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Home My WebLink About202-145MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, August 30, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC PSI-01 PRUDHOE BAY UNIT PSI-01 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2024 PSI-01 50-029-23104-00-00 202-145-0 W SPT 8040 2021450 2400 1892 1895 1911 1915 143 439 430 425 REQVAR P Austin McLeod 7/22/2024 Two year to MAIP. AIO 4G.010. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT PSI-01 Inspection Date: Tubing OA Packer Depth 221 2628 2605 2605IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM240722182423 BBL Pumped:2.8 BBL Returned:2.8 Friday, August 30, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 AIO 4G.010. James B. Regg Digitally signed by James B. Regg Date: 2024.08.30 14:59:16 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 18, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC PSI-01 PRUDHOE BAY UNIT PSI-01 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/18/2022 PSI-01 50-029-23104-00-00 202-145-0 W SPT 8040 2021450 2350 1982 1983 1982 1981 0 65 66 64 REQVAR P Austin McLeod 7/18/2022 2 year MITIA to MAIP. AIO 4G.010. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT PSI-01 Inspection Date: Tubing OA Packer Depth 678 2712 2688 2685IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220718182913 BBL Pumped:2.6 BBL Returned:2.6 Thursday, August 18, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.18 15:36:11 -08'00' Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Monday, August 10, 2020 2:12 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Stan Golis; Bo York; Oliver Sternicki Subject: OPERABLE: Sea Water Injector PSI -01 (PTD #2021450) AA AIO 4G.010 Attachments: aio4G.010.pdf Mr. Wallace, Sea Water Injector PSI -01 (PTD # 2021450) passed an AOGCC witnessed MIT -IA on 07/29/20 which verifies two competent well barriers. Administrative Approval Area Injection Order 4G.010 for continued water injection only has been granted. The well is now classified as OPERABLE under the conditions specified under AA AIO 4G.010. Please respond with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity /Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity Sent: Thursday, July 16, 2020 11:35 AM Tp�chris-waIlace@alaska.gov Cc: Pm-regg@alaska.gov; Stan Golis <sgolis@hilcorp.com>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.St cki@hilcorp.com> Subject: UNDER"EVALUATION: Sea Water Injector PSI -01 (PTD #2021450) possible TxIA communication Mr. Wallace, Sea Water Injector PSI -01 (PTD #2021 was flagged on 07/15/20 as having possible TxIA communication due to slow inner annulus casing repressurization. The II is now classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan forward: 1. DHD: Bleed IAP 2. Wellhead Technician: Perform PPPOT-T 3. DHD: Monitor IAP for BUR 4. Fullbore (pending): Perform AOGCC witnessed MIT -IA 5. Well Integrity Engineer (pending): Apply for AA 6. Field Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity /Compliance andrew.ogg@hilcorp.com MEMORANDUM TO: Jim Regg.��1� P.I. Supervisorrl FROM: Guy Cook Petroleum Inspector Well Name PRUDHOE BAY UNIT PSI -01 Insp Num: mitGDC200729071111 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 30, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC PSI -01 PRUDHOE BAY UNIT PSI -01 Src: Inspector Reviewed By: _ P.I. Supry51Z Comm API Well Number 50-029-23104-00-00 Inspector Name: Guy Cook Permit Number: 202-145-0 Inspection Date: 7/29/2020 Thursday, July 30, 2020 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PSI -01 Type Inj w, 8040 Tubing 1880 1881 11881 1881 - PTD 2021450 Type Test BBL Pumped 3 BBL SPT Test psi 2010 IA Returned: 3 OA 186 22 2608 290 2583 { 283 2577 278 Interval's OTHER IP/F P - Notes: MIT -IA for possible TxIA communication to see if they need to seek an AA. Testing was accomplished with a Little Red Services pump truck and calibrated gauges. Thursday, July 30, 2020 Page 1 of 1 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Thursday, July 16, 2020 11:35 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Stan Golis; Bo York; Oliver Sternicki Subject: UNDER EVALUATION: Sea Water Injector PSI -01 (PTD #2021450) possible TxIA communication Mr. Wallace, Sea Water Injector PSI -01 (PTD #2021450) was flagged on 07/15/20 as having possible TxIA communication due to slow inner annulus casing repressurization. The well is now classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan forward: 1. DHD: Bleed IAP 2. Wellhead Technician: Perform PPPOT-T 3. DHD: Monitor IAP for BUR 4. Fullbore (pending): Perform AOGCC witnessed MIT -IA 5. Well Integrity Engineer (pending): Apply for AA 6. Field Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/Compliance andrew.ogg@hilcorp.com P:(907)659-5102 M: (307)399-3816 MEMORANDUM State of Alaska Permit Number: 202-145-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg !'J DATE: Thursday, October 3, 2019 P.I. Supervisor `�P-5 ls� I �4 � (G/ SUBJECT: Mechanical Integrity Tests ( l _ BP Exploration (Alaska) Inc. FROM: Bob Noble PSI -01 45 Min 60 Min PRUDHOE BAY UNIT PSI -01 Petroleum Inspector 1629 1628 ' PTD zo214s0 Type Test SPT Test psi zolo IA 1031 2183 Sre: Inspector 2181 - 2179 - Reviewed By: 1.4 - BBL Returned: P.I. Supry W NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT PSI -01 API Well Number 50-029-23104-00-00 Inspector Name: Bob Noble Permit Number: 202-145-0 Inspection Date: 9/26/2019 Insp Num: mitRCN190928093000 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PSI -01 Type Inj w TVD 8040 - Tubing 1509 1510- 1509 1631 - 1629 1628 ' PTD zo214s0 Type Test SPT Test psi zolo IA 1031 2183 2176 -E21 85 - 2181 - 2179 - BBL Pumped: 1.4 - BBL Returned: 2.3 OA 10 43 4444 42 41 Interval 4YRTST P/F P Notes: Second attempt of 2. Dealing with rate changes but it looks like the last 30 min passed. Thursday, October 3, 2019 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE: Thursday, October 3, 2019 P.I. Supervisor , \ r i 1U��' (� SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. PSI -01 FROM: Bob Noble PRUDHOE BAY UNIT PSI -01 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry 3� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT PSI -0I API Well Number 50-029-23104-00-00 Inspector Name: Bob Noble Permit Number: 202-145-0 Inspection Date: 9/26/2019 v Insp Num: mitRCN190928092202 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PSI-ol Type Inj W, TVD 8040 ' Tubing 131s 1508 ' 1510 1509 - 1509 1509 - PTD 2021450 Type 'rest SPT Test psi 2010 IA 369 2205 2203 2208 - 2214 - 2217 ' BBL Pumped: T 2.4 • BBL Returned: 1.6 OA 0 31 34 37 - 41 44' Interval_ _ 4YRTST P/F I ✓ Notes: This is the first MIT of 2 to get this well to pass. Dealing with injection rate changes and thermaling. Thursday, October 3, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,October 06,2015 Jim Regg P.I.Supervisor Z (Ok SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC PSI-01 FROM: Bob Noble PRUDHOE BAY UNIT PSI-0l Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry t NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT PSI-01 API Well Number 50-029-23104-00-00 Inspector Name: Bob Noble Permit Number: 202-145-0 Inspection Date: 9/19/2015 Insp Num: mitRCN150919172044 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Welt PSI-01 Type Inj w. TVD 8040 , Tubing 1489 1490 � 1490 _ 1491 - PTD 2021450 - Type Test SPT Test psi 2010 - IA 300 2204 - 2190 • 2187 IntervalI4YRTST P/F P V OA 0 110 - 108 105 Notes: Tuesday,October 06,2015 Page 1 of 1 • • Brooks, Phoebe L (DOA) 1'c9#2oZ1uS0 From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, October 06, 2015 4:42 PM To: Brooks, Phoebe L (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: RE: September 2015 AOGCC MIT forms Attachments: PSI-01 (PTD #2021450) Directional Survey.xls; PSI-01 (PTD #2021450)Wellbore Schematic.pdf; 09-11 (PTD #1760840) Directional Survey.xls; 09-11 (PTD #1760840) Wellbore Schematic.pdf Phoebe, For PSI-01 it appears the SSTVD was entered into the injector database instead of the true TVD. Are you calculating the TVD to be 8040' TVD? I've attached the directional survey for PSI-01 as well. Perform MD/TVD/5S Depth Conversions Bore Name: [P5I-01 MD Depth: 9083 TVD Depth: 8,040.23 141,41E,Ei MAY 2 7 2016 SS Depth: -7989.18 X Coord: 704,956.221 Y Coord:, 5,968,498.051 Incline: 19.02 Submit Query Reset ResetAll I The packer depth for 09-11 matches the depth on the submitted forms and depth convertor. I've included the directional survey and schematic for reference as well. Perform MD/TVD/SS Depth Conversions Bore Name: 09-11 MD Depth: 109561` TVD Depth: 8,359.37 SS Depth:, -8,305.37] X Coord: 724,028.31 Y Coord: 5,943,058.15 Incline: 43.38 Submit Query Reset] Reset All I Whitney Pettus (Alternate. Kevin Parks) BP Alaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 TREE .. 7.1/16"5K CIW • WELLHEAD=13-5/8"5K FMC '_O S NOTES: WELL REQUIRES A SSSV. ACTUATOR= KB. ELEV-= 52.10' A e_ BF.ELEV = 34.50' KOP Max Angle= 36 @ 3472' 1014' — 13-3/8"TAM PORT COLLAR Datum MD= _ 9619' Datum TVD= 8500'SS 2201' —17-5/8"X 7"XO, ID=6.276" I CA MCO DB NIP, ID=6.000" I 2204' I--I7-5/8"X 7"XO, ID=6.276" I 13-3/8"CSG,68#, L-80, ID=12.400° — 5108' 7-5/8"TBG,29.7#, .0459 bpf, ID=6.875" —I 9907' 9007' —7-5/8"X 7"XO, ID=6.276" 1 9019' —17"HES R NIP,ID=5.963" Minimum ID = 5.770" @ 9119' I I 9041' —IPBR, ID=6.060" 7" HES RN NIPPLE l J g ---- 9083' —7"X 9-5/8"BKR SABL-3 PKR,ID=6.0" ' 9107' —17"HES R NIP, ID=5.963" I 9119' —7"HES RN NIP, ID=5.770" 7"TBG,26#,.0383 bpf, ID=6.276" —I 9132' 1--- �— 9132' —17"WLEG, ID=6.276" 9130' —I ELMD TT LOGGED(08/20/02) PERFORATION SUMMARY REF LOG: BHCS ON 08/05/02 ANGLE AT TOP PERF: 18 @ 9310' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9310-9340 O 11/20/02 3-3/8" 6 9340-9370 O 11/19/02 3-3/8" 6 9416-9434 O 11/19/02 3-3/8" 6 9448-9468 O 11/19/02 3-3/8" 6 9490-9560 O 08/20/02 3-3/8" 6 9570-9630 O 08/21/02 9175' —7"X 9-5/8"BKR ZXP LNR TOP PKR W/TIEBACK SLV 9-5/8"CSG,47#,L-80, ID=8.681" IH 9289' 1 I I I PBTD — 9648' N��+1�� 7"LNR,26#,L-80, .0383 bpf, ID=6.276" —I 9735' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/09/02 DAV/KK ORIGINAL COMPLETION WELL: PSI-01 08/20/02 TMN/KK IPERFS PERMIT No: 2021450 11/16/02 GC/KAK XO DEPTH CORRECTION AR No: 50-029-23104 11/20/02 JB/TP 'ADD PERFORATION SEC 15,T11N,R15E, 1480'FNL&701'FWL 12/09/02 DRS/tlh PERF CORRECTION 02/10/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) ( ( 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. ~O.;¡ - Llþ.5 Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 ~scan Needed 1111111111111111111 R~AN ø Color Items: 0 Greyscale Items: DIGITAL DATA ~skettes, No. d- O Other, No/Type: OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: NOTES: Scanning Preparation ~ x 30 = h1J 0 Other:: Date/O/rr!fJlf I'¡ WtP 1111111111111111111 Date ID/~Ot 151 VVtfJ + ~o = TOTAL PAGES ??O (Count doe~ot . ~clude cover Shl~)A. .p Date: I 0 I~ 0 if Isl VVI , 1111111111111111111 BY: Helen éaria ) Project Proofing BY: Helen ~ BY: Helen C Marig~ 1 Production Scanning Stage 1 Page Count from Scanned File: <3 I (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES - Helen~ Date 10 /a: ~'f If NO in stage 1, page(s) discrepancies were found: YES NO NO fsf Yvtf Stage 1 BY: BY: Helen Maria BY: Helen Maria Date: Isf 1'111111 1111111111111111111 Date: /sl Quality Checked 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned Comments about this file: 8/24/2004 Well History File Cover Page. doc 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 16, 2011 TO: Jim Regg 1 I(kiit P.I. Supervisor 1 I SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC PSI -01 FROM: Matt Herrera PRUDHOE BAY UNIT PSI -01 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT PSI - 01 API Well Number: 50 029 - 23104 - 00 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH111105172818 Permit Number: 202 -145 -0 Inspection Date: 11/2/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 PSI-01 • - • Type Inj. 1 W' TVD 8040 IA 560 2200 2185 2180 P.T.D 2021450 - TypeTest SPT Test psi 2010 • OA 8 29 31 31 Interval 4YRTST P/F P ' Tubing 1220 1220 1220 1220 Notes: Wednesday, November 16, 2011 Page 1 of 1 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 ta A N 4 2,011 • December 21, 2010 Q OP. I I + Mr. Tom Maunder c I — 0 1 Alaska Oil and Gas Conservation Commission IL= e ' ` 333 West 7 Avenue Anchorage, Alaska 99501 ��`tl� Subject: Corrosion Inhibitor Treatments of GPB PSI 1 111Cnr , -±� Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB PSI that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, 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: 12/21/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal PSI -01 2021450 50029231040000 NA 1 NA 5.10 10/25/2010 PSI -05 2031390 50029231740000 NA 1 NA 5.95 10/24/2010 PSI -06 2020790 50029230820000 NA 12.3 NA 45.90 10/25/2010 PSI -07 2031480 50029231770000 NA 1.2 NA 6.80 10/24/2010 PSI -08 2021720 50029231140000 NA 1.3 NA 6.80 10/23/2010 PSI -09 2021240 50029230950000 NA 1.9 NA 12.80 10/23/2010 PSI -10 2021590 50029231100000 NA 0.7 NA 3.40 10/23/2010 qt • MEMORANDUM To: Jim Regg P.I. Supervisor ~ ~~ 7~~7~1„ FROM: Jeff Jones Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 27, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC PSI-Ol PRUDHOE BAY UNIT PSI-Ol Src: Inspector NON-CONFIDENTIAL Reviewed By j P.I. Suprv ~J~ Comm Well Name: PRUDHOE BAY UNIT PSI-O1 Insp Num: mitJJ100721172703 Rel Insp Num: API Well Number: s0-029-23104-00-00 Permit Number: 202-14s-0 Inspector Name: Jeff Jones Inspection Date: 7/4/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well PsI-ol ~ Type Inj. ~' ~ TVD soao - IA sso z61o 2s8s 2s8s P.T.D 20214s0 TypeTest sPT Test psi 2010 OA 180 360 360 360 Interval aYRTST p/F P Tubing lgzo lglo 1810 lglo Notes: 3.1 BBLS methanol pumped. 1 well inspected; no exceptions noted. Tuesday, July 27, 2010 Page 1 of 1 MEMORANDUM • To: Jim Regg ~~~/; ~i~~~L' 7 P.I. Supervisor j (, FROv[: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, November O5, Z00? SUB3ECT: Mechanical Inte~ity Tests BP fiXPLORATIOI`1 (ALASKA) INC PSI-0 ] PRUDHOE BAY UNIT PSI-Ol Src: Inspector NON-CONFIDENTIAL i ~~~ ~~ Reviewed By: P.I. Suprv~_ Comm Well Name: PRLiDHOE BAY [NIT PSI-O L API Well Number: 50-029-2 3 1 04-00-00 Inspector Name: John Crisp Insp Num: mitJCr071105061241 Permit Number: 202-145-0 Inspection Date• 1 04/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well j rsI-0I ~iType Inj. ~ TVD ~ aoa~~ IA o ~ a3oo zzao ~ zzaa P.T. ~ zo2laso ~ITYPeTest sP T t psi _2oio OA - o _~ ~ ° ° ° _~_ - Interval 4YxTST p~ P /_ Tubing i tsso I3so I3so I3so Notes• 2.7 bbl's pumped for test a~~.~l~'~~~~~ IV~~ .ti LU~I Monday, November O5, 2007 Page l of 1 ~~o . -- - - . . Subject: RE: Missing MITs From: "Hughes, Andrea" <hugha4@BP.com> Date: Mon, 15 Jan 200720:22:26 -0900 Jim and Bob, Attached are the missing MIT forms questioned in your email. r 1. MITs that appeared past due: -33 PTD 189, 00 MITIA performed on 04/17/05 PSI-Ol (PTD 2021450) MITIA performed on 11/10/03 Z-33A (PTD 1890050) MITIA 05/09/03 12-30 (PTD 1881420) MITIA 12/04/04 2. MITs done: 12 - 2 3 (PTD 184058 0) M I TOA 07/2 9/ 0 6 13-22 (PTD 1820770) MITOA 08/26/06 Please let me SCANNEDuJÄ~t1 ~u2Ónir information. Thank you, ¡"'ndrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 -----Original Message----- From: James Regg C Sent: Thursday, January 11, To: NSU, ADW Well Integrity Subject: Missing MITs . C:.i:....¿:iC.2. El~<' .1...:3] PM We have completed a review of the MITs due during the past quarter (October - December 2006) and due in January 2007. Several lists below: 1. MITs that appear to be past due *PBU 12-33* (PTD 1890100); MIT due 10/20/2006; status - injecting *PBU 1"SI-Ol* (PTD 2021450); MIT due 11/2/2006; status - injecting *PBU Z-33A* (PTD 1890050); MIT due 10/19/2006; status - injecting 2. MITs done (based on monthly injector integrity report); no Commission record of the test: *1"8U 12-23* (1"TD 1840580); annual MITOÞ. done 7/29/2006 *1"BU 13-22* (1"TD 1820770); annual MITOA done 8/26/2006 Please co~ple~e MITs and provide missing reports by January 31, 2 07. 3. MITs due durlng January 20 7 according to our data: *M1"U C-36* (PTD 1980010); due 1 17/2007; status - lnjecting *¡V¡PU F-92* (?TD 1981930 ; due 1/17/2007; s at us - injecLi~g *~PU F-95* (PTD 1981790); due l/17/2007; status - injecting 4. ShuL in wells approachi~g MIT anniversary date; it is acceptable t-ì o ~ U16/2007 9:35 AM . . to defer testing these until they recommence inJection: *PB'1 WB-06* (1"TD 1982210); due 1/13/2007; status - 81 since 9/2003 *1"B'1 PWDW2-1* (PTD 1760630); due 1/27/2007; status - 81 since 3/2003 Call if you need to discuss. Jim Regg AOGCC Content-Description: MIT PBU 12-30,33 12-04-04.xls MIT PBU 12-30,33 12-04-04.xls Content-Type: applicationivnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU PSI-Ol 11-10-03 (2).x1s MIT PBU PSI-OI11-10-03 (2).xls Content-Type: applicationivnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU Z-33A 05-09-03.xls MIT PBU Z-33A 05-09-03.xls Content-Type: applicationivnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 12-23 07-29-06.xls MIT PBU 12-23 07-29-06.xls Content-Type: applicationivnd.ms-exce1 Content-Encoding: base64 Content-Description: MIT PBU 13-22 08-26-06.xls MIT PBU 13-22 08-26-06.xls Content-Type: applicationivnd.ms-excel Content-Encoding: base64 20f2 I/16/2007 9:35 AM , . . 01 ¡b/ 1 ~ Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test \Z a¿,(l BP Exploration (Alaska), Inc, Prudhoe Bay / PBU / PSI 11/10/03 Andrea Hughes ç ~O~ \4' Packer Depth Pretest Initial 15Min. 30 Min. WelllPSlc01 I Type Inj. ! N TVD I 8,040' Tubing 2,250 2,250 2 .250 2,250 Interval! 0 PTD,12021450 I Type test I P Test psi 2010 Casing 20 2,000 1,970 1,970 P/F! P Notes: MITclA for eval possible TxlA communication. OA 0 0 0 0 Weill I Type Inj, I TVD I Tubing I Interval! PTD,I I Type test I Test psi! Casing I P/FI Notes: OAI Weill I Type Inj.1 TVD I Tubing Interval! PTDI I Type testl Test psil Casing P/FI Notes: OA Weill I Type Inj, I I TVD I Tubing Interval I PTD,I I Type testl I Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval I PTDI I Type test I I Test psil Casing P/FI Notes: OA TYPE INJ Codes 0::; Drilling Waste G = Gas ! = Industrial Wastewater N = Not Injecting W = Water MIT Reoort Form 8FL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R ::: internal Radioactive Tracer Survey .A.::: Temperature Anomaly Survey 0::; D¡fferential Temperature Test INTERVAL Codes !::; Initial Test 4::: Four Year Cycle V ;::: Required by Variance T = Test dUring Workover o = Other (describe in notes) "\¡1ITPSU ='Si,C1 ~1-1D-03 i:2)-1xis -/' . . ·..·····r························· :' .,.\"-,.,, "-',.<.., .. ',"<, 1 ...... ;-,1lr MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc ) ids C!\J ~ "---\1. WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC Atten: Robin Deason 333 W. 711' Street Suite # 100 Anchorage, Alaska 99501 --_.~._._----_._---_.. RE : Distribution - Final Print(sJ ) c;;(; (J ~Â -I 'fs--' The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1389 Stafford, TX 77497 WELL LOG TYPE DATE Open Hole PSI01 8-24-04 Res. Eva!. CH t, " f,' I'>. ~"ï. ,\.~ Il-:: ~~: ,")¡ \.J!t....'H ~" ,".[.,. ;igned : aµ~rL ~~J #~.?/J ~~- Mr/tf/2-Æ/ Jrint Name: BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 Electronic Data ImaÇ)es 1 BLUE LINE PRINT(S] REPORT OR COLOR 1 1 1 - qnn~:7 '(! ~~ t.JJ ùa Date: ~f~ Phonc:(28 1) 565-9085 Fax:(28 I) 565- 1369 PI(oACliVI Di^<iNO~lic Suwi(ü, INC., PO Box I ~69 SIA/lOltd IX 77477 Wcbsite: www.memorylog.com E-mail: pds@mcmorylog.com ;(tj àJr t- ~.~. DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2021450 Well Name/No. PRUDHOE BAY UNIT PSI-01 Operator BP EXPLORATION (ALASKA) INC Y~2JJ.Lw,~~ API No. 50-029-231 04-0;-~b MD 9735 ./ TVD 8663 / Completion Date 8/20/2002 ",.. Completion Status 1WINJ currer~'NJ ~ (UIC Y "") -------.-------. ~"-~-"---'-------- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes --~---~_._-_.~----- ---~~-_.~----------~---_._-~---- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, USIT, AIT HALS, TLD, CNL, AMS-c, DIPOLE SONIC Well Log Information: (data taken from Logs Portion of Master Well Data Maint) 5 Blu _d Interval OH/ Start Stop CH Received Comments -~'-------'_._--'- ~ 9270 Case 8/30/2002 uJ[r 0 9735 Open 8/23/2002 8970 9724 Open 11/8/2002 Platform Express Combo Log ~ 9270 Case 8/30/2002 0 9735 Open 8/23/2002 ¡ t,: IC... ~ 9698 Open 11/8/2002 Platform Express High resolution Laterolog ~ 9326 Case 8/30/2002 ~ Bottom Hole Pressure Survey PSP ~12 9734 Open 11/8/2002 BHC HRLA 0 9735 Open 8/23/2002 MWD ,-¿, ~ 9326 Case 8/30/2002 Static Bottom Hole Pressure Survey PSP A Directional Survey Log is required to be submitted, This record automatically created from Permit to Drill Module on: 7/11/2002. ~O 9610 Case 12/1 0/2002 /'221 9697 Open 2/28/2003 ..-wro 9680 Open 11/8/2002 '15ìatform Express 221 9697 Case 2/28/2003 ~O 9326 Case 8/30/2002 Static Bottom Hole Pressure Survey PSP ~ 9270 Case 8/30/2002 ~--'----'~~~'-~'----_._---- Log/ Data Digital Type Med/Frmt L~ Rpt ~ Electr Dataset Number Name ~nic Directional Survey Log Log Run Scale Media No 5 Col 1 See Notes /f/'ð 25 Blu ~ ~ ~ ~pêraturê ' $ectional Survey S~tes . . 5 Col ~ .,.eãSing collar locator Blu ~C Rpt ~7 See Notes Directional Survey ~ Pr~ure Blu ~~ Temperature 5 Blu ~ D (j..1-5'46 Gamma Ray ~ ~er log 25 Blu Rpt LIS Verification -rõ9 4ámma Ray Blu L~ ..GafiÍma Ray 5 Col DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2021450 MD 9735 ~ ~ (og ~ ~ ~D C Asc ED C Pdf ~ ED ED C Pdf C Pdf C Pdf C Pdf ";:D C Pdf ~ Well Name/No. PRUDHOE BAY UNIT PSI-01 TVD 8663 Completion Date J)ifS'éfíonal Survey pessure See Notes M Ö 8/20/2002 J:efnperature ~c f1'2006 LIS Verification 12006 Induction/Resistivity 12006 Induction/Resistivity 12006 Density 12006 Neutron 12006 Density ""'-2006 Neutron ,;J;emperature Well Cores/Samples Information: Name Interval Start Stop Well Cored? ADDITIONAL INFORMATION Y~ Chips Received? .. Y J ~J - Analysis Received? Comments: Y/N Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23104-00-00 Completion Status 1WINJ Current Status 1WINJ UIC Y 0 9735 Open 8/23/2002 ~D--~~ 5 Blu Ð400 9610 Case 12/1 0/2002 25 Blu ~70 9724 Open 11/8/2002 Platform Express Combo Log 1 ,.,..... B I u ~O 9326 Case 8/30/2002 Static Bottom Hole Pressure Survey PSP 5 Blu ,..Mf0 9724 Open 11/8/2002 _. 1,2,3 ,220 9735 rOpen 6/2/2003 25 Final _113 9735 Open 6/2/2003 MWD-ROP, DGR, EWR- MD 25 Final ...-113 8663 Open 6/2/2003 MWD-DGR, EWR- TVD 25 Final 113 973~pen 6/2/2003 MWD-DGR, CNP, SLD-MD 25 Final r113 973 Open 6/2/2003 MWD-DGR, CNP, SLD-MD 25 Final -113 8663 Open 6/2/2003 MWD-DGR, CNP, SLD- TVD 25 Final ~3 8663 fipen 6/2/2003 MWD-DGR, CNP,.SLD- TVD 25 Blu ~ 9625 Case 7/23/2003 Temperature Warmback Log - PSP-PBMS --~--~---~- ---------.---- Sent Sample Set Number Comments Received Daily History Received? Ø,N rG/N Formation Tops -----~_.._------~----- - ~------~-----_..---,,~._------_. -------~---~-------- - ~-'-----~---_._---- - DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2021450 Well Name/No. PRUDHOE BAY UNIT PSI-01 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23104-00-00 MD 9735 TVD 8663 . J comp. mpletion Date 8/20/2002 Compliance Reviewed By: '"d--O Completion Status 1WINJ Current Status 1WINt UIC Y Date: C ~~- t.{ - ( ~Oé)-115' 1800Lp WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 ~chorage, Alaska 99501 May 23, 2003 RE: MWD Formation Evaluation Logs: PSI-Ol, AK-MW-22123 PSI-Ol: Digital Log Images 50-029-23104-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ~chorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~D \ ~ /V\ ~ '- "-Þ--:t:..bV'.-. Or;) fI.OO.? L L. ;) ~~~.\'f\~ ( . 115Ljfo DaD 1-)'15 ;¿ o;t -[ 'is- WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 ~chorage,Alaska February 27, 2003 RE: MWD Formation Evaluation Logs PSI-OI, AK-MW-22123 1 LDWG formatted Disc with verification listing. API#: 50-029-23104-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMmAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Signed~Ú-~ RECEIVED FEB 2 8 2003 AIaab Oii & Gas Cons. Commieeion AnchorJge Schlumberger 12/09/02 NO. 2588 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503.5711 A TTN: Beth A-11 PSI-06 PSI-01 NK-27 D.S. 9-34A Z-32B L 1 NK-38 D.S. 1-32 C-35A P1-08 D.S.1-26A D.S. 9-28A Well I ~ J- O~~<K. a~-o74 a~- Jl"¡.~ I ~O~ J I~ - aOI I í.-D35 , 4 - / ÎO I ,to;- /d. Î ! 5 -dOG ! (;j'ì-09 r I ~ -OJ;). I 4. -Olf,~ Field: Prudhoe Bay ~ Job# Log Description Color Date Blueline Sepia Prints CD 11/16/02 1 11/11/02 1 11/19/02 1 11/29/02 1 11/11/02 1 11/11/02 1 11/27/02 1 11/07/02 1 11/25/02 1 11/07/02 1 11/08/02 1 11/10/02 1 INJECTION PROFILE INJECTION PROFILE SBHP PROD PROFILEIDEFT LDL MEM PSP PROD PROFILE/DEFT STATIC PRESSURE SURVEY GRAVEL PACK W/RST-C PSP LDL SBHP SURVEY PRODUCTION PROFILE PRODUCTION LOG PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECE\VED DEC 10 ?002 Ai_a a¡ & Gas Cons. Commi83ion Anchorage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth R6~~~ ~ ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: ADD PERFS 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address Operation shutdown- Pull tubing - P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1480'FNL,4579'FEL,Sec. 15, T11N, R15E, UM At top of productive interval 4234' FNL,2147'FEL, Sec.09,T11N, R15E, UM At effective depth 4158' FNL, 2228' FEL, Sec. 09, T11 N, R15E, UM At total depth 4149' FNL,2237'FEL, Sec. 09, T11N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Stimulate - Alter casing - 5. Type of Well: Development - Exploratory- . Stratigraphic- Service_X (asp's 707827, 5966097) (asp's 704905,5968544) (asp's 704822, 5968618) (asp's 704813, 5968626) 9735 feet 8663 feet Plugs (measured) Plugging - Perforate _X Repair well - Other - 6. Datum elevation (DF or KB feet) RKB 51 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number PSI-01 9. Permit number I approval number 202-145 10. API number 50-029-23104-00 11. Field / Pool Prudhoe Bay Oil Pool Effective depth: measured 9648 feet Junk (measured) true vertical 8579 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 260 sx Arctic Set (aprox) 145' 145' Surface 5074' 13-3/8" 1311 sx Arctic Set III, 5108' 4648' 600 sx Class 'G' Intermediate 9258' 9-5/8" 618 sx Class 'G' 9289' 8236' Liner 560' 7" 145 sx Class 'G' 9175' - 9735' 8127' - 8663' Perforation depth: measured Open Perfs 9310'-9370',9416'-9434',9448'-9468', 9490'-9560', 9570'-9630' true vertical Open Perfs 8256'-8313',8357'-8374',8388'-8407', 8428'-8495', 8504'-8562' Tubing (size, grade, and measured depth) 7-5/8" 29.7# L-80 @ 2201' MD. 7-5/8" x 7" XO @ 2201'. 7" x 7-5/8" XO @ 2204'. 7-5/8" 29.7# L-80 @ 9907' MD. 7-5/8" x 7" XO @ 9007' MD. 7" 26# L-80 @ 9132' md. Packers & SSSV (type & measured depth) 7" X 9-5/8" Baker SABL-3 Packer @ 9083' MD, 7" Camco DB Nipple @ 2202'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniectio?\ft(Ska On& Gas Gons. CommiSSion Oil-Bbl Gas-Met Water-Bbl Cas~qe Tubing Pressure 45636 1209 Prior to well operation 11/10/2002 Subsequent to operation 11/28/2002 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations - Oil- Gas - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~øt!~ Form 10-404 Rev 06/15/88 . RECFIVFO DEC 042002 108142 16. Status of well classification as: Title: Technical Assistant } 1619 Suspended - Service WATER INJECTION RBDMS 8Ft Date December 04, 2002 P':'~'~:I~:':~:~:::~M'51~ r.; 11/01/2002 11/02/2002 11/04/2002 11/05/02 11/12/2002 11/13/2002 11/19/2002 11/20/2002 12/02/2002 12/02/2002 PSI-01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS INJECTIVITY TEST: AC-FLUID LEVEL NEW WELL POST: AC-MITIA INJECTIVITY TEST: AC-MONITOR PUT ON SEA WATER INJECTION NEW WELL POST: LOAD WELL TO SECURE NEW WELL POST: LOAD WELL TO SECURE NEW WELL POST: PERFORATING; STATIC BOTTOM HOLE PRESSURE SURVEY NEW WELL POST: PERFORATING TESTEVENT --- INJ PRESS, PSI: 1,323 TYPE: SW VOL: 91,410 NEW WELL POST: SSSV C/O OR STROKE EVENT SUMMARY 11/01/02 T/I/O = 1300/950/300, IA FL @ SURFACE POST INJECTION START-UP. 11/02/02 T/I/O= 900/150/200 MITIA TO 2100 PSI. PASSED (AOGCC WITNESSED, JEFF JONES). INITIAL IA FL AT SURFACE. MITIA LOST 0 PSI IN THE FIRST 15 MINUTES AND 0 PSI IN THE SECOND 15 MINUTES FOR A TOTAL OF 0 PSI IN 30 MINUTES. PUMPED 2 BBLS OF DIESEL DOWN THE IA. FINAL WHp1s = 900/200/200 11/04/02 TIO= 1150/VAC/80 (POST MITIA) 11/05/02 PUT ON SEA WATER INJECTION. 11/12/02 LOAD IA W/ 500 BBLS CRUDE 11/13/02 FREEZE PROTECT TUBING W/ 140 BBLS 60/40 METH AND FLOWLINE W/ 12 BBLS 60/40 METH 11/19/02 CORRELATE TO SWS BHCS LOG DATED 8-5-02. STOP COUNTS IN LUB 191, PRESS=2472. STOP COUNTS @9500' MD=83861 TVD 36 MINUTES PRESSURE=3319 PSI, TEMP=87.5 DEGF. STOP COUNTS @9600. MD=84861 TVD SS FOR 20 MINUTES PRESSURE=3351 PSI, TEMP=76 DEGF, PRESSURE CHANGE <1PSI/20 MINUTES. PERFORATED 94481-94681 WITH 3406 POWERJET 6 SPF 3 3/8 . PERFORATED 9416-9434 WITH 3406 POWERJET 6 SPF 3 3/8. PERFORATED 93401-9370' WITH 3406 POWERJET 6 SPF 3 3/8. CHARGE DATA:3406 POWERJET, 6 SHOTS PER FOOT, 38.6" PENETRATION, 0.45" ENTRANCE HOLE, 22.7 GRAMS. COMPLETE FOLLOWING DAY. «< WELL SHUT-IN »> Page 1 PSI-01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/20/02 CORRELATE TO SWS SHCS DATED 5-AUG-2002 AND SWS JEWELRY LOG DATED 20-AUG-2002, PERFORATED 93101-9340. WITH 3406 POWERJET 6 SPF 33/8. CHARGE DATA:3406 POWERJET, 6 SHOTS PER FOOT, 38.611 PENETRATION, 0.4511 ENTRANCE HOLE, 22.7 GRAMS. 12/02/02 TESTEVENT --- INJECTION PRESSURE, PSI: 1,323 TYPE: SW VOL: 91,410 BWPD. 12/02/02 SET T' A-1 WATER INJECTION VALVE W/ DB-6 LOCK. SERIAL# = (HTS-641), WELL ON A V AC. «< WELL PUT BACK ON INJECTION »> Fluids Pumped BBLS 4 157 500 2 663 DIESEL FOR SURFACE PRESSURE TEST (4 TESTS) 60/40 METHANOL WATER CRUDE DIESEL TOTAL ADD PERFS 11/19 -20/2002 THE FOLLOWING INTERVALS WERE PERFORATED USING 3-3/811 3406-PJ, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 93101 - 93401 9340' - 9370' 94161 - 94341 94481 - 94681 Page 2 Scblull~ePDep NO, 2539 Company: Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well PSI-01 dûd - ILl 5 PSI-01 PSI-01 PSI-01 PSI-01 PSI-01 ,/ PSI-08 dQ;;).- 11 ~ PSI-08 .. ' PSI-08 "'V 11/07/02 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Sepia Prints CD 08/05/02 08/05/02 1 08/05/02 1 08/05/02 1 08/05/02 1 08/05/02 1 09/21/02 09/21/02 1 09/21/02 1 Job# Log Description 22376 OH EDIT BHC/HRLA (PDC) 22376 BHC 22376 PEX-HRLA 22376 PEX-COMBO 22376 PEX-COMBO SSTVD 22376 PEX-HCAL-CALIPER 22449 OH EDIT GR & BHC (PDC) 22449 BHC-GR 22449 BHC-GR SSTVD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth ReceiV~~ RE IV NOV 08 200? I! !~~b ")" fj r" ¡'lI¡;;.U'f\!t ~I'. ,., . "':;;'''. '. '. '''..'.~.m'. .'. . _..,,~~ v..:m£l~ An:;rHX~nll~ tY"" ~ .-~" ) (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned iii Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3800' NSL, 4579' WEL, SEC. 15, T11 N, R15E, UM At top of productive interval 1046' NSL, 2147' WEL, SEC. 09, T11N, R15E, UM At total depth 1131' NSL, 2237' WEL, SEC. 09, T11N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 51.05' ADL 034631 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 7/23/2002 8/5/2002 8/20/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 9735 8663 FT 9648 8579 FT iii Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, USIT, AIT, HALS, TLD, CNL, AMS-c, Dipole Sonic 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 34" X 20" 94# H-40 35' 110' 42" 260 sx Arctic Set (Approx.) 13-3/8" 68# L-80 34' 5108' 16" 1311 sx Arctic Set III, 600 sx 'G' 9-5/8" 47# L-80 31' 9289' 12-1/4" 618 sx Class 'G' 7" 26# L-80 9175' 9735' 8-1/2" 145 sx Class 'G' SIZE 7-5/8",29.7#, L-80 x 7", 26#, L-80 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 135 Bbls of Diesel 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 6 spf MD TVD 9490' - 9560' 8428' - 8495' 9570' - 9630' 8504' - 8562' 25. MD TVD 26. 27. Date First Production October 29,2002 Date of Test Hours Tested 1 0/29/2002 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL 279 WATER-BBL Flow Tubing Casing Pressure CALCULATED Press. 1 ,239 24-HoUR RATE OIL-BBL GAs-McF 11/05/02, Put on Injection Classification of Service Well Gas Cap Injection 7. Permit Number 202-145 8. API Number 50- 029-231 04-00 9. Unit or Lease Name Prudhoe Bay Unit 302-252 10. Well Number PSI-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2202' MD 1900' (Approx.) AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 9132' PACKER SET (MD) 9083' CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core I! € E I V E D No core samples were taken. 28. ~90MS BFt Form 10-407 Rev. 07-01-80 NOV I 8 2002 NOV 0 6 2002 Alaska on.& Gas gems. Commission Anchorage Submit In Duplicate .., ( 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Ugnu 1 6572' 5885' West Sak 2 7193' 6411' West Sak 1 7418' 6599' Colville Mudstone 3 7769' 6891' Colville Mudstone 2 8421' 7437' Colville Mudstone 1 8678' 7665' HRZ 9116' 8071' LCU I Top Ivishak I Zone 3 9304' 8250' Zone 2C/ BCGL 9371' 8314' Zone 1 9559' 8494' Kavik 9663' 8594' 31. List of Attachments: ( 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RE€!'VEÐ NOV 0 6 2002 Þ 011.& Gas Gons. Comm\SS\Ofl Alas Anchorage Summary of Daily Drilling Reports and Post-Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~J\J\Å..l. ~ Title Technical Assistant Date J I - OS. 0 ^ PSI-01 202-145 302-252 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Rob Tirpack, 564-4166 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 (, MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill Commissioner fl"lN DATE: November 2, 2002 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder BPXA Petroleum Engineer ~ Q9fI\. PSI Pad r:J.Y \\\",,°7 PSI-01, 08, 09, 10 FROM: Jeff Jones Prudhoe Bay Unit Petroleum Inspector Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. TV.D. 8040 Tubing 900 900 900 900 Interval Test psi 2010 Casing 150 2090 2090 2085 P/F OA 200 450 450 450 Notes: Pre-test pressures monitored 15 min. & stable. Test fluid 60/40 methanol. S riser temp: 70 deg. F Well PSI-01 Type Inj. S P.T.D. 202145~ Type test P Well PSI-08 Type Inj. S T.V.D. 8014 Tubing 1175 1340 1340 1350 Interval P.T.D. 202172~Typetest P Test psi 2004 Casing 80 2110 2090 2110 P/F OA 220 420 420 420 Notes: Pre-test pressures monitored 15 min. & stable. Test fluid 60/40 methanol. S riser temp: 72 deg. F Well PSI-09 Type Inj. S TV.D. 8034 Tubing 1160 1000 1160 1150 Interval P.T.D. 202124~Type test P Test psi 2009 Casing 380 2060 2060 2065 P/F OA 380 560 560 560 Notes: Pre-test pressures monitored 15 min. & stable. Test fluid 60/40 methanol. S riser temp: 76 deg. F Pretest Initial 15 Min. 30 Min. 45 Min. Well PSI-10 Type Inj. S TV.D. 8056 Tubing 850 850 850 850 850 Interval P.T.D. 2021590 /Type test P Test psi 2014 Casing 0 2090 2085 2080 2080 P/F ~ OA 320 580 580 580 580 Notes: Pre-test pressures monitored 15 min. & stable. Test fluid 60/40 methanol. S riser temp: 74 deg. F Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALT WATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details November 2, 2002: I traveled to BPXA's PSI Pad in the Prudhoe Bay Field to witness initial MIT's on water iI1iection wells PSI-OI, PSI-08, PSI-09 and PSI-lO. Roland Johnson was the BPXA representative today and he performed the tests in a safe and proficient manner. The pre-test pressures were observed for 15 minutes and found to be stable. The standard annulus pressure test was then performed, with all four wells passing the MIT. Well PSI-I 0 was monitored an additional 15 minutes to further demonstrate integrity and the casing pressure stabilized at 2080 PSI. The four well houses were inspected with no exceptions noted. Summary:1 witnessed successful MIT's on BPXA's Prudhoe Bay Field water injection wells PSI-OI, PSI-08, PSI-09 and PSI-lO. Four well house inspections; no exceptions noted. .I.T.'s performed: ~ Attachments: Number of Failures: ~ Total Time during tests: 5 hrs. cc: M IT report form 5/12/00 L.G. MIT PBU PSI 01,08,09,10 11-2-02 JJ.xls I e I e I .e I .e 11/4/2002 \ Jl. //~£ 4'./I.D"Z.þD <:I"'" {~"~ ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned iii Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well a~ surface r C(j~11F ':, 'l:.t6c:AhõÑS1" 3800' NSL, 4579 WEL, SEC. 15, T11 N, R15E, UM ~ L,'\T::' " t ~} At top of productive interval ~ ;~ ,z.Þ~-{2.'4- D .1 1046' NSL, 2147' WEL, SEC. 09, T11N, R15E, UM i.. VE.'-qjClE]) ).' k..$.,.., "..'... .. s! 10. Well Number At t~tal depth, I" . I, :11[.- t e '-<,.tt ~ 1131 NSL, 2237 WEL, SEC. 09, T11 N, R15E, UM ,,;;.;.¡,;¡¡,~.-.,,.,....,.,,.¿ "",:~~1.;¡' 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool KBE = 51.05' ADL 034631 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 7/23/2002 8/5/2002 8/20/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 9735 8663 FT 9648 8579 FT iii Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, US IT, AIT, HALS, TLD, CNL, AMS-c, Dipole Sonic 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 34" X 20" 94# H-40 35' 110' 42" 260 sx Arctic Set (Approx.) 13-3/8" 68# L-80 34' 5108' 16" 1311 sx Arctic Set III, 600 sx 'G' 9-5/8" 47# L-80 31' 9289' 12-1/4" 618 sx Class 'G' 7" 26# L-80 9175' 9735' 8-1/2" 145 sx Class 'G' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 6 spf MD TVD 9490' - 9560' 8428' - 8495' 9570' - 9630' 8504' - 8562' 25. MD TVD 26. Classification of Service Well Water Injection 7. Permit Number 202-145 8. API Number 50- 029-231 04-00 9. Unit or Lease Name Prudhoe Bay Unit 302-252 PSI-01 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2202' MD 1900' (Approx.) AMOUNT PULLED TUSING RECORD DEPTH SET (MD) 9132' PACKER SET (MD) 9083' SIZE 7-5/8",29.7#, L-80 x 7",26#, L-80 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 135 Bbls of Diesel Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA, .1'" ~.. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core Chi~< t l ~ ~ .~J 27. Date First Production Not on Injection Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR Oll-BSl TEST PERIOD GAs-McF Oil -BSl GAs-McF No core samples were taken. Form 10-407 Rev. 07-01-80 WATER-Bsl WATER-Bsl CHOKE SIZE GAS-Oil RATIO Oil GRAVITY-API (CORR) &~ (' . G\V LR B 0 M S B F L SEP I 6 2002Submit In Duplicate 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Ugnu 1 6572' 5885' West Sak 2 7193' 6411' West Sak 1 7418' 6599' Colville Mudstone 3 7769' 6891' Colville Mudstone 2 8421' 7437' Colville Mudstone 1 8678' 7665' HRZ 9116' 8071' LCU I Top Ivishak I Zone 3 9304' 8250' Zone 2C / BCGL 9371' 8314' Zone 1 9559' 8494' Kavik 9663' 8594' 31. List of Attachments: ( 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. EC i qj ~¿J ,& ljQfwmssmr¡ Summary of Daily Drilling Reports and Post-Rig Work, Surveys 32. I hereby certify thatthe foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~~. ~ Title Technical Assistant Date o9"'lo.o~ PSI-O 1 202-145 302-252 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Rob Tirpack, 564-4166 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: Common Name: Test Date 7/28/2002 7/30/2002 8/4/2002 PSI-01 PSI-01 Test Type FIT FIT FIT TestOepth (TMD) (ft) 5,108.0 (ft) 9,289.0 (ft) BP EXPLORATION Leak..QffTestSummary TesfDepth (TVD) (ft) 4,648.0 (ft) 8,236.0 (ft) AMW (ppg) 9.20 (ppg) 9.00 (ppg) Surface Pressure. Lêak Off Pressure (BMP) (psi) (psi) 677 (psi) 2,898 (psi) 555 (psi) 4,406 (psi) EMW 9.20 (ppg) 12.00 (ppg) 10.30 (ppg) .~ .~ Printed: 8/12/2002 2:49:13 PM (' ( Paget óf11 BP .EXPLOAATION .Qp,réltiøn$....S.ul'Qmaf!'J.........~@R9[t Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-01 PSI-01 DRILL +COMPLETE NABORS NABORS 27ES Start: 7/23/2002 Rig Release: 8/9/2002 Rig Number: Spud Date: 7/23/2002 End: 8/9/2002 7/22/2002 16:00 - 00:00 8.00 MOB P PRE 7/23/2002 00:00 - 04:00 4.00 MOB P PRE 04:00 - 05:00 05:00 - 14:00 1.00 RIGU P 9.00 RIGU P PRE PRE 14:00 - 16:00 2.00 BOPSUR P SURF 16:00 - 18:30 2.50 BOPSURP SURF 18:30 - 19:30 1.00 BOPSURP SURF 19:30 - 20:00 0.50 BOPSUR P SURF 20:00 - 22:00 2.00 BOPSURP SURF 22:00 - 23:00 1.00 BOPSUR P SURF 23:00 - 00:00 1.00 BOPSURP SURF 7/24/2002 00:00 - 00:30 0.50 DRILL P SURF 00:30 - 04:00 3.50 DRILL P SURF 04:00 ... 00:00 20.00 DRILL P SURF 7/25/2002 00:00 ... 08:00 8.00 DRILL P SURF [)e$Criptionof pperations Remove swab valve on PSI-09 and Otis connection from tree cap for clearance to move off well. Pick up cellar. PJSM with Peak pusher and drivers. Move out pump room, door section of pipe shed, motor complex, pits, skate section of pipe shed, and sub. Spot sub on PSI-01. Set mats for pipe shed. Hold Pre-Job Safety Meeting - Spot 1st Section Pipe Shed, Mud Pits, Motor Complex, And Second Section Pipe Shed Hook Up Utilities - Service Lines And Electric Cables Spot Cuttings Tank, Fuel Storage Tank And Power Factor Trailor - Work On Berms Around Rig & Pre-Spud Check List - Spot Cement Silo's And Water Tanks... Nipple Up Diverter System, Flow Lines And Fill Up Lines - Load Pipe Shed With 60 Joints Of 5" Drill Pipe For Top Hole Section *NOTE* Nabors Rig 27E Accepted For Well Work On PSI-01 On Tuesday 07-23-2002 At 10:00 Hours Service Top Drive... Change Out All Grabber Dies - Attach Blower Hose - Change Lube Oil And Filters Hold Pre-Job Safety Meeting - Prepare Rig Floor And Pick Up 60 Joints Of 5" Drill Pipe From Pipe Shed & Stand Back In Mast For Top Hole Section - Drift Pipe As Required *NOTE* Tag Up On Ice At 52' Preform Diverter Function Test - Test Accumulator & Gas Alarms - Witness Of Test Waived By AOGCC Representive Chuck Scheve - Hold "D3" Diverter Drill With All Personal Hold Pre-Spud Meeting With BP Drilling Forman And All Personal Regarding Up Coming Drilling Operation Hold Pre-Job Safety Meeting - Clear Floor For BHA And Bring 16" Tools To Rig Floor - Rig Up Tongs And Floor Equipment... Make Up Bit, Motor, Lead Collar, Stab, Cross Over And Stand Of 5" HWDP Test Mud Line With Air - Fill 20" Conductor With Spud Mud ... Test Mud Line At 1,500 Psi. (Good Test) Break Circulation Spud Well At 23:00 Hours... Drill Ice From 52' To 113' (Conductor Depth) ... Drill 16" Hole To 155' Hold Pre-Job Safety Meeting- Drill Ahead From 155' To 215' POH Stand Back HWDP - Bit, Motor, Lead Collar, Stab... Make Up Steel Drill Collars & Stand Back In Mast... Lay Down Single 5" Drill Pipe And Pick Up Drilling Jars - RIH With Mud Motor - Lay Down Single... Pick Up MWD Tools And Orient Same - Initalize MWD Tool - Pick Up Flex Drill Collars And RIH To 215' Directional Drill Ahead From 215' To 2,138'... Weight On Bit 10K To 50K With Pump Rate At 177 Strokes Or 750 GPM - Off Bottom Pump Pressure At 1350 Psi. & On Bottom Pump Pressure At 1620 Psi. - Top Drive RPM At 90 To 100 - Off Bottom Torque At 4K & On Bottom Torque At 7K ... String Rotating Weight At 140K - With Pump On Drag Up At 148K And Drag Down At 130K Directional Drill Ahead From 2,138' To 2,889'... Weight On Bit 5K To 45K With Pump Rate At 177 Strokes Or 750 GPM... Off Bottom Pump Pressure At 1450 Psi. & On Bottom Pump Pressure At 1750 Psi. - Top Drive RPM At 70 To 80... Off Printed: 8/1212002 2:49:22 PM (' ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-01 PSI-01 DRILL +COMPLETE NABORS NABORS 27ES Start: 7/23/2002 Rig Release: 8/9/2002 Rig Number: Spud Date: 7/23/2002 End: 8/9/2002 7/25/2002 00:00 - 08:00 8.00 DRILL P SURF Bottom Torque At 4K & On Bottom Torque At 10K - String Rotating Weight At 135K - With Pump Off Drag Up At 150K And Drag Down At 135K 08:00 - 09:30 1.50 DRILL P SURF Circulate Bottoms Up And Condition Mud 09:30 - 10:30 1.00 DRILL P SURF Hold Pre-Job Safety Meeting - POH To Drill Collars (NO PROBLEMS) 10:30 -11:30 1.00 DRILL P SURF Service Top Drive, Traveling Blocks, Crown Sheaves 11 :30 - 16:00 4.50 DRILL N RREP SURF Hold Pre-Job Safety Meeting - Inspect Draw Works Drum Clutch (Need Repairs) - POH To 20" Conductor - Change Out Choke In Sperry Sun MWD Pulser Sub - Replace Quick Release Valve On Emsco Draw Works Clutch 16:00 ... 16:30 0.50 DRILL N RREP SURF Remove Twist From Can-Rig Top Drive Blower Hose 16:30 -17:00 0.50 DRILL N RREP SURF Hold Pre-Job Safety Meeting - RIH With 16" Bit And BHA 17:00 - 18:30 1.50 DRILL P SURF RIH (NO PROBLEMS) To 2,795' - Wash Last Stand To Bottom At 2,889' (*NOTE* 15 Foot Of Fill) 18:30 - 00:00 5.50 DRILL P SURF Directional Drill Ahead From 2,889' To 3,639' - Weight On Bit 5K To 50K With Pump Rate At 177 Strokes Or 750 GPM - Off Bottom Pump Pressure At 1600 Psi. & On Bottom Pump Pressure At 2000 Psi. ... Top Drive RPM At 80 - Off Bottom Torque At 9K & On Bottom Torque At 12K - String Rotating Weight At 152K - With Pump Off Drag Up At 170K And Drag Down At 133K 7/26/2002 00:00 - 19:30 19.50 DRILL P SURF Directi()nalDrill Ahead From 3,639' To 5,125' - Weight On Bit 35K To 70K With Pump Rate At 177 Strokes Or 750 GPM - Off Bottom Pump Pressure At 1800 Psi. & On Bottom Pump Pressure At 2400 Psi. - Top Drive RPM At 80 - Off Bottom Torque At 10K & On Bottom Torque At 13K - String Rotating Weight At 175K - With Pump Off Drag Up At 205K And Drag Down At 145K 19:30 ... 21 :00 1.50 DRILL P SURF Circulate Bottoms Up - Rotate And Reciprocate Drill String 21 :00 ... 22:30 1.50 DRILL P SURF Monitor Well Bore (Static) - Hold Pre-Job Safety Meeting - Wiper Trip... POH (Wet) From 5,125' To 2,795' (Last Wiper Trip Depth) Tight At 4,799' ... 4,479' ... 4,007' - 3,289' ... Pull 35K To 65K Above Normal Upward Drag 22:30 - 23:30 1.00 DRILL P SURF RIH From 2,795' To 5,051' - Work Thru Three Areas On Trip In Hole - Make Up Top Drive - Wash Last Stand To Bottom At 5,125' (NO Fill) 23:30 ... 00:00 0.50 DRILL P SURF Circulate Bottoms Up And Condition Mud... Rotate And Reciprocate Drill String 7/27/2002 00:00 - 01 :00 1.00 DRILL P SURF Circulate Bottoms Up ... Rotate And Reciprocate Drill String... 80 Rpm-750 Gpm. 01 :00 - 03:00 2.00 DRILL P SURF Monitor Well Bore (Static) - Hold Pre-Job Safety Meeting ... Pump Dry Job... POH To 2704'. 03:00 ... 03:30 0.50 DRILL P SURF Work Tight Spot 2704' To 2610' (125K Above Normal Upward Drag)'" Connect Top Drive And Back Ream Thru Section 03:30 - 05:00 1.50 DRILL P SURF Continue With Trip Out POH (Wet) From 2,605' To B.H.A. 05:00 ... 08:00 3.00 DRILL P SURF Work BHA Stand Back 5" HWDP And Lay Down (6) 8" Steel Drill Collars Stand Back Flex Drill Collars (SLM .06 Differance) 08:00 - 09:00 1.00 DRILL P SURF Clean and Clear Floor - Make Dummy Run With FMC Flutted Hanger with landing joint. Printed: 8/12/2002 2:49:22 PM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-01 PSI-01 DRILL +COMPLETE NABORS NABORS 27ES Date . Frörrf2Tô. .'HoÜr'Sc'.......TäSk'.' Códê' - NFf"'. .Phâse 7/27/2002 09:00 - 10:30 1.50 CASE P SURF 10:30-11:00 0.50 CASE P SURF 11 :00 - 20:30 9.50 CASE P SURF 7/28/2002 20:30 - 00:00 00:00 - 00:30 SURF SURF 3.50 CASE P 0.50 CASE P 00:30 - 06:00 5.50 CASE P SURF 06:00 - 09:00 3.00 CASE P SURF 09:00 - 12:00 3.00 CASE P SURF 12:00 - 13:30 1.50 CASE P SURF 13:30 - 19:00 5.50 CASE P SURF 19:00 - 22:00 3.00 CASE P SURF 22:00 - 00:00 2.00 CASE P SURF Start: 7/23/2002 Rig Release: 8/9/2002 Rig Number: Spud Date: 7/23/2002 End: 8/9/2002 DesCriptfÔÌ1'of..Oþeråtions Hold Pre-Job Safety Meeting - Remove Short Set Of Elevator Links - Remove Top Drive Clamp & Saver Sub - Hold Pre-Job Safety Meeting - Pick Up And Make Up GBR Franks Fill Up Tool Pick Up Shoe Track And Float Equipment - Fill With Mud To Check Floats Continue To RIH With 124 Joints Of 133/8" 681b. L-80 Casing- Tight At 3,265' To 3,357' - Break Circulation And Wash Thru Area - Continue To RIH With Casing to 5108' Per Program. Circulate And Condition Mud For Cement Job Hold Pre-Job Safety Meeting With All Personal Regarding Upcoming Cement Job - Rig Down Franks Fill-Up Tool-Install Crossover And Dowell Schlumberger Cement Head - Make Up Circulating Lines - Circulate With B.oth Mud Pumps To Verify Operational Shut Down And Turn Over To Dowell - Pump 5 BBLS. Fresh Water - Pressure Test Surface Equipment And Lines To 3,500 Psi. - Shut Down And Drop Bottom Plug - Pump 75 BBLS. 10.2 PPG. Mud Push With Red Dye - Start Pumping 10.7 PPG Lead Cement At 8 BPM - Pump 1,037 BBLS. Of Lead Slurry - Lost Returns Briefly Prior To Mud Push Turning The Corner - Swap To Tail Slurry And Pump A Total Of 125 BBLS. 15.8 PPG Tail Cement - Shut Down And Drop Top Plug - Pump 10 BBLS. Behind Plug - Shut Down And Swap To Rig For Displacement - Pump Rate At 10 BPM With Full Returns - Slow Pump Rate To 2 BPM At 1,100 Psi. - Did Not Bump Plug With 749 BBLS. 9.3 PPG Mud - Bleed Pressure To 0 Psi. - Remove Cement Hose And Check Floats (OK) - Total Cement Volume To Surface 433 BBLS. - Cement In Place At 05:45 Hours. Hold Pre-Job Safety Meeting - Wash Off Casing Tools And Rig Down Same - Remove Long Set Of Bales From Can-Rig Top Drive - Clear Rig Floor - Back Out Landing Joint And Lay Down Same - Flush Flow Line And Diverter Riser Hold Pre-Job Safety Meeting For Simultaneous Operations Regarding Removal Of Draw Works Drum Clutch - Mud Line Union Replaced And Nipple Down Of 16" Diverter Line And 21 1/4" Riser, Annular, And Diverter Spool - Remove From Cellar Area Hold Pre-Job Safety Meeting - Nipple Up FMC Big Bore 5M Split Uni-Head - Test Metal To Metal Seal To 1,000 Psi. For Ten Minutes (Good Test) Hold Pre-Job Safety Meeting -Install 13 5/8 5M BOP Stack And Nipple Up BOP And Related Equipment Hold Pre-Job Safety Meeting - Install FMC Lower Test Plug And Rig Up To Test Bop Equipment - Witness Of BOP Test Waived By AOGCC Inspector Chuck Scheve - Attempt To Test Blind Rams And Choke Manifold At 250 Psi. Low And 4,000 Psi. High - Test Failed Leaking By Blind Shear Rams - Bleed Preasure To 0 Psi. Hold Pre-Job Safety Meeting - Place Blind Shear Rams In Neutral Position - Open Up Blind Ram Doors - Remove And Printed: 8/1212002 2:49:22 PM (' ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-01 PSI-01 DRILL +COMPLETE NABORS NABORS 27ES Start: 7/23/2002 Rig Release: 8/9/2002 Rig Number: Spud Date: 7/23/2002 End: 8/9/2002 7/28/2002 22:00 - 00:00 2.00 CASE P SURF Change Out For Regular Set Of Blind Rams - Test Choke Manifold Manual Valves At 250 Psi. Low And 4,000 Psi. High 7/29/2002 00:00 - 02:00 2.00 DRILL N RREP INT1 Hold Pre-Job Safety Meeting - Remove And Change Out Blind Shear Rams For Regular Set Of Blind Rams 02:00 - 03:00 1.00 DRILL P INT1 Hold Pre-Job Safety Meeting - Test Blind Rams, Manual And HCR Valves On Choke And Kill Lines At 250 Psi. Low And 4,000 Psi. High 03:00 - 10:00 7.00 DRILL N RREP INT1 Hold Pre-Job Safety Meeting - Change Out 752 Traction Motor On Can-Rig Top Drive And Function Test 10:00 - 12:30 2.50 DRILL P INT1 Hold Pre-Job Safety Meeting - Nipple Up Riser On BOP Stack - Install Flow Line And Fill Up Lines - Make Up Turnbuckles - Install Mouse Hole - Pick Up Tools And Extra Parts Around Celler And Rig Floor 12:30 - 13:00 0.50 DRILL P INT1 Hold Pre-Job Safety Meeting - Install FMC Lower Test Plug And Rig Up To Test Bop Equipment 13:00 - 15:00 2.00 DRILL P INT1 Hold Pre-Job Safety Meeting - Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector Chuck Scheve - Test Annular At 250 Psi. Low And 3,500 Psi. High - Test Upper And Lower Pipe Rams, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 4,000 Psi. High - Test Pit PVT System And H2S And LEL Detectors - Perform Accumulator Test 15:00 - 16:00 1.00 DRILL P INT1 Rig Down Testing Equipment - Remove Test Plug -Install Long Bowl Protector 16:00 - 18:00 2.00 DRILL P INT1 Hold Pre-Job Safety Meeting - Install Lower Valve And Clamp On Can-Rig Top Drive - Install Short Set Bales And 5" Drill Pipe Elevators - Install Blower Hose On Top Drive 18:00 - 19:30 1.50 DRILL P INT1 Inspect Top Drive And Service - Grease Traveling Blocks And Crown Sheaves - Install High Pressure Mud Line 19:30 - 20:00 0.50 DRILL P INT1 Bring BHA NO.2 - Bit And Tools To Rig Floor 20:00 - 22:30 2.50 DRILL P INT1 Hold Pre-Job Safety Meeting - Pick Up And Make Up 121/4" PDC Bit And BHA NO.2 - Orient MWD/LWD Tools And Initialize Same 22:30 - 23:00 0.50 DRILL P INT1 Pick Up Flex Drill Collars, 5" HWDP, Drilling Jars From Mast And RIH 23:00 - 00:00 1.00 DRILL P INT1 Hold Pre-Job Safety Meeting - Pick Up And Rabbit 49 Joints Of 5" Drill Pipe And RIH 7/30/2002 00:00 - 02:00 2.00 DRILL P INT1 Hold Pre-Job Safety Meeting - Cut And Slip 1 3/8" Drilling Line - Adjust Draw Works Mechanical Brakes 02:00 - 02:30 0.50 DRILL P INT1 Break Circulation Test High Pressure Mud Line At 4,000 Psi. (Test Good) 02:30 - 05:30 3.00 DRILL P INT1 Continue To Pick Up (Drill Pipe For Next Two Hole Sections) And Rabbit Total Of 140 Joints 5" Drill Pipe - RIH Tag Cement Stringers At 4,930' *NOTE* Hold Kick While Tripping Drill 05:30 - 07:00 1.50 DRILL P INT1 Hold Pre-Job Safety Meeting -Break Circulation And Prepare For Casing Test - Test 13 3/8" Casing To 3,500 Psi. For 30 Minutes While Recording On Circle Chart 07:00 - 07:30 0.50 DRILL N RREP INT1 Repair Can-Rig Top Drive - Pipe Grabber Sticking - Trouble Shoot And Repair 07:30 - 10:30 3.00 DRILL P INT1 Drill Cement Stringers From 4,930' To 5,023' (Top Of Wiper Printed: 8/12/2002 2:49:22 PM PageS of 11 Legal Well Name: PSI-01 Common Well Name: PSI-01 Spud Date: 7/23/2002 Event Name: DRILL +COMPLETE Start: 7/23/2002 End: 8/9/2002 Contractor Name: NABORS Rig Release: 8/9/2002 Rig Name: NABORS 27ES Rig Number: Date From - To HourS. . TaSk COde NPT Phase DèSCriptionof Operations 7/30/2002 07:30 - 10:30 3.00 DRILL P INT1 Rubbers) - Drill Wiper Rubbers And Tag Float Collar At 5,025' - Continue To Drill Float Collar And Cement In Shoe Track To Top Of Float Collar At 5,106' - Drill Float Shoe To 5,108' - Wash And Ream 16" Rat Hole From 5,108' To 5,125' - Drill New 121/4" Hole From 5,125' To 5,145' *NOTE* Displace To 9.2 PPG LSND Mud System While Drilling Shoe Track 10:30 - 11 :30 1.00 DRILL P INT1 Hold Pre-Job Safety Meeting - Circulate And Condition Mud - Finish Getting 9.2 PPG Mud Around - Pull Bit In 13 3/8" Casing Shoe Closed Pipe Rams And Performed FIT. Strokes Pmp'd Pressure 5 251 psi 10 388 psi 15 550 psi 20 659 psi 22 677 psi Held Test F/10 minutes w/107 Psi. Pressure Loss. MW 9.2 ppg, Csg Shoe TVD 4,648' Pressure 677 psi = 12.0 ppg EMW. Bleed Pressure To 0 Psi. - Opened Pipe Rams. 11 :30 - 12:00 0.50 DRILL P INT1 Preform Sperry Sun PWD Base Line Test 12:00 - 12:30 0.50 DRILL P INT1 Service Top Drive 12:30 - 00:00 11.50 DRILL P INT1 Drill Ahead From 5,145' To 6,549' - Weight On Bit 5K To 20K With Pump Rate At 201 Strokes Or 850 GPM - Off Bottom Pump Pressure At 2350 Psi. & On Bottom Pump Pressure At 2500 Psi. - Top Drive RPM At 60 To 80 - Off Bottom Torque At 9K & On Bottom Torque At 12K - String Rotating Weight At 185K - With Pump Off Drag Up At 215K And Drag Down At 165K 7/31/2002 00:00 - 00:00 24.00 DRILL P INT1 Drill Ahead From 6,549' To 8,613' - Weight On Bit 5K To 20K With Pump Rate At 199 Strokes Or 841 GPM - Off Bottom Pump Pressure At 2500 Psi. & On Bottom Pump Pressure At 2850 Psi. - Top Drive RPM At 80 To 110 - Off Bottom Torque At 15K & On Bottom Torque At 20K - String Rotating Weight At 220K - With Pump Off Drag Up At 250K And Drag Down At 192K *NOTE* Veco Drilling Conductor Hole For PSI-1 0 8/1/2002 00:00 - 06:30 6.50 DRILL P INT1 Drill Ahead From 8,613' To 8,897' - Weight On Bit 15K - With Pump Rate At 199 Strokes Or 841 GPM - Off Bottom Pump Pressure At 2900 Psi. & On Bottom Pump Pressure At 3100 Psi. - Top Drive RPM At 110 - Off Bottom Torque At 15K & On Bottom Torque At 21 K - String Rotating Weight At 225K - With Pump Off Drag Up At 275K And Drag Down At 185K 06:30 - 08:00 1.50 DRILL P INT1 Circulate And Condition Mud Get A Good 10.3 PPG Mud Around - Record New Slow Pump Rates - Pump Sweep While Rotating And Reciprocating Drill String - Maximum Gas Seen 54 Units Printed: 8/1212002 2:49:22 PM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-01 PSI-01 DRILL +COMPLETE NABORS NABORS 27ES Start: 7/23/2002 Rig Release: 8/9/2002 Rig Number: Spud Date: 7/23/2002 End: 8/9/2002 8/1/2002 08:00 - 10:30 2.50 DRILL P INT1 Hold Pre-Job Safety Meeting - Monitor Well Bore (Static)- POH With 10 Stands 5" Drill Pipe - Pump Dry Job - Continue To POH With 5" Drill Pipe To 133/8" Casing Shoe With No Tight Hole Problems 10:30 - 11 :00 0.50 DRILL P INT1 Hold Pre-Job Safety Meeting - Service Can-Rig Top Drive - Tum Stand Pipe 11 :00 - 13:00 2.00 DRILL P INT1 Hold Pre-Job Safety Meeting - RIH From 133/8" Casing Shoe To 8,802' With No Problems - Connect Can-Rig Top Drive And Break Circulation - Wash Last Stand To Bottom At 8.897' (No Fill) 13:00 - 14:00 1.00 DRILL P INT1 Drill Ahead From 8,897' To 8,975' 14:00 - 14:30 0.50 DRILL P INT1 Circulate Out Air From Trip - Monitor Well (Static) 14:30 - 17:00 2.50 DRILL P INT1 Drill Ahead From 8,975' To 9,020' 17:00 - 17:30 0.50 DRILL N RREP INT1 Repair Valve Cap Guide On Number 2 Continental Emsco Mud Pump 17:30 -19:30 2.00 DRILL P INT1 Drill Ahead From 9,020' To 9,275' 19:30 - 20:30 1.00 DRILL N RREP INT1 Change Swab On Number 1 Continental Emsco Mud Pump 20:30 - 21 :00 0.50 DRILL P INT1 Drill Ahead From 9,275' To 9,300' (9 5/8" Casing Setting Point) 21 :00 - 22:00 1.00 DRILL P INT1 Circulate Sweep Around While Rotating And Reciprocating Drill String 22:00 - 22:30 0.50 DRILL P INT1 Hold Pre-Job Safety Meeting - Wiper Trip From 9,300' To 8,810' With No Problems 22:30 - 00:00 1.50 DRILL P INT1 Circulate Bottoms Up While Rotating And Reciprocating Drill String - Prepare To Spot Lube-Tex Pill 8/2/2002 00:00 - 00:30 0.50 DRILL P INT1 Circulate While Rotating And Reciprocating Drill String - Monitor Well Bore (Static) - Spot 5% Lube-Tex Pilll Thru HRZ Formation 00:30 - 05:00 4.50 DRILL P INT1 Hold Pre"Job Safety Meeting - POH 10 Stands 5" Drill Pipe To 8,324'(No Problems) - Connect Top Drive And Break Circulation - Pump Dry Job - Continue To POH With 5" Drill Pipe (SLM) Monitor Well At 13 3/8" Casing Shoe And Remove T()p Drive Blower Hose - POH To BHA 05:00 - 06:00 1.00 DRILL P INT1 Stand Back 5" HWDP - Hold Pre-Job Safety Meeting - Lay Down Drilling Jars And Flex Drill Collars 06:00 - 07:00 1.00 DRILL P INT1 Flush Smart Iron And Mud Motor With Fresh Water - Down Load Sperry Sun MWD Tool And Lay Down Same - Drain Motor And Break Break Off PDC Bit - Lay Down Motor 07:00 - 07:30 0.50 DRILL P INT1 Clear Rig Floor Of 121/4" Drilling Tools And Equipment 07:30 - 08:00 0.50 CASE P INT1 Rig Up And Pull Wear Ring - Install Lower FMC Test Plug 08:00 - 09:30 1.50 CASE P INT1 Hold Pre-Job Safety Meeting,. Open Doors On Top BOP Gate And Remove Ram Blocks And Change To 9 5/8" - Close Doors 09:30 ,. 10:00 0.50 CASE P INT1 Test Door Seals To 3,500 Psi. - Pull Test Plug And Lay Down Test Joint 10:00 -12:00 2.00 CASE P INT1 Hold Pre-Job Safety Meeting,. Remove Short Set Of Elevator Links - Pick Up And Make Up GBR Franks Fill Up Tool - Install Long Set Of Elevator Links And 350 Ton Elevators - Make Dummy Run With FMC Flutted Hanger With Landing Joint - Load Cement Head With Top And Bottom Plugs 12:00 - 20:00 8.00 CASE P INT1 Hold Pre-Job Safety Meeting - Pick Up 9 5/8" Shoe Track And Float Equipment - Fill With Mud To Check Floats - Continue To RIH With 124 Joints Of 95/8" 471b. L-80 Casing Per Program To 13 3/8" Casing Shoe (5,075') Printed: 8/12/2002 2:49:22 PM ( ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-01 PSI-01 DRILL +COMPLETE NABORS NABORS 27ES Fmm-Tô. Hours .TâSk. êóde NPT PhaSe 12:00 - 20:00 8.00 CASE P INT1 20:00 - 21 :00 1.00 CASE P INT1 21 :00 - 00:00 3.00 CASE P INT1 00:00 - 01 :30 1.50 CASE P INT1 8/212002 8/3/2002 01 :30 - 02:00 0.50 CASE P INT1 02:00 - 02:30 0.50 CEMT P INT1 02:30 - 04:00 1.50 CEMT P INT1 04:00 - 06:00 2.00 CEMT P INT1 06:00 - 07:30 1.50 CEMT P 07:30 - 08:30 1.00 DRILL P INT1 PROD1 08:30 - 10:00 1.50 DRILL P PROD1 10:00 -11:00 1.00 DRILL P PROD1 11 :00 - 15:00 4.00 DRILL P PROD1 Start: 7/23/2002 Rig Release: 8/9/2002 Rig Number: Spud Date: 7/23/2002 End: 8/9/2002 DeScription of OperatiOns. Break Circulation - Stage Up Pump Rate To 9 BPM - Circulate One Casing Volume Continue To RIH With 192 Joints Of 95/8" 471b. L-80 Casing Per Program With (NO LOSSES) Hold Pre-Job Safety Meeting - Continue To RIH With 225 Joints Of 9 5/8" 471b. L-80 Casing Per Program With (NO LOSSES) - Make Up FMC Flutted Hanger And Landing Joint - Stab In Franks Fill Up Tool And Break Circulation - Circulate Landing Joint To Bottom At 9,289' And Land Hanger (20' Fill) Stage Up Pump Rate To 6 BPM - Clear Personal From Rig Floor While Reciprocating Casing Up Weight At 480K And Down Weight At 275K - Flutted Hanger Caught In Lower Gate On BOP Weight Indicator At 525K Discontinue Reciprocation At This Point - Land 9 5/8" Casing - Circulate And Condition Mud Hold Pre-Job Safety Meeting - Shut Down Mud Pumps - Rig Down Franks Casing Fill Up Tool - Install Cement Head Adaptor And Cement Head - Make Up Circulation Hose Continue To .Circulate And Condition Mud Stage Up Pump Rate To 9.5 BPM At 900 Psi. With Two Mud Pumps - Hold Pre-Job Safety Meeting Regarding Up Coming Cement Job With All Personal- Batch Mix 50 BBLS. 12.0 PPG Mud Push And 132BBLS. 15.8 PPG Class "G" Gasblock Cement - Condition Mud And Reduce Volume In Mud System Pump With Both Rig Pumps And Shut Down And Turn Over To Dowell- Pump 10 BBL. CW-100 - Test Lines At 3,500 Psi. - Pump 70 BBLS. CW-100 - Pump 50 BBLS. 12 PPG. Mud Push - Drop Bottom Plug - Pump 132 BBLS. Batch Mixed 15.8 PPG Class "G" GASBLOCK Tail Cement Slurry At 6 BPM - Drop Top Plug - Flush Dowell Cement Lines With 10 BBLS. Water - Shut Down And Swap To Rig Pumps For Displacement - Displace With 664 BBLS. Of 10.3 PPG Mud At 12 BPM - Slow Pumps To 2 BPM And Bump Plug With 500 Psi. Above Final Circulation Pressure - Bleed Pressure To 0 Psi. And Check Floats (Floats OK) - Cement In Place At 06:00 Hours Hold Pre-Job Safety Meeting - Rig Down Dowell Cement Head - Back Out 9 5/8" Landing Joint And Lay Down Same - Rig Down Casing Tools And Clear Rig Floor Hold Pre-Job Safety Meeting - Change Bales To Short Set- Pick Up 5" Drill Pipe Elevators - Latch Up Stand Of 5" HWDP And Install 9 5/8" Pack Off - Test At 5,000 Psi. For 10 Minutes (Test Good) Hold Pre-Job Safety Meeting - Open Doors On Top BOP Gate And Remove Ram Blocks And Change To 4 1/2" X 7" Variables - Close Doors Hold Pre-Job Safety Meeting - Install Upper Test Plug And Rig Up Testing Equipment - Flush Mud Lines With Water Hold Pre-Job Safety Meeting - Witness Of BOP Test Waived By AOGCC Inspector John Crisp - Test Annular At 250 Psi. Low And 3.500 Psi. High - Test Upper And Lower Pipe Rams, Blind Rams, Choke Manifold, Floor Safety Valve, Dart Valve. Top Drive Upper And Lower IBOP Valves, Manual And HCR Printed: 8/1212002 2:49:22 PM (' ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-01 PSI-01 DRILL +COMPLETE NABORS NABORS 27ES Start: 7/23/2002 Rig Release: 8/9/2002 Rig Number: Spud Date: 7/23/2002 End: 8/9/2002 Date Frôrff ..To HOÙrsiTâSf( COde- <NÞT 'PhaSé' "DèSêriptionofOþerations 8/3/2002 11 :00 - 15:00 4.00 DRILL P PROD1 Valves On The Choke And Kill Lines At 250 Psi. Low And 4,000 Psi. High - Test Pit PVT System And H2S And LEL Detectors - Perform Accumulator Test 15:00 -16:00 1.00 DRILL P PROD1 Rig Down Testing Equipment - Remove Test Plug - Install Short Bowl Protector And Energize Lock Down Studs 16:00 - 20:00 4.00 DRILL P PROD1 Hold Pre-Job Safety Meeting - Bring BHA NO.3 - Bit And Tools To Rig Floor - Pick Up And Make Up 8 1/2" Bit And BHA - Orient MWD/LWD Tools And Initialize Same - Hold Pre-Job On Radioactive Source - Install Source And RIH 20:00 - 00:00 4.00 DRILL P PROD1 RIH With BHA NO.3 And 5" Drill Pipe From Mast To 9,100'- Break Circulation And Fill Drill String Every 30 Stands During Trip. *NOTE* Hold Pre-Job Safety Meeting - While Making Trip In Hole Rig Up And Pumped Down 13-3/8" x 9-5/8" Annulus Established Injectivity Rate At 2 BPM With 1,350 Psi. - Rig Up Little Red - Test Lines To 2,500 Psi. Bull Head 133 BBLS. Of Dead Crude Oil Down Annulus To Freeze Protect 8/4/2002 00:00 - 00:30 0.50 DRILL P PROD1 Connect Top Drive And Establish Circulation At 9,108' 00:30 - 01 :30 1.00 DRILL P PROD1 Hold Pre-Job Safety Meeting - Test 9 5/8" Casing At 3,500 Psi. For 30 Minutes 01 :30 - 02:30 1.00 DRILL P PROD1 Tag Casing Wiper Rubbers At 9,200' - Drill Wiper Rubbers And Tag Float Collar At 9,202' - Drill Cement To 9,240' 02:30 - 04:00 1.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - Swap Out Mud System To 9.0 PPG BaradrilN Mud - Clean Possom Belly And Under Shakers 04:00 - 05:00 1.00 DRILL P PROD1 Continue To Drill Cement And Tag Top Of Float Shoe At 9,287' (Bottom At 9,289') - Wash And Ream 121/4" Rat Hole From 9,289' To 9,300' - Drill 8 1/2" New Hole To 9,320' 05:00 - 05:30 0.50 DRILL P PROD1 Circulate Bottoms Up - Verify 9.0 PPG Mud In And Out 05:30 - 06:00 0.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - Pull Bit In 9 5/8" Casing Shoe Closed Pipe Rams And Performed FIT. Strokes Pmp'd Pressure 2 169 psi 4 261 psi 6 361 psi 8 443 psi 10 534 psi 11 555 psi Held Test F/10 minutes wI 57 Psi. Pressure Loss. MW 9.0 ppg, Csg Shoe TVD 8,236' Pressure 555 psi = 10.3 ppg EMW. Bleed Pressure To 0 Psi. - Open Pipe Rams 06:00 - 00:00 18.00 DRILL P PROD1 Obtain Slow Pump Rates With New 9.0 PPG Mud - Drill Ahead From 9,320' To 9,700' - Weight On Bit 20K To 25K - With Pump Rate At 131 Strokes Or 554 GPM - Off Bottom Pump Pressure At 2000 Psi. & On Bottom Pump Pressure At 2265 Psi. - Top Drive RPM At 65 - Off Bottom Torque At 15K & On Bottom Torque At 16K - String Rotating Weight At 215K - With Pump Off Drag Up At 305K And Drag Down At 170K Printed: 8/1212002 2:49:22 PM ( ( Legal Well Name: PSI-01 Common Well Name: PSI-01 Spud Date: 7/23/2002 Event Name: DRILL +COMPLETE Start: 7/23/2002 End: 8/9/2002 Contractor Name: NABORS Rig Release: 8/9/2002 Rig Name: NABORS 27ES Rig Number: -eate From :To HoUrS-Task Code. NPT .Phase Description ofOperatio"s 8/4/2002 06:00 - 00:00 18.00 DRILL P PROD1 Top Of Zone 3 (Sadlerochet /Ivishak) At 9,308' Measured Depth 8/5/2002 00:00 - 01 :00 1.00 DRILL P PROD1 Continue To Drill Ahead To 9,735' TD For 81/2" Hole- Circulate Bottoms Up - Monitor Well Bore (Static) - Spot Logging Pill In Open Hole 01 :00 - 02:00 1.00 DRILL P PROD1 Pump Up Survey - Circulate Bottoms Up - Monitor Well Bore (Static) - Spot Logging Pill In Open Hole 02:00 - 02:30 0.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - POH Slow To 9 5/8" Casing Shoe (9,289') With "NO" Problems 02:30 - 03:30 1.00 DRILL P PROD1 Monitor Well Bore (Static) - Pump Dry Job - Drop Rabbit With Slick Line Tail Attached - Dry Job Didn't Take Pump Down Rabbit And Pull Two More Stands To Allow Dry Job To Fall (NO Good) - Mix Second Dry Job And Pump 03:30 - 07:00 3.50 DRILL P PROD1 Blow Down Top Drive - POH With 5" Drill Pipe Stand Back In Mast 07:00 - 08:00 1.00 DRILL P PROD1 Stand Back 5" HWDP - Hold Pre-Job Safety Meeting - Lay Down Drilling Jars And Flex Drill Collars 08:00 - 08:30 0.50 DRILL P PROD1 Hold Pre-Job Safety Meeting - Remove Radio Active Sources 08:30 - 10:30 2.00 DRILL P PROD1 Down Load Sperry Sun MWD Tools - Pull Pulser - Lay Down MWD Tools - Drain Mud Motor - Break Off 8 1/2" Bit - Lay Down Motor - Clear Rig Floor 10:30 - 11 :30 1.00 EVAL P PROD1 Ho.ld Pre-Job Safety Meeting - Rig Up Schlumberger - Make Up USIT Tool And Test Same 11 :30 - 16:00 4.50 EVAL P PROD1 RIH With Schlumberger Wire Line And US IT Tools (Run No.1) - Log With USIT Tool From 9,289' To 7,000' For Cement Bond Quality - Top Of Cement At 7,220' - POH And Lay Down Logging Tools 16:00 - 18:00 2.00 EVAL P PROD1 Pick Up And Make Up Logging Tools (Run No.2) - BHC-Sonic-Lateral Caliper Tools RIH To 9,734' Wire Line Measurement - Tool Failed 18:00 - 21 :30 3.50 EVAL N DFAL PROD1 POH With Wire Line Tools - Change Out Tools And RIH (Run No.3) 21 :30 - 23:00 1.50 EVAL P PROD1 Log From 9,734 Wire Line Measurement To 9,289' - POH With Wire Line 23:00 - 00:00 1.00 EVAL P PROD1 Clean Off Wire Line Tools And Lay Down Same - Rig Down Schlumberger - Clear Rig Floor 8/6/2002 00:00 - 00:30 0.50 CASE P PROD1 Continue to RU for 7" liner. 00:30 - 02:30 2.00 CASE P PROD1 PJSM. PU 7" liner. Check floats. Fill every 5 joints. 02:30 - 03:00 0.50 CASE P PROD1 Change elevators. Pick up liner hanger, liner top packer, and one stand of DP. Circulate one liner volume. Liner wt: 20K. 03:00 - 08:30 5.50 CASE P PROD1 RIH with liner on stands of 5" DP to 9,252'. Fill every 10 stands. 08:30 - 10:30 2.00 CASE P PROD1 Circulate and condition mud at 9 5/8" casing shoe at 6 bpm, 600 psi. PU=235K, SO=190K. RU cement head while circulating. 10:30 - 11 :30 1.00 CASE P PROD1 RIH with 5 stands of DP. MU cement head. 11 :30 - 12:30 1.00 CASE P PROD1 Circulate down at 2 bpm, 500 psi. Tag bottom at 9,735'. Stage up pump rate to 5 bpm, 600 psi. Circulate and condition mud. 12:30 - 13:30 1.00 CEMT P PROD1 Pump 5 bbls ofCW-100. Test lines to 4,000 psi. Pump 25 bbls of CW-100, 30 bbls 10 ppg mud push spacer, 32 bbls 15.8 ppg class G cement with latex. Drop plug. Displace with rig pumps. Bump plug. CIP 13:30. Printed: 8/1212002 2:49:22 PM ( ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-01 PSI-01 DRILL +COMPLETE NABORS NABORS 27ES Start 7/23/2002 Rig Release: 8/9/2002 Rig Number: Spud Date: 7/23/2002 End: 8/9/2002 8/6/2002 13:30 -14:00 0.50 CASE P PROD1 Bump plug to 3,500 psi to set liner hanger. Slack off 75K to set liner top packer while pumping 5 bpm. Rotate and slack off to ensure packer is set. 14:00 - 15:00 1.00 CEMT P PROD1 Circulate out 15 bbls of cement off top of liner. 15:00 - 16:00 1.00 CEMT P PROD1 RD cement head and equipment. 16:00 - 19:30 3.50 CASE P PROD1 Pump dry job and POH. 19:30 - 20:00 0.50 CASE P PROD1 LD liner running tool and RU floor to PU 3.5" HWDP. 20:00 - 22:00 2.00 CASE P PROD1 PU 3.5" HWDP. 22:00 - 00:00 2.00 CASE P PROD1 RIH w/ 5" DP from derrick. 8n /2002 00:00 - 03:00 3.00 CASE P PROD1 Continue to RIH with 7" and 9 5/8" casing scrapers. Tag landing collar at 9,648'. 03:00 - 06:30 3.50 CASE P PROD1 Circulate and spot trucks for displacement. Flush pumps and mud lines with water. Pump 50 bbl caustic wash, 50 bbl dirt magnet, 25 bbl hi vis sweep, followed by seawater until obtaining 65 NTU. 06:30 - 07:30 1.00 CASE P PROD1 RU and pressure test casing to 4,000 psi for 30 minutes. 07:30 - 10:30 3.00 CASE P PROD 1 Pump dry job and POH. Stand 29 stands in derrick and LD other. 10:30 - 12:00 1.50 CASE P PROD 1 Slip and cut drilling line. Adjust brakes. 12:00 - 14:00 2.00 CASE P PROD1 LD5" DP. 14:00 - 15:30 1.50 CASE N RREP PROD1 Work on pipe skate. 15:30 - 19:00 3.50 CASE P PROD1 Continue to LD 5" DP and 31/2" HWDP. 19:00 - 19:30 0.50 RUNCOIVP COMP Clear floor. Pull wear bushing. 19:30 - 21 :00 1.50 RUNCOI\tP COMP RU to run completion. 21:00 - 00:00 3.00 RUNCOfvP COMP PJSM. Run 7" tail pipe assembly. Change to 7 5/8" handling equipment. Run 7 5/8", 29.7#, L-80, IPC, ST-L tubing. 8/8/2002 00:00 - 07:00 7.00 RUNCOI\tP COMP PJSM with Grant-Prideco rep. and Nabors casing hand. Continue to run 7 5/8",29.7#, L-80, ST-L, IPC tubing. 07:00 - 08:30 1.50 RUNCO~ RREP COMP Segment broke in elevators. Replace elevators. Dress elevators for 7 5/8". 08:30 - 16:30 8.00 RUNCOI\tP COMP Continue to run tubing. 16:30 - 18:00 1.50 RUNCOI\P COMP RU to set packer. Pressure up to 1,000 psi and hold pressure for 5 minutes. Pressure up to 1,750 and hold for 10 minutes. Slack off 30K Ibs. Pressure up to 2,000 psi and hold for 1 minutes. Pressure up to 2,500 psi and hold for 15 minutes. Bleed down tubing to 0 psi and pressure test annulus to 1,000 psi for 15 minutes. Witness of test waived by John Spaulding of AOGCC. 18:00 -18:30 0.50 RUNCOI\ P COMP Pick up and shear PBR. PBR sheared at 110,000 Ibs over pull. 18:30 - 20:30 2.00 RUNCOI\P COMP LD spaceout joints. RD casing equipment. Pick up tubing hanger and RU to reverse circulate. 20:30 - 21 :30 1.00 RUNCOI\P COMP Reverse circulate seawater with corrosion inhibitor at 3 bpm. 21 :30 - 23:30 2.00 RUNCOI\ P COMP RULittle Red hot oil. Test lines to 3,500 psi. Pump 135 bbls of diesel down IA at 3 bpm, 750 psi. Let U-tube into tubing. 23:30 - 00:00 0.50 RUNCOI\tP COMP Land tubing. RILDS. 8/9/2002 00:00 - 00:30 0.50 RUNCOIVP COMP Continue to RILDS. RU to test tubing and casing. 00:30 - 02:00 1.50 RUNCOI\ P COMP Pressure test tubing to 4,000 psi for 30 minutes. Bleed tubing pressure to 2,500 psi. Test annulus to 4,000 psi for 30 minutes. Bleed pressure to zero. RD testing equipment. 02:00 - 03:00 1.00 RUNCOI\ P COMP Back out landing joint. Install TWC. Flush diesel from stack. Test TWC to 1000 psi. 03:00 - 03:30 0.50 RUNCOI\P COMP Blow down mud lines. Clean out rotary table with guzzler. 03:30 - 06:00 2.50 RUNCOIVP COMP ND choke and kill lines. Remove turnbuckles and attach Printed: 8/1212002 2:49:22 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-01 PSI-01 DRILL +COMPLETE NABORS NABORS 27ES Start: 7/23/2002 Rig Release: 8/9/2002 Rig Number: Spud Date: 7/23/2002 End: 8/9/2002 8/9/2002 03:30 - 06:00 06:00 - 09:00 2.50 RUNCO,., 3.00 RUNCOI\P COMP COMP slings. ND flow line. ND BOP, set back and secure. Clean well head and install SBMS seal sleeve in adapter flang. Nipple up adapter flange and tree. Pressure test seals to 5,000 psi. Fill tree and test to 5,000 psi. Pull TWC. Set BPV. Remove swab valve from tree. Clean cellar. Release rig at 10:00 on 8/9/02. 09:00 - 10:00 1.00 RUNCOM> COMP Printed: 811212002 2:4.9:22 PM Well: Field: API: Permit: ( PSI-01 Prudhoe Bay Unit 50-029-23104-00 202-145 Rig Accept: 07/23/02 Rig Spud: 07/23/02 Rig Release: 08/09/02 Drilling Rig: Nabors 27E POST RIG WORK 08/18/02 PULL BPV. PULLED BALL & ROD. PULLED 41/2" "RHC-M" PLUG BODY. PULLED 7" "RBX" NIPPLE REDUCER. DRIFTED TO 9,653' CORRECTED DEPTH WI 11' X 2.50 DUMMY GUN (HARD BOTTOM) SAMPLE BAILER FULL OF CEMENT, SAMPLE TURNED IN TO BP. 08/20/02 LOG TEMPI PRESS DOWN FROM 9000' TO 9644' (TD) @ 40 FPM. LOG JEWELRY PASS FROM 9644' TO 9000'. TT @ 9130' ELM. PERFORATE 9570'-9630' IN TWO RUNS WITH 3 318"PJ (3406 HMX), 6 SPF, 60 DEG PHASE. WHP REMAINED 0 PSI. SWS TO RE-HEAD AND CONTINUE IN THE AM. 08/21/02 PERFORATE 9490'-9560' IN THREE RUNS WITH 3 3/8"PJ (3406 HMX), 6 SPF, 60 DEG PHASE. ALL SHOTS FIRED. WHP REMAINED 0 PSI (WELL ON VACUUM). PERFORMED SBHPS AT 9000' (8438' SS) FOR -1HR. PRESSURE DROPPED FROM 3150.5 PSI TO 3147.5 PSI DURING SURVEY. TEMP REMAINED 151 DEG. NOTIFY DSO AT DEPARTURE. WELL SHUT IN & SECURED. 19-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well PSI-01 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00 I MD I M D (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~~-/V5 DEF NT VE North Slope Alaska BPXA Lisburne PSI (East Dock), Slot PSI slot A PSI-01 Job No. AKZZ22123, Surveyed: 5 August, 2002 -- SUR VE Y R E PO R T 19 August, 2002 Your Ref: API 500292310400 Surface Coordinates: 5966097.64 N, 707827.02 E (700 18' 38.6942- N, 1480 18' 56.7668- W) Kelly Bushing: 51.05ft above Mean Sea Level -< SP&!¡.'."."'.'y-su., DAIL-LING SERVices A Halliburton Company Survey Ref: svy11254 Sperry-Sun Drilling Services . Survey Report for PSI-01 Your Ref: API 500292310400 Job No. AKZZ23104, Surveyed: 5 August, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°11 OOft) 0.00 0.000 0.000 -51.05 0.00 0.00 N O.OOE 5966097.64 N 707827.02 E 0.00 AK-6 BP IFR-AK -, 203.00 0.230 246.840 151.95 203.00 0.168 0.37W 5966097.4 7 N 707826.65 E 0.113 0.17 292.39 0.780 272.060 241.34 292.39 0.218 1.15W 5966097.40 N 707825.88 E 0.649 0.72 386.03 1.060 262.460 334.96 386.01 0.308 2.64W 5966097.27 N 707824.39 E 0.340 1.77 474.79 1.060 269.410 423.71 474.76 0.42 8 4.28W 5966097.11 N 707822.76 E 0.145 2.92 563.35 1.050 271.610 512.25 563.30 0.40 8 5.91 W 5966097.08 N 707821.13 E 0.047 4.15 657.37 1.050 268.450 606.26 657.31 0.40 8 7.63W 5966097.03 N 707819.40 E 0.062 5.43 744.07 0.880 265.910 692.95 744.00 0.47 8 9.09W 5966096.92 N 707817.95 E 0.202 6.48 844.77 0.990 272.450 793.63 844.68 0.49 8 10.73 W 5966096.86 N 707816.31 E 0.152 7.69 937.12 1.970 298.100 885.95 937.00 0.29N 12.93 W 5966097.58 N 707814.09 E 1.256 9.85 1033.07 3.440 315.160 981.79 1032.84 3.11 N 16.41 W 5966100.30 N 707810.53 E 1.730 14.33 1126.94 4.070 319.060 1075.46 1126.51 7.63N 20.58 W 5966104.69 N 707806.24 E 0.724 20.44 1219.53 4.150 321.710 1167.81 1218.86 12.74 N 24.81 W 5966109.69 N 707801.87 E 0.223 27.00 1314.68 4.780 317.290 1262.67 1313.72 18.35 N 29.63 W 5966115.17 N 707796.89 E 0.754 34.34 1405.60 6.620 317.150 1353.14 1404.19 24.98 N 35.77 W 5966121.62 N 707790.58 E 2.024 43.32 1501.94 7.420 317.940 1448.76 1499.81 33.67 N 43.71 W 5966130.09 N 707782.39 E 0.836 55.03 1594.21 6.890 319.270 1540.31 1591.36 42.29 N 51.31 W 5966138.49 N 707774.56 E 0.602 66.44 1688.11 6.630 317.590 1633.56 1684.61 50.56 N 58.64 W 5966146.55 N 707767.00 E 0.348 77.42 .-. 1785.47 6.320 316.160 1730.29 1781.34 58.57 N 66.15 W 5966154.36 N 707759.28 E 0.359 88.35 1878.62 6.570 310.370 1822.86 1873.91 65.72 N 73.76 W 5966161.30 N 707751.47 E 0.747 98.79 1972.74 8.160 309.150 1916.20 1967.25 73.43 N 83.04 W 5966168.74 N 707741.98 E 1.697 110.85 2065.61 12.000 315.640 2007.62 2058.67 84.50 N 94.91 W 5966179.48 N 707729.81 E 4.306 127.07 2156.91 14.300 317.510 2096.52 2147.57 99.60 N 109.16W 5966194.18 N 707715.15 E 2.562 147.76 2252.45 16.560 315.960 2188.61 2239.66 118.09 N 126.60 W 5966212.18 N 707697.20 E 2.404 173.08 2347.97 17.890 312.970 2279.85 2330.90 137.88 N 146.80 W 5966231.40 N 707676.46 E 1.672 201.32 2440.95 18.930 311.970 2368.07 2419.12 157.70 N 168.46 W 5966250.61 N 707654.26 E 1.169 230.68 2537.05 22.440 312.190 2457.96 2509.01 180.45 N 193.65 W 5966272.66 N 707628.45 E 3.653 264.62 2630.88 28.300 313.020 2542.70 2593.75 207.67 N 223.20 W 5966299.05 N 707598.16 E 6.257 304.80 2723.36 32.900 312.730 2622.28 2673.33 239.69 N 257.70 W 5966330.10 N 707562.79 E 4.977 351.85 2817.69 33.590 312.690 2701.17 2752.22 274.76 N 295.70 W 5966364.12 N 707523.83 E 0.732 403.56 -----~---- . 14 August, 2002 - 9:53 Page 2 of6 DrillQllest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for PSI-01 Your Ref: API 500292310400 Job No. A KZZ231 04, Surveyed: 5 August, 2002 BPXA North Slope Alaska lisburne PSI (East Dock) Measured Sub.Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 2910.76 34.150 312.610 2778.45 2829.50 309.91 N 333.85 W 5966398.19 N 707484.72 E 0.604 455.42 .-". 3004.65 34.100 313.580 2856.17 2907.22 345.89 N 372.31 W 5966433.09 N 707445.28 E 0.582 508.07 3097.21 33.930 313.220 2932.90 2983.95 381.47 N 409.93 W 5966467.62 N 707406.69 E 0.285 559.83 3190.65 34.620 312.400 3010.11 3061.16 417.22 N 448.54 W 5966502.29 N 707367.11 E 0.889 612.44 3279.60 35.360 311.990 3082.98 3134.03 451.48 N 486.33 W 5966535.49 N 707328.39 E 0.873 663.44 3377.68 35.990 312.770 3162.66 3213.71 490.04 N 528.57 W 5966572.86 N 707285.09 E 0.792 720.64 3472.12 36.010 310.380 3239.06 3290.11 526.87 N 570.09 W 5966608.53 N 707242.56 E 1.488 776.14 3566.20 35.640 309.920 3315.34 3366.39 562.37 N 612.18 W 5966642.86 N 707199.51 E 0.486 831 .18 3661.19 34.190 309.630 3393.23 3444.28 597.16 N 653.97 W 5966676.47 N 707156.78 E 1.536 885.52 3752.68 34.41 0 310.710 3468.81 3519.86 630.42 N 693.36 W 5966708.63 N 707116.48 E 0.707 937.06 3847.44 35.070 310.790 3546.68 3597.73 665.66 N 734.27 W 5966742.73 N 707074.61 E 0.698 991.05 3943.12 34.580 309.750 3625.23 3676.28 700.98 N 775.96 W 5966776.88 N 707031.96 E 0.805 1045.67 4034.99 35.340 310.730 3700.52 3751.57 734.99 N 816.14 W 5966809.77 N 706990.86 E 1.029 1098.30 4130.20 35.310 310.880 3778.20 3829.25 770.97 N 857.81 W 5966844.57 N 706948.21 E 0.096 1153.34 4216.49 34.950 311.280 3848.77 3899.82 803.60 N 895.24 W 5966876.15 N 706909.89 E 0.495 1202.99 4320.06 33.960 310.670 3934.17 3985.22 842.02 N 939.47 W 5966913.34 N 706864.61 E 1.012 1261,58 4411.42 33.230 310.190 4010.27 4061.32 874.81 N 977.95 W 5966945.05 N 706825.24 E 0.850 1312.12 4506.10 31 .940 311.750 4090.05 4141.10 908.23 N 1016.45 W 5966977.39 N 706785.82 E 1.626 1363.10 ..-... 4602.41 32.080 310.540 4171.72 4222.77 941.81 N 1054.90 W 5967009.90 N 706746.46 E 0.682 1414.15 4697.70 32.460 311.080 4252.29 4303.34 975.06 N 1093.40 W 5967042.07 N 706707.05 E 0.501 1465.02 4791.55 33.170 311.830 4331.16 4382.21 1008.74 N 1131.52 W 5967074.68 N 706668.02 E 0.872 1515.88 4882.19 33.480 312.940 4406.90 4457.95 1042.30 N 1168.30 W 5967107.21 N 706630.33 E 0.755 1565.67 4979.09 32.190 312.880 4488.31 4539.36 1078.08 N 1206.78 W 5967141.91 N 706590.87 E 1.332 1618.19 5051.09 32.290 314.140 4549.21 4600.26 1104.52 N 1234.63 W 5967167.57 N 706562.29 E 0.944 1656.58 5163.85 32.730 314.380 4644.30 4695.35 1146.82 N 1278.03 W 5967208.65 N 706517.74 E 0.407 1717.12 5256.91 33.190 314.500 4722.39 4773.44 1182.26 N 1314.18 W 5967243.08 N 706480.62 E 0.499 1767.69 5352.44 33.500 314.210 4802.19 4853.24 1218.97 N 1351.73 W 5967278.74 N 706442.07 E 0.365 1820.15 5446.45 33.750 314.700 4880.47 4931.52 1255.43 N 1388.89 W 5967314.16 N 706403.92 E 0.392 1872.14 5540.35 33.880 314.380 4958.49 5009.54 1292.09 N 1426.13 W 5967349.77 N 706365.67 E 0.235 1924.34 5634.62 33.000 311.980 5037.15 5088.20 1327.64 N 1464.00 W 5967384.25 N 706326.84 E 1.685 1976.26 14 August, 2002 . 9:53 Page 3 0(6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for PSI.01 Your Ref: API 500292310400 Job No. AKZZ23104, Surveyed: 5 August, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5728.19 33.560 312.440 5115.38 5166.43 1362.13 N 1502.03 W 5967417.69 N 706287.87 E 0.656 2027.60 ~- 5822.41 33.520 313.060 5193.91 5244.96 1397.47 N 1540.26 W 5967451.95 N 706248.68 E 0.366 2079.65 5915.82 32.560 311.330 5272.22 5323.27 1431.68 N 1577.98 W 5967485.10 N 706210.03 E 1.441 2130.57 6009.24 31 .990 311.910 5351.20 5402.25 1464.81 N 1615.27 W 5967517.19 N 706171.83 E 0.694 2180.45 6104.98 32.000 312.370 5432.40 5483.45 1498.85 N 1652.88 W 5967550.17 N 706133.29 E 0.255 2231 .18 6198.49 30.490 309.870 5512.35 5563.40 1530.76 N 1689.40 W 5967581.06 N 706095.90 E 2.128 2279.67 6292.95 30.510 309.010 5593.74 5644.79 1561.21 N 1726.42 W 5967610.48 N 706058.05 E 0.463 2327.57 6385.04 30.480 309.110 5673.09 5724.14 1590.66 N 1762.71 W 5967638.91 N 706020.96 E 0.064 2374.26 6479.18 30.020 309.750 5754.41 5805.46 1620.78 N 1799.34 W 5967668.00 N 705983.51 E 0.597 2421.65 6573.87 30.920 309.880 5836.02 5887.07 1651.52 N 1836.22 W 5967697.72 N 705945.79 E 0.953 2469.64 6668.24 31.260 310.840 5916.84 5967.89 1683.08 N 1873.36 W 5967728.23 N 705907.80 E 0.637 2518.35 6762.37 31.670 310.370 5997.12 6048.17 1715.06 N 1910.66 W 5967759.17 N 705869.63 E 0.508 2567.48 6856.93 31 .960 309.950 6077.48 6128.53 1747.21 N 1948.76 W 5967790.25 N 705830.66 E 0.386 2617.31 6950.41 32.350 309.370 6156.62 6207.67 1778.96 N 1987.06 W 5967820.93 N 705791.49 E 0.532 2667.03 7042.89 32.910 309.280 6234.50 6285.55 1810.56 N 2025.63 W 5967851.45 N 705752.06 E 0.608 2716.85 7137.23 33.170 308.670 6313.59 6364.64 1842.91 N 2065.62 W 5967882.68 N 705711.19 E 0.447 2768.23 7230.91 33.790 308.440 6391.72 6442.77 1875.12 N 2106.03 W 5967913.76 N 705669.90 E 0.676 2819.83 7324.44 33.070 310.160 6469.78 6520.83 1907.75 N 2145.91 W 5967945.27 N 705629.14 E 1.272 2871.31 ~. 7417.08 33.120 309.650 6547.39 6598.44 1940.20 N 2184.71 W 5967976.63 N 705589.45 E 0.305 2921.87 7510.69 33.420 310.270 6625.66 6676.71 1973.18 N 2224.07 W 5968008.51 N 705549.19 E 0.484 2973.20 7603.07 33.760 309.980 6702.61 6753.66 2006.12 N 2263.15 W 5968040.36 N 705509.22 E 0.407 3024.29 7698.51 34.130 309.680 6781.79 6832.84 2040.25 N 2304.08 W 5968073.35 N 705467.36 E 0.426 3077.55 7792.46 34.470 309.700 6859.40 6910.45 2074.06 N 2344.82 W 5968106.02 N 705425.70 E 0.362 3130.46 7886.09 34.740 309.540 6936.46 6987.51 2107.97 N 2385.78 W 5968138.78 N 705383.82 E 0.304 3183.60 7980.00 35.190 309.800 7013.42 7064.47 2142.33 N 2427.20 W 5968171.98 N 705341.46 E 0.505 3237.39 8073.71 34.100 309.590 7090.52 7141.57 2176.35 N 2468.19 W 5968204.85 N 705299.54 E 1.170 3290.63 8167.10 33.160 309.170 7168.28 7219.33 2209.17 N 2508.17 W 5968236.55 N 705258.67 E 1.037 3342.31 8262.45 31.630 309.260 7248.78 7299.83 2241.46 N 2547.75 W 5968267.74 N 705218.22 E 1.605 3393.34 8356.02 29.800 312.220 7329.23 7380.28 2272.62 N 2583.97 W 5968297.88 N 705181.15 E 2.536 3441 . 11 8450.06 29.310 312.730 7411.03 7462.08 2303.94 N 2618.18 W 5968328.24 N 705146.08 E 0.586 3487.49 14 August, 2002 - 9:53 Page 4 of6 DrillQllest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for PSI..01 Your Ref: API 500292310400 Job No. AKZZ23104, Surveyed: 5 August, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8544.18 27.670 313.570 7493.75 7544.80 2334.64 N 2650.94 W 5968358.02 N 705112.48 E 1.794 3532.37 8638.94 26.250 312.810 7578.21 7629.26 2364.05 N 2682.26 W 5968386.55 N 705080.37 E 1.542 3575.32 8731.93 24.190 313.210 7662.33 7713.38 2391.07 N 2711.23 W 5968412.76 N 705050.65 E 2.223 3614.93 8825.97 22.190 313.420 7748.77 7799.82 2416.47 N 2738.18 W 5968437.41 N 705023.02 E 2.129 3651.94 8923.05 21.310 313.600 7838.94 7889.99 2441.23 N 2764.27 W 5968461.44 N 704996.25 E 0.909 3687.90 9017.60 19.730 313.260 7927.49 7978.54 2464.02 N 2788.33 W 5968483.55 N 704971.56 E 1.676 3721.02 9110.68 18.710 313.600 8015.38 8066.43 2485.08 N 2810.59 W 5968503.99 N 704948.74 E 1.102 3751.65 9206.71 17.980 313.730 8106.53 8157.58 2505.95 N 2832.45 W 5968524.25 N 704926.30 E 0.761 3781.86 9319.11 17.800 313.530 8213.49 8264.54 2529.78 N 2857.44 W 5968547.37 N 704900.66 E 0.169 3816.36 9412.94 17.170 312.350 8302.99 8354.04 2548.98 N 2878.08 W 5968566.00 N 704879.50 E 0.770 3844.55 9508.73 16.840 312.610 8394.59 8445.64 2567.90 N 2898.74 W 5968584.34 N 704858.33 E 0.354 3872.56 9596.23 16.210 313.280 8478.47 8529.52 2584.86 N 2916.96 W 5968600.78 N 704839.65 E 0.752 3897.44 9670.40 15.460 314.640 8549.83 8600.88 2598.90 N 2931.53 W 5968614.42 N 704824.69 E 1.128 3917.66 9735.00 15.460 314.640 8612.09 8663.14 2611.00 N 2943.78 W 5968626.17 N 704812.11 E 0.000 3934.86 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to PSI slot A. Northings and Eastings are relative to PSI slot A. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from PSI slot A and calculated along an Azimuth of 311.680° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9735.00ft., The Bottom Hole Displacement is 3934.87ft., in the Direction of 311.572° (True). --'--------~----- -. --------- 14 August, 2002 - 9:53 Page 5 0'6 DríllQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for PSI-01 Your Ref: API 500292310400 Job No. AKZZ23104, Surveyed: 5 August, 2002 . North Slope Alaska BPXA Lisburne PSI (East Dock) Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9735.00 8663.14 2611.00 N 2943.78 W Projected Survey Survey tool program for PSI-01 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 9735.00 8663.14 AK-6 BP _IFR-AK 14 August, 2002 - 9:53 Page 60f6 DrillQllest 2.00.08.005 19-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well PSI-01 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , M D (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) a~-/ý's North Slope Alaska BPXA Lisburne PSI (East Dock), Slot PSI slot A PSI-01 MWD Job No. AKMW22123, Surveyed: 5 August, 2002 SUR VE Y R E PO R T 19 August, 2002 Your Ref: API 500292310400 Surface Coordinates: 5966097.64 N, 707827.02 E (70018' 38.6942'" N, 148018'56.7668" W) Kelly Bushing: 51.05ft above Mean Sea Level -~~ SpBi .".r.Y-SUf1 bAILLINti . s~ÀVIê:èS A Halliburton Company Survey Ref: 5vy11280 Sperry-Sun Drilling Services . Survey Report for PSI-01 MWD Your Ref: API 500292310400 Job No. AKMW23104, Surveyed: 5 August, 2002 BPXA North Slope Alaska lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -51.05 0.00 O.OON 0.00 E 5966097.64 N 707827.02 E 0.00 MWD Magnetic ~ 203.00 0.230 246.840 151.95 203.00 0.168 0.37W 5966097.47 N 707826.65 E 0.113 0.17 292.39 0.780 272.350 241.34 292.39 0.218 1.15W 5966097.40 N 707825.88 E 0.650 0.72 386.03 1.060 262.590 334.96 386.01 0.298 2.64W 5966097.28 N 707824.39 E 0.342 1.78 474.79 1.060 269.140 423.71 474.76 0.41 8 4.28W 5966097.11 N 707822.75 E 0.136 2.92 563.35 1.050 271.340 512.25 563.30 0.40 8 5.91 W 5966097.07 N 707821.12 E 0.047 4.14 657.37 1.050 268.110 606.26 657.31 0.418 7.63W 5966097.02 N 707819.40 E 0.063 5.43 744.07 0.880 265.390 692.95 744.00 0.49 8 9.09W 5966096.90 N 707817.95 E 0.203 6.46 844.77 0.990 272.010 793.63 844.68 0.528 10.73 W 5966096.82 N 707816.31 E 0.153 7.67 937.12 1.970 297.830 885.95 937.00 0.25N 12.93 W 5966097.53 N 707814.09 E 1 .258 9.82 1033.07 3.440 314.820 981.79 1032.84 3.05N 16.43 W 5966100.23 N 707810.51 E 1.729 14.30 1126.94 4.070 319.010 1075.46 1126.51 7.55N 20.61 W 5966104.61 N 707806.21 E 0.732 20.41 1219.53 4.150 321.710 1167.81 1218.86 12.66 N 24.84 W 5966109.60 N 707801.84 E 0.226 26.97 1314.68 4.780 317.550 1262.67 1313.72 18.28 N 29.65 W 5966115.10 N 707796.87 E 0.744 34.30 1405.60 6.620 317.330 1353.14 1404.19 24.93 N 35.76 W 5966121.57 N 707790.58 E 2.024 43.29 1501.94 7.420 318.180 1448.76 1499.81 33.65 N 43.67 W 5966130.07 N 707782.43 E 0.837 55.00 1594.21 6.890 319.240 1540.31 1591.36 42.28 N 51.26 W 5966138.49 N 707774.61 E 0.592 66.40 1688.11 6.630 317.760 1633.56 1684.61 50.56 N 58.58 W 5966146.56 N 707767.06 E 0.333 77.38 ~, 1785.47 6.320 316.190 1730.29 1781.34 5R59 N 66.07 W 5966154.38 N 707759.35 E 0.367 88.31 1878.62 6.570 310.530 1822.86 1873.91 65.75 N 73.67 W 5966161.33 N 707751.56 E 0.733 98.75 1972.74 8.160 309.280 1916.20 1967.25 73.48 N 82.93 W 5966168.80 N 707742.08 E 1.698 110.80 2065.61 12.000 315.590 2007.62 2058.67 84.56 N 94.80 W 5966179.54 N 707729.92 E 4.296 127.03 2156.91 14.300 318.050 2096.52 2147.57 99.72 N 108.98 W 5966194.31 N 707715.32 E 2.592 147.71 2252.45 16.560 316.550 2188.61 2239.66 118.39 N 126.23 W 5966212.49 N 707697.56 E 2.402 173.00 2347.97 17.890 313.380 2279.85 2330.90 138.35 N 146.26 W 5966231.89 N 707676.99 E 1.704 201.23 2440.95 18.930 312.400 2368.07 2419.12 158.33 N 167.78 W 5966251.26 N 707654.93 E 1.167 230.59 2537.05 22.440 312.340 2457.96 2509.01 181.20 N 192.85 W 5966273.43 N 707629.23 E 3.653 264.53 2630.88 28.300 313.020 2542.70 2593.75 208.46 N 222.38 W 5966299.86 N 707598.96 E 6.253 304.70 2723.36 32.900 313.180 2622.28 2673.33 240.62 N 256.74 W 5966331.06 N 707563.72 E 4.975 351.75 2817.69 33.590 312.450 2701.17 2752.22 275.76 N 294.67 W 5966365.14 N 707524.83 E 0.846 403.46 ---_.__._~ -------_.----- -- 14 August, 2002 - 10:21 Page 2 0'6 Dr;IIQfIf~st 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for PSI-01 MWD Your Ref: API 500292310400 Job No. AKMW23104, Surveyed: 5 August, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 2910.76 34.150 312.750 2778.45 2829.50 310.87 N 332.85 W 5966399.18 N 707485.69 E 0.628 455.32 3004.65 34.100 314.210 2856.17 2907.22 347.11 N 371.07 W 5966434.35 N 707446.49 E 0.874 507.96 3097.21 33.930 313.410 2932.90 2983.95 382.96 N 408.43 W 5966469.15 N 707408.14 E 0.517 559.70 3190.65 34.620 313.080 3010.11 3061.16 419.01 N 446.77 W 5966504.12 N 707368.83 E 0.765 612.30 3279.60 35.360 312.400 3082.98 3134.03 453.62 N 484.23 W 5966537.69 N 707330.42 E 0.940 663.30 3377.68 35.990 313.210 3162.66 3213.71 492.49 N 526.19 W 5966575.38 N 707287.40 E 0.803 720.49 3472.12 36.010 310.720 3239.06 3290.11 529.60 N 567.46 W 5966611.34 N 707245.12 E 1.550 775.99 3566.20 35.640 310.880 3315.35 3366.40 565.58 N 609.14 W 5966646.15 N 707202.46 E 0.406 831.05 3661.19 34.190 311.040 3393.24 3444.29 601.22 N 650.20 W 5966680.64 N 707160.43 E 1.530 885.41 3752.68 34.410 311.200 3468.82 3519.87 635.13 N 689.04 W 5966713.46 N 707120.67 E 0.260 936.96 3847.44 35.070 311.670 3546.68 3597.73 670.86 N 729.52 W 5966748.06 N 707079.21 E 0.752 990.96 3943.12 34.580 310.920 3625.23 3676.28 706.92 N 770.57 W 5966782.97 N 707037.18 E 0.680 1045.60 4034.99 35.340 311.600 3700.52 3751.57 741.64 N 810.14 W 5966816.58 N 706996.66 E 0.930 1098.24 4130.20 35.310 310.990 3778.20 3829.25 777.97 N 851.50 W 5966851.75 N 706954.31 E 0.372 1153.29 4216.49 34.950 311.450 3848.77 3899.82 810.69 N 888.85 W 5966883.42 N 706916.07 E 0.518 1202.94 4320.06 33.960 309.760 3934.17 3985.22 848.83 N 933.33 W 5966920.32 N 706870.56 E 1.329 1261.52 4411.42 33.230 309.770 4010.27 4061.32 881.17 N 972.18 W 5966951.56 N 706830.82 E 0.799 1312.04 4506.10 31.940 311.440 4090.05 4141.10 914.34 N 1010.90 W 5966983.65 N 706791.20 E 1.661 1363.02 4602.41 32.080 310.890 4171.72 4222.77 947.94 N 1049.33 W 5967016.18 N 706751.86 E 0.336 1414.07 4697.70 32.460 311.430 4252.29 4303.34 981.43 N 1087.64 W 5967048.59 N 706712.64 E 0.501 1464.94 4791.55 33.170 312.290 4331.16 4382.21 1015.37 N 1125.51 W 5967081.47 N 706673.84 E 0.905 1515.80 4882.19 33.480 314.140 4406.90 4457.95 1049.46 N 1161.80 W 5967114.55 N 706636.63 E 1.172 1565.57 4979.09 32.190 312.810 4488.32 4539.37 1085.62 N 1199.91 W 5967149.64 N 706597.52 E 1.525 1618.08 5051.09 32.290 314.910 4549.22 4600.27 1112.23 N 1227.60 W 5967175.47 N 706569.11 E 1.562 1656.46 5163.85 32.730 315.250 4644.31 4695.36 1155.14 N 1270.40 W 5967217.18 N 706525.14 E 0.423 1716.96 5256.91 33.190 315.090 4722.39 4773.44 1191.05 N 1306.09 W 5967252.09 N 706488.4 7 E 0.503 1767.49 5352.44 33.500 314.760 4802.19 4853.24 1228.13 N 1343.27 W 5967288.13 N 706450.28 E 0.376 1819.92 5446.45 33.750 315.340 4880.48 4931.53 1264.97 N 1380.05 W 5967323.94 N 706412.49 E 0.433 1871.89 5!540.35 33.880 314.830 4958.49 5009.54 1301.98 N 1416.94 W 5967359.91 N 706374.59 E 0.332 1924.05 5634.62 33.000 312.550 5037.16 5088.21 1337.87 N 1454.49 W 5967394.74 N 706336.06 E 1.627 1975.96 14 August, 2002 - 10:21 Page 3 0(6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for PSI-01 MWD Your Ref: API 500292310400 Job No. AKMW23104, Surveyed: 5 August, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5728.19 33.560 313.030 5115.38 5166.43 1372.75 N 1492.17 W 5967428.57 N 706297.43 E 0.661 2027.29 - 5822.41 33.520 313.220 5193.92 5244.97 1408.33 N 1530.17 W 5967463.09 N 706258.4 7 E 0.119 2079.33 5915.82 32.560 311.620 5272.22 5323.27 1442.69 N 1567.75 W 5967496.39 N 706219.94 E 1.389 2130.25 6009.24 31.990 312.190 5351.21 5402.26 1476.01 N 1604.88 W 5967528.67 N 706181.91 E 0.692 2180.14 6104.98 32.000 312.710 5432.40 5483.45 1510.25 N 1642.31 W 5967561.86 N 706143.54 E 0.288 2230.86 6198.49 30.490 310.220 5512.35 5563.40 1542.37 N 1678.63 W 5967592.97 N 706106.35 E 2.125 2279.35 6292.95 30.510 309.260 5593.74 5644.79 1573.02 N 1715.50 W 5967622.58 N 706068.65 E 0.516 2327.27 6385.04 30.480 309.460 5673.09 5724.14 1602.66 N 1751.63 W 5967651.21 N 706031.71 E 0.115 2373.96 6479.18 30.020 310.000 5754.41 5805.46 1632.97 N 1788.10 W 5967680.50 N 705994.41 E 0.568 2421.36 6573.87 30.920 310.190 5836.03 5887.08 1663.90 N 1824.83 W 5967710.40 N 705956.84 E 0.956 2469.35 6668.24 31.260 311.040 5916.84 5967.89 1695.62 N 1861.82 W 5967741.08 N 705918.98 E 0.588 2518.08 6762.37 31.670 310.710 5997.13 6048.18 1727.77 N 1898.98 W 5967772.20 N 705880.96 E 0.472 2567.20 6856.93 31.960 310.160 6077.48 6128.53 1760.10 N 1936.92 W 5967803.47 N 705842.13 E 0.434 2617.04 6950.41 32.350 309.930 6156.62 6207.67 1792.11 N 1975.01 W 5967834.41 N 705803.18 E 0.437 2666.77 7042.89 32.910 309.780 6234.51 6285.56 1824.07 N 2013.29 W 5967865.29 N 705764.02 E 0.612 2716.61 7137.23 33.170 308.460 6313.59 6364.64 1856.52 N 2053.19 W 5967896.63 N 705723.24 E 0.811 2768.00 7230.91 33.790 307.870 6391.73 6442.78 1888.45 N 2093.82 W 5967927.42 N 705681.74 E 0.747 2819.58 7324.44 33.070 309.110 6469.79 6520.84 1920.51 N 2134.16 W 5967958.36 N 705640.53 E 1.061 2871.02 ..-;", 7417.08 33.120 308.540 6547.40 6598.45 1952.23 N 2173.56 W 5967988.97 N 705600.26 E 0.340 2921.54 7510.69 33.420 308.650 6625.66 6676.71 1984.26 N 2213.70 W 5968019.88 N 705559.26 E 0.327 2972.82 7603.07 33.760 309.700 6702.62 6753.67 2016.55 N 2253.32 W 5968051.05 N 705518.76 E 0.729 3023.88 7698.51 34.130 309.640 6781.79 6832.84 2050.57 N 2294.34 W 5968083.93 N 705476.81 E 0.389 3077.14 7792.46 34.470 309.890 6859.40 6910.45 2084.43 N 2335.04 W 5968116.65 N 705435.19 E 0.392 3130.05 7886.09 34.740 309.560 6936.47 6987.52 2118.41 N 2375.93 W 5968149.49 N 705393.37 E 0.351 3183.19 7980.00 35.190 309.250 7013.43 7064.48 2152.58 N 2417.52 W 5968182.49 N 705350.86 E 0.515 3236.97 8073.71 34.100 309.990 7090.52 7141.57 2186.54 N 2458.55 W 5968215.31 N 705308.90 E 1.247 3290.21 8167.10 33.160 309.530 7168.28 7219.33 2219.62 N 2498.31 W 5968247.28 N 705268.24 E 1.043 3341.90 8262.45 31.630 309.630 7248.79 7299.84 2252.17 N 2537.68 W 5968278.72 N 705227.98 E 1.606 3392.95 8356.02 29.800 312.640 7329.24 7380.29 2283.58 N 2573.69 W 5968309.12 N 705191.12 E 2.554 3440.72 8450.06 29.310 315.890 7411.04 7462.09 2315.93 N 2606.90 W 5968340.54 N 705157.02 E 1.782 3487.04 14 August, 2002 - 10:21 Page 4 0'6 DríllQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for PS/-01 MWD Your Ref: AP/500292310400 Job No. AKMW23104, Surveyed: 5 August, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8544.18 27.670 314.370 7493.76 7544.81 2347.76 N 2638.56 W 5968371.48 N 705124.50 E 1.905 3531.85 '~''- 8638.94 26.250 313.180 7578.22 7629.27 2377.49 N 2669.57 W 5968400.34 N 705092.67 E 1.603 3574.78 8731.93 24.190 313.250 7662.35 7713.40 2404.62 N 2698.45 W 5968426.66 N 705063.06 E 2.216 3614.39 8825.97 22.190 312.220 7748.78 7799.83 2429.75 N 2725.64 W 5968451.03 N 705035.19 E 2.170 3651.41 8923.05 21.310 313.930 7838.95 7890.00 2454.31 N 2751.92 W 5968474.85 N 705008.23 E 1.117 3687.37 9017.60 19.730 313.910 7927.50 7978.55 2477.30 N 2775.79 W 5968497.17 N 704983.73 E 1.671 3720.49 9110.68 18.710 314.450 8015.39 8066.44 2498.65 N 2797.77 W 5968517.91 N 704961.18 E 1.112 3751.10 9206.71 17.980 314.550 8106.54 8157.59 2519.84 N 2819.33 W 5968538.49 N 704939.04 E 0.761 3781.29 9319.11 17.800 313.430 8213.51 8264.56 2543.82 N 2844.17 W 5968561.77 N 704913.55 E 0.345 3815.78 9412.94 17.170 312.490 8303.00 8354.05 2563.03 N 2864.79 W 5968580.41 N 704892.39 E 0.736 3843.97 9508.73 16.840 312.930 8394.60 8445.65 2582.03 N 2885.38 W 5968598.83 N 704871.29 E 0.370 3871.98 9596.23 16.210 313.450 8478.49 8529.54 2599.06 N 2903.53 W 5968615.36 N 704852.68 E 0.740 3896.86 9670.40 15.460 314.940 8549.84 8600.89 2613.17 N 2918.04 W 5968629.05 N 704837.78 E 1.150 3917.07 9735.00 15.460 314.940 8612.11 8663.16 2625.33 N 2930.23 W 5968640.87 N 704825.26 E 0.000 3934.27 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to PSI slot A. Northings and Eastings are relative to PSI slot A. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from PSI slot A and calculated along an Azimuth of 311.680° (True). -\ Based upon Minimum Curvature type calculations, at a Measured Depth of 9735.00ft., The Bottom Hole Displacement is 3934.29ft., in the Direction of 311.859° (True). --_.-._-----~--~._.-_._-- 14 August, 2002 - 10:21 Page 5 0'6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for PSI-01 MWD Your Ref: API 500292310400 Job No. AKMW23104, Surveyed: 5 August, 2002 . North Slope Alaska BPXA lisburne PSI (East Dock) Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9735.00 8663.16 2625.33 N 2930.23 W Projected Survey Survey tool program for PSI-01 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 9735.00 8663.16 MWD Magnetic - ------------- --- 14 August, 2002 - 10:21 Page 60f6 Dril/Qup.st 2.00.08.005 08/21/02 Schlumbel'ger NO. 2343 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color ~- Well Job# Log Description Date Blueline Sepia Prints MPL-32 } '11-010 t3 22374 SCMT 06/25/02 2 MPS-11 ~Od.-/I ~ 22371 SCMT 07/01/02 2 MPS-13 aÖd-.-1I 22375 SCMT 07/02/02 2 PSI-01 at) ~ -/4 - 22373 USIT 08/05/02 2 D.S. 18-09B / <8"- 0, ~ 22370 SCMT 07/06/02 2 C-16 J~D-O/O 22359 RST-SIGMA 07/23/02 W-20 ~~ OYl.o 22361 RST -SIGMA 07/28/02 CD 1 1 ~~ Date Delivered: RECEIVED AUG 2e 2002 Alaska O;t &AnGSchS Cons. Commission crage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Receive~ ~pA~ ~ Hubble. Terrie L From: Sent: To: Subject: Tirpack, Robert B Thursday, August 08, 2002 9:42 AM Hubble, Terrie L FW: PSI-01 Completion Change -----Original Message----- From: Winton Aubert [mailto:Winton_Aubert@admin.state.ak.us) Sent: Thursday, August 08,20029:06 AM To: Tirpack, Robert B Subject: Re: PSI-01 Completion Change Rob, This confirms AOGCC1s verbal approval waiving the packer depth requirement of 20 AAC 25.412 (b) for well PSI-01, as detailed below. All other permit stipulations apply. Please submit documentation as required. Winton Aubert AOGCC 793-1231 "Tirpack, Robert B" wrote: > Winton, > > As per our conversation this morning, I would like to request a variance to > 20 AAC 25.412 for PSI-01. The injection packer will be set with-in 2501 of > the injection zone, exceeding the rule of 2001. The current tally estimate > shows the packer being set 2131 above the injection zone. > > PSI-01 will have a 1211 liner lap. The USIT log has been run and shows good > cement through the HRZ. > > If there are any questions, please call. > > Regards, > Rob Ti rpack > GPB Drilling Eng > 907-564-4166 office > 907-440-8633 cell > tirpacrb@bp.com 1 Re: PSI-O 1 Completion Change Subject: Re: PSI-Ol Completion Change Date: Thu, 08 Aug 200209:05:51 -0800 From: Winton Aubert <Winton_Aubert@admin.state.ak.us> Organization: AOGCC To: "Tirpack, Robert B" <TirpacRB@BP.com> ~~g'145 Rob, This confirms AOGCC's verbal approval waiving the packer depth requirement of 20 AAC 25.412 (b) for well PSI-01, as detailed below. All other permit stipulations apply. Please submit documentation as required. Winton Aubert AOGCC 793-1231 "Tirpack, Robert B" wrote: > Winton, > > As per our conversation this morning, I would like to request a variance to > 20 AAC 25.412 for PSI-Ol. The injection packer will be set with-in 250' of > the injection zone, exceeding the rule of 200'. The current tally estimate > shows the packer being set 213' above the injection zone. > > PSI-Ol will have a 121' liner lap. The USIT log has been run and shows good > cement through the HRZ. > > If there are any questions, please call. > > Regards, > Rob Tirpack > GPB Drilling Eng > 907-564-4166 office > 907-440-8633 cell > tirpacrb@bp.com 1. Type of Request: 0 Abandon 0 Alter Casing ,/ II Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 0 Suspend 0 Plugging 0 Time Extension 0 Repair Well 0 Pull Tubing :tü Variance 0 Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate ~ tiJ\- -i/~2. .utr'" ~ I) :p J' 'fe, 0 Perforate 0 Other 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: 0 Development 0 Exploratory 0 Stratigraphic 181 Service 6. Datum Elevation (DF or KB) Planned RKB = 52. l' 7. Unit or Property Name Prudhoe Bay Unit 4. Location of well at surface 3800' NSL, 4579' WEL, SEC. 15, T11N, R15E, UM At top of productive interval 4190' SNL, 2181' WEL, SEC. 09, T11N, R15E, UM (As Planned) At effective depth 8. Well Number , PSI-01 '/. 9. Permit Number 202-145 10. API Number 50- 029-231 04-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool At total depth 4089' SNL, 2294' WEL, SEC. 09, T11 N, R15E, UM (As Planned) 12. Present well condition summary Total depth: measured true vertical 9735 feet 8663 feet 9609 feet 8512 feet Plugs (measured) true vertical Effective depth: measured Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 113' 5074' 9258' 567' 20" X 34" 13-3/8" 9-5/8" 7" 260 sx Arctic Set (Approx.) 1311 sx Arctic Set III, 600 sx 'G' 618 sx Class 'G' 155 sx Class 'G' 113' 5108' 9289' 9168' - 97351 113' 4654' 8230' 8112' - 8663' R,ECEI\/ED Perforation depth: measured None true vertical None AUG 0 8 2002 AI ska Oil & Gas Gons. Gomm¡ssion 7-5/8",29.7#, L-80 to 9138' (In Progress, EsÎtmated D~bhora!Je Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) (In Progress, Estimated Depth) 7" x 9-5/8" 'SABL-3' packer at 9094'; SSSVat 2200' 13. Attachments 181 Description Summary of Proposal 14. Estimated date for commencing operation Ay,~002 ,. ~, 16. If proposal was verþállý approv; ~d Winton Aubert 8/8/2002 Name of approvJri ~ Date Approved Contact Engineer Name/Numbee: ' 'Rob Tirpack, 564-4166 17. I hereby certify that the" for~ is true a correct to the best of my knowledge Signed L II C ' .,. Title Senior Drilling Engineer owe rane 0 Detailed Operations Program 15. Status of well classifications as: 0 Oil 0 Gas 0 Suspended 0 BOP Sketch Service Water Injection Prepared By Name/Number: Terrie Hubble, 564-4628 Date 9-~-Od-.- . ' :;~:> . Conditions of Approval: Notify Commission so representative may witness A I N 2. 2 - 2... Plug integrity - BOP Test - Location clearance - pprova o. 3D - 5 Mechanical Integrity Test -Ann I SìSut>-s~Quent form required 10- 1./07 4ev tI,~J~tt ~ ~~~ ~oo~ I \. ....APproved by order of the Commission Cammy OechSIOitaß I G I N . ^I Commissioner Date ~ iCf f);;;" Form 10-403 Rev. 06/15/88 , (\ I :J I ., /-\ - Submit~'Tri~licate ¡:(.....I-01 Completion Cha~_e 7-5/8", 29.7#, ST-L, IPC, Injection Tubing (wIT' accessories) 7" x 5.963" HES R Nipple 7" x 9-5/8" Baker Seal Assy 7" x 9-5/8" SABL-3 packer with 20' PBR 7" x 5.963" HES R Nipple 7" x 5.77" HES RN Nipple 7" WLEG Tieback sleeve Top Liner Hanger, ZXP Top 9-5/8",47# Intermediate Casing - TSAD - Est. Top Perf. Date 08-06-02 Rev By RBT u ~ ß / ~ Comments XOver #4-Seal Assembly: 7 -5/8" STL Box X 7" TCII Pin t 9094' MJ} I 9138' Mr} ~.----~..-- I ~ 9169' MD 9176' MD ~ 9289' MD . 9308' Mr} .. 7", 26#, L-80, BTC-M Injection Liner .. @ +1- 9,735' MD PROJECT: GCWI WELL: PSI-01 API NO:50-029-23104 GPB Rotary Drilling I t;7ßS:rc .'lì? (El ð\ ß AItASIiA. OIL AND GAS CONSERVATION COMMISSION Brian Robertson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 ( TONY KNOWLES, GOVERNOR 333 W. PH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit PSI-Ol BP Exploration (Alaska), Inc. Permit No: 202-145 Surface Location: 3800' NSL, 4579' WEL, Sec. 15, TIIN, RI5E, UM Bottomhole Location: 4089' SNL, 2294' WEL, Sec. 09, T11N, RI5E, UM Dear Mr. Robertson: Enclosed is the approved application for permit to drill the above referenced service well. The 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 permit in the event it was eIToneously 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. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (M!) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~ Duu' ~(J~ - Cam~echsli Tayl~;-D- Chair BY ORDER OF THE COMMISSION DATED thisJafu day of July, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. 1 . (STATE OF ALASKA f ALASKA_.~ AND GAS CONSERVATION COMrJ....,.:ION PERMIT TO DRILL 20 MC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Development Oil II Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned RKB = 52.1' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 034631 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / PSI-01 9. Approximate spud date 07/19/02 ( Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 9773' MD / 8675' TVD 0 17. Anticipated pressure {S~20 AAC 25.035 (e) (2)} 33 Maximum surface 3012 psig, At total depth (TVD) 8675' / 3879 psig Setting Depth TOD Botom MD TVD MD TVD Surface Surface 113' 113' Surface Surface 5098' 4652' Surface Surface 9328' 8257' 9228' 8162' 9773' 8675' \l.J4A- 7/ ¡J/OL ~ (IU(~ 1 a. Type of work II Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3800' NSL, 4579' WEL, SEC. 15, T11N, R15E, UM At top of productive interval 4190' SNL, 2181' WEL, SEC. 09, T11N, R15E, UM At total depth 4089' SNL, 2294' WEL, SEC. 09, T11 N, R15E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028306, 1190' MD See Attached Plan / 16. To be completed for deviated wells Kick Off Depth 900' MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize Casina WeiQht Grade Couplina 34"x20" 91.51# H-40 Welded 13-3/8" 68# L-80 BTC 9-5/8" 47# L-80 BTC-M 7" 26# L-80 BTC-M 11. Type Bond (See 20 MC 25.025) Number 2S 100302630-277 Hole 42" 16" 12-1/4" 8-1/2" LenQth 78' 5063' 9293' 545' Quantity of Cement (include staQe data) ~60 sx Arctic Set (Approx.) 1205 sx Arctic Set III, 603 sx 'G' 633 sx Class 'G' 140 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEI\/ED JUL 10 2002 ~aska Oil & Gas Gons. CommiSSion . J\nchorage Perforation depth: measured true vertical II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Rob Tirpack, 564-4166 R15t' Prepared By Name/Number: Sondra Stewman, 564-4750 21. I ~erebY certify that the fo..re. ing is. tr"a~ correct to the best of my ~nowl~~ge . Signed Brian Robertson c. "( ~ Title Senior Dnlllng Engineer Date 20. Attachments Permit Number API Number .., 3 /0 ¿) .2. 0.2... - / ~ >' 50- o¿ 9 - ¿...- T Conditions of Approval: Samples Required 0 Ves J8 No Hydrogen Sulfide Measures 0 Ves )J.No Required Working Pressure for BOPE 0 2K 0 3K Other: T~~,nafgg~' Br VO&O f(/. Approved By Cammy Oed1sli Taylof O. .... ~~i~.' C1«K.~. Form 10-401 Rev. 12-01-85 r\ I \) , , '~ ~')rova~D~ See cover letter ., ~ V 0\ for other requirements Mud Log qequ red 0 Ves )8. No Directional Survey Required gVes 0 No D4K D5K D10K D15K 0 3.5K psi for CTU by order of Le commission Date 2J~tk~cate (' ( I Well Name: I PSI-01 Drill and Complete Summary 1 Type of Well (producer or injector): 1 Injector - Water Surface Location: (As Built) Target Location: Bottom Hole Location: x = 707,827 1 Y = 5,966,098 3800' FSL,4579' FEL, Sec. 15,T11N,R15E X = 704,870 1 Y = 5,968,587 4190'FNL,2181'FEL,Sec.09,T11N,R15E X = 704,754 1 Y = 5,968,685 4089'FNL,2294'FEL,Sec.09,T11N,R15E 1 AFE Number: 4P1900 I Estimated Start Date: I 07/19/02 I 1 MD: 19,773' 1 I TVD: 18,675' I I Ria: I Nabors 27e / I Operatina days to complete: 120.7 I Ground Elevation: 117.6' I RKB: I I Well Desian (conventional, slim hole, etc.): 1 Big Bore 1 Objective: I High rate water injection into Ivishak Gas Cap, Zones 3 through 1 Formation Markers Formation Tops MD TVDss Comments Base PF 1 ,878' -1 ,820' 8.6 ppg SV4 3,708' -3,438' 8.6 ppg SV3 4,197' -3,847' 8.6 ppg SV2 4,439' -4,049' 8.6 ppg SV1 4,898' -4,433' 8.6 ppg UG4 5,519' -4,952' 8.6 ppg UG3 5,809' -5,194' 8.6 ppg UG1 6,576' -5,835' 8.6 ppg West Sak 2 7,208' -6,364' 8.6 ppg West Sak 1 7,439' -6,557' 8.6 ppg CM3 7,670' -6,750' 8.6 ppg CM2 8,421' -7,380' 8.6 ppg CM1 8,698' -7,623' 8.6 ppg THRZ 9,135' -8,024' 8.6 ppg BHRZ/LCU 9,328' -8,205' 8.6 ppg TZ4 N/A N/A 7.5 ppg; HC Bearing TZ3 9,328' -8,205' 7.5 ppg; HC Bearing TZ2 9,365' -8,240' 7.5 ppg; HC Bearing TZ2B 9,417' -8,289' 7.5 ppg; HC Bearing BSAD 9,656' -8,513' 7.5 ppg; HC Bearing TO 9,773' -8,623' 7.5 ppg; TLSB NI A -8,673' 8.6 ppg; HC Bearing Surface TD Criteria: Based on -100' TVD below SV1 Top Intermediate TD Criteria: Casing to be set above the BHRZfTZ3 transition TD Criteria: Based upon 50' TVD above TLSB PSI-01 Permit to Drill 3/29/02 I I 52.1' I I I / Page 1 . , . (' ( CasinWTubinQ ProQram Hole Size Csgl WtlFt Grade Conn Length Top Btm Tbg O.D. MDITVD MDITVD 42" Insulated 20" 91.51 # H-40 Welded -78' GL -113' I 113' (34" OD) 16" 13-3/8" 68# L-80 BTC -5063' GL 5,098' 14652' 12-1/4" 9-518" 47# L-80 BTC-M -9,293' GL 9,328' 18,257' 8-1/2" 7" 26# L-80 BTC-M -545' 9,228'/8,162' 9,773' I 8,675' Tubing 7-5/811 29.7# L-80 STL -9,126' GL 9,161' I 8,100' / ./ -330 In intermediate section from 2,799' to 8,249' The nearest well is East Bay State-1 which is -83' well-to-well at surface, -235' away at the top of the Ivishak and 128' away at TD. East Bay State-1 passes BP's Anti-Collision Policy assuming a 1-in-200 Minor Risk Rating. East Bay State-1 is currentlyTA'd in the Ivishak. Standard MWD Surveys from surface to TD. Directional KOP: I 900' MD Maximum Hole Angle: Close Approach Well: Survey Program: Mud ProQram 16" Suñace Hole I Freshwater Spud Mud From Surface to -100' TVD below top SV1 Interval Density Viscosity (ppg) (seconds) 8.6 - 8.8 200-300 9.5 / 200-250 9.5 75-150 Initial Base Perm Interval TD YP (lb/100ft2) 50-70 30-45 20-35 12-1/4" Intermediate Hole I LSND From Surface Casing Shoe to BHRl Interval Density Plastic Viscosity (ppg) (cp) Initial to HRl 9.0-9.5 / 10-15 HRl to Tl4 9.8-10.0 10-15 YP tauo (lb/100ft2) (lb/100ft2) 25-30 4-7 20-30 4-7 8-1/2" Production Hole I BARADRILn From Intermediate Casing Shoe to TD Interval Density Plastic Viscosity YP tauo (ppg) (cp) (lb/100ff) (lb/100ff) 8.8 ,/ 10-15 17-25 3-5 Ivishak Integrity Testing Fracture gradient information from offsets are shown below: Well Name PSI-06 East State Bay-1 L2-32 L3-01 L3-05 Formation SV-1 SV-4? SV-4 SV-3 SV-3 TVDss 4545' TVDss 2745' TVDss 3589' TVDss 4009' TVDss 4032' TVDss PSI-01 Permit to Drill 3/29/02 tauo (lb/100ft2) >8 >6 >6 API FL (mls/30min) 35-55 30-40 16-30 10' Gel API HTH P FL (mls/30min) 6-10 4-61<12.0 10 10 10' Gel API HTH P FL (mls/30min) 4-6<12.0 10 Frac Gradient, PPG 13.4 ppg EMW, 12.1 ppg EMW 12.5 ppg EMW, 13.8 ppg EMW 12.5 ppg EMW /" pH 8.5 - 9.5 8.5- 9.5 8.5- 9.5 pH 8.5-9.5 8.5-9.5 LGS 0/0 vol <5 <5 pH LGS 0/0 vol <5 8.5-9.5 Page 2 ( /' PSI-01 will be FIT'd t012.0 ppg EMW. This will provide a more than adequate kick tolerance of 114 bbls to drill to the planned well TD. Kick tolerance volume will be continually updated as the well is in progress, incorporating the most up-to-date data available from the well. Below are the planned integrity test points. Test Point Surface Casing Shoe Depth 20' minimum below shoe EMW FIT to 12.0 ppg for an -114 bbl kiCk tolerance 10.0 ppg EMW Test Type FIT Intermediate Casing Shoe 20' minimum below shoe FIT Well Evaluation Program :I 16" Surface: Drilling: Open Hole: Cased Hole: Coring: Sampling: 12-1/4" Intermediate: Drilling: Open Hole: Cased Hole: Coring: Sampling: 8-112" Production: Drilling: Open Hole: Cased Hole: Coring: Sampling: MWD 1 GR - Recorded over entire interval. None None None None MWD 1 GR 1 Res - Realtime from 500' above BHRZ to section TD None '" USIT / None Cuttings Samples and Gas Detection - from 500' above BHRZ to section TD MWD 1 GR - Realtime over entire interval PEX (AIT/HALSITLD/CNUAMS-c) with Dipole Sonic (c&s) None None Cuttings Samples and Gas Detection - Entire Interval Cement Program The following surface casing cement calculations are based upon a single stage job. As contingency, a port collar will be run in the casing at -1000' MD to allow circulating cement to surface if the single stage is unsuccessful. Casing Size 113-3/8" Surface I Basis: Lead: Open hole volume + 4000/0 excess in permafrost; 50% excess below permafrost. Lead TOC: To Surface. Tail: Open hole volume + 500/0 excess + 82' shoe track volume. Tail TOC: 1000' MD above 13-3/8" shoe (-4098' MD) Fluid Sequence & Volumes: Pre None Flush Spacer Lead Tail 75 bbls MudPUSH Viscoyfied Spacer weighted to 10.0 ppg 953 bbl 15351 ft3 11205 sks of Dowell ArticSET III-Lite at 10.7 ppg and 4.44 disk, BH$T 45° I BHCT 52°, TT = 6.0 hrs 125 bbl I 700 ft3 I 603~ks of Dowell Premium 'G'at 15.8 ppg and 1.16 disk, BHST 90° I BHCT 86°, TT = 4 hrs PSI-01 Permit to Drill 3/29/02 Page 3 r . (' ~ Casing Size I 9-5/8" Intermediate Basis: Lead: None Tail: Open hole volume + 50% excess + 82' shoe ~ck volume Tail TOC: 1500' above 9-5/8" shoe (-7,828' MD) Fluid Sequence & Volumes: Pre 10 bbls Chemical wash at 8.3 ppg Flush Spacer Lead Tail 50 bbls MudPUSH Viscosified Spacer weighted to 11.5 ppg None / 132 bbl I 741ft3 I 633 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 dIsk, BHST 170° I BHCT 131°, TT = Batch Mix + 4.0 hrs Liner Size I 7" Production Basis: Lead: None Tail: Open hole VOlum¡e + 500/0 Excess + 82' shoe track + 100' liner lap + 200' of 9-5/8" x 5" DP annulus volume. Tail TOC: -9228' MD (8162' TVD) - Liner top. Fluid Sequence & Volumes: Pre 30 bbls Chemical wash at 8.3 ppg Flush Spacer Lead Tail 40 bbls MudPUSH Viscosified Spacer weighted to 11.0 ppg None /' 30 bbl I 168 fe I 14cf sks of Dowell Premium Latex 'G' at 15.8 ppg and 1.16 dIsk, BHST 181° I BHCT 137°, TT = Batch Mix + 3.5 hrs Well Control 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. / Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Surface Interval- BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 13-3/8" Casing Test pressure Intermediate Interval- BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test pressure PSI-01 Permit to Drill 3/29/02 r 20", 2M Diverter (Hydril - MSP) 2080 psi (8.6 ppg @ 4652' TVD) 1615 psi (.10 psi/ft gas gradient to surface) N/A . Function test 3500 psi surface pressure 13-3/8", 5M, 3 Gates with Annular (Hydril - GL) 3693 psi (8.6 ppg @ 8257' TVD) 2867 psi (.10 psi/ft gas gradient to surface) 114 bbls with a 12.0 ppg FIT Rams test to 3,500 psi/250 psi. Annular test to 2,500 psi/250 psi 3500 psi surface pressure Page 4 , ' (" Production Interval- BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing/7" Liner Test Planned completion fluids 13-3/8", 5M, 3 Gates with Annular (Hydril - GL) 3879 psi (8.6 ppg @ 8675' TVD) 3012 psi (.10 psi/ft gas gradient to surface) Infinite Rams test to 4,000 psi/250 psi. / Annular test to 2,500 psi/250 psi 4000 psi surface pressure 8.4 ppg Seawater 1 6.8 ppg Diesel Disposal . No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . . PSI-01 Permit to Drill 3/29/02 Page 5 ( (" Drill and Complete Procedure Summary Pre-Ria Work: 1. Install 20" insulated conductor. 2. Weld an FMC landing ring for the FMC Big Bore wellhead on the 20" conductor. Install two 4" side outlet valves on the conductor pipe for surface cementing operations. Ria Operations: 1. MIRU Nabors 27e. / fl 2. Nipple up and function test diverter system. PU 5" to drill surface hole and stand back in derrick. 3. MU 16" drilling assembly with MWD/GR and dirè lonally drill surface hole to approximately 5,098' MD I 4,652' TVD. The actual surface hole TD will be +1-100' TVD below the top of the SV1 sands. 4. Run and cement the 13-3/8", 68# surface casing back to surfac¿' A port collar will be run in the casing to allow for secondary cementing if cement is not circulated to surface during pri~a~em~ operations. 5. ND diverter system and NU casing I tubing head. NU BOPE and test to .3.5e6'ì5i?~ /' 6. MU 12-1/4" drilling assembly with MWD/GR/Res and RIH to float collar. Test the 13-3/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.0 ppg lSND drilling fluid. Drill new formation to 20' below 13-3/8" shoe and perform Formation Integrity Test. 8. Drill ahead as per directional plan. Increase mud weight to 10.0 ppg prior to entering the HRZ. Short trip as required. " 9. TD the 12-1/4" interval in the Base of the HRZ. Control drill the BHRZ to aid in picking TD. 10. Run and cement the 9-518'':'47# intermediate casing to 1500' above the top of the shoe. Displace the 9-5/8" casing with 10 ppg lSND drilling mud during cementing operations and freeze protect the 13-3/8" X 9-518" annulus as required. ",.. 11. MU 8-1/2" drilling assembly with MWD/GR and RIH to float collar. Test the 9-518" casing to 3500 psi for 30 minutes. 12. Drill out shoe joints and 20' of new formation. Formation Integrity Test will be the 10.0 ppg MW in the hole. Displace hole over to 8.8 ppg BARADRILn fluid. 13. Drill ahead as per directional plan to proposed TD at 9,773' MD 18,675' TVD. The actual TD of the well will extend +1-60' TVD below the BSAD, but no deeper than 50' TVD above the TLSB. Short trip as required and condition hole for running thy7" liner. 14. RU E-line. Run USIT log to determine bond quality and TOC. Make second E-line run with either Di-Pole Sonic/GR or BHC Sonic/GR, depending on USIT data and bond quality. RD E-line. 15. Run and cement the 7", 26# liner. The liner will extend up into the 9-5/8" casing -100' MD and will be fully cemented to the liner top. Displace cement with mud. POOH. 16. RIH with 9-5/8" and 7'~sing scrapers. Tag PBTD, circ hole clean. Displace wellbore over to seawater. 17. Test wellbore to 4000 psi for 30 minutes. POH laying down drill pipe. 18. Run 7-5/8", IPC, Flush-joint, injection string. 19. Set packer with tubing tail at least 30' above liner hanger top. 20. Sheer out of PBR. PU and space out. Make up tubing hanger. 21. Circulate Freeze protection. 22. land Tubing hanger. Allow diesel to U-Tube in annulus. 23. Pressure test tubing and annulus to 4000 psi for 30 mins. 24. ND BOPE. NU tree and test to 5000 psi. 25. Set BPV, RDMO. Post-Ria Work: 1. Clean-up location as required. 2. Perforate and stimulate Ivishak intervals as required. 3. POI. PSI-01 Permit to Drill 3/29/02 Page 6 Job 1: MIRU Hazards and Contingencies ~ The rig move will involve no surface close approach hazards with adjacent wells. The PSI-01 well will be drilled from an existing pad with three (3) other wells on the location: PSI-06, PSI-09, and East Bay State #1, an exploration well drilled in 11/74. EBS#1 was DST'd and then suspended with a CIBP @ 9300' MD and 100sx of cement. ~ H2S is not expected to be encountered during the planned drilling operations. Offset wells are not productive from the Ivishak and therefore are not relevant. Nevertheless, Standard Operating Procedures for H2S precautions should be followed at all times. Job 2: Drill Suñace Hole Hazards and Contingencies ~ No fault crossing are expected in the surface interval. ~ The nearest well is East Bay State-1 which is -83' well-to-well at surface, -235' away at the top of the Ivishak and 128' away at TD. East Bay State-1 passes BP's Anti-Collision Policy assuming a 1-in-200 Minor Risk Rating. East Bay State-1 is currently T A'd in the Ivishak. ~ Gas hydrates have not been observed at the other wells on the pad: PSI-06, PSI-09, and East Bay State #1. Gas hydrates are not expected at PSI-01. ~ Two offset wells on the West Beach pad have experienced deeper gravel beds below the Permafrost. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) ~ Abnormally pressured shallow gas zones have NOT been observed in offset wells and is not expected at PSI-01. >:,>.'""""'",....,.,.,..",.,.'Y.N"-""',, Job 3: Install 13-3/8" SurfaceCasinQ Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 400% excess cement through the permafrost zone (and 50% excess below the permafrost) is planned. As contingency, a port collar will be run in the casing at -1000' MD to allow circulating cement to surface if the single stage is unsuccessful. ~ Hole cleaning will be difficult in the 16" hole with 5" DP. Maintain adequate viscosity and high flow rates. Short trip as required. ~ Cementing practices on the surface casing should meet the below criteria. 1. Pipe reciprocation during cement displacement 2. Cement - Top of lead to surface 3. Cement - Top of tail >1000' MD above shoe using 50% excess. 4. Casing Shoe Set approximately -100'TVD below SV-1 sand. "",,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,",,,,,-,,,,-, -,- ""'":','',','''''''''''''''''-''''''''--''' Job 4: Drilllntermediate/Production Hole Hazards and Contingencies ~ Fault crossings are not expected along the PSI-01 wellpath in the intermediate hole. ~ The nearest well is East Bay State-1 which is -83' well-to-well at surface, -235' away at the top of the Ivishak and 128' away at TD. East Bay State-1 passes BP's Anti-Collision Policy assuming a 1-in-200 Minor Risk Rating. East Bay State-1 is currently T A'd in the Ivishak. ~ Lost circulation is not expected in the intermediate hole section. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures if LC is encountered. PSI-01 Permit to Drill 3/29/02 Page 7 (' ~ Drill Site 4 is located approximately 3.5 miles to the SE. Cretaceous injection has the potential for raising the pore pressure to 9.5 ppg EMW in the Ugnu. No increase in pore pressure was observed at PSI-06 and is not expected at PSI-01. Check for flow after cutting the Ugnu. ~ The directional plan has been built to minimize directional work and tangent angle in the HRZ. With the current directional plan, raise MW to 10.0 ppg before entering the HRZ to aid in hole stability. ~ Differential sticking will be a problem if the drill string is left stationary for an extended period of time across the long permeable sections of the Ugnu and West Sak intervals. Minimize the time the pipe is left stationary. ~ For adequate hole cleaning flow rates should be maintained in the 800 gpm range, particularly while drilling with higher RaP's (200'/hr). . ~ The kick tolerance for the 12-1/4" open hole section would be 114 bbls assuming a kick while at the section TD (-9,328' MD / 8,257' TVD). This is a worst case scenario based on a 10.0 ppg pore pressure gradient, a fracture gradient of 12.0 ppg at the 13-3/8" shoe, gauge hole, and 10.0 ppg mud in the hole. ~ Picking the 9-5/8" casing point is critical. Every attempt should be made to hit the BHRZ. If too much HRZ is left open while drilling the Ivishak, hole problems can be encountered due to the HRZ sloughing. If too much of Zone 3 is drilled, LC could be encountered due to the low pore pressure in Zone 4 (7.5 ppg). -"'N"'~¡"''''''''''''-''...._--,-,-,-'''''----><.-'' """..,~-~.~-"'_.,',.--"..,- Job 6: Install 9-5/8" Intermediate/Production CasinQ Hazards and Contingencies ~ Differential sticking is a concern across the Ugnu and West Sak sand intervals. Communicate individual responsibilities to all members of rig team and review connection / tripping practices to minimize the time the pipe is left stationary. ~ Verify the floats are holding prior to continuing operations. If floats are not holding, hold pressure and wait on cement. ~ Run USIT log to determine cement bond quality and TOC. State must approve cement integrity to allow injection. :<:<~K>¡K_:<JI:_~ --'»(~Ifi:"m._--:<:<""J<' ~,..~~ Job 7: Drill 8-1/2" Production Hole Hazards and Contingencies ~ Fault crossings are not expected along the PSI-01 well path in the production hole. ~ Lost circulation is considered to be a moderate risk because of the low pore pressure in the Ivishak. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. ~ KICK TOLERANCE: The kick tolerance for the 8-1/2" open hole section would be an infinite influx assuming a kick from the Ivishak. This is a worst case scenario based on a 8.6 ppg pore pressure gradient, a fracture gradient of 10.0 ppg at the 9-5/8" shoe, and 9.0 ppg mud in the hole. ~ Extra vigilance is required to avoid swabbing. The Ivishak will be highly permeable and gas bearing. ~ The. nearest well is East Bay State-1 which is -83' well-to-well at surface, -235' away at the top of the Ivishak and 128' away at TD. East Bay State-1 passes BP's Anti-Collision Policy assuming a 1-in-200 Minor Risk Rating. East Bay State-1 is currently T A'd in the Ivishak. ~":-¡",:-:~"""¡,,¡,,,,,mm. >:"",¡,¡1¡",¡,,¡¡,y,.1,m,y,.~ >">1¡""¡¡'¡»¡"¡~~",»»"Y.>¡,>1:,>¡¡"¡",,,,,,,¡,»~ "m¡",,»,,¡¡,,»,¡¡,,¡::o";:'.~~.w.~ Job 8: Loa 8-1/2" Hole Hazards and Contingencies ~ Differential sticking is a concern in the Ivishak due to the low pore pressure. Keep tools moving at all times and monitor line tension. PSI-01 Permit to Drill 3/29/02 Page 8 ( ... -. - ..- . Job 9: Install 7" Production Liner Hazards and Contingencies » Differential sticking could be a problem. Minimize the time the pipe is left stationary while running the liner. » Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. >«<"'''''''J<''''''''''''''''''''''''''''-''''''''''' ..............._~;,---,--~;;., Job 12: Run Completion Hazards and Contingencies » Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. » The injection tubing will be large diameter with flush joint connections. This job will be non-routine. Ensure all personnel are briefed of the potential hazards. Review all aspects of the operation with all rig team members prior to starting the job. » Ensure personnel are clear of rig floor during packer setting and when shearing out of the PBR. There will be the potential for a sudden release of stored energy with the string to jump at surface. » Freeze protection operations will also be non-routine without a RP Shear valve in the injection string. Freeze protection will be done through the BOP stack and choke manifold. Take extra precaution to avoid spills. Ensure all lines are blown down to vac truck. "'«_w.ðCoW.i>C'~'¡"'U..U""¡'.'-'~')G«~'~'N:.«'""",'M",,«'~n'I::::::: Job 13: ND/NU/Release RiQ Hazards and Contingencies » See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. ~"'¡",m'¡¡:-1'¡'~'~ >:>,,¡,,¡,,¡X>¡»~.~. '¡)"¡¡"¡"¡¡¡"N~ '"">11"X"1))",»"",»,,,»,,m,:<:>1». PSI-01 Permit to Drill 3/29/02 Page 9 t ( PSI-01 Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates were not observed at the other 3 wells on this pad, and are not expected at PSI-01. . Shallow gas was not observed at the other 3 wells on this pad, is not expected at PSI-01. . 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. Intermediate Hole Section: . Fault crossings are not expected along the PSI-01 wellpath in the intermediate hole. . Lost circulation is not expected in the intermediate hole section. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures if LC is encountered. . Drill Site 4 is located approximately 3.5 miles to the SE. Cretaceous injection has the potential for raising the pore pressure to 9.5 ppg EMW in the Ugnu. This was not seen at PSI-06 is not expected at PSI-01. . The directional plan has been built to minimize directional work and tangent angle in the HRZ. With the current directional plan, raise MW to 10.0 ppg before entering the HRZ to aid in hole stability. . Differential sticking will be a problem if the drill string is left stationary for an extended period of time across the long permeable sections of the Ugnu and West Sak intervals. Minimize the time the pipe is left stationary. . The kick tolerance for the 12-1/4" open hole section would be 114 bbls assuming a kick while at the section TD (-9,328' MD / 8,257' TVD). This is a worst case scenario based on a 10.0 ppg pore pressure gradient, a fracture gradient of 12.0 ppg at the 13-3/8" shoe, gauge hole, and 10.0 ppg mud in the hole. . Picking the 9-5/8" casing point is critical. Every attempt should be made to hit the BHRZ. If too much HRZ is left open while drilling the Ivishak, hole problems can be encountered due to the HRZ sloughing. If too much of Zone 3 is drilled, LC could be encountered due to the low pore pressure in Zone 4 (7.5 ppg). Production Hole Section: . Lost circulation is considered to be a moderate risk because of the low pore pressure in the Ivishak. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. . The kick tolerance for the 8-1/2" open hole section would be an infinite influx assuming a kick from the Ivishak. This is a worst case scenario based on a 8.6 ppg pore pressure gradient, a fracture gradient of 10.0 ppg at the 9-518" shoe, and 9.0 ppg mud in the hole. HYDROGEN SULFIDE - H2S / This drill-site not designated as an H2S drill site. H2S is not expected during the planned drilling operations. Offset wells are not productive from the Ivishak and therefore are not relevant. Nevertheless, Standard Operating Procedures for H2S precautions should be followed at all times. . DRILLING CLOSE APPROACH . The nearest well is East Bay State-1 which is -83' well-to-well at surface, -235' away at the top of the Ivishak and 128' away at TD. East Bay State-1 passes BP's Anti-Collision Policy assuming a 1-in-200 Minor Risk Rating. East Bay State-1 is currently T A'd in the Ivishak. CONSULT THE PSI PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION PSI-01 Permit to Drill 3/29/02 Page 10 . SP~-S1..I1 North Slope A\..Ska DFtlL-L.ING SERVlc::eS BPXA A Iia.llbynon COMpany 1000 - 2000 - 3000 - ~ :§ C/) ëi5 4000 - a.. - .c +-' 0- Q) Q -æ 0 .~ 5000 > 6000 - 7000 - .=: 0 g 8000 - II .s:: () .!; Qj -æ () (/) DrillQuest 2.00.09.006 Lisburne p~'least Dock) PSI 1 WP06 DrillQuest' Proposal Data for PSI 1 WP06 0 ,.--/' Begin 16" Hole ~;~~~r8r?~n : Measurement Units : North Relerence : PSI slot A PSI sbt A It True North Dogleg severity: Degrees per 100 leet (US) Vertical Section Azimuth : 311.6800 Vertical Section Description: PSI sbt A Vertical Section Origin: 0.00 N,O.OO E Measured ncl. Azlm. Depth o.m 34.m \XX),<KI I4IXIJX) 1 X26.X2 192R X3 25<X!.(x) 2799.20 X24R60 9ß5.17 9327.77 977259 ,800_00 End ~,¿;~I ~ .!1.402°: 1!2~82ftMD,1!2!.:.60ftTVDBPERMAFR05T, 1871.6OftTVD Begin Dir @ 2.0000/100ft : 1928.83ft MD, 1921.6011 TVD ,:;('>000 Vertical Depth O,(X) 34.00 9CKUX) 1399.37 lX21.(,() 1921.60 2466.57 2730,24 72X5,OO X075.61 8256.(-~) 8674.60 Northings Eastings Vertical Dogleg Section Rate O,(x) N O.OOE n.oo O,OON O.(X)E (UX) O,(x)O O.(X) N O,(X) E OJ)() OJXX) 14.50 N 16.2X \Ii 2U;O I.(XX) 54.9<> N 61.13 \Ii X2.66 I.5(X) 6X.37 N 76.80 \Ii 102,82 O.(XX) 17<.1,<}6 N 202,I2W 27(),63 /'2.(X)() 273.42 N 3m.IOW 411.18 35(X) 2262.71 N 2541.55 W 3402,x.¡ O,(X)() 2526.53 N 2R37.&i \Ii 37<.1<.1.59 I.5<X) 2570.33 N 2&i7.m W 3865.46 O,(X)() 2671.4<.1 N 3(x)O.70 W 4017.60 O.(X)() ~Begln Dir @ 1.0000/100ft: 9OO.00ft MD, 9OO.00ft TVD 1200,00 O.(X)() O.()()() o.mo 5.()()() 11.402 1 J.4I)2 22JQ6 33.298 33.298 19.99<) 19.m \9.9<,)<.1 O.()(X) O.()()() O.<XJO 311.ti!«) 311.(~O 311.ti!«) 311.(~O 311.678 311.671\ 311.ti!«) 311.6XO 311.680 --Increase in Dir Rate @ 1.5OO0/100ft: 1400.00ft MD,1399.37ft TVD Increase in Dir Rate @ 3.5OO0/1001t : 2500.0Oft MD, 2466.57ft TVD Current Well Properties PSI 1 WP06 5966097.64 N, 707827.02 E 56.31 N, 67.67 E 70018'38.6933" N, 1480 18'56.7646" W Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: RKB Elevation: End Dir, Start Sail @ 33.298° : 2799.20ftMD,2730.24ftTVD 000.00 51 .60ft above Mean Sea Level 51 .60ft above Structure True North Feet (US) North Reference: Units: 600.00 - - - - - - - - - - - _5V4, 3489,6()ft TVD - -- - - - - - - - - - - - - - - _5V2, 4100.60IlT\lD 800,00 -- - - - - - - ~ - - - - - - - _S\lI, 44S4.601tTIID - -- - - - - - - - - - - - _004. 5003.6011TVD 200.00- - - - - - - - _WESTSAK2, 6415.6()ftTVO - - - - - - - - _WESTSAK1, 6608.6OOTVD Begin Dlr @ 1.5000/100ft: 8248.60ft MD, 7285.00ft TV End Dlr, Start Sail @ 19.999° : 9135.17ftMD,8075.61ft Be9i!J 8.112" Hole --- PSI 1 T1 8256.60ft TVD, 2570.33 N, 2887.07 9 518" Casing 9000.00 9327. 77ft MD 8256.60ft TVD - - _THRZ. 0075,61ftTVD I 0 1000 Scale: 1 inch = 1000ft BHRZlCUlTZ3ITCGL, 8256.60ft TVD = = =TZ2C/BCGL, 8291.6()ft TVD - - -rZ2BI'¿3SB, 8340.60ft TVD ~.o: _BSAD. 8564,60llTIID . PSI TD DD's Polv @ 95%-.... - ~ _T, DITL5B 8674,6()ftTVD PSl1 TD 8674.6011 TVD, 2671.49 N, 3000.70 W ~;i~~;~ft MD Total Depth: 9772.59ftMD,8674.60ftTV 8674.60ft TVD I I 3000 4000 Section Azimuth: 311.680° (True North) Vertical Section (PSI slot A) I 2000 ( spe'-''-'Y-5U11 North Slope Alaska DRILLING SERVtc:és BPXA A tlat8l>UI1On Company Vertical Origin: Horizontal Origin: Measurement Units: North Reference: Dogleg severity : Vertical Section Azimuth : Vertical Section Description: Vertical Section Origin: Measured Inel. Depth 0.00 34.00 900.00 1400.00 1826.82 1928.83 2500.00 2799.20 8248.60 9135,17 9327.77 9772.59 0.000 0.000 0.000 5.000 11.402 11.402 22.826 33.298 33.298 19.999 19.999 19.999 rotal Depth: 9m.59ftMD,8674.6OftTVD PSI 1 TD 8674.60ft TVD 2671.49 N, 3000.70 W 1,,"PSI1 TD Gøo Poly I...... , "-,. . .""..~~~~~/ ...-------"..pSI TD DD's Poly@95% ...-- 600, o. PSI 1 T1 . .-""- """--"-;~~:~;'~~~~~7 W I i 7" LinerL, " 2500 -:::~~~~D 9 5/8" Casing 9327.77ft MD 8256.60ft TVD 2000 - ~ Õ (j) ëi5 1500 - ~ (J) C) c E t 0 Z 1000 - 500 - 4:: 0 0 LO II ..c: u .5 õ.) (ij U (j) DrillQuest 2,00.09.006 Lisburne P~I ,East Dock) PSI 1 WP06 DrillQuest' I Proposal Data for PSI 1 WP06 PSI slot A PSI slot A ft True North Degrees per 100 feet (US) 311.680° PSI slot A 0.00 N,O.OO E Azim. Vertical Northings Eastings Vertical Dogleg Depth Section Rate 0.00 O.OON O.OOE 0.00 34.00 O.OON O.OOE 0,00 O. ()()() 900.00 O.OON O.OOE 0.00 o. ()()() 1399.37 14.50 N 16.28W 21.80 1.000 1821.60 54.96 N 61.73 W 82.66 1.500 1921.60 68.37 N 76.80 W 102.82 0.000 2466.57 179.96 N 202.12 W 270.63 2.000 2730.24 273.42 N 307.10 W 411.18 3.500 7285.00 2262.71 N 2541.55 W 3402.84 0.000 8075.61 2526.53 N 2837.88 W 3799.59 1.500 8256.60 2570.33 N 2887.07 W 3865.46 0.000 8674.60 2671.49 N 3000.70 W 4017.60 0.000 0.000 0.000 0.000 311.680 311.680 311.680 311.680 311.678 311.678 311.680 311.680 311.680 Current Well Properties PSI 1 WP06 5966097.64 N, 707827.02 E 56.31 N, 67.67 E 70018' 38.6933" N, 148018' 56.7646" W Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: RKB Elevation : 51.60ft above Mean Sea Level 51.60ft above Structure True North Feet (US) North Reference: Units: End Dlr, Start Sail @ 19.999' : 9135.17ftMD,8075.61ftTVD Begin Dir @ 1.S000/100ft: 8248.6Oft MD, 7285.00ft TVD 0 I -3000 Scale: 1 inch = 500ft I ~2500 I I -2000 -1500 Eastings (PSI slot A) I -1000 I -500 0 Reference is True North End Dlr, Start Sail @ 33.298° : 2799.2OftMD,273O.24ftTVD Increase in Dir Rate @ 3.5000/100ft : 2SOO.00ft MD, 24G6.57ft TVD WdnDI~I~~J.~ogOf~¿o1~2:8iIrJ.r~M8~11Š~~~-PvD Increase in Dlr Rate @ 1.sooo/100ft: 1400.00ft MD, 1399.37ft TVD Begin Dlr @ 1.000o/100ft : 9OO.00ft MD, ~e:fUY~~ . , . ( SipE!r'T'\I-5U1! North Slope A8dska DAII...L.ING SEAvlces BPXA A IialtÞuROl> C_øany Lisburne pL. (East Dock) PSI 1 WP06 DrillQuest' bp Single Well Target Data for PSI 1 WP06 Measurement Units: ft Coordinate Target Point TVD Northings Eastings SSTVD Northings Eastings Target Name Type ASPY ASP X Shape PSI I TI Entry Point 8256.60 2570.33 N 2887.07 W 8205.00 5968587.00 N 704870.00 E Point PSI 1 TD Geo Poly Entry Point 8674.60 2671.49 N 3000.70 W 8623.00 5968684.98 N 704753.62 E Polygon Boundary Point A 8674.60 2793.57 N 3109.28 W 8623.00 5968804.00 N 704641.70 E B 8674.60 2571.54 N 3111.24 W 8623.00 5968582.00 N 704645.89 E C 8674.60 2567.13 N 2879.96 W 8623.00 5968584.00 N 704877 .20 E D 8674.60 2794.05 N 2873.67 W 8623.00 5968811.00 N 704877 .21 E PSI TD DD's Poly @ 95% Entry Point 8674.60 2671.49 N 3000.70 W 8623.00 5968684.98 N 704753.62 E Polygon Boundary Point A 8674.60 2751.80 N 3066.01 W 8623.00 5968763.45 N 704686.11 E B 8674.60 2743.69 N 3073.93 W 8623.00 5968755.12 N 704678.42 E C 8674.60 2729.75 N 3077 .02 W 8623.00 5968741.10 N 704675.72 E D 8674.60 2632.20 N 3078.32 W 8623.00 5968643.55 N 704677.12 E E 8674.60 2617.25 N 3076.65 W 8623.00 5968628.65 N 704679.20 E F 8674.60 2609.06 N 3068.48 W 8623.00 5968620.69 N 704687.59 E G 8674.60 2607.50 N 3056.13 W 8623.00 5968619.48 N 704699.98 E H 8674.60 2605.38 N 2932.69 W 8623.00 5968620.77 N 704823.43 E I 8674.60 2607.11 N 2920.93 W 8623.00 5968622.83 N 704835.14 E J 8674.60 2615.42 N 2911.34 W 8623.00 5968631.40 N 704844.50 E K 8674.60 2629.65 N 2907.83 W 8623.00 5968645.72 N 704847.61 E L 8674.60 2729.94 N 2904.58 W 8623.00 5968746.06 N 704848.08 E M 8674.60 2745.35 N 2905.91 W 8623.00 5968761.43 N 704846.33 E N 8674.60 2753.71 N 2914.05 W 8623.00 5968769.56 N 704837.96 E 0 8674.60 2755.03 N 2926.69 W 8623.00 5968770.53 N 704825.29 E P 8674.60 2754.48 N 3053.15 W 8623.00 5968766.48 N 704698.89 E PSI 1 WP06 Formations Measured Vertical Sub-Sea Depth Depth Depth Dip Dip Dir. Formation Name (1t) (1t) (1t) (Deg) (Deg) 1877.83 1871.60 1820.00 0.000 0.000 BPERMAFROST 3707.72 3489.60 3438.00 0.000 0.000 SV4 4197.05 3898.60 3847.00 0.000 0.000 SV3 4438.73 4100.60 4049.00 0.000 0.000 SV2 4898.16 4484.60 4433.00 0.000 0.000 SVl 5519.10 5003.60 4952.00 0.000 0.000 UG4 5808.63 5245.60 5194.00 0.000 0.000 UG3 6575.53 5886.60 5835.00 0.000 0.000 UG1 7208.44 6415.60 6364.00 0.000 0.000 WEST SAK 2 7439.34 6608.60 6557.00 0.000 0.000 WEST SAK 1 7670.25 6801.60 6750.00 0.000 0.000 CM3 8421.49 7431.60 7380.00 0.000 0.000 CM2 8698.39 7674.60 7623.00 0.000 0.000 CMI 9135.17 8075.61 8024.01 0.000 0.000 THRZ 9327.77 8256.60 8205.00 0.000 0.000 BHRZ/CU/TZ3/TCGL 9365.01 8291.60 8240.00 0.000 0.000 TZ2C/BCGL 9417.16 8340.60 8289.00 0.000 0.000 TZ2B/23SB 9655.53 8564.60 8513.00 0.000 0.000 BSAD 9772.59 8674.60 8623.00 0.000 0.000 TD/TLSB DrillQuest 2.00.09.006 " . ¡ MD : Delta , (ft) i MD (ft) 1. 0.00 ----- 2 34.00 ------ 3 900.00 4 1400.00 5' : 1826.82- '.-6~'---T-1928.83 7 2500.00 I 8 2799.20 9 8248;60 10 Øl~~~17 11 T .. 9327.17, 12T i. 9772.59,' 9 -luly,2002-J5:32 34.00, 866;00 500.00 426.82 ' 102.01 571.17 299.20 5449.39 886~57 192.60 ' 4,44:82' , Sperl/-Sun Drilling Seí "ices Proposal Data - PSI 1 WPS - PSI 1 WP06 001=5.1 Draft Copy Inclin. (°) 0.00 0.00 O.OO~ 5.00 . 11040. .11040 22.83 33;30 .33.30 20.00 ~O.OO .~g:~()l:.~ , I I Azimuth i TVD Delta Northings e) (ft) TVD (ft) (ft) .0;00 0.00 0.00 0.00 34J)O 34..00 0.001 0.00. . 9OO;QO .866.00' '0.00\ 3n~68 1399;3t~ . 49~t37, 14J)()N.¡ 311<68 1821.60 422:23 ,54,96N¡ 311.68 1921.60 l00:00:6~:37N! 311.68 2466~51' 54:4.97 179:96N! 311.682730:24 . 263;66 ~73.42:N 31 L6ß ,7285;00 45~;7;~22a2],t,.N" 311.68 .ØQ7~;6t;,,'.i79;Ø:;~~':':,?~gpiS$!I':l, $t1;ß8 8256.60 ':'180:99 2570.33 N ,.~1i\~~.I. 867 4.60 \?;.:~~"~:~9J 2671 .49 N, I TooIface I VS (312°) (°) (ft) 0.0 --._---_--...:.----- 0.0 --'-...,..---- 0.0 '----"~-21-:á -+-_._- ..~_._-----_. 82.7 ..-.-- --,,_._-_..._~ 102.8 --"'._'''--L,...~..__. 270.6 411:2 34Q2~8 ,\~r9$;6 '3f3ß$.þ .,~RÙ.;~' Eastings Dogleg A. Build j A. Turn (ft) (0/10Oft) (0/100ft) I (0/10Oft) 0.00:. .o;oo! 0.00, :o~()()j 0.00 ~~~.W i 1.00. 61.73Wj 1.50 . . . . I 1S.80W! 0.00 202:12W\ 2.00 , ~i;lOW 3.50 ,2p4};55W,' ,9;00' ~8å:r¡ij8,W 1.50. 2887.07 W ......',.".:.',Q..()p:-' ' .30~:70 wJJ'"I\:.,.:::;o'\2:q9.:\:.".?; :., .' 0.00 0.00 0.00 O.ooc. 0.00 0.00 l~OO~ 0.00 311.68 1~50; 0.00 0.00 .0;00' 0.00 0.00 2.00 o~oo 0.00 3;50 ,6.00 359.99 ,o.q<) . ,0.00,' , .0.00 ,'ë1;$Q, . . .0.09 .,., : ,,'1~P~Q(l' ,.,. ',:;'i:i~:=::' I. ~l ..:;:~~l:,,:;~;,':,..:::~~,L}" DrlllQuest Revised: 9 July, 2002 PROPOSAL REPORT 9 July, 2002 ,.-.", Surface Coordinates: 5966097.64 N, 707827.02 E (70018'38.6942" N, 148018'56.7668" W) Surface Coordinates relative to Project H Reference: 966097.64 N, 207827.02 E (Grid) Surface Coordinates relative to Structure: 56.40 N, 67.60 E (True) Kelly Bushing: 51.60ft above Mean Sea Level ~ '~""'''''''\I-SU'''' CRIL_LING" SERVICËfs A Halliburton Company Proposal Ref: pro11243 Sperry-Sun Drilling Services . Proposal Report for PSI 1 WPS - PSI 1 WP06 Revised: 9 July, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (o/100ft) 0.00 0.000 0.000 -51.60 0.00 O.OON O.OOE 0.00 Begin 16" Hole 34.00 0.000 0.000 -17.60 34.00 O.OON O.OOE 0.000 0.00 900.00 0.000 0.000 848.40 900.00 O.OON O.OOE 0.000 0.00 Begin Dir @ 1.0000/100ft : 900.00ft MD, 900.00ft TVD ~ 1000.00 1.000 311.680 948.39 999.99 0.58N 1.000 0.87 1100.00 2.000 311.680 1048.36 1099.96 2.32N 1.000 3.49 1200.00 3.000 311.680 1148.26 1199.86 707821.01 E 1.000 7.85 1300.00 4.000 311.680 1248.08 1299.68 707816.34 E 1.000 13.96 1400.00 5.000 311.680 1347.77 1399.37 707810.34 E 1.000 21.80 Increase in Dir Rate @ 1.5000/100ft : 1400.00ft MD, 1399.37ft TVD 1500.00 6.500 311.680 1447.26 1498.86 23.77 W 5966118.13 N 707802.68 E 1.500 31.82 1600.00 8.000 311.680 1546.46 1598.00 33.19W 5966126.26 N 707793.02 E 1.500 44.44 - 1700.00 9.500 311.680 1645.29- - 1696f89 39.67 N 44.55 W 5966136.06 N 707781 .39 E 1.500 59.65 1800.00 11 .000 311.680 1 743.69 = 1795I29 51 .50 N 57.84 W 5966147.52 N 707767.77 E 1.500 77.45 1826.82 11.402 311.680 1770.00 ~-1.82l-.60 54.96 N 61.73 W 59661 50.87 N 707763.79 E 1.500 82.66 End Dir, Start Sail @ 11.402° : 1826.82ftMD, 1821.6OOTVD 1877.83 11 .402 311.680 1820.00 1871 .60 61 .67 N 69.27 W 5966157.37 N 707756.07 E 0.000 92.74 BPERMAFROST 1900.00 11 .402 311.680 1841.74 1893.34 64.58 N 72.54 W 5966160.19 N 707752.72 E 0.000 97.12 1928.83 11 .402 311 .680 1870.00 1921.60 68.37 N 76.80 W 5966163.86 N 707748.36 E 0.000 102.82 Begin Dir @ 2.000°/1000 : 1928.83ft MD, 1921.60ft TVD 2000.00 12.826 311 .680 1939.58 1991.18 78.31 N 87.95 W 5966173.48 N 707736.94 E 2.000 117.76 2100.00 14.826 311.680 2036.68 2088.28 94.20 N 105.80 W 5966188.87 N 707718.66 E 2.000 141 .65 .~~ 2200.00 16.826 311.680 2132.88 2184.48 112.33 N 126.16 W 5966206.43 N 707697.80 E 2.000 168.92 2300.00 18.826 311.680 2228.08 2279.68 132.68 N 149.03 W 5966226.15 N 707674.38 E 2.000 199.53 2400.00 20.826 311.680 2322.15 2373.75 155.24 N 174.36 W 5966247.99 N 707648.43 E 2.000 233.45 2500.00 22.826 311 .680 2414.97 2466.57 179.96 N 202.12 W 5966271.93 N 707620.00 E 2.000 270.63 Increase in Dir Rate @ 3.500°/1000 : 2500.00ft MD, 2466.57ft TVD 2600.00 26.326 311 .679 2505.90 2557.50 207.61 N 233.18 W 5966298.72 N 707588.18 E 3.500 312.21 2700.00 29.826 311.679 2594.12 2645.72 238.90 N 268.32 W 5966329.02 N 707552.19 E 3.500 359.26 2799.20 33.298 311.678 2678.64 2730.24 273.42 N 307.10 W 5966362.46 N 707512.47 E 3.500 411.18 End Dir, Start Sail @ 33.298° : 2799 .20ftM D ,2730.24ftTVD 9 July, 2002 - 17:22 Page 2 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for PSI 1 WPS - PSI 1 WP06 Revised: 9 July. 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) COlt OOft) 2800.00 33.298 311.678 2679.30 2730.90 273.71 N 307.43 W 5966362.7j 512.14E 0.000 411 .62 2900.00 33.298 311 .678 2762.88 2814.48 310.22 N 348.43 W 5966398~10N 470.14 E 0.000 466.52 3000.00 33.298 311.678 2846.47 2898.07 346.72 N 389.43 W 5966433.45 N~ 28.14 E 0.000 521.42 3100.00 33.298 311.678 2930.05 2981.65 383.23 N 430.44 W - 500ê:46tk81. N 7Øp386.14 E 0.000 576.32 - 3200.00 33.298 311.678 3013.63 3065.23 419.73 N -: 5966504.tõN 707344.14 E 0.000 631.21 3300.00 33.298 311.678 3097.22 3148.82 :~6539.5¿ N 707302.14 E 0.000 686.11 3400.00 33.298 311.678 3180.80 3232.40 5966574.88 N 707260.15 E 0.000 741 .01 3500.00 33.298 311.678 3264.38 3315.98 5 5966610.23 N 707218.15 E 0.000 795.91 3600.00 33.298 311.678 3347.96 3399.56 635.46 W 5966645.59 N 707176.15 E 0.000 850.81 3700.00 33.298 311.678 3431.55 3483.15 676.46 W 5966680.94 N 707134.15 E 0.000 905.71 3707.72 33.298 311.678 3438.00 34~89.sq - 679.63 W 5966683.67 N 707130.91 E 0.000 909.95 SV4 3800.00 33.298 311.678 3515.1 :l 3566. 73~ - 717.46W 5966716.30 N 707092.15 E 0.000 960.61 3900.00 33.298 311.678 3598.7f- c 365(l~1 - 758.47 W 5966751.66 N 707050.16 E 0.000 1015.51 4000.00 33.298 311.678 3682.30 ~--¿ 3733>'90 799.47 W 5966787.01 N 707008.16 E 0.000 1070.41 4100.00 33.298 311.678 3765.88 :-.3817.48 840.47 W 5966822.37 N 706966.16 E 0.000 1125.31 4197.05 33.298 311 .678 3847.00 3898.60 783.70 N 880.27 W 5966856.68 N 706925.40 E 0.000 1178.58 SV3 4200.00 33.298 311.678 3849.46 3901.06 784.78 N 881.48 W 5966857.72 N 706924.16 E 0.000 1180.20 4300.00 33.298 311.678 3933.04 3984.64 821 .28 N 922.48 W 5966893.08 N 706882.16 E 0.000 1235.10 4400.00 33.298 311.678 4016.63 4068.23 857.79 N 963.49 W 5966928.44 N 706840.16 E 0.000 1290.00 4438.73 33.298 311.678 4049.00 4100.60 871 .93 N 979.37 W 5966942.13 N 706823.90 E 0.000 1311.26 SV2 4500.00 33.298 311.678 4100.21 4151.81 894.29 N 1004.49 W 5966963.79 N 706798.17 E 0.000 1344.90 ~ 4600.00 33.298 311.678 4183.79 4235.39 930.80 N 1045.49 W 5966999.15 N 706756.17 E 0.000 1399.80 4700.00 33.298 311.678 4267.38 4318.98 967.30 N 1086.50 W 5967034.50 N 706714.17 E 0.000 1454.70 4800.00 33.298 311 .678 4350.96 4402.56 1003.81 N 1127.50 W 5967069.86 N 706672.17 E 0.000 1509.60 4898.16 33.298 311.678 4433.00 4484.60 1039.64 N 1167.75 W 5967104.57 N 706630.95 E 0.000 1563.49 SV1 4900.00 33.298 311 .678 4434.54 4486.14 1040.31 N 1168.50 W 5967105.22 N 706630.17 E 0.000 1564.50 5000.00 33.298 311.678 4518.13 4569.73 1076.82 N 1209.51 W 5967140.57 N 706588.18 E 0.000 1619.40 5097.96 33.298 311 .678 4600.00 4651.60 1112.58N 1249.68 W 5967175.21 N 706547.03 E 0.000 1673.18 Begin 12-1/4" Hole 133/8" Casing 5100.00 33.298 311.678 4601.71 4653.31 1113.32 N 1250.51 W 5967175.93 N 706546.18 E 0.000 1674.30 5200.00 33.298 311.678 4685.29 4736.89 1149.83 N 1291.52 W 5967211.28 N 706504.18 E 0.000 1729.19 9 July. 2002 - 17:22 Page 3 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for PSI 1 WPS - PSI 1 WP06 Revised: 9 July, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 5300.00 33.298 311.678 4768.87 4820.47 1186.33 N 5967246.64 462.18 E 0.000 1784.09 5400.00 33.298 311.678 4852.46 4904.06 1222.84 N 596728~tOON 420.18 E 0.000 1838.99 5500.00 33.298 311.678 4936.04 4987.64 1259.34 N 5967311.35 N c 78.18 E 0.000 1893.89 5519.10 33.298 311.678 4952.00 5003.60 1266.31 N 50073Z~U 1 f'!. 7; 70.16 E 0.000 1904.38 UG4 5600.00 33.298 311.678 5019.62 5071 .22 1295.85 N N 706336.19 E 0.000 1948.79 5700.00 33.298 311.678 5103.21 5154.81 7388.07 N 706294.19 E 0.000 2003.69 5800.00 33.298 311.678 5186.79 5238.39 5967423.42 N 706252.19 E 0.000 2058.59 5808.63 33.298 311.678 5194.00 5245.60 5967426.47 N 706248.57 E 0.000 2063.33 UG3 5900.00 33.298 311.678 5270.37 5321.97 5967458.78 N 706210.19 E 0.000 2113.49 6000.00 33.298 311.678 5353.95 5405.55 5967494.13 N 706168.19 E 0.000 2168.39 6100.00 33.298 311.678 5437.54 5489.14~ 1660.55 W 5967529.49 N 706126.20 E 0.000 2223.29 6200.00 33.298 311.678 5521.12. - 55-12]2 1701.55 W 5967564.85 N 706084.20 E 0.000 2278.18 6300.00 33.298 311.678 5604.70 5656,30 1742.56 W 5967600.20 N 706042.20 E 0.000 2333.08 6400.00 33.298 311.678 5688.29 . 5739,89 1783.56 W 5967635.56 N 706000.20 E 0.000 2387.98 6500.00 33.298 311.678 5771.87 5~3.47 1824.56 W 5967670.91 N 705958.20 E 0.000 2442.88 6575.53 33.298 311.678 5835.00 5886.60 1651.96 N 1855.53 W 5967697.62 N 705926.48 E 0.000 2484.35 UG1 6600.00 33.298 311.678 5855.45 5907.05 1660.89 N 1865.57 W 5967706.27 N 705916.20 E 0.000 2497.78 6700.00 33.298 311.678 5939.03 5990.63 1697.40 N 1906.57 W 5967741.63 N 705874.21 E 0.000 2552.68 6800.00 33.298 311.678 6022.62 6074.22 1733.90 N 1947.57 W 5967776.98 N 705832.21 E 0.000 2607.58 6900.00 33.298 311.678 6106.20 6157.80 1770.41 N 1988.58 W 5967812.34 N 705790.21 E 0.000 2662.48 7000.00 33.298 311.678 6189.78 6241 .38 1806.91 N 2029.58 W 5967847.69 N 705748.21 E 0.000 2717.38 ~~ 7100.00 33.298 311.678 6273.37 6324.97 1843.42 N 2070.58 W 5967883.05 N 705706.21 E 0.000 2772.28 7200.00 33.298 311.678 6356.95 6408.55 1879.92 N 2111.59 W 5967918.41 N 705664.22 E 0.000 2827.17 7208.44 33.298 311.678 6364.00 6415.60 1883.00 N 2115.05 W 5967921.39 N 705660.67 E 0.000 2831.81 WEST SAK 2 7300.00 33.298 311.678 6440.53 6492.13 1916.43 N 2152.59 W 5967953.76 N 705622.22 E 0.000 2882.07 7400.00 33.298 311.678 6524.11 6575.71 1952.93 N 2193.60 W 5967989.12 N 705580.22 E 0.000 2936.97 7439.34 33.298 311.678 6557.00 6608.60 1967.29 N 2209.73 W 5968003.03 N 705563.70 E 0.000 2958.57 WEST SAK 1 7500.00 33.298 311.678 6607.70 6659.30 1989.44 N 2234.60 W 5968024.47 N 705538.22 E 0.000 2991.87 7600.00 33.298 311.678 6691.28 6742.88 2025.94 N 2275.60 W 5968059.83 N 705496.22 E 0.000 3046.77 7670.25 33.298 311.678 6750.00 6801 .60 2051.59 N 2304.41 W 5968084.67 N 705466.72 E 0.000 3085.34 CM3 9 July, 2002 - 17:22 Page 4 of 10 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for PSI 1 WPS - PSI 1 WP06 Revised: 9 July, 2002 BPXA North Slope Alaska Lisburne PSI (East Dock) Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 7700.00 33.298 311.678 6774.86 6826.46 2062.45 N 454.22 E 0.000 3101.67 7800.00 33.298 311.678 6858.45 6910.05 2098.95 N 412.23 E 0.000 3156.57 7900.00 33.298 311.678 6942.03 6993.63 2135.46 N 70.23 E 0.000 3211.47 8000.00 33.298 311.678 7025.61 7077.21 2171.96 N -, 28.23 E 0.000 3266.37 _. 8100.00 33.298 311.678 7109.19 7160.79 2208.47 N 705286.23 E 0.000 3321.27 8200.00 33.298 311.678 7192.78 7244.38 705244.23 E 0.000 3376.16 8248.60 33.298 311.678 7233.40 7285.00 705223.82 E 0.000 3402.84 Begin Dir @ 1.500°/1000: 8248.60ft MD, 7285.00ft TVD 8300.00 32.527 311.678 7276.55 7328.15 5968307.14 N 705202.46 E 1.500 3430.77 8400.00 31.027 311.678 7361.56 7413.16 5968341.05 N 705162.17 E 1.500 3483.43 8421.49 30.704 311.678 7380.00 7431.60 5968348.15 N 705153.74 E 1.500 3494.46 CM2 . . 8500.00 29.527 311.678 7447.91 ~..~.. 7499.51'-' 2639.40 W 5968373.52 N 705123.60 E 1.500 3533.85 8600.00 28.027 311.679 7535.56- -~ 7587"t6 - 2675.35 W 5968404.52 N 705086.78 E 1.500 3581.99 8698.39 26.551 311.679 7623.00 - 7674:60 2709.04 W 5968433.57 N 705052.27 E 1.500 3627.10 CM1 8700.00 26.527 311.679 7624.44 .'l6nÜ)4 2709.58 W 5968434.04 N 705051.72 E 1.500 3627.81 8800.00 25.027 311.679 7714.49 :H66.09 2742.06 W 5968462.04 N 705018.45 E 1.500 3671.30 8900.00 23.527 311.679 7805.64 7857.24 2468.56 N 2772.77 W 5968488.52 N 704987.00 E 1.500 3712.41 9000.00 22.027 311.679 7897.84 7949.44 2494.30 N 2801.68 W 5968513.45 N 704957.39 E 1.500 3751.13 9100.00 20.527 311.680 7991.02 8042.62 2518.43 N 2828.78 W 5968536.82 N 704929.63 E 1.500 3787.41 9135.17 19.999 311.680 8024.01 8075.61 2526.53 N 2837.88 W 5968544.67 N 704920.31 E 1.500 3799.59 End Dir, Start Sail @ 19.999° : 9135.17ftMD,8075.61ftTVD THRZ ,..-. 9200.00 19.999 311.680 8084.94 8136.54 2541.27 N 2854.44 W 5968558.95 N 704903.35 E 0.000 3821.77 9300.00 19.999 311.680 8178.91 8230.51 2564.02 N 2879.98 W 5968580.97 N 704877.19 E 0.000 3855.97 9327.77 19.999 311.680 8205.00 8256.60 2570.33 N 2887.07 W 5968587.09 N 704869.92 E 0.000 3865.46 Begin 8-1/2" Hole 9 5/8" Casing BH RZ/CUfTZ3fTCGL 9365.01 19.999 311.680 8240.00 8291 .60 2578.80 N 2896.59 W 5968595.29 N 704860.18 E 0.000 3878.20 TZ2C/BCGL 9400.00 19.999 311.680 8272.88 8324.48 2586.76 N 2905.52 W 5968603.00 N 704851.02 E 0.000 3890.17 9417.16 19.999 311.680 8289.00 8340.60 2590.66 N 2909.91 W 5968606.78 N 704846.53 E 0.000 3896.04 TZ2B/23SB 9 July, 2002 - 17:22 Page 5 of 10 Dri//Quest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for PSI 1 WPS - PSI 1 WP06 Revised: 9 July, 2002 North Slope Alaska Measured Sub-Sea Vertical local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 9500.00 19.999 311.680 8366.85 8418.45 2609.50 N 2931 .07 W 5968625.Q~ 24.86 E 9600.00 19.999 311.680 8460.82 8512.42 2632.24 N 2956.61 W 596864 ].05f\t 798.70 E 9655.53 19.999 311.680 8513.00 8564.60 2644.87 N 2970.80 W 5968659.29 N~ 84.17 E 9700.00 19.999 311.680 8554.79 8606.39 2654.99 N 2982.16 W 596866!};O8 N..:- 772.53 E 9772.59 19.999 311.680 8623.00 8674.60 2671.49 N 3oømBW . 5968685.01N 7 4753.54 E All data is in Feet (US) unless otherwise stated. Directions and coordinates arl Vertical depths are relative to PSI slot A. Northings and Eastings are ri Magnetic Declination at Surface is 26.501 ° (09-Jul-02). The Dogleg Severity is in Degrees per 100 feet (UScr;.~"- !c. Vertical Section is from PSI slot A and calculated alol1g~n AziJnuth Based upon Minimum Curvature type calculations, at a r\lfèåsured Depth of 9772.500., The Bottom Hole Displacement is 4017.60ft., in the Direction of 311.678° (True). Comments Measured Depth (ft) 0.00 900.00 1400.00 1826.82 1928.83 2500.00 2799.20 5097.96 8248.60 9135.17 9 July, 2002 - 17:22 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 900.00 1399.37 1821.60 1921.60 O.OON O.OON 14.50 N 54.96 N 68.37 N 2466.57 2730.24 4651 .60 7285.00 8075.61 179.96 N 273.42 N 1112.58 N 2262.71 N 2526.53 N Comment 0.00 E O.OOE 16.28 W 61 .73 W 76.80 W Begin 16" Hole Begin Dir @ 1.0000/100ft : 900.00ft MD, 900.000 TVD Increase in Dir Rate @ 1.500°/1000: 1400.00ft MD, 1399.37ft TVD End Dir, Start Sail @ 11.402° : 1826.82ftMD,1821.6OOTVD Begin Dir @ 2.0000/100ft : 1928.83ft MD, 1921.60ft TVD 202.12 W 307.10 W 1249.68 W 2541.55 W 2837.88 W Increase in Dir Rate @ 3.5000/10Oft: 2500.00ft MD, 2466.57ft TVD End Dir, Start Sail @ 33.298° : 2799.2OOMD,2730.24ftTVD Begin 12-1/4" Hole Begin Dir @ 1.500°/1 OOft : 8248.600 MD, 7285.00ft TVD End Dir, Start Sail @ 19.999° : 9135.17ftMD,8075.61ftTVD Page 6 of 10 Dogleg Rate (o/100ft) 0.000 0.000 0.000 0.000 0.000 Vertical Section 3924.37 3958.57 3977.56 3992.77 4017.60 . BPXA Lisburne PSI (East Dock) Comment BSAD Total Depth: 9772.59ftMD ,867 4.60ftTVD 7" Liner TDITLSB ~ DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for PSI 1 WPS - PSI 1 WP06 Revised: 9 July, 2002 . North Slope Alaska BPXA Lisburne PSI (East Dock) Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9327.77 9772.59 8256.60 8674.60 2570.33 N 2671.49 N 2887.07 W 3000.70 W Begin 8-1/2" Hole - ~- - ;- - -- Total Depth : 9'7cl~D.8P74.6E}ftT\fQ~ .~"'<-'% Comments (Continued) Formation Tops Formati on Plane Profile (Below Well Origin) Measured Vertical Sub-Sea Dip Dip Dir. Depth Depth Eastings Formation Name (ft) Deg. Deg. (ft) (ft) 1820.00 0.000 0.000 1877.83 61 .67 N 69.27 W BPERMAFROST 3438.00 0.000 0.000 3707.72 605.07 N 679.63 W SV4 3847.00 0.000 0.000 4197.05 783.70 N 880.27 W SV3 4049.00 0.000 0.000 4438.73 871 .93 N 979.37 W SV2 4433.00 0.000 0.000 4898.16 1039.64 N 1167.75 W SV1 4952.00 0.000 0.000 5519.10 5003.60 4952.00 1266.31 N 1422.36 W UG4 5194.00 0.000 0.000 5808.63 5245.60 5194.00 1372.01 N 1541.08 W UG3 5835.00 0.000 0.000 6575.53 5886.60 5835.00 1651.96 N 1855.53 W UG1 6364.00 0.000 0.000 7208.44 6415.60 6364.00 1883.00 N 2115.05 W WEST SAK 2 6557.00 0.000 0.000 7439.34 6608.60 6557.00 1967.29 N 2209.73 W WEST SAK 1 ~ 6750.00 0.000 0.000 7670.25 6801.60 6750.00 2051 .59 N 2304.41 W CM3 7380.00 0.000 0.000 8421.49 7431.60 7380.00 2323.63 N 2609.98 W CM2 7623.00 0.000 0.000 8698.39 7674.60 7623.00 2411.83 N 2709.04 W CM1 8024.02 0.000 0.000 9135.17 8075.61 8024.01 2526.53 N 2837.88 W THRZ 8205.00 0.000 0.000 9327.77 8256.60 8205.00 2570.33 N 2887.07W BHRZ/CUrrZ3rrCGL 8240.00 0.000 0.000 9365.01 8291 .60 8240.00 2578.80 N 2896.59 W TZ2C/BCGL 8289.00 0.000 0.000 9417.16 8340.60 8289.00 2590.66 N 2909.91 W TZ2B/23SB 8513.00 0.000 0.000 9655.53 8564.60 8513.00 2644.87 N 2970.80 W BSAD 8623.00 0.000 0.000 9772.59 8674.60 8623.00 2671 .49 N 3OOO.70W TDrrLSB 9 July, 2002 - 17:22 Page 70t10 DrillQuest 2.00.09.006 North Slope Alaska Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> <Surface> <Surface> Targets associated with this wellpath Target Name PSI1 T1 PSI 1 TD Gee Poly 9 July, 2002 - 17:22 Sperry-Sun Drilling Services Proposal Report for PSI 1 WPs - PSI 1 WP06 Revised: 9 July, 2002 To Measured Vertical Depth Depth (ft) (ft) 5097.96 9327.77 9772.59 Casing Detail 4651.60 8256.60 8674.60 13 3/8" Casing 9 5/8" Casing 7" Liner Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Boundary Point #1 #2 #3 #4 Mean Sea Level/Global Coordinates #1 #2 #3 #4 Page 8 of 10 Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 8256.60 2570.24 N 2887.00 W 8205.00 5968587.00 N 704870.00 E 70° 19' 03.9682" N 148° 20' 21.0086" W 8674.60 2671.40 N 3000.62 W 8623.00 5968684.98 N 704753.62 E 70° 19' 04.9628" N 148° 20' 24.3253" W 8674.60 2793.47 N 3109.20 W 8674.60 2571.44 N 3111.16W 8674.60 2567.04 N 2879.88 W 8674.60 2793.95 N 2873.59 W 8623.00 5968804.00 N 704641.70 E 8623.00 5968582.00 N 704645.89 E 8623.00 5968584.00 N 704877.20 E 8623.00 5968811.00 N 704877.21 E . BPXA Lisburne PSI (East Dock) Target Target Shape Type Point Drillers Polygon Geological -'. DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for PSI 1 WPS - PSI 1 WP06 Revised: 9 July, 2002 North Slope Alaska Target Name Targets associated with this wellpath (Continued) Geographical Coordinates #1 #2 #3 #4 PSI TD DD's Poly @ 95% Mean Sea L-elJellGjobal Coordinates: Geograpbiçal Coordinates: Boundary Point #1 #2 #3 #4 #5 #6 #7 #8 #9 #10 #11 #12 #13 #14 #15 #16 Mean Sea Level/Global Coordinates #1 #2 #3 #4 #5 #6 #7 #8 #9 #10 9 July, 2002 - 17:22 Page 9 of 10 Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 1.6.1630" N 1480 20' 27.4953" W ... 13.9792" N 1480 20' 27.5497" W 70019' 03.9368" N 148020' 20.8010" W 70019' 06.1686" N 148020' 20.6199" W 8674.60 8623.00 2671 .40 N 3000.62 W 5968684.98 N 704753.62 E 700 19' 04.9628" N 1480 20' 24.3253" W 8674.60 2751.71 N 3065.93 W 8674.60 2743.60 N 3073.85 W 8674.60 2729.66 N 3076.94 W 8674.60 2632.11 N 3078.24 W 8674.60 2617.15 N 3076.57 W 8674.60 2608.96 N 3068.40 W 8674.60 2607.41 N 3056.05 W 8674.60 2605.29 N 2932.61 W 8674.60 2607.02 N 2920.85 W 8674.60 2615.33 N 2911.26 W 8674.60 2629.56 N 2907.75 W 8674.60 2729.85 N 2904.51 W 8674.60 2745.26 N 2905.83 W 8674.60 2753.62 N 2913.97 W 8674.60 2754.94 N 2926.61 W 8674.60 2754.39 N 3053.07 W 8623.00 5968763.45 N 704686.11 E 8623.00 5968755.12 N 704678.42 E 8623.00 5968741.10 N 704675.72 E 8623.00 5968643.55 N 704677.12 E 8623.00 5968628.65 N 704679.20 E 8623.00 5968620.69 N 704687.59 E 8623.00 5968619.48 N 704699.98 E 8623.00 5968620.77 N 704823.43 E 8623.00 5968622.83 N 704835.14 E 8623.00 5968631.40 N 704844.50 E . BPXA Lisburne PSI (East Dock) Target Target Shape Type Polygon Drillers ~ DrillQuest 2.00.09.006 . Sperry-Sun Drilling Services Proposal Report for PSI 1 WPS - PSI 1 WP06 Revised: 9 July, 2002 BPXA Lisburne PSI (East Dock) North Slope Alaska Entry Coordinates Northings Eastings (ft) (ft) 8645.72 N 704847.61 E 8746.06 N 704848.08 E 761 .43 N 704846.33 E 769.56 N 704837.96 E 770.53 N 704825.29 E 5968766.48 N 704698.89 E Target TVD (ft) 8623.00 8623.00 8623.00 8623.00 8623:00 8623.Q() Target Target Shape Type Target Name #11 #12 #13 #14 #15 #16 1480 20' 26.2321" W 148020' 26.4630" W 148020' 26.5530" W 1480 20' 26.5897" W 1480 20' 26.5409" W 1480 20' 26.3025" W 1480 20' 25.9421" W 1480 20' 22.3401" W 148020' 21.9969" W 148020' 21.7171" W 148020' 21.6150" W 1480 20' 21 .5214" W 148020' 21.5602" W 148020' 21.7978" W 148020' 22.1666" W 148020' 25.8569" W 700 19' 05.7524" N 700 19' 05.6725" N 700 19' 05.5354" N 700 19' 04.5760" N 700 19' 04.4289" N 700 19' 04.3484" N 700 19' 04.3332" N 70019' 04.3127" N 700 19' 04.3299" N 700 19' 04.4116" N 70019' 04.5516" N 700 19' 05.5379" N 700 19' 05.6895" N 70019' 05.7717" N 70019' 05.7846" N 700 19' 05.7787" N Geographical C 3 #4 #5 #6 #7 #8 #9 #10 #11 #12 #13 #14 #15 #16 --., DrillQuest 2.00.09.006 9 July, 2002 - 17:22 Page 10 of 10 Nan~ +N'~S +Ei-W Northing PSI I 5%(>09;6.1 :'6.31 67,68 =J§å -125 -100 -75 -50 -25 -0 270- -25 -50 -75 -100 -125 =H~ WI:1.1. DETAll.S COMPANY DEL\ll S SURV¡:Y PRO(iRAM WI.I.I.I'''TII DIT\IIS ANì1-COLLlSION SETTINGS Eas.ring Longitude BP Nn()CO Je-plhFm.OepthTt) Suryt"yIPÞn 5!XJ,OO PJannoo: PSI I wp(16 V I 9;72.59 Plannoo: PSI I wp06 V I Tnp I'Lln I'~I J Slot Lîtitude Inlerpolalion MeIhod:MO Imerval: 50.00 Deplh Range From: 34.00 To: 9772.59 Maximum Range: 1173.86 Reference: Plan: PSI I wp06 P~lIl Pf.\l.O-: U;O' (J).J.t¡ SI.linn '" Cß.-GYRO-SS Ri< MWI>+JfR+MS nd.l>iltUlll Cakulatinn Method. Errof Sysl.:m. Scan Me[hQJ. E1Tor Surface. Waming Mett\(!{l: 707x2ì.02 70' JR38.693N (..)8" J8'56.765\\"" NfA V.Si.'~1Þ11I ^ngk Orj~1II Ongul St.iltulJ; +Ni.s ,.(I\\' I"r\lm 1\,) noo (W(I 0.00 'I I./\.' fr""î Colour 11- ~"II- "'III) 7~11 - ToMD 250 500 750 1000 1250 1500 1750 2000 4000 6000 8000 9000 9250 9500 9750 LEGEND - PSI 10 (pIon PSI 10), hla~'r Ri,k - PSI5 1PL1n PSI:)), ~L1jlr Hi..).: - PSI 6 (Rig PSI.06I, MaJnr Risk - PSI; IPJ¡,n PSI Î), hÞ~'r Risk - PSI 8 ¡Pion PSI 8,. M.pr RL'k - I'SI ~ (RI!: PSI 9), Ma1)¡ R... - IJIAYST.UI WßAY~'1'.()), Minnr 1f2<X1 - U.UI (U.OI), Maj<>rRi,k - I'tJlIPSl1 --- I)SII wpM 1111111- ( ~"II 1"\1111 I 7 "II ~11I1I1 ,~II( III '1411111 MIIIII '1111111 t-l ~ ~;(I '~IIII PL,n: PSI I wpl)"; ¡PSI IIPlan PSI I) ............ ("rç.at~-ó B)"; P('~I.;h HoltLJuan [>at..:: 07¡W . Re\it....'(~d. -----~----------- [);¡"---- ApprowJ: ---- tr<lt(-. lRO '-'--EBAYST-Ol (EBAYST-Ol) SECTION [JET AILS s« Mt> 1m: A/.i TVD +NI.S .IJW I~.<l Thu:c VSec Target I 34.00 0.00 0,00 .1-I,()(I 0.00 0.00 0.00 0.00 0,00 .) 91)),00 0.00 0,00 900.00 0,00 0.00 0,00 0.00 0.00 :I 1400.00 ~.OO 311.(,~ JJ99.3ï 1~.50 ~j6.28 1.00 311.68 21.80 4 1826,82 11..10 311.68 1821.60 5.1.% .61.73 1.50 0.00 82.61\ 5 1928.83 IJAO 311.68 1921.60 68.37 .76.80 0,00 0,00 102.82 6 25{X)JX} 22.K3 311.68 2-,511 119.% .201.12 2.1.) o.m 270.6.1 7 279Y.20 3330 311.68 2730.23 27.~.42 .:J07,(j :1.50 U.UO ~II.III 8 8248.59 33.30 311.68 7285./XI 2262.78 -25~1.~8 0.00 0,00 :J.I02.II~ 9 9135,16 20.00 311.68 80;5.61 2526.6[ -2837.80 1.50 180,00 ~799.~R 10 9:'27.76 20.00 311.(>8 8256.(,(1 2570.41 .2886.99 0.00 0.00 3865..1, 11 9ï72.59 20,00 311.68 867~,(,(I 2671.57 ~3000.62 000 0.00 4017.59 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [50ft/in] .' . Sperry-Sun Anticollision Report ( Company: BP Amoco Field: Usbume Reference Site: East Dock (PSI) Reference Well: PSI 1 Reference Wellpath: Plan PSI 1 GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 34.00 to 9772.59 ft Maximum Radius: 1173.86 ft Survey Program for Definitive Wellpath Date: 08/30/2001 Validated: No Planned From To Survey ft ft 34.00 500.00 500.00 9772.59 Summary <.. ~....~_.........._.~_.~..Offsèt .Wèllpatb .__..~_._----_._--..---- > Site Well Wellpath Site: East Dock (PSI) Well: PSI 10 Rule Assigned: Wellpath: Plan PSI 10 V8 Plan: PSI 10 wp04 V1 Inter-Site Error: Reference Offset SeP1i-MajorAxis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI. TFO-HS Casing Distance Area De,'iation Warning 1t ft ft ft ft ft deg deg in ft ft ft 50.00 50.00 50.00 50.00 0.04 0.08 71.61 71.61 13.375 270.06 1.80 268.26 Pass 75.00 75.00 75.00 75.00 0.09 0.13 71.61 71.61 13.375 270.06 2.36 267.70 Pass 100.00 100.00 100.00 100.00 0.15 0~16 71.61 71.61 13.375 270.06 2.88 267.18 Pass 125.00 125.00 125.00 125.00 0.24 0.28 71.61 71.61 13.375 270.06 3.75 266.31 Pass 150.00 150.00 150.00 150.00 0.32 0.37 71.61 71.61 13.375 270.06 4.52 265.54 Pass 175.00 175.00 0.41 0.44 71.61 71.61 13.375 270.06 5.25 264.82 Pass 200.00 200.00 0.50 0.50 71.61 71.61 13.375 270.06 5.94 264.13 Pass 225.00 225.00 0.55 0.56 71.61 71.61 13.375 270.06 6.54 263.52 Pass 250.00 250.00 0.61 0.62 71.61 71.61 13.375 270.06 7.12 262.94 Pass 275.00 275.00 0.66 0.67 71.61 71.61 13.375 270.06 7.69 262.37 Pass 300.00 300.00 0.72 0.72 71.61 71.61 13.375 270.06 8.25 261.81 Pass 325.00 325.00 0.77 0.77 71.60 71.60 13.375 270.06 8.80 261.26 Pass 350.00 350.00 0.81 0.82 71.57 71.57 13.375 270.06 9~33 260.72 Pass 375.00 375.00 0.86 0.86 71.51 71.51 13.375 270.05 9.86 260.19 Pass 400.00 400.00 0.91 0.90 71.43 71.43 13.375 270.04 10.38 259.66 Pass 424.99 424.99 425.00 424.99 0.92 0.95 71.33 71.33 13.375 270.03 10.82 259.21 Pass 449.98 449.98 450.00 449.98 0.94 0.99 71.20 71.20 13.375 270.02 11.25 258.76 Pass 474.97 474.97 475.00 474.97 0.96 1.04 71.05 71.05 13.375 270.00 11.68 258.32 Pass 499.96 499.96 500.00 499.96 0.97 1.08 70.88 70.88 13.375 269.99 12.10 257.88 Pass 524.94 524.94 525.00 524.94 0.98 1.12 70.68 70.68 13.375 269.98 12.50 257.48 Pass Casing Points MD ft 5098.02 I 9327.91 9772.59 1VD 1t 4651.60 8256.60 8674.46 East Döck (PSI) East Dock (PSI) EastDock (PSI) East Dock (PSI) East Dock (PSI) East Dock (PSI) East Dock (PSI) East Dock (PSI) EX EBAYST-01 Lis OS 03 Date: 07/09/2002 Time: 17:28:25 Page: 1 Well: PSI 1, True North Plan PSI-û1 51.60' (0-14) 51.6 Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cytinder North Ellipse + Casing Co-ordinate(NE) Reference: Vertical (TVD) Reference: Reference: Error Model: Scan Method: Error Suñace: Version: Toolcode 7 Tool Name Planned: PSI 1 wp06 V1 Planned: PSI 1 wp06 V1 CB-GYRO-SS MWD+JFR+MS Camera based gyro single shots MW 0 + IFR + Multi Station Diameter in Hole Size in 17 .500 12.250 8.500 PSI10 PSI 5 PSI6 PSI 6 PSI 7 PSI8 PSI 9 PSI 9 EBAYST-01 L3-01 Reference Offset Ctr-Ctr No~Go AlloWQ.ble MD MD Distance. Area Deviation Warning ft ft ft ft ft 922.89 925.00 271.71 19.11 252.60 Pass: Major Risk 1518.88 1525.00 110.02 27.59 82.44 Pass: Major Risk 1094.40 1100.00 134.42 22.17 112.26 Pass: Major Risk 1170.65 1175.00 136.91 19.12 117.85 Pass: Major Risk 1343.09 1350.00 177;94 24.61 153.34 Pass: Major Risk 1044.53 1050.00 203.3'7 21.32 182.05 PaSS: Major Risk 1144.25 1150.00 238.01 22.13 215.89 Pass:. Major Risk 1046.46 1050.00 239.61 16.29 223.35 Pass: Major Risk 300.00 300;00 87.00 4.63 82.37 Pass: Minor 1/200 7036.74 9250.00 246.42 223.18 36.03 Pass: Major Risk Plan PSI 10 V8 Plan: P Plan PSI 5 V5 Plan: PS Plan PSI 6 V13 Plan: P RigPSI-06 V9 PlanPSI7V6.Plan:PS PlanPSI8V12Plan:P Plan PSI 9 V16 Plan: P Rig: PSI 9 V1 EBAYST-01 V4 L3-01 V1 . ' , PC .-01 Completion Desid .~ 100,000 bblslday @ 2700 psi injection pressure XOver #1- Tbg Hanger: 7" NSCC Box X 7-5/8" STL Pin 20" x 34" Insulated Conductor @ +1- 80' Tree: 6-3/8" bore x 7-1/6" 5K, 625 Inlay, CIW H Wellhead: 13-5/8", 5K, Big Bore FMC 7" Cameo 6.00" DB Nipple with Injection Valve at -2200' 7-5/8",29.7#, ST-L, IPC, Injection Tubing (wIT' accessories) 7" x 5.963" HES R Nipple ). ..{ 7" x 9-5/8" Baker Seal Assy 7" x 9-5/8" SABL-3 packer with 20' PBR 7" x 5.963" HES R Nipple 7" x 5.77" HES RN Nipple 7" WLEG 13-3/8" TAM Port Collar @ +1- 1000' MD XOver #2&3-lnjection Valve: 7-5/8" STL Box X 7" TCII Pin 7" TCII Box X 7-5/8" STL Pin 13-3/8", 68#, L-80, BTC Surface Casing @ +1- 4652' TVD; 5098' MD XOver #4-Seal Assembly: 7 -5/8" STL Box X 7" TCII Pin Packer set at +1- 9161' MD 7" x 9-5/8" Baker HMC Liner Hanger, ZXP Liner Top packer, and tieback sleeve 9-5/8",47#, L-80, BTC-M Intermediate Casing @+I- 8257' TVD; 9328' MD Note: All tailpipe and accessories to be TCII 7", 26#, L-80, BTC-M Injection Liner @ +1- 8675' TVD: 9773' MD Date 4-30-02 7-10-02 Comments Rev By RBT RBT Completion Design Move PackerfTailpipe uphole PROJECT: GCWSI WELL: PSI-01 API NO: GPB Rotary Drilling ,iApr-1t.::2-Q02 16:48 From-MCC WING 6 +907-659-5065 (' u .:r .,.. <1. .... '" M :r. ~ ~ Q t:I i (/'. ~. ~ " l ... « .. 9 ~ 0 '.1 L :.: .. ,2 .. 0 ',. r. co .... C> ~ ~ ~ ,. .u c;> ~ 'S - . .. ¿, #/ // . . ,/ /" . PRUDHOE BAY... // .' .../ ..../ ..' ..' . . ,..-.., ../.../ . ...., CI~~ /' . ,.// ...' Q~V /' ...' ~ s>(\ / .' ..' ~w (-..) 0 b p c -"'" :;: 'G ~ f5 a. r -N - I WA INJECTION / WELL FACILITY (EAST DOCK WEST PAD) ...J -' CD 0) ~ ..... I I I ø (/) Vi ü) Z Q.. CL 0. ¡:::. + + +- V) x &..oJ . NOTES: 1. DATE OF SURVEY: APRIl. 12, 2002. 2, REFERENCE FIELD SOOK: PB02-04 PAGES. 29-30. 3. CaORDINA TES ARE ALASKA STATE PLANE. 20NE-4 NAD27. 4. GEOD~TIC COORDINAìE:S ARE NAD-27. 5. EAST DOCK PACH...ITY AVERAGE SCALE FACTOR IS 0.999949103. 6. HORIZONTAL CONTROL ESTABLISHED BY GPS STATIC 08SERVATIONS BASED ON DRILLSITE OPERA TOR MONUMENT "DS-11 A". 7. ELEVAilONS ARE ARea MI...LW BASED ON DRILLSITE 11 OPERATOR MONUMENT "os-nA". T-855 P.Q02/002 F-958 /'XIJDHOE BA'I -- - PROJECT AREA , I~..~.~, ~. ' '- , - '.~ . ;, LISBURNE" DRILL SITE 3 . 21 . 22 .,.' I VICINITY MAP N.T.S. LEGf:ND 4- AS-BUILT CONDUCTOR . ËXISTING CONDUCTOR $URVEYORtS CERTIFICA TE I HERESY CERTifY THAT AM PROPERL Y REGISTERED AND LICENSED iO PRACTICE LAND SuRVEYING IN THE STATE OF" AI...ASKA AND TH AT THIS PLAT REPRESENTS A SuRVEY MADE 13Y ME OR uNDER MY DIRECT suPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF APRIL 12, 2002. LOCA~rED WITHIN PROTRACTED SEC. 15, T. 11. N., R. 15 E., UMIAT MERIDIAN, ALASKA WEl-L .- A.S.P.' PLANT GEODETIC GE"ÖOETIC' CELLAR - SECTION NO, COO~D¡NA TES COOROINA TES POSITION(DM~) POSITION(P.DO) BOX - ELEV. OFTSETS Y;;::;5:966.097.64 N-=10.000.00 - 70"18'38.694" 70.31 Ö7483" -, :S.8"OQ' FSL PSI~1 x= 797,827.02 E= 4..909.96 14S"18'56.767::^ 148.3157694' 17.6' 4.579' F:;. Y=5,966¡14B.95 N:::10,OOO.17 70'18'39.160" 70.3108778" 3,84ä' F'SI. PSI-6 x= 7071~67.83 E= 5,959.83 118'18'52.619~. J 48.31461671' 17.6' 4.436' FEL Y= 5,966,179.51 N== 9.999.86 70.18'39.438" 70.3109550" :5 876' PSL PSI-9 x~ 708,05.2.69 E= 5,150.02 148"18':5°.120" 14?3139222' - 17.4' 4,351' FEL. -- \~~o.l<ell,-. . -- -,~--' , -.. . -- ! m~illœD J.JC LOn ~fII~ ¥<ttI.q.,a ~~ 41\, w('$( ^"'....~ ""'"' 111' CHt<... ~. --.... ~~ are...wt<, - JACaaS ë;:;(Gi(N-A~i.;;;- -I,...TC 3/27/0;- O~R~~ ED 02-00 . -.(Jc NO, - '~C~f¡ 1 M CI 12(}' T"--r.- '" 0 '-' ." or 0 ~ . Q 4-/, ~/O~ t;"i\JEO FOO lNf'okMA'T1Qf! ~ HO. D)'TJ: RE""~ON ~tA~" bp -¡¡fI.~, GPB EAST DOCK WFI PAD AS-BUILT CONDUCTORS WELLS PSI-1. PSI-B. & PSI-9 Ý,CtT. 1 Of 1 H 206976 DATE 7/1/02 INVOICE / CREDIT MEMO CK062602F ~sr-Ol THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY TO THE ORDER OF DESCRIPTION PERMIT TO DRI~L FEE GROSS TOTAL ~ RE(:Ef\/ED 'JUL 1 0 20)2 Alaska 011 &. Gas Gons.L'mmmsslOf: Anchorage FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 412 B P fi,~ 'r't~~ tlf~ì () f:"(;I~: :. ... w.~..,LIJ' \10" 'HI!!' "'", "'" DATE JULY 1, 2002 VENDOR DISCOUNT DATE 7/01/02 CHECK NO. H206976 NET CONSOLIDATED COMMERCIAL ACCOUNT No. H 206976 *****$100.00***** AMOUNT ALASKA STATE ALASKA üIL& GAS CONSERVATION COMMISSION 333.W 7TH AVE STRIOO ANCHORAGE, AK. 99501 !:!f~~;~~I!~;~t¡; III 2 0 b c:¡ ? b III ': 0 ~ ~ 2 0 3 ß c:¡ 5 I: 0 0 ß ...... . c:¡ III H .-. -'.. CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WE~ INJECTION WELL RED RILL Rev: 6/18/02 C\jody\templates ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME/8ú pç / -- (J / CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) "CL UE" The permit is for a new wellbore segment of existing well --' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), 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). ANNULAR DISPOSAL Please note that an disposal of fluids generated . . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD L.) SP ACING EXCEPTION DRY DITCH SAMPLE Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume 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 the permafrost or from where samples are first caught and 10' sample intervals through target zones. n~ . .WELL PERMIT CHECKLIST COMPANY Iff X WELL NAME /5"/-- 0 / PROGRAM: Exp - Dev - Redrll- Se~.2{. WeHbore seg - Ann. disposal para req - ,FIELD & POOL 6 ~~/ s' ~ INIT CLASS 1- ¿,.v.. ("'~ 0. GEOL AREA ~ í (") UNIT# // C. ç.ð ON/OFF SHORE ~...cJ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y ,N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . .. Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . .. . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit ca~ be issued without administrativ~ approval.. . . . . \ y.1 N 13. Can permit be approved before 15-day walt.. " . . . . . . . W N 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ~N 3t.i It )t Û7 if e tl 3 ' 15. Surface casing protects all known USDWs. . . . . . . . . . . Y N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . N 14-J¿}' cI.ut< F!-"f~CP~ c:" 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y<6P U 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N 19. Casing designs adequate for C, T,S & permafrost. . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . . N ¡JC1LbtPrS 2.. 71E 21. If a re-drill,.has a 10-403 for abandonment been approved. . . .~ ^'11f- 22. Adequate wellbore separation proposed.. . . . . . . . . .-. . ~ N 23. If diverter required, does it meet regulations. . . . . . . . . . . .. N 24. Drilling fluid program schematic & equip list adequate. . . . . .. N 25. SOPEs, do they meet regulation. . . . . . . . . . . . . . . . . N ( -I- t APPR DATE 26. SOPE press rating appropriate; testto tj()()O psig. N mS¡? 30f?.. (J~t. ~. Cr~ f/Ç- i./OtJO 1";'. \riCA- ë ("i 0 l.- 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 1f2 N 28. Work will occur without operation shutdown. . . . . . . . . . . è2t N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y (fjJ 30. Permit can be issued w/o hydrogen sulfide measures. . . . . é5fj N 31. Data presented on potential overpressure zones. . . . . . . $N A) _/1 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y ,.. t '6T7' ~RR -PJ:rJi 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N . Æ/r 7¡ (/( ð/ - 34. Contact name/phone for weekly progress reports [exploratory on. Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal' Y N (D) will not damage producing formation or impair recovery fro Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.41 . Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP~¿ JOH? ~ WGA \JJk~ ftìR ~~?- ENGINEERING GEOLOGY . APPR DATE 1/¿ ?J;)¿ ) /!/¡ Â, Comments/Instructions: COT OTS <' G:\geology\permits\checklist. doc