSR on 7/7/2023*** 7/7/2023 LRS Test Unit # 1, Continued from 7/6/23 WSR, IL Well Z-100 / OL Well Z-21, Assist CTU Perf/ Clean out, Assist CTU as needed, POP Well. Continue to 7/8/23 WSR 7/7/2023 CTU 9, 1.75" 0.156" Job Scope: FCO w/PTS assist. GR/CCL Tie in Log, Add Perf. Change tools to 2.125". RIH with HES GR/CCL. Log from compression @ 7038, paint flag at 6950.5, top of log at 6500. POOH L/D HES GR/CCL memory log, download data. -14' correction. Make up HES 2.5" Millenium guns. RIH, correct depth at flag perforate interval 6941'-6971'. POOH, recover 1/2" ball L/D HES spent guns. RDMO ***Job Complete*** Daily Report of Well Operations PBU Z-100 Daily Report of Well Operations PBU Z-100 7/8/2023 LRS Test Unit # 1, Continued from 7/7/23 WSR, IL Well Z-100 / OL Well Z-21, Assist CTU Perf/ Clean out, Assist CTU as needed, POP Well and flowback. 8hr PB WT. Bring on GL @ 1.5 and Stabilize. Inc. GL to 2.2 mmscf/d, Stabilize. Continue to 7/9/23 WSR 7/9/2023 LRS Well Test Unit # 1. Cont. WSR from 7/8/23. IL Well Z-100/OL Well Z-21. Start 8 Hr PB Test @ midnight. End PB Test @ 8:00. Begin BD and RD. Unit move from Z- pad to LRS yard. End WSR on 7/9/23. ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~03 - 17- 1 Well History File Identifier Organizing (done) o Two-sided 11111111111111" III o Rescan Needed 111111111111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Color Items: D Greyscale Items: D Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: BY: ( M~ui;:¡ ) ( ( Date:~. {5' O~ D Other:: 151 v11.Q 1111111111111111111 ýVt!J Project Proofing BY: ~~ ~ Date: J-.. 1"& ()?:, . I X 30 = ?)O + Date:J,.j¡r;: Ób 151 BY: ( Mari;') Scanning Preparation q = TOTAL PAGES ~c¡ (Count does not include cover sheet) 11111. '0 151 , f ~. Production Scanning Stage 1 Page Count from Scanned File: if 0 (Count does include co~heel) Page Count Matches Number in Scanning !¡eparation: V YES BY: ç,: Maria) Dale:;;""/ j 5/'t.:b Stage 1 If NO in stage 1, page(s) discrepancies were found: 111111111111111111I NO 151 Y11LJ YES NO BY: Maria Date: 151 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 11I111111111111111I BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page. doc • • bp BP Exploration (Alaska) Inc. '~' "" Attn: Well Integriry Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~a~~~~ ~; r, ; ~~ ~s ~au~ ';~.~'ty,li'~,~v~ t.o~. . . August 14, 2009 ~~~~~~~~ Mr. Tom Maunder OCT 0 5 2009 Alaska Oil and Gas Conservation Commission p~~~ po~ ~ Gas Cons. Corr~mi~~i~a 333 West 7th Avenue Anchorape Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Z-Pad ~d3 - ~~ ~ ~ ~ l~~ Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Z- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Z-Pad 8/i 3/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al Z-01 B 2081080 50029218300200 NA 0.2 NA 3.40 7/24/2009 Z-02A 1960430 50029218140100 NA 0.4 NA 3.40 7/24/2009 Z-03 1971310 50029227870000 NA 1.3 NA 11.90 7/24/2009 Z-04A 2042300 50029219900100 NA 1.5 NA 14.50 7/24/2009 Z-05 1900780 50029220560000 NA 1 NA 8.50 7/24/2009 Z-O6 1880320 50029217980000 NA 0.1 NA 1.70 7/24l2009 Z-07A 1931100 50029220460100 NA 2 NA 17.00 7/24/2009 Z-OSA 1931280 50029217870100 NA 0.2 NA 2.55 7/24/2009 Z-09A 2081410 50029219670100 NA 0.2 NA t.70 7/24/2009 Z-10 1891160 50029219860000 NA 1.3 NA 11.10 7/24/2009 Z-11 A 2050310 50029220530100 NA 0.2 NA 1.70 7/26/2009 Z-12 1891020 50029219770000 NA 1.2 NA 8.50 7/26/2009 Z-13A 2042030 50029220690100 NA 3.6 NA 24.66 7/26/2009 Z-14B 2060990 50029218440200 NA 0.2 NA t.70 7/26/2009 Z-15 1880880 50029218490000 NA 0.2 NA 1.70 7/26/2009 Z-16 1920120 50029222450000 NA 0.3 NA 2.55 7/26/2009 Z-17 1891390 50029220010000 NA 3.7 NA 34.00 7/26/2009 Z-18 1890960 50029219710000 NA 0.2 NA 1.70 7/26/2009 Z-19A 2061050 50029222510100 NA 0.2 NA 1.70 7/26/2009 Z-20 1881000 50029218590000 NA 0.2 NA 1.70 7/26/2009 Z-21A 2001010 50029219380t00 NA 0.2 NA 1.70 7/23/2009 Z-22B 1960350 50029220370200 NA 0.5 NA 5.10 7/23/2009 Z-238 2041080 50029219500200 NA 0.3 NA 1.70 7/23/2009 Z-24 1890180 50029219170000 NA 0.3 NA 2.55 7/23/2009 Z-25 1881590 50029219020000 NA 0.2 NA 1.70 7/23/2009 Z-26A 2060790 50029219450100 NA 0.3 NA 3.40 7/23/2009 Z-27 1900310 50029220220000 NA 0.2 NA 2.55 7/25/2009 Z-28 1881270 50029218790000 NA 0.2 NA 1.70 7/25/2009 Z-29 1890650 50029219540000 NA 0.2 NA 1.70 7/25/2009 Z-30A 2032190 50029220130100 NA 02 NA 3.40 7/25/2009 Z-31 1881120 50029218710000 NA 0.3 NA 3.40 7/26/2009 Z-328L1 1970350 50029219246000 NA 0.2 NA 1.70 7/25/2009 Z-33A 1890050 50029218950100 NA 0.5 NA 3.40 8/8/2009 Z-35 1980930 50029228840000 NA 1.3 NA 11.50 7/4/2009 Z-38 1980600 50029228730000 NA 1.2 NA 11.90 7/26/2009 Z-39A 2042240 50029229950t00 NA 3.8 NA 39.90 7/25/20p9 Z-46A 2052030 50029232800100 NA 1.7 NA 13.60 7/26/2009 Z-100 2031710 50029231820000 NA 5 NA 45.90 7/23/2009 Z-101 2001620 50029229780000 NA 1 NA 10.20 7/23/2009 Z-102 2070500 50029233530000 NA 1.5 NA 15.30 7/25/2009 Z-103 2042290 50029232350000 NA 1.5 NA 10.20 7/25/2009 Z-108 2052010 50029232920000 NA 1.5 NA 11.90 7/2M2009 Z-112 2071720 50029233800000 NA surface NA UNDER EVALUATION: Z-100 (P~D #2031710) TxIA Communication Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, January 29, 2009 7:10 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Well Pad Z; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot Subject: UNDER EVALUATION: Z-100 (PTD #2031710) TxIA Communication Attachments: Z-100 TIO Plot.doc; Z-100.pdf AI I, Well Z-100 (PTD #2031710) was found to have sustained casing pressure on the IA. The TIOs were 2000/2080/830 psi on 01/27/09 and a subsequent TIFL failed on 01/28/09. ewe was initially shut-in on 01/12/09 and gas lift was used to ~ freeze protect. Since the IA was stacked out with gas lift at the beginning of the test, the GLVs were likely open initially and may not have closed properly. This would result in the failed test. The well has been reclassified as Under Evaluation and placed on a 28-day clock. The plan forward for the well is as follows: 1. WOE/PCC: POP Well 2. D: Repeat TIFL 3. WIE: Eval for gas lift work A TIO plot and wellbore schematic have been attached for reference. «Z-100 TIO Plot.doc» «Z-100.pdf» Please call with any questions or concerns. Thank you, Andrea Hughes .,~~,~~, ~, ~ ~., - Well Integrity Coordinator ~ ~~ Office: (907) 659-5102 Pager: (907) 659-5100 x1154 U29/2009 PBU Z-100 PTD 203-171 1 /29/2009 TIO Pressures a.ooo i ?.000 1,0f_~0 11/29/03 12106/08 1211 ~~'08 12f2201f~ 12!2?108 01/02409 01/10/0.3 01117!09 1i1;2a.415 f Tbg -F IA -~ OA --+ OOA -~ OOOA On • .E = 4-1116" GNV WELLHEAD = FMC ACTUATOR KB. ELEV = -~= 81' BF. ELEV -_ 64' KOf' = 1400' Max Angle = 19 @ 2373' Datum MD = 6825' Datum ND = 6600' SS SA NOTES: z-~ 70' 4-112" X 3-112" XO, ID = 2.998" 112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-j 70 9 518" CSG, 40#, L-80, ID = 8.75" -~ 2929' 2179' I-{ 3-112" HES X NIP, ID = 2.813" GAS LIFE MANDRELS Mm~mum ID = 2.813" 3-112"' HES X NIPPLE (3 T{JTAL) ST MD ND DEV TYPE VLV LATCH PORT DATE 7 2645 2609 18 CA DMY RK 0 08/01!08 6 3373 329$ 17 MMG DOME RK 16 08/01/08 5 3878 3783 18 MMG DMY RK 0 12104103 4 4571 4443 18 GA DOME RK 16 08/01/08 3 5263 5096 1$ MMG DMY RK 0 12/04/03 2 5896 5700 15 CA DOME RK 16 08J01108 1 6401 6190 12 CA SO RK 20 08/01!08 6620' (~ 3-1(2" BKR CMD SLIDING SLV, ID = 2.813" ~3-1i2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" (-~ 6797' PERFORATION SUMMARY REF LOG: TGP PERF ANGLE AT TOP PERF: 11° @ 6884' Note: Refer to Roductian DB for historical pert data SIZE SPF INTERVAL OpnlSgz DATE 2-1(2" 6 6884 - 6920 O 01/15/04 2-112" 6 6924 - 6930 O 01(15/04 PBTD 7061' 7" GSG, 26#, L-80, ID = 6.276" 7146' 6676' -i 7" X 3-1t2" BKR PREMIER PKR, ID = 2.870" 6765' 3-1/2" HES X NIP, 1D = 2.813" 6786' -~ 3-112" HES X NIP, ID = 2.813" 6798' 3-1!2" WLEG; ID = 2.992" 6796' ELMD TT LOGGED 01!15104 6778' 7" MARKER JT WI RA TAG 6920' I--(7" MARKER JT Wi RA TAG DATE REV BY COMMENTS DATE REV BY COMMENTS 12/Q8/03 PWE1Ti_P ORIGINAL COM PLETiON 01•'20104 CAO;TLH CORRECTIONS &GLV Cr0 0223104 JLJtTLP GLV C!O 08!05%08 KSBIPJC GLV C!O (08!05!08} BOREALIS WELL: Z-100 PERMIT No: 2031710 API No: 50-029-23182-00 SEG 19, T11 N, R12E, 455T NSL & 3043' WEL 8P Exploraiion (Alaska} • • •.~,_ =~_ - 4 ~Y~ }~ ,~~' ~"~` _, MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\L.aserFiche\CvrPgs_Inserts\Microfilm_Marker.doc SChh~q~l"~BP Sehlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~~ Nov ~ 2aa~ Well Job # log Description N0.4409 Company: Alaska Oil R Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 700 Anchorage, AK 99501 Field: Polaris Orion Borealis Date BL Color CD V-203L7 40012957 OH EDIT MWD/LWD ~ 01/24106 2 1 V-712 40073754 OH EDIT MWDILWDV ~ m 03/02106 2 1 Z-108 40012738 OH EDIT MWDILWD - - 02104/07 2 1 Z-100 NIA SBHP SURVEY 09175/07 1 5-273A 17855809 SBHP SURVEY 06/37/07 1 PLEASE ACKNOWLEDGE RECEIPT BV SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. - ~ ' Petrotechnical Data Center LR2-1 _ ~ - p - ~ ': 900 E Benson Blvd A -' ,' , '"'"" Anchorage AK 99508-4254 Date Delivered ~ ad ~t ~~, ~ (LlU! Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~ '-~~ os/2o1o7 • U 01/22107 Schlum~erger NO.4114 Schlumberger-DCS 2525 Gambell 51, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 6)03 - 1<}/ :rt 1t-/350 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Borealis Orion Well Job # Log Description Date BL Color CD Z-100 10672336 LDWG OH EDIT WIRELlNE 12/02105 2 1 V-122 11536192 CH EDIT usn PDC·GRI 01/01/07 1 1 5-124 11465666 USIT 11/06/06 1 V-214 11212898 U51T 11/02106 1 5-121 11366505 MEM PROD PROFILE 11/06/06 1 '- - . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508·4254 SCANNED JAN 3 0 2007 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503·28 ATTN Beth I) ZDDl . Date Oelivered -_._----~-- Received by /Ç- f& ~~k DATA SUBMITTAL COMPLIANCE REPORT 2/3/2006 Permit to Drill 2031710 Well Name/No. PRUDHOE BAY UN BORE Z-100 Operator BP EXPLORATION (ALASKA) INC sp uJ ). (;2d~ íJ ¡) ~'='ü.1 API No. 50-029-23182-00-00 MD 7163 ~ TVD 6939 ....- Completion Date 1/15/2004 Completion Status 1-01L Current Status 1-01L UIC N --- ~--------- --~---- --- --------- REQUIRED INFORMATION Mud Log No Samples No Directional Surve1- ~-_~_o - --- --- -- - -- --- -- --- --- ---- - -------~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint ~ 13455 Interval ~ Log Log Run OH/ Scale Media No Start Stop CH Received Comments 105 7095 1/9/2006 FINAL. LST/FINAL.TIF/FIN AL MWD MD PDS AND .(;;- TVD PDS Blu 105 7095 1/9/2006 MEASURED DEPTH LOG COMPOSITE FINAL ?.. y- PRINT COR GAMMA RAY $ Blu 105 7095 1/9/2006 TRUE VERTICAL DEPTH LOG COMPOSITE FINAL PRINT COR GAMMA RAY - -- --" --- ....' Log ~ 13455 Gamma Ray Log 13455 Gamma Ray ~ Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments - ADDITIONAL INFOR~N Well Cored? ~ Chips Received? -- Y / t~ ~ Daily History Received? @ GN Formation Tops Analysis Received? "---------- ------- - Comments: Date: 5Kb~~ ---- ----------------- -- "------- - ----- Compliance Reviewed By: ~ ~- ~ - L~-/' 12/28/05 RECEIVED Schlumbørgør JAN 0,..9 2006 NO. 3634 Schlumberger-DCS Company: Alaska Oil & Gás Cons Comm 2525 Gambell St, Suite 400 AlllkaOH & Gas ConS. eomrniSSiOO Attn: Helen'Wannan Anchorage, AK 99503-2838 333 West 7th Ave, Suite 100 ATTN: Beth Anchorage, AK 99501 Ancttorage Field: Borealis Aurora Well Job# Log Description Date Color BL CD Z-100 ) 40009858 OH LDWG EDIT OF MWD/LWD 12/02/03 1 Z-100 c;).)3-111 40009858 MD CDR-GR 12/02/03 1 Z-100 40009858 TVD CDR-GR 12/02/03 1 S-116 40009909 OH LDWG EDIT OF MWDILWD 12/14/03 1 S-116 40009909 MD CDR-GR 12/14/03 1 S-116 40009909 TVD CDR-GR 12/14103 1 S-120 40009967 OH LDWG EDIT OF MWDILWD 12/28/03 1 S-120 40009967 MD CDR-GR 12/28/03 1 S-120 40009967 TVD CDR-GR 12/28/03 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Schlumberger-DCS Petrotechnical Data Center LR2 2525 Gambell St, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 Anchorage, Alaska 99508 :::.~:~~~ Date Delivered: ~ " 6>, fJ 2ût)Q SC~~EÇ fEtI (, \;;' ) STATE OF ALASKA ALASKA ".... AND GAS CONSERVATION COM 1\,. )ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4557' NSL, 3043' WEL, SEC. 19, T11 N, R12E, UM Top of Productive Horizon: 276' NSL, 2030' WEL, SEC. 18, T11N, R12E, UM Total Depth: 325' NSL, 2012' WEL, SEC. 18, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 599629 y- 5959360 Zone- ASP4 TPI: x- 600626 y- 5960371 Zone- ASP4 Total Depth: x- 600643 y- 5960420 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD, GR, PWD, PEX I Sonic One Other 5. Date Comp., Susp., or Aband. 1/15/2004 6. Date Spudded 11/24/2003 7. Date T.D. Reached 12/112003 8. KB Elevation (ft): 81.5' 9. Plug Back Depth (MD+TVD) 7061 + 6839 10. Total Depth (MD+TVD) 7163 + 6939 11. Depth where SSSV set (Nipple) 2179' MD 19. Water depth, if offshore N/A MSL 1 b. Well Class: 181 Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-171 13. API Number 50- 029-23182-00-00 14. Well Name and Number: PBU Z-100 15. Field I Pool(s): Prudhoe Bay Field I Borealis Pool Ft Ft 16. Property Designation: ADL 028262 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) , ,:CA~'Nq,'1 ;:!"·.,"~14E."..,,, 20" 9-5/8" ':",tl, ~~¡~~~:' ': '1"',I~,I;~'f,!-II'1 H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SE~ING,PçP.¡tJ;!:ry1þ,~(, .'.·~roIN(3P¡:~THJ1(D'.,. :.,':;::Hoç¡kl:"'..'i' ,,":lcJRI,,"!¡!::SOrrrøM:: ,I, 1',:]i(!)Þ:,,· Bb¡¡;;r0M::.,I.:,.:,;,'StZe:!,",;!',' Surface 80' Surface 80' 42" 260 sx Arctic Set (Approx.) 29' 2929' 29' 2878' 12-1/4" 512 sx AS Lite, 290 sx Class 'G' 26' 7146' 26' 6922' 8-3/4" 208 sx Class 'G', 143 sx Class 'G' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): March 3, 2004 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-Bsl 3/3/2004 4 TEST PERIOD + 110 Flow Tubing Casing Pressure CALCULATED + Oll-Bsl Press. 65C 24-HoUR RATE 2,640 22. '....'..::","".',.":.::"',.;.':......,, : 'IWr .PER"F;r,,:!, 91.5# 40# 26# 7" 23. Perforations oRen to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-1/2" Gun Diameter, 6 spf MD TVD MD TVD 6884' - 6920' 6665' - 6700' 6924' - 6930' 6704' - 6710' I,AMqU~T;',: :1',::,.:AUtL:EP,:"I, 24.', I': ::'1 ;' ':,:t6åING'RecPRci:"I:,""'i' SIZE DEPTH SET (MD) 3-1/2", 9.2#, L-80 6798' PACKER SET (MD) 6676' :' "::: ',i,:'i');;' I ":':1 1':':"::"1:::" ,'¡',!:,:;',!,:i; :', 1'.',::111 DEPTH INTERVAL (MD) 2200' 6884' - 6930' AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls Diesel Frac'd: Placed 97,400 # of 16/20 Carbolite Behind Pipe GAs-McF 50.25 W A TER-Bsl 27.5 CHOKE SIZE GAS-Oil RATIO 55 457 Oil GRAVITY-API (CORR) GAs-McF 1,206 W A TER-Bsl 660 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of,pij, ea~f.Q{ ,.,~~ (. ~~._..,. .Q.". "'Separate sheet, if necessary). Submit.core chips; if none, state "none".r< t:. ~ C I 'V:lo .. t ' None , -/4&.fj·· . ~:.",.~,. .._,.,....r/..... ....... I~"·~ ,~ R\\JJUS BfL Form 10-407 Revised 12/2003 MAR 0 9) 1.~@\ MAR 0 5 200t; URGINAl CONTINUED ON REVERSE SIDE ~p G GEOLOGIC MARKERS ) 29. JRMA TION TESTS ---,~ 2.8. ';'1 NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 3041' Ugnu M Sands 4269' Schrader Bluff N 4518' Schrader Bluff 0 4701' Base Schrader / Top Colville 5064' HRZ 6630' Kalubik 6850' Kuparuk C 6884' Kuparuk B 6934' Kuparuk A 6938' Miluveach 7009' 2984' None 4155 4392' 4566' 4910' 6416' 6631' 6665' 6714' 6718' 6788' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble /fO~ "~ Title Technical Assistant Date 0 '6- OS ..0'-( PBU Z-1 00 203-171 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Neil Magee, 564-5119 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 21: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Legal Name: Z-100 Common Name: Z-100 Test Date 11/29/2003 Test Type LOT SF> L.eak-QffTe$tSul11h"1ÆirY Test Depth (TMD) 2,928.0 (ft) TestDepth(TVD) 2,877.0 (ft) AMW 9.60 (ppg) $ur'face·.pres$Llre L.eãk()ffpl:e$$lI"~(~flP) 532 (psi) 1 ,967 (psi) EMW 13.16 (ppg) ._~ Printed: 12/8/2003 9:02:01 AM ) BP Op~ratiQns~ummary Report ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-100 Z-100 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES . Date From ~ To Hours Task· Code NPT Phase 11/22/2003 00:00 - 04:30 4.50 RIGU P PRE 04:30 - 06:00 1.50 RIGU P PRE 06:00 - 08:30 2.50 RIGU P PRE 08:30 - 11 :30 3.00 RIGU P PRE 11 :30 - 14:00 2.50 RIGU P PRE 14:00 - 17:00 3.00 RIGU P PRE 17:00 - 18:00 1.00 RIGU P PRE 18:00 - 19:00 1.00 RIGU P PRE 19:00 - 00:00 5.00 RIGU P PRE 11/23/2003 00:00 - 05:00 5.00 RIGU P PRE 05:00 - 06:00 1.00 RIGU P PRE 06:00 - 08:30 2.50 RIGU P PRE 08:30 - 11 :30 3.00 RIGU P PRE 11 :30 - 12:00 0.50 RIGU P PRE 12:00 - 13:00 1.00 DIVRTR P SURF 13:00 - 18:30 5.50 DRILL P SURF 18:30 - 19:30 1.00 DRILL P SURF 19:30 - 20:30 1.00 DRILL P SURF 20:30 - 21 :00 0.50 DRILL P SURF 21 :00 - 00:00 3.00 DRILL P SURF 11/24/2003 00:00 - 02:00 2.00 DRILL P SURF 02:00 - 02:30 0.50 DRILL P SURF Page lor7 Start: 11/20/2003 Rig Release: 12/5/2003 Rig Number: 7ES Spud Date: 11/21/2003 End: 12/5/2003 Description of Operations Held PJSM. N I U Diverter System. Assembled Wellheads in Cellar. Measured RKB's. Hooked Up Cement Valves on Conductor, Installed Riser and Air Boot. Worked on Pits, Prepared to Take on Water. Held PJSM. Cleared Rig Floor, Installed Anadrill's Sensor on Stand Pipe. Rigged Up Rig Floor. Function Tested Mud Pumps. Finished Installing Anadrill's Sensor on Stand Pipe. Brought Subs to Rig Floor. Tested Accumulator. Filled Riser, Circulated System and Checked for Leaks. Pressured Tested Mud Lines and All Associated Lines. System Would Not Hold Pressure. Isolated Separate Areas of the System to Located Pressure Leak. Loaded Pipe Shed wi 4" DP and 5" HWDP. Held PJSM. Pressured Tested Mud Lines and All Associated Lines; System Would Not Hold Pressure. Isolated Separate Areas of the System to Located Pressure Leak. Replaced 1 - 2" Demeo Valve, Rebuilt 1 - 2" Demeo Valve and Stand Pipe Valve. Successfully Pressured Tested Mud Lines and All Associated Lines to 4,500 psi wi No Pressure Loss. Finished Loading Pipe Shed wi 4" DP and 5" HWDP. Held PJSM. Began Load Test on SCR System Using Mud Pumps Circulating Through 1 Open Jet in 8-1/2" Bit. Observed Knife Valve on Diverter wi Slight Leak. Held PJSM. Replaced Knife Valve and Function Tested, OK. Restarted Load Test on SCR System. Ran Mud Pump #1 on SCR #1, Mud Pump #2 on SCR #3 with Engine #1. Pump Rate 275 gpm, 3,000 psi Through 1 Open Jet in Bit fl 1 hour. Repeated Load Test wi Mud Pump #1 on SCR #2 and Mud Pump #2 on SCR #4 wi Engine #2 fl 1 hour. Repeated the Last Load Test wi Both Engine #1 and #2. During All of the Load Tests the Engines Ran Within Normal Operating Parameters. Tested PFC, OK. ADW HSE Advisor Audited the Rig and OK'd Nabors 7 ES for Operations. RID All Testing Equipment. Function Tested Diverter System, OK. Function Test Witnessed by AOGCC Rep Chuck Scheve. Held PJSM. PI U 34 Stands of 4" Drill Pipe and 8 Stands of 5" HWDP and Stood Back in Derrick. Serviced Top Drive. Brought Subs and Tools to Rig Floor fl BHA. Held PJSM, Pre-Spud Meeting wi Drilling Crew, Tool Pusher, Anadrill, M-I and Drilling Supervisor. M I U BHA #1: 12-1/4" HTC MX-C1 Bit, Ser# 5027114, dressed wi 1 x14, 3x18 jets - 9-5/8" Motor wi 1.5 deg Bent Housing - 2 x 10' Non Mag Pony Collars - 12.25" Near Bit Stabilize - MWD - Orienting Sub - 2 x Non Mag XO. Total BHA Length - 85.56'. Held PJSM. Drilled 12-1/4" Hole from 80' to 175'. WOB 2,000# - 10,000#, RPM 35, Motor RPM 48, No Torque, Pump Rate 425 gpm, SPP 350 psi. Displaced Hole to 8.7 ppg Spud Mud. Pump Rate 425 gpm, Printed: 12/8/2003 9:02: 11 AM ') ) BP Operatiorïs$u O1l11aryReport Page 2 of7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-100 Z-100 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 11/20/2003 Rig Release: 12/5/2003 Rig Number: 7ES Spud Date: 11/21/2003 End: 12/5/2003 pate Frorn ~ To Hours Task Code NPT Phase Descri ption of· Oþerations 11/24/2003 02:00 - 02:30 0.50 DRILL P SURF SPP 350 psi. Flow Line Plugged Off as Mud Circulated Back to Surface. Shut Down Pumps, POOH. 02:30 - 03:30 1.00 DRILL N DPRB SURF Cleaned Out Plugged Off Flow Line. Engaged Charge Pump Through Fill Up Line to Ensure Flow Line Was Clear. 03:30 - 05:30 2.00 DRILL N DPRB SURF Washed and Reamed Back to Bottom to Clean Hole. Pump Rate 250 gpm, 200 psi. RPM 50. Circulated Bottoms Up to Clean Hole. 05:30 - 07:00 1.50 DRILL P SURF Drilled 12-1/4" Hole from 175' to 264'. WOB 5,000# - 20,000#, RPM 60, Motor RPM 58, No Torque, Pump Rate 500 gpm, SPP 350 psi. 07:00 - 07:30 0.50 DRILL P SURF Circulated Bottoms Up, Pump Rate 500 gpm, SPP 350 psi. Took Survey. 07:30 - 08:00 0.50 DRILL P SURF POOH to UBHO Sub for Additional BHA Components. 08:00 - 09:30 1.50 DRILL P SURF Held PJSM. M I U Additional Drill Collars, Stabilizer and Jars. BHA #1 now consists of: 12-1/4" HTC MX-C1 Bit, Ser# 5027114, dressed wi 1 x14, 3x18 jets - 9-5/8" Motor wi 1.5 deg Bent Housing - 2 x 10' Non Mag Pony Collars - 12.25" Non Mag Stabilizer - MWD - Orienting Sub - 12.25" Non Mag Stabilizer - Non Mag Drill Collar - 2 x Non Mag XO - Non Mag Drill Collar - 8.75" Non Mag Stabilizer - Non Mag Drill Collar - XO - Hyd Jars. Total BHA Length - 224.74'. 09:30 - 10:00 0.50 DRILL P SURF RIH wi BHA #1 to 260'. 10:00 - 12:00 2.00 DRILL P SURF Drilled 12-1/4" Hole from 264' to 375'. WOB 15,000# - 25,000#, RPM 60, Motor RPM 54, Torque 2,000 ft I Ibs, Pump Rate 475 gpm, SPP 700 psi. 12:00 - 19:00 7.00 DRILL P SURF Held PJSM. Drilled 12-1/4" Hole from 375' to 920'. WOB 15,000# - 30,000#, RPM 70, Motor RPM 63, Torque Off Bottom 2,000 ft I Ibs, Torque On Bottom 5,000 ft I Ibs, Pump Rate 550 gpm, SPP Off Bottom 1,200 psi, SPP On Bottom 1,300 psi. Slid from 553' - 583' and 731' - 761' to Maintain Hole Angle Below 1 deg. 19:00 - 19:30 0.50 DRILL P SURF Changed out 5" Equipment to 4" HT40 Equipment. 19:30 - 00:00 4.50 DRILL P SURF Drilled 12-1/4" Hole from 920' to 1,296'. WOB 20,000#- 35,000#, RPM 75, Motor RPM 63, Torque Off Bottom 1,000 ft I Ibs, Torque On Bottom 4,000 ft I Ibs, Pump Rate 550 gpm, SPP Off Bottom 1,250 psi, SPP On Bottom 1,450 psi. String Weight Up 80,000#, String Weight Down 78,000#, String Weight Rotating 80,000#. ART = 12 hrs, AST = 0.80hrs. Krevs = 89 11/25/2003 00:00 - 01 :30 1.50 DRILL P SURF Drilled 12-1/4" Hole from 1,296' to 1,392'. WOB 20,000#- 35,000# RPM 75, Motor RPM 63, Torque Off Bottom 1,000 ft I Ibs - Torque On Bottom 5,000 ft I Ibs, Pump Rate 550 gpm, SPP Off Bottom 1,250 psi, On Bottom 1,450 psi. String Weight Up 80,000#, String Weight Down 78,000#, String Weight Rotating 80,000#. 01 :30 - 08:30 7.00 DRILL P SURF Drilled 12-1/4" Directional Hole by Rotating and Sliding from 1,392' to 1,870. WOB Sliding 40,000# - 45,000#, WOB Rotating 20,000# - 35,000# RPM 55, Motor RPM 63, Torque Off Bottom 2,000 ft I Ibs - On Bottom 5,000 ft I Ibs, Pump Rate Printed: 12/8/2003 9:02: 11 AM ) ') BP Operations SumrnaryReport Page30f7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-100 Z -1 00 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 11/20/2003 Rig Release: 12/5/2003 Rig Number: 7ES Spud Date: 11/21/2003 End: 12/5/2003 Date From - To Hours Task Code NPT . Phase Descri pHon of Operations 11/25/2003 01 :30 - 08:30 7.00 DRILL P SURF 550 gpm, SPP Off Bottom 1,250 psi, On Bottom 1,375 psi. String Weight Up 90,000#, String Weight Down 85,000#, String Weight Rotating 91,000#. 08:30 - 09:30 1.00 DRILL P SURF Circulate & Condition Mud &Clean Hole. 600 GPM @ 1480 psi. 09:30 - 12:00 2.50 DRILL P SURF POH to HWDP. Max pull15K to 20K from 1500' up to 900'. 12:00 - 14:00 2.00 DRILL P SURF POH wi BHA, cia Bit & RIH. 14:00 - 15:30 1.50 DRILL P SURF RIH to 1870' wi no problems. 15:30 - 00:00 8.50 DRILL P SURF Drilled 12-1/4" Directional Hole by Rotating and Sliding from 1,870' to 2,826'. WOB Sliding 40,000# - 45,000#, WOB Rotating 20,000# - 35,000# RPM 55, Motor RPM 65 to 80, Torque Off Bottom 3,500 ft I Ibs - On Bottom 5,500 ft I Ibs, Pump Rate 550 gpm, SPP Off Bottom 1,850 psi, On Bottom 2,000 psi. String Weight Up 102,000#, String Weight Down 95,000#, String Weight Rotating 100,000#. Daily ART = 7.92 Hrs. AST = 4.07 Encountered Hydrates @ 2473' for approx 40' MD & again @ 2812' for approx 50'. 11/26/2003 00:00 - 00:30 0.50 DRILL P SURF Circulate out Heavy Hydrates. 00:30 - 02:00 1.50 DRILL P SURF Drilled 12-1/4" Directional Hole by Rotating from 2826' to 2935'.- TO per Geologist. WOB Rotating 20,000# - 35,000# RPM 80, Motor RPM 65 , Torque Off Bottom 5,500 ft I Ibs - On Bottom 6,000 ft I Ibs, Pump Rate 600 gpm, SPP Off Bottom 2,000 psi, On Bottom 2,100 psi. String Weight Up 102,000#, String Weight Down 95,000#, String Weight Rotating 100,000#. 02:00 - 06:30 4.50 DRILL P SURF Circulate and condition Mud, Clean Hole & Circulate out Hydrates, Wt up to 9.4 ppg. 06:30 - 09:00 2.50 DRILL P SURF Wiper trip to 1675'. Max drag 25K. Pumped out from 1965' to 1675' due to swabbing. 09:00 - 10:00 1.00 DRILL P SURF RIH to TO @ 2935'. No Problems - No Fill. 10:00 - 12:00 2.00 DRILL P SURF Condition Mud and Circulate clean. 585 GPM @ 1775 psi & 90 RPM. 12:00 -17:00 5.00 DRILL P SURF POH, SLM. 25K Overpull @ 2440'. Wiped through & eliminated. 17:00 - 20:00 3.00 DRILL P SURF LID BHA, Clear & clean Floor. 20:00 - 22:00 2.00 CASE P SURF PJSM, RIU Casing Equipment. 22:00 - 22:30 0.50 CASE P SURF PJSM with Rig Crew, Caser, Tam hand, TP & Co. Rep. 22:30 - 00:00 1.50 CASE P SURF MIU Shoe Track, RIH & Check Floats - OK. Run 9 5/8" surface Casing as per program. 11/27/2003 00:00 - 04:00 4.00 CASE P SURF Run 70 Jts, 95/8",40#, L-80, BTC Casing, good displacement, no hole problems. 04:00 - 05:00 1.00 CASE P SURF Make up landing Jt., break circ. and precautionary wash to setting depth @ 2928'. Circulate bottoms up staging up pumps to 3.5 BPM. Reciprocate pipe 10'. Up wt = 128K, On Wt. = 110K. 05:00 - 05:30 0.50 CEMT P SURF Break out & LID Franks Fill Up Tool. MIU Cement Head. 05:30 - 07:30 2.00 CEMT P SURF Break circ and stage up pumps to 10 bpm. Circulate & Condition Mud for Cement job. Hold PJSM with cementers and rig crew while circulating. 07:30 - 08:00 0.50 CEMT P SURF Pump 5 bbl water and test lines to 3500 psi. Pump 20 bbl CW - 100 followed with 75 bbls. 10.2 ppg MUDPUSH II. 08:00 - 09:30 1.50 CEMT P SURF Drop bottom plug, mix and pump 405 bbl (525 sx) 10.7 ppg ArcticSet Lite III Lead slurry followed by 61 bbl (300 sx) 15.8 ppg Class "G" Tail slurry. Reciprocate casing, land on hanger Printed: 12/8/2003 9:02: 11 AM ') ) BP Operations Summary Report Page 4 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-100 Z-100 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 11/20/2003 Rig Release: 12/5/2003 Rig Number: 7ES Spud Date: 11/21/2003 End: 12/5/2003 Date From - To Hours Task Code NPT Phase Description of Operations 11/27/2003 08:00 - 09:30 1.50 CEMT P SURF after 200 bbllead cement around shoe. 09:30 - 10:00 0.50 CEMT SURF Drop top plug and pump 10 bbl water. Change over to the rig pumps and displace with 205 bbl mud at 6-10 bpm. Bump plug with 1500 psi. Floats held. Full returns throughout job. 10:00 - 10:30 0.50 CASE P SURF Pressure up casing to 3500 psi and hold for 30 minutes. 10:30 - 12:00 1.50 CASE P SURF Bleed pressure - Floats OK. RID Casing Equip. Back out & LID Landing Jt. 12:00 - 13:00 1.00 CEMT P SURF Wash out flow line & Blow down mud lines 13:00 - 15:00 2.00 CASE P SURF N/D Diverter System 15:00 - 16:30 1.50 WHSUR P PROD1 N/U FMC Gen 5 11" Split Uni Head & Test metal to metal seal to 1 000 psi 16:30 - 21 :00 4.50 BOPSURP PROD1 N/U 13 5/8" , 5000# BOPE 21 :00 - 00:00 3.00 BOPSURP PROD1 R/U Test Equipment & Test BOPE to 250 psi Low & 5000 psi High I 3500 psi Annular. John Crisp, AOGCC witnessing Test. 11/28/2003 00:00 - 06:00 6.00 BOPSURP PROD1 Continue testing BOPE. Repair leaking HCR valve, Weep hole in tubing head, and IBOP valve. All retesting OK. 06:00 - 10:00 4.00 BOPSUR N SFAL PROD1 Change lower well control valve and actuator on top drive. 10:00 - 11 :00 1.00 BOPSURP PROD1 Continue testing BOPE. All retested OK. 11 :00 - 11 :30 0.50 BOPSURP PROD1 RID Test Equip. Install Wear Bushing. 11 :30 - 15:30 4.00 DRILL P PROD1 P/U & Stand back in Derrick 66 Jts. of 4" DP. 15:30 - 16:00 0.50 DRILL P PROD1 Bring BHA to Floor. Change out elevators to 5". 16:00 - 19:00 3.00 DRILL P PROD1 M/U BHA #4, Orient & RIH wi HWDP. Surface Check MWD - OK. 19:00 - 22:00 3.00 DRILL P PROD1 RIH, P/U 4" DP to 2770' 22:00 - 00:00 2.00 DRILL P PROD1 Wash down to 2819' - Tagged Cement. Drill Cement Plugs & Shoe Track. Clean out Rat Hole to 2935'. Drill 20' of New Hole to 2955'. Displaced to New, 9.6 ppg., LSND Mud while drilling Shoe Track. 11/29/2003 00:00 - 00:30 0.50 DRILL P PROD1 Circulate bottoms up @ 2955'. 450 GPM @ 1400 psi. 00:30 - 01 :30 1.00 DRILL P PROD1 Perform LOT with 9.6 ppg Mud @ 2877 TVD (Shoe). Leak off Pressure = 532 psi LOT = 13.16 ppg. EMW 01 :30 - 03:30 2.00 DRILL P PROD1 Dir. Drl8 3/4" hole from 2955' to 3229'.560 GPM @ 1900 psi. Torque = 4K WOB = 10 -15K. Calc. ECD = 10.42 ppg. Actual ECD = 10.66 ppg. 03:30 - 04:30 1.00 DRILL N FLUD PROD1 Shaker Screens blanking from UGNU tar & Oil. Loosing much mud over shakers. Stopped drilling and circulated at a reduced rate while changing & cleaning screens. 04:30 - 05:00 0.50 DRILL P PROD1 Dir Drl from 3229' to 3295'. Same parameters. 05:00 - 07:30 2.50 DRILL N FLUD PROD1 Problems again with screens blanking off & loosing mud. Circ. at reduced rate & clean same. Build Mud Volume. 07:30 - 00:00 16.50 DRILL P PROD1 Dir. Drill from 3295' to 4759'.580 GPM @ 2100 psi. Torque on = 6K, off = 4.5K. WOB = 5K to 15K Up Wt = 135K, On Wt = 110K, Rot Wt = 123K Calc. ECD = 10.47 ppg. Actual ECD = 10.5 ppg Daily ART = 6.4 Hrs. AST = 6.4 Hrs. 11/30/2003 00:00 - 00:00 24.00 DRILL P PROD1 Drill 8 3/4" Directional Hole from 4759' to 6400'.580 GPM @ 3100 psi. Up Wt = 173K, On Wt = 128K, Rot. Wt. = 145K Torque on Bottom = 7500 - Off Bottom = 5000 Calc ECD = 11.07 ppg. Actual ECD = 11.3 ppg. Printed: 12/8/2003 9:02: 11 AM ) \ , BP Operations Summary Report Page 5 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-100 Z-100 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 11/20/2003 Rig Release: 12/5/2003 Rig Number: 7ES Spud Date: 11/21/2003 End: 12/5/2003 pate From ~To Hours· Task Code NPT Phase Description of Operations 11/30/2003 00:00 - 00:00 24.00 DRILL P PROD1 NOTE: Raised Mud Weight from 9.7 ppg. to 10.2 ppg., with spike fluid while drilling by 5160'. Daily ART = 6.76 AST = 6.91 12/1/2003 00:00 - 06:00 6.00 DRILL P PROD1 Directional Drill 8 3/4" Hole from 6400' to 6960'.580 GPM @ 3600 psi. Torque = 8K on Bot, 5K off. Up Wt = 182K, On Wt = 135K, Rot Wt. = 153K. RPM = 100 ECD's remain within 0.3 ppg. of calculated. 06:00 - 06:30 0.50 DRILL N SFAL PROD1 Replace valve cover packing on #1 Mud Pump. Circ wi #2 @ 300 GPM. 06:30 - 09:00 2.50 DRILL P PROD1 Directional Drill 8 3/4" Hole from 6960' to 7163'. TO as per Geologist. 580 GPM @ 3800 psi. Torque = 8K on Bot.5.5K off. Up. Wt = 185K, On Wt = 140K, Rot Wt = 158K RPM = 100 ECD @ TO = 11.1ppg. Calculated ECD = 11.24 ppg. 09:00 - 11 :00 2.00 DRILL P PROD1 Pump Sweep, Circulate Bottoms Up 2 X. Small gas bubbles breaking out in mud at riser - no flow. 11 :00 -16:30 5.50 DRILL P PROD1 Wiper Trip. Some tight hole 30K Max pull - wiped clean. At 3195' - swabbing, pump out to 2926'. 16:30 - 17:00 0.50 DRILL P PROD1 Monitor well - Blow down Top Drive. Well Static. 17:00 - 18:30 1.50 DRILL P PROD1 Cut & Slip Drilling Line. Inspect Brakes. Service Top Drive. 18:30 - 21 :30 3.00 DRILL P PROD1 RIH - @ 6894' taking 40K. Ream to 6860'. RIH to 7056'. Precautionary wash to TO of 7163'. 21 :30 - 00:00 2.50 DRILL P PROD1 Pump sweep circulate Bottoms Up 2 Times. Sharp splintered shale cuttings. Begin to weight up to 10.3 ppg. 12/2/2003 00:00 - 02:00 2.00 DRILL P PROD1 Circulate and condition mud, raising mud weight from 10.2 ppg. to 10.3 ppg. No more splintered shale. 02:00 - 04:00 2.00 DRILL P PROD1 POH, intermittent drag from 7145' to 6769'. Max 30K. Swabbing @ 6769'. Backream to above HRZ @ 6577'. Saw nothing backreaming. Run back to 7163' dry - No Problem. 04:00 - 06:00 2.00 DRILL P PROD1 Pump Sweep. C&C Mud, raising weight to 10.4 ppg. 06:00 - 10:30 4.50 DRILL P PROD1 POH, SLM. No Problems. Drag 5K To 10K, no swabbing. Monitor at Shoe 10:30 -14:00 3.50 DRILL P PROD1 Monitor well @ HWDP. POH & stand back HWDP. LID BHA. 14:00 - 21 :30 7.50 EVAL P PROD1 PJSM with SWS E-Line Crew. RlU. Log PEX I Dipole Sonic. RID SWS. 21 :30 - 00:00 2.50 CASE P COMP Pull wear bushing, set test plug. CIO top rams to 7". R/U to test door seals 12/3/2003 00:00 - 00:30 0.50 CASE P COMP Test door seals on top rams to 3500 psi. RID test equipment. 00:30 - 03:30 3.00 CASE P COMP Make Dummy Run wi landing Jt. & Hgr. Measurements OK. RIU to run 7" Production Casing. 03:30 - 04:00 0.50 CASE P COMP PJSM with Casers & Crew. 04:00 - 09:30 5.50 CASE P COMP MIU Shoe Track, pump through floats. Run & Centralize 7" Production Casing as per program to 2915'. Fill every Jt. Displacement Correct. 09:30 - 10:30 1.00 CASE P COMP Break Circulation. Stage up Pumps to 7 BPM @ 500 psi. Circulate 1 1/2 Times Bottoms Up. No Losses. 10:30 - 19:00 8.50 CASE P COMP Continue to run 7" Casing into open hole. Fill every Jt., break circulation every 10 Jts. & circulate for 15 minutes every 25 jts. (Slowed run speed to 90 seconds per joint after showing slight losses while RIH.) Run to setting depht of 7145'. 14 bbls. under calculated displacement. Total 172 Jts Ran of 7", 26#, L-80, BTC-M Casing. Shoe @ Printed: 12/8/2003 9:02: 11 AM ) ) BP Operations.·Summåry·:Réport . Page 6 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2-100 2-100 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 11/20/2003 Rig Release: 12/5/2003 Rig Number: 7ES Spud Date: 11/21/2003 End: 12/5/2003 Date From - To Hours Task Code NPT Phase . Descriþtion of Operations 12/3/2003 10:30 - 19:00 8.50 CASE P COMP 7145', FIC @ 7060'. 20' Marker Jts. wi RA Pip Tags @ 6920' & 6777'. Centralized as per program. 19:00 - 20:30 1.50 CEMT P COMP Break circulation. Stage pumps up to 7 BPM @ 900 psi. Circulate & Condition Mud. Reciprocate Casing throughout wi 210K Up Wt. & 155K On Wt. 20:30 - 21 :00 0.50 CEMT P COMP Rig down Franks Tool. Rig up Cement Head. 21 :00 - 22:00 1.00 CEMT P COMP Re-establish circulation at same parameters. Circulate & Condition Mud to Vis of 43, 16 Plastic & 12 Yield. PJSM wi Dowell, Rig crew, Mud Eng., Truck drivers & Co Rep. 22:00 - 23:30 1.50 CEMT P COMP Switch lines to Dowell & Cement as follows: Pump 5 bbls CW-1 00. Test lines to 4000 psi. Pump 15 Bbls CW-100. Pump 30 Bbls 11.0 ppg MudPush. Drop Bottom Plug. Mix & Pump 90 Bbls, 12.0 ppg, LiteCRETE Slurry wi 2.46 yield. Mix & Pump 30 Bbls, 15.8 ppg, Class G Slurry wi 1.16 yield. Clean out Doweel cement line to floor. Switch to rig pumps. Drop Top Plug. Displace cement wi 271 Bbls filtered Seawater Bump Plug wi 3000 psi. Switch back to Dowell pump & pressure casing to 4000 psi - Hold & Chart. Reciprocated casing in 10ft. strokes throughout Job. Up Wt = 190K, On Wt + 135K. Full returns through job. 23:30 - 00:00 0.50 CEMT P COMP Hold & Chart 4000 psi Casing pressure test for 30 minutes. 12/4/2003 00:00 - 00:30 0.50 CEMT P COMP Pressure lines wi Rig pump. Open valve to Dowell & bleed off pressure. Check Floats - OK. 00:30 - 02:00 1.50 CEMT P COMP RID & LID Cement Head. Flush stack & Wellhead. Back out Landing Jt. & LID. RID Casing elevators. Change Bales. 02:00 - 03:00 1.00 CASE P COMP M/U & install 7" Pack-Off. R.I.L.D.S. Test Pack-Of to 5000 psi. for 10 minutes. 03:00 - 11 :00 8.00 CASE P COMP R/U & Lay down 4" Drill Pipe & 5" HWDP. 11 :00 - 13:00 2.00 RUNCONP COMP CIO Upper Pipe Rams to 3 1/2" X 6" Variables. Test Door seals to 3500 psi. 13:00 - 14:00 1.00 RUNCONP COMP R/U to run 3.5 Completion String. PJSM with all Hands. 14:00 - 00:00 10.00 RUNCONP COMP Run 3.5" Completion string as per program to 6642'. 12/5/2003 00:00 - 00:30 0.50 RUNCONP COMP Complete running 3.5" Tubing. total 202 Jts 3.5", 9.2#, L-80 BTC-M + 1 Jt. 4.5", 12.6#, L-80 TC-II . 00:30 - 01 :30 1.00 RUNCONP COMP M/U Tubing Hanger & Landing Jt. Land String. R.I.L.D.S, 87K Up Wt., 75K On Wt. WLEG set @ 6797'. 01 :30 - 02:30 1.00 RUNCONP COMP R/U to Reverse Circulate. 02:30 - 04:00 1.50 RUNCONP COMP Test Lines to 3500 psi. Reverse circulate 60 Bbls. KCL Brine wi corrosion inhibitor. Follow wi 120 Bbls Seawater - 3 BPM @ 250 psi. 04:00 - 04:30 0.50 RUNCONP COMP Drop Ball - Rod Back out Landing Jt. Fill BOP through Kill Line & Close Blind Rams. 04:30 - 06:30 2.00 RUNCOrvP COMP Pressure tubing to 4500 psi to set Packer. Hold 4500 psi for 30 minute Printed: 12/8/2003 9:02: 11 AM ) ') BP Operåtions SlimmªryReport Page 70f 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Z-100 Z-100 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 11/20/2003 Rig Release: 12/5/2003 Rig Number: 7ES Spud Date: 11/21/2003 End: 12/5/2003 Date From- To Hours Task CodeNPT Phase Description of Operations 12/5/2003 04:30 - 06:30 2.00 RUNCOIVP COMP tubing test. Bleed tubing to 2500 psi. & pressure annulus to 3500 psi. Hold for 30 minute Packer test. Bleed Annulus to "0", then Tubing. Pressure Annulus to shear OCR Valve. Sheared @ 3200 psi. Set TWC wi dry rod. Test from below to 1000 psi. N/D BOPE. Install Adapter Flange & Tree. Test to 5000 psi. R/U DSM Lubricator, Pull TWC. R/U little Red, test lines to 3000 psi. Reverse 80 Bbls diesel down 3 1/2" X 7" Annulus. Shut in and allow to U-Tube into Tubing to Freeze Protect to 2200' MD. Set BPV wi DSM Lubricator. Test to 1000 psi. Secure Well & Release Rig. 06:30 - 07:00 0.50 WHSUR P COMP 07:00 - 11 :00 4.00 WHSUR P COMP 11 :00 - 13:00 2.00 WHSUR P COMP 13:00 - 13:30 0.50 WHSUR P COMP 13:30 - 16:30 3.00 WHSUR P COMP 16:30 - 17:00 0.50 WHSUR P COMP 17:00 - 18:00 1.00 WHSUR P COMP RIG RELEASED @ 1800 HRS. 12/05/2003 Printed: 12/8/2003 9:02: 11 AM ) ) Well: Field: API: Permit: Z-1 00 Prudhoe Bay Unit 50-029-23182-00-00 203-171 Accept: Spud: Release: Rig: 11 /22/03 11/24/03 12/05/03 Nabors 7ES POST RIG WORK 01/12/04 PULL R & B FROM 67721 SLM. PULL 1 -1/2" SHEAR VALVE FROM STA. # 4. @ 45711 MD. SET 1 - 1/2" DGLV, RK LATCH STA. # 4. BEGIN PUMPING DOWN IA FOR MITIA. 01/13/04 PULL 3 1/2" RHC FROM 67751, SLMD. DRIFT W/ 2 1/211 DMY GUN / TEL / SB. TAG TO @ 70541 MD. CORRECTION = + 101. (SAMPLE BAILER EMPTY) MITIA TO 3500 PSI. PASS. 01115/04 JEWELRY LOG, PERF INTERVALS 69301-6924" 6920'-68841, WITH 2.511 HMX 2506 PF, 6 SPF, REFERENCED TO SWS PEX 12-03-03, TTAIL LOGGED AT 67961, TAGGED BOTTOM AT 70541. 01/18/04 T/I/O=400/130/100. FRAC KUPARUK C SAND PERFS 68841-69301. PUMP DATA FRAC WITH 150 BBLS YF-125 LG FLUID SYSTEM. ISIP= 1533 PSI TC= 8.4 MIN, PC =4250 PSI, PNET =175 PSI, CT=.0038 FTrrIME^1/2. PUMP FRAC JOB WITH 1200 BBLS YF-125LG FLUID AND 225K LBS 16/20 CARBOLlTE PROPPANT AT 20 BPM. RAMP FROM 1-10 PPGA, SCREENOUT WITH 169 BBLS 8# AWAY. PLACED 107 BBLS OF 8 PPGA IN PERFS. PLACED 97.4 K# OF PROP BEHIND PIPE, LEFT 18 K# IN CSG. NO FLUSH, NO FREEZE PROTECT, TOS IF PACKED IS 34351 MD. MAX TREAT- 8100 PSI, AVG TREAT- 8100 PSI, LOAD TO RECOVER-785 BBLS. ALL TREESAVER CUPS RECOVERED. 02/16/04 FRAC CLEANOUT. RIH WITH BHA #1 (2.111 CRC, 2.011 CHECKS, 2.01lX 6911 STINGER, 2.111 JSN). SAT DOWN AT 2721 CTMD. HARD OBSTRUCTION, SUSPECT ICE. SAW SIGNS OF ICE/SLUSH TO 12001 CTMD. FOUND SAND TOP AT APPROX. 24001 CTMD. CLEANED OUT TO A TOTAL DEPTH OF 7050' CTMD. TAGGED HARD BOTTOM. FREEZE PROTECTED WELL WITH METH TO 2850' CTMD. WELL LEFT SHUT IN. JOB COMPLETE. 02/22/04 SET 3 1/2 X-CATCHER SUB @ 67491SLM. PULL DGLV FROM STATION # 1 @ 63911SLM. PULL DGLV FROM STATION # 2 @ 58851SLM. 02/23/04 PULL DGLV FROM STATION # 4 @ 45611SLM. PULL DGLV FROM STATION # 7 @ 2632 ISLM. SET LGLV(1542# ,1/4, RK) IN STATION # 7 @ 26321SLM. SET LGLV(1566# ,1/4, RK) IN STATION # 4 @ 45611SLM. SET LGLV(1575#, 1/4, RK) IN STATION # 2 @ 58851SLM. SET OGLV(22/64, RK) IN STATION # 1 @ 63911SLM. PULL 3.511 X C-SUB FROM 67491SLM. NOTIFY PAD OP TO NOT POP. 03/02/04 ASSIST ASRC TEST UNIT WITH HOT POP. PUMPED 10 BBLS NEAT MEOH, 100 BBLS OF CRUDE @ 180°,10 BBLS NEAT MEOH. 4-1/16"CIW FMC ) . TREE = WELLHEAD = ÄcrÚÄ TOR = ,,,,,.............,.............,,.............,,"""'........,...,,....,"'.......,.........,,..........,,"",,..........."''''''''~,,'' KB. ELEV = 81' ·BF~'ËLEV-;··--·~,· ·s¡;· ,....... ................. .......... ........... ........." ..,..""f KOP = 1400' Mä·xAr:ïgië;;;;··u19 @·2373ï ÔätumM6·;··ww..w·····"6825í· ""~""",,.,". . ,,,.,,. '''' ..,,,.,,~""~,.,,"''''',,,.,','''''',.. ,'"" ,'""",,",.w.,,, Datum lV D = 6600' SS 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 195/8" CSG, 40#, L-80, ID = 8.75" l-i 2929' ~ Minimum ID = 2.813" 3-1/2" HES X NIPPLE (3 TOTAL) 13-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" l-i 6797' I PERFORA TION SUMMARY REF LOG: TCP PERF ANGLEAT TOP ÆRF: 11° @ 6884' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/2" 6 6884-6920 0 01/15/04 2-1/2" 6 6924-6930 0 01/15/04 I PBTD l-i 7061' 17" CSG, 26#, L-80, ID = 6.276" l-i 7146' DA TE REV BY COMMENTS 12/08/03 PWElTLP ORIGINAL COM PLETION 01/20/04 CAO/TLH CORRECTIONS & GLV C/O 70' Z-1 00 ! J I. L I I I r:=) I SAFE: I I· NOTES: 70' 1-i4-1/2" X 3-1/2" XO, ID = 2.998" I 2179' 1-i3-1/2"HESXNIP,ID=2.813" I ~ ST MD lVD 7 2645 2609 6 3373 3298 5 3878 3783 4 4571 4443 3 5263 5096 2 5896 5700 1 6401 6190 GAS LIFT MANDRELS DEV TYÆ VLV LATCH 18 MMG DMY RK 17 MMG DMY RK 18 MMG DMY RK 18 MMG DMY RK 18 MMG DMY RK 15 MMG DMY RK 12 MMG DMY RK PORT DATE o 12/04/03 o 12/04/03 o 12/04/03 o 01/13/04 o 12/04/03 o 12/04/03 o 12/04/03 6620' l-i 3-1 /2" BKR CMD SLIDING SL V, ID = 2.813" I :g ~ 6676' I-iT' X 3-1/2" BKR PREMIER PKR, ID = 2.870" f t 6765' l-i 3-1/2" HES X NIP, ID = 2.813" I 6786' 1-i3-1/2" HES X NIP, ID = 2.813" I 6798' 1-i3-1/2" WLEG, ID = 2.992" I 6796' l-i ELMD TT LOGGED 01/15/04 -----1 6778' I-iT' MARKER JT W/ RA TAG I ----1 6920' I-iT' MARKER JT W/ RA TAG I I~ DA TE REV BY COMMENTS BOREALIS WELL: 2-100 PERMIT No: 2031710 API No: 50-029-23182-00 SEC 19, T11 N, R12E, 4551' NSL & 3043' WEL BP Exploration (Alaska) Generated 2/6/2004 9:04 AM Page 1 01 2 Z-1 OO\Z-1 OO\Z-1 00\Z-100 SurveyEditor Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rt-546 ) ) ) bp Z-100 Survey Report Schlumberger Report Date; 1·Dee-03 Survey / DLS Computation Method; Minimum Curvature / Lubinski Client; BP Exploration Alaska Vertical Section Azimuth; 44.790' Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure/Slot: Z·PAD / Z·100 TVD Relerence Datum: KB Well: Z·100 TVD Relerence Elevation: 81.50 ft relative to MSL Borehole: Z·100 Sea Bed / Ground Level Elevation: 53.00 ft relative 10 MSL UWVAPI#: 500292318200 Magnetic Declination: 25.202' Survey Name/Date: Z·100/ December 1, 2003 Total Field Strength: 57552.674 nT Tort / AHD / DDI/ ERD ratio: 69.381' / 1555.00 ft / 5.047/0.224 Magnetic Dip: 80.797' Grid Coordinate System: NAD27 Alaska Slale Planes, Zone 04, US Feel Declination Date: November 27, 2003 Location Lat/Long: N 701754.218, W 1491135.384 Magnetic Declination Model: BGGM 2003 Location Grid NIE YIX: N 5959360.050 ftUS, E 599628.850 ftUS North Reference: True North Grid Convergence Angle: +0.75961208' Total Corr Mag North -> True North: +25.202' Grid Scale Factor: 0.99991128 Local Coordinates Referenced To: Well Head Measured Inclination Azimuth TVD Sub-Sea TVD Vertical Along Hole NS EW DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Departure (It) (deg) (deg) (It) (ft) (It) (It) (It) (It) ( deg/1 00 It ) ( deg/100 ft ) ( deg/100 It ) (ftUS) (ItUS) 0.00 0.00 0.00 0.00 -81.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5959360.05 599628.85 N 70 17 54.218 W 149 11 35.384 105.26 0.15 178.78 105.26 23.76 -0.10 0.14 -0.14 0.00 0.14 0.14 0.00 5959359.91 599628.85 N 70 17 54.217 W 1491135.384 193.11 0.37 147.29 193.11 111.61 -0.24 0.53 -0.49 0.16 0.29 0.25 -35.85 5959359.56 599629.02 N 701754.214 W 1491135.379 294.44 1.06 138.58 294.43 212.93 -0.37 1.79 -1.47 0.96 0.69 0.68 -8.60 5959358.59 599629.82 N 70 17 54.204 W 149 11 35.356 304.20 0.58 158.39 304.19 222.69 -0.40 1.93 -1.58 1.03 5.64 -4.92 202.97 5959358.48 599629.90 N 70 17 54.203 W 149 11 35.354 483.13 0.98 149.79 483.10 401.60 -1.15 4.36 -3.75 2.14 0.23 0.22 -4.81 5959356.33 599631.04 N 701754.181 W 14911 35.322 575.80 0.92 144.51 575.76 494.26 -1.48 5.90 -5.04 2.97 0.11 -0.06 -5.70 5959355.05 599631.88 N 70 17 54.169 W 14911 35.298 660.39 0.90 139.50 660.34 578.84 -1.65 7.24 -6.10 3.79 0.10 -0.02 -5.92 5959354.01 599632.72 N 70 17 54.158 W 1491135.273 750.19 0.24 328.78 750.14 668.64 -1.67 7.84 -6.47 4.15 1.27 -0.73 -190.11 5959353.63 599633.09 N 70 17 54.155 W 149 11 35.263 841 .43 0.48 335.77 841 .37 759.87 -1.48 8.41 -5.96 3.90 0.27 0.26 7.66 5959354.14 599632.83 N 701754.160 W 14911 35.270 937.14 0.79 321.96 937.08 855.58 -1.26 9.47 -5.07 3.33 0.36 0.32 -14.43 5959355.02 599632.24 N 70 17 54.168 W 149 11 35.287 1033.64 0.93 319.68 1033.57 952.07 -1.11 10.92 -3.95 2.41 0.15 0.15 -2.36 5959356.13 599631.31 N 70 1754.179 W 1491135.314 1129.67 0.97 305.97 1129.58 1048.08 -1.17 12.50 -2.88 1.25 0.24 0.04 -14.28 5959357.19 599630.14 N 701754.190 W 14911 35.348 1225.20 0.91 301.61 1225.10 1143.60 -1.46 14.07 -2.01 -0.05 0.10 -0.06 -4.56 5959358.04 599628.82 N 70 1754.199 W 1491135.386 1322.31 0.80 297.12 1322.20 1240.70 -1.84 15.52 -1.30 -1.31 0.13 -0.11 -4.62 5959358.74 599627.55 N 70 17 54.206 W 149 11 35.422 1417.99 1.75 40.54 1417.86 1336.36 -0.59 17.19 0.12 -0.96 2.18 0.99 108.09 5959360.16 599627.89 N 701754.220 W 14911 35.412 1513.84 3.52 52.59 1513.61 1432.11 3.78 21.59 3.02 2.33 1.92 1.85 12.57 5959363.10 599631.14 N 70 1754.248 W 1491135.316 1609.70 4.70 53.51 1609.22 1527.72 10.58 28.46 7.14 7.83 1.23 1.23 0.96 5959367.29 599636.58 N 70 17 54.289 W 149 11 35.156 1704.63 8.02 66.51 1703.56 1622.06 20.58 38.93 12.10 17.03 3.79 3.50 13.69 5959372.37 599645.72 N 701754.337 W 149 11 34.888 1800.31 8.31 65.86 1798.27 1716.77 33.24 52.52 17.58 29.46 0.32 0.30 -0.68 5959378.02 599658.07 N 701754.391 W 149 11 34.525 1894.81 10.19 63.85 1891.54 1810.04 47.51 67.70 24.06 43.20 2.02 1.99 -2.13 5959384.68 599671.72 N 70 17 54.455 W 1491134.125 1991.36 11.51 64.27 1986.36 1904.86 64.66 85.88 32.01 59.54 1.37 1.37 0.44 5959392.84 599687.96 N 70 1754.533 W 149 11 33.648 2086.58 13.72 58.17 2079.28 1997.78 84.61 106.65 42.09 77.70 2.71 2.32 -6.41 5959403.16 599705.98 N 701754.632 W 1491133.119 2183.00 17.71 57.99 2172.07 2090.57 110.02 132.76 55.90 99.86 4.14 4.14 -0.19 5959417.26 599727.95 N 701754.768 W 149 11 32.473 2278.10 17.77 58.58 2262.65 2181.15 138.20 161.74 71.13 124.51 0.20 0.06 0.62 5959432.82 599752.39 N 70 17 54.918 W 1491131.755 2373.36 19.13 58.29 2353.01 2271.51 167.49 191.89 86.91 150.19 1.43 1.43 -0.30 5959448.94 599777.86 N 70 1755.073 W 149 11 31.006 2469.15 18.75 57.19 2443.62 2362.12 197.79 222.98 103.51 176.48 0.54 -0.40 -1.15 5959465.88 599803.93 N 70 17 55.236 W 149 11 30.239 2565.73 18.63 57.17 2535.11 2453.61 228.02 253.93 120.28 202.49 0.12 -0.12 -0.02 5959482.99 599829.71 N 701755.401 W 1491129.481 2660.45 19.46 59.08 2624.64 2543.14 258.09 284.83 136.59 228.74 1.10 0.88 2.02 5959499.65 599855.74 N 70 1755.562 W 1491128.716 2757.20 19.34 58.37 2715.90 2634.40 289.28 316.97 153.27 256.21 0.27 -0.12 -0.73 5959516.69 599882.98 N 701755.726 W 1491127.915 2820.40 19.49 58.57 2775.50 2694.00 309.69 337.98 164.26 274.11 0.26 0.24 0.32 5959527.91 599900.74 N 70 1755.834 W 1491127.393 2865.43 19.63 57.90 2817.94 2736.44 324.35 353.05 172.20 286.93 0.59 0.31 -1.49 5959536.02 599913.45 N 701755.912 W 1491127.020 2946.56 19.01 57.98 2894.50 2813.00 350.49 379.89 186.44 309.68 0.76 -0.76 0.10 5959550.57 599936.00 N 70 1756.052 W 149 11 26.356 3042.68 18.87 58.25 2985.41 2903.91 380.85 411.09 202.92 336.17 0.17 -0.15 0.28 5959567.39 599962.27 N 70 1756.214 W 149 11 25.584 3138.29 18.63 57.99 3075.95 2994.45 410.75 441.83 219.16 362.27 0.27 -0.25 -0.27 5959583.97 599988.15 N 70 1756.374 W 14911 24.823 3234.23 17.95 59.29 3167.04 3085.54 439.99 471.93 234.83 387.97 0.83 -0.71 1.36 5959599.98 600013.64 N 70 1756.528 W 1491124.074 3329.96 17.29 59.61 3258.28 3176.78 468.02 500.91 249.56 412.93 0.70 -0.69 0.33 5959615.04 600038.39 N 70 1756.673 W 149 11 23.347 3425.84 16.93 60.04 3349.92 3268.42 495.26 529.12 263.74 437.31 0.40 -0.38 0.45 5959629.54 600062.59 N 701756.812 W 149 11 22.636 3521.90 17.00 60.15 3441.80 3360.30 522.30 557.15 277.71 461.61 0.08 0.Q7 0.11 5959643.83 600086.70 N 701756.949 W 14911 21.927 3617.06 16.86 59.92 3532.83 3451.33 549.04 584.86 291.55 485.62 0.16 -0.15 -0.24 5959657.99 600110.51 N 70 1757.086 W 149 11 21.227 3712.95 16.86 59.82 3624.60 3543.10 575.89 612.67 305.51 509.67 0.03 0.00 -0.10 5959672.27 600134.38 N 701757.223 W 149 11 20.526 3808.10 18.23 59.54 3715.32 3633.82 603.61 641.35 320.00 534.43 1.44 1.44 -0.29 5959687.07 600158.94 N70 1757.365 W 1491119.804 3902.53 17.92 59.87 3805.09 3723.59 631.92 670.65 334.78 559.72 0.35 -0.33 0.35 5959702.19 600184.04 N 70 1757.511 W 1491119.067 3998.92 17.61 59.73 3896.88 3815.38 660.33 700.06 349.57 585.14 0.32 -0.32 -0.15 5959717.31 600209.25 N 70 1757.656 W 149 11 18.326 4094.10 17 .49 59.80 3987.63 3906.13 688.05 728.76 364.02 609.94 0.13 -0.13 0.Q7 5959732.09 600233.85 N 701757.798 W 149 11 17.603 4190.78 17.22 60.50 4079.91 3998.41 715.86 757.60 378.38 634.95 0.35 -0.28 0.72 5959746.78 600258.67 N 701757.939 W 149 11 16.874 4284.16 17.27 60.85 4169.10 4087.60 742.49 785.28 391.93 659.09 0.12 0.05 0.37 5959760.65 600282.62 N701758.073 W1491116.170 4379.81 17.26 59.60 4260.44 4178.94 769.85 813.67 406.03 683.73 0.39 -0.01 -1.31 5959775.07 600307.07 N 701758.211 W 149 11 15.452 4476.51 17.57 54.83 4352.71 4271.21 798.09 842.60 421.70 708.03 1.51 0.32 -4.93 5959791.06 600331.16 N 70 17 58.365 W 149 11 14.743 4572.42 18.63 50.33 4443.88 4362.38 827.60 872.38 439.82 731.66 1.83 1.11 -4.69 5959809.49 600354.55 N 701758.544 W 149 11 14.054 Generated 2/6/2004 9:04 AM Page 2 01 2 Z-1 00\Z-1 00\Z-1 00\Z-1 00 SurveyEditor Ver 3.1 RT-SP3.03-HF2.03 Bld( d031 rt-546 ) ) ') Measured Inclination Azimuth TVD Sub-Sea TVD Vertical Along Hole NS EW DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Departure (II) (deg) (deg) (II) (It) (II) (It) (It) (II) (deg/l00 II) (deg/100 It) (deg/100 It) (1IUS) (IIUS) 4669.10 19.08 43.40 4535.38 4453.88 858.77 903.59 461.16 754.41 2.36 0.47 -7.17 5959831.13 600377.01 N701758.753 W1491113.391 4766.35 18.58 36.53 4627.44 4545.94 890.00 934.94 485.16 774.55 2.34 -0.51 -7.06 5959855.39 600396.83 N 701758.989 W 149 11 12.804 4861.75 18.38 28.48 4717.93 4636.43 919.48 965.14 510.60 790.77 2.68 -0.21 -8.44 5959881.04 600412.71 N 70 1759.240 W 149 11 12.331 4957.29 18.48 21.28 4808.58 4727.08 947.82 995.31 537.95 803.45 2.38 0.10 -7.54 5959908.56 600425.03 N 701759.509 W 149 11 11.961 5052.75 18.69 15.28 4899.07 4817.57 975.01 1025.71 566.81 812.98 2.01 0.22 -6.29 5959937.53 600434.17 N 701759.792 W 149 11 11.684 5148.63 18.66 15.40 4989.90 4908.40 1001.74 1056.41 596.4 1 821.10 0.05 -0.03 0.13 5959967.24 600441 .89 N70180.084 W1491111.447 5243.91 18.85 15.19 5080.13 4998.63 1028.41 1087.04 625.96 829.18 0.21 0.20 -0.22 5959996.89 600449.58 N70180.374 W1491111.211 5338.99 18.82 14.36 5170.11 5088.61 1054.98 1117.74 655.64 837.01 0.28 -0.03 -0.87 5960026.67 600457.02 N70180.666 W1491110.983 5434.76 18.90 14.60 5260.74 5179.24 1081.71 1148.69 685.62 844.75 0.12 0.08 0.25 5960056.74 600464.36 N70180.961 W1491110.757 5528.75 18.20 24.64 5349.87 5268.37 1108.66 1178.53 713.70 854.71 3.47 -0.74 10.68 5960084.95 600473.94 N 70181.237 W 149 11 10.466 5625.29 17.47 29.74 5441.78 5360.28 1136.81 1208.08 739.99 868.18 1.79 -0.76 5.28 5960111.41 600487.07 N70181.496 W1491110.074 5721.03 16.00 31.76 5533.46 5451.96 1163.54 1235.64 763.68 882.26 1.65 -1.54 2.11 5960135.29 600500.83 N 70 18 1.729 W 149 11 9.663 5816.08 15.59 31.82 5624.92 5543.42 1188.75 1261.51 785.67 895.89 0.43 -0.43 0.06 5960157.46 600514.16 N 70181.945 W 149 11 9.266 5911.80 15.29 31.08 5717.19 5635.69 1213.55 1287.00 807.41 909.18 0.37 -0.31 -0.77 5960179.37 600527.17 N 70 182.159 W 149 11 8.878 6007.29 15.12 32.08 5809.33 5727.83 1237.93 1312.04 828.75 922.30 0.33 -0.18 1.05 5960200.88 600540.00 N 70182.368 W 149 11 8.496 6101.95 14.90 32.34 5900.76 5819.26 1261.85 1336.56 849.49 935.36 0.24 -0.23 0.27 5960221.79 600552.79 N 70182.572 W 14911 8.114 6198.66 14.11 32.45 5994.39 5912.89 1285.51 1360.78 869.94 948.34 0.82 -0.82 0.11 5960242.41 600565.49 N 70182.774 W 14911 7.736 6294.87 12.11 32.51 6088.09 6006.59 1306.83 1382.60 888.35 960.06 2.08 -2.08 0.06 5960260.97 600576.96 N 70 182.955 W 149 11 7.394 6391 .43 11.34 30.34 6182.63 6101.13 1325.92 1402.22 905.09 970.30 0.92 -0.80 -2.25 5960277.84 600586.98 N 70 18 3.119 W 149 11 7.096 6487.58 13.22 23.66 6276.58 6195.08 1345.33 1422.65 923.32 979.49 2.45 1.96 -6.95 5960296.19 600595.92 N 70 183.298 W 149 11 6.828 6582.99 11.51 23.10 6369.78 6288.28 1364.35 1443.08 942.07 987.60 1.80 -1.79 -0.59 5960315.04 600603.78 N 70183.483 W 149 11 6.591 6679.41 10.65 22.34 6464.40 6382.90 1381.53 1461.61 959.16 994.76 0.90 -0.89 -0.79 5960332.22 600610.72 N 70183.651 W 14911 6.382 6774.68 12.26 20.44 6557.77 6476.27 1398.88 1480.52 976.78 1001.64 1.74 1.69 -1.99 5960349.93 600617.36 N 70183.824 W 14911 6.182 6870.24 11.31 19.38 6651.31 6569.81 1416.59 1500.04 995.13 1008.29 1.02 -0.99 -1.11 5960368.37 600623.77 N 70 184.005 W 14911 5.988 6965.69 10.97 19.78 6744.97 6663.47 1433.27 1518.48 1012.50 1014.47 0.37 -0.36 0.42 5960385.82 600629.72 N 70 18 4.176 W 149 11 5.808 7061.00 10.36 21.20 6838.63 6757.13 1449.35 1536.12 1029.03 1020.64 0.70 -0.64 1.49 5960402.42 600635.67 N 70184.338 W 149 11 5.628 7163.00 10.97 19.78 6938.87 6857.37 1466.55 1555.00 1046.71 1027.24 0.65 0.60 -1.39 5960420.19 600642.03 N 70184.512 W 149 11 5.435 LeQal Description: NorthinQ (V) rftUSl EastinQ (X) rftUSl Surlace: 4557 FSL 3044 FEL S 19 T11 N R 12E UM 5959360.05 599628.85 BHL: 324 FSL 2013 FEL S18 T11 N R12E UM 5960420.19 600642.03 C~) CQ) ) I.~ Tr"." [".t rm [þ ~ ~_ ® ~ ! «fÆ !f\.¡ L -' ~.J J0J t.-=J f..n\; C..- ~ L ) AI~ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSK/, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudheo Bay Unit PBU Z-100 BP Exploration (Alaska), Inc. Permit No: 203-171 Surface Location: 4557' NSL, 3043'WEL, Sec. 19, TIIN, RI2E, UM Bottomhole Location: 367' NSL, 1958' WEL, Sec. 18, TIIN, RI2E, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~-~~~ Randy RutIrich Commissioner BY ORDER OF THE COMMISSION DATED this-9- day of October, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ~6A ¡{)IO 11(~V'3 '" '\ STATE OF ALASKA ALASKA 0, ..~"AND GAS CONSERVATION COMI""ÀSION PERMIT TO DRILL 20 MC 25.005 III Drill 0 Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4557' NSL, 3043' WEL, SEC. 19, T11N, R12E, UM Top of Productive Horizon: 304' NSL, 20051 WEL, SEC. 18, T11N, R12E, UM Total Depth: 367' NSL, 1958' WEL, SEC. 18, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-599629 y-5959360 Zone-ASP4 16. Deviated Wells: Kickoff Depth 18:' Câ$ing,¡Prbgråm:l;i,: ' '<"·.',;,I:,.I;,:,Size.,,···.,.,·,:,,I,,;,, Hole Casing 42" 20" 12-1/4" 9-518" 8-3/4" 7" 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: 1m Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 7155 TVD 6914 7. Property Designation: ADL 028262 III Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU Z-100 12. Field I Pool(s): Prudhoe Bay Field I Borealis Pool 8. Land Use Permit: 13. Approximate Spud Date: 11/01/03 / 14. Distance to Nearest Property: 8200' 9. Acres in Property: 2560 1400 ft Maximum Hole Angle 17° 10. KB Elevation Plan RKB 15. Distance to Nearest Well Within Pool (Height above GL): = 82.3 feet Z-14 is 450' away at 6575' TVDss 17. Anticipated pressure (see 20 AAC 25.035) ,/' Max. Downhole Pressure: 3440 psig. Max. Surface Pressure: 2777 psig ,,:,:,;:;",',I,::!(:I·~~tti¡!gll:P!~p~h 'II '1',,',,'1',::,,',1 \;;'1::'", I:¡",."'), ',;:;: 1¡IQu~p{ity,of :eement,' :::':'::1:':':";:';:::" :::',:'\' ':'føp,~." ,::,:,:~:::¡,:::,':::t~, ~,I!';:,',::,I;~:'I'!'::':,;,::'..),i; :':'is:óttåm::i,'i:L'!,/,;;,''I:':'! :":'i ":':::·;·,"I,::'i: ":'i.::, ';:, I;I,';,::!. ;.: :":~:' :::,';,:~ ':.:~' (.c,~f~,: ',Of,,'så:c'k's)i.:: 111:':":"":'" MD TVD MD TVD (including stage data) Surface Surface 110' 110' 260 sx Arctic Set (Approx.) Surface Surface 3031' 2976' 510 sx AS Lite, 290 sx Class 'G' /' Surface Surface 7154' 6915' 230 sx Class 'G', 135 sx Class 'GI / Weight 91.5# 40# 26# Grade H-40 L-80 L-80 Coupling Length Weld 80' BTC 3031' BTC-M 7154' 1:9... . .1· . '. PßESEN~,W!EI:.'~:eQNQ,J:T,I'ØN,$'~M~AR¥.i(~()ibel;tQ~Pletaøi 'fQ~~ØgfiU"À~Þ'Re:-~QirY Op~ra~iØns)·· Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): I Effective Depth TVD (ft): Junk (measured): Ca$ing L.ength Size' Cement Volume MD TVD Structural Conductor Surface Interm.edi~te Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments 181 Filing Fee 0 BOP Sketch 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Property Plat 0 Diverter Sketch 0 Seabed Report 181 Drilling Fluid Program 181.20 MC 25.050 Requirements Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Lowell; rane Title Senior Drilling Engineer . ~ C'--c..--<I~ / Contact Neil Magee, 564-5119 Signature Date 10- 9- 03 Prepared By Name/Number: Terrie Hubble, 564-4628 Phone 564-4089 Commission Use Only Permit To Drill API Number: Permit Approval See cover letter for Number: .2.ð3 - /7/ 50- 0.2-9 - .2 .3 J ~ 2- Date: I V IIJ /oJ otherrequirements Conditions of Approval: Samples Required D Yes ~ No Mud Log Required' K I::. rt~\ ~Ð Hydrogen Sulfide Measures D Yes ~ No Directional Survey Required '1tŸes Y"èr"f\Jo Other: it's.-\- Be PE ~ $OC)ú r~¿ < OCT 1 0 2003 Approved BV: ~ ~ COMMISSIONER Form 10-401 Revised 3/2003 0 RIG I ~\ I ^ I jt\laska Oil & Gas Cons. Commission BY ORDER OF Anchorage THE COMMISSION Date / r13(Ð ~ Suomit In Duplicate ) ) IWell Name: Z-100 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Producer x = 599,628.85' Y = 5,959,360.05' 45571 FSL, 30431 FEL, Sec. 19, T11 N, R12E /" X = 600,650.00' Y = 5,960,400.00' 3041 FSL, 20051 FEL, Sec. 18, T11 N, R12E / X = 600,695.06' Y = 5,960,463.10' 3671 FSL, 19581 FEL, Sec. 18,T11N,R12E /' Top of productive interval in Z-1 00 (6575' TVDss) is 450 ft away from Z-14 the nearest wellbore. The well aproaches to within 8200' ft of the nearest Prudhoe Bay property line. Surface Location: As-Built (Slot S-G) Target Location: Kuparuk Bottom Hole Location: I AFE Number: 1 BRD5M4141 I I Estimated Start Date: 111/1/2003 I I MD: 17155' I TVD: 16914' I I Ria: 1 Nabors 7ES / I Operatina days to complete: 110.6 I RT/GL: 128.5' I I RKB: 182.3' I Well Desian (conventional, slim hole, etc.): 1 Ultra Slimhole Producer I Objective: 1 Single zone producer in the Kuparuk formation. CasinglTubing Program: Hole Csgl Wt/Ft Grade Size Tba O.D. / 42" Insulated 20" 91.5# H-40 12 1,4" 9 5/8" 40# L-80 8 %" 1'1 26# L -80 Tubing 3 Y2" 9.2# L-80 * 9-5/8" Burst 5,750 psi, collapse 3,090 psi ** 7" Burst 7,240 psi, collapse 5,410 psi Z-100 Drilling Program- AOGCC cor WLD BTC BTC-m IBT-M Length Top MDrrVD GL GL GL GL Btm MDrrVD bkb 110/110 3031/2976' 7154'/6915' 6816'/6591 ' 80' 3031' 7154' 6816' Page 1 ) ) Mud Program: 12 "'A" Surface Hole (0-3031 '): Densitv (ppg) 8.5 - 9.2 /~~~I. ;.Q~ 9.5 ~llax Initial Base PF to top SV SV toTD Viscosity (seconds) 250-300 200-200 150-200 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/100ft£) (mls/30min) 45 - 70 NC 35 - 45 < 8 25 - 35 < 8 9.0- 9.5 9.0- 9.5 9.0- 9.5 8 314" Production Hole (3031' - 7155'): Interval Density YP PV (ppg) 9.7 "".,.~...) &1 pH LSND API Filtrate 6-8 Upper Interval Top of HRZ to TD 25-30 1 0-1 5 9.0-9.5 22-28 1 0-15 9.0-9.5 4-5.5 Hydraulics: Surface Hole: 12~114" interval Pump Drill AV Pump PSI ECD Motor Jet Noz.?;I~.s TFA ') GPM Pipe (fpm) ppg-emw ("/32) (in"-) 0-1889' 600 4" 15.7# 90 1800 10.0 N/A 18,18,18,16 .942 1889' -3031 ' 680 4" 15.7# 110 3200 10.2 N/A 18,1818,16 .942 Production Hole: 8 3/4" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (ín2) 3031 - 7155' 580 4" 15.7# 240 3800 11.5 N/A 3x14,3x15 .969 Directional: Ver. Anadrill(P4)(Slot 3) KOP: 1400' Maximum Hole Angle: Close Approach Wells: 17 deg at 2,035' MD All wells pass 1/200 minor risk criteria. Z-101 - 24' @ 650' /' Z-26 - 64' @1490' Gyro surveys required for kick-off due to proximity of Z-1 01. IFR-MS corrected surveys will be used for survey validation. Z-100 Drilling Program- AOGCC Page 2 Logging Program: Surface Production Hole ) Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: Formation Tops SV6 SV5 Base Permafrost SV4 SV3 SV2 SV1 Fault No.1 UG4A UG3 UG1 Ma WS2 Na WS1 Oa Obf Base CM2 (Colville) CM1 THRZ BHRZ (Kalubik) K-1 TKUP Kuparuk C LCU (Kuparuk B) Kuparuk A Miluveach TD Criteria Formation Markers: TVDss 1030 1690 1805 1810 2290 2485 2795 2800 2975 3290 3830 4055 4290 4470 4810 5065 5765 6295 6510 6560 6575 6575 6625 6635 6690 Integrity Testing: Test Point Depth Surface Casing Shoe 20' min from surface shoe Z-100 Drilling Program- AOGCC ) MWD/GR None None MW DIG R/PWD PEX- Triple Combo. (Dipole sonic in expert mode across Kuparuk.) Estimated pore pressure, PPG Not hydrocarbon bearing Hydrocarbon bearing, 8.6 ppg EMW Hydrocarbon bearing, 8.5 ppg EMW Hydrocarbon bearing, 8.5 ppg EMW Not hydrocarbon bearing ~.1 \ O. "1.- Hydrocarbon Bearing, 3423 psi, 9.9 ppg EMW Hydrocarbon Bearing, 3438 psi 9.9 ppg EMW Hydrocarbon Bearing, 3440 psi 9.9 ppg EMW 150' MD below top of Miluveach Test Type LOT EMW 11.8 ppg EMW Target Page 3 ) ) Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casinq Size 19-5/8" Surface I Basis: Lead: Based on conductor set at 110', 1789' of annulus in the permafrost @ 2500/0 excess and 392' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOG: To surface Tail: Based on 750' MD(>500'TVD) open hole volume + 30% excess + 80' shoe track volume. Tail TOG: At ....2281' MD .._-··-ì Total Cement Volume: Lead 405 bbl / 2272~fe..I-ê~.~) sks of Dowell ARTICSET Lite at 10.7 ppg and .4~?sk. Tail 60 bbl / 3~§.Jt, t'9Dkksof Dowell Premium 'G' at 15.8 ppg and6~(>éf/ŠI<: The 7" production casing will be cemented as follows: Casinq Size 17" Production Longstring I Basis: Tail: Based on TOC 500' above top of Kuparuk formation + 30% excess + 80' shoe Cement Placement: From shoe to 6,384' MD Lead: Based on TOC 500' above top of Schrader Ma +30% excess volume Cement Placement: From 6,384' MD to 4183' MD (500' above Schrader Ma sand) Total Cement Volume: Lead 74 bbls / 4}5-f¡e /á~ks of Dowell Premium "G" at 13.5 ppg and (.8p!cf/SR........--, Tail 2~"~.~ls / 157 fe t!~ks of Dowell G at 15.8 ppg and 1f.1 t;)ef/sk L(·/' Well Control: Surface hole will be drilled with a diverter. The intermediate/production hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test of 4000 psi for casing integrity considerations, the BOP equipment will be tested to 5000 psi. ../ Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 3440 psi @ 6635' TVDss - Kuparuk A 2777 psi @ surface / (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 5000 psi (The casing will be tested to 4000) / 8.4 ppg filtered brine / 6.8 ppg diesel Z-100 Drilling Program- AOGCC Page 4 ) ) Disposal: · No annular disposal in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. Z-100 Drilling Program- AOGCC Page 5 ) ) DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor was installed in November 2000. (Slot 3) 1. Weld an FMC landing ring for the FMC Ultra slim hole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 7ES. /. /' 2. Nipple up diverter spool and riser. PU 4" DP as required and stand back in derrick. 3. MU 12 "j4" drilling assembly with MWD/LWD (page 5) and directionally drill surface hole to approximately 100' TVD below the SV1 Sands. An intermediate wiper/bit trip to surface for a bit will be performed prior to exiting the Permafrost. 4. Run and cement the 9-5/8", 40# surface casing back to surface. A Tam port collar will be run as a /' contingency if surface drilling is problematic. 5. NO riser spool and NU casing / tubing head. NU BOPE and test to 5000 psi. -- 6. MU 8-3/4" drilling assembly with MWD/LWD (page 5) and RIH to float collar. Test the 9-5/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.5 ppg drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 8. Drill to +/-100' above the HRZ, ensure mud is in condition to 10.2 ppg and perform short trip as needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 9. Drill ahead to intermediate TO at approximately 150' MD' below top Miluveach in order to log entire Kup interval. (TO estimated at 7154' MD). 10. Run and cement the 7" production casing. Test casing to 3500 psi. 11. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on the Morning Report. 12. Run a 3-1/2", 9.2#, Butt, L-80 comple;!9n assembly. Set packer and test the tubing to 4500 psi and /' annulus to 4000 psi for 30 minutes. 13. Shear DCK valve and install TWC. 14. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. /' 15. RU hot oil truck and freeze protect well by pumping diesel to DCR shear GLM. Allow to equalize. 16. Rig down and move off. /. ".--. ....--' Z-100 Drilling Program- AOGCC Page 6 ) ) Z-100 Drilling Program Outline Job 1: MIRU Hazards and Contingencies ~ V-Pad is not designated as an H2S site. None of the current producers on V-Pad have indicated the presence of H2S. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. ~ The cellar area surrounding Z-100 (Slot 3) should be checked to insure level prior to move in. ~ Check the landing ring height on V-114. The BOP nipple up may need review for space out. Reference RPs .:. "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" ';,;;,.,.!,,~~~m¡;fflt!.~ , ;m"l~,'i1mWffl~;,:;,~ Job 2: Drillina Surface Hole ~ There are two close approach issues in the surface hole. Z-101 approaches with a center to center distance of 24' at 650' and Z-26 approaches within 64' at 1490'. ~ Hydrates have been observed in wells drilled on Z-Pad. These were encountered near the base of permafrost to the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to MI mud recommendation. ~ There is a sizeable fault at 2800' TVD immediately below the top of theSV-1 sand. This fault has a 75' throw. There may be losses associated with this fault. This fault will be covered by surface casing during the drilling of the production hole section. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations (during gyro use) '-:- -:-:~_»'.,::__I:._I_:_:_I:_,~tt_:;~::;.-"¡_"''':·, n~"'-_-'-"i"",~H1(::!~!::II:- ~:_ Job 3: Install Surface Casina Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 250% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be available as a contingency if surface hole drilling is problematic. If used the port collar will be positioned at ±1 OOO'MD to allow remedial cementing. ~ "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2. Cement - Top of tail >500' TVD above shoe using 30% excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. Z-100 Drilling Program- AOGCC Page 7 ) ) Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" :;¡__~:<Oillll-· IC::_lal:nl~·:::·~1-'M,_""""W.¥'U"'·'-...._~_y'-~;"~"'.~·.~"":".,.¡....~;:,m«.)U1lm,:aa_~'.:,<'v...'n~ ~N~...--_.C:I::::- -lalra1J:>\YI~:alll:a:llr1:~lala:lm:CI»>-,~~<+;...}K",·.CliC:·IC, lIe II Job 7: DrHlinQ Production Hole Hazards and Contingencies » Z-100 is expected to cross two faults in the intermediate hole section. The approximate location of the first fault is 4400'TVD ss (+/- 200') and has an estimated throw of 50'. Lost circulation is considered a minimum risk. The second fault is at 5800'TVD ss (+/- 150') in the Colville and has an estimated throw of 50'. Lost circulation is considered a risk however significant losses have been encountered due to "breathing" in previous wellbores which encountered faults in the Colville. If losses/breathing is encountered, consult the Lost Circulation Decision Tree regarding LCM treatments and procedures and adjust drilling practices to reduce breathing phenomena. ~ KICK TOLERANCE: In the case scenario of 9.9 ppg pore pressure at the top Kuparuk target depth, gauge hole, a fracture gradient of 11.8 ppg at the surface casing shoe, 10.1 ppg mud in the hole the kick tolerance is 25 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Manager if LOT is less than 11.8 ppg. ~ There is one "close approach" issues with the production hole interval of Z-100. Z-14 approaches within 105' at 5450' MD. Any alterations to the well plan must include a close approach analysis of this well. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. ERD Recommended Practice Section 5.2" Operating Practices" .:. "Shale Drilling- Kingak & HrZ" :nl:I*).»w.:la:111:1:1:+¡.r~:W:__~_MIW.«~~........,..,.:.,,,,.;I;'¡,;::::~:II~~_I..::.:11. .1. -:-_I.~ÑY~11Ir'::a'lrl::,::m:c_::.::11 *'__:~II:I!llm:lT:nlll:I::___-'-I-:-.rnlm"M>:II'_II__I::-:-1:::1111 Job 8: LOQ Production Hole Hazards and Contingencies ~ Ensure the hole is in optimal condition prior to logging to ensure a successful logging program. Review the use of lubricant pill across logging interval. ~ If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 7" longstring casing. Reference RPs .:. Follow Schlumberger logging practices and recommendations. .:. "Drillpipe Conveyed Logging" Z-100 Drilling Program- AOGCC Page 8 ') ) :.I:>·+Nj'i««««JU_·'N·······~W,,,..........W.... ,,···...w...~~,~::····:·~~»:-"-W~Il*~ Job 9: Case & Cement Production Hole Hazards and Contingencies ~ The interval is planned to be cemented with a lead and tail slurry. The lead slurry will cover from 500' above the Kuparuk to 500' above the Schrader Ma and the tail will cover from the shoe to 500' above the top of Kuparuk interval. ~ Considerable losses during running and cementing the 7" longstring has been experienced on offset wells. A casing running program will be jointly issued by the ODE and Drilling Supervisor detailing circulating points and running speed. In addition a LCM pill composed of "G Seal" may be placed across the Schrader and Ugnu to help arrest mud dehydration if losses were experienced while drilling this interval. ~ Ensure a minimum hydrostatic equivalent of 10.2 ppg on the HRZ during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. ~ Ensure the lower production cement has reached at least a 70BC thickening value prior to freeze protecting. Pump approximately Y2 volume of casing-casing annulus prior to freeze. After freeze protecting the 7" x 9-5/8" casing outer annulus with 63 bbls of dead crude (2035' MD, 2026'TVD), the hydrostatic pressure will be 7.7 ppg vs 8.5 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 110 psi underbalance to the open hole. (A second LOT is requested during freeze protect. This to satisfy AOGCC for future annular pumping permits.) Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" ~_l~~lllmllt:I!!I"m~.Y<I:III:' lloC-M_-<+:<-___»>::_ .,::~.,u..._,____....u-J...,~~~· Job 12: Run Completion Hazards and Contingencies ~ Watch hole fill while running the completion and verify proper safety valves are on the rig floor. The well will be underbalanced if there is a casing integrity problem. ~ Shear valves have been failing at lower than the 2500 psi differential pressure. When testing annulus maintain no more than a 1500 psi differential. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus _.-JAi"'-__I.·.~o'3'~~'.,_W.~~"._,~· ,..""......:I_~_:.........._..-"'·Al,....,....~._._W_..,.: I "¡_"':1~"",,"~" ~_'J'_A..--..:....~'-....'_\"'_~.'...w,O,_-A"·...-" Z-100 Drilling Program- AOGCC Page 9 ) ) Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus ,.;:.w:.~~,~",,¡ ;,¡;'~M'/:.'1~y..,.y,.J.1'''Æ> Z-100 Drilling Program- AOGCC Page 10 ··BF:ECÐi~········ KOP= ,~~~:~~~ì~:~:··......... Datum MD = "5ã't'u'm""~f\/'ij"';"'w", .'.'.·.'.··w'.'.w.,···.'.····.'.··,.'.··w'.··,···· ) Z-100 / ) I i 1-1 3-1/2" HES X NIP, ID = 2.813" I 9-5/8" CSG, 40#, L-80, 10 = 8.835" l-i 3031' ~ ~ ST MD "NO DEV ìYÆ VLV LATCH PORT I DATE 1 6200 KBG Dummy BTM 3.5x1.5 L 2 5700 KBG Dummy BTM 3.5x1.5 3 5100 KBG Dummy BTM 3.5x 1.5 4 4400 KBG DCK-3 BTM 3.5x 1.5 5 3800 KBG Dummy BTM 3.5x1.5 Minimum ID = 2.813" 6 3300 KBG Dummy BTM 3.5x 1.5 3-1/2" HES X NIPPLE (3 total) 7 2600 KBG Dummy BTM 3.5x1.5 I I 1 / ~ 1-i3-1/2" BKR CMD SLIDING SLV, ID = 2.813" (top joint)4-1/2" TBG, 12.6#, L-80, TCII, .01522 bpf, ID = 3.958" 3-1/2" TBG, 9.2#, L-80, Butt, .0087 bpf, ID = 2.992" :g ~I 7" X 3-1/2" BKR PREMIER PKR, 10 = I 2.992" ÆRFORA TION SUMMARY REF LOG: TCP ÆRF ANGLEATTOPÆRF: xx @xxxx' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE ljt 1-1 3-1/2" HES X NIP, 10 = 2.813" I 1-1 3-1/2" HES X NIP, ID = 2.813" 1-1 3-1/2" WLEG, 10 == 2.875" I 13-1/2" TBG, 9.2#, L-80, Tell, .0087 bpf, ID = 2.992" 11 ] 1-1 Pip in collar at 1-1 Pip in collar at 1 PBTD I- I 7" CSG, 26#, L-80, .0383 bpf, 10 == 6.276" l-i ~ 71541 10/08/03 NM Proposed Completion « P4) 1 0/02/03 ÆRMrT No: API No: BP Exploration (Alas ka) ) ) .Z-100 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates may be encountered near the base of the Permafrost at 1888' MD and near the TD hole section as well. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. · Z-100 is expected to cross a fault at 2800' TVD immediately below the top of the SV-1 sand. There may be mud losses associated with this fault. · Well Z-1 01 approached within 24' of the planned path of Z-1 00 at 650'. This should be highlighted to the crew in the pre-spud. A gyro survey should be available as a back-up to ensure directional control of the surface hole. Production Hole Section: · There is one "close approach" in the production hole. Well Z-14 approached within 105' at 5450'. · The production hole section will be drilled with a recommended mud weight of 10.2 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 9.9 ppg pore pressure. · Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices and close monitoring of PWD data will contribute to favorable hole conditions. · Z-100 is expected to cross two faults in the production hole section. The approximate location of the fault is 4400'TVD ss (+/- 200') and has an estimated throw of 50'. Lost circulation is considered a minimum risk. The second fault occurs in the Colville at 5800' TVD ss (+/-150'). Losses have been encountered due to "breathing" in previous wellbores which encountered faults in the Colville. Loss circulation is considered to be a minor risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. HYDROGEN SULFIDE - H2S · This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE Z-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies bp Z-100PB1 (P4) Proposal Schlumberuer Report Date: October 3, 2003 Survey / DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 44.790° Field: Prudhoe Bay Unit - WOA tudy Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: Z-PAD/Z-100 feasibility TVD Reference Datum: KB Well: Plan Z-100 TVD Reference Elevation: 81.0 ft relative to MSL Borehole: Z-100PB1 Sea Bed / Ground Level Elevation: 54.000 ft relative to MSL UWUAPI#: 50029 Magnetic Declination: 25.216° Survey Name / Date: Z -1 OOPB 1 (P4) / October 3, 2003 Total Field Strength: 57551.690 nT Tort I AHD I DDII ERD ratio: 39.803° / 1609.33 ft / 4.821/0.233 Magnetic Dip: 80.797° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: November 15, 2003 Location LatlLong: N 70.29839398, W 149.19316224 Magnetic Declination Model: BGGM 2003 Location Grid NIE Y/x: N 5959360.050 ftUS, E 599628.850 ftUS North Reference: True North "_ _f - Grid Convergence Angle: +0.75961208° Total Corr Mag North .> True North: +25.216° Grid Scale Factor: 0.99991128 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth TVD Sub-Sea TVD Vertical NS EW DLS Tool Face Northing Easting Latitude Longitude Depth Section (ft ) (deg) ( deg ) (ft ) (ft ) (ft ) (ft ) (ft) ( deg/100 ft ) ( deg ) ( ftUS ) (ftUS ) KBE 0.00 0.00 60.00 0.00 -81.00 0.00 0.00 0.00 0.00 60.00M 5959360.05 599628.85 N 70.29839398 W 149.19316224 G1 351.00 0.00 60.00 351.00 270.00 0.00 0.00 0.00 0.00 60.00M 5959360.05 599628.85 N 70.29839398 W 149.19316224 SV6 1111.00 0.00 60.00 1111.00 1030.00 0.00 0.00 0.00 0.00 60.00M 5959360.05 599628.85 N 70.29839398 W 149.19316224 KOP Bid 1.5/100 1400.00 0.00 60.00 1400.00 1319.00 0.00 0.00 0.00 0.00 60.00M 5959360.05 599628.85 N 70.29839398 W 149.19316224 Bid 3/100 1500.00 1.50 60.00 1499.99 1418.99 1.26 0.65 1.13 1.50 59.76M 5959360.72 599629.97 N 70.29839577 W 149.19315306 1600.00 4.50 59.76 1599.84 1518.84 6.32 3.29 5.66 3.00 59.71 M 5959363.41 599634.46 N 70.29840296 W 149.19311643 1700.00 7.50 59.71 1699.28 1618.28 16.42 8.55 14.68 /3.00 O.OOG 5959368.80 599643.42 N 70.29841735 W 149.19304333 SV5 1772.54 9.68 59.70 1771.00 1690.00 26.88 14.02 24.04 3.00 O.OOG 5959374.38 599652.70 N 70.29843228 W 149.19296761 1800.00 10.50 59.69 1798.04 1717.04 31.53 16.45 28.19 3.00 O.OOG 5959376.87 599656.82 N 70.29843891 W 149.19293398 Base Perm 1889.88 13.20 59.68 1886.00 1805.00 49.36 25.76 44.12 3.00 O.OOG 5959386.39 599672.62 N 70.29846435 W 149.19280498 SV4 1895.02 13.35 59.68 1891.00 1810.00 50.50 26.35 45.14 3.00 O.OOG 5959387.00 599673.63 N 70.29846598 W 149.192: [ 1900.00 13.50 59.68 1895.84 1814.84 51.62 26.94 46.14 3.00 O.OOG 5959387.59 599674.62 N 70.29846758 W 149.192~6 2000.00 16.50 59.67 1992.42 1911.42 76.63 40.00 68.47 3.00 O.OOG 5959400.95 599696.78 N 70.29850327 W 149.19260778 End Cry 2035.78 17.57 59.67 2026.64 1945.64 86.76 45.30 77.52 3.00 O.OOG 5959406.37 599705.76 N 70.29851773 W 149.19253450 SV3 2397.01 17.57 59.67 2371.00 2290.00 192.17 100.37 171.66 0.00 O.OOG 5959462.68 599799.15 N 70.29866818 W 149.19177223 SV2 2601.55 17.57 59.67 2566.00 2485.00 251.86 131.56 224.96 0.00 O.OOG 5959494.57 599852.03 N 70.29875338 W 149.19134058 SV1 2926.73 17.57 59.67 2876.00 2795.00 346.74 181.14 309.71 0.00 O.OOG 5959545.26 599936.10 N 70.29888881 W 149.19065435 9-5/8" Csg Pt 3031.62 17.57 59.67 2976.00 2895.00 377.35 197.13 337.04 0.00 O.OOG 5959561.61 599963.22 N 70.29893250 W 149.19043299 UG4A 3115.54 17.57 59.67 3056.00 2975.00 401.84 209.92 358.91 0.00 O.OOG 5959574.69 599984.92 N 70.29896745 W 149.19025590 Marker 3150.00 17.57 59.67 3088.85 3007.85 411.89 215. 18 367.89 0.00 O.OOG 5959580.06 599993.82 N 70.29898180 W 149.19018317 UG3 3445.96 17.57 59.67 3371.00 3290.00 498.2ô 260.30 445.02 0.00 O.OOG 5959626.20 600070.34 N 70.29910507 W 149.18955859 UG1 4012.39 17.57 59.67 3911.00 3830.00 663.54 346.66 592.64 0.00 O.OOG 5959714.51 600216.79 N 70.29934097 W 149.18836319 Ma 4248.41 17.57 59.67 4136.00 4055.00 732.41 382.64 654.14 0.00 O.OOG 5959751.30 600277.80 N 70.29943926 W 149.18786510 Version DO 3.1RT (d031rL546) 3.1RT-SP3.03 Z-100\Plan Z-100\Z-100PB1\Z-100PB1 (P4) Generated 10/3/2003 11: 19 AM Page 1 of 2 Comments Measured Inclination Azimuth TVD Sub-Sea TVD Vertical NS EW DLS Tool Face Northing Easting Latitude Longitude Depth Section (ft) (deg) ( deg ) (ft ) (ft ) (ft) (ft) (ft ) ( deg/100 ft) ( deg ) (ftUS ) ( ftUS ) Cry 3/100 4444.19 17.57 59.67 4322.64 4241.64 789.54 412.49 705.17 0.00 -102.02G 5959781.82 600328.42 N 70.29952079 W 149.18745192 Na 4494.87 17.32 54.67 4371.00 4290.00 804.37 420.72 717.93 3.00 -97.25G 5959790.21 600341.07 N 70.29954327 W 149.18734858 4500.00 17.30 54.16 4375.89 4294.89 805.87 421.61 719.17 3.00 -96.76G 5959791.12 600342.30 N 70.29954569 W 149.18733854 4600.00 17.20 44.03 4471.42 4390.42 835.33 440.95 741.50 3.00 -87.09G 595981Q.75 600364.37 N 70.29959852 W 149.18715766 Z-100 Sch Tgt 4683.36 17.50 35.70 4551.00 4470.00 860.04 459.99 757.38 3.00 O.OOG 5959830.00 600380.00 N 70.29965054 W 149.18702903 OA 4683.37 17.50 35.70 4551.01 4470.01 860.04 459.99 757.38 3.00 -102.08G 5959830.00 600380.00 N 70.29965055 W 149.18702901 4700.00 17.40 34.07 4566.87 4485.87 864.95 464.08 760.24 3.00 -100.52G 5959834.13 600382.80 N 70.29966172 W 149.18700592 OBa 4740.98 17.22 29.98 4606.00 4525.00 876.84 474.42 766.70 3.00 -96.62G 5959844.54 600389. 13 N 70.29968994 W 149.18695356 OBb 4772.38 17.14 26.80 4636.00 4555.00 885.73 482.57 771.11 /3.00 -93.58G 5959852.76 600393.42 N 70.29971222 W 149.18691785 4800.00 17.10 23.99 4662.39 4581.39 893.40 489.91 774.60 3.00 -90.89G 5959860.14 600396.81 N 70.29973228 W 149.18688962 OBc 4824.70 17.11 21.47 4686.00 4605.00 900. 13 496.61 777.40 3.00 -88.49G 5959866.88 600399.53 N 70.29975057 W 149. 1868pcq9 OBd 4882.26 17.24 15.64 4741.00 4660.00 915.35 512.70 782.80 3.00 -82.91G 5959883.04 600404.71 N 70.29979454 W 149.186<' 3 .~ 4900.00 17.31 13.86 4757.94 4676.94 919.91 517.80 784.14 3.00 -81 .22G 5959888.15 600405.99 N 70.29980845 W 149.18681230 End Cry 4932.93 17.49 10.61 4789.36 4708.36 928.21 527.42 786.22 3.00 O.OOG 5959897.79 600407.94 N 70.29983473 W 149.18679541 OBf Base 5039.49 17.49 10.61 4891.00 4810.00 954.70 558.89 792.12 0.00 O.OOG 5959929.34 600413.42 N 70.29992071 W 149.18674764 CM2 5306.85 17.49 10.61 5146.00 5065.00 1021.16 637.85 806.91 0.00 O.OOG 5960008.49 600427.16 N 70.30013643 W 149.18662777 Cry 3/100 5534.68 17.49 10.61 5363.30 5282.30 1077.80 705.14 819.52 0.00 102.36G 5960075.93 600438.88 N 70.30032026 W 149.18652562 5600.00 17.17 17.11 5425.66 5344.66 1094.46 724.01 824.17 3.00 96.16G 5960094.85 600443.27 N 70.30037179 W 149.18648800 5657.90 17.07 23.00 5481.00 5400.00 1109.92 740.00 830.00 3.00 102.01G 5960110.92 600448.89 N 70.30041548 W 149.18644073 5700.00 16.85 27.27 5521.27 5440.27 1121.47 751.11 835.21 3.00 97.93G 5960122.10 600453.95 N 70.30044584 W 149.18639853 End Cry 5786.92 16.69 36.29 5604.51 5523.51 1145.83 772.37 848.37 3.00 O.OOG 5960143.53 600466.83 N 70.30050392 W 149.18629193 CM1 6039.02 16.69 36.29 5846.00 5765.00 1217.43 830.72 891.22 0.00 O.OOG 5960202.43 600508.90 N 70.30066329 W 149.18594488 THRZ 6592.32 16.69 36.29 6376.00 6295.00 1374.56 958.77 985.26 0.00 O.OOG 5960331.71 600601.22 N 70.30101308 W 149.18518318 BHRZ 6816.78 16.69 36.29 6591.00 6510.00 1438.30 1010.71 1023.41 0.00 O.OOG 5960384.15 600638.68 N 70.30115497 W 149.18487418 K1 6868.97 16.69 36.29 6641.00 6560.00 1453.12 1022.79 1032.28 0.00 O.OOG 5960396.34 600647.39 N 70.30118797 W 149.18480231 Target 6884.63 16.69 36.29 6656.00 6575.00 1457.57 1026.41 1034.94 0.00 O.OOG 5960400.00 600650.00 N 70.30119787 W 149.18478076 Top Kup I C 6884.64 16.69 36.29 6656.01 6575.01 1457.57 1026.42 1034.94 0.00 O.OOG 5960400.00 600650.00 N 70.30119788 W 149.18478074 LCU I Kup B 6934.74 16.69 36.29 6704.00 6623.00 1471.80 1038.01 1043.46 0.00 O.OOG 5960411.71 600658.36 N 70.30122955 W 149.1847 ~7 KupA 6935. 79 16.69 36.29 6705.00 6624.00 1472.09 1038.25 1043.64 0.00 O.OOG 5960411.95 600658.54 N 70.30123021 W 149.184;~ OWC 6973.37 16.69 36.29 6741.00 6660.00 1482.77 1046.95 1050.02 0.00 O.OOG 5960420.73 600664.81 N 70.30125397 W 149.18465859 7004.69 16.69 36.29 6771.00 6690.00 1491.66 1054.20 1055.35 0.00 O.OOG 5960428.05 600670.03 N 70.30127377 W 149.18461548 TMLV I FWL 7004.70 16.69 36.29 6771.01 6690.01 1491.66 1054.20 1055.35 0.00 O.OOG 5960428.05 600670.03 N 70.30127377· W 149.18461546 /' TD I 7" Csg Pt 7154.69 16.69 36.29 6914.68 6833.68 1534.26 1088.91 1080.84 0.00 O.OOG 5960463.10 600695.06 N 70.30136859 W 149.18440897 Leqal Description: Northin~ (Y) rftUSl Eastin~ eX) rftUSl Surface: 4557 FSL 3044 FEL S19 T11N R12E UM 5959360.05 599628.85 Sch Tgt : 5017 FSL 2285 FEL S19 T11N R12E UM 5959830.00 600380.00 Kup Target: 304 FSL 2005 FEL S18 T11N R12E UM 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M.. -..-¡. -.. -... ¡:;¡::¡::¡¡5fij~~~~:¡;:¡::¡t¡:;¡:;~~~:~~:~:¡;;¡;:¡;;¡;;¡;;¡;!¡;;¡::¡;;¡;;¡;:¡;;¡;;¡;:¡;;i;;¡;:¡:;¡;;¡;;¡;:¡::¡;;¡;:¡¡¡;;¡::' 6000 4000 3000 2000 1000 o 5000 4000 2000 3000 1000 o TVD Ro/: KB (81.00 ft abovo MSl) Srvy Date: November 15, 2003 Mscolloneous Slot: Z·I00 Plan: Z·I00PBI (P4) NAD27 Alaska Stato Pianos, Zone 04, US Foot Northing: 5959360.05 nus Grtd Conv: +0.75961208' Eostlng: 599628.85 ftUS Scola Fact: 0.9999112757 Surfaco Location Dale: November 15, 2003 I lot: N70 17 54.218 FS: 57551.7nT lon: W1491135.384 Dip: 80.797· Mag Doc: +25.216- STRUCTURE Z-P AD Prudhoe Bay Unit - WOA I FIELD Z-100PB1 (P4) Schlumbørgør ) ) 7000 6000 5000 4000 II (l) (¡j U CIJ o ç 3000 e- O' o o ..- c: c ..- 2000 1000 o Magnotlc ~ßramotora Model: eGGM 2003 I WEll ^ ^ ^ z 4? Õ LO 0! ê :=:- II () ro u C/) C/) V V V bp 'NEll Z-100PB1 (P4) Magnetic Parameters Model BGGM 2003 Dip: 80.797" Mag Dee +25216" -250 1000 750 500 250 ..............,.......................... o ...... ... ~..., ."... ~... ..~.... -250 Schlumberuer Prudhoe Bay Unit - WOA STRUCTURE Z-P AD Surface Location Dale: November 15. 2003 Lat N70 17 54218 FS: 57551.7 nT lon- W149 11 35_384 HAm7 AJaska State Planes. Zone 04. US Feet Northilg: 5959360.05 nus Grid ConY: +0.75961208' Easmg: 599628~85ftUS Scale Fad: O~9999112757 MisœIIaoeous Slot Z-100 Plan: Z-100PB1 (P4) 1VD Ref: KB (81.00 ft above MSl) Srvy Date: Ncwember 15. 2003 o 250 500 750 1000 1250 :N ¡ TO / 7" Csg pt ¡ ! ¡ Target : Z-100PB1 (P4) ¡ ¡ ¡ ~ ./ : < . . . . 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"T....····" ........ ......... o 250 500 750 «< W Scale = 1 (in):250(ft) E >>> 1000 1250 ~ 1000 750 500 .~.I 250 o ') BPX AK Anticollision Report ) Company: BP Amoco Date: 10/3/2003 Time: 11 :37:54 Page: Field: Prudhoe Bay Reference Site: PB Z Pad Co-ordinate(NE) Reference: Well: PlanZ-100, True North Reference Well: Plan Z-100 Vertical (TVD) Reference: Z-100 plan81.0 Reference Wellpath: Plan Z-100PB1 Db: Sybase NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 7154.64 ft Scan Method: Trav Cylinder North Maximum Radius: 3000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Well path Date: 9/10/2003 Validated: No Version: 5 Planned From To Survey Toolcode Tool Name ft ft 28.50 7154.64 Planned: Plan #4 V3 MWD+IFR+MS MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 3032.15 2976.50 9.625 12.250 95/8" 7154.64 6914.69 7.000 8.750 7" Summary <------------------- . Offset Well path ----------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Well path MD MD Distance . Area Deviation Warn? ft ft ft ft ft PB Z Pad Plan Z-220 Plan Z-220 V1 Plan: PI 348.30 350.00 262.21 6.08 256.13 Pass: Major Risk PB Z Pad Z-01 Z-01 V1 1434.88 1450.00 484.37 21.70 462.68 Pass: Major Risk PB Z Pad Z-02A Z-02A V1 1485.80 1500.00 511.93 23.97 487.96 Pass: Major Risk PB Z Pad Z-02 Z-02 V1 1485.80 1500.00 511.93 23.97 487.96 Pass: Major Risk PB Z Pad Z-03 Z-03 V4 746.99 750.00 536.60 11.70 524.89 Pass: Major Risk PB Z Pad Z-04 Z-04 V1 1475.46 1500.00 575.55 22.08 553.47 Pass: Major Risk PB Z Pad Z-05 Z-05 V1 1517.23 1550.00 606.48 23.81 582.67 Pass: Major Risk PB Z Pad Z-06 Plan#7 Z-06A V3 Plan: 1476.33 1500.00 639.88 21.89 617.99 Pass: Major Risk PB Z Pad Z-06 Z-06 V1 1476.33 1500.00 639.88 21.88 617.99 Pass: Major Risk PB Z Pad Z-07A Z-07A V1 1478.72 1500.00 668.27 24.32 643.95 Pass: Major Risk PB Z Pad Z-07 Z-07 V1 1478.72 1500.00 668.27 24.32 643.95 Pass: Major Risk PB Z Pad Z-08A Z-08A V1 1435.73 1450.00 713.17 24.04 689.13 Pass: Major Risk PB Z Pad Z-08 Z-08 V1 1435.73 1450.00 713.17 24.04 689.13 Pass: Major Risk PB Z Pad Z-09 Z-09 V1 1237.36 1250.09 732.49 23.47 709.02 Pass: Major Risk PB Z Pad Z-101 Plan Z-101A V3 Plan: Z 647.69 650.00 24.05 10.69 13.36 Pass: Major Risk PB Z Pad Z-101 Plan Z-101APB1 VO Plan 647.69 650.00 24.05 10.83 13.22 Pass: Major Risk PB Z Pad Z-101 Z-101 V5 648.38 650.00 24.07 10.85 13.23 Pass: Major Risk PB Z Pad Z-10 Z-10V1 639.16 650.00 768.25 12.48 755.78 Pass: Major Risk PB Z Pad Z-10 Z-10A WPS V1 Plan: Z-1 645.57 650.00 768.42 12.56 755.86 Pass: Major Risk PB Z Pad Z-11 Z-11 V1 1483.49 1500.00 304.48 23.72 280.76 Pass: Major Risk PB Z Pad Z-12 Z-12 V1 1484.21 1500.00 282.30 24.56 257.74 Pass: Major Risk PB Z Pad Z-13 Z-13 V1 1484.74 1500.00 275.11 22.42 252.69 Pass: Major Risk PB Z Pad Z-14A Z-14A V1 5453.51 5650.00 105.91 83.37 22.55 Pass: Major Risk PB Z Pad Z-14B Z-14B V1 5453.51 5650.00 105.91 83.37 22.55 Pass: Major Risk PB Z Pad Z-14 Z-14 V1 5453.51 5650.00 105.91 83.37 22.55 Pass: Major Risk PB Z Pad Z-15 Z-15 V1 2640.50 2700.00 134.61 56.97 77.64 Pass: Major Risk PB Z Pad Z-16 Z-16 V1 593.55 600.00 264.04 12.06 251 .99 Pass: Major Risk PB Z Pad Z-17 Z-17 V1 1438.05 1450.00 275.51 23.35 252.16 Pass: Major Risk PB Z Pad Z-18 Z-18 V1 688.99 700.00 275.61 11.45 264.16 Pass: Major Risk PB Z Pad Z-19 Z-19 V1 1606.35 1650.00 139.70 39.30 100.39 Pass: Major Risk PB Z Pad Z-20 Z-20 V1 1736.90 1750.00 308.21 28.80 279.40 Pass: Major Risk PB Z Pad Z-21 Z-21 V3 1530.48 1550.00 240.48 24.39 216.08 Pass: Major Risk PB Z Pad Z-21 Z-21A V5 1490.97 1500.00 239.49 23.17 216.32 Pass: Major Risk PB Z Pad Z-22A Z-22A V1 897.24 900.00 205.79 14.56 191.23 Pass: Major Risk PB Z Pad Z-22B Z-22B V1 897.24 900.00 205.79 14.56 191.23 Pass: Major Risk PB Z Pad Z-22 Z-22 V1 897.24 900.00 205.79 14.56 191.23 Pass: Major Risk PB Z Pad Z-23 Plan#3 Z-23AL 1 V1 Plan 1496.20 1500.00 169.15 23.85 145.30 Pass: Major Risk PB Z Pad Z-23 Z-23 V3 1532.80 1550.00 171.08 28.59 142.49 Pass: Major Risk PB Z Pad Z-23 Z -23A V2 1496.20 1500.00 169.15 23.68 145.47 Pass: Major Risk PB Z Pad Z-24 Z-24 V1 1486.61 1500.00 132.44 23.73 108.71 Pass: Major Risk PB Z Pad Z-25 Z-25 V1 1487.26 1500.00 101.88 28.47 73.41 Pass: Major Risk PB Z Pad Z-26 Z-26 V1 1490.07 1500.00 64.4 7 24.25 40.22 Pass: Major Risk PB Z Pad Z-27 Z-27 V1 1435.37 1450.00 486.12 23.62 462.51 Pass: Major Risk PB Z Pad Z-28 Z-28 V1 1522.46 1550.00 516.75 22.71 494.05 Pass: Major Risk ) BPX AK Anticollision Report ) Company: SP Amoco Field: Prudhoe Bay Reference Site: PB Z Pad Reference Well: Plan Z-100 ReferenceWellpath: Plan Z-100PB1 Date: 10/3/2003 Time: 11 :37:54 Page: 2 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: PlanZ-100, True North Z-100 plan 81.0 Db: Sybase Summary <--------~-------~---- Offset Wellpatb. -------------;.-----~> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB Z Pad Z-29 Z-29 V1 1479.35 1500.00 549.20 23.57 525.63 Pass: Major Risk PB Z Pad Z-30 Plan#104 Z-30L 1 VO Pia 1191.91 1200.00 583.80 19.37 564.43 Pass: Major Risk PB Z Pad Z-30 Z-30 V3 1191.91 1200.00 583.80 19.20 564.60 Pass: Major Risk PB Z Pad Z-31 Z-31 V1 1396.21 1400.00 617.85 27.65 590.20 Pass: Major Risk PB Z Pad Z-32A Z-32A V6 1467.23 1450.00 655.54 23.85 631.69 Pass: Major Risk PB Z Pad Z-32BL 1 Z-32BL 1 V2 1437.12 1450.00 655.15 23.52 631.64 Pass: Major Risk PB Z Pad Z-32BPB 1 Z-32BPB 1 V2 1437.12 1450.00 655.15 23.52 631.64 Pass: Major Risk PB Z Pad Z-32BPB2 Z-32BPB2 V2 1437.12 1450.00 655.15 23.52 631.64 Pass: Major Risk PB Z Pad Z-32BPB3 Z-32BPB3 V2 Plan: Unde 1437.12 1450.00 655.15 23.52 631.64 Pass: Major Risk PB Z Pad Z-32B Z-32B V2 1437.12 1450.00 655.15 23.52 631.64 Pass: Major Risk PB Z Pad Z-32 Z-32 V2 1437.12 1450.00 655.15 23.52 631.64 Pass: Major Risk PB Z Pad Z-33 Plan Z-33B V2 Plan: PI 1518.27 1550.00 690.82 26.77 664.06 Pass: Major Risk PB Z Pad Z-33 Z-33 V1 1477.48 1500.00 684.21 23.12 661.09 Pass: Major Risk PB Z Pad Z-33 Z-33A V1 1518.27 1550.00 690.82 26.77 664.06 Pass: Major Risk PB Z Pad Z-35PB1 Z-35PB1 V2 1517.43 1550.00 826.26 21.58 804.68 Pass: Major Risk PB Z Pad Z-35 Z-35 V2 1517.43 1550.00 826.26 21.58 804.68 Pass: Major Risk PB Z Pad Z-38PB1 Z-38PB1 V3 796.49 800.00 934.23 11.78 922.44 Pass: Major Risk PB Z Pad Z-38 Z-38 V5 796.49 800.00 934.23 11.78 922.44 Pass: Major Risk PB Z Pad Z-39 Z-39 V15 444.92 450.00 320.24 6.84 313.41 Pass: Major Risk ---------- Field: Prudhoe Bay Site: PB Z Pad Well: Plan Z-lOO Wellpath: Plan Z-lOOPBl 100 ~ -294 200 -0 27 90 Z~.J2I~~.ß\) 100 ; - 200 -294 Z-12 (Z-12) Z-13 (Z-13) Z-IDI~;¡¡4!I) , 7 Plan Z-220 (Plan Z-220) Travelling Cylinder Azimuth (TFO+AZI) [deg] V5 Centre to Centre Separation [100ft/in] -- NOT 1/,11(\ ./IF.T1=J::¡ 1Q() nA,Y:~.~«"",-~~__",_~~~_ .; ~.\: ~: ~\:: ::;.;~: :::~~:: g~:: ~. i:::;~~::"~;~< :.::~;i.~:::; ~4~:.:~i :\~~;¿::~ ...... ..... ,t.P'Þ"" I'M#. .... ........... ...... ~..". ....-. g~%:t1~;}~;t~:DBJ III 0 5 5 . ~ ? III ¡: 0 ~ L 2 0 ~ B 9 5 I: O. 2 '7 B 9 b III ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 AMOUNT DATE August 22,2003 *******$100.00******* CONSOLIDATED COMMERCIAL ACCOUNT 055147 No.P 56-389 412 ,r\!aska Oil & Gas Cens. Commìs$~úÎ¡ Anchor ¿¡ye t')r""f" ] 0 ^'()P0 UL ¡ . ¿~UûJ F¿!=CEjVEC¡ H NET VENDOR DISCOUNT CHECK NO. 055147 DATE 8/22/2003 TO THE ORDER OF: B- .····..P r;... 'ro ¡IIIII) ,fllltl ,('I- ('Ii ¡,po . . ,. !.lull.. 1'111.1 11111" ..J' -u.' il" NATIONAL CITY BANK Ashland, Ohio .. TOTAL ~ z- (00 PERMIT TO DRILL FEE GROSS DESCRIPTION PAY: BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 THE ATTACHED CHECK IS IN PAYMENT FOf¡ ITEMS DESCRIBED ABOVE. 8/22/2003 INV# PR0820031 INVOICE / CREDIT MEMO DATE p055147 ) ) TRANSMIT AL LETTER CHECK· LIST CIRCLE APPROPRJATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellboresegment of existing well Permit No, API No. Production. should continue to be reported as a function· of the original API number. stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated In both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to fuD compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample iIitervals through target zones. W~~L~.I!,~~;tYI~TCHEt:~LÎST! Company BP EXPLORATION (~LASKA) INC Well Name: PRUDHOE BAY UN BORE Z-100 Program DEV Well bore seg D PTD#: 2031710 Field & Pool ..E.IlliDJiO_EJ3AY.,J3_QB.E8LLS._QI.L::..6.~toj_3.o Initial ClasslType ----DßLL1:.Q1l_ GeoArea Unit ._.___ On/Off Shore.o~ Annular Disposal D Administration 1 P.ß(mitfee attached. . . . _ . _ _ . . _ . . _ . . . . . .. . . _ .. _ _ _ _ . _ . _ . . . . . _ . . _ . _ _ _ Y.ß$ _ . . _ . _ . _ . _ . . . . . _ _ . . _ _ _ _ _ _ _ _ . _ _ . . _ _ _ . _ _ _ _ _ _ _ _ . . _ . . _ _ _ _ _ _ _ _ . _ _ _ _ . . _ . . _ . . _ 2 .Leas.ß_nurnber _app-rQpriç¡te. . _ . .. _ _ . . . . . . _ . . _ _ . . . _ . _ _ . _ . .. . . . . . _ . _ _ . . _ Y.ß$ _ . _ . . _ . _ . .. _ . _ _ _ _ _ . _ _ . . . . . . . _ _ _ . . . . . . . _ .. . . . . _ . . . . _ . .. _ . _ _ _ _ . . . . . _ . _ _ . _ _ . _ _ 3 .U.nique well.n.am.ß.a[1q oumb.er . . . . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ . _ . . . . . . _ _ Y.ß$ _ _ _ . . . . . . . . . . . . . . . _ . _ _ . . _ _ _ . . _ _ _ _ _ . _ _ . . . . _ . _ _ _ _ _ . _ . . . . . . . . . . _ _ _ _ _ _ . _ . _ . _ _ _ . 4 .We.IUQcated in.aßefined .pool. _ . _ . . _ _ . . . . . _ _ . _ _ _ _ . _ _ _ . . _ _ . . . . ,. _ . . . _ _ Y.ß$ _ _ . _ . _ . _ . . . _ . . _ . . . . . . _ . _ _ _ . . _ . . _ . . . . . _ . _ _ _ _ . _ . . . . _ _ _ _ . _ _ _ _ _ _ _ . _ . . . _ _ _ _ _ . _ . _ 5 .We.IUQcated pr.oper .distance. from drilling unitb_ound.ar:y. . _ _ _ . . . . .. . . . . . . _ . . . _ . _ _ Yes _ _ _ . . . . . _ . _ . _ _ _ . . . . . . _ . . _ . _ . . . . . . . . _ . _ _ _ . _ _ _ _ . .. . . . . . . . _ . _ _ . _ .. .. . . . . . . . . . . _ . . 6 _We.IIJQcated pr.oper .distance. from otber wells. . . . . _ _ . . . . . . _ . . . . . . _ . . _ . . _ _ _ _ Y.ß$ . . . . . . .. _ . . _ _ _ _ . . . _ . _ . _ _ _ . . . . . . . . . . . . . . _ _ _ _ . . . . . . . . _ _ _ _ _ . _ _ _ . _ .. _ . . . . . .. . . . . . 7 _S.ufficient _acreage.ayailç¡ble in.drilJiOQ unjt _ . . . _ . . . . _ _ . _ . . _ . . . . . . . . . . _ . _ _ _ _ Y.ß$ _ . _ . _ . . .. .. _ _ . _ . . _ . . _ _ _ _ _ . . _ _ . . . . . . _ . . _ . _ _ _ _ _ . . . . . . . . .. _ . _ . _ . .. _ . . _ . _ . . . .. . . . 8 Jf.d.ßviatec!, js. weJlbQre platilJcJu.dec! . . . . . . . _ . _ . . _ . . . . . _ . . . . _ . . _ . _ . _ _ _ _ _ Y.ß$ _ .. _ . . . _ . _ . . _ . _ . . . . . . . .. . _ _ . _ _ . _ . . . _ . _ . _ . _ _ _ _ _ _. _.. _ . _ _ _ . _ _ _ _ _ _ . . . . . . . . . . . . . 9 .Qper:.ator only- affected party. _ _ _ .. _ _ . _ . . . . _ . . . _ _ . _ _ _ _ _ . . . . . . . . . _ _ _ _ . . yes . . . . _ _ _ _ _ _ _ _ . _ . . . . _ . _ . . . . _ . . . . . . . . . . . _ . _ _ _ . _ _ _ .. . . _ . _ _ _ _ _ . .. . . . . . . . . . _ _ _ _ . _ . . 10 .Qper:.ator bas.appropriate. bond in .fQrce. . . . . . . . . . . . . . . . . . . . . . . _ . . . _ . . . . . . .Y.ß$ . . . . _ . . . . _ _ _ _ _ _ _ . _ . . . _ . . _ . . . . . . . . . . _ . _ . _ . _ . . . . . . . . _ . . _ _ _ _ _ . . . . . . . . . . _ . . . . . . 11 P.ß(mit Ca[1 Þe iS$ueçl wjtbQut co.nserva.tion order. . . . . _ _ _ . . _ _ . . . . _ _ . . . . _ _ . _ . . Y.ß$ _ . _ _ . . . _ _ _ _ _ . . . . . _ . . . . . . _ . . _ . _ . . . ... . . . _ _ . . . . . . . . _ . _ . . _ _ _ _ . . . . . . . .. . . . _ . . _ . _ _ Appr Date 12 P.ß(mit ca[1 Þe iS$ueçl wjtbQut admilJi$t(ati\(e.approvaJ . _ _ _ . _ _ . _ _ . _ . _ _ . .. . _ _ . _ _ Y.ß$ _ . . . _ . _ . . . . . . . . . . . . . . _ . _ _ _ _ . . . . . _ . . . . - . - . - - - . - .. . . . . . . . - - - . - - . - . . - . . . - . . . . - . r ) 10/10/2003 13 Can permit be approved before 15-daywait Yes 14 .We.IUQcated within area an.d..strata .authQr~ed by.lnjectiol'J Ord.ß( # (putlO# in.c.olJ1m_ents).(FQr_ NA . _ _ _ . _ _ _ . _ _ _ _ . . . . . _ . . _ . . . _ _ . _ . . . . . . . . . . .. . _ . . _ . _ _ . _ _ . . . - . . - . - . - . . . . . . . - . . - . - 15 _All weUs. wit!1i.n .1l4.l1Jile.are.a.of (eyiew jd.ßotifieq (F9r:. ~ervjc.e .welJ onlY-L _ _ _ . . . . _ _ _ . _ . _ NA . . . . . . _ . _ _ _ . _ . . _ . . _ . . . _ . . . . _ . _ _ . _ . . . . _ _ _ _ . . . . . . . . . . . . . . . . . _ . . . _ . . . . . . . . . . . . 16 Pre.-producedinjectQr; dur.atio.n.ofpre-produGtiOlJl.e$s.than.3months.(For.ser:.vicewell QnJy) _ _ _NA _. _ _ _ _... _.. _...... _. _ _. _ _ _ _. _ _ _ _ _...... _ _ _. _.. _ _. _ _" _... _ _.. _ _ _.. _. _ _ _... 17 ACMP_F.inding.of CQn.sistency.h.as Þee.nj~s!.led.for.tbis pr_olec( _ . . . . . _ . . . . . . _ _ . _ . _ NA. . _ _ _ _ . _ _ . . . . . . . _ _ . . . . _ . . . _ _ . . _ _ . . . . . _ _ . _ . . . _ _ _ _ . _ . . _ . . . . _ _ . _ _ . _ . . .. .. - . - . . . . . -.-.--- Engineering 18 .C.ondu.ctor st(ing.prQvided . . . . . . . . _ _ . . . . . . . . . . .. . . . . . _ . . _ . . . .. _ _ _ _ _ _ . Y.ß$ . . . . . _ . _ . _ . _ . _ . . . _ . . _ . . . . _ . . . _ . _ . . . . . _ _ . _ _ _ . . _ . _ _ . . _ .. . .. _ _ . _ . _ . . . . . . . . . . . . . . 19 .S.udac.ß .ca~ing. pJQtec.t$. all.known. USOWs . . .. . _ _ . _ _ . . . _ . . . . . _ . . . . . . . _ . _ _ _ Yes. . _ . _ . _ . . .. _ . . _ . _ . . . . . _ _ . _ _ _ . _ _ . . . _ . . . _ . _ . _ _ . . . . . .. _ _ . . _ . _ _ . _ _ . . . . . . _ _ _ . . _ - . _ 20 .CMT v.ol adequ.ate.to circ_ul.ate.on _co nd.u ctor. & SUJf.csg . . _ _ .. . _ . . _ . . . _ _ _ . _ _ _ _ _ .. _ Y.ß$ . . . _ _ _ . Ade~uate ex.œ$.s, . _ _ _ _ . _ . . . . . . _ . _ _ . _ _ _ _ _ _ _ _ _ . . _ _ _ . . _ . _ . _ _ . _ . . . . . . _ . . . . . _ . . 21 .CMT v.ol. adequ.ate.to tie-i_nJQng _string to_sul1 cS!g. . . . . _ _ . . . . _ . . _ . . . . _ _ _ _ _ _ _ . . No. . . . _ . _ . _ . _ . _ . _ . . . . _ _ _ _ _ . . _ . . . . . _ . . . _ . . . . _ _ _ _ . . . . _ . . . . .. .. _ _ _ . _ _ _ _ . . . . . . . . _ . . . 22 .CMTwill coyer.a]l KlJo.wn_pro.ductiYe bQri~on.s. . . . _ . . _ _ _ _ . _ _ . . . . . . _ . . . _ . . _ . . yes . . . . _ . _ _ _ . _ _ . _ . . . _ . . _ . . . . . . _ . . . . . . . . . _ . . . _ . _ . . . . . . . _ . _ . . _ _ _ _ _ . . . . . . . . . . 23 .C.asing de.sig[1s adequate f.o( C,.T., B _&. permafr.ost . . . _ . . _ _ . _ _ . . . _ . . . . . _ . . . . . Y.ßs . . . . . _ _ _ . . . . _ . . . . . . . . . . . . . . _ . . . . . . . . . _ _ _ _ _ . _ _ . . _ . . _ . . _ _ . _ . . . _ . . . . . . . . _ _ _ . . _ 24 Adequç¡te.tan.kage.oJ re.serye pit _ _ . . . .. . . . . . . . . _ _ _ . _ _ _ . . . . . . . . . . . _ . _ . . Y.ß$ . . . . . _ _ Nab.ors.7.ES,. . . . _ . . _ . . . . . _ _ _ . . . . . .. _ . _ _ . . _ . _ .. . _ _ _ . . . .. _ _ _ . . . . . . . . . . _ _ _ _ 25 Jf.a.re-p(ill~ has.a_ 1.0:-4.03 fQr .abançlOl1rne.nt be.ßO aPPJQved . . _ . . _ . . . . . . . . . _ . . . _ . . NA_ _ _ _ . _ _ _ . _ _ _ . . . . . . _ . . . _ _ _ . _ . _ _ _ . _ . . _ . . . . . . _ _ _ _ _ _ .. . _ _ _ . _ _ . _ . . . . . . . _ . _ . . _ _ 26 .Adequ.ate.w.ellbore. S!eparatjo.n.pro.PO$eP. . . . _ . . . . _ . . . . . . . . . . . _ . . _ . . . . . . . . Y.ß$ . . . . . . . . . . . . . . _ . _ . _ . _ _ _ . _ _ _ _ . _ . _ . . . . . _ . . . . . . . . . . _ _ . _ _ . . . . . . . . . . . _ . . _ _ _ _ _ _ . _ 27 Jf..djver:t~r requiJ~d, dQes jt meet r~guJa_ti9ns. . . . . . _ . . . _ _ . _ . . . . . _ . . . . _ _ .. _ _ _ _ Y.ßs . _ _ . _ . _ _ . _ . _ _ . . . . _ . . . _ _ . _ _ . _ . . . . _ _ . _ _ _ _ _ _ . . _ . . _ _ . . _ _ _ _ _ _ . _ . _ _ . . . . _ _ _ _ _ _ . . - _ Appr Date 28 _DrilliOQ flujd_prQgram $chematic.& eq_uipJist.adequate. _ _ . _ . _ . . . . . . . . _ . . . . . _ _ _ . Y.ßs _ _ _ _ _ _ . Max MW.tP2.ppg.. . . _ _ _ . _ _ _ _ _ . . . _ . . _ _ _ _ _ . . _ _ _ . . _ . _ _ _ _ _ . . . . . _ _ _ . _ . . . _ _ _ _ . _ . V' 10/10/2003 29 .BOPEs,.d9 .they meet. reguJa.tiOI1 _ . _ . _ _ _ . . _ . _ . . _ _ .. . . . _ _ _ . . _ _ _ . _ _ . _ _ . . . Y.ßs _ . . _ _ . . . _ _ _ _ . _ _ . _ _ _ . . . _ . . . _ _ . . _ _ . _ . _ _ _ _ _ _ _ . _ _ _ . . . _ . . . _ . _ _ _ _ _ _ _ _ _ _ . _ . . . . .. . _ . 30 .B.o.PE.pre.s$ ratilJQ appropr:iate;_testto.(pu.t psig Ln.comm~nt$)_ _ _ _ . . . . . _ _ . . . _ _ . _ _ _ Y.ßs _ _ _ . . _ _ T~st tp_50QO.psi. .MSP 27.77 psi._ _ . _ _ _ _ . . _ . _ _ _ . . _ . _ . _ _ . .. _ _ . . _ _ _ _ . _ _ _ _ . . . _ . _ _ . _ _ _ . 31 .C_hoke.manjfQld cQmpJies. w/APtRP-53 (May 84). . . . . . _ _ _ . . _ . _ _ _ _ _ _ . _ _ . _ _ _ . . Y.ß$ _ . . _ _ _ _ . _ . . _ _ _ . .. _ . _ _ _ _. _ . _ _ _ . _ _ . _ . _ . _ _ _ . . _ . _ _ _ _ _ . _ _ _ _ . _ . . _ . _ . . . _ _ _ _ _ _ . _ . _ _ 32 .WQrk will occ_ur: without.operation .sbutdo.wn _ . _ _ _ _ _ . _ . . . _ _ _ _ . . . . _ . _ . . . _ _ . . _ Yes _ . . . . . . . _ . _ . . _ . _ . . . . _ . . . _ _ . . _ . . _ . _ . . _ . . _ _ _ _ _ . _ _ . . . . . _ . . . _ _ . _ . . . _ . _ . . _ _ . . _ . . 33 J$. pre$.ence. 0.1 H2S gas. probable _ . _ . . . . . _ _ _ _ _ _ . . _ _ _ . _ . _ _ _ _ _ _ . _ _ _ _ . _ _ _ No. _ _ . . . _ . . .. . _ . . _ . _ . _ _ . _ _ _ _ . _ . . _ . _ _ . . . _ _ _ _ . . . _ _ . . _ .. - - . 34 Meç:ha_nica!.c0l1d.ition9f we.lIs wtthin A08. yerified (For_s_ervice wet! ol1ly). . . . . . _ _ . _ _ . . . .NA. _ . . . _ . _ _ _ _ _ _ _ . . . _ . . _ _ _ . . _ . . . . . . . . _ . . _ _ . _ . . _ _ . _ _ _ _ . . _ . _ _ _ _ _ _ _ _ . _ . . _ _ . _ _ _ . _ _ . 35 36 Date 37 10/10/2003 38 39 Appr RPC P.ß(rnit c.ao be tS$u.eçl wlo. hyçlr:ogen_ s_ulfide measures _ _ _ . . _ . . . . . . . . . .. . _ _ _ _ . . . . _Y.ßs _ .D.ata.pJ~selJted on. pote.ntial overpres_suœ .zones _ _ _ . . _ _ . _ . . _ . _ _ . _ _ . . . _ _ . . . _ . NA_ . . . . . _ _ _ .Sei.smic_analys,is.o.f $hallow gas.z.olJes. . _ . _ _ _ . . . . . . _ . _ _ _ . _ _ . . _ . _ _ . _ _ _ NA_ _ _ _ _ _ _S.ßabed _conditiolJ survey _(if off-shpr:e) . . . . _ _ . _ _ _ _ . . _ . . _ _ _ . . _ _ . _ _ _ _ . .NA _ _ _ . . Co.nta_ct namelp!1Ol1eJor_w.eelsly progress.reports [explQratpry _only]. . _ _ . _ . _ . _ . _ _ . _ . . NA. _ _ - - - - - - - - - - - ~ - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - Geology - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - . - - - - - - - - - - - - - . - . - - - - - - - - - . - - - - - - - - . - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Engineering Public Date Commissioner: Date: Commissioner: Date Commissioner ~rs /ó!' 3/3 ~ ~ ~~~J