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186-069
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 25, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC LGI-10 PRUDHOE BAY UN LIS LGI-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2023 LGI-10 50-029-21573-00-00 186-069-0 G SPT 8261 1860690 2065 2667 2667 2667 2665 14 40 41 41 4YRTST P Sully Sullivan 5/23/2023 PT to 3445 for 500 psi dp 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 UN LIS LGI-10 Inspection Date: Tubing OA Packer Depth 58 3445 3429 3421IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230524080427 BBL Pumped:10.4 BBL Returned:6.9 Tuesday, July 25, 2023 Page 1 of 1 MEMORANDUM State of Alaska Depth Alaska Oil and Gas Conservation Commission TO: Jim Regg 1 ie s�2�-��9 DATE: Wednesday, May 22, 2019 P.I. Supervisor fr SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. Type Test SPT Test psi 1 LGI-10 FROM: Matt Herrera PRUDHOE BAY LIN LIS LGI-10 Petroleum Inspector BBL Pumped- I IBBL Returned 1 Src: Inspector Reviewed By: P P.I. Supry y) NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN LIS LGI-10 API Well Number 50-029-21573-00-00 Inspector Name: Matt Herrera Insp Num: mi[MFH190521125331 Permit Number: 186-069-0 Inspection Date: 5/192019 Rel Insp Num: Wednesday, May 22, 2019 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1,01-10 Type Inj G TVD 8261 Tubing 3490 3469 - 3468 - 3JOS PTD 1860690 Type Test SPT Test psi 1 2065 IA 4.6 — OA 2004 2492 - 2485 IS -1 395 430 429 - 428 --- BBL Pumped- I IBBL Returned 1 Interval 4YRTST P/F P Notes: IA pressure tested to 2500 PSI per Operator This test is a retest after two previous tests that were inconclusive due to unstable IA pressures and flowrates on 5/16/19. LA was fluid packed prior to test and bled back beyond starting pressure thus BBL Return higher than BBL Pump upon test completion. Wednesday, May 22, 2019 Page 1 of 1 MEMORANDUM State of Alaska Pretest Initial Alaska Oil and Gas Conservation Commission � TO: Jim Regg I`� x/22/l� DATE: Tuesday, May 21, 2019 P.I. Supervisory SUBJECT: Mechanical Integrity Tests TVD BP EXPLORATION (ALASKA) INC. Tubing, 3468 1465 LGI-10 FROM: Matt Herrera PRUDHOE BAY UN LIS LGI-10 Petroleum Inspector SPT Test psi Ste: Inspector IA Reviewed By: X501 P.I. Supry-j NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN LIS LOI-10 API Well Number 50-029-21573-00-00 Inspector Name: Matt Herrera IUSp Nom: mi[MFH 190516190746 Permit Number: 186-069-0 Inspection Date: 5/16/2019 Rel Insp Num: Tuesday, May 21, 2019 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well LGI-10 Type Inj G' TVD 5261 Tubing, 3468 1465 1467 PIGS. 3465 PTD' 1860690 Type Test SPT Test psi 2065 IA 212 X501 2506 - 2310 - 2515 BBL Pumped: 3.a BBL Returned: 3.8 OA 23 - _ 28 ', sl 37 ' Interval i 4YRTST P/F I Notes: 1A Pressure testd to 2500 PSI per Operator . Test deemed inconclusive due to unstable IA pressures Tuesday, May 21, 2019 Page 1 of 1 MEMORANDUM TO: Jim Regg l tl P.I. Supervisor FROM: Matt Herrera Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 21, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. LGI-10 PRUDHOE BAY UN LIS LGI-10 Sre: Inspector Reviewed By- P.I. Supry +r77 NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN LIS LGI-10 API Well Number 50-029-21573-00-00 Inspector Name: Man Herrera Permit Number: 186-069-0 Inspection Date: 5/16/2019 IBSp Num: mi[MFH190516191211 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -1 Well LGI-I0 Type Inj C' TVD 8261 Tubing 3473 - 3474 3470 - 7471 - — PTD 1860690 Type Test SPT .Test psi 2065 - IA 2028 - 2500 2512 2524 BBL Pumped: 3.8 ' BBL Returned: 3s OA 104 43 152 - 160 Intervale 4YRTST P/F 1 Notes: Retest due to prior inconclusive result on previous pressure test mitMFH190516190746. IA Pressure testd to 2500 PSI per Operator. lA bled to 2000 PSI and S/I to stabilize for 15 Min. prior to re -test. Test deemed inconclusive due to unstable IA pressures. Tuesday, May 21, 2019 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg (-I DATE: Monday, June 10, 2019 1 ZI I /t� PA. Supervisor t "�`i SUBJECT: Mechanical Integrity Tests l BP EXPLORATION (ALASKA) INC. LGI-10 FROM: Jeff Jones PRUDHOE BAY UN LIS LGI-10 Petroleum Inspector Sre: Inspector Reviewed By: t� P.1. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN LIS LGI-10 API Well Number 50-029-21573-00-00 Inspector Name: Jeff Jones Permit Number: 186-069-0 Inspection Date: 5/14/2019 - Insp Num: mitJJ190531093938 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Vlin Well LGI-10 'IType Inj G T� 8261 TUbing 3534 3143 3550 3548 3556 311s PTD 1s6o690 Ty ep Test sPT (Test psi 2065 IA s5s 2500 1494- zags 2489 24-1 - BBL Pumped: 4 BL Returned: OA 226 427 423 426 427 421 Interval 4YRTST _ IP/F I Notes: This test was inconclusive due to test fluid/wellhead Delta T. Test fluid was not bled back for temp. equalization.l well inspected, no exceptions noted. TIO: 75 Min. 3559/2461/416, 90 Min. 3550/2495/438, 105 Min. 35502495/438, 120 Min. 3480/2474/446, 135 Min. 3479/2466/441, & 150 Min. 3483/2469/442. Monday, June 10, 2019 Page I of 1 • • P& L(i- (0 Regg, James B (DOA) (36,0610 From: Cocklan-vendl, Mary E <mary.cocklan-vendl@bp.com> Sent: Tuesday, September 13, 2016 3:40 PM !7/l To: Regg,James B (DOA) l' ( Cc: AK, OPS FF Well Ops Comp Rep;AK, OPS Pipeline Compl Specialist Subject: RE: LGI-10 Start-Up Backflow Approval Jim, Per our conversation this afternoon, AOGCC approval is granted for this activity. We will put comments on the test report indicating that this miscellaneous test is being conducted to enable backflow for startup purposes to distinguish this test from a normal miscellaneous test. Thanks, Mary C� Pc�`U� ��E� ups Op ,� ,j'.�. `�� Mary E Cocklan-Vend/ tOreg , " ` Pipeline Team Lead n(i?Cu1""� A c4Su� Office Phone-Anchorage: 907-564-4766 ( + "�el Office Phone– North Slope: 907-670-7550 p roceSS Cell Phone: 907-227-3464 ti e-mail: Mary.Cocklan-Vendlnabp.com �Sk?S5 ,use- ASO se- ;asO (20-- From: Cocklan-vendl, Mary E ("&' 00K (-- sei) Sent: Monday, September 12, 2016 9:05 AM �uMe� To: Regg, James B (DOA) (jim.regg@alaska.gov) Cc: AK, OPS FF Well Ops Comp Rep; AK, OPS Pipeline Compl Specialist Subject: LGI-10 Start-Up Backflow Approval Jim, As previously discussed with Vince Pokryfki via phone on September 9th,the Lisburne Production Center(LPC) will be utilizing injection Well LGI-10 to hack feed the LPC Plant for startup purposes.The LPC has been down for Summer TAR work and will coming back online sometime within in the next week. BPXA seeks approval for this Operation which has been performed numerous times in the past with AOGCC approval and notification. A witnessed AOGCC miscellaneous SVS test will be required due to the 1000 psi Low Pressure Pilot that will be installed during this Short term-- Operation. ermOperation. BP will submit the test request at least 24 hours in advance. — Please call me on my cell phone with any questions or concerns that you may have. Thanks, Mary Mary E Cocklan-Vend! Pipeline Team Lead Office Phone-Anchorage: 907-564-4766 Office Phone– North Slope: 907-670-7550 Cell Phone: 907-227-3464 e-mail: Mary.Cocklan-Vendkabp.com 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 01,2015 TO: Jim Regg (-Rep P.I.Supervisor I � I SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC LGI-10 FROM: Matt Herrera PRUDHOE BAY UN LIS LGI-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN LIS LGI-10 API Well Number 50-029-21573-00-00 Inspector Name: Matt Herrera Permit Number: 186-069-0 Inspection Date: 5/30/2015 Insp Num: mitMFH150531153622 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well LGI-10 -1-Type Inj GTVD ! 8261 [Tubing) 3064 3065 . 3063 . 3063- 1860690 —'SPT } 2065 - 1 32 2500 - 2499 - 2499 - PTD Type Test Nest psi IA Interval 14YRTST PAF P 1 OA 35 44 , 45 - 46 - Notes: Monday,June 01,2015 Page I of l • P54. LC;r -o r 1 8, °qo Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] � e� 6/0-7, Sent: Thursday, June 07, 2012 8:10 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; G GPB FS1 DS; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Chivvis, Robert Cc: Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M; LeBaron, Michael J; King, Whitney; Yeager, Kevin E; AK, D &C DHD Well Integrity Engineer Subject: UNDER EVALUATION: Injector LGI -10 (PTD #1860690) IA Repressurization Attachments: Injector LGI (PTD #1860690) TIO Plot.docx; Injector LGI -10 (PTD #1860690) Wellbore schematic.pdf All, Injector LGI -10 (PTD #1860690) has recently shown signs of inner annulus repressurization as seen on the attached TIO plot. The operator bled the well on 06/05/12 from 2000 psi to 1300 psi. The IA has increased to 1820 psi as of 06/07/12. This well has been reclassified as Under Evaluation. The well may remain on injection while diagnostics are performed. JUL 1 8 ZUiZ The plan forward for this well is: 1. Fullbore: MIT -IA to 4500 psi — PASSED (05/17/12) 2. Wellhead: PPPOT -T 3. Downhole Diagnostics: Bleed IA to 500 psi - 4. Well Integrity Coordinator: Monitor IA over 5 to 7 days to obtain a buildup rate , 5. E -line: Evaluate for a leak detect log - A wellbore schematic and TIO plot are attached for reference: «Injector LGI (PTD #1860690) TIO Plot.docx» «Injector LGI - 10 (PTD #1860690) Wellbore schematic.pdf» Please call if you have any questions or concerns. Thank you, Whitney King filling in for Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1 • • PBU LGI-10 PTD #1860690 6/7/2012 TIO Pressures Plot WelIA.G1-111 , 4.000 3 3.000 -41- -II- IA 2.000 -a-OA 000A .44.41 Oe 011012 01712 03412 03 No:2 041 04,2112 Nan 050 00312.12 0121912 050612 06612 Injection Plot tliel.61111 • - . OM 7 20 es000 7 55 OM 0.000 -MP 0.060 0.. - MO :250% -'5003 -00017 - 301 200 ' 1052)12 03/3 023 132 311 040 041 0612 321212 0160312 01 05+1912 0526.12 060212 , • TREE = ? • WELLHEAD = FMC SAFETY NOTES: WELL REQUIRES A SSSV. ACTUATOR = AXELSON LGI-1 0 1 KB. ELEV = 52' BF. ELE\/= - KOP = 1300 Max Angle = 64* ri) 9000' , Datum ND= 14,307 i 2175' 1-15-1/2" CA NVTRDP-1A-SSA -T SSSV, ID = 4.567' Datum ND = 8900 SS 0 [V-3/8' 13-3/8" CSG, 68#/72#, K-55/L-80, ID = 12.347" H 6387' 1.--4 11 GAS LIFT MANDRELS ST IVO ND DEV TYPE VLV LATCH PORT DATE 1 13215 8182 49 CA-PM-G RKED 10/18/86 Minimum ID = 4.126" @ 13388' CAMCO DB NIPPLE I 13319' j—I BROWN SEAL ASSY - . :,,.. 7.17•4 OM 13335 H 9-5/8" X 5-1/2" BROWN 2-B PKR, ID = 6.0" I I TOP OF 7" LNR I 13364' 13388 H CAMCO 06 NIP, ID = 4.125" . 5-1/2" TBG-IPt, 17N, L-80, 0.0232 bpf, ID = 4.892" I---I 13428 l[[,[ I ' 5-1/7' I I 13428' —I 5-1/2" TUBING TAIL WIWLEG I I 13428' H ELMD TT LOG UNAVAILABLE I I 9-5/8" CSG, 47#, L-80, 0 = 8.681" H 13582' 1-41 111. x 6(870 r PERFORATION SUMMARY LOG: LT/CNL ON 07/23/86 ANGLE AT TOP PERF: 46° © 13664' Note: Refer to Production De for historical pert data SIZE SF F INTERVAL Opn/Sqz DATE 3-3/8" 6 13664-13740 0 10/18/86 3-3/8" 6 13750-13844 0 10/18/86 4" . 4 13844-13870 0 10/17/86 4 11111r I 14140' I-17 CCL - 26' OF 4" PERF GUN - 19" C.ABLEHEAD I PBTO I—I 14170' FONVOT •••••••• ••••■••• 1.4.4...........4 I 7" LNR, 294, L-80, 0.0371 bpf, ID = 6.184" H 14216' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/18/86 ORIGINAL COIVFLETION 03/19/10 JLW/SV CSG CORRECTION WO_L: LGI-10 12/20/00 SIS-MA4-1 CONVERTED TO CA WAS 02/11/11 Mf3/JN1) ADDED SSSV SAFETY NOTE PERMT No: 1860690 02/23/01 SIS-LG FINAL 05/25/12 JMD DRAWING RECTION AR No: 50-029-21573-00 10/03/01 RN/TP CORRECTIONS SEC 1, T1 1N, R14E 17.5 FEL 3864.56 FNL 03/01/07 RL DATUM MD BP Exploration (Alaska) • • S cif atr[E A[LAs SEAN PARNELL, GOVERNOR ALASKA OIL AND GA 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION SSIO T ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 June 14, 2011 Mr. Bob Gerik BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 66519 -6612 tOtA ", " , ] 'l 1 4 `.U' Dear Mr. Gerik: Thank you for the information provided in support of a request to allow the temporary flowback of a gas injector at the Prudhoe Bay Unit Lisburne Gas Injection (LGI) pad in conjunction with Lisburne Production Center summer maintenance activities. Per the original request dated May 23, 2011 and revised May 31, 2011, BP Exploration (Alaska) Inc. (BPXA) is proposing the flowback of a LGI injector for the restart of the Lisburne Production Center and Greater Pt McIntyre Are ' A drillsites. This work is to occur during July 2011. BPXA's request to use PBU GI -10 (PTD 1860690) is similar to a request in 2010 for LPC - approved by the Alaska Oil and gas Con - ' . ion ommission (Commission) on July 1, 2010 - with the exception of adding a contingency well (PBU LGI -02, PTD 1861400). BPXA's request to use either injection well LGI -10 or LGI -02 for temporary flowback of gas for the restart of LPC and GPMA drillsites following 2011 LPC summer maintenance is approved. Supplementing BPXA's request was a management -of -change document, a decision tree analysis (part of BPXA's process safety review), the startup procedure (including the injector backflow procedure), and information demonstrating the mechanical integrity of the 2 candidate injectors. In addition, the Commission reviewed its files from last year's effort for required changes and suggestions made regarding procedures to be employed by BPXA, and the inspection results from the 2010 LPC restart. It appears based on our review of the information provided that BPXA has integrated into the restart plan all the comments and conditions of our 2010 approval. The Commission witness of the wellhead safety valve system functional check -out is required before flowback is commenced. We note that BPXA's LGI -10 Backflow Procedure (Appendix A of "GPMA Drill Sites Startup Procedure ") includes the proper contact information and timing for this requirement. Please contact Jim Regg at 793 -1236 or email jim.regg )alaska.gov should there be any deviation in the approved plan. Sincerely, i �-J y �" Cathy . Foerster Commissioner • • Colombie, Jody J (DOA) From: Regg, James B (DOA) Sent: Tuesday, June 14, 2011 10:40 AM To: Colombie, Jody J (DOA) Subject: FW: Request for AOGCC approval of LGI -10 backflow to restart LPC fyi; file with Lisburne letter. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: Regg, James B (DOA) Sent: Tuesday, June 14, 2011 10:25 AM To: Gerik, Bob G; Warner, Ross L Cc: DOA AOGCC Prudhoe Bay Subject: RE: Request for AOGCC approval of LGI -10 backflow to restart LPC Thank you for the information provided in support of a decision regarding the temporary flowback of a gas injector at PBU Lisburne Gas Injection (LGI) pad. Your request to use either LGI -10 or LGI -02 for temporary flowback of gas for the restart of LPC and GPMA drillsites following 2011 LPC su.mmer maintenance is approved. Commission notice for an opportunity to witness functional check -out of the wellhead safety valve system is required - as outlined in BPXA's LGI -10 Backflow Procedure (Appendix A of GPMS Drill Sites Startup Procedure). A formal letter approving BPXA's request will follow this email approval (I believe letter was signed this morning). Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: Gerik, Bob G [mailto:Bob.Gerik @bp.com] Sent: Thursday, June 09, 2011 4:04 PM To: Regg, James B (DOA) Cc: Warner, Ross L Subject: RE: Request for AOGCC approval of LGI -10 backflow to restart LPC Jim, LGI -02 was shut -in due to the compressor problems we had at the LPC but the plan is to have the well on for the State witnessed test. It may have actually been completed today, so you may have more up to date info with an inspector on location. The startup procedure is attached. If you have additional questions, let me know. As we discussed I'll be out of the office starting tomorrow until 6 -20 -11 so if you have not completed your analysis today, please follow up with Ross Warner. 564 -5359. thx Bob • • From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, June 09, 2011 2:20 PM To: Gerik, Bob G Subject: RE: Request for AOGCC approval of LGI -10 backflow to restart LPC Thank you; do you have a startup procedure? Attached is procedure Inspector received during site visit prior to startup in 2010. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Gerik, Bob G [mailto:Bob.Gerik @bp.com] Sent: Thursday, June 09, 2011 2:04 PM To: Regg, James B (DOA) Subject: RE: Request for AOGCC approval of LGI -10 backflow to restart LPC Jim, A PDF is attached of the decision tree. I'm looking into the status of LGI -02, but from what I can tell, it has passed a MIT -IA and it appears the State witnessed test is next, but I will (et you know. There is one comment that they were in need of a ring gasket but I don't have details yet. Let me know if you have additional questions. thx Bob From: Regg, James B (DOA) [mailto:jim.regg©alaska.gov] Sent: Thursday, June 09, 2011 1:21 PM To: Gerik, Bob G Subject: FW: Request for AOGCC approval of LGI -10 backflow to restart LPC Mechanical Integrity Test for LGI -02 was due 6/7/11; it appears the well is currently shut in; for what reason? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: Regg, James B (DOA) Sent: Thursday, June 09, 2011 11:35 AM To: 'Gerik, Bob G' Subject: RE: Request for AOGCC approval of LGI -10 backflow to restart LPC I need a printable version of decision tree; can you send in pdf? As is, it will only print page 1 Jim Regg AOGCC 2 • • 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Gerik, Bob G [mailto:Bob.Gerik @bp.com] Sent: Tuesday, May 31, 2011 3:11 PM To: Regg, James B (DOA) Cc: Daniel, Ryan; Yeager, Kevin E; Garing, John D Subject: FW: Request for AOGCC approval of LGI -10 backflow to restart LPC Jim, As we discussed, in addition to requesting AOGCC approval to temporarily backflow LGI -10 to restart the LPC, we are requesting approval to temporarily backflow LGI -02 as an alternate if required. A pad plot is included indicating LGI -02 is approximately 232' from LGI -10 thus the diagrams and decision tree provided are applicable for LGI -02 also. Wellbore schematics for both wells have been included for your reference too. Please let me know if you have any questions. thx Bob From: Gerik, Bob G Sent: Monday, May 23, 2011 3:10 PM To: 'jim.regg @alaska.gov' Cc: Daniel, Ryan; Yeager, Kevin E; Garing, John D Subject: Request for AOGCC approval of LGI -10 backflow to restart LPC Jim, As discussed, we are again requesting AOGCC approval to temporarily backflow LGI -10 to restart the LPC(restart currently scheduled 7- 22 -11) following this summers shutdown as was requested and performed for the 2010 LPC restart. The decison tree for process safety has been completed and attached, along with system drawings and the correspondence from last years LGI -10 backflow request. Your comments from last year have been incorporated into this years procedure as listed below. If you or the inspectors have any other questions, please let me know. thx Bob Gerik 564 -4476 From: Regg, James B (DOA) [mailto :jim.regg @alaska.gov] Sent: Thursday, July 01, 2010 5:04 PM To: Gerik, Bob G; DOA AOGCC Prudhoe Bay Cc: AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Warner, Ross L; Garing, John D; AK, OPS GPMA Fac Engr; Daniel, Ryan Subject: RE: Follow -up to AOGCC questions(6- 30 -10) regarding LGI -10 Bob, Ryan, and Harry - Thank you for working through and addressing our concerns regarding the proposed LGI -10 flowback for restart of LPC. The Commission is satisfied with the procedure, safety measures and accomodations being made as outlined below in your email earlier today and as discussed with a Commission Inspector on 6/292010. I have alerted the North Slope Inspectors of this upcoming activity for witness of SVS test; he will also look for a copy of the updated Decision Tree per #4 below when at the location. Please give the Inspectors as much notice as possible for witness of the SVS test - pager # 907 -659 -3607. Jim Regg AOGCC 3 • • 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Gerik, Bob G [mailto:Bob.Gerik @bp.com] Sent: Thursday, July 01, 2010 9:42 AM To: Regg, James B (DOA) Cc: AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Warner, Ross L; Garing, John D; AK, OPS GPMA Fac Engr; Daniel, Ryan Subject: Follow -up to AOGCC questions(6- 30 -10) regarding LGI -10 Jim, As we discussed here are the responses to your questions. Please let me know if you have questions. The current schedule for LPC startup is July 4th. Thx Bob 564 -4476 1) Operations will have a person commited to monitoring LGI -10 during flowback and be informed of the procedure and in constant contact with the LPC. 2) Instead of setting a hold open sleeve in LGI -10, a pump truck will be available to reopen the SSSV and SSV if the system is tripped. 3) The LGI -10 1000 psi pilot has been reviewed with Operations and they have increased the pressure to a 1500 psi set point. 4) A decision tree for process safety review has been completed and attached with approvals by the LPC Facilities Engineer, Engineering Team Lead, Process Safety TA, Anchorage Engineering Authority and the OSM /OIM. Updates to this attachment are the increase in pilot pressure to 1500 as per #3 and hold open sleeve elimination as per #2 5) Operations will have a copy of the MOC at LGI - 10 6) Operations will test LGI - 10 SSSV, SSV, pilot system before startup. «BPXA MOC PSA Checklist.pdf» From: Engel, Harry R Sent: Wednesday, June 23, 2010 9:14 AM To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA); Warner, Ross L; AK, D &C Well Integrity Coordinator; AK, OPS LPC DS Ops Lead; AK, OPS GPMA Fac Engr; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C WL & Completions Coordinator; AK, D &C Wireline Operations Team Lead Subject: Follow -up to AOGCC questions regarding LGI -10 Jim - See the response below and enclosed drawing. The current schedule is for the start up to begin around July 2 -3. Thanks, Harry 1) Time duration the SSSV will be out of service; please confirm the well will be continuously manned (and what that means) The hold open sleeve will be in place for a few days to a week. It will remain shutin except for the backflow duration which is expected to take 8 -10 hours and no more than 24 hours maximum. During the backflow operation there will be a person at the well site to monitor operations. Currently the well has a TRSSSV in place, but we want to install a hold open sleeve in this well before the pressuring up project takes place to ensure the well doesn't prematurely shut in during these operations. 4 2) Implications for LPS set and trip points; how 1D111 these be adjusted to conform to AOGCCCuirements? (refer to SVS Failure Policy) For the backflow operation a pilot will be set at a pressure equal to or greater than 1000 psig. This pilot will be sensing pressure on the well side of the choke. The expected shutin pressure of the well is 2500 psig. As the pressure comes up the pilot may be changed out with a higher pressure pilot. The well will be shutin to perform this pilot swap. In addition to the above a remote system will be installed to the control panel at the well site. This will be a 25 -50 ft hydraulic hose from the well to a location outside the well house so an operator can open a whitey valve and dump the hydraulic pressure and shut in the well. 3) Control of LGI -10 in event of failure of surface piping between wellhead and ( ?); it would be useful to have a line drawing of configuration of how gas is getting into the LPC for testing In event of surface piping failure the pilot and hydraulic hose will meet the safety requirements for this project. I have enclosed a simplified system drawing to illustrate the piping. 4) Function pressure testing of LPS and SSV coincident to swap to production; call for AOGCC witness We can accommodate this request. Harold R. Engel (Harry) Engineering Team Leader Integrity Management, Alaska Drilling & Wells 907 - 564 -4194 office From: Regg, James B (DOA) [mailto:iim.re•g alaska.gov] Sent: Friday, June 18, 2010 4:31 PM To: Engel, Harry R Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: LGI -10 You indicated LPC will be going through turnaround in a few weeks, and that it is planned to use LGI -10 (gas injector) to provide gas pressure for testing /restarting the plant. LGI -10 currently has a SSSV in it but BP believes one is not required by AOGCC (not sure I agree, but that's another discussion; SSSV is installed, maintained and tested at a minimum per BP's internal policy). I have the following questions about reversing flow direction for LGI -10: 1) Time duration the SSSV will be out of service; please confirm the well will be continuously manned (and what that means) 2) Implications for LPS set and trip points; how will these be adjusted to conform to AOGCC requirements? (refer to SVS Failure Policy) 3) Control of LGI -10 in event of failure of surface piping between wellhead and ( ?); it would be useful to have a line drawing of configuration of how gas is getting into the LPC for testing 4) Function pressure testing of LPS and SSV coincident to swap to production; call for AOGCC witness That should get us started. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 5 Follow -up to AOGCC questions(6- 30- regarding LGI -10 • Page 1 9 Regg, James B (DOA) From: Gerik, Bob G Bob.Gerik b com PT6 -C69 (r/i t Sent: Thursday, June 09, 2011 4:04 PM vi `� 6 I qi dl Ply 1 0 ° 6- 1 To: Regg, James B (DOA) Cc: Warner, Ross L Subject: RE: Request for AOGCC approval of LGI -10 backflow to restart LPC Attachments: GPMA DS Startup SOP - Post 2010 TAR rev A.doc Jim, ✓' LGI -02 was shut -in due to the compressor problems we had at the LPC but the plan is to have the well on for the State witnessed test. It may have actually been completed today, so you may have more up to date info with an inspector on location. The startup procedure is attached. If you have additional — questions, let me know. As we discussed I'll be out of the office starting tomorrow until 6 -20 -11 so if you have not completed your analysis today, please follow up with Ross Warner. 564 -5359. thx Bob From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, June 09, 2011 2:20 PM To: Gerik, Bob G Subject: RE: Request for AOGCC approval of LGI -10 backflow to restart LPC Thank you; do you have a startup procedure? Attached is procedure Inspector received during site visit prior to startup in 2010. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Gerik, Bob G [mailto:Bob.Gerik @bp.com] Sent: Thursday, June 09, 2011 2:04 PM To: Regg, James B (DOA) Subject: RE: Request for AOGCC approval of LGI -10 backflow to restart LPC Jim, N' A PDF is attached of the decision tree. I'm looking into the status of LGI -02, but from what I can tell, it has passed a MIT -IA and it appears the State witnessed test is next, but I will let you know. There is one comment that they were in need of a ring gasket but I don't have details yet. Let me know if you have additional questions. thx Bob From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, June 09, 2011 1:21 PM To: Gerik, Bob G Subject: FW: Request for AOGCC approval of LGI -10 backflow to restart LPC Mechanical Integrity Test for LGI -02 was due 6/7/11; it appears the well is currently shut in; for what 6/9/2011 • GPMA Drill Sites Startup Procedure 0 by Post 2010 Turnaround AUTHORITY TITLE : PROCEDURE NUMBER: REVISION NUMBER / DATE: GPMA Field O&M TL Rev. 1 07/01/10 CUSTODIAN: ORIGINAL ISSUE DATE: NEXT REVIEW DATE: GPMA SOP SME 07/01/10 N/A DOCUMENT ADMINISTRATOR ISSUING DEPT. CONTROL TIER: PSM Analyst GPMA Operations 4 Temporary Procedure 1.0 Purpose /Scope To provide the steps for starting up GPMA Drill Sites in a safe and effective manner after turnaround activities are completed. This procedure will be used in conjunction with the LPC Startup — Post 2010 Turnaround SOP. 2.0 Acronyms /Definitions Term Definition LPC Lisburne Production Center DSO Drill Site Operator PSSR Pre - Startup Safety Review IWL Incomplete Work List NGL Natural Gas Liquid ESD Emergency Shutdown ESDV Emergency Shutdown Valve IPV Inlet Plug Valve 3.0 Specific Requirements 3.1 Health, Safety, Environmental Concerns 3.1.1 Health Concerns 3.1.1.1 To avoid harmful exposure to dangerous substances, wear appropriate PPE (personal protective equipment). Refer to appropriate MSDS (material safety data sheets). 3.1.1.2 If working with any type of chemical, refer to applicable MSDS. Document Number: UPS -US -AK -XXX- XXX- XX -XXXX PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http:// eportal. bpweb. bp. com /omsoo /documentum /Default.aspx Print Date: 6/9/11 Page 1 of 11 0 GPMA Drill Sites Startup Procedure Procedure # bp Post 2010 Turnaround Issue Date: 07/01/10 Rev. Date: 07/02/10 Rev. 1 3.1.2 Safety Concerns 3.1.2.1 Safety regulations, as defined in the Alaska Safety Handbook (ASH) are to be understood and followed during the execution of this procedure. 3.1.3 Environmental Concerns 3.1.3.1 Environmental impacts are to be understood and minimized as per Environmental Management System guidelines. 3.1.3.2 Immediately report all spills (oil, hazardous substances and chemicals, etc.) to security at Ext. 5700. 3.2 Pre - requisites • Ensure that PSSR has been completed and that all applicable signatures have been obtained. • MOC's initiated to capture changes to systems during the turnaround must be at stage 4. • The restart checklist for each drill site shall be completed and signed by the appropriate authority prior to commencing with startup activities. • Operations personnel involved with restarting drill site facilities shall review this procedure and sign the AMOC training roster. 3.3 Equipment, Materials, Tools 3.3.1 Equipment • Drill Site Pump Truck 3.3.2 Materials • Methanol • Nitrogen • Valve lubricant and sealant 3.3.3 Tools • Miscellaneous hand tools • Harmony radio 4.0 Key Responsibilities 4.1 Drill Site Operator Document Number: UPS- US- AK- XXX- XXX- XX -XXXX Print Date: 6/9/11 Page 2 of 11 • 0 GPMA Drill Sites Startup Procedure Procedure # bp Post 2010 Turnaround Issue Date: 07/01/10 Rev. Date: 07/02/10 Rev. 1 4.1.1 Complete the Restart Checklist and obtain required signature(s). 4.1.2 Safely execute the steps as noted in this procedure. 4.2 Drill Site Lead Operator 4.2.1 Coordinate startup activities with LPC Lead Operator and LPC Board Operator 4.2.2 Ensure all turnaround MOC's are at stage 4. 4.2.3 Provide training to Drill Site Operators participating in restart and ensure that training roster is signed by affected personnel. 4.3 LPC Lead Operator 4.3.1 Review the Drill Site startup procedure with LPC Operators and provide training as needed. 4.3.2 Coordinate startup activities with Drill Site Lead Operator Procedure Begins on Next Page Document Number: UPS -US -AK -XXX- XXX- XX -XXXX Print Date: 6/9/11 Page 3 of 11 • GPMA Drill Sites Startup Procedure by Post 2010 Turnaround AUTHORITY TITLE : PROCEDURE NUMBER: REVISION NUMBER / DATE: GPMA Field O &M TL Rev. 1 07/01/10 CUSTODIAN: ORIGINAL ISSUE DATE: NEXT REVIEW DATE: GPMA SOP SME 07/01/10 N/A DOCUMENT ADMINISTRATOR ISSUING DEPT. CONTROL TIER: PSM Analyst GPMA Operations 4 Temporary Procedure 5.0 Procedure /Process Note: After LPC purges nitrogen from their systems and starts the flare, PBU fuel gas will be diverted to the HPFG distribution pipelines to pressurize drill site systems (production, test, fuel gas, gas lift) and common lines. Step Action Signoff Lisburne Drill Sites and PM1 1. Prepare to 1.1 Open E001 -SDV and E002 -SDV bypass valves pressurize systems 1.2 Open E003 -SDV and E004 -SDV bypass valves 1.3 Put Pd073 -V in AUTO — 10 -20 psig setpoint 1.4 Verify that L012 -V is in AUTO — 5 -10% setpoint Monitor level as system is pressurized. Open belly drain valves as needed to maintain low level in separator 1.5 Open production and test divert valves in each manifold module at a selected well slot. 1.6 Common up gas lift header to production header in manifold modules. 1.7 Open E005 -SDV bypass valve 1.8 Put P131 -V in MANUAL — 100% output or high clamp value Document Number: UPS- US- AK- XXX- XXX- XX -XXXX PAPER COPIES ARE UNCONTROLLED. THIS COPY VALID ONLY AT THE TIME OF PRINTING. THE CONTROLLED VERSION OF THIS DOCUMENT CAN BE FOUND AT http: / /eportal. bpweb. bp. com /omsoP /documentum /Default.aspx Print Date: 6/9/11 Page 4 of 11 • 0 GPMA Drill Sites Startup Procedure Procedure # bp Post 2010 Turnaround Issue Date: 07/01/10 Rev. Date: 07/02/10 Rev. 1 1.9 Open E006 -SDV bypass valve 1.10 Verify that block valve upstream of P012 -CV is closed. At PM1 verify that E007 -SDV is closed. 1.11 Notify Lead Drill Site Operator that all systems are common and ready to be pressurized. Note: During the pressurization process leak -check fluids and NGL's will be distributed throughout process piping. After the systems are pressurized and equalized with PBU fuel gas pressure, transmitters should be checked and blown down as needed. PM -2 2. Prepare to 2.1 Open E001 -SDV and E002 -SDV bypass valves pressurize systems 2.2 Put test separators in HP / parallel mode 2.3 Put Pd073 -CV's in AUTO — 10 -20 psig setpoint 2.4 Verify that L012 -CV's are in AUTO — 5 -10% setpoint Monitor separator levels as systems are pressurized and open bypass valves as needed to maintain low level in vessels. 2.5 Open ESDV bypasses — both separators 2.6 Open production and test divert valves at a selected well slot in manifold module 2.7 Common up gas lift system to production header and test header in each manifold module. Utilize drain manifolds at the end of modules and ensure that gas lift choke is in the full -open position. 2.8 Put P131 -CV in manual — 30% output 2.9 Open E005 -SDV and E006 -SDV bypass valves in module 4915. Document Number: UPS- US- AK- XXX- XXX- XX -XXXX Print Date: 6/9/11 Page 5 of 11 • 0 GPMA Drill Sites Startup Procedure Procedure # by Post 2010 Turnaround Issue Date: 07/01/10 Rev. Date: 07/02/10 Rev. 1 2.10 Notify Lead Drill Site Operator that all systems are common and ready to be pressurized. Niakuk 3. Prepare to 3.1 Open E001 -SDV and E002 -SDV bypass valves pressurize systems 3.2 Open E003 -SDV, E004 -SDV, and E005 -SDV bypass valves 3.3 Put Pd073 -CV in AUTO — 10 -20 psig setpoint 3.4 Put L012 -CV in AUTO — 5 -10% setpoint 3.5 Open production and test divert valves at selected well slot in each manifold module. 3.6 Common up gas lift header to production and test header in each manifold module. 3.7 Open E404 -SDV bypass valve at L5 — Module 4905 3.8 Open E006 -SDV bypass valve at Niakuk 3.9 Notify Lead Drill Site Operator that all systems are common and ready to be pressurized. LGI / P1G1 4. Prepare to 5.1 Open battery limits valve(s) — LGI pressurize systems 5.2 Open header block valves and lateral valves — Slots 2, 4, 6, 8, and 10 5.3 Open lateral valve — P1G1 5.4 Notify Lead Operator that RGI system is ready to be pressurized. Document Number: UPS -US -AK -XXX- XXX- XX -XXXX Print Date: 6/9/11 Page 6 of 11 • GPMA Drill Sites Startup Procedure Procedure # bp Post 2010 Turnaround Issue Date: 07/01/10 Rev. Date: 07/02/10 Rev. 1 6. Pressurize 6.1 Verify correct position of valves as noted above. Drill Site Systems Note: At this time LPC will divert PBU fuel gas into the RGI system and establish flow to the drillsites. Target pressure of all systems is 400 - 450 psig. 6.2 Monitor pressure increase closely and ensure that all systems are equalizing at the same rate. Attention! CAUTION: In the event that a leak occurs, contact the LPC Board Operator and stop fuel gas flow into the RGI system. Isolate the leak cAUr,, and make necessary repairs before proceeding. 6.3 Continue monitoring all systems until target pressure is reached. 6.4 Verify that pressure is equalized field -wide and secure all drill sites. 6.5 Close and lock all ESDV bypass valves - field wide. Refer to valves listed in steps 1 through 3 above. 7. Pressurize 7.1 Refer to backflow procedure as described in Appendix RGI system A. Proceed to step 7 after HPFG system is pressurized with LGI -10 to - 2500 psig. Note: At this time LPC will open the common line ESDV's, initiate an ESD reset for each drill site, and prepare to start reinjection .� compressor 1807. Initial production inflow to LPC will be provided by L2 -03 via the 14" common line. During 1807 startup preparations will be made field -wide to bring on additional production at LPC's request. 8. Prepare to 8.1 Verify that common line ESDV's at LPC are open. Document Number: UPS- US- AK- XXX- XXX- XX -XXXX Print Date: 6/9/11 Page 7 of 11 • GPMA Drill Sites Startup Procedure Procedure # • bp Post 2010 Turnaround Issue Date: 07/01/10 Rev. Date: 07/02/10 Rev. 1 bring field 8 Normal up production ESDV's — field -wide. Refer to on -line SOP — Normal Startup — HP Common Lines 8.3 Start crude heaters. Refer to SOP — Normal Startup — Crude Heater 8.4 Verify IPV is closed and open L2 -03. 8.5 Contact Board Operator and advise that well is ready to bring on line. 9. Resume 9.1 Verify that LPC is ready to receive production flow from production L2. Note: At this time all production wells that do not require gas lift should be ready to bring on line (field - wide). ,/ 9.2 Bring on L2 -03 9.2.1 Gradually open the choke and increase rate to LPC. Coordinate opening of well with Board Operator. 9.3 Monitor 1807 compressor discharge pressure and open choke on P1 G1 as needed to maintain 3900 — 4000 psig. 9.4 Bring on additional high -GOR wells at Board Operator's request. Note: When the LPC compressor discharge pressure stabilizes, gas lift systems at drill sites will be started up and returned to normal. Refer to Normal Startup — Gas Lift System SOP's relative to system being restarted. As gas lift usage increases, adjustments will need to be made at P1 G 1 or LGI to maintain proper RGl header pressure. 9.4.1 Bring on wet wells at LPC's request. 9.4.2 Continue opening wells as needed until LPC is stable and throughput is optimized. Document Number: UPS -US -AK -XXX- XXX- XX -XXXX Print Date: 6/9/11 Page 8 of 11 • 0 GPMA Drill Sites Startup Procedure Procedure # bp Post 2010 Turnaround Issue Date: 07/01/10 Rev. Date: 07/02/10 Rev. 1 Note: The control panel upgrade on compressor 1808 will require several days of tuning and Operator training before it is ready to bring on line. Production rates will be curtailed until machine is operational and additional wells can be brought on line. END OF PROCEDURE Technician Signature Date of Completion Supervisor Signature Date of Completion 6.0 Key Documents /Tools /References • PSM Pre - Startup Safety Reviews Procedure UPS- US -AK- ALL - ALL - HSE -DOC- 00313 -2 • PSM Restart Procedures for Planned & Emergency / Unplanned Shutdown U PS -U S -AK -G P D- ALL -H S E -DOC- 00219 -3 • Operations Document Information Exchange or ODIE • 2010 BP Alaska Safety Handbook • AMOC — LISBDS — 0009 7.0 Comments This section is used to capture any changes or deviations from the procedure, reasons for such, and approvals to do so. Example would be sections or steps not performed during the procedure such as a N/A of a step, including authorization of such. Revision /Review Log Revision Date Authority Custodian Revision Details 07/01/10 Todd Lirette Mark Evans Initial Issue Document Number: UPS -US -AK -XXX- XXX- XX -XXXX Print Date: 6/9/11 Page 9 of 11 • 0 GPMA Drill Sites Startup Procedure Procedure # bp Post 2010 Turnaround Issue Date: 07/01/10 Rev. Date: 07/02/10 Rev. 1 Appendix A: LGI -10 Backflow Procedure LGI -10 Flowback Plan Key Points: • AOGCC approval must be obtained prior to implementation of this procedure. An AOGCC inspector will also witness a functional check -out of the wellhead safety valve systenLprior to bringing the well on line. Note: The SSSV will remain fully functional for the duration of the job. A contract pumping unit will be staged at LGI and will be used to open the downhole valve in the event of a not -for- cause dump of the wellhead safety valve system. • LGI will be manned by a competent Operator during the flowback process. • Stage 4 approval for MOC 40327869 -01 is required before putting the system in service. ' • PBU fuel gas will be used to pressurize the system to — 400 psig. • All non - essential personnel shall stay clear of Drill Site facilities and pipeline right -of ways during startup activities. • RGI system pressure after flowback is completed will be equal to LGI -10 SITP. ( -2600 psig) The low- pressure shutdown switches for the reinjection compressors at LPC are set at 2300 psig and should not have to be defeated during restart. • Upon completion of flowback, LGI -10 choke and check valve will be swapped to their normal operating position. • If a gas leak occurs in the system during the flowback process, shut in the well and isolate / depressurize affected equipment so that appropriate repairs can be made. If repair(s) require blowdown of the gas distribution pipeline(s), LPC will depressurize the system to the pit via the flare header. Steps: 1. Verify that all drill sites are manned and ready for restart. 2. Verify that wellhead SVS is functional and all devices are in their normal operating position. Document Number: UPS- US- AK- XXX- XXX- XX -XXXX Print Date: 6/9/11 Page 10 of 11 GPMA Drill Sites Startup Procedure Procedure # by Post 2010 Turnaround Issue Date: 07/01/10 Rev. Date: 07/02/10 Rev. 1 NOTE: The LPP will be defeated until the upstream choke pressure exceeds 1500 psig. Reset and normalize the LPP prior to opening the choke. 3. Open block valves downstream of choke to establish an open flow path from the well to the reinjection header. 4. Verify that choke is closed and slowly open the wing valve. Record SITP and reset the LPP. 5. Slowly open the choke and establish flow into the RGI system. Monitor and record FTT upstream of the choke. Temperature should increase after one tubing volume is displaced with formation gas. 6. Continue opening the choke and monitor gas rate, pressure, and temperature locally and - on SETCIM. Target gas rate is 90 mmscf /d. 7. Continue flowback until the system pressure equalizes with formation pressure and flow ceases. Notify LPC Board Operator that well is secure. 8. Close and flag wing valve, choke, lateral valve, and header block valve. NOTE: At this time LPC will restart 1807 reinjection compressor and prepare to bring LPC on line. Refer to GPMA Drill Site Startup — Post 2010 Turnaround SOP for details. Document Number: UPS -US -AK -XXX- XXX- XX -XXXX Print Date: 6/9/11 Page 11 of 11 BPXA MOC PSA Checklist • • Page 1 of 3 L Decision Tree (for supplemental Process Safety Review) actions: Work Order / MOC #: 40369132'`01 This is to be completed for each Technical MOC and attached to the electronic MOC record. Yes No Process Safety Hazard Assessment Method Does the change introduce a new hazard ✓',::: No scenario to the facility that is not covered in the existing facility PHA/HAZOP table? Does the change impact the scenario cause, consequence, or add /remove /modify an independent protection layer (IPL) listed in the HAZOP? NOTE: Any PSV change associated /, with this change that impacts the design sizing • ' basis for the flare system is a 'Yes' response. [If temporarily defeating a safeguard or level of protection, refer to the BPXA Defeated Major or Small /Medium Project: Safety Device Control Procedure.] Does the change add or delete an IPF or affect • MAR (Major project only) the probability of failure on demand of a • HAZID component of an existing IPF (instrumented • Facility Siting protective function /ESD /SDV) or mechanical HAZOP/LOPA // safety function? (e.g. modification of test •Integrity Level Calculation /'�; frequency or changing components) NOTE: This includes changes to the fuel gas supply or the burner management systems (BMS) associated with gas fired equipment (heaters /turbines) to ensure the IPF meets the required integrity level. Does the change include introduction of hazards that would impact existing occupied ✓.;:. spaces, the addition of an occupied building, or the modification of an existing occupied building? Does the change, including off - normal operation or work, have the potential to impact the specification of crude oil or fuel gas delivered to another facility (inclusive of In addition to evaluation of above PS01); i.e., temperature, pressure, vapor p p methods, these items trigger 3rd pressure, BS &W, composition, multiphase party notification. flow, gas flow, rapid rate of change of any parameter, etc? Communicate to appropriate II I file: / /C: \Documents and Settings \gerikbg \Desktop \state temp \moc_decision_tree,htm 6/9/2011 • Does the change, including off-normal Operator (e.g. Alyeska) and operation or work, have the potential to provide them with scope and expose any other facility (inclusive of PSO1) schedule information and request \ f 'C':, V No to new hazards or increase the severity or involvement in the review and likelihood of a known hazard; i.e., vapor approval process. release from areas adjacent to facility, critical work over /under shared roadways, etc? If yes to any question above, contact the Process Safety and Risk Team in the HSSE and Engineering Group or the I3U Engineering Manager to evaluate the necessity of a facilitated review. If no to above, continue with questions below Does the change add/remove a safeguard listed Yo, / in the HAZOP (i.e. gas detection, HVAC, Conduct hazard review, update No halon)? If temporarily defeating a safeguard or facility HAZOP log sheet(s) and level of protection, refer to the BPXA Defeated attach. Safety Device Control Procedure. Does the change add, remove or modify a process flow path including auxiliary or utility Yes ✓\'o systems (i.e. new tie in, size change, lube oil modification, locking valves or valves stops, Conduct hazard review, update changes in control valve sizes)? facility HAZOP log sheet(s) and Does the change add or modify a basic process attach or, if no log sheet(s) exist k0 control system (BPCS)? - Complete MOC Hazards Assessment Does this change modify process variables, Yes ✓No such as pressure, temperature, fluid composition, heat/material balance, etc.? Does the change affect the mechanical Above action - OR - 4 components or mechanical integrity (i.e. Add comments to this form and `' removal or addition of valves, change in pipe attach any supplemental spec, etc.)? documents to the MOC. If support is required, contact Process Safety and Risk Team. Documentation of additional hazard or process safety assessment(s) shall be available in the MOC library. t/Ycs No Supplemental Process Safety Assessment attached in the MOC library If no to all above: Document any remaining process safety concerns and how they have been addressed, or document that there are no process safety concerns from this change and add comments on how this conclusion was drawn. This MOC will reverse a choke and check valve to enable the backflow of Lisburne Gas from LGI well 10 to provide a back pressure on the system for restart of the facility after the 2011 TAR, This issue was planned for in the original startup manual and is noted on the P &IDs. Jumpers will need to be installed on P018SL and P017SL to open the E017SDV and E018SDV. These switches are not listed in the LPC HAZOP worksheets. Acronyms and reference does File: / /C: \Documents and Settings \gerikbg \Desktop\state temp\moc_decision_tree.htm 6/9/2011 BPXA MOC PSA Checklist Page 3 of 3 Process used to assess process buildings (I.e., location, Engineering Technical n/a Facility Siting construction and function) based on the known hazards (i.e., Practice 04-30 toxic, fire and explosion). Engineering Technical HAZID Hazard identification Brainstorming approach used to identify possible hazards. Practice 48 -05 Systematic qualitative technique to identify and evaluate Engineering Technical Hazard and process hazards and potential operating problems, using a Practice 48 -02 / HAZOP operability study series of guidewords to examine deviations from normal Alaska Site Technical process conditions. Practice CRT- AK -48 -02 Discrete level for specifying the integrity requirements of Engineering Technical IL Integrity level instrumented functions to be allocated to the instrumented Practice 30 -75 / 9 Y Alaska Site Technical systems Practice CRT- AK -30 -75 Safety function with a specified integrity level that is necessary to Engineering Technical Instrumented Practice 30 -75 / IPF achieve functional safety by putting process to a safe state or protective function Alaska Site Technical maintaining it in a safe state under predefined conditions. Practice CRT- AK -30 -75 Device, system, or action that is capable of preventing a postulated accident sequence from proceeding to a defined, Engineering Technical Instrumented undesirable endpoint. An IPL is (1) independent of the event practice 48 -03 / IPL protection Layer that initiated the accident sequence and (2) independent of any Alaska Site Technical other IPLs. IPLs are normally identified during layer of Practice CRT- AK -48 -03 protection analyses. Method for evaluating the effectiveness of protection layers in Engineering Technical Layer of protection reducing the frequency and /or consequence severity of Practice 48 03 / LOPA analysis Alaska Site Technical hazardous events. Practice CRT- AK -48 -03 Engineering Technical The combination of likelihood and consequence of major Practice 48 -50 / Alaska MAR Major Accident Risk accidents. Site Technical Practice CRT- AK -48 -50 Device, system, or action that would likely interrupt the chain n/a Safeguard of events following an initiating cause or that would mitigate loss event impacts. Completed by: Kiland, Dan D ate: 4/25/2011 i additional reviews, as required Reviewed by a,, Bossier, Mark Date: 5/8/2011 Engineering Team Lead: Reviewed by Process Berry, Jeff Date: 5/10/2011 , Safety TA: f ........ � Reviewed by . 7 pi Whipple, Tracy D ate: 5/10/2011 Engineering Authority: LA Reviewed by OSM /OIM: - i Clopton, Jeff M. Date: 5/10/2011 t r I file: / /C: \Documents and Settings \gerikbg \Desktop \state temp \Inoc_decision_tree.htm 6/9/201 1 1 " �U � 1 P �"` iii ( i l � '°'` a d, -' 442• � �� � ���',�� �� ��� a . + °I. -.A.,,, - ,, ,';, ,,,,,, . A..i, r , 4 � - 1 gypp' 7 — Erer /Exit ' ' r , i 1 \ /.= t5 it, u 1 ,,, Ha �, *,,,,, �`. 0 xs_ - 4;10"k'' , ., �� 1 y A M 1 hi 3k,G } 'PI 4 f N .,, 1 , ' G al � . 1 10 A 2 i ll 1 0 $ o 'I lr 0 I co a � ,, :: : 1 ,, M 4 I ,r., , O� , 0 00 0 (1 1 __I il ,, A J ` \. ,,,, � _, ., ,.:• - -i4c Enter /Exit WELL PRODUCER • or ❑ WELL INJECTOR A DATE : 12/2/2010 SCALE : 1" = 100' MAP DATE : 2010 PBU - LGI WELL SLOT W /CONDUCTOR M bs14495.mxd TREE = WELLHEAD = FMC • GI-1 sAFETyiks: WELL REQUIRES A SSSV. ACTUATOR; AXELSON KB. ELEV = 52' „ . . BF. ELEV = KOP = 1300' Max Angle = 64 @ 9000' I 2175' H5-1/2" CAM/TRDP-1A-SSA-T SSSV, ID = 4.562" I - Datum = 14,302" Datum TVD 8900' SS 13-3/8" CSG, 68#/72#, K-55/L-80, D = 12.347" H 5367' GAS LIFT MANDRELS ST MD - ND DEV TYPE VLV LATCH PORT DATE 1 13215 8182 49 CA-MMI-G RKED Minimum ID = 4.125" @ 13388' CAMCO DB NIPPLE 13319' J—I BROWN SEAL ASSY I *.m r --- 9-5/8" X 5-1/2" BROWN 2-B PKR, ID = 6.0" I 13388' H 5-1/2" CAMCO DB NIP, ID = 4.125" I I 5-1/2" TBG-IPC, 17#, L-80, 0.0232 bpf, ID = 4.892" 1--f 13428' I I 13428' H 5-1/2" TUBING TAIL W/WLEG I 13428' H ELMD TT LOG UNAVAILABLE I I TOP OF 7" LNR 13364 9-5/8" CSG, 47#, L-80, ID = 8,681" 13582' I PERFORATION SUMMARY REF LOG: LT/CNL ON 07/23/86 ANGLE AT TOP PERF: 46 @ 13664' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 13664-13740 0 10/18/86 3-3/8" 6 13750-13844 0 10/18/86 4" 4 13844-13870 0 10/17/86 [ COL - 26' OF 4" PERF GUN - 19" CABLEHEAD PBTD H 14170' m•I'T V 4 4 *4 Pe* M 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" H 14216' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/18/86 ORIGINAL COMPLETION 03/19/10 JLW/SV CSG CORRECTION WELL: LGI-10 12/20/00 SIS-MWH CONVERTED TO CANVAS 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE PERMIT No: 1860690 02/23/01 SIS-LG FINAL API No: 50-029-21573-00 10/03/01 RN/TP CORRECTIONS SEC 1, T11N, R14E 17.5 FEL 3864.56 FNL 03/01/07 RL DATUM MD BP Exploration (Alaska) • 0 0 0 aq- lee - MO. eke+ etterT darno .--...."'" 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L I. t; t, t --- t---t- k a ! 1 i t -L---1- - t t -- �-+ ---•L t THE TiON Of THIS LINE REFER O E f 2S f` J TO '' EVEN N %YELLS '.• • / 0 14" D E a d :L N 'ELLS L. {.w} ? t DRE,63tTE., ,. DRIINYi6 Nt). ! %.; '"'' a '*' DDD f�f LL01-2 2 P Y / ( D.S. -L6 PLO-MOO -50363 ., 3, VH•1 r. EVEN ,� G� ' *WELLS 3M` vie 1 ` .r 1� OS.- LGx PLD •A107 -30370 n of WELLS �� w a, # 1 .• w 1 ( 2, INSTRUMENT IDLMTIFKATION: i esait ^i• O DD +`+ 4:1 4:1 l INSTRUMENT 1YOLWERS GIVEN ARE fOR ORILLSITE LGI WELL No. 7 7 +'� WELLDi r �U 1.1•344' • 1N .CTKx+ ONLY. THEY CAM4GE AT EACH WELL. FOR COARTI WTION OF INSTRUMENT [ �.?h` + + POINT OCO Eves .. - WJIA>yE 4,SEE INSI Rt/M(MTATION 9PECIFICdAT10N:. `.RQ� - .� WE WE �`�. INSTR an tA6Tit. ' r NOTE 3 4X D` r r '.' «' P 301-1T ea.mooN NUMBER ''t' I 51 , / /. 41 01PQA301-1 1 INSTAW#ENT TAG NumIEN • A41 - e111 ,.. �el . 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AR-OUT S�'oOL W HEADER 4• T NET LT CAEN DR4LSrEE AI WE SEE 1 1 � ESD L f 0 0.1'� f t*11( R '• 1 - --�14 t (Ik)1E 13) (MAIN FLOW) T C SPECIFIC OPAWI NF WHICH WILL GME 71* LUKE N . FOR (Wf NCO) In EACH WELL AT THAT pgLLitTE. t. 1 1 L 1 M TO 12:3 FROM lAf i 1 SFF MD- 4107 -3031D -001 „ ,\ , 1° W. - 1j �TO 0 fRO LG-0 f 5 DELETED E/+ I"%0 + �\ S. F OR Oil TtJL. �..... I ^ _ -- ..a - R�..... Y. F(16 LGa 'FLEE k,b,q,lx, AIID 14 pLr RR 1 11;:gg 1 t A L DELETED I - FLAM6E AT LGl FOR Lel PRE-PRODLC'ION TIL -INS DELETE GNEArOJT _ "I� J a e -4 WELLS ONLY 8 6WOOL, D1WN00MER APO I1EROtlTE PER LW FLD- MMO- 30505. ”" - S ONLY Wy ,, I tgil 10. FOR WELL L5 -29 SEE MPD- 4105 -001 SHT. 201 Iiii?'''* LA/IGE ACCESS V AUL T ./ 11. ea ELSOR SPOOL. NO CHOKE. LGI-6, 161 -2 CHOKE ON TOP, LGI-10 ON OOTTOM 0 RISER. 4 � 12. ea ELO0N SPOOL, NO CHOKE, 1.01 LG -10. NO SPOOL OR L CONNECTION ON LG4-6 o- 13.5E4-2, 13.5(4 -2. 1.01-10. 5 % CAAAC.o L 177 �al.. Tele -I A - Ss/t _ r � ! 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A- fON S£CA J.1YlSftiKETi S .R, TSA tiR ,.co r•> to-.o ,m .1111. law.. 47. tam E., ' • • Page 1 of 1 • Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] Sent: Thursday, June 09, 2011 4:46 PM k�c =�� (l ( � I To: Regg, James B (DOA) Subject: RE: MIT and TIO Plot for LGI -02 (PTD 186140) Attachments: MIT PBU LGI -02 06- 04- 11.xls; Injector LGI -02 (PTD #1861400) TIO and Injection Plot.doc Jim, Here is the requested data for LGI -02 (PTD 186140). A witnessed test is scheduled for tomorrow also on the well. Please let me know if I can be of further assistance. Regards, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, June 09, 2011 4:23 PM To: AK, D &C Well Integrity Coordinator Subject: MIT and TIO Plot for LGI -02 (PTD 186140) I am working on a request from Lisburne folks to allow the temporary flowback of a gas injector at LGI. Request is in support of LPC restart after summer maintenance is concluded. They are considering LGI -10 and LGI -02 as candidates. I need the following for LGI -02 (I have everything I need for LGI -10): - TIO Plot (beginning June 2010) - MIT (understand BP did one recently but it was not witnessed by AOGCC; that will be fine for this effort) I am trying to wrap this up tomorrow so would appreciate your normal quick response. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 -793 -1236 6/10/2011 Page 1 Follow -up to AOGCC questions(6 -3.0) regarding LGI -10 • � Regg, James B (DOA) Bob.Gerik com j rat CCU From: Gerik, Bob G b n � [ @p� l Sent: Thursday, June 09, 2011 2:04 PM COQ t_CZ - v 2— ' ' I To: Regg, James B (DOA) Subject: RE: Request for AOGCC approval of LGI -10 backflow to restart LPC Attachments: 4594_001. pdf Jim, A PDF is attached of the decision tree. I'm looking into the status of LGI -02, but from what I can tell, it has passed a MIT -IA and it appears the State witnessed test is next, but I will let you know. There is one comment that they were in need of a ring gasket but I don't have details yet. Let me know if you have additional questions. thx Bob From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, June 09, 2011 1:21 PM To: Gerik, Bob G Subject: FW: Request for AOGCC approval of LGI -10 backflow to restart LPC Mechanical Integrity Test for LGI -02 was due 6/7/11; it appears the well is currently shut in; for what reason? teiZD10 Jim Regg !Proms rtt AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Regg, James B (DOA) Sent: Thursday, June 09, 2011 11:35 AM To: 'Gerik, Bob G' Subject: RE: Request for AOGCC approval of LGI -10 backflow to restart LPC I need a printable version of decision tree; can you send in pdf? As is, it will only print page 1 Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Gerik, Bob G [mailto:Bob.Gerik @bp.com] Sent: Tuesday, May 31, 2011 3:11 PM To: Regg, James B (DOA) Cc: Daniel, Ryan; Yeager, Kevin E; Garing, John D Subject: FW: Request for AOGCC approval of LGI -10 backflow to restart LPC Jim, As we discussed, in addition to requesting AOGCC approval to temporarily backflow LGI -10 to restart the 6/9/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.redoaalaska.gov; doa. aogcc.prudhoe.bavCcaalaska.00v; phoebe.brooksl alaska.00v; tom.maunder(caalaska.00v OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / LGI DATE: 06/04/11 OPERATOR REP: Gerald Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. _ Well LGI -02 ' Type Inj. G ' TVD ' 8,260' Tubing 3950 3950 ' 3950 3950 3950, Interval 4 P.T.D. 1861400 ' Type test P Test psi - 2065 Casing 490 2500 2489 2482 2480 P/F P - Notes: 5.5 bbls diesel pumped OA 20 20 20 20 20 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P /F_ Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU LGI - 02 06 04 11.xls — PaS5tk PCIA — ‘ ( 4 ( kt PBU LGI-02 PTD #1861400 - .)c)(9- Wer e-c, 6/9/2011 JIcei 6/1olik TIO Pressures Plot 1 I Well: L61-02 4,000 - ...... ni ....m...1.06.0-- r 3,000 --.— T bg 2,000 - 0 OA II _.____ 000A 1,000 - — On 111IIIIIIMI-_MIIIIIIIIPMIMI• , RINPK9■1,0mar • Air . ": 07/03/10 08/03/10 09/03/10 10/04110 11/04/10 12/05/10 01/05/11 02/05/11 . 03/68/11 04/08/11 05/09/11 06/09/11 Injection Plot . . Well: L6I-02 .e- 4,000 - 100,000 3,500 -: 80,000 .ecio WH IP 3,000 El: 2,500 : 60,000 0 PW 2,000 -. \..--A.--A 40,000 13 C, - , ) -- — MI • ID Oth 20,000 er G O i n 07/03/10 08/03/10 09/03/10 10/04/10 11/04/10 12/05/10 01/05/11 02/05/11 03/08/11 04/08/11 05/09/11 06/09/11 I PBU LGI-10 - Pa.ce'a 141T 6 1 5 1 PTD 1860690 6/9/2011 ue&-i,t-ejr, 3 acif TIO Pressures Plot , I Well: 161-10 I , 4,000 - 3,000 - --ilk— Tbg —U—IA 2.000 - —A— OA 00A —41— 000A 1.000- —On 03/12/11 03119111 03126111 04102/11 04109111 04/16/11 04/23/11 04)30/11 05107111 05/14111 05/21/11 05128111 06/04/11 Injection Plot Well: 1151-10 1 - , .0300 - - . - 80,000 3,500 - - - 70,000 3,000 - - -. 60 , 000 WE SW EL. 2,500 -. - 50,000 c PW mi III GI 1,000 - :- 20 ' 000 c' — Other - ...... On , 500 - - 10,000 . . . . , . , . , • , • 03112/11 03/26/11 04/09/11 04123/11 05/07/11 05/21111 06/04/11 tt 6(eqii .. R34kL Combined SVS Test Results Jan 01, 2006 Through (Excludes Reason = "Retest ") PLT SSV SSSV Insp/ Date Test Retest Failure Well Name Permit # CP IF CP IF CP IF Oper Tested Reason Period Tests Components Failures Rate PRUDHOE BAY UN LIS LGI -02 1861400 1 0 1 0 1 0 IN 4/25/2006 180 3 0 PRUDHOE BAY UN LIS LGI -10 1860690 1 0 1 0 1 0 IN 4/25/2006 180 3 0 PRUDHOE BAY UN LIS LGI -06 1860670 1 0 1 0 1 1 OP 9/13/2006 Misc 3 1 PRUDHOE BAY UN LIS LGI -02 1861400 1 0 1 0 1 0 OP 10/29/2006 Misc 3 0 PRUDHOE BAY UN LIS LGI -10 1860690 1 0 1 0 1 0 OP 10/29/2006 Misc 3 0 PRUDHOE BAY UN LIS LGI -02 1861400 1 0 1 0 1 0 IN 4/1/2007 Misc 3 0 PRUDHOE BAY UN LIS LGI -10 1860690 1 0 1 0 1 0 IN 4/1/2007 Misc 3 0 PRUDHOE BAY UN LIS LGI -06 1860670 1 0 1 0 1 0 OP 6/17/2007 Misc 3 0 • PRUDHOE BAY UN LIS LGI -02 1861400 1 0 1 0 1 0 IN 10/26/2007 90 3 0 PRUDHOE BAY UN LIS LGI -06 1860670 1 0 1 0 1 0 IN 10/26/2007 90 3 0 PRUDHOE BAY UN LIS LGI -10 1860690 1 0 1 0 1 0 IN 10/26/2007 90 3 0 PRUDHOE BAY UN LIS LGI -02 1861400 1 0 1 0 1 0 IN 4/28/2008 180 3 0 PRUDHOE BAY UN LIS LGI -06 1860670 1 • 1 0 1 0 IN 4/28/2008 180 3 0 PRUDHOE BAY UN LIS LGI -10•No► 1860690 4101110 1 0 1 0 IN 6/24/2008 Misc 3 1 PRUDHOE BAY UN LIS LGI -02 1861400 1 I 1 0 1 0 IN 10/21/2008 180 3 0 PRUDHOE BAY UN LIS LGI -06 1860670 1 0 1 0 1 0 IN 10/21/2008 180 3 0 PRUDHOE BAY UN LIS LGI -10 1860690 1 0 1 0 1 0 IN 10/21/2008 180 3 0 PRUDHOE BAY UN LIS LGI -02 yo. 1861400 1 gip 1 0 1 0 IN 5/11/2009 180 90 3 1 PRUDHOE BAY UN LIS LGI -06 1860670 1 0 1 0 1 1 IN 5/11/2009 180 90 3 1 PRUDHOE BAY UN LIS LGI -10 1860690 1 0 1 0 1 0 IN 5/11/2009 180 90 3 0 PRUDHOE BAY UN LIS LGI -06 1860670 1 0 1 0 1 1 OP 8/18/2009 180 3 1 PRUDHOE BAY UN LIS LGI -10 1860690 1 0 1 0 1 0 OP 8/18/2009 180 3 0 PRUDHOE BAY UN LIS LGI -06 1860670 1 0 1 0 1 0 IN 10/13/2009 180 3 0 PRUDHOE BAY UN LIS LGI -10 1860690 1 0 1 0 1 0 IN 10/13/2009 180 3 0 • PRUDHOE BAY UN LIS LGI -06 1860670 1 0 1 0 1 0 OP 4/25/2010 180 3 0 PRUDHOE BAY UN LIS LGI -10 1860690 1 0 1 0 1 0 OP 4/25/2010 180 3 0 PRUDHOE BAY UN LIS LGI -10 1860690 1 0 1 0 1 0 IN 7/7/2010 Misc 3 0 PRUDHOE BAY UN LIS LGI -02 1861400 1 0 1 0 1 0 OP 9/13/2010 Misc 3 0 PRUDHOE BAY UN LIS LGI -06 1860670 1 0 1 0 1 0 OP 10/19/2010 180 3 0 PRUDHOE BAY UN LIS LGI -10 1860690 1 0 1 0 1 0 OP 10/19/2010 180 3 0 PRUDHOE BAY UN LIS LGI -02 1861400 1 0 1 0 1 0 OP 10/29/2010 Misc 3 0 Thursday, June 09, 2011 Page 1 of 2 r PLT SSV SSSV Insp/ Date Test Retest Failure Well Name Permit # CP IF CP IF CP /F Oper Tested Reason Period Tests Components Failures Rate PRUDHOE BAY UN LIS LGI -06 1860670 1 0 1 0 1 1 IN 4/12/2011 180 3 1 PRUDHOE BAY UN LIS LGI -10 1860690 1 0 1 0 1 0 IN 4/12/2011 180 3 0 PBU LIS LGI 33 99 6 6.06% • • Thursday, June 09, 2011 Page 2 of 2 • • Page 1 of 2 Regg, James B (DOA) — e at - From: Noble, Robert C (DOA) Sent: Tuesday, June 29, 2010 7:17 PM ;/ 6/9116/( J To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay Subject: LGI -10 Attachments: DSCO2904.JPG; DSCO2906.JPG; DSCO2909.JPG; DSCO2908.JPG; scan0003.jpg; scan0004.jpg; scan0005.jpg Jim I went out and met with BPX Rep Dave Tyner (LGI DSO). I ask Mr. Tyner a number of questions to help us better understand what their doing on LGI -10 I ask what the reason for putting this pressure on the line? ; ,They needed to put 2300 psi. on the plant as the Frame 5 gen. would not start without the pressure on them. I ask about the choke and the check valve. He told me that they had both been turned around in the line so they operate in the right direction. I ask if the drill site will be manned during the operation 24/7 and by whom? Dave told me it would be manned by the Drillsite operator. He want on to say during the operation all the drillsites will be manned 24/7. I ask about the piping they were going to flow though? t /His reply was 6" at the well then into 14" main line all of it is 2500 series pipe. I ask him what the normal pressure was on this line. He told me it's their gas lift line and it normally has 3800 to 4200 psi on it. I ask what kind of SSSV valve it was and wh y wanted to put a sleeve in it? ) , f - Dave had to call Mike Shoemake and it' normal hyd operated SSSV. Mike said they wanted to put the sleeve to prevent it from closing, ause if it closed they would have to get a pump truck to pump it ��' tioL open. i t-iC(L I ask Dave about their remote shut down system. Our email states that it will be 25 -50 feet away. 0 /Oat - Dave told me it will be 100' away. He also showed me where they were going to be located. C O , 1 C55 I ask Dave what's the shut in pressure of LGI -10? „ cPSc Dave said he didn't know and we could not check right now because they were tied into the tree cap L� pressure testing. I ask Dave how they came up with the expected 2500 psi. shut in pressure? ✓ Dave told me they came up with that because LGI -2 was shut in May 24 2010 and it had 2400 psi. I ask Dave about the 1000 psi pilot setting. /fie told me he didn't like it and he would recommend some where from 1500 to 2000 psi set point. /5 } ; Pr la I ask Dave where the pilot was going to be located. He told me it was going to remain in the same place it is now. 11� I told Dave we wanted to witness a SVS test. I ask Dave to get back with us on: The shut in pressure of the well. 24 hour notice on a SVS test The trip pressure of the pilot. Dave gave me a copy of their procedure and a well schematic, which III include with this email. Also included will be some pictures. 6/9/2011 • • Page 2 of 2 Bob Noble AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, AK. 99501 907 - 659 -3607 Cell 907 - 299 -1362 6/9/2011 Follow -up to AOGCC questions( -10) regarding LGI -10 • Page 1 of 3 Regg, James B (DOA) From: Gerik, Bob G [Bob.Gerik @bp.com] � (Tn I 4.1(4; Sent: Tuesday, May 31, 2011 3:11 PM To: Regg, James B (DOA) Ott 1-41- ' I bC L40 � �' Cc: Daniel, Ryan; Yeager, Kevin E; Caring, John D Subject: FW: Request for AOGCC approval of LGI -10 backflow to restart LPC Attachments: moc_decision_tree.htm; 40369132 LGI -10 Rigup Temp Jumper to pressure Pi. -lin- Simp Sys Dwg.doc; 40369132% 20LGI %20Backflow %20drawings.pdf; PBU_LGI.pdf; LGI- 10.pdf LGI- 02.pdf Jim, As we discussed, in addition to requesting AOGCC approval to temporarily backflow LGI -10 to restart the LPC, we are requesting approval to temporarily backflow LGI -02 as an alternate if required. A pad plot is included indicating LGI -02 is approximately 232' from LGI -10 thus the diagrams and decision tree provided are applicable for LGI -02 also. Wellbore schematics for both wells have been included for your reference too. Please let me know if you have any questions. thx Bob From: Gerik, Bob G Sent: Monday, May 23, 2011 3:10 PM To: 'jim.regg @alaska.gov' Cc: Daniel, Ryan; Yeager, Kevin E; Garing, John D Subject: Request for AOGCC approval of LGI -10 backflow to restart LPC Jim, As discussed, we are again requesting AOGCC approval to temporarily backflow LGI -10 to restart the LPC(restart currently scheduled 7- 22 -11) following this summers shutdown as was requested and performed for the 2010 LPC restart. The decison tree for process safety has been completed and attached, along with system drawings and the correspondence from last years LGI -10 backflow request. Your comments from last year have been incorporated into this years procedure as listed below. If you or the inspectors have any other questions, please let me know. thx Bob Gerik 564 -4476 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, July 01, 2010 5:04 PM To: Gerik, Bob G; DOA AOGCC Prudhoe Bay Cc: AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Warner, Ross L; Garing, John D; AK, OPS GPMA Fac Engr; Daniel, Ryan Subject: RE: Follow -up to AOGCC questions(6- 30 -10) regarding LGI -10 Bob, Ryan, and Harry - Thank you for working through and addressing our concerns regarding the proposed LGI -10 flowback for restart of LPC. The Commission is satisfied with the procedure, safety measures and accomodations being made as outlined below in your email earlier today and as discussed with a Commission Inspector on 6/292010. I have alerted the North Slope Inspectors of this upcoming activity for witness of SVS test; he will also look for a copy of the updated Decision Tree per #4 below when at the location. Please give the Inspectors as much notice as possible for witness of the SVS test - pager # 907 - 659 -3607. Jim Regg AOGCC 6/9/2011 Follow -up to AOGCC questions(6 -3-10) regarding LGI -10 • Page 2 of 3 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Gerik, Bob G [mailto:Bob.Gerik @bp.com] Sent: Thursday, July 01, 2010 9:42 AM To: Regg, James B (DOA) Cc: AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Warner, Ross L; Garing, John D; AK, OPS GPMA Fac Engr; Daniel, Ryan Subject: Follow -up to AOGCC questions(6- 30 -10) regarding LGI -10 Jim, As we discussed here are the responses to your questions. Please let me know if you have questions. The current schedule for LPC startup is July 4th. Thx ` ob 564 -4476 ��� 1) Operations will have a person commited to monitoring LGI -10 during flowback and be informed of the procedure and in constant contact with the LPC. `�'�✓ 2) Instead of setting a hold open sleeve in LGI - 10, a pump truck will be available to reopen the SSSV and SSV ,, if the system is tripped. Q.AV ` 7 ✓ 3) The LGI - 10 1000 psi pilot has been reviewed with Operations and they have increased the pressure to a 1500 psi set point. E✓ 4) A decision tree for process safety review has been completed and attached with approvals by the LPC Facilities Engineer, Engineering Team Lead, Process Safety TA, Anchorage Engineering Authority and the OSM /OIM. Updates to this attachment are the increase in pilot pressure to 1500 as per #3 and hold open sleeve elimination as per #2 q a 5) Operations will have a copy of the MOC at LGI -10 fi) Operations will test LGI - 10 SSSV, SSV, pilot system before startup. «BPXA MOC PSA Checklist.pdf» From: Engel, Harry R Sent: Wednesday, June 23, 2010 9:14 AM To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA); Warner, Ross L; AK, D &C Well Integrity Coordinator; AK, OPS LPC DS Ops Lead; AK, OPS GPMA Fac Engr; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C WL & Completions Coordinator; AK, D &C Wireline Operations Team Lead Subject: Follow -up to AOGCC questions regarding LGI -10 Jim - See the response below and enclosed drawing. The current schedule is for the start up to begin around July 2 -3. Thanks, Harry 1) Time duration the SSSV will be out of service; please confirm the well will be continuously manned (and what that means) The hold open sleeve will be in place for a few days to a week. It will remain shutin except for the backflow duration which is expected to take 8 -10 hours and no more than 24 hours maximum. During the backflow operation there will be a person at the well site to monitor operations. Currently the well has a TRSSSV in place, 6/9/2011 Follow -up to AOGCC questions(6 - -10) regarding LGI -10 Page 3 of 3 but we want to install a hold open sl a in this well before the pressuring upproject takes place to ensure the well doesn't prematurely shut in during these operations. 2) Implications for LPS set and trip points; how will these be adjusted to conform to AOGCC requirements? (refer to SVS Failure Policy) For the backflow operation a pilot will be set at a pressure equal to or greater than 1000 psig. This pilot will be sensing pressure on the well side of the choke. The expected shutin pressure of the well is 2500 psig. As the pressure comes up the pilot may be changed out with a higher pressure pilot. The well will be shutin to perform this pilot swap. In addition to the above a remote system will be installed to the control panel at the well site. This will be a 25 -50 ft hydraulic hose from the well to a location outside the well house so an operator can open a whitey valve and dump the hydraulic pressure and shut in the well. 3) Control of LGI -10 in event of failure of surface piping between wellhead and ( ?); it would be useful to have a line drawing of configuration of how gas is getting into the LPC for testing In event of surface piping failure the pilot and hydraulic hose will meet the safety requirements for this project. I have enclosed a simplified system drawing to illustrate the piping. 4) Function pressure testing of LPS and SSV coincident to swap to production; call for AOGCC witness We can accommodate this request. Harold R. Engel (Harry) Engineering Team Leader Integrity Management, Alaska Drilling & Wells 907 - 564 -4194 office From: Regg, James B (DOA) [mailto:jim.recici alaska.gov] Sent: Friday, June 18, 2010 4:31 PM To: Engel, Harry R Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: LGI -10 You indicated LPC will be going through turnaround in a few weeks, and that it is planned to use LGI -10 (gas injector) to provide gas pressure for testing /restarting the plant. LGI -10 currently has a SSSV in it but BP believes one is not required by AOGCC (not sure I agree, but that's another discussion; SSSV is installed, maintained and tested at a minimum per BP's internal policy). I have the following questions about reversing flow direction for LGI -10: 1) Time duration the SSSV will be out of service; please confirm the well will be continuously manned (and what that means) 2) Implications for LPS set and trip points; how will these be adjusted to conform to AOGCC requirements? (refer to SVS Failure Policy) 3) Control of LGI -10 in event of failure of surface piping between wellhead and ( ?); it would be useful to have a line drawing of configuration of how gas is getting into the LPC for testing 4) Function pressure testing of LPS and SSV coincident to swap to production; call for AOGCC witness That should get us started. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 6/9/2011 TREE = SAF OTES: WELL REQUIRES A SSSV. WELLHEAD = FM1 CAT I - SV, HES(PPM) 140 ACTUATOR = A5<a§6N1 L.G1-02 KB. ELEV = 52' BF. ELEV KOP = 3200' • Max Angle = 35 @ 5400' 2164' H5-1/2" CAMCO TRDP 1A-SSA-T SSSV, ID = 4.562" 1 - Datum MD; 9727' Datum TV D = 8900' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" H 4058' GAS LIFT MANDRELS ST MD TVD DEV TYPE LATCH PORT DATE 1 8862 8170 21 CA/MMI-G RK Minimum ID 4.125" @ 9012' CAMCO DB NIPPLE x 8960' I-1 9-5/8" BROWN 2-B PKR, Dr 6.00" 1 I 9012' H 5-1/2" CAMCO DB NIP, ID = 4.125" I [TOP OF 7" LNR 1 9018'J 5-1/2" TBG-IPC, 17#, L-80, 0.0232 bpf, ID 4.892" H 9051' I j 9051' . 1-1 5-1/2" TUBING TAIL W/WLEG I 9051' H ELMD TT LOGGED 11/02/86 I I 9-5/8" CSG, 47#, L-80, ID = 8.681" H 9198' I • PERFORATION SUMMARY REF LOG: LDT/CNL ON 08/12/86 ANGLE AT TOP PERF: 26 @ 9274' — Note: Refer to Production DB for historical perf data SIZE_ SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9274-9374 0 11/02/86 PBTD 10100' 06+ OA A 1 I 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" H 10150' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/26/86 ORIGINAL COMPLETION 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE WELL: LGI-02 12/15/00 SIS-MWH CONVERTED TO CANVAS PERMIT No: 86-140 02/23/01 SIS-LG FINAL API No: 50-029-21634-00 10/01/01 RN/TP CORRECTIONS SEC 1, T11N, R14E 4173.85 FEL 4385.36 FNL 03/01/07 RL DATUM MD BP Exploration (Alaska) • • Page 1 of 1 Regg, James B (DOA) A-7 t 4 4 , . 1 e 1 I 11O 15J 313 From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] ` Sk' t d Sent: Thursday, June 09, 2011 10:35 AM C/3/>1 To: Regg, James B (DOA) R e1q 6p1/ Subject: RE: TIO Plot - PBU LGI -10 (PTD 1860690) Attachments: Injector LGI -10 (PTD #1860690) TIO and Injection Plot.doc Jim, Enclosed is the requested data for LGI -10 (PTD 1860690). The injection was shut in after the test, but the IA pressure has remained 100 psi for the last 5 days. I believe the increasing IA pressure during the test was a result or thermal expansion. Please let me know if I can be of further assistance. Regards, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 - 0755 .4 ,]i. N .. S did Pager (907) 659 -5100 Ext. 1154 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, June 09, 2011 10:04 AM To: AK, D &C Well Integrity Coordinator Subject: 110 Plot - PBU LGI -10 (PTD 1860690) Please send TIO Plot for LGI -10. Commission Inspector witnessed an MIT on 6/3/11; results were deemed inconclusive because of the increasing IA pressure during the 30min test. This could be possible thermal expansion. Presumably the IA pressures were bled off following the MIT, so the IA pressure data following the MIT will be valuable in making a pass /fail decision about the MIT. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 6/9/2011 PBU LGI -10 PTD 1860690 6/9/2011 TIO Pressures Plot Well: 161-10 4,000 = r.+'•.A 3,000 - —IP— Tbg —U— IA 2 ,000 - —A— OA 004 1 ,000 - 0 0 0OA 03/12/11 03/19/11 03/26/11 04/02/11 04/09/11 04/16/11 04/23/11 04/30/11 05/07/11 05/14/11 05/21111 05/28/11 06/04/11 Injection Plot Well: LGI -10 4,000 - 80,000 3,500 - - 3,000 - - 70,00a WHIP co - 60,000 ' SW 2,500 - 50,000 ° PW . 2,000 i = 40,000 MI 1,500 _ - 30,000 GI 1,000 _ 20.000 ° — On 500 - - 10,000 03/12/11 03/26/11 04/09/11 04/23/11 05/07/11 05/21/11 06/04/11 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Regg � qq1,1 DATE: Thursday, June 09, 2011 TO: Jim Re \ P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC LGI -10 FROM: John Crisp PRUDHOE BAY UN LIS LGI -10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN LIS LGI -10 API Well Number: 50- 029 - 21573 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr110604150323 Permit Number: 186 -069 -0 Inspection Date: 6/3/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well LGI -lo 'Type Inj. G ' TVD 8261 IA 570 - 2550 2560 j '2570 P.T.D " 1860690 LTypeTest sPT Test psi 2065 OA 70 80 85 ; 85 Interval 4YRTST P/F P Tubing 3200 3200 3200 3200 Notes: 3.7 bbls pumped for test. Pressure increase 10 psi per 15 minute interval. BP Well Integrity Rep was aked if they would like to run the test out for 45 minutes or an hour. My opinion was that this possible thermal expansion could best be determined reviewing TIO pressures after well had IA bled down after the MIT. Supervisor would make determination of pass fail status. _ 7—To 004 cc ecktcet? lideLt .• WJUN 1 3 201, Thursday, June 09, 2011 Page 1 of 1 OPERABLE: LGI-10 (PTD #1860690) IA repressurization due to thermal effects Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, December 20, 2008 3:57 PM To: Regg, James B (DOA) ~~~~~ IZ~~~-~ Cc: NSU, ADW Well Integrity Engineer Subject: RE: OPERABLE: LGI-10 (PTD #1860690) IA repressurization due to thermal effects Attachments: LGI-10 TIO and Injection Plot.doc Hi Jim, ~(IUe solved the background color issue and changed gas injection to red. Red is also used for when a well is on MI but WAG wells and dedicated gas injectors are kept separate. Please let us know if this meets your needs for printing and scanning. Thanks! Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: (907} 659-5100 x1154 _.,l. ~_ i ~ z <.. e, r,,r 3 > From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, December 19, 2008 11:45 AM To: NSU, ADW Well Integrity Engineer Subject: RE: OPERABLE: LGI-10 (PTD #1860690) IA repressurization due to thermal effects Is there any way that you can either change colors being used in plots or add a grey background to plots? The gas injection plot is a faint yellow line on a white background; can barely see the plot, and yellow won't copy. I understood from Taylor that someone is supposed to be adjusting the graphs to make it easier to read the legend {black wording on dark blue background doesn't work either). Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Saturday, December 06, 2008 10:01 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GPMA OTL; GPB, LPC DS Ops Lead; GPB, Area Mgr North (Gas Plants/GPMA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Randall, Jaclyn S; Townsend, S. Eliot; Winslow, Jack L.; NSU, ADW Well Integrity Engineer Subject: OPERABLE: LGI-10 (PTD #1860690) IA repressurization due to thermal effects 12/22/2008 OPERABLE: LGI-10 (PTD #1860690) IA repressurization due to thermal effects Page 2 of 2 • • All, Well LGI-10 {PTD #1860690} showed signs of IA repressurization and was bled on 11125/08. Since this time the IA pressurization has stabilized and has not been bled again. During the observed timeframe of IA pressurization the injection rates were increased {as shown in attached plots}. We have attributed the rise in IA pressure to thermal effects from the increased injection rates and have changed the well status back to Operable. The well can continue injection as Operations sees fit. «LGI-10 TIO & Rate 12-06-08.ZIP» If there are any questions or points of clarification please contact me. Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, November 30, 2008 8:55 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FSi DS Ops Lead; GPB, FSl OTL; GPB, Area Mgr East (FSl/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Randall, Jaclyn S; Townsend, S. Eliot; Winslow, Jack L.; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: LGI-10 (PTD #1860690) Increased rate of IA repressurization All, Well LGI-10 (PTD #1860690) showed signs of IA pressurization and broke MOASP on 11/25/08. The TIO's on 11/25/08 were recorded as 3930/2100/400 psi. The well was bled immediately and has been monitored for repressurization. During this timeframe the injection rate has increased daily and is believed to be the cause of the IA pressurization. Therefore the well has been reclassified as Under Evaluation to monitor the wellhead pressures. The plan forward for the well is as follows: 1. DHD: Monitor wellhead pressures A TIO plot and wellbore schematic have been included for reference. « File: LGI-10 TIO.doc (Compressed) » Please call with any questions. Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 12/22/2008 I,Gi-1C'~ (PTD #1860690) TIO Plot a,ooG 3. U00 2:000 1:000 ~!p,'2p1L'8 0~~'2?!0$ 1 Oi0a ~ ~0 1 G'111 !Uc 1011$108 i ~: ~ 510$ 11101 ~ U$ 11 !0$!0$ 11115~r0$ 17122 J0$ 11 J2$i p$ 1210610$ 12J13J0~ 121201 U$ i..LF`- _ ` ;PTD #1850690) Injection Plot .... _ . _ ..... .-~.~... ~....~.....-..-.~-..-~.-.~-~......-..-.~..-..-.-~~. 1 Go.GOn ^~,~ .. .. - --~~ , %'r. ~~ $0:000 j ~, . 50,000 . ~e~~ ii 4 = =.Gu 1 y ~ 40,000 ,~', r .QUO a 20,000 r I ~ ;~ -j f a 0$ ~?~:«0$ 09127lU8 ~ Ol~'aJfB I ! ° ~ 1 ~4$ 1011$!n$ 10125/US 11101 !0$ 1110$108 i l 11510$ 11 J22i 0$ i t 12910$ 12JU610$ 12/1.$10$ 1212UJ08 -~ Tbg -E- IA -~ OA -+- OOA -~ OOOA ^- On WHIP SW Irv MI GI 0 Cher On • • • PBU LGI-10 PTD 186-069 12/6/2008 UNDER EVALUATION: LGI-10 (PTD #1860690) Increased rate of IA repressurization Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, December 01, 2008 4:47 PM ~~~ 1~71~/ (2LG~Ci To: 'NSU, ADW Well Integrity Engineer' Cc: Maunder, Thomas E (DOA) Subject: RE: UNDER EVALUATION: LGI-10 (PTD #1860690) Increased rate of IA repressurization Page 1 of 1 Thank you for the notice. We would appreciate an update when you confirm what caused the sudden increase in IA pressure. Please also note in the update when pressure bleeds occur. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 ~8'1<3~t~~~ ~ ~ ~ ~~ ~ ~~ ~ ~~~` Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Sunday, November 30, 2008 8:55 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Randall, Jaclyn S; Townsend, S. Eliot; Winslow, Jack L.; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: LGI-10 (PTD #1860690) Increased rate of IA repressurization AI I, / ~~ a~e~~. ~~~~~ St,V~ 1~SSLi,~2. Well LGI-10 (PTD #1860690) showed signs of IA pressurization and broke MOASP on 11/25/08. The ~10's on 11/25/08 were recorded as 3930/2100/400 psi. The well was bled immediately and has been monitored for repressurization. During this timeframe the injec ion rate has increased daily and is believed to be the cause of the IA pressurization. Therefore the well has been reclassified as Under Evaluation to monitor the wellhead pressures. The plan forward for the well is as follows: 1. DHD: Monitor wellhead pressures / A TIO plot and wellbore schematic have been included for reference. «LGI-10 TIO.ZIP» Please call with any questions. Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 12/ 1 /2008 • • PBU LGI-10 PTD 186-069 11/30/2008 ~-. v .~ ~t ~znFr,, Qin6~ ozf7F~ee o~~~a~-~ oa;;sn~e o~,nwo~ oeriwoG n+~V~)~ ~za.~ r~~znm 1ruz1liTa ,~rzv~:, MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg ~e.d.(j(; £17(0] P.I. Supervisor T DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC LGI-1O PRUDHOE BAY UN LIS LGI-1 0 \,0/ DId\ ,Lb FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv,J~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN LIS LGI-IO API Well Number: 50-029-21573-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070606080545 Permit Number: 186-069-0 Inspection Date: 6/5/2007 ../ ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well LGI-1O Type Inj. G TVD 8261 IA 400 I 2500 2500 2500 I P.T.D 1860690 TypeTest SPT Test psi 2065.25 OA 0 I 0 0 0 I Interval 4YRTST P/F P ../ Tubing 3700 I 3700 3700 3700 I Notes: Pretest pressures observed and found stable. ,./ sCANNED JUN 2 1 2007 Wednesday, June 06,2007 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winlon_Auberl@admin.slale.ak.us;Bob_Fleckenslein@admin.slale.ak.us;Jim_Regg@adrnin.slate.ak.us;Tom_Maunder@adrnin.slale.ak.us OPERA TOR: FIELD I UNIT I PAD; DATE: OPERATOR REP; AOGCC REP: BP Exploration (Alaska), Inc. lis bourne I GPMA I LGI pad 06/05/07 Anna Dube Chuck Scheve Packer Depth Prelest Initial 15Min. 30 Min. Weill LGI-02 I Type Inj. I G TVD I 8,260' Tubing 3700 3700 3700 3700 Interval I 4 P.T.D.I 1861400 I Type test I P Teslpsi 2065 Casing 400 2500 2500 2500 P/FI P Notes: AOGCC Slale witnessed MIT-IA for UIC OA 0 0 0 0 út Weill LGI-10 1\ Type Inj. I G TVD I 8,261' Tubing 4000 4000 4000 4000 Inlervat 4 p.T.D.1 1860690 I tType lesl I P Tesl psil 2065 Casing 600 2500 2460 2460 P/FI P t . '9V'~~. e wilnessed MIT -IA for UIC OA 0 0 0 0 compliance. Well' I Type Inj.1 I TVD I Tubing Interval! P.T.D. I Type testl Tesl psi Casing P/FJ Noles: OA Well' I Type Inj.' , TVD I Tubing Inlervall P.T.D.I I Typelestl I Test psi' Casing P/F! Noles: OA Weill I Type Inj.' I TVD 1 Tubing Inlerval p.T.D.1 ! Type lest , Test psil Casing P/FI Noles; OA TYPE INJ Codes D ~ Drilling Waste G ~ Gas I ~ Industrial Wastewater N ~ Not Injecting W ~ Waler MIT Report Form BFL 9/1/0S TYPE TEST Codes M ~ Annulus Monitoring P ~ Standard Pressure Test R ~ Internal Radioactive Tracer Survey A ~ Temperature Anomaly Survey D ~ Differential T emperalure Test INTERVAL Codes I ~ Initial Test 4 ~ Four Year Cycle V ~ Required by Variance T ~ T esl during Workover o ~ Other (describe in notes) SCANNED JUN 1 22007 MIT GPMA LGI-02, LGI-20 06-0S-D7.xls I J' Ofo~ \ f.Q '0 ~ r"\ {'7ÎJ r.1'P n~\ C";', I, (.,1 \1,_, í! if¡ \ II - I" -. --. t ¡ : i ,,' ¡ \ i~' , ClJ) U LrÜ U Lb ("'" 1..0"1 r' \ ,.- ¡ I ! ¡ l . , ¡ I í J ,.. lU) u !A--\ ['1 1/-;:\ (c:~\ ¡'liï ll\\ . \ I \ \ "'. ¡ ( . ¡ \ /"'\I! !l.\\_'_\i¡-,/i' lI\'1 ~Lru t~ U\.1U Ü ì / f ! .. FRANK H. MURKOWSKI, GOVERNOR , ALAS fiA 0 IL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276.7542 May 12, 2004 Mr. Bruce 1. Williams GPB Operations Integrity Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage,AJ( 99519-6612 ~~-b~ e¡ Dear Ms. Williams: The Alaska Oil and Gas Conservation Commission ("Commission") perfonned an inspection of your well safety valve system (SVS) at Lisburne Gas Injection (PBU LGI) on May 1, 2004. Attached is a copy of the Inspection Report. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 22.2 percent was identified during the above-noted inspection. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 10% failure threshold. Effective May 1, 2004, and until an acceptable level of performance is achieved, the safety valve systems associated with wens located on PBU LOI must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to w' ess the SVS test. Sincerely, ø~ Daniel T. Seamount, Jr. Commissioner Attachment cc: AOOCC Inspectors (via email) Safety Valve & Well Pressures Test Report - Review Reviewed By: P.I. Suprv Comm Pad: PBU_LIS_LGI Inspection Dt 5/1/2004 Inspected by John Spaulding Interval: InspectNo: svsJS040501164551 Src: Inspector Field Name PRUDHOE BAY Operator BP EXPLORATION (ALASKA) INC Operator Rep Bill Moxlow Reason ISO-Day Well Number Permit Number Separ PSI Set PSI LIP Trip Test Test Test Code Code Code Date SI Oil,WAG.GINJ, GAS,CYCLE, SI Inner PSI Outer PSI Tubing PSI Yes/No Yes/No LGl-06 1860670 4000 2900 2700 P P P IGINJ -.0 0 3850 No No -- LGI-IO 1860690 4000 2600 1800 30 P P IGINJ 450 0 4150 No No LGI-02 1861400 4000 2900 2300 P 40 P \GINJ 200 0 4060 No No ) Comments Performance LGl.2 ssv initially failed - stroked valve, retested and passed, possibly hydrates LGl-IO pilot initially failed - cycled and retested ok at 2600psi Wells 3 Components 9 Failures 2 Failure Rate 22.22% ) Wednesday, May 12,2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state. ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / GPMA / LGI 06/15/03 John Petty John Crisp Packer Depths (ff.) I Pretest Initial 15 Min. 30 Min. WelllLGI-02 I Type Inj. J G Test psil 2,0651 I Casin~ll 2401 2,5001 2,4601 2,4601 P/FI ~°1~.~°1 ~.~°1 ~"~'~1 ~,~°°1 ~.~oq ~.~oq ~,~oq mt~I P.T.D.~1861400 T~pe test Notes: 4-year MITIA WeIIILG,-10] Typelnj. I ~ I'~'~1 ~'~'1 ~'~0'1Tubingl 4'0001 4'0001 4'0001 4'0001 Inte~al P.T,D. I1860690 Type test I I Test psiI 2,0651 "1 Casin~l 2801 2,5001 2,5001 2,5001 P/FI Notes: 4-year MITIA Type Inj Notes: P.T.D.I Notes: WellI P.T.D.I Notes: Type Inj. Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 AUG 0 ~ 2003 2003-0615_.MIT_PtMac_LGI-02_-10.xls ~RE: FYI: MIT Forms for WGI & LGI Subject: Date: From: To: CC: RE: FYI: MIT Forms for WGI & LGI Mon, 16 Jun 2003 00:05:20 -0500 "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer~BP.com> "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer~BP.com>, "AOGCC Field Inspectors (E-mail)" <AOGCC_Pmdhoe_Bay~admin.state.ak.us>, "AOGCC Jim Regg (E-mail)" <Jim_Regg~admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <Winton_Aubert~admin.state.ak.us>, "AOGCC Bob Fleckenstein (E-mail)" <Bob_Fleckenstein~admin.state.ak.us> "Petty, John C" <PettyJC~BP.com>, "Engel, Harry R" <EngelHR~BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor~BP.com>, "Rossberg, R Steven" <RossbeRS~BP.com> With the attachments this time! <<MIT GPMA LGI-02, 10 06-15-03.xls>> <<MIT PBU WGI-06, 07 06-15-03.xls>> > ..... Original Message ..... > From: NSU, ADW Well Integrity Engineer > Sent: Sunday, June 15, 2003 9:04 PM > To: AOGCC Field Inspectors (E-mail); AOGCC Jim Regg (E-mail); AOGCC Winton Aubert (E-mail); AOGCC Bob Fleckenstein (E-mail) > Cc: Petty, John C; Engel, Harry R; NSU, ADW Well Operations Supervisor; Rossberg, R Steven > Subject: FYI: MIT Forms for WGI & LGI > > Attached are MIT forms for 4-year MIT's conducted at WGI & LGI on 6/15/03. All the MIT's passed. Please call if you have any questions. Joe Joe Anders, P.E. / John Cubbon Well Integrity Coordinator, BP Exploration, Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, x1154 Emai l : NSUADWWel l In tegri tyEngineer@bp . corn (Alaska) Inc. I P 02 "'~ | Type: Microsoft Excel Worksheet [-~M T G MA LGI- ,10 06-15-03.A~i. '' ~ tappncauoruvna.ms-exce~) i!Encoding: base64 I B 6 [-~M T P U WGI-0 , 07 06-15-03.x,~ ' ' ' 1 of 1 6/25/2003 3:14 PI~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commbsion TO: THRU: FROM: Julie Heusser, ' ,~\u DATE: Commissioner Tom Maunder, ~A/~~sUB~cT. P. I. Supervisor' John H Spaulding, Petroleum Inspector April 10, 2001 SVS Tests. BPX PBU LGI & PM-O1 April 11, 2001' I traVeled to BPX's Lisbume Gas Injection (LGI) and also on to the Point Mclntyre PM-01 location to witness Safety Valve Testing. The AOGCC SVS test reports are attached for reference. As noted 3 failures were observed on both pads; with 2 being repaired and retested immediately. The third failure a sssv and Will need further attention. Mark Wysocki, lead operator was training 2 new hires. The crew did an excellent job. Summary: ! witnessed the SVS tests on LGI and PM-01 LGi, 3 wells, 9 components, 1 failure, 11% failure rate PM-01, 11 wells, 33 components, 2 failUres, 6% failure rate Attachment; Svs bpx igi 4-10-01js Svs bpx prn-01 4-10-0 ljs N0,,,n Con~iden~ti, al Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Mark Wysocki .... AoGcC Rep: _John H~ Spaulding . . Submitted By: John._ Spaulding Date: Field/~nit/Pad: Pt Mcln~e/PBU/PM-01 Separator psi: LPS ' 460 HPS 4/9/01 i · . . - .:- _ ~ Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Numbe, r Number. , ,P.,.SI , PSI Trip ,.. Code Code ,Code Passed . G,AS or C,Y, CL~ 12 191'0370 m_o2"' 1880050 .................................. PI-O~" 18~0130 ' " 460 ' ~50 ' " 310 P 'p P ........ OIL P 1-04 'i 9306~0 460 700 700 P P P OIL _ P1-05 "1930870 '" 460' 350 300 P P 9 oIL pl.o6' '' 1'9~1370 ' ' 4i~0 "~0o " 67~" ' P .... P "P ..... OIL iil-07' i89i340 ' ....................... ~i-208 "i'9~0980" ' 460 "1500 '1200 .... P ........ P' 'P ......... oil Pi-09 '' 1'961540 " 460 "'350 300 P P P ........ 0iL PI-ll' ' 1920860' ' 460 350 ' '250 pi ' P P ....... 0IL Pl-12 1910130! Pl-i3"' 1930740 .... 460 ' 1'500 1150 P "'P- P ......... ' ...... OIL P1-17 1930510 460 ' 3'50 ' 280 P P P OIL , , P1-20' 1'920940 ' ~0 .... 350 175' 5 "'P .....P .... 4/9/01 ...... 0IL P1-23 1961240 Pl'2~ ...... "1961490 ......................... P1-G1 1921150 3600 2900 2850 P P P G~NJ Wells: , ,, 11, Components: 22 Failures: 2 Failure Rate: 9.09% 0 ~o oar Remarks: P1.,0S & P1-3 were choked back, hence the higher pilot settings ............... p 1_:20 pilot re-Set..~.d. 'rete..stedI' .'....' .... "".'-'i.. .: .. .......... "..-. RJF 1/16/01 Page 1 ofl 010409-SVS PM-01 PBU-js Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: ,,M. ~k Wysocki AOGCC Rep: J0 ~hr), H' Spaulding Submitted By:. Tjo.,hn,.Spauld'm4g Date:. Field/Unit/Pad: Lisburne/PBU/LOI Separator psi: LPS.~ HPS 4/9/01 ~ Well Permit Separ Set L/P Test Test Test Date oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE ., LGI-02 1861400 3800 2900 2300 ~ P P 4/9/01 GINJ LGI-04 1880130 LGI-06 1860670 3800 2900 2500 P P P GINJ LGI-08 1860570 ,, LGI-10 1860690 3800 2600 2300 P P P GINJ , , , LGI- 12 1860540 Wells: 3 Components: 6 Failures: 1 Failure Rate: 16.67o~] 9o oar Remarks: LGI-02 Pilot tripped to low and was reset-retested and passed RJF 1/16/01 Page 1 of l 010409-SVS LGI Lisburne-js A~¢O ALASka INC. LISBURNE ENGINEERING Date: 2-9-87 From: Pam Lambert Enclosed are the following: OH Finals for Lisburne Wells '"' L1-2 Mudlog 9-2-85 NL Baroid '~Ll-14 Mudlog 7-13-85 Westlog -"~L2-3 Mudlog 11-4-85 NL Baroid ~ L2-21 Mudlog 11-26-85 NL Baroid ~L2-25 Mudlog 1-30-86 NL Baroid ~L2-33 Mudlog 2-28-86 NL Baroid ~ L3-2 Mudlog 9-9-86 Westlog ~L3-5 Mudlog 9-18-85 Westlog ~ L3-11 Mudlog 10-25-85 Westlog ~ L3-22 Mudlog 11-18-86 Westlog '~- L3-19 Mudlog 12-19-85 Westlog -'~ L3-30 Mudlog 12-31-86 Westlog ~'- L5-4 Mudlog 1-20-87 Westlog ~'"'~-.LGI-2 Mudlog 8-7-86 Westlog LGI-6 Mudlog. 6-20-86 Westlog ~LGI-8 Mudlog 5-19-86 Westlog ~ LG~i~l%%: 7-19-86 Westlog Please sign and return tofPam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STATE EXXON STANDARD FILE ROOM TRANSMITTAL # 167 CENTRAL FILES asl0il & Gas commission Cons. Anchorage AI~CO ALA~I~ INC. LISBURI~ ENGrI~I~ING Date: 2-2-87 From: Para Lamber t Enclosed are the following: OH Finals for LGI-10 GCT Directional Survey 8-3-86 Run 2 5" Sch CBT 8-3-86 Run 2 5" Sch ~ L3-2 CET 9-21-86 Run 1 5" Sch L5-24 Gr to Position Guns 11-2-86 Run 1 5" Sch L5-24 CET 11-1-86 Run 1 5" Sch LGI-2 Perforation Record 11-2-86 Run 1 5" Sch Received by: & Gas Cons. Commission Anchorage Please sign and return t~ Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 ~ D & M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 161 AKCO ALASKA INC. LISBURNE ENGINEERING =Date: 12-19-86 From: Para Lamber Enclosed are the following: CH Final for L1-9 . Gamma Ray 1-15-86 Run 1 5" DA CH Final for LGI #10 Collar Log 10-16-86 Run I 5" DA CH Final for LI-1 Collar Log 1-21-86 Run 1 5" DA Received by: Alaska Oil & Gas Cons Commission Please sign and return to~Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STATE EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 126 STATE OF ALASKA ALAS/"%OIL AND GAS CONSERVATION COM! 'SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator Operation shutdown I~ jStimulate Alter Casing [] Other'7'~ /[~ Plugging © ARCO ALASKA, INC 3. Address P.O.B. 100360, ANCHORAGE, AK. 99510 Location of well at surface 1189' FNL, 1680' FEL At top of productive interval . Sec. 1, TllN, R14E, UM 1100' FSL, 100' ateffectivedepth 1472' FSL, 920' Attotaldepth 1.478' FSL~ 817' Perforate [] Pull tubing []" 5. Datum elevation (DF or KB) RKB 52 Feet 6. Unit or Property name Prudhoe Bay/Lisburne 7. Well number LGI-iO 8. Approval number476 9. APl number 029-21573 50-- 10. Pool LISBURNE OIb POOL FEL. FWL, FEL ~ 11, Present well condition summary Total depth: measured true vertical Sec. 30, T12N, R15E,UM Sec. 16, TllN, R15N, UM(app Sec. 29~ TllN~ R15E~UM 11420' feet Plugs(measured) NONE 9422' feet Effective depth: measured 1 1365 ' true vertical 938/+' feet Junk (measured) NONE feet Casing Length Size Structural 80 ' 20" Conductor Surface 4133 ' 13-3/8" Intermediate Production 10444 ' 9-5/8" Liner 1145 ' Perforation depth: measured 10548'-10654' true vertical 8783 '-8858' ~ Tubing (size, grade and measured depth) 5-1/2", L80, Packers and SSSV (type and measured depth) Cemented Measured depth waiting on report 110' 3200 sx PF E & 400 sx class G 1400 sx class G & 300 sx PFC 225 sx class G ~ueVerticaldepth 110' 4163' 4003' 10474' 8732' 10276-11421' 8597-9422' ~ 10666'-10816', 10852'-10952', 10968'-11074' 8866'-8978', 8998'-9071', 9083'-9160' IUBING W/IAIL @ 13428 PACKER: BROWN 28, 8.25" @ 13335' SSSV: CAMCO TRDP-1A, 4.562" @ 2175' 12. Stimulation or cement squeeze summary Intervals treated (measured) SEE ATTACHED SUMMARY REPORT ! ; ~.' ., : ]; Treatment description including volumes used and final pressure i-. ~, ,.. .... ~ .,, ~. ~ 13. Representative Daily Average Production or Injection Data Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pre~su(e Tubing Pressure -- N/A N/A 100000 N/A N/AVAIL. 4000 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] hereby certify that the foregoing is true and correct to the best of my knowledge ~, 15. I Signed B j~~~cj~,/v~b~j Form 10-404 Rev. 124-85 LISBURNE OP. COORD. Title 12/2/86 Date Submit in Duplicate LGI-10 SEQUENCE OF EVENTS W~OO ZONES 6 & 5 TESTING october 23, 1,,,9,,,8,6 Pre-stimulation flow test Wahoo zones 6 & 5. Well flowed @ rate of 10.2 MMCFD, for 6 hours. WHP-- 2400 PSI. October 24, 1986 Rig up Halliburton. Pumped Wahoo 6 & 5 perforation breakdown treatment. (Fullbore displacement - down 5 1/2' tubing.) Pumped 10 BBLS. diesel w/ 10% Musol A, 202 BBLS. 15% Hcl, flushed w/ 311 BBLS. diesel. Initial tubing pressure 3000 PSI. Pressure declined to 1100 PSI. (500 PSI drop when acind reached perforations) ISIP 620 PSI 5 min 390 PSI 15 min 5 PSI WHP @ start of flowback = 1200 PSI. (App. Shut-in - 2 hrs.) Total breakdown load = 523 BBLS. Open well to 400 BBL upright to recover diesel flush. (10=48 hrs.) Recovered 380 bbls. @ 14=00 hrs. (diesel/spent acid) Switch flOw through in-line heater and high pressure seperator. Injecting methanol in flow line to prevent hydrates and freezing. Flow well at gas rates varying from 6 MMCFD to 16 MMCFD. Final flow rate 16 MMCFD, 700 BCPD, WHP 2600 PSI. Shut-in well @ 20:45 hrs. Seperator iced up. October 25,1986 Ran Echo-Meter to determing static liquid level. Liquid level calculated @ 10,802'. Sonic velocity was 1358 FPS. 13:20 hrs. Open well to flow. Initial rate 8.4 MMCFD, 319 BCPD, WHP 2800 PSI. 21:00 hrs. Choked well back to 2.9MMCFD, 162 BCPD, WHP 2800 PSI. (To allow logging tools to drop downhole) Rig up Otis E-line unit to run HP,Temp,CCL. Run in hole with tool string. Increased flow tare to 6.1MMCFD, 700 BCPD, WHP 2800 PSI. Obtained flowing bottomhole pressures/temp @ following measured depths: 9529' 3665.4 PSI 137.2 F 10,529' 3730.1 " 149.9 " 13,229' 3911.9 " 174.2 " 13,702' 3950.0 " 176.3 " 13,810' 3966.8 " 176.6 LGI-10 SEQUENCE OF EVENTS Increased gas rate to 8.4 MMCFD~ 13,810' decreased to 3963.5 PSI. Increased gas rate to 12.4 MMCFD~ 13,810' decreased tp 3958.8 PSI. Flowing bottomhole pressure @ Flowing bottomhole pressure @ Shut-in well with bottomhole pressure gauge hung @ 13,810'. Pressure increased to 3972.8 PSI in approximately 2 hrs. Obtained static pressure stops coming out of hole @ the following depths= 13,810' 3972.8 PSI 13,702' 3957.5 13,229' 3919.8 " 10,529' 3736.1 9529' 3671.0 ARCO ALASF, A INC. LISBURNE ENGINEERING Date: 12-1-86 From: Para Lambert Enclosed are the following: Finals for LGI 10 FMS Composite 7-24-86 Sch Part 1 of 4 through 4 of 4 Received by: Please sign and return to:Pam Lambert ARCO AK INC. 700 G Street AT0~7 Anchorage, AK. 9951 D &M STATE EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 109 LISBURNE ENCINEERINC Date: 11-17-86 From: Para Lambert' ~~ Enclosed are the following: Pressure Reports ~LI'U2~'~ 9-17-86 Static Gradient Camco LGI I0 10-25-86 Flowing Gradient Otis L2-33 Production Profile 11-5-86 Run 1 Camco Field Print __ / 'NOV 2 5 1986 (._9 "~ ~//Alaska Oil & Gas Cons. CommlsgOll Anchorage Received by: Please sign and return t~ Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M EXXON STANDARD CENTRAL FILES TRANSMITTAL # 102 :,~"~ STATE OF ALASKA ~ ~ ALASKA~L AND GAS CONSERVATION C(~,~iM'ISSION f~ 1. Status of Well Classification of Service Well OIL [] (~AS [] 'SUSPENDED [] ABANDONED [] SERVICE [~ 2. Na'me'0f OPerat°r ....................................... 7. Permit I~umber ARCO Alaska, Inc. 86-69 3. Address 8. APl Number P. 0. Box 10036.0, Anchorage,. AK 99510-0360 . . 50- , .029-2157;~ 4. Location of well at surface 9. Unit or Lease Name 1129' FNL, 1680' FEL, Sec. 1, T11N, R14E, UM Prudhoe Bav Unit/Lisburne At Top PrOducing Interval '10. Well Number '1136' FSL, 4590' FWL, Sec. 30, T12N, R15E, UM LGI-IO At Total Depth 11. Field and Pool 1416' FSL~ 4837' FWL~ Sec. 30~ T12N, R15E, UN~ Prudhoe Bay Field 5. Elevation in f~t (indicate KB, O~, etc,) J 6, 'Leas-e ~ignat-io'n and Serial No. Prudhoe Bay 0i l Pool 52' RKB , ~ ~I ADL 34628 ALK .863. . 12. Date Spudded 13. Da~eT.D. Re~h~ 14. DateC~P.,-Su~.orAband. ~lS. WaterD~th, ifoffshore 116. No. of Completions 07/01/86 07/23/86 07/~7/86' ........ ' N/A~~. feet MSL 1 17. TotaiDePt'h(MD+TVD) iS.PlagBa~k'Depth,~) 19.:DireCtionalSurvey I 20. Depthw~ereSSSVset ! 21. Thickness of Permafrost 14216 'MD,.8884 'TVD 14170 'MD ,.8849 ,TVD YES~ NO ~ 2175 feet MD l~n, 22. Type E~t.r'~ Or ~Othe'r L~S Run ' ' ' DLL/SP/NGT/CAL, LDT/GR/CNL/EPT/CAL, FSH/GR/ANS. CET, 23.. ............. ' .CA~JNG,.L!~N~:R AND CEME~?NG ~.ECORO SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTT'OM HOLE SIZE CEMENTING 'RECORD AMOUNT PULLED ..... . wv,, 13-3/8" 6fl.0/72_O~ K-~R/I-R~ &urf . R~7~ .~7-!/2" 2~00 SX A~ ~ ~ E0O ~X C]:== G 9-5/8" . ~7.0~ . . L~80 .'Surf 13~R2f .... 12,1/~" 9~0 ~ 7" 29.0~ 1-80 . ~1~', . 1~21R~ .... R-1/9~ 300 sx 24. Perforations open to Productio~ (MD+TVD of Top and Bottom and 2-~. "- TUBING RE~ORD' interval, size and number) SlZE DEPTH SET (MD) PACKER SET (MD) 13662' - 13738'HD 8~76' - 8530~TVD 5-!/2" !3(2~', 137~8~ - 13868~HD 8537~ - 8623~TVD ~ , ~26. ' ...... ACID, FRACTURE, CEMENT SQUEEZE, ETC. .-DEPTH INTERVAL (UD) .AMOUNT ~ K,Np OF MATERIAL USED --N-/A ........................ .......... , ~ , , , . ~ , , , ...... 27. N/A .... PRODUCTION TEST O~e F~,~ ~o~ ] U~,ho~ ~ Op;a;~o~ (~,°;~n~. ;a~ ~,'~'~'. e;;.~ ! cHOKE SIZE {~A~'0~'~RA~IO TEs~ PERIOD '~ F'lo~ Tabin~- ~'a;ing'PreSsure CALCULATED'~ 01"L-BS"L ..... G~S-MCF ' WATER-BBL'' OIL GRAV'ITY' ~P~ {'c°rr) Press. 24-HOUR RATE ~ ~2~ ........... ' ' "CORE DATA ' ~ ~ , ~ ....... , · . , ...... ~ , ......... Brief aescription of HthOlo'~, porosity, fraCtures, apparent dips and presence of oil, gas or ware r. Submit core chips. None EE EIVE9 NOV ~ 7 ]986 ~ 0il & ~as C0~. C0mmi~io~ ~ch0rage Form 10-407 Rev. 7-1 '80 CONTINUED ON REVERSE SIDE DAM/WCl:150 Submit in duplicate~ 29.__ I':' 30~ {,? '~'~ '~ GEOLOGIC MAR ~I~R~:j · ' . "-FORMATION TESTS . NAME Include interval tested, pressure datal all fluids recovered and'gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ..- Top Wahoo Zone 7 Trunca~:ed N/A Top Wahoo Zone 6 1366/+' 8/+78' Top Wahoo Zone 5 13750~ 8538' Top Wahoo Zone ~, 13876' 8629' Top Wahoo Zone 3 lZ~127' 8816' Top Wahoo: Zone 2 1./+193 ' 8866' 31. LIST OF ATTACHMENTS None · 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~ ~,, TitleAss°ci ate Engi near Date //-/2-~ Signed // ,,, 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 cement- ing and the location of the cementing tool. ' Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 10/22/86 6/23/87 thru 6/30/87 LGI-10 Perform long term tubing test. Inject reserve pit fluids w/cumulative total of 33,350 bbls. Drilling Supervisor Date ADDENDUM WELL: LGI-10 7/20/88 Arctic Pak well w/ 400 sx AS 1. Date DRILLIN9 ANCHORAGE FILE COFY ARCO ALASK~',, INc., ~UB-$URFACE DIRECTIONAL ~URVEY I~1 UIDANCE I o ,, uou NICi OFILMED I~OOL Company ARCO ALASKA, INCORPORATED Well Name LGI-IO (1129' FNL, 1680' FEL, SEC 1,TllN?R14E,UM) F~e~d/Locat[Orl .... PRUDHOE BAY/LISBURNE,, POOL~ NORTH SLOPE~ ALASKA · lOb l:leferenc® No. R E C E IV E D 71650 AUG 2 ~ 198~ 3-AUG-86 Loaaed By: Computed By: SALAZAR Alaska 0il & 6as Cons, Gommission Anchorage HAL S T EAD GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA~ INC. LGI-IO PRUDHOE BAY/LISBURNE POOL NORTH SLOPE,ALASKA SURVEY DATE: 03-AUG-86 ENGINEER: SALAZAR METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH " INTERPCLATION: LINEAR VERTICAL ~ECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 40 DEG 36 MIN EAST LGI-IO PRUDHOE 5AY/LISSURNE POOL NORTH SLOPE,ALASKA COMPUTATION DATE: 13-AUG-86 PAGE DATE OF SURVEY: 03-AUG-86 KELLY BUSHING ELEVATION: ENGINEER: SALAZAR INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -52.00 0 0 N 0 0 E 100.00 100.00 48.00 0 15 S 88 3 E 200.00 200.00 148.00 0 9 S 32 52 W 300.00 .300.00 248.00 0 21 S 31 13 E 400.00 400.00 348.00 0 15 S 73 43 E 500.00 500.00 449.00 0 10 S 11 11 E '600.00 599.99 547.99 0 27 S 45 lg E 700.00 699.99 647.99 0 47 N 70 34 E 800.00 799.95 747.95 I 54 N 47 10 E 900.09 699.85 847.85 3 36 N 43 15 E 1000.00 999.54 947.54 5 5 1100.00 1099.02 1047.02 6 30 1200.00 1198.22 1146.22 8 4 1300.00 1297.02 1245.02 9 28 1400.00 1395.43 1343.43 11 3 1500.00 1493,29 1441,29 12 37 1600.00 1590.55 1538.55 14 27 1700.00 1686.85 1634.85 16 40 1800.00 1782.09 1730.09 18 52 l~O0.O0 1875,94 1823.94 21 42 N 39 44 E N 37 49 E N 35 36 E N 34 24 E N 34 42 E N 34 26 E N 32 24 E N 30 25 E N 31 51 E N 36 29 E 2000.00 1967.61 1915.61 25 lB 2100.00 2056.90 2004.90 27 49 2200.00 2144.71 2092.71 29 19 2300.00 2230.82 2178.82 32 4 2400.00 2314.24 2262.24 34 55 2500.00 2394.97 2342.97 37 15 2600.00 2473.02 2421.02 40 8 2700.00 2548.10 2496.10 42 26 2800.00 2620.06 2568.06 45 44 2900.00 2687.29 2635.29 49 48 52.00 FT 3000.00 2749.02 2697.02 54 1 3100.00 2804.63 2752.63 58 17 3200.00 285~.58 2802.58 61 3 3300.00 2902.71 2850.71 61 6 3400.00 2951.72 2899.72 60 6 3500.00 3002.03 2950.03 59 35 3600.00 3052.77 3000.77 59 25 3700.00 3103.92 3051.92 59 3 3800.00 3155.25 3103.25 59 30 3900.00 3205.35 3153.35 60 9 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E 0.07 0.13 0.10 S 0.22 E 0.10 0.26 0.18 S 0.36 E -0.29 0.27 0.69 S 0.36 E -0.27 0.18 1.00 S 0.75 E -0.12 0.96 1.04 S 1.02 E -0.38 0.24 1.64 S 1.33 E -0.10 2.10 1.88 S 2.05 E 2.61 0.29 0.16 S 4.20 E 6.98 2.69 2.92 N 7.31 E 14.71 1.66 8.78 N 24.89 1.16 16.71 N 37.48 2.17 26.86 N 52.85 0.84 39.54 N 70.47 1.57 54.14 N 90.89 1.56 71.02 N 113,97 2.43 90.38 N 140.51 2.18 113.42 N 170.53 2.71 139.63 N 204.79 3.50 N 32 8 E 244.47' N 30 46 E 288.78 N 33 58 E 336.16 N 32 53 E 386.60 N 33 25 E 441.19 N 35 40 E 499.93 N33 6 E 562.05 N 31 55 E 627.41 N 31 38 E 695.99 N 31 43 E 769.07 N 31 51 E 846.80 N 31 56 E -928.92 N 32 7 E 1014.56 N 32 41 E 1101.31 N 33 20 E 1187.72 N 34 3 6 1273.51 N 34 47 E 1359.18 N 35 47 E 1444.73 N 36 22 E 1530.29 N 37 0 E 1616.63 0.00 N 0 0 E 0.24 S 65 27E 0.40' S 63 43 E 0.77 S 27 25 E 1.24 S 36 51 E 1.46 $ 44 32 ~ 2.11 S 39 0 2.78 S 47 23 4.21 S 87 48 E 7.87 N 68 12 E ~ 12.36 E 15.16 N 54 38 E 18.74 E 25.11 N 48 16 E 26.26 E 37.56 N 44 21 E 35.08 E 52.85 N 41 34 E 45.12 E 70.48 N 39 48 E 56.81 E 90.95 N 38 39 E 69.69 E 114.12 N 37 38 E 83.59 E 140.89 N 36 23 E 99.14 E 171.24 N 35 22 E 168.00 N 118.67 E 205.69 N 35 14 E 4.07 2.01 1.78 3.05 3.36 2.82 3.18 2.41 3.98 4.24 200.78 N 141.41 E 245.58 N 35 9 E 239.46 N 164.38 E 290.45 N 34 28 E 279.76 N 190.15 E 338.27 N 34 12 a 322.08 N 218.29 E 389.08 N 34 7 E 368.42 N 248.11 E 444.18 N 33 57 E 416.70 N 282.04 E 503.17 N 34 5 ~ 468.19 N 317.42 E 565.65 N 34 8 ~ 523.98 N 352.77 i 631.66 N 33 57 ~ 583.04 N 389.23 E 701.03 N 33 43 E 646.01 N 428.07 E 774.97 N 33 31 E 4.29 4.28 1.13 0.76 1.03 0.86 0.69 0.78 1.30 0.55 712.84 N 469.53 E 853.58 N 33 22 E 783.37 N 513.43 E 936.63 N 33 14 E 856.81 N 559.34 E 1023.22 N 33 8 E 930.85 N 606.28 E 1110.88 N 33 4 E 1003.92 N 653.79 E 1198.04 N 33 4 E 1075.86 N 701.69 E 1284.46 N 33 6 E 1146.92 N 750.43 E 1370.61 N 33 11 E 1217.09 N 600.02 E 1456.48 N 33 19 E 1286.43 N 850.59 E 1542.21 N 33 28 e 1355.80 N 902.31 E 1628.61 N 33 38 E COMPUTATION DATE: 13-AUG-86 PAGE 2 ARCO ALASKA, INC. DATE OF SURVEY: 03-AUG-86 LGI-IO PRUDHOE BAY/LISBURNE POCL NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: SALAZAR $2.. O0 F1 INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET DEG MIN 4000.00 3255.07 3203.07 60 9 4100.00 3304.34 3252.84 60 16 4200.00 3353.90 3301.90 61 0 4300.00 3402.04 3350.04 61 20 4400.00 3449.60 3397.60 61 50 4500.00 3496.30 3444.30 62 39 4600.00 3542.37 3490.37 61 55 4700.00 3590.1~ 3538.18 61 5 4800.00 35~0.02 3588.02 59 10 4900.00 3692.11 3640.11 58 22 N 37 17 E 1703.24 N 37 53 E 1789.84 N 38 48 E 1876.92 N 39 37 E 1964.54 N 40 4 E 2052.50 N 40 25 E 2140.92 N 41 3 E 2229.67 N 41 5 E 2317.50 N 41 2 E 2404.18 N 41 21 E 2489.54 0.29 1.42 0.88 0.86 0.42 0.98 2.13 1.79 1.70 0.28 1424.95 N 954.74 5 1715.22 N 33 49 E 1493.78 N 1007.51 E 1801.79 N 33 59 E 1562.01 N 1061.71 E 1888.68 N 34 12 E 1629.95 N 1117.09 E 1976.01 N 34 25 E 1697.42 N 1173.52 E 2063.58 N 34 39 E 1764.90 N 1230.67 E 2151.60 N 34 1832.22 N 1288.51 E 2239.92 N 35 1898.32 N 1346.34 E 2327.28 N 35 20 1963.75 N 1403.20 E 2413.56 N 35 32 E 2027.95 N 1459.46 E 2498.52 N 35 44 E 5000.00 3744.79 3692.79 57 59 5100.00 3798.11 3746.11 57 39 5200.00 3851.74 3799.74 57 33 5300.00 3905.73 3853.73 56 59 5400.00 3960.86 3908.86 56 9 5500,00 4016.66 3964.66 55 54 5600.00 ~072.95 4020.95 55 26 5700.00 4129.44 4077.44 56 17 5800,00 4184.23 4132.23 57 3 5900.00 4238.10 4186.10 57 39 N 41 14 E 2574.53 N 40 29 E 2659.13 N 40 49 E 2743.53 N 41 17 E 2827.70 N 41 52 E 2911.11 N 42 18 E 2994.07 N 42 22 E 3076.68 N 43 21 E 3159.14. N 44 37 E 3242.64 N 45 19 E 3326.64 0.92 0.39 0.34 0.77 0.78 0.82 0.93 2.11 1.26 0.59 2091.68 N 1515.69 E 2583.11 N 35 55 E 2155.77 N 1570.92 E 2667.42 N 36 4 E 2219.82 N 1625.89 E 2751.56 N 36 13 E 2283.31 N 1681.15 E 2835.45 N 36 21 E 2345.70 N 1736.53 E 2918.53 N 36 30 E 2407.25 N 1792.19 E 3001.14 N 36 40 E 2468.38 N 1847.81 E 3083.40 N 36 49 E 2528.97 N 1903.82 E 3165.48 N 36 58 E 2589.15 N 1961.93 E 3248.52 N 37 9 E 2648.69 N 2021.53 E 3331.99 N 37 21 E 6000.00 4291.53 4239.53 57 37 6100.00 4345.06 4293.06 57 34 6200.00 4399.66 4347.66 56 18 6300.00 4454.57 4402.57 56 56 6400.00 ~509.92 4457.92 56 18 6500.00 4565.10 4513.10 56 29 6600.00 4620.83 4568,83 55 53 6700.00 4676.56 4624.56 56 5 6800.00 4732.53 4680.53 56 10 6900.00 4787.74 4735.74 57 1 h 45 54 E 3410.85 N 46 14 ~ 3494.92 N 45 52 E 3578.30 N 45 31 E 3561.54 N 45 41 E 37~4.52 N 46 10 E 3827.54 N 45 29 E 3910.21 N 43 52 E 3993.01 N 40 58 E 4075.82 N 38 40 E 4159.18 0.50 0.51 1.40 1.10 0.75 0.43 1.18 2.58 2.74 1.82 2707.84 N 2081.93 E 3415.67 N 37 33 E 2766.36 N 2142.84 E 3499.21 N 37 45 E 2824.41 N 2203.24 E 3582.11 N 37 57 E 2882.78 N 2263.03 E 3664.94 N 38 7 E 2941.14 N 2322.45 E 3747.54 N 38 17 E 2999.06 N 2382.46 E 3830.21 N 38 27 .,~) 3056.80 N 2442.12 E 3912.54 N 38 3', 3115.64 N 2500.69 E 3995.09 N 38 45 ' 3176.82 N 2556.58 E 4077.78 N 38 49 E 3241.08 N 2609.69 E 4161.14 N 38 50 E 7000.00 4841.28 ~789.28 57 59 7100.00 4893.78 4841.78 58 30 7200.00 4945.59 4893.59 59 15 7300.00 4996.48 4944.48 59 35 7400.00 5047.33 4995.33 58 42 7500.00 5099.87 5047.87 58 25 7600.00 5151.51 5099.51 59 28 7700.00 5201.58 5149.58 59 54 7~00.00 5251.85 5199.85 59 47 7900.00 5302.28 5250.28 59 50 N 38 13 E 4243.56 N 38 13 E 4328.60 N 38 28 E 4414.07 N 38 35 E 4500.09 N 38 27 E 4586.15 N 38 26 E 4671.17 N 39 8 E 4756.76 N 40 8 E 4843.30 N 40 11 E 4929.75 N 41 20 E 5016.10 0.65 0.33 0.95 0.57 1.90 0.86 1.59 1.75 0.87 1.42 3307.34 N 2662.05 E 4245.59 N 38 49 E 3374.22 N 2714.70 E 4330.70 N 38 49 E 3441.30 N 2767.76 E 4416.23 N 38 48 E 3508.61 N 2821.42 E 4502.31 N 38 48 E 3575.91 N 2875.13 E 4588.41 N 38 48 E 3642.56 N 2928.02 E 4673.49 N 38 47 E 3709.42 N 2981.53 E 4759.13 N 38 47 E 3776.09 N 3036.73 E 4845.68 N 38 48 E 3842.05 N 3092.60 E 4932.09 N 38 49 E 3907.59 N 3148.83 E 5018.40 N 38 51 E ARCO ALASKA~ INC. LGI-IO PRUDHOE 5AY/LIS3URNE POOL NORTH SLOPE,ALASKA COMPUTATION DATE: 13-AUG-86 , PAGE DATE OF SURVEY: 03-AUG-86 KELLY BUSHING ELEVATION: ENGINEER: SALAZAR 52.00 FT 8000.00 '5352.30 5300.30 60 6 8100.00 5401.93 5349.93 60 26 8200.00 5450,82 5398.82 60 48 8300,00 5500.13 5448,13 60 12 8400.00 5549.88 5497.88 60 8 8500.00 5599.33 $547.33 60 35 8600.00 5648.00 5596.00 61 13 8700.00 5695.53 5643.53 61 43 8800.00 5742.56 5690.56 62 30 8900.00 5787.88 5735.8~ 63 15 9000.00 5832.71 5'780.71 63 31 9100.00 5877.59 5825.59 62 33 9200.00 5925.40 5873.40 60 22 9300.00 5976.37 5924.37 58 17 9400.00 6030.47 5978.47 56 47 9500.00 6084.90 6032.90 57 21 9600.00 6138.30 6086.30 58 3 9700.00 6190.95 6138.95 58 18 9800.00 6244.27 6192.27 57 24 9900.00 6297.81 6245.81 58 0 10000.00 6350.44 6298.44 58 8 10100.00 6403.61 6351.61 57 27 10200.00 6457.90 6405.90 57 17 10300.00 6511.90 6459.90 57 17 10400.00 6565.84 6513.84 57 28 10500.00 6619.62 6567.62 57 22 10600.00 6673.75 6621.75 57 6 10700.00 6728.18 6676.18 56 56 10800.00 6782.93 6730.93 56 41 10900.00 6837.98 6785.98 56 29 11000.00 6893.27 6841.27 56 22 11100.00 6948.87 6896.87 56 6 11200.00 7004.68 6952.68 56 0 11300.00 7060.65 7008.65 55 52 11400.00 7117.32 7065.32 55 12 11500.00 7174.41 7122.41 55 8 11600.00 7231.52 7179.52 55 17 11700.00 7288.34 7236.34 55 16 11800.00 7345.25 7293.25 55 21 11900.00 7402.11 7350.11 55 27 DEG MIN FEET DEG/IO0 FEET FEET FEET OEG MIN N 42 4 E 5102.66 N 42 19 E 5189.45 N w2 27 E 5276.63 N 42 44 E 5363.58 N 42 50 E 5450.26 N 43 12 E 5537.10 N 43 22 E 5624.36 N 43 27 E 5712.24 N 43 32 E 5800,37 0.26 0.58 0.71 0.67 0.28 0.53 1.25 0.35 1.39 N 43 41 E 5889.38 0.65 N 43 7 E 5978.66 N 42 56 E 6067.94 N 41 24 E 6155.71 N 39 43 E 6241.73 N 40 0 E 6325.83 N 40 46 f 6409.71 N 41 20 5 6494.25 N 41 38 E 6579.26 N 40 54 E 6663.85 N 40 32 E 6748.30 0.20 2.58 2.53 2.58 0.62 0.93 0.66 0.30 0.51 0.72 N 41 10 E 6833.33 N 41 53 E 6918.02 N 41 48 E 7001.97 N 41 44 E 7086.12 N 41 39 E 7170.30 N 41 31 E 7254,60 N 41 28 E 7338.68 N 41 16 E 7422,57 N 41 0 E 7506.25 . N 40 50 E 7589.73 1.42 2.21 0.48 0.58 0.26 0.53 0.31 0.39 0.18 0.16 N 40 29 E 7673,04 N 40 8 E 7756.16 N 39 49 E 7839.13 N 39 32 E 7922.00 N 39 22 E 8004,37 N 39 0 E 8086.45 N 38 42 E 8168.50 N 38 22 E 8250.73 N 38 1 E 8332.88 N 37 54 E 8415.06 0.54 0.40 0.37 0.52 0.27 0.38 0.32 0.80 0.20 0.45 3972.06 N 3206.63 E 5104.87 N 38 54 E 4036.41 N 3264.91 E 5191.55 N 38 58 E 4100.84 N 3323.71 E 5278.63 N 39 1 E 4164.85 N 3382.63 E 5365,46. N 39 4 E 4228.50 N 3441.56 E 5452.02 N 39 8 E 4292.07 N 3500.84 E 5538.75 N 39 12 ~ 4355.62 N 3560.78 E 5625.88 N 39 4419.53 N 3621.24 E 5713.64 N 39 19 4483.58 N 3681.96 E 5801.66 N 39 23 f 4548.03 N 3743.52 E 5890.55 N 39 27 E 4612,96 N 3804,97 E 5979,73 N 39 31 E 4678,11 N 3866,13 E 6068,91 N 39 34 E 4743.17 N 392.5,11 E 6156.64 N 39 36 E 4808.56 N 3981.01 E 6242.65 N 39 37 E 4873.31 N 4034.68 E6326.75 N 39 37 E 4937.19 N 4089.03 E 6410.62 N 39 37 E 5000.92 N 4144.59 E 6495.14 N 39 39 E 5064.58 N 4200.95 E 6580.11 N 39 40 E 5128.11 N 4256.82 E 6664.68 N 39 41 E 5192.16 N 4311.85 E 6749.12 N 39 42 E 5256.59 N 4367.33 E 6834.13 N 39 43 E 5319.88 N 4423.62 E 6918.79 N 39 44 E 5382.47 N 4479.62 E 7002.71 N 39 46 E 5445,24 N 4535,68 E 7086,82 N 39 47 E 5508.08 N 4591.72 E 7170.98 N 39 48 E 5571.17 N 4647.64 E 7255.24 N 39 50 5634.16 N 4703.35 E 7339.30 N 39 51 5697.11 N 4758,82 E 7423.17 N 39 52 5760.14 N 4813.86 E 7506.83 N 39 53 E 5823.22 N 4868.55 E 7590.30 N 39 53 E 5886.40 N 4922.86 E 7673.61 N 39 54 E 5949.75 N 4976.67 E 7756.72 N 39 54 E 6013.34 N 5029.9? E 7839.69 N 39 54 E 6077.14 N 5082.88 E 7922.58 N 39 54 E 6140.76 N 5135.21 E 8004.96 N 39 54 E 6204.36 N 5187.14 E 8087.05 N 39 53 E 6Z68.29 N 5238.63 E 8169.13 N 39 53 E 6332.63 N 5289.93 E 8251.40 N 39 52 E 6397.25 N 5340.76 E 8333,58 N 39 51 E 6462.13 N 5391.35 E 8415.80 N 39 50 E DEPTH DEPTH DEPTH DEG MIN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA CCURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATISN AZIMUTH SECTION SEV=RITY NORTH/SOUTM EAST/WEST DIST. AZIMUTH ARCO &LASKA., INC. LGI-iO PRUDHD5 BAY/LISBURNE PDCL NORTH SLOPE,ALASKA COMPUTATION DATE: I3-AUG-86 PAGE DATE OF SURVEY= 03-AUG-86 KELLY BUSHING ELEVATIDN: ENGINEER: SALAZAR 52.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR CDDROINATES.HDRIZ, DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG MIN 12000.00 7458.31 7406.31 56 11 12100.00 7513.56 7461.56 56 42 12200.00 7568.16 7516.16 57 7 12300.00 7622.58 7570.58 56 28 12400.00 7678.74 7626.74 55 27 12500.00 7735.84 7683.84 54 41 12600.00 7794.33 7742.33 53 50 12700.00 7853.71 78G1.71 53 9 12800.00 7914.65 7862.65 51 46 12900.00 7977.2b 7925.26 50 41 DEG MIN FEET N 37 46 E 849'7.68 N 37 36 E 8580.91 N 37 27 E 8664,57 N 37 41 E 8748.35 N 38 0 E 8831.00 N 38 23 E 8913.01 N 38 50 E 8994.08 N 39 15 E 9074.50 N 39 51 E 9153.78 N 40 20 6 9231,75 N 40 36 E 9308.71 N 40 15 E 9385.04 N 40 2 E 94S1.12 N 39 51 E 9537.00 N 39 30 E 9612.72 N 39 21 E 9688.28 N 40 8 E 9762.55 N 40 46 E 9834.65 N 41 39 E 9905.00 N 41 36 E 9973.81 N 41 30 ~ 10041.24 N 41 37 E 10107,09 N 41 29 E 10171.75 N 41 29 E 10182.09 DEG/IO0 FEET FEET FEET DEG MIN 0.66 0.49 0.44 1.44 0.49 1.38 0.79 1.59 1.39 1.21 0.83 0.33 0.73 1.20 1.06 2.58 2,54 0.88 1.37 1.11 0.64 2.47 0,00 0,00 6527.43 N 5442.12 E 8498.47 N 39 49 E 6593.38 N 5493.08 E 8581.75 N 39 47 E 6659,83 N 5544.09 E 8665,47 N 39 46 E 6726,36 N 5595,22 E 8749,30 N 39 45 E 6791,69 N 5645,99 E 8832.00 N 39 44 E 6856.21 N 5696.73 E 8914,05 N 39 43 % 6919.60 N 5747,35 E 8995,16 N 39 42 6982,10 N 5798,01 E 9075.61 N 39 42 7043,25 N 5848,48 E 9154,90 N 39 42 ~ 7102.88 N 589a,72 E 9232.86 N 39 42 E 7161.35 N 5948.76 E 9309.82 N 39 42 E 7219.43 N 5998.28 E 9386.14 N 39 43 E 7277,61 N 6047,31 E 9462.22 N 39 43 E 7335 80 N 6096 03 E 9538 11 N 39 43 : 7394,12 N 6144.33 E 9613.84 N 39 43 = 745.2,56 N 6192,26 E 9689,42 N 39 43 E 7509,70 N 6239,73 E 9763,70 N 39 43 E 7564,43' N 6286,67 E 9835.79 N 39 43 E 7617,30 N 6333.06 E 9906.11 N 39 44 E 7668,75 N 6378,79 E 9974,90 N 39 45 E 7719.24 N 5423.49 6100e2.31 N 39 45 E 7768.59 N 6467.10 E10108.14 N 39 46 E 7817.02 N 6509.96 610172o77 N 39 47 E 7824.77 N 6516.81 610183.11 N 39 47 E 13000.00 8041.11 7989.11 50 1 13100.00 8105.71 8053.71 49 39 13200.00 8170.61 8118..61 49 20 13300.00 8235.72 8183.72 49 13 13400.00 8301.04 8249.04 49 7 13500.00 8366.51 8314.51 48 44 13600.00 8433.46 8381.46 47 7 13700.00 8502.75 8450.75 45 23 13800.00 8573.82 8521.82 44 7 13900.00 8646.36 8594.36 42 55 lWO00.O0 8720.20 8668.20 41 47 1~100.00 8795.44 37~3.44 40 31 14200.00 8871.72 6819.72 40 16 14216.00 8883.93 8831.93 40 16 ARCO ALASKA, INC, LGI-iO PRUDHOE BAY/LIS~URNE POOL NORTH SLOPEtALASKA COMPUTATION DATE: 13-AUG-86 PAGE DATE OF SURVEY: 03-AUG-86 KELLY BUSHING ELEVATION: ENGINEER: SALAZAR iNTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -52.00 0 0 1000.00 999.54 947.54 5 5 2000.00 1967.51 1915.61 25 3000.00 2749.02 2697.02 54 1 4000.00 3255.07 3203.07 60 9 5000.00 3744.79 3692.79 57 59 6000.00 4291.53 4239.53 57 37 7000.00 4841.28 4789.28 57 59 8000.00 5352.30 5300.30 50 6 9000.00 5832.71 5780.71 63 31 10000.00 5350.44 0298.44 5~ 8 11000.00 6893.27 6841.27 56 22 12000.00 7458.31 7406.31 13000.00 80~1.11 7989.11 50 1 14000.00 8720.20 8668.20 41 47 14216.00 8883.93 8831.93 40 16 52. O0 ET VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUT~ FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 N 39 44 E 14.71 N 32 8 E 244.47 N 31 51 E 846.80 h 37 17 ~ 1703.24 N 41 14 E 2574.53 N. 45 54 E 3410.85 N 38 13 ~ 4243.56 N 42 4 E ~102.66 N 43 7 E 5978.66 N 41 10 E 6833.33 N 40 29 E 7673.04 N 37 46 E 8497.68 N 40 36 E 9308.71 N 41 30 E 10041.24 N 41 29 E 10182.09 0.00 1.66 4.07 4.29 0.29 0.92 0.50 0.65 0.26 0.20 1.42 0.54 0.66 0.83 0.64 0.00 0.00 N 0.00 E 0.00 N 0 0 = 8.78 N 12.36 E 15.16 N 54 38 ~ 200.78 N 141.41 E 245.58 N 35 '9 E 712,84 N 469.53 E 853,58 N 33 22 E 1424.95 N 954.74 E 1715.22 N 33 49 E 2091.68 N 1515.69 E 2583.11 N 35 55 -~, 2707,84 N 2081.93 E 3415.67 N 37 3~ 3307,34 N 2662.05 E 4245.59 N 38 49 3972.06 N 3206.63 E 5104.87 N 38 54 ~. 4612.96 N 3804.97 E 5979.73 N 39 31 E 5256.59 N 4367.33 E 6834.13 N 39 43 E 5886.40 N 4922.86 E 7673.61 N 39 54 E 6527.43 N 5442.12 E 8498.47 N 39 49 E 7161.35 N 5948.76 E 9309.82 N 39 42 5 7719.24 N 6423.49 510042.31 N 39 45 E 7824.77 N 6516.81 E10183.11 N 39 47 ~ COMPUTATION DATE: 13-AUG-86 PAGE ARCO ALASKA, INC. DATE OF SURVEY: 03-AUG-86 LGI-iO PRUDHOm 8AY/LIS6URNE POOL NORTm SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: SALAZAR INTERPOLATED VALUES FOR EVEN 100 F~ET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURE3 VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -52.00 0 0 N 0 0 E 152.00 152.00 100.00 0 4 S 50 25 E 252.00 252.~0 200.00 0 20 S 7 11 W 352.00 352.00 300.00 0 17 S 53 52 E 452.00 452.00 400.00 0 11 N 78 51 E 552.01 552.00 500.00 0 24 S 23 16 E 652.01 652.00 500.00 0 25 S 63 38 E 752.03 752.00 700.00 I 47 N 50 22 E 852.09 852.00 800.00 2 26 N 45 27 E 952.29 952.00 900.00 4 29 N 40 34 E 1052.70 1052.00 1OO0.O0 5 53 1153.36 1152.00 1100.00 7 18 1254.39 1252.00 1200.00 8 59 1355.80 1352.00 1300.00 10 15 1457.74 1452.00 1400.00 11 58 1560.27 1552.00 1500.00 13 38 1663.69 1652.00 1600.00 15 53 1768.28 1752.00 1700.00 18 9 1874.31 1852.00 1800.00 20 51 1982.72 1952.00 1900.00 24 42 N 38 39 E N 36 28 E N 34 39 E N 34 24 E N 34 42 E N 33 28 E N 30 52 E N 30 54 E N 35 46 E h 32 58 E 52,00 FT 2094.45 2052.00 2000.00 27 43 2208.35 2152.00 2100.00 29 26 2325.07 2252.00 2200.00 32 47 2446.45 2352.00 2300.00 36 4 2572.66 2452.00 2400.00 39 21 2705.30 2552.00 2500.00 42 34 2846.50 2652.00 2500.00 47 3005.11 2752.00 2700.00 54 14 3194.63 2852.00 2800.00 61 0 3400.56 2952.00 2900.00 60 6 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E 0.17 0.61 0.11 S 0.39 E -0.11 0.62 0.39 S 0.28 E -0.33 0.25 0.90 S 0.55 E -0.15 0.59 1.02 S 0.96 f -0.28 0.33 1.33 S 1.12 E -0.36 0.47 1.88 S 1.63 E 1.06 1.00 1.21 S 3.04 E 4.47 2.48 1.13 N 5.56 E 10.75 1.09 5.74 N ~9.81E 3598.49 3052.00 3000.00 59 25 3793.63 3152.00 3100.00 59 26 3993.83 3252.00 3200.00 60 9 4196.10 3352.00 3300.00 60 58 4405.07 3452.00 3400.00 61 50 4620.2~ 3552.00 3500.00 61 39 4823.25 3652.00 3600.00 58 50 5013.59 3752.00 3700.00 57 54 5200.49 3852.00 3800.00 57 33 5384.13 3952.00 3900.00 56 14 19.77 1.40 12.69 N 31.29 1.50 2'1.83 N 45.56 1.25 33.49 N 62.29 2.13 47.38 N 81.93 1.51 63.61 N 104.44 1.91 82.32 N 130.49 2.21 104.65 N 160.62 2.32 131.03 N 195.50 3.71 237.15 4.60 N 30 37 E 285.22 N 34 7 E 340.20 N 32 41 E 399.88 N 35 1 E 468.09 N 33 49 E 544.71 N 31 53 E 630.96 N 31 39 E 729.36 N 31 51 E 850.90 N 32 5 E 1009.90 N 33 20 E 1188.20 h 34 46 E 1357.89 N 36 20 E 1524.83 N 37 16 E 1697.90 N 38 46 E 1873.52 N 40 5 E 2056.97 N 41 9 E 2247.48 N 41 7 E 2424.11 N 41 5 E 2586.05 N 40 49 E 2743.94 N 41 47 ~ 2897.96 O. O0 N 0 0 E 0.41 S 74 37 E 0.48 S 35 44 E 1.06 S 31 23 E 1.40 S 43 1 ? E 1.73 S 40 5 12.49 S 41 3.27 s 68 19 5.67 N 78 30 11.37 N 59 39 E 15.57 E 20.09 N 50 48 E 22.61 E 31.43 N 46 0 E 30.93 E 45.59 N 42 43 E 40.45 E 62.29 N 40 29 E 51.68 E 81.96 N 39 5 ,E 64.45 E 104.55 N 38 3 E 78.42 E 130.77 N 36 53 E 93.93 E 161.22 N 35 38 E 160.55, N 113.10 E 196.38 N 35 9 E 194.48 N 137.51 E 23~.18 N 35 15 E 1.94 1.67 2.56 3.07 3.56 2.50 3.98 4.28 1.27 1.02 237.23 N 163.05 E 287.85 N 34 30 283.13 N 192.43 E 342.33 N 34 12 E 333.35 N 225.54 E 402.48 N 34 4 E 390.78 N 263.35 E 471.23 N 33 58 E 453.60 N 307.80 E 548.17 N 34 9 E 527.03 N 354.66 E 635.25 N 33 56 611.80 N 406.96 E 734.79 N 33 37 716.36 N 471.72 E 857.73 N 33 21 852.82 N 556.85 E 1018.52 N 33 8 1004.33 N' 654.06 E 1198.53 N 33 4 E 0.68 1.24 0.29 0.90 0.45 1.33 1.42 1.15 0.34 1.25 1145.85 N 749.69 E 1369.31 N 33 11 E 1282.01 N 847.34 E 1536.73 N 33 27 E 1420.70 N 951.49 E 1709.89 N 33 48 E 1559.35 N 1059.58 E 1885.28 N 34 11 E 1700.84 N 1176.40 E 2068.04 N 34 40 E 1845.61 N 1300.24 E 2257.63 N 35 9 E 1978.77 N 1416.29 E 2433.39 N 35 35 E 2100.35 N 1523.28 E 2594.58 N 35 57 E 2220.13 N 1626.16 E 2751.97 N 36 13 E 2335.91 N 1727.74 E 2905.43 N 36 29 E ARCO ALASKA, INC. LGI-IO PRUDHOE 5AY/LISBURNE POOL NORTH SLOPE,ALASKA COMPUTATION DATE: 13-AUG-86 PAGE DATE OF SURVEY: 03-AUG-86 KELLY BUSHING ELEVATION: ENGINEER: SALAZAR INTERPOLATEO VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE Sd3-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 5562.98 4052.00 4000.00 55 41 5741.02 4152.00 4100.00 56 44 5926.01 425'2.00 ~200.00 57 44 6112.94 4352.00 4300.00 57 28 5295.28 4452.00 4400.00 57 0 6476.25 4552.00 4500,00 56 33 6655.77 4652.00 4600.00 56 13 6835.07 4752.00 4700.00 56 21 52, O0 F1 7020.26 4852.00 4800.00 58 8 N 38 13 = 4260.74 7212.60 4952.00 4900.00 59 20 N 38 30 E 4424.9.0 0.89 1.06 0.46 0.84 0.91 0.26 1.25 2.46 0.77 0.51 2445,81 N 1827,27 E 3053,02 N 36 45 E 2553,78 N 1927,46 E 3199,51 N 37 2 E 2664.13 N 2037.19 E 3353.76 N 37 24 E 2773,91 N 2150,72 E 3510,01 N 37 47 E 2880.00 N 2260.21 E 3661.01 N 38 7 2985,36 N 2368,15 E 3810,57 N 38 25 3089.39 N 2474.93 E 3958.49 N 38 41 3199.03 N 2575.49 E 4106,94 N 38 50 ' 3320.84 N 2672.69 E 4262.78 N 38 49 3449,79 N 2774.51 E 4427,07 N 3.8 48 E 7408,90 5052,00 5000,00 58 36 7600,97 5152.00 5100.00 59 29 7800,30 5252,00 5200,00 59 47 7999.40 5352,00 5300.00 60 6 8202,43 5452,00 5400,00 50 48 8404,25 5552,00 5500,00 60 9 8608.32 5652.00 5600.00 61 17 8820,51 5752.00 5700,00 62 46 9043.31 5852,00 5800,00. 63 30 9252,95 5952,00 5900,00 59 1~ N 38 27 E 4593,72 N 39 9 E 4757,60 N 40 11 E 4930,01 N 42 4 E 5102,14 N 42 27 E 5278,76 N 42 51 E 5453.94 N 43 22 E 5631.65 N 43 37 E 5818,55. N 43 12 E 6017.40 N 40 26 E 6201.50 1,51 1,58 0,87 0,26 0.73 0,35 1,30 1,27 0,80 2,35 3581,85 N 2879,84 E 4595,99 N 38 47 E 3710,07 N 2982,06 E 4759,97 N 38 47 E 3842,25 N 30~2,77 E 4932.36 N 38 49 E 3971.67 N 3206.28 E 5104.35 N 38 54 E 4102,41 N 3325,14 E 5280,75 N 39 1 E 4231,20 N 3444,07 E 5455,70 N 39 8 E 4360.92 N 3565.79 E 5633.16 N 39 16 E 4496,78 N 3694,49 E 5819,82 N 39 24 E 4641,26 N 3831,47 E 601B,43 N 39 32 E 4777.76 N 3955.12 E 6202.41 N 39 37 E 9439.2'9 6052.00 6000,00 56 55 9625,92 6152,00 6100,00 58 9 9814.35 6252.00 6200.00 57 24 10002.94 6352.00 6300.00 58 7 10189.10 6452.00 6400.00 57 14 10374,25 6552.00 6500,00 57 25 10559,28 6652,00 6600,00 57 12 10743,60 6752,00 6700,00 56 49 10925.41 6852.00 6800.00 56 26 11105.60 6952.00 6900.00 56 6 N 40 18 E 6358.69 N 41 27 E 6516.27 N 40 48 E 6675.94 N 41 12 E 6835.82 N 41 48 E 6992.80 N 41 43 E 7148.59 N 41 28 E 7304,97 N 41 8 E 7459,08 N 40 46 E 7610.92 N 40 7 E 7760,81 1.09 0,39 0.41 1,36 0.48 0.46 0.28 0,45 0.42 0,34 4898,43 N 4055,87 E 6359,61 N 39 37 E 5017,44 N 4159,15 E 6517,15 N 39 39 E 5137,25 N 4264,72 E 6676,77 N 39 41 E 5258.47 N 4368.98 E 6836.63 N 39 43 E 5375.63 N 4473.50 E 6993.54 N 39 45 E 5491.87 N 4577,28 E 7149,27 N 39 48 ~ 5608,91 N 4681,02 E 7305,60 N 39 5C 5724,58 N 4782,88 E 7459,67 N 39 52 5839,25 N 4882,40 E 7611,49 N 39 54 ~ 5953.31 N 4979.67 E 7761.38 N 39 54 E 11284,56 7052,00 7000,00 55 55 11460,76 7152,00 7100,00 55 10 11636.01 7252.00 7200.00 55 22 11811.86 7352,00 7300,00 55 20 11988.64 7452.00 7400.00 56 7 12170.28 7552.00 7500.00 56 59 12352,70 7652.00 7600.00 55 46 12527.81 7752.00 7700,00 54 23 12697.14 7852,00 7800.00 53 11 12859,93 7952,00 7900.00 51 8 N 39 34 E 7909.21 N 39 11 E 8054.24 N 38 36 E 8198.10 N 38 0 E 8342,63 N 37 47 E 8488,25 N 37 28 E 8639,67 N 37 51 E 8792.01 N 38 29 E 8935.63 N 39 14 E 9072.21 N 40 9 E 9200.64 0.35 0.44 0.36 0.17 0.78 0.55 1.03 0.96 1.47 1.07 6067.28 N 5074.72 E 7909.79 N 39 54 E 6179.35 N 5166.82 E 8054.84 N 39 54 E 6291.42 N 5257,14 E 8198.75 N 39 52 E 6404.94 N 5346.77 E 8343.34 N 39 51 E 6519.96 N 5436.33 E 8489.03 N 39 49 E 6640.03 N 5528.93 E 8640.55 N 39 46 E 6760.92 N 5621.99 E 8792.99 N 39 44 E 6873,93 N 5710.81 E 8936,69 N 39 43 E 6980.32 N 5796.56 E 9073.31 N 39 42 E 7079.13 N 5878.62 E 9201.75 N 39 42 E N 42 17 E 3046,17 N 43 50 E 31~3,35 N 45 28 E 3348,55 N 46 14 E 3505.78 N 45 32 E 3657.59 N 46 10 E 3807.83 N 44 48 E 3956,31 N 39 55 E 4104.99 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN ARCO ALASKA, INc. LGI-IO PRUDMDE 8AY/LISEURNE POOL NORTH SLOPE~ALASKA COMPUTATION DATE: 13.-AUG-86 PAGE DATE DF SURVEY: 03-AUG-B6 KELLY BUSHING ELEVATION: ENGINEER: SALAZAR INTERPOLATED. VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SU6-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 13016.96 8052.00 8000.00 49 52 13171.40 8152.00 6100.00 49 27 13324.91 8252.00 8200.00 49 15 13477,88 8352.00 8300.00 49 3 13627.11 8452.00 8400.00 46 33 13769,50 8552°00 8500,00 44 28 13907,69 8652.00 8600.'00 42 51 14042.46 8752.00 8700.00 41 14 14174.15 8852.00 8800,00 40 16 14216.00 8883.93 8831.93 ~0 16 52,00 FT VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 7171.22 N 5957.23 E 9322.82 N 39 43 E 7260.99 N 6033.34 E 9440.51 N 39 43 E 7350.29 N 6108.10 E 9556.97 N 39 43 E 7439,64 N 6181.69 E 9672.72 N 39 43 E 7524°78 N 6252.51 E 9783.46 N 39 43 E 7601.38 N 6318.91 E 9884.81 N 39 44-~ 7672.66 N 6382.25 E 9980.13 N 39 4~ 7740.30 N 6442.14 510070.43 N 39 46 7804.50 N 6498.89 E10156.07 N 39 47 E 7824.77 N 6516.81 E10183.11 N 39 47 E N 40 34 E 9321.71 N 40 4 E 9439.40 N 39 43 E 9555.86 N 39 17 E 9571.59 N 40, 28 E 9782.32 N 41 31 E 9883.,69 N 41 35 E 9979.04 N 41 29 ~ 10069.37 N 41 29 E 10155.04 N 41 29 E 10182.09 1.10 0.63 0.49 0.76 2.39 1.20 0.96 0.84 0.00 0.00 ARCO ALASKA, INC. LGI-IO PRUDHOE BAY/LISBURNE POOL NORTH SLOPE,ALASKA MARKER TOP WAHOO'ZONE TOP WAHOO ZONE TOP WAN03 ZONE TOP WAHOO ZONE TOP WAHOO ZONE PBTD TOP WAHOO ZONE TD COMPUTATION DATE: 13-AUG-86 INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH B'ELOW KB FROM KB PAGE DATE OF SURVEY: 03-AUG-86 KELLY BUSHING ELEVATION: ENGINEER: SALAZAR 52,. O0 F1 SURFACE LOCATION AT ORIGIN= llZg' FNLs 1680' FELs SEC Is TllN, R14E~ TVD RECTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/NEST ABSENT/TRUNCATED 13664.00 8477.55 8425.55 7544.96 N 6269.87 E 13750,00 8538,11 8486.11 7591,12 N 6309,85 E 13876.00 8628.82 8576.82 7656.51 N 6367.90 F 14127.00 8816,03 8764.03 7781.67 N 64'78,69 L ~., 14170.0,0 8848.83 8796.83 7802.49 N 6497.11 E 14193.00 8866.38 8814.38 7813.63 N 6506.96 f 14216,00 8883.93 8831,93 7824,77 N 6516,81 E COMPUTATION OATE: 13-AUG-86 PAGE 10 ARCO ALASKA, INc. DATE OF SURVEY: 03-AUG-86 LGI-iO PRUDHOE BAY/LISBURNE POOL NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: SALAZAR 52~00 FT MARKER MEASURED DEPTH BELOW KB FROM KB SURFACE LOCATION AT ORIGIN: 1129' FNL, 1680' FEL, SEC 1~ TllN, R14E, TVD RECTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST TOP WAHOO ZONE TOP WAHOO ZONE TOP WAHOO ZONE TOP WAHOO ZONE TOP WAHOO ZONE PBTD TOP WAHOO ZONE TO ABSENT/TRUNCATED 13664.00 13750.00 13876.00 14127.00 14170.00 14193.00 14216.00 8477.55 8425.55 7544.96 N 6269.87 8538.11 8486.11 7591.12 N 6309.85 8628.82 8576.82 7656.51 N 6367.90 8816.03 8764.03 7781.67 N 6478.69 8848.83 8796.83 7802.49 N 6497.11 8866.38 8814.38 7813.63 N 6506.96 8883.93 8831.93 7824.77 N 6516.81 FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 1~216.00 8883.93 8831.93 10183.11 N 39 47 E SCHLUMBERGER D I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL LO I - 10 FI ELD PRUDHOE BAY/L I SBURNE POOL COUNTRY USA RUN TWO DATE LOGGED 03 - AUG 86 REFERENCE O0007ISSO (1129' FNL, 1680' FEL, £C 1,TllN,R14E,UM) NORTH 1~000 REF 0000716~0 ~C~LE = 1/2000 IN/FT f' . ~, ~, ~ ~ , ~ , , . ~ ~, ~ , ~ . . ,, ~, ~ , -'~.-~"~ ...... *"-'~ .... .-'v...-.r.-,...~.~--~....~...~ ........ ~-~-.~...~ ...... +-~...~ ..... ~..~.~... ~-~+.,..~..?,-.~..+,-+...~....-,-~.~-~......,-?.~-+..+--, ..... +.~--~.+.-+..+..+.,+--,.,_+_~....m~ ...... ~ ....... ~_~...~._....;...~_~...~.._L,...~ ....... ~...~ ....................... ~ .++++- .++.H ...... ..... ...H-u- .+~-.~ -+-4.~+....+~::L ~b+.~ .4.-~......+.+.+.; ...... ,-+.~4-.. --;-.~-.4.-.;--- ~ ~ ~ J- -J-~;-; - ~ ~-~ ~-4- i- i- t ~ t 'i-~"'~ ..... ?"F't ..... 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"¥"T'"T"'t ...... ?"t"?'"~ ..... t"r"r"~-'~"+"?'+-?'-~'"~'"~"-'-~-~ ~'~'"~-'~..- ..~--~---~..-~'..-~---~-~.-.~ ..... ~..-~---~-.-~.-. t---~---~ ..~---~ .... ~..4..-%..L +..~..~..]~].~] ~]]~]~]]~]]~]]]~]~ .......r.+..~ ....... ~...~...~ ........ ~,.~...~..4...~..-.~-4-~...~ ....... ~-4-4..4.....4-~ ~ ~.4 ? ~ ~ ~ ~ ~ ~ ~ ~ .~ ~: ~ L ~.~...J ..~ LL... ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . , ~,~ .... ,, ~ ~ ,,: .......... ~ ~.~ ~ , ~T-',,'T"T''~ ........... T'"?'-~"T"T'"T"~"'T .......... T"T"~"'T'"T'"~'"T"T--' 40, --I -q t PROJECTION ON VERTICRL PLANE 40. - 220. SCI:LED IN VERTICAL OEPTHS HORIZ SCALE = 1/2000 IN/FT RECEIVED Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR,' WELL NAME AND NUMBER Reports and Materials to be received by:,, tt ,- / Date Required Date Received Remarks Completion Report , , w~ ~o~ , Samples Core Chips .... Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports .~~ ~~I~/~ ~=o~t~o~ ~ ~o=t~ ~o~ ~u~ 7~ ~- o ~-., z~ ~K .... Digitized Data STRATIGRAPHIC HIGH RE'SOLUTION DIP METER LOCATED IN THE APPENDIX LISBUP. NE ENGINEERING Date: 11-3-86 From: Pam Lambert Enclosed are the following: LGI 10 Stratigraphic High-Resolution Dipmeter MSD Computations 7-24-86 Run 1 Sch LGI 10 Stratigraghic High Resolution Dipmeter Run 1 7-24-86 Sch L3-12 Acoustic CBL 10-14-86 Run 1 5" DA Please sign and return to= Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STATE EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 089 STATE OF ALASKA ~'-,,~ ALASKA~ .;L AND GAS CONSERVATION COMMI, ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging r~ Perforate ~ Pull tubing Alter Casing [] Other ~ Complete 2. Name of Operator 5. ARCO Alaska~ Inc 3. Address 6. P. O. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 7. 1129' FNL, 1680' FEL, Sec. 1, T11N, R14E, UN At top of productive interval 8. 1136' FSL, 4590' FWL, Sec. 30, T12N, R15E, UM Datum elevation (DF or KB) RKB 52 ' Feet Unit or Property name Prudhoe Bay Unit/Lisburne Well number LGI-IO Approval number 327 At effective depth 9. APl number 1393' FSL, 4817' FWL, Sec. 30, T12N, R15E, UM 50-- 029-21573 At total depth 10. Pool 1416' FSL, 4837' FWL, Sec. 30, T12N, R15E, UM Lisburne 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 5330' 1 421 6 'MD feet Plugs (measured) None feet 8884 ' TVD I 41 70 'MD 8849 ' TVD Size 20" 1 3-3/8" feet Junk (measured) feet N o n e Producti on 1 3546 ' Liner 852 ' Perforation depth: meaSured true vertical 9-5/8" 7" Cemented Measured depth 1800# Poleset 120'MD 2400 sx AS III & 5367 'MD 600 sx Class G Top job w/130 sx Class G 940 sx Class G 13582'MD 300 sx Class G 13662' - 13738'MD 13748' - 13868'MD 8476' - 8530'TVD 8537' - 8623'TVD Tubing (size, grade and measured depth) 5-1/2", L-80, tbg w/tail @ 13428' Packers and SSSV (type and measured depth) 2B pkr @ 13335~ (WLM) & SSSV ~ 2175' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure True Vertical depth I 20 ' TVD 3943 'TVD 8421 'TVD 13364'-14216'MD 8278'-8849 RECEIVED OCT 1 !986 13. Representative Daily Average Production or Injection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Well History, w/Addendum, dated 8/06/86) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ Gyro 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 ~/ Associate Engineer Date /~9'~'~(., (DA,H) s',':O/I "'~;ubmit" in Duplicate 'TVD ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty. parish or borough IState Alaska North Slope Borough Alaska Field ILease or Unit IWell no. Prudhoe Bay ADL ~34628 LGI-I0 Tiffs Completion Auth. or W.O. no. ~FE AL0281 Nabors 1-ES AP1 50-029-21573 Operator IARCO W.I. ARCO Alaska, Inc. 50% Spudded or W.O. begun [Oate IHour [Prior status if s W.O. Complete 10/14/86 1500 Hrs. Date and depth as of 8:00 a.m. 10/15/86 10/16/86 10/17/86 Complete record for each day reported 7" f/13,364'-14,216' 14,170', POH w/gage ring/JB 9.3 ppg NaC1 Brine Accept ri~ @ 1500 hfs, 10/14/86. ND tree, NU & tat BOPE to 5000 psi. Pull tbs hgt. RU DA, rn 8.35'" gage ring/JB/CCL to 13,376' W~M, POOR w/~L. 7" f/13,364'-14,216' 14,170', Displ tbg to diesel 9.9 ppg NaC1 Brine POOR w/gage ring/JB. Tst csg to 3000 psi; OK. TIH.w/9-5/8" pkr, set @ 13,335' ~LH, POOR, RD DA. RU & rn 322 its, 5½", 17# AB Hod tbg, space out &lnd. Tst tbg to 2000 psi. RU & displ 5½" tbg to diesel. 7" f/13,364'-14,216' 14,170', Wrk stuck gun 9.4 ppg NaC1 Brine/6.9 ppg diesel in tbg Sting into pkr/seal assy, lnd tbg hgt. Press 9-5/8" x 5-1/2" ann to 2500 psi; lost 100 psi. Tst tbg to 3800 psi; O[. ND BOPE, NU & tst tree. RD DA, RIR, per£ £/13,844'-13,870' (LDT/CNL) [13,842'-13,868' CBT], POOR, stuck gun in DB nipple. Att to wrk thru w/o success. Pull out of rope socket, RD DA. RU Camco. (Ran 322 its, 5½", 17#, L-80 AB Mod tbg w/SSSV @ 2175', Pkr @ 13,335' ~LM, TT @ 13,428', DB Nipple @ 13,388') The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JDate 10/23/86 1TM Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for-an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish I State Alaska North Slope Borough ] Alaska Field Lease or Unit Well no. Prudhoe Bay ADL //34628 LGI-I0 Auth. or W.O. no. Tit e AFE AL0281 Completion . Operator Nabors 1-ES ARCO Alaska, Inc. Spudded or W.O. begun Complete 0400 Hrs. Date and depth as of 8:00 a.m. Old TD Released rig 10/18/86 Classifications (oil, gas, etc.) Oil AP1 50-029-21573 IA.R.Co. W.I. Fotal number of wells (active or inactive' on this] ~ost center prior to plugging and 50~ ~bandonment of this well 10/14/86 ] 1500 Hrs. Complete record for each day reported 7" f/13,364'-14,216' 14,170','RR 9.4 ppg NaCl Brine in ann/6.9 ppg diesel in tbs Knock 4" gun loose f/DB nipple, chase to btm (TOF @ 14,132' SLM), POOH, RD Camco. RU DA, fin perf'g w/3-3/8" gun, 6 SPF, f/13842'-13,748' & 13,738'-13,662', RD DA. Set BPV. RR @ 0400 hfs, 10/18/86. New TD Date RECEIVED OCT ! 1986 Alaska Oil & gas Cons. Comm~ Anchorat~ 10/18/86 PB Depth 14,170' Kind of rig IType completion (single, dual, etc.) Single Official reservoir name(s) Lisburne Rotary Producing method Flowing Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % iGOR Gravity Allowable Effective date corrected The above is correct Date [Title 10123186 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drillin~ Superviso: ADDENDUM WELL: 8/03/86 LGI-IO Rn CET f/11,200'-14,173'. Rn gyro f/14,173'-surf. RECEIVED OCT ~ 1 1986 Alaska 0}{ & Gas Cons. ~,ummission Anchorage Drilling Supervisor Date ~ IAI I~ UP AI.R~I~A A~ OIL AND GAS CONSERVATION COM~I~ION APPLIC . ION FOR SUNDRY A PROVALS 1. ly~ of Request: ~n~n ~ Su,~nd ~ ~r,tlon 8hu~n ~ ~ter ,u,,~ well ~ Alter c,lng ~ / T Ttme ~ten8ion ~ Ch~n~ ~p~ pr~mm ~ Plugging ~ StlmulltK~ ~11 ruing ~ A~M ~er ~ ~rfomte ~ 2. O'r,to, ...... (DF or KB) ~ ~~ INC. f~t i 3. Address P.O.B. ~3~, ~NCHOR~E, ~. ~2e ~~o~~bur~ '4. ~ation of well at surface ' 7. Well number ~~ F~ 2~e~ FEL~ Sec. ~ T~N~ R2~~ At top of productive intewal 8. ~rmlt number 11~' F~, 1~' F~, ~c. 3e, TI~, Rl~,~(app.) ~9 At effective depth 9. APl number 1~19' FSL, 8~' FWL, Sec. 3~, TIB, RI~, ~(app. ) 50, ~9-~1573 At total depth 10. ~1 1~' FSL, ~5~' ~, S~. 3~, T1B, Rl~,~(app.) LI~BURNE OIL PO~ 1~. Present well condition summa~ Total depth: measured 14~1~' feet PluQs (measured) true ve~lcal ~9' feet Effective depth: measured 141~B' feet Junk (measured) true ve~ical ~9' feet CasinQ ~nQth Size Cement~ Measured depth True Ve~ical depth Conductor ~' ~" 18~ SX pOLE~T I~B' 1~' Surface ~38' 13-3/8" ~ sx AS I I I & 5367' 396~' ~ ~ ;x class 6; ~op 3ob m/13~ sx class 135~6~ ~5/8' 9~ sx class ~ 1358~~ Production Liner 8~~ 7" ~ sx class G 1336~-1~16~ 83~-8859~ ~rforation depth: measured ~ CURRENTLY BEI~ ~M~ k ~ ~ E true ve~ical OCT 2 0 198G Tubing (size, grade and measured depth) WELL ~R~~Y ~I~ CDMPL~~ 011 & ~a; Anch0Ka~e Packers and SSSV (type and measured depth) Packers = WELL CUR~NTLY BE IN6 COMPLETED ~= WFLL EURRFNTLY REIN~ 12.Attachments Description summa~ of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation ~TOBER 15~ 14. If proposal was verbally approved Name of approver L. SHITH Date approved 15. I hereby ce.ify~ the foregoin~is true an~.cp[re.ct to the best of ~y knowled~fi'~ ~. Signed ~~ . ___[1 _)~~_ L[SBUR~ OPER. COORD. Date 1~/1~/8~ . . . .... Commission Use Only Conditions of approval Notify commission so representative may witness · I Approval No. ~~ ~ Plug integrity *~ BOP Test~P~'D,~urn~atipn~v~d- ~'/clearancel~, ~ ~~~' / Approved by -/ .~. ~~~ ~mmissioner the commission Date Fo~m 10-403 Rev 12-1~ ' ~ / ~ ~ Submit i~ triplicate I]~tobee 16, 1986 t~TTACHIqENT I MELL LGI-10 ARCO Alaska, Inc. proposes to stimulate Lisbur~e well L81-10 ~ith: 10 bbls of diesel ~ith 18~ mutual solvent 198 bbls of 15% HC1 a~d additives 388 bbls of diesel The fluids will be pumped through tubing a~d the ~ell ~ill be flowed back to a test facility to re~over the load. A multi-rate deliverability test ~ill then be conducted on the well. Lisburne Engineering To: State of Ak John Boyle F rom: Pam Lambert Date: 9-5-86 Transmitted herewith are the following: OH Finals for LGI 10 ELL/SGR 7-23-86 Run 1 2"&5" Sch PT 7-23-86 Run 1 2"&5" Sch ~Natural GR Spectroscopy 7-23-86 Run 1 2"&5" Sch ~LDT/CNL (Raw) 7-23-86 Run 1 2"&5" Sch ~LDT/CNL (Poro)'7-23-86 Run 1 2"&5" Sch "-Formation Micro Scanner Monitor 7-24-86 Run 1 Sch ~Cybercore 7-24-86 Run 1 Sch '"'-Cyberlook 7-24-86 Run 1 Sch ~- CET 7-24-86 Run 1 Sch ~--Neutron-GR thru Casing 7-23-86 Run 1 2"&5' Sch ~~ RecUrn ReceiPt. to: ARCo Alaska Pam Lambert ATO 477 PO Box 100360 Anchorage, Alaska 99510 Transmittal No: O5~ ARCO Alaska [nc. Lisburne En$ineerin$ State of Ak From: ,, John Boyle Pam Lambert Date: 8-29-86 Transmitted herewith are the following: Magnetic Tapes for Lisburne Well LGI 10 Unshifted 7-23-86 Run 1 Tape Number 71614 Sch~O S~.hifted 7-23-86 Run 1 Tape Number 71614 ~ ~ ~ Alaska o. ~ u,~ ouns. L;ommLB~lo~ Return/R'~ceip~ to.~z~CO Ala~ Inc. An~orage Anchorage, Alas~ 99510 Transmittal No To .. State of Ak John Boyle Lisburne gngineerln$ ~-~ F~om: Da=e: Para Lambert 8-21-86 Transmit=ed herewith are =he following: GCT Directional Survey for LGI 10 8-3-86 Sch Receipt Acknowledgement: Return Receipt =o: ARCO Alaska Inc. Pam Lambert ATO 477 PO Box 100360 Anchorage, Alaska 99510 Trans.ittal NO: O~ // AUG 2 ~:.~ r~!iJaska Oil & L~as L;u~. Anchorage , ,-T"~ STATE OF ALASKA ALA~,A OIL AND GAS CONSERVATION CON,...'SsIoN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ~ Operation ShutdownZ'Z~ Re-enter suspended well ~ Alter casing ~ Time extension ~ Change approved program ~ Plugging [] Stimulate ~_ Pull tubing ~ Amend order ~ m Perforate F£ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address p. '0. Box 100360 Anchorage, AK 99510 =,, 4. Location of well at surface 1129'FNL, 1680'FEL, $ec.1, TllN, R14E, UN At top of productive interval 1100~FSL, IO0~FEL, 5ec.30, T12N, R15E, UN (approx.) At effective depth 1419~FSL, 4830~FWL, Sec.30, T12N, R15E, UN (approx.) total epth At1446'~E, 4852'. FWL, Sec,30, T12N, R15E, UN (approx.) 5. Datum elevation (DF or KB) 52' RKB feet 6. Unit or Property name Prudhoe Bay Unit/Lisburne 7. Well number LGI-10 8. Permit number 86-69 9. APl number 50-- 029-21573 10. Pool Lisburne Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 14216'MD feet 8859 ' TVD feet 14170 'MD 8829' TVD feet feet Plugs (measured) None Junk (measured) None Casing Length Size Conductor 80' 20" Surface 5330' 13-3/8" Producti On 13546' 9-5/8" Li net 852 ' 7" Cemented Measured depth 1800# Pol eset 120' MD 2400 sx AS III & 5367~ND 600 sx Class G Top job w/130 sx Class G 940 sx Class G 13582'ND 300 sx Class G 13364'-14216'MD True Vertical depth 120'TVD 3960'TVD 8445'TVD 8302'-8859'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None None Packers and SSSV (type and measured depth) · 12.Attacl~ments Description summary of proposal [] Detailed operations program [] BOP sketch [] Well History 13. Estimated date for commencing operation February, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed &/~~,~~¢.JL~ Title Associate Engineer ~/' Commission Use Only (DAN) $A/092 Conditions of approval Notify commission so representative may witness [] Plug integrity Date ~-'7- ~_~ Approved by ]]JT S IIli ,, I Approval No. [] BOP Test ~ Location clearance ~ ~ 7 we . "~' .... ': by order of ~ . ~ ~ Commissioner the commission Date ~ '~~~ Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History- Initial Report- Daily Inetructiona: Prepare and submit the "Initial Report" on the first Wednesday after a welt is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District I State Alaska Alaska I County. parish or borough North Slope Borough Field I Lease or Unit Iwe, no. Prudhoe Bay I ADL #34628 I LGI-10 I Tit,e Drill Auth. or W,O. no, AFE AL0281 Rowan #41 API 50-029-21573 Operator ARCO W.I. ARCO Alaska· Inc. 50% -SpuddedorW.O. begUnspud IDate 7/01/86 IHOur 1430 Hrs. ProrstatusifaW.O. Date and depth as of 8:00 a.m. 7/02/86 7/03/86 7/04/86 7/05/86 7/06/86 Complete record for each day reported 20" @ 120' 878', (758'), DD Wt. 9.0+, PV 22, YP 60, PH 9.8, WL 12.4, Sol 5 Accept rig @ 1300 hrs, 7/1/86. NU diverter sys. S~ud well @ 1430 hfs, 7/1/86. Drl 17½" hole to 700', DD to 878'. 20" @ 120' 2133', (1255'), DD building angle @ 2133' Wt. 9.2, PV 30, YP 46, PH 9.0, WL 14, Sol 6.5 DD 17½" hole to 2133'. 700', Assumed vertical 844', 2.2°, N41.5E, 843 TVD, 2.76 VS, 2.07N, 1296', 9.2°, N33.8E, 1293 TVD, 51.38 VS, 40.49N, 1841' 1.83E 31.83E · 19.9°, N33.8E, 1820 TVD, 186.09 VS, 154.06N, 106.36E 20" @ 120' 3526', (1393'), Navi-Drl Wt. 9.4, PV 15, YP 45, PH 7.5, WL 22, Sol 8 DD & rotary drl to 3183', POOH, chg BHA, RIH & Navi-Drl 17½" hole to 3526'. 2025', 26.3°, N30.9E, 1989.17, 257.21 rS, 215.00N, 144.96E 2393', 34.0°, N32.0E, 2308.73, 437.58 rS, 367.58N, 244.00E 2832', 46.1°, N32.0E, 2643.30, 717.37 VS, 607.56N, 393.96E 3138', 58.9°, N32.4E, 2829.52, 956.76 VS, 812.62N, 522.51E 20" @ 120' 4987', (1461'), Drlg Wt. 9.5, PV 8, YP 48, PH 7.8, WL 22, Sol 8.5 Navi-drl 17½" hole to 4987'. 3410' 59.6° N31.1E, 2968, 1188.52 VS, 1009 22N, 648.96E , , · 4021', 59.8°, N36.9E, 3280, 1712.30 VS, 1438.16N, 952.13E 4483', 62.3°, N40.4E, 3504, 2116.21VS, 1750.93N, 1207.57E 13-3/8" @ 5367' 5369', (382'), Prep to cmt 13-3/8" Wt. 9.4, PV 7, YP 10, PH 8.5, WL 28, Sol 8.5 Drl & surv to 5369', 20 std short trip, C&C, POOH. RU & rn 132 its, 13-3/8", L-80, 72# BTC csg w/2 its, 68#, K-55 BTC csg w/FS @ 5367', FC @ 5285'. Prep to cmt. 4788', 59.6°, N41.1E, 3653, 2382.80 VS, 1952.90N, 1381.59E 5294', 57.2°, N40.SE, 3920, 2812.31VS, 2279.80N, 1660.24E The above is correct 8/05/86 J~tle Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all Drill stem tests 'sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerim" sheets when filled out but not less frequently than every 30 days, or (2} on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District ICounty or Parish State Alaska NOrth Slope Borough I Field ILease or Unit Prudhoe Bay ADL #34628 Alaska IWell no. LGI-10 Date and depth as of 8:00 a.m. 7/07/86 7/08/86 7~09/86 7/10/86 7/11/86 The above is correct Complete record for each day while drilling or workover in progress 13-3/8" @ 5367' 5369', (0'), RIH w/12¼" bit/BHA Wt. 8-.3 ppg gelled wtr Cmt 13-3/8" w/2400 sx AS III, followed by 600 sx C1 "G" w/2% CaCi~. Displ using rig pmps, bump plug; left 25 bbls cmt in 13-378". Pmp 130 sx C1 "G" top job. ND diverter. NU & tst BOPE. PU 12¼" BHA,& RIH. 13-3/8" @ 5367' 6611', (1242'), POOH Wt. 8.9, PV 4, YP 11, PH 12.0, WL 50, Sol 4.5 RIH, tag cmt @ 4966', drl cmt to 5285', circ & tst csg to 2500 psi. DO cmt & flt equip + 10' new hole. Conduct formation tst to 12.7 ppg EMW. Drl & surv 12¼" hole to 6611', POOH f/BHA chg. 5559', 55.5°, N43.3E, 4067, 3032.66 VS, 2443.58N, 1807.97E 6048', 57.7°, N46.4E, 4336, 3438.78 VS, 2732.96N, 2095.83E 6541', 56.5°, N47.1E, 4604, 3850.05 VS, 3016.57N, 2397.32E 13-3/8" @ 5367' 7749', (1138'), Chg BHA Wt. 9.1, PV 4, YP 16, PH 11.3, WL 22, Sol 6 Chg BHA, RIH, taking wt @ 6286'. Wsh & rm to 6611', DD to 7749', POOH, chg'g BHA to rotary assy. 6819', 56.3°, N40.4E, 4758, 4081.60 VS, 3183.74N, 2557.35E 7433', 57.7°, N38.0E, 5085, 4600.38 VS, 3588.69N, 2882.31E 7679', 59.9°, N40.4E, 5213, 4810.78 VS, 3751.73N, 3015.28E 13-3/8" @ 5367' 8725', (976'), RIH Wt. 9.1+, PV 8, YP 5, PH 10.2, WL 12, Sol 6 Chg BHA, RIH, drl & surv 12¼ hole to 8725' . 8169', 60.7°, N42.2E, 5455.60, 5236.24 VS, 4071.47N, 3296.19E 8665', 61.7°, N43.6E, 5694.55, 5670.29 VS, 4389.86N, 3592.05E 13-3/8" @ 5367' 9366', (641'), DD Wt. 9.1, PV 7, YP 5, PH 9.8, WL 11.4, Sol 6.5 DD & surv 12¼" hole to 9366'. 8973', 63.5°, N43.3E, 5836.28, 5943.42 VS, 4588.37N, 3780.10E 9380', 56.6°, N39.7E, 6039.35, 6295.81 VS, 4852.28N, 4013.59E Date [Title 8/05/86 Drilling Supervisor · For form DreDaration and distribution see Procedures Manual Section 10, DrilLing, Pages 86 and 87 ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District [County or Parish JState Alaska North Slope Borough Field ILeaae or Unit #34628 I Complete record for each day while drilling or workover in progress Prudhoe Bay Date and clepth as of 8:00 a.m. 7/12/86 7/13/86 Alaska IWell no. LGI-IO 13-3/8" @ 5367' 10,110', (744'), POOH f/bit chg Wt. 9.2, PV 9, YP 11, PH 8.8, WL 11.6, Sol 6.5 DD & surv 12¼" hole to 10,110'. 9,757', 57.5°, N40.SE, 6244.40, 6612.17 VS, 5093.73N, 4217.99E 10,006', 58.4°, N41.SE, 6376.54, 6823.17 VS, 5252.28N, 4357.28E 13-3/8" @ 5367' 10,954', (844'), Drlg Wt. 9.3, PV 8, YP 9, PH 8.3, WL 13, Sol 7 Drl & surv 12¼" hole to 10,954'. 10,482', 57.3°, N41.SE, 6629.83, 7226.08 VS, 5552.71N, 4625.89E 10,796', 56.7°, N41.1E, 6800.85, 7489.41VS, 5750.09N, 4800.21E 7/14/86 7115186 7/16/86 7/17/86 The above is correct 13-3/8" @ 5367' 11,391', (437'), RIH Wt. 9.5, PV 6, YP 5, PH 12.0, WL 10.2, Sol 8.5 Drl & surv 12¼" hole to 11,391', POOH, chg bit, RIH. 11,107', 56.1°, N40.4E, 6972.95, 7748.45 VS, 5946.33N, 4969.30E 11,326', 55.6°, N40.1E, 7095.89, 7929.68 VS, 6084.65N, 5086.40E 13-3/8" @ 5367' 12,145', (754'), Drlg Wt. 9.5, PV 9, YP 8, PH 11.9, WL 6.4, Sol 8.5 Wsh & rm f/11,330'-11,391', drl to 12,145'. 11,635', 55.2°, N38.TE, 7271.35, 8183.89 VS, 6281.19N, 5242.84E 11,949', 55.8°, N38.0E, 7449.20, 8442.40 VS, 6484.13N, 5408.40E 13-3/8" @ 5367' 12,528', (383'), Drlg Wt. 9.6+, PV 8, YP 5, PH 11.8, WL 6.4, Sol 9.5 Drl 12¼" hole to 12,528'. 13-3/8" @ 5367' 12,982', (454'), RIH Wt. 9.9, PV 12, YP 6, PH 11.6, WL 6,4, Sol 11 Drl to 12,982', circ gas cut mud, raise mud wt to 9.9 ppg, POOH, chg BHA, RIH. 12,537', 54.1°, N38.7E, 7780, 8927.84 VS, 6866.78N, 5707.75E 12,932', 50.2°, N41.1E, 8021, 9240.26 VS, 7107.21N, 5907.28E IDate 8/05/86 IT"'e For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 ARCO Oil and Gas COmpany Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is Set. Submit weekly for workovers and following setting of oil string until completion. Alaska DistriCt Field Prudhoe Bay Date and deptl~ 7/18/86 as of 8:00 a.m. 7/19/86 7/20/86 The above is correct r county or Parish IState North Slope Borough Alaska Lease ADL #34628 or Unit 7/21/86 7/22/86 For form preparation and distribution see Prooeclures Manual 3eotion 10, Drilling, Pages 86 and 87 Complete record for each day while drilling or workover in progress 13-3/8" @ 5367' 13,012', (30'), Att to rotate Wt. 10.1, PV 13, YP 9, PH 11.6, WL 5.0, Sol 12 RIH, drl 12¼" hole to 13,012',.circ gas cut mud (9.9 ppg in - 7.5 ppg out); hole packing off & losing 10 bbl/hr. Add nut plug & fine mica, POOH; bit OK. RIH, rm 12,365'-12,395'. Cunt RIH, rm 12,821'-13,000', circ & raise mud wt to 10.1 ppg; losing mud @ 10 bbl/hr. Treat w/nut plug & mica, att to drl; unable to rotate on btm. 13-3/8" @ 5367' 13,590', (578'), Short trip Wt. 10.1, PV 11, YP 8, PH 11.8, WL 6.4, Sol 13 Circ, pmp hi-wis pill, dri 12¼" hole to 13,570'. 13,086', 49.7°, N40.4E, 8121, 9358.15 VS, 7196.51N, 5984.23E 13,451', 49.0°, N39.4E, 8359, 9634.93 VS, 7408.56N, 6162.17E 13-3/8" @ 5367' 13,590', (0'), Rn'g 9-5/8" csg Wt. 10.1, PV 11, YP 9, PH 11.5, WL 6.4, Sol 13 25 std short trip, C&C, POOH. RU & begin rn'g 9-5/8" csg. 9-5/8" @ 13,582' 13,590', (0'), Circ & cut back mud wt 10.1 ppg Fin rn'g 341 its, 9-5/8", 47#, L-80 NS-CC csg & 5 its, 9-5/8", 47#, L-80 BTC csg w/FC @ 13,497', FS @ 13,582'. Cmt w/150 sx 50/50 Pozz w/8% D-20, .5% D-65, .5% D-112 & .2% D-46, followed by 790 sx C1 "G" w/1.5 gal/sx D-600, .05 gal/sx M-45, .06 gal/sx E-2009, .3% D-65 & .1% D-133. Displ using rig pmps, bump plug. Chg out spool, tst BOPE. RIH w/8½" BHA, tag FC, circ & cut mud wt to 9.3 ppg f/lO.1 ppg. 9-5/8" @ 13,582' 13,912', (322'), Drlg Wt. 9.2, PV 7, YP 9, PH 11.2, WL 8.8, Sol 8 Tst csg to 3000 psi. DO cmt & flt equip + 10' new hole. Conduct formation tst to 11.8 ppg EMW. Drl 8½" hole to 13,740', circ & spot nut plug pill for mud losses & cunt to drl to 13,912'. (Total fluid lost = 150 bbls - losing @ 7 - 9 BPH). IWell no. LGI-10 JDate 8/05/86 JTit,e ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations, If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District [County or Parish J State Field Alaska lEe,se orUnit North Slope Borough Prudhoe Bay Date and deptl~ as of 8:00 ,a.m. ADL #34628 Complete record for each day while drilling or workover in progress 7/23/86 7/24/86 7/25/86 9-5/8" @ 13,581' 14,216', (304'), C&C f/logs Wt. 9.2, PV 7, YP 10, PH 10.5, WL 11.8, So1 6 Drl 8½" hole to 14,216', short trip to 13,581', C&C, POOH f/logs. 9-5/8" @ 13,581' 14,216' TD, (0'), Logging w/CET Wt. 9.2+, PV 7, YP 6, PH 11.0, WL 8.6, Sol 6 RU Schl, rn DLL/SP/NGT/CAL, LDT/GR/CNL/EPT/CAL, FMS/GR/AMS, CET. 9-5/8" @ 13,581' 14,216', (0'), Prep to cmt 7" Wt. 9.2+, PV 7, YP 5, PH 11.4, WL 10.2, Sol 6 Fin rn'g CET f/13,581'-11,984', RD Schl. Make cond'g trip f/7". Chg rams, RU & rn 20 its, 7" on DP. The above is correct *'- ~-: - ' Alaska IWell no. LGI-10 IDate ITitle 8/05/86 For form preparation and distribution see Procedures Manual Section 10. Drilling Supervisor AtlanticRichfieldCompany Daily Well History-Final Report Instructions: Prepare and submit the "Final Report'' on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Spudded or W.O. begun Spud District lCounty or Parish Alaska I North Slope Borough Field ~Lease or Unit Prudhoe Bay I ADL #34628 Auth. or W.O. no. ITM AFE AL0281 I Drill Rowan #41 API 50-029-21573 ' cost center prior to plugging and I ARCO Alaska, Inc. 50% abandonment of this well I Date Hour Prior statue if a W,O. I 7/01/86 1430 Hrs. 7/26/86 thru 7/28/86 Date and depth as of 8:00 a.m. Complete record for each day reported 7" f/13,364'-14,216' 14,170' PBTD, RR 9.3 ppg NaC1 w/C-193 inhibitor .Cmt 7" w/320 sx 35/65% flyash C1 "G" w/2% D-20, .8% D-112, .4% D-65 & .2% D-46. Displ using rig pmps, bump pmps. Chg rams to 5" & tst. RIH w/8½" bit & 9-5/8" csg scrpr, tag cmt @ 13,260', rm & drl cmt to TOL @ 13,364', CBU, POH. RIH w/6" bit & 7" scrpr, drl cmt f/TOL to LC @ 14,054', tst csg to 3000 psi, CBU, rev circ 9.3 ppg filtered brine, POH, LD DP. ND BOPE, NU & tst tree to 5000 psi. Freeze protect annulus. RR @ 2400 hfs, 7/27/86. IAccounting cost center code State Alaska Well no. LGI-10 14,216' 14,170' Re~eased r|g Date K~nd of Hg 2400 Hrs. 7/27/86 Rotary Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Oil I Single Producing method I Official reservoir name(s) Flowing I Sadlerochit Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Date 8/05/86 ITM For form preparation and distribution, see Procedures Manual Section 10, Drilling, Pages 86 and 87, Drilling Supervisor Lisburne Engineering To: State of Ak From: John Boyl,e Date: Pam Lambert 8-19-86 Transmitted herewith are the following: Magnetic Tape for Lisburne Well LGI 10 GCT LIS 8-3-86 Run 2 Tape Number .Z/~50 Sch Receipt Acknowledgement: Return Receipt to: ARCO Alaska Inc. Pam Lambert ATO 477 PO Box 100360 Anchorage, Alaska 99510 Transmittal No: O/? Anohorag, MEMORAN .UM State-of Alaska ALASKA OIL A~J GAS CONSERVATION COMMISS.~N . FI LE NO.: D. BDF. 53 THRU: -Lonnie C. Smith ~~ TELEPHONE NO.: Commissioner FROM' Bobby D. Foster Petro !e,am Inspector SUBJECT: BOP Test ARCO PBU LGI ~10 Permit 86-69 Lisburne Oil Pool Monday~ July 7: 1986: The BOP test began at 1:30 a.m. and was ~nci~aed" ~ 3'.30'p~m. As the attached BOP test report shows, there were no failures. In s~ary, I witnessed the BOp test on ARCO's LGI ~10. 02-O01 A ( Rev 10-84) STATE OF ALASKA 'ALASKA OIL & C~5 CONSERVATION C'O~'~S$ION ~.0.P.£. Inspection Report Mud Svs:~s Visual Audio Trip Tank Pi: Gauge Flow Monitor Gas De:et:ors BOPE Stack I t : est Pressure Choke Line Valves Y~il! Line Valves Check V~Ive , Pressure After Closure /~O psig, Pump incr. clos. pres. 200 psig -- =in'sec. Full Charge Pressure Attained: ' 5 nih/~ sec. Controls: .Master ,~ S . , Remote~ ~ Blinds switch cover ?~_T Kelly and.rldor Safety Valves' . " Upper Kelly / Test Pressure ~ ~~ Lower Ke~y -/ Test Pressure ~~ ~a!l T)~e / Test Pressure ~~ inside BOP ~ Tes: Pressure ~~ ,, ~ 4 ~ Choke .~n..old W~Tes: Pressure ~~ ~o. Valve, /~ No. flanges ~ ~ , A~justab~a Chokes, / /' ~. , , ~v~rauiC~!2v o~er~te~ choke ] Test Resu!:s: ~ailuzes ~ Test Time ~ hrs. Repair or Replacement of failed equipmen~ to be ma~e ~:hin day~ and Inspector/ o o Co~./ssion office notified. " Rema~s: -- · , D.s ~_ ibu.ion -"- orig. - AO&GCC cc - Supem, isor March 21, 1986 Mr. T. P. Oostermeyer Regional Drilling. Engineer ARCO Alaska, Inc. P. O. Box 100360 ~nchorage, Alaska 99510-0360 -Telecopy= (907) 276-7542 Re: Prudhoe Bay Unit ~I-10 ARCO Alaska, Inc. Permit No. 86-69 Sur. Loc. l129'FNL, 1680'FEL, Sec. 1, TllN, R14E, UM. Btm_hole Loc. 1472'FSL, 217'FWL, Sec. 29, T12N, R15E, UM. Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. ~e permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies. Prior to commencing operations at the well Site, To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention eauiDment so that a representative of the Commission. may b~ ~es~nt to witness testing of the equipment before the surface p ~ .casing shoe is drilled. Where a diverter system is required, please also nOtify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C, V. Chatterton Chairman o f Alaska Oil and Gas Conservation Commission BY OPJ)ER OF THE COMMISSION dlf Enclosure cc: Depar~ent of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr'. Doug L. Lowery~ /'"", STATE OF ALASKA ~""h R E C E IV E D ALASKA oIL AND GAS CONSERVATION Ck.,,vlMISSION PERMIT TO DRILL MAR 1 9 1986 20 AAC 25.005 la. Type of work. DRILL j~]X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] S E R V I c~l~l~a 0i~T~ ~ ~;~,~ i~:missio~ SINGLE ZONE ~ Anchorage MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1129' FNL, 1680' FEL, Sec.1, TllN, R14E, UM At top of proposed producing interval At Target @ 8552'TVD:llOO'FSL, 100' FEL, Sec.30, T12N, R15E, UM At total depth 1472' FSL, 217' FWL, Sec.29, T12N, R15E, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 52', PAD 13' I APL 34628 ALK 863 12. Bond information (see 20 AAC 25.025) Federal I n surance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town I 14. Distance to nearest property or lease line 9-1/2 mi. N of Deadhorse 10 16. Proposed depth (MD & TVD) 14261 'MD, 8875 ' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 800 feet. 21 miles ' ~ 3014'TVD/3611 'MD&3736'TVD/4922'MD 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLEANGLE56.62° (see 20AAC25.035(c) (2) 9. Unit or lease name Prudhoe Bay Unit/Lisburne 10. Well number LGI -10 11. Field and pool Prudhoe Bay Field Lisburne 0il Pool Amount $500,000 15. Distance to nearest drilling or completed LG 1-12 47½ ' ~ 1211 'MD/1209 'TVDeet 18. Approximate spud date 6/11/86 3420 psig@_ 40°F Surface 4490 .psig@ 8952 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hoie I Casing Weight 3U" [ 20" 91.5# 17-1/2" [ 13-3/8" 68.0# 17-1/2"I 13-3/8" 72.0# 12-1/4" 9-5/8" 47.0# ~-3/2" 7" 29.0# 22. Describe proposed program: CASING AND LINER Grade Couplin~ Length H-40 Wel~ 80' ! K-55 BTCJ 70' i L-80 BTCI 5293' L-80 BTC/ 13474' L-SO BTCJ 1050'' MD 39' 39' 109' 37' 13211 ' SETTING DEPTH TOP TVD I 39' 39' I 109' I I 37' 8297 ' MD BOTTOM TVD 119' I 119' 109~ I 109' 5402' I 4000' 13511' I 8462' 14261' 8875' QUANTITY OF CEMENT (includes{agedata) 2000# Poleset 1955 sx AS III & 600 sx Class G Tail 780"G"/300AS I&ArcPack 300sx65%"G"-35%Poz ARCO Alaska, Inc., proposes to drill this Lisburne gas injection we'll to approximately 14,261 'MD (8875'TVD). is planned as a Lisburne gas injectiOn well in the Wahoo formation. It A surface diverter will be installed and operationally tested prior to spud. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 13-3/8" surface pipe. It will be tested to 5000 psi (3000 psi for annular) upon installation and weekly thereafter. We plan to set 9-5/8" casing just above the Wahoo and a 7" liner across the Wahoo production interval. Selected intervals will be logged.. A string of 5-1/2", 17.0#, L-80', EUE, 8rd AB-MOD tubing, including provisions for subsurface safety equipment, Will be run with the packer set above the Wahoo. Selected intervals in the Wahoo gas cap will be perforated and reported on subsequent reports. Perforated zones will be production tested prior to beginning gas injection. · 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~'~' ~ 4"" TITLE .egional Drilling Engr. DATE The spacebelowforCommission use ~/~_~--' ~' '~_ _-___~-'~: injection into weAA must .[kot occur until authorized by an orderissued' under 20AAC 25.402 or 20AAC 25.460 CONDITIONS OF APPROVAL Samples required Mud log required J-]YES ~O []YES ~ Permit number ~~1/~//q/[I~App rovaJ da te APPROVED BY a~:~J'~ //~ J\ ,COMMISSIONER DATE ~~~_~ by order of the Commission Form 10401 (JJG) PD/PD85 Submit in triplicate Directional Survey required ] APl number pC~.Es []NO 50- o-~-~-~ E7 ~ SEE COVER LETTER FOR OTHER REQUIREMENTS RECEIVED PERMIT TO DRILL LGI-IO (cont'd) Alaska 0:,1 & Gas Cons. Anchorage Non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus of this well prior to Arctic Pack operations (approx 130 bbls Arctic Pack on top of 300 sx Arctic Set I cement). That annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The maximum anticipated surface pressure of 3420 psig ~ 40°F was calculated from the Wahoo datum pressure of 4490 psig ~ 8952'TVD and 183°F. it assumes a 300' oil column to 8652'TVD and a gas column from there to surface, gas temperature and compressibility effects considered. A similar calculation, assuming a full gas column and original reservoir pressure in the Sadlerochit Sand @ 8052'TVD, yields a maximum surface pressure of 3348 psig @ 40~F. Such surface pressures could occur only if 9-5/8" casing had been set. With 13-3/8" casing set @ 4000'TVD, the maximum anticipated surface pressure is 2440 psig, based on a 13.7 ppg EMW pump-in gradient at the shoe and a gas column to surface. Our formation leak-off test history, for surface pipe set at similar depth, shows a 11.5 to 13.7 ppg EMW pump-in gradient just below the casing shoe. The closest well is LGI-12, 47-1/2' away at 1211'MD/1209'TVD, diverging away below that. LGI-8 is 60' away at the surface, diverging below 800'. 3000 4000 ,-~ 5000 6000 7000 8000 9000 10000 1000 2000 3000 4000 S000 6000 7000 8000 9000 10000 11000 12000 0 12.5 17.5 ALASKA, INC. 37.5 SH~ 112~' :N~ 1G80' ~L, ~2.5 . 47.5 SEC 1, s~.~ EOC TVD = 2714 ~ D = 306~ DEP = 1(~31 % m~ 1100 FSL, 100' FEL, . . . ~/ 3-3/R' ~IIRFACF TVD = 4~( ,~ MD = ~4~ DFP = ~R~ 9890 ~VERAGE J ,NGLE 56 DEG 37 MIN K-l, TVD = ~227 MD =, 11267 DE[P = 7879~ i~VD = 77;'7 MD = 12266 DEP = 8714 ~n~.~ ~.T~ / ~,, T.n ~ on~ f~,n ~ ~,~ nco ~ 8131 KAVIK T'/D -- 839 ~ MD -- 1~384 DEP -- 9647 9-5/8' CASING TVD = 8z 62 MD = 13511 DEl' = 9753~-. · ............................................................................................................ 0 1000 2000 3000 4000 5000 6000 7000 8000 900O lOOO 2000 3000 4000 5000 6000 7000 8000 9000 10000 10000 llO00 12000 f~'~ F. - N OOORO I NB?ES -~ o - ! 000 0 ! OOO ~ 2000 3000 zJO00 500U 6000 7000 8000 9000 ~HI: ll;n' ~= I 1RRn' SEC 1, Tl1~ R14E, UM - r'HL: 1100' $L, 100' FEL, SEC 30, T1 N, R15E, UM -1~5 TARGE ~ TVD '- 1552' Tun- DEP ' ~890' N 750~ ~,~.,~,,~ ] q ~0~~ Ancf )rage 0 0 - 1000 0 1000 2000 3000 4000 5000 6000 7000 8000 E - 14 COORDINII?ES 9000 E - N COORDINFtTRS 0o - 1000 0 ! 000 2000 3000 '~000 5000 6000 7000 8000 900 ,il,il,ii , , , , , I , , i , , , , , , , , , , , , , , , i , i , , , , i i , , , , , I , , , , , , , , , , , , , i , i , , i i i i i i , , , , , , , i , , i , , , , I , 'LG I - / LSI O ,,, ~ ' Anchorage , , , , , , , , , , , , , , , , , , , , , , , , , , , ,,,,,,,,,: ,,,,,,,,,: ,,,,,,,,,, ,,,,,,,,, , , , , , , , , , , , , ,,,, , , ,, , , , , , , , - ! 000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 E - N COOROINRTES -~oo -~oo . o ~oo ' ~.oo .~o0. · ~o°' soo 4 I. I .. i I ' . . I I . I I I I I I · i I · . '. ~ , , ' -, i . -. ? · 37~5 . · - "- '3714 36"~E · ' 3 bu~3~~5~8 3: ' ,~/1677 /' /2895 .,,"%onr:'' /' .~2F 1 4 / 12@6 ~~77 ~o~_~l~t ~-' ,,"2 1 8.9 96 ' ~K~P '/~r~' ,x '...~'.., I L.!..' '~ ~, crt"! o~ . , ',. . ,...~.~ i i i i i i i i i i i i i i i i i i i i i i i i i i i ° 3720 ~73 I ! ! i .c~ ! -200 - 1 O0 0 1 O0 200 300 '~00 500 W (I5o 0 0 E - N OOORDINPITES SURFACE HOLE D IVERTER SYSTEM SCHEMATIC ARCO ALASKA INC'. ~ IO" HYD. (]PR. BALL VALVE /~tf~LL BORE ISEE: DE 'lAIL! / /.~---IO" HYD. OPR. BALL VALVE ,,/ .//~ I ALL 90' 1URNS ARE "TEE" I I I I I I I I I I I I I I I I I I I I RESERVE PI! ARE A NOTE' FLORL lIVE ILL lNG R I SER 20" 2000 PSi ~P ,a~,,INULAR PREVENTOR Valves on diverter lines open automati- cally when the annular nreventer is closed. ILL lNG SPOOL :ONOUCT(~R PIPE I0' HYDRAULIC OPERATED BALL V/I~VES "DETAIL" ~ogoo I o~'o BL.~ND ~ ii /8" ~ ~ ~:Lq:;RAM 10. 12. 1~. 2. Check ~ ~i12 acc'.mA~a~ ~se~o~ ~o ~r leve2 ~ ~~c ~d. 1S00 ~ ~~ o~ ~ ~~OT. ~ ~ ~ C~ ~~SS~ ~ ~e~ ~. ~i~ ~esx ~s. · S. -~ e~ o~ ~ ~1~ ~, ~ir~ ~ld a · es~ a~ ~ ~ ~s~ ~. ~ue ~~ ~o~2~ ~. ~~ ~s~ ~o SO00 ps2 ~ ~es. ~ SO00 psi ~~ ~ v~ve ~ ze~ p~s~e Bi~ ~s~ ~0 :e~. ~ ~m sec of bl~ ~ ~ ce~ to 5000 psi for az leu: ~es. Te~ s'~i~ valves ~ ~000 psi. 18. ~~ ~le~e ~ ~e~ ~ a ~ ~ ~- ,-~ ARCO Alaska, Inc. ' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - LGI Pad (Wells 2, 4, 6, 8, 10,12, 14, 16) Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate En§i neer JG/tw GRU13/L91 EnclOsure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany '~/ '° %~:_ t ,_, , ,, ,' ,.1= /,,.._i ,~ / J~ · i It II I0 ~ rr ~o i 14 · ' · ,0. .. ., ~ (vJcmJ~ ~P) ARCO LISflUR~E FACILITIES ~JECT : '~ 4 · NOTES- '" ;~ ~ " L__ Jl ~ I.STATE PBNE COORDINATES ARE } ~ ' ' , J .~eeo.oo ZONE 4. ~ ~-- N7~.oo ~ALL 6E~IC ~SlT~S ARE // // ~SEO ON tad 1liT. // // 5.~FSETS TO SECTIO~ LINES ARE C~. // /~ PUTEO B~EO ~ ~OTRACTEO VALUES OF THE / SECTION CORNER POSITIONS. 4. PLANT CO~OI~TES CEO 4~7-17212~ Slit ~1~ REV. I. i I III I III I I LOC~TION N SECTION STATE PLANE COORDINATES GEODETIC ~SlTIOa A/8 PLA~T COORDINATE5 , ~, , ~ ,, 2 - ~J65 m'm i632' ' S976~.53 6~734.64 70' ~ '~.6~" 148;'~ '36.823" ~.~1 6487.56 4 1~ 1644 S~635S.~ 6~2l.~ 70.~24.~ 14r~f37.174- 8I~.09 64~.58 5 1247 1G~ 597~1~ 6~7~.41 70'~'24.~9' ~~7.~ ~.0~ 6487.~3 S llS8 lGG8 597~.~ 6~.~ 70-~,25.418= 148'~,~7.~8w ~0.07 6487.50 10 ~129 26~ 5976530.35 6~.60 70'~'25.~" 14e-~,)e.22e, ~.Ot 6467.52 12' 1070 1692 24 1012 1704' SgT~.~ ~53.S7 70-~e~.lS~ 148-~38.9~1- ~40.~ 6487.48 [6 ~3 1716 59767~.72 6~40.08 70.~.730w 148'~39.282w ~.01 64~.49 F~EC~iVFD AlasK~ Oii& b~ Ou,-,s. bO;,.:m~SSJOn III I I I II I i HERE~Y CERTIFY THAT' I AM PROPERLY REGISTERED AND LICENSED TO PRACTIC[~.,'. ~Y ~[ OR U~DER ~Y SUPERViSiON, OTHER DETAILS ARE CORRECT. L$1 PAD m i . SURVEYED FOR: ~ mm ~.'~g t R C 0 ~" e I/24/86 I"= 400' b~w~ ay :"[' · CHK BY: SNEET: IBSSDG, "~ ~ COMMENTS: ~ ........ FRB -ANCH FB-8~2 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Company Lease & Well No. YES NO REMARKS (1) Fee / 8) (~thru 12) 10. <~f. ,'~.~_ 3 -';~ ~ 11. ('10 and 12) 12. (13 thru 21) (22 thru 26) (6) Add: 13. .14. 15. 16. 17. 18. 19. 20. 21. 1. Is the permit fee attached ..................................... 2. Is well to be located in a defined pool .................... 4. Is well located proper distance from other wells ......... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ..... 7. Is operator the only affected party .............. 8. Can permit be approved before ten-day wait ::::::..::1 .... 22. 23. 24. 25. 26. 27. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst..~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Additional requirements ~ ee~eeeeee®eee~eeeeeeeeee~eeeeeeeeee~e~e~eeee >:., Ad~ditional Remarks: Is a diverter system required e e · · e e e e · · e · e · · · · · · · · · · · · $ · · · · · · · · · · · · e Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ,5"0/1~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas prObable ................................. ' ' ' / Gee logy: Engi~eerin~: :cs JAL . · rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,,, Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . FMS Composite Sepia's 186-069 1-4 Are in special storage due to . overSIze. . Please ask the Liberian to retrieve them for you in the storage upstairs. STMA~IGRAPHIC OlP~gTER i4SD CO~'PtJTATIONS COMPANY FIELD COUNTRY RUN OATfl LOGGFO REFYR~]r~C£ ARCO ALASKA bGI~lO PRUDHO~: BAY-LISBURNE POOL NORTH SLOPE ~4 - JUL - ~6 72025 ARCO A6ASKA INC LGI-IO PAGM l-FIb~ 1 * D~P~H DIP DIP D~V DEV DIA~ DIAN Q * * AZN AZM I-3 2-4 * * * 13647 7~ 16,1 6~ 47 0 76 21,3 i14 46:B 77 4,5 301 46.'7 78 12,1 274 46,6 79 8,6 62 46,7 79 11 1 245 46.7 * 13649 * 13651 * 13653 * 13655 * 1.3657 * ~ 3659 $ 1366i * I],6~ , * 136 * 13673 * 13675 * 13677~ * 136~3 * 13685 * 136~7 * 13659 * 13691 : 13693 i3695 3701 3703 80 20 81 5 81 22 83 12 84 1~ 85 11 85 15 89 334 46,7 23 46.6 155 46,6 162 46,5 183 46.5 172 46,4 144 I~3 63 46.! 21b 46.1 189 46.0 90 %4, 0 45 9 21 45.8 93 5 212 45,~ 94 NO'COR~ 45, * 13705,96 I2 * 1370 '96 * 1~70 .~:97 * 13711.98 : 1 *I! oo , O0 226 45,6 247 45,6 o 45,5 115 45,5 ~00 45,5 2OO 45,5 261 45,5 39 10.1 39 9,8 39 39 9,4 39 9,5 39 9,~ 39 9, 39 9,0 39 9,1 39 9 ! 39 9 0 39 9 0 39 ~ 9 39 9 0 39 9 0 39 9,1 39 9,1 39 9 39 9 ~ 9 9 39 9 2 39 9 2 39 9 ~ 39 ~9 9 ~9 9 ~ 39 39 9,1 39 9 1 39 9 1 39 ~.1 39 39 9,2 39 9,2 9,5 9,8 10,0 9,8 8,9 8,9 8 .9 9 0 9,0 ,9 S,9 9'0 0 0 ii 9,1 9~0 o i° * .1.3 ' 36 6 266 45 39 * 13726'02 24,,8 26.8 45.4 39 95~, 8~9 D * *********************************** '**** ********************************* :-: ' "'..."' '"' "':?.,.i.;' ARCO AbAMKA INC bGI-lO PAGE; 2-FlbE 1 DEPTH DIP DIP OEV [)EV DIAM OIAM Q * ************************************************************************* * 13728 03 12 6 180 45,4 * 13730 04 46 0 191 45 4 * 13732 * 13734 * 13736 * 13738 * 13740 * 13742 * 13744 * 13746 * 13748 * 13750 * 13752 * 1.3754 , 13756 * 13758 * i3760 * 13762 * 13764 * }3778 * 3780 * 113782 * 3784 * 1.3794 * 13796 * 13802 * 13804 * 13806 04 51 6 22i 05 25 4 318 06 .50 4 ' 178 45.2 07 5 8 90 45.2 07 18 08 22 10 ! 1 I1 14 22 ..! 6 2 17 26 20 1~ , .. ~0 28 *~**~ 152 45,1 145 45,1 166 45,0 138 45.0 55 45.0 317 45,0 203 45.0 214 81 45. 234 45,1. 26 45,0 24 0 86 44.0 354 44,8 63 44,7 240 ~ 7 350 44,6 37 44.6 71 ~., ]9 9,3 8,9 39 9 3 ~,9 39 9 3 8.8 39 9 5 9,0 39 9 4 9.0 ]9 98 91 39 95 91 39 10 0 9 2 39 9 4 9 1 39 9 7 9 1 39 9 4 9 1 39 9 3 9 0 39 9 2 9 0 40 9,2 9,0 40 9.1 8.9 40 9~2 9.0 40 9,2 8,9 40 91 I 8 9 40 9 I 8 9 40 9 2 8 9 40 9 2 40 9 2 9 0 40 40 9 ~ ,0 40 9 I 8 40 9 ,0 40 91 ~.9 40 9i 8,~ 40 9 8, 40 9 I ~,~ 40 9 0 40 9 o 0 9,' 8 7 262 4 ; 6 40 ~, ********************** , O * D * C C , C C , D D * C * C * O C A B · B D C 0 O * A * 0 , C * B , ARCO ALASKA iNC LGI-IO PAGE * DEPTH DiP DIP * AZ~ AZM 1-3 2-4 ************************************************************************* * * ! 3808 * 1381~ * 1381 * 11814 * 13816 * 13818 * 13820 * 13826 * ! 3828 * 13830 * t 3832 * 138;{4 * ! 3836 , ~3838 3840 ~ 13812 , 138 4 * } 3846 * 3848 * 1 * I ~ . 1 3864 ~ 13866 138B8 : 1 3~72 30 7,1 95 44,4 31 5,6 50 44.4 32 6,5 47 44,4 33 16,1 42 44,4 ]3 21. ,7 39 44,4 34 11,0 42 35 1,8 44 44,3 35 5,7 291 44,3 87,0 255 44,2 ii NO CORR 44,2 0 8 315 44,1 38 0 9 275 44,1 44,! 0 0 9 9 39 3 39 16 40 12 41 58 4~ 0 5i 2~ 288 175 44 298 287 219 225 .{09 43, 258 43 311 43 338 43 3t8 43 325 43 2!0 43, 2 2 70 .43, 54 2t~ 2 ~ 43, : 13878 54 ~ i 3880 55 9 9 5 5 5 6 5 40 40 40 40 4O 40 4.0 40 40 4O 4O 40 40 40 40 40 40 40 40 40 40 40 40 4O 40 4O 40 40 4O 40 4O 4O 4O 0 40 40 9.1 9,1 9,1 9,1 9,0 9,0 9,0 9,1 9,1 9,2 9,2 9.3 9, " 3 9 8,9 8,9 9,0 9,0 8 ? 8 8 9 U 0 9 0 9,0 , B * C * L) C * D * B * C O * , A A * B * C * O D D O * A A A * B A A A B D A ,2 43 5 40 4 1 C * · 278 433 6 40 9 4 I C * 57 3,0 112 43,6 40 9,i ARCO AbASKA IN¢ I,~I-l~ PAGE 4-FII,E 1 ~ZM AZ~ 1-3 2-4 * , 1. 3888 58 * 13890 * 1 3892 * ! 3894 * 13896 * 13898 * 13900 * 139042 * ! 390 , 13906 ~ ~390~ , 139 * 1~914 * 13916 ,I * :I ~ ~ 395~ ~ 13962 13964 8,2 144 43,5 58 13.7 3lb 43.4 59 el,2 298 43.3 60 40,2 250 43.3 61 4 65 15 66 15 7 22 ,76 14 ,82 359 43.3 295 43,3 318 43.3 214 43.3 230 43.3 269 43.3 232 43,3 298 4],3 74 4 ~2 3 ~ ,2 33 43.2 35 43.t 229 4.3,1 44 67 43 74 43 A q7 42 113 42 9 20 42 9 2] 42 9 3i8 42 9 3lb 42 9 57 42 9 154 42 9 I69 42 9 4 42 9 329 42 8 307 42~7 357 42~7 14 4' 33~ 2,7 42,7' 40 40 40 40 ~ 9 40 8 9 40 8 9 40 8 9 40 8 9 40 9 2 40 9 2 40 9 4 40 9 q 40 9 3 40 9 3 40 9 2 40 9 3 40 9 3 40 9 4 40 9 4 40 9 5 4O 9 5 40 ~ 6 40 7 40 4O 9 ~0 9 ~0 40 9 40 40 40 8,0 {5,9 6,9 6,9 6,9 ~ 9 7 9 8 7 9 0 9 0 9 0 9 0 9 0 9 0 8 9 9,0 9,0 9 .2 9 ! 9 0 8 A C D D * D 0 * C C A C A A C D * A A C * ¢ A o A 13970~86 7 6 3 42.6 13972~87 4 5 ~27 42.6 13974 87 2 8 333 42.5 13976 88 6 6 6~ 42,5 13980 13982 13984 13990 13992 } 3994 3996 13998 14000 14002 14004 1401 140 140 1:40,, 140: 140~ 14039 1404I 14043 14045 89 5 4 89 9 9O 35 91 12 93 lO 93 3 ~98 9 ,99 9 oo o0 0 04 ~ 04 48 42°5 26 42,4 146 42.4 325 42.4 354 42,4 24 42 233 42.3 4 :1 38 42 39 4 3~1 . 0 96 ii 9 148 41 9 267 41 8 I67 418 40 40 40 40 40 40 40 40 4O 40 4o 40 40 40 40 40 40 40 40 40 40 40 40 40 40 40 40 40 40 40 40 40 40 40 40 40 40 9,1 9,2 9,1 9.1 9.1 ! 9,1 9 1 9 0 8 9 9 o 0 9,0 8,7 8,8 8 7 8 8 8.8 8.8 8.8 8,7 8 6 8 7 8 7 8, '8 C A A * A C D * C A B D A C * B A A A A A A O A A A A C A ARCO ALASKA INC LG!-I(, PAGE ************************************************************************* * DEPTH DIP OIP DEV t)EV [)IA~ D/AM ~ * AZ~ AZ~ 1-3 , * 14049 13 2.1 0 41,6 * 14051 13 4 1 268 41,5 * 14053 14 329 199 41,5 , 14O55 * 14057 * 14059 * 14061 , , , , * 14079 * 14081 * 14083 * 14085 * 14087 * 14089 * 1409i * 1409 15 12 15 6 16 24 I? 21 14063,17 2 14065,18 14067,i 14069, ~ 14071~i 14075, ~4 25 17 ~6 15 $o 14 ]0 16 14103, 14107,32 14109.3~ : 14111 14113 * 14115 * 14117 * 14119 * 14121 * 141,23 * 1,4125 * 14127 ******* 34 5 i2 6 1,4 ? 1o 38 19 38 18 4 353 41,4 3 273 41.4 2 259 41,3 I 33b 4i.3 4 271 41,3 3 326 41,3 9 160 41,3 8 189 41,3 5 12 0 355 41,3 0 306 41 4 78 41 4 34t ql 288 ql ~ 290 41 2 33b 41 1 249 2 ~ ~0 8 40 ~ 7 40 348 40 58 40 50 40 50 40 4 67 40, 9 72 40, o 63 40 o 78 40 39 7.9 239 40 4O 4O 40 40 4O 40 4O 4O 40 4O 40 4O 40 4O 4O 4O 4O 4O 4O 4O 40 40 4O 4O 4O 4O g 40 0 40 40 4O 40 40 8 40 8 f6 40 8 9.1 9,2 9,2 9,5 9,6 9,7 9.5 9,4 9,i 9,2 ,! ,0 $ 8.8 89 91 92 9,4 9.2 91 9O 94 92 94 9,1 8 ~8 8 8,9 8.9 ,9 8,9 9,0 ~,9 , A * A C * b * O * O * 0 A D D * C C A * A B A * C * B * A A * 0 c : L') * A 14129, 14131 14133 1.4135 14137 14139 14141 141 1414,7 141,49 141.5 1415~ 14155 14{.57 14159 1416! 14167 14169 1418,5 14185 C LGI-IO ********************* H DiP DIP DEV DEV DIAN AZN **************************** 160 40,6 40 243 40,5 40 237 40,5 40 200 40.5 40 131 40.5 40 325 40,5 40 295 40.5 40 3O$ 40,4 40 145 40.4 40 302 40,4 4O 2?9 40.4 40 45 40,4 40 43 40.3 40 22~ 40,] 40 17 40,3 40 189 40.3 40 196 40.2 40 17 40,2 40 28 90,1 40 77 40,1 40 67 40.0 40 4O 4O 40 0,5 41 I 9 41 6 7 42 7 7 43 16 1 43 7 0 44 9 1 45 10 0 45 1 1 2 47 6 ,0 48 4,8 49 8,6 49 6,2 50 7,8 52 ,2 ,54 9,1 79 40,0 55 NO CORR 40,0 56 NO CORR 40,~ 40 56 NO CORR 40,0 40 57 ~0 CO~ , 40 40 S8 ~3,6 2!2 40:0 40 59 27.] 218 39 40 8,8 8,8 8,8 8, 8, 8 8 8 7 8 8 9 8 B ? 7 PAGE 7-FIhE 2-4 * ************************************* 8,9 8,9 8,9 8,9 8,9 8,9 8,9 8,9 B 9 8 9 8 9 8 9 8 8 ~,8 8 A * A * A * B A * C * A B A B * B A A * A * A * A * A * C * C A * A * D , , , B * A~CU ALASKA I~C bGI-iO ************************************************************************* , D~PrH * DIP t)IP ~ DEV D~V DIAN DZAM , AZU , AZM 1-3 2-4 ************************************************************************* · TOP · 1,3647,76 16,1 6~, 47,0 39, 10,1 9,5 D · BOTTOM * · 1,4!85,59 27,3 218, 39,5 40, 6,5 6,5 C 13700-13800 3 13800-13900 1 13g00-14000 3 14000'i4100 14100-141~5 3 DiP FREQUENCY BY AZIMUTH 0-10 DEGREE DiPS 330 N 30 60 E 120 1,50 I 2 2 4 2 3 2 4 4 7 3 I I 4 6 3 2 2 2 2 4 3 2 1 210 2 1 PReSenTAtION 210 240 1364:13700 1 ~3700~1,3800 3 b 13800-13900 3 8 13900'14000 2 1 14000'14100 ] 14100"14185 ] ~ {)lP FRB~UENCY BY AZIMUTH lO-gO OgORgE DIPS 300 330 N 30 60 E 120 lbO 2 1 1 2 2 3 I 2 I I 3 4 2 3 1 2 4 3 1 I 1 1 2 1 4 1 I 1 4 5 i 210 2 3 1 13647-11700 2 13700-13800 2 3 13800-13900 4 2 ~3900-14000 7 J 14000-14100 3 2 14100-14185 ] 2 DIP F~EOt{ENC¥ ~Y AZINUTH 0-!0 D~:GRE~ DiPS !20 150 S 2 ! 2 2 2 1 2 210 240 w 300 i 2 2 8 2 4 5 5 4 3 1 2 2 2 30 1 4 4 11647-117 0 ~ 11700-13800 2 4 13900-14000 10 4 14000-14!00 7 3 14100-14185 ? ~ * 0-90 [)EGR~E DiPS 2 2 5 2 2 ~ 2 2 210 240 ~ ]00 330 ] 1 1 1 2 6 9 4 2 2 4 I0 8 10 2 5 2 3 ? 4 ? 5 6 6 6 I 2 3 2 30 2 6 1 4. ARCO AbASKA ~NC bGl-lO SUMMARY * DEPTH * DIP PIP * DgV BEV PIAN DiAM * QUAb * * TOP * 1~647,76 16.1, 6~. 47,0 39, lO.l 9,5 P * * , * BOTIO~ , * 14185,59 27,3 218, ~9.5 40, 6,5 6,5 C * ]o-f,]C~-~6 - 10;57~45 LIS TAPE VERIFICATION'LISTiNG LVP OlO.H02 VERIFICATION LISTING PAGE ~ REEL HEADER ** SERVICE NAME :EDIT DATE :8610811] ORIGIN : REEL NAME : ZERO CONTINUATION # :0! PREVIOUS REEL : COMMENTS :LIBRARY TAPE · ~ TAPE HEADER SERVICE NAME :EDIT DATE :86/08/13 ORIGIN :7161 TAPE NAME CONTINUATION ~ :0! PREVIOUS TAPE : COMMENTS :LIBRARY TAPE · ~ FILE HEADER FILE NAME :EDIT .001 SERVICE NAME : VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE PRE¥IOUS FILE INFORMATION RECORDS MNEM CONTENTS CN : ARCO ALASKA, INC. WN : LGI-10 FN : PRUDHOE BAY/LISBURNE POOL RANG: TOWN: 1IN SECT: COUN: NORTH SLOPE STAT: ALASKA CTRY: USA MNEM CONTENTS PRES: E ~ COMMENTS UNIT TYPE CATE SIZE CODE 0-00 000 018 065 000 000 006 065 000 000 026 065 000 ,000 00~ 065 000 000 004 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 00¢ 065 UNIT TYPE CATE SIZE CODE 000 000 001 065 LVP OlO.H02 VERIFICATION LISTING PAGE 2 ~- SCHLUMBERG=R. ~- ALASKA COMPUTING CENTER COMPANY : ARCO ALASKA INC WELL : LGI-IO FIELD : PRUDHOE BAY/LISBURNE FIELD COUNTY : NORTH SLOPE BOROUGH STATE = ALASKA SURFACE LOCATION : 1129' FNL [ 1680°FEL~ SEC 1F TliN~ R14E JOB NUMBER AT ACC: 71614 RUN ~1, DATE LOGGED: 23-JUL-86 LOP: L. B. CUDNEY API SERIAL NO: 5002921573 PERMANENT DATUM: MSL ELEV OP PERM. DATUM: 0.0 F LOG MEASURED FROM: RKB DRLG MEASURED FROM: RKB ELEVATIONS: KB: 52.0 F DF: 51.0 F GL: 13.0 F DEPTH-DRILLER = 14216 F DEPTH-LOGGER = 14225 F BTM. LOG INTERVAL= 1~210 F TOP LOG INTERVAL= 5300 F CASING-DRI~LLER CASING-LOGGER CASING ~EIGHT = 13581 P = 13586 F = 9.625 " 47.0 LB/F LV'P 010.H02 V=RiFICATION LISTING PAGE 3 BIT SIZE = 8.5 " DEPTH : 14216 F TYPE FLUID = BALANCED SALINITY SOURCE OF SAMPLE : CIRCULATED DENSITY : 9.30 LB/G RM : 2.170 @ 71.0 DF VISCOSITY = 40.0 S RMF : 1.560 @ ?0.0 DF PM : 10.9 RMC : 2.890 @ 64.0 DF FLUID LOSS : 9.6 C3 SOURCE RMF/RMC : MEAS/MEAS TIME CIRC STOPPED: 0630 (7-23) RM AT BHT : 1.058 @ 153. DF TIME LOGGER ON BTM.: 1313 (7-23) RMF AT BMT = .751 @ 153. OF MAX REC. TEMP. = 153.0 OF RMC AT BHT : 1.282 @ 153. DF LOGGING UNIT NO: 8266 LOGGING UNIT LOC: PRU'DHDE BAY FIELD ENGINEER: RUBENSTEIN WITTNESSED BY: PRZYBYSZEWSKI MATRIX : LIMESTONE MDEN : 2.71 G/C3 DHC : NONE HC = CALI FLUID DENSITY = 1.0 GM/C3 REMARKS: 1.5" STANDOFFS. USED ON DLL. 30000 PPM CHLORIDES. TARGET LOCATION: llO0'FSL ~ IO0'FEL 30-12N-15E. MAXIMUM DEVIATION ='61DEG AT 5800 FT. N,GT TELEMETRY SPIKES AT 13926' & 13850' ON REPEAT DID NOT O:CCUR ON M~IN PASS. LVP 010.H02 VERIFICATION LISTING P~GE ~ LOGGED NGT THROUGH CASING UNTIL A COBALT MARKER WAS LOCATED AT 13407 FT. EQUIPMENT NUMBERS: DLE E 789 NGC H 1905 AMM A 870 DLH CB 2725 NGD B 746 TCM AB 95 AH 169 T22 GPIC A 718 LCM 799 DLS F 754 TCC A 123 ALL INTERPRETATIONS ARE OPINIONS BASED ON INFERENCES FROM ELECTRICAL OR OTHER MEASUREMENTS AND WE CANNOT, AND DO NOT GUARANTEE THE ACCURACY DR CORRECTNESS OF ANY INTERPRETATIONS, AND WE SHALL NOT, EXCEPT IN THE CASE OF GROSS OR WILLFUL NEGLIGENCE ON OUR PART, BE LIABLE OR RESPONSIBLE FOR ANY LOSS, COSTS9 DAMAGES OR EXPENSE'S INCURRED OR SUSTAINED BY ANYONE RESULTING FROM ANY INTERPRETATION MADE BY ANY OF OUR OFFICERS9 AGENTS, OR EMPLOYEES. THESE INTERPRETATIONS ARE ALSO SUBJECT TO OUR GENERAL TERMS AND COMDITIONS AS SET OUT IN OUR CURRENT PRICE SCHEDULE. · ~* ~-' ~- MAIN LOGS · -~;~ THIS DATA HAS BEEN DEPTH SHIFTED ~~ BASE LOG: DLL ********************************** SCHLUMBERGER LaGS INCLUDED WITH THIS MAGNETIC TAPE: LVP OlO.H02 VERIFICATION LISTING PAGE 5 DUAL LATERLOG (DLL) ~ LITHO OENSITY COMPENSATED LOG (LOT) ~ COMPENSATED NEUTRON LOG (CNL) -~ ELECTROMAGNETIC PROPAGATION TOOL (EPT) :~ NATURAL GAMMA TOOL (NGT) ¢ COMPENSATED NEUTRON IN CASING (GR.CHL) ~ SHOT (CALIPER ~ DIRECTIONAL DATA) ~ (SHI:IST PASS~ SH2:2ND PASS) :~ GPIT (DIRECTIONAL DATA~ GPT) -,- ~ DATA FORMAT RECORD ~ ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 ! 66 0 4 I 66 1 8 4 73 6O 9 4 65 .lIN 16 t 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API API API API FILE SIZE SPL REPR PROCESS ID ORDER # LOG TYPE CLASS' MOD NO. CODE (OCTAL) DEPT FT O0 000 O0 0 0 4 I 68 00000000000000 LLS DiLL OHMM O0 220 ~09 0 0 4 I 68 00000000000000 LLD DiLL OHMM O0 220 10 0 0 4 I 68 00000000000000 LVP OlO.H02 VERIFICATION LISTING PAGE 6 SGR DLL GAPI O0 310 SP DLL MV O0 SVO DLL MV O0 000 SIO DLL UA O0 000 DVO DLL MY O0 000 OIO DLL UA O0 000 MRES DLL OHMM O0 823 MTEM DLL DEGF O0 660 TENS DLL LB O0 635 NRAT CNL O0 420 RNRA CNL O0 000 NPHI CNL PU O0 890 NCNL CNL CPS O0 330 FCNL CNL CPS O0 330 GR CNL GAPI O0 310 TENS CNL LB O0 635 MRES CNL DHMM O0 823 MTEM CNL DEGF O0 660 GR LDT GAPI O0 310 CALI LDT IN O0 280 RHDB LDT G/C3 O0 350 DRHO LDT G/C3 O0 356 DPHI LDT PU O0 890 PEF LDT O0 358 LL LOT CPS O0 LU LDT CPS O0 354 LS LDT CPS O0 354 LITH LDT CPS O0 354 SS1 LDT CPS O0 000 SS2 LDT CPS O0 000 QSS LDT O0 000 QLS LDT O0 000 TENS LDT LB O0 635 MRES LDT OHMM O0 823 MTEM LDT DEGF O0 660 SGR NGT GRPI O0 310 CGR NGT GAPI O0 310 POTA NGT PU O0 719 THOR NGT PPM O0 790 URAN NGT PP'M 00. 792 WiNG NGT CPS O0 310 W2NG NGT CPS O0 W3NG NGT CPS O0 310 WANG NGT CPS O0 ,310 WSNG NGT CPS O0 310 MRES NGT OHMM O0 823 MTEM NGT DEGF O0 660 TENS NGT LB O0 635 GR EPT GAPI O0 310 CALI EPT IN O0 280 MRES EPT OHMM O0 823 MTEM EPT DEGF O0 660 TENS EPT LB O0 635 AZIM GPT DEG O0 630 O1 0 0 4 O1 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 O0 0 0 4 50 0 0 4 50 0 0 4 21 0 0 4 O1 0 0 4 O0 0 0 4 O0 0 0 4 31 0 0 4 30 0 0 4 O1 0 0 4 21 0 0 4 50 0 0 4 50 0 0 4 O1 0 0 4 O1 0 0 4 02 0 0 4 O1 0 0 4 O0 0 0 4 O1 0 0 4 O1 0 0 4 01 0 0 4 O1 0 0 4 O1 0 0 4 O0 0 0 4 O0 0 0 4 00 0 0 4 O0 0 0 4 21 0 0 4 50 0 0 4 50 0 0 4 0I 0 0 4 O1 0 0 4 50 0 :0 4 50 0 0 4 50 0 0 4 01 0 0 4 O1 0 ,0 4 Oi 0 0 4 01 0 0 4 O1 0 0 4 50 0 0 4 50 0 0 4 21 0 0 4 Ol 0 0 4 O1 0 0 4 50 0 0 4 50 0 0 4 21 0 0 4 O1 0 0 4 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00'000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 '00'00000'0000000 68 00000000000000 68 0'0000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 000'00000000000 68 00000000000000 68 00000000000000 68 0~00000000000'00 68 00000:000000000 68 00000000000000 68 0000000000000~0 68 00000000000000 68 00000000000000 6B 00000000000000 68 00000000000000 68 00000000000000 68 00000000~000000 68 00000000000000 68 00000~00000:0000 68 00000000000000 68:00000000000000 6800000000000000 68 00000000000000 68 '00000000000000 68 00000000000000 68 00000000000000 LVP OIO.HO2 VERIFICATION LISTING PAGE 7 DEVI GPT DEG O0 RB GPT DEG O0 GR SH1 GAPI O0 DEVI SM1 DEG O0 RB SM1 DEG O0 AZIM SM1 OEG O0 HAZI SH1 DEG O0 GR SH2 GAPI O0 DEVI SH2 OEG O0 RB SH2 DEG O0 AZIM SH2 DEG O0 HAZI SH2 DEG O0 620 631 310 620 631 630 630 310 620 631 630 630 DATA DEPT SP DIO NRAT FCNL MTEM DRHO LU SS2 MRES POTA WZNG MRES CALI AZIM DEVI GR HAZI 14246.5000 LLS -999.2500 SVO -999.2500 MRES -999.2500 RNRA -999.2500 GR -999.2500 GR -999.2500 DPHI -999,.2500 LS -999.2500 QSS -999.2500 MTEM -999.2500 THOR -999.2500 W3NG -999.2500 MTEM -999.2500 MRES -999.2500 DEVI -999.2500 RB -999-2500 DE¥1 -999.2500 DEPT SP DIO :NRAT FCNL MTEM DRHO LU SS2 MRES PO'TA W2NG MRES CALI AZIM DEVI GR HAZI 14200.0000 LLS 35.574Z SVO 467.1406 MRES 1.4405 RNRA 2441.5000 GR 158.6875 GR 0.0518 DPHI 252.5625 LS 308.6406 QSS 0.0703 MTEM 0.3418 THOR 39.1367 W3NG 0.0737 MTEM 9.0723 MRES 40.7617 OEVi '-999.2500 RB -999.2500 DEVI -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ,-999.2500 -999.2500 -999.2500 -999.250'0 -999.2500 -999.2500 7.1584 3.1663 0.0737 1.5499 23.6299 23.6299 9.0820 267.3906 0.0293 158.6875 1'0264 9.4473 151.4375 0.0703 39.44'92 -999.2500 -999.2500 O1 Ol O1 O1 O1 O1 O1 O1 O1 O1 O1 O1 LLD SIO MTEM NPHI TENS CALI PEF LITH QL S SGR URAN WANG TENS' MTEM RB AZIM RB LLD SIO MT E M NPHI TENS CALI PEF LITH QLS SGR URAN WANG TENS MTEM RB AZIM RB -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999-2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999-2500 -999.2500 -999.2500 1 68 00000000000000 1 68 00000000000000 i 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 O000000000000O I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 SGR -999.2500 DVO -999.2500 TENS -999.2500 NCNL -999.2500 MRES -999.2500 RHOB -999.2500 LL -999.2500 SS1 -999.2500 TENS -999.2500 CGR -999,2500 WING -999-2500 WSNG -999.2500 GR -999.21500 . TENS -999.2500 GR, -999-2500 HAZI -999.2500 AZIM -999.2500 11.0550 SGR 22.7080 641.8i25 DVO 5-8015 151.4375 TENS 6411.2500 5.5664 NCNL 3783.50:00 0.0386 TENS 660?.2500 22-7080 CGR 9-?285 1.7628 WING 78.2773 1-3487 WSNG 0.0000 6411.2500 GR 23,6299 158.6875 TENS 6607.2500 146.6875 GR -999,2500 -999,2500 MAZI -999.2500 -999.2500 AZIM -999.2500 LVP OlO.HO2 VERIFICATION LISTING PAGE 8 DEPT SP DIO NRAT FCNL MTEM DRHO LU SS2 MRES POTA W2NG MRES CALI AZIM DEVI GR HAZI DEPT SP OIO NRAT FCNL MTEM DRHO LU SS2 MRES POTA WZNG MRES CALI AZIM DEVI HAZI DEPT. S P DIO NRAT FCNL MT E M DRHO LU SS2 MRES POTA W2NG MRES CALI AZIM DEVI 14100.0000 LLS 32.0117 SVO 167.9375 MRES 1.3946 RNRA 2223.5000 GR 158.9375 GR 0.0093 DPHI 209.9375 LS 269.1406 QSS 0.0703 MTEM 0.2930 THOR 36.6680 W3NG 0.0737 MTEM 9.1035 MRES 39.2617 DEVI 40.4180 RB 27.7393 DEVI 41.3867 14000.0000 LLS 49.4492 SVO 75.4648 MRES 2.0549 RNRA 1247.6875 GR 157.4375 GR 0.0054 DPHI 214.I875 LS 269.3906 QSS 0.0713 MTEM 0.2441 THOR 48.2617 W3NG 0.0747 MTEM 9.1816 MRES 39.2930 DEVI 41.6992 RB 24.9180 DEVI 41.3242 139:00.0000 LLS · 40.9492 SVO 36.0430 MRES 1.4346 RNRA 2305'5000 GR 155.8125 GR -0.0063 OPHI 212.4375 LS 264.6406 QSS 0.0723 MTEM 0.2441 THOR 14.7676 W3NG 0.0752 MTEM 9.3691 MRES 39.2930 DEVI 42.7617 RB 105.2187 16. 7393 0.0737 1.3897 31.1299 31. 1299 3.0273 208.8125 0 · 0356 158.8125 1.3096 10.9004 152.1875 0.0703 40.3555 176.4375 40.4805 219.5510 23.1143 0.0747 2.1428 24.4063 24.4063 4.7852 217.9375 0.0371 157.3125 1.1348 11.8223 151.4375 0.0718 41.5742 177.0625 41,7305 570.1864 32.3242 0.0752 1.5391 12.8066 12.8066 5.5176 217.3125 0.0278 156-0625 0.2427 8.4395 150.6875 0.0723 42.6992 185.9375 LLD SIO MTEM NPHI TENS CALI PEF LITH QLS SGR URAN W4NG TENS MTEM RB AZIM RB LLD SIO MTEM NPHI TENS CALI PEF LITH SGR URAN W4NG TENS MTEM RB AZIM LLD SIO MTEM NPHI TENS CALI PEF LITH QLS SGR URAN W4NG TENS MTEM RB AZIM 111.2565 230.6875 152.1875 5.0293 6791.2500 9.1035 5.0828 40.2305 -0.0210 22.5361 1.7149 2.9729 6587.2500 158.8125 172.0625 40.6992 87.5898 379.9084 152.6875 151.4375 14.7949 6683.2500 9.1504 3.6096 45.0430 0.0103 28.1455 2.6565 2.9553 6483.2500 157.3125 16B.9375 40 5742 1201.7092 82.2148 150.6875 5.3223 6483.2500 9.3613 5.3796 41.7930 0'0210 14.6738 1.2979 3.1643 6535.'2500 155.8125 173.1875 40.8242 SGR DVO TENS NCNL MRES RHO8 LL SS1 TENS CGR WING WSNG GR TENS GR HAZI AZIM SGR DVO TENS NCNL MRES RHOB LL SSI TENS CGR WING WSNG GR TENS GR HAZI ~ZIM SGR DVO TENS NCNL MRES RHOB LL SS1 TENS CGR WiNG WSNG GR TENS GR HAZ I 22.5361 20.9893 6587.2500 3089.5000 0.0703 2.6565 103.7773 205.4375 6787.2500 9.9004 72.3398 0.0000 31.1299 6787.2500 24.2236 40.6992 41.3867 28.1455 32.1992 6483.2500 2673.5000 0.0713 2.6272 110.8398 204.9375 6747.2500 8.5723 88.6523 0. 9849 24.4063 6455.2500 27.2705 40.5742 41.3242 14.6738 48.6367 6535.2500 3547.5000 O.0723 2.6155 111.1523 198.6875 6475.2500 5.1140 50'6367 2.1096 12.8:066 6483.2500 16.1:143 40.8242 LVP OiO.HOZ VERIFICATION LISTING PAGE 9 GR 15.9160 DEVi HAZI 41,3555 DEPT 13800.0000 LLS SP 58.8242 SVO DIO 50.7617 MRES NRAT 1.7208 RNRA, FCNL 1614.6875 GR MTEM 154.4375 GR DRHO -0.0073 DPHI LU 278.3906 LS SS2 289.8906 QSS MRES 0.0?32 MTEM POTA 0.2441 THOR W2NG 23.2236 W3NG MRES 0'0762 'MTEM CALI 9.0957 MRES AZIM 39,1055 DEVI DEVI 43.9805 RB GR 14.T03! DEVI HAZI 41.5117 DEPT 13700.0000 LLS SP 43.8242 SVO DIO 74.9648 MRES NRAT 1.4278 RNRA FCNL 2575.5000 GR MTEM 153.3125 GR DRHO -0.0117 DPHI LU 207.4375 ES SS2 265.6406 QSS MRES 0.0742 MTEM POTA 0.4395 THOR W2NG 54.7305 W3NG MRES 0.0767 MTEM 'CALI 9.I738 MRES AZIM 38.3555 DEVI DEVI 45.1055 RB GR 39.5117 DEVI HAZI 40.6055 DEPT 136'00,00:00 LLS SP 43.8867 SVO DIO 360,8906 MRES NRAT 3.9768 RNRA FCNL 343,1406 GR MTEM 151.1875 GR DRHO 0.0396 DPHI LU 379.6406 LS SS2 331.6406 QSS MRES 0.0747 MTEM POTA 2-4414 THOR W2NG 167.3125 W3NG MRES 0.0781 MTEM 42,8555 300.0536 25.0674 0.0762 1.8604 14.0879 14.0879 15.6250 286.8906 0.0234 154.6875 0.7051 7.3914 149. 5625 0.0732 43.9180 180.8125 44,0430 369.0727 27,4111 0.0767 1,4893 31.9531 31.9531 5.1758 214.3125 0.0103 153.3125 1.9971 21,0518 14~.8!25 '0742 45.07.42 180.5720 45.2305 4,0998 2.2463 0,0781 ,4.1921 99,0273 98,0234 23.5352 397.8906 0,0522 151. 1875' 1~0. 8535 63.1680 146.6:875 RB LLD SIO MTEM NPHI TENS CALI PEF LITH QLS SGR URAN W4NG TENS MTEM R8 AZIM RB LLD SIO MTEM NPHI TENS CALI PEF LITH QLS SGR URAN W4NG TENS MTEM RB AZIM RB LLD SIO MTEM NPHI TENS CALI PEF LITH QLS SGR U R A N W4NG TENS 91.0898 AZIM 682.8704 SGR 121,2148 DVO 149.5625 TENS g.9609 NCNL 6167.2500 MRES 9.0488 RHOB 5.3289 LL 5g.lgg2 SS1 -0.0127 TENS 14.1973 CGR 1.0167 WING 1.0557 W5NG 6203.2500 GR 154.5625 TENS 174.9375 GR 40.5742 HAZI 92.4607 AZIM 396,0583 SGR 107.7148 DVO 148,8125 TENS 5,5664 NCNL. 6187.2500 MRES g.0488 RHOB 4.2859 LL 42.7305 SS1 0,0410 TENS 37.3555 CGR 3.012,0 WING 1.0518 W.SNG 5935.2~00 GR 153'0625 TENS 176.8125 GR 39,6992 MAZI 93.7148 AZIM 8.8048 SGR 794.8125 DVO 146,6875 TENS 39.5020 NCNL 6135.2500 MRES 16.5830 RHOB 3.4788 LL 103.4648 SSI. ,-0-0234 TENS 105'4648 CGR 3.5t20 WING 8.4160 WSNG 5727.2500 GR 41.3555 14.1973 38.9492 6203.2500 3005.5000 0.0732 2.4417 147.9375 208,8125 6243.2500 6.7117 45.4180 1.0557 14.0879 6315.2500 16,8730 40.5742 41.5117 37..3555 33.3555 5935.2500 3835.5000 0.0742 2.6194 110.5898 I95.0625 6187.2500 15.1738 122.0898 5,2625 3t'9531 6311.2500 47.8359 39.6992 40.6055 105.4648 3.5686 5727,2500 1.438,6875 0.0747 2,3069 208,1875 240.8125 6135.25.00 79.5898 347.3906 5.2625 98.5156 LVP OlO.H02 VERIFICATION LISTING PAGE 10 CALI AZIM DEVI GR HAZI DEPT SP DIO NRAT FCNL MTEM DRHO LU SS2 MRES POTA W2NG MRES CALI AZIM DEVI GR HAZI OEPT sp OIO NRAT FCNL M'TEM ORHO LU SS2 MRES POTA W2NG MRES CALI AZIM DEVI GR HAZI DEPT SP OIO NRAT FC N:L MTEM DR HO LU SS2 MRES 16.5830 MRES 35.7305 OEVI -999.2500 RB 102.0273 OEVI 37.3013 13500.0000 LLS 34.6992 SVO 950.3125 MRES -999.2500 RNRA -999.2500 GR -999.2500 GR -999.2500 OPHI -999.2500 LS -999.2500 QSS -999.2500 MTEM 0.8301 THOR 66.1523 W3NG 0.0776 MTEM -999.2500 MRES 336.6406 DEVI -999.2500 R8 -999.2500 OEVI -999.2500 13400.0000 LLS 114.1523 SVO 1283.6875 MRES -999.2500 RNRA -999.2500 GR -999.2500 GR -999.2500 DPHI -999.2500 LS -999.2500 QSS -999.250:0 MTEM 0.2441 THOR 31.I924 W3NG 0.0781 MTEM -999.2500 MRES 325.6406 DEVI -999.2500 -999.2500 DE¥I -999.2500 13388.0000 LLS 92.7773 SVO 938o3125 MRES -999.2500 RNRA -999.2500 GR -999.2500 GR -999.25'00 DPHI -999.2500 LS -999.2500 QSS -999.2500 MTEM 0.0747 MTEM 43.5430 RB -999.2500 AZIM 46.4606 RB 0.1496 LLD 0.0586 SIO 0.0776 MTEM '-999.2500 NPHI -999.2500 TENS -999.2500 CALI -999.2500 PEF -999.2500 LITH -999.2500 QLS -999.2500 SGR 3.0452 URAN 18.3799 W4NG 146.1875 TENS -999.2500 MTEM 48.5430 RB -999.2500 AZIM -ggg.2500 RB 0.1313 LLO O. 0098 SIO 0. 0781 MTEM -999.2500 NPHI -999.2500 TENS -999. 2500 CALI -999.2500 PEF -999.2500 LITH -999.2500 C~LS -999.25:00 SGR 2. 3186 URAN 11.4941 W4NG 145.4375 TENS -999.2500 MTEM 49-1055 RB -999.2500 AZIM -999.2500 RB 0.1478 LLD 0.0479 SIO 0.0781 MTEM -999.2500 NPHI -999.2500 TENS -999°2500 CALI -999.2500 PEF -999.2500 LITH -999.2500 QLS ,-999.2500 SGR 151.1875 TENS 325.8906 GR -999.2500 HAZI 90.1410 AZIM 1.3804 SGR 23.07.5000 DVO 146.1875 'TENS -999.2500 NCNL -999.2500 MRES -999.2500 RHOB -999.2500 LL -999.2500 SS1 -999.2500 TENS 39.5117 CGR 1.9620 WING 7.3523 WSNG 5763.2500 GR -999.2500 TENS 83.0273 GR -999.2500 HAZI -999.2500 AZIM 0.9456 SGR 2629.5000 DVO 145.4375 TENS '999.2500 NCNL -999.2500 MRES -999.2500 RHOB -999.2500 LL -999.2500 SSI -999.2500 TENS 19.0830 CGR 0.8218 WING 0,0000 WENG 5695.2500 GR -999.2500 TENS 82.7773 GR -999.2500 HAZI -999.2500 AZIM 1.3020 SGR 2335.5000 DVO 145.4375 TENS -999.2500 NCNL -999.2500 MRES -999.2500 RHOB -999.2500 LL -999.2500 SSI -999.2500 TENS 23.3174 CGR 6135.2500 -999.2500 -999.2500 37.3013 39.5117 1.4727 5763.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 25.0674 121.3398 1.8380 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 19.0830 1.3624 5695.2500 ' -999.2500 -999.2500. -999-2500 -999.2500 -999,2500 -999.2500 .13.0332 62.3867 3.283,4 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 23.3174 1. 3721 5711.25 O0 -999.2500 -999.2500 -9'99.2500 -999. 2500 -999.2500 -999.2500 9.6895 LVP OlO.H02 VERIFICATION LISTING PAGE PDTA W2NG MRES CALI AZIM DEVi GR MAZI 0.3906 THOR 47.3867 W3NG 0.0781 MTEM -999.2500 MRES 3~2.1~06 DEVI -999.2500 RB -999.2500 DEVI -999.2500 0.7983 URAN 11.4395 W4NG 145.~375 TENS -999.2500 MTEM 49.0430 RB -999.2500 AZIM -999.2500 RB 1.8506 W1NG 1.6339 WSNG 5711.2500 GR -999.2500 TENS 83.0273 GR -999.2500 HAZI -999.2500 AZIM 71.9023 0.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ~ FILE TRAILER FILE NAME :EDIT .001 SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE NEXT FILE NAME : .*~ FILE HEADER *~ FILE NAME :EDIT .002 SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : *~): COMMENTS ** MAIN LOGS THIS DATA HAS BEEN DEPTH SHIFTED B~SE LOG: .OLL SCHLUMBERGER LOGS INCLUDED IN THIS FILE: LVP OiO.H02 VERIFICATION LISTING PAGE SHDT, 1.25" SAMPLE RATE (CALIPER & DIRECTIONAL DATA) (SHI:IST PASSs SH2:2ND PASS) · ~ DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 ! 66 0 4 I 66 ! 8 4 73 15 9 4 65 .lIN 16 0 I 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API API API API FILE SIZE SPL REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NO. COOE (OCTAL) DEPT FT O0 000 O0 0 0 4 I 68 00000000000000 C1 SM1 IN 00 280 13 0 0 4 I 68 00000000000000 C2 SH1 IN O0 280 24 0 0 4 I 68 00000000000000 C1 SH2 IN O0 280 13 0 0 4 1 68 00000000000000 CZ SH2 IN O0 280 24 0 0 4 1 68 00000000000000 DATA DEPT 14189.3750 C1 4.3992 C2 4.3640 C1 -999.2500 ,C2 -999.2500 DEPT 14100.2500 C1 8.8691 C2 8.8457 C1 8.7363 C2 8.8535 DEPT 14000.2500 C1 9.0098 C2 8.7129 C1 8.5254 C2 8.9785 DEPT 13900.2500 C1 8.8613 C2 6.8601 C1 8.6582 C2 9.1348 LVP 010.H02 VERIFICATION LISTING PAGE 13 DEPT 13800.2500 C1 C2 8.8145 9.0436 C2 DEPT 13700.2500 C1 C2 8.9004 9.1352 C2 DEPT 13600.2500 C1 C2 12.4707 -999.2500 C2 DEPT 13560.0000 C1 C2 -999.2500 -999.2500 C2 · ~ FILE TRAILER ~, FILE NAME :EDIT .002 SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : NEXT FILE NAME : 8.7337 C1 9.1063 C1 -999.2500 C1 -999.2500 C1 8.4082 8.6035 10.0566 -999.2500 ** FILE HEADER FILE NAME :EDIT .003 SERVICE NAME : VERSION DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : COMMENTS ~,~ MAIN LOGS *~ · **~ THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRI~NTS ***** SC=HLUMBERGER LOGS INC=LUDED IN THIS FILE: LVP 010.H02 VERIFICATION LISTING PAGE 14 COMPENSATED NEUTRON IN CASING (GR.CHL) · ~ DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 4 8 4 73 60 9 4 65 .liN 16 1 66 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API API APt API FILE SIZE SPL REPR ID ORDER ~ LOG TYPE CLASS MOD NO. DEPT FT O0 000 O0 0 0 4 NPHI CHL PU O0 890 O0 0 0 4 NRAT CHL O0 420 O1 0 0 4 FCNL CHL CPS O0 330 30 0 0 4 NCNL CHL CPS O0 330 31 0 0 4 GR CHL GAPI O0 310 O1 0 0 4 RNRA CHL O0 000 O0 0 0 4 TENS CHL LB O0 635 21 0 0 4 PROCESS CODE (OCTAL) 1 68 00000000000000 1 6B 00000000000000 1 6,8 00000000000000 I 68 00000000000000 i 68 00000000000000 1 68 0000000000'0000 1 68 00000000000000 I 68 00000000000000 DATA DEPT NCNL DEPT' NC!NL DEPT NCNL 13578.0000 NPHI 1375..6875 GR '13500.0000 NPHI 1214.6875 GR 13400.0000 NPHI 1687.6875 GR 40.9668 NRAT 50.3867 RNRA 38.0859 NRA'T 39.1055 RNRA 18.2617 NRAT 22.0205 RNRA 3-8850 FCNL 4"0984 TE~NS 3.7327 FCN:L 4'0437 TENS 2'6409 FCNL 3.0862 TENS 335.6406 3505°5000 300 . 1406 5767.2500 546.8125 5727.25,00 LVP OlO.H02 VERIFICATION LISTING PAGE 15 DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCN:L DEPT NCNL 13300.0000 NPHI 1549.6875 GR 13200.0000 NPHI 1359.6875 GR 13100.0000 NPHI 1578.6875 GR 13000.0000 NPHI 1515.6875 GR 12900.0000 NPHI 1174.6875 GR 12800.0000 NPHI 1115.6875 GR 12700.0000 NPHI 1171.6875 GR 12600.0000 NPHI 1212.6875 GR 12500.0000 NPHI 1163.6875 GR 12400.0000 NPHI 1203.6875 GR 12300.0000 NPHI 1284.6875 GR 12200.0000 NPHI 1212.6875 GR 12100.0000 NPHI 1289.6875 GR 12000'0000 NPHI 1205'6875 GR 11900.0000 NPHI 1300o6875 GR 11800.0000 NPHI 1384.6875 GR 11700,0000 NPHI 1177.6875 GR 11600.0000 NPHI 1268.6875 GR 13.8672 13.1895 25.7813 20.3486 18.4082 18.5361 18.7988 32.9180 53.6133 136.8125 47.5586 71.8398 48.9746 46.6992 47.2168 66.0898 45.9473' 86.7773 38.8184 51.9180 44. 9805 41.8945 53. I992 26.6602 43. 5430 30. 5664 53.2930 44.2383 45. 2617 35.6934 46.9180 45.6543 48. 355:5 43. 1641 48.0117 NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT R N R A NRAT RNRA NRAT RNRA NR AT RNRA NRAT RNRA NR'AT RNRA NRAT RNRA NRAT RNRA 2.3499 2.4729 3.0784 3.2209 2.6487 2.7288 2.6760 2.8518 4.5554 5.3562 4.2351 4.3132 4.3093 .4.1609 4.2156 5.0007 4.1492 4.6257 3.7698 3.7014 3.0920 3.1584 3.9338 4.5007 3.1272 3.2893 3.3342 3.2170 4.0593 4.7039 3.6038 4.0437 4'1335 4.2312 .4.0007 4.1062 FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS 626.3125 5727.2500 421.8906 5687.2500 578.3125 5575.2500 531.3125 5563.2500 219.1875 5467.2500 258.6406 5391.2500 281.3906 5327.2500 242.4375 5247.2500 251.4375 5155.2500 325.1406 5131.2500 406.6406 5035.2500 269.3906 5007.2500 391.8906 4943.2500 374.6406 4983.2500 276.3906 4895.2500 342.1406 4907.2500 ,278.1406 4871.2500 308.8906 4843.2500 LVP OlO.HO2 VERIFICATION LISTING PAGE 16 DEPT NCNL DEPT NCNL OEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL D E PT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL DEPT NCNL 11500.0000 NPHI 1200.6875 GR 11400.0000 NPHI 1167.6875 GR 11300.0000 NPHI 1130.6875 GR 11200.0000 NPHI 1033.6875 GR 11100.0000 NPHI 1133.6875 GR 11000.0000 NPHI 1164.6875 GR 10900.0000 NPHI 1265.6875 GR 10800.0000 NPHI 1097.6875 GR 10700.0000 NPHI 1152.6875 GR 10600.0000 NPHI 1122.6875 GR 10500.0000 NPHI 1205.687,5 GR 10400.0000 NPHI 1097.6875 GE 10300.0000 NPHI 1162.6875 GR 10200.0000 NPHI 1121.6875 GR 10100'0000 NPHI 1430.6875 GR 10000.0000 NPHI 1388.6875 GR 9900.0000 NPHI 1219.6875 GE 9800.0000 NPHI 1365.6875 GR 40.5273 40.5742 37.8906 49.2930 42.4316 57.5742 38.0371 57.1992 37.7441 54.3242 43.0664 54.0430 37.0605 58.7930 39.1602 56.2305 35.8398 46.8867 50.8789 43.3867 45.8984 46.7617 47.7051 33.2930 34.5215 29.5830 53.1250 46.4492 38.5254 33.4492 30.2734 28'1611 37.5488 16.5049 27.5879 33.3867 NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNR~ NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA 3.8616 3.9436 3.7209 3.6311 3.9631 3.5256 3.7288 3.8108 3.7131 3.5256 3.9944 3.8323 3.6780 3.7483 3.7893 3.6116 3.6135 3.6643 4.4109 4.5671 4.1453 4.5984 4.2429 4.3328 3.5432 3.6311 4.5281 5,7468 3.7542 3.8245 3.3167 3.2581 3-7034 4.2078 3.1741 3.0725 FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FC:NL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS 304.3906 4847.2500 321.3906 4743.2500 320.6406 4655.2500 271.1406 4647.2500 321.3906 4607.2500 303.8906 4587.2500 337.6406 45.15.2500 303.8906 4487.2500 314.3906 4487.2500 245.56.25 4403.2500 262.1406 4447.2500 253.1.875 4343.2500 320.1406 4311.2500 195.0625 4295.2500 373.89~06 4255.2500 426.1406 4155.2500 289'6406 4147. 2500 444.3906 4175.2500 LVP OlO.H02 VERIFICA'TION LISTING PAGE DEPT 9700.0000 NPHI NCNL 1412.6875 GR DEPT 9600.0000 NPHI NCNL 1301.6875 GR DEPT 9500.0000 NPHI NCNL 1283.6875 GR DEPT 9400.0000 NPHI NCNL 1222.6875 GR DEPT 9300.0000 NPHI NCNL 1365.6875 GR DEPT 9200.0000 NPHI NCNL 1119.6875 GR DEPT 9100.0000 NPHI NCNL 1218.6875 GR DEPT 9000.0000 NPHI NCNL 1067.68T5 GR DEPT 8900.0000 NPHI NCNL 1365.6875 GR DEPT 8800.0000 NPHI NCNL 1288.6875 GR DEPT 8700.0000 NPHI NCNL 1017.8125 GR DEPT 8600.0000 NPHI :N'CNL 1166.6875 GR DEPT 8500.0000 NPHI NCNL 1168.6875 G'R DEPT 8400.0000 NPHI NCNL 1199.6875 GR DEPT 8300°0000 NPHI NCNL 1182.6875 GR DEPT 8200.0000 NPHI NCNL 1267.6875 GR DEPT 8100.0000 NPHI NCNL 1415.6875 GR DEPT 8000.0000 NPHI NCNL 1264.6875 GR 30.1270 36.6055 38.0371 34.5430 34.1797 28.2705 34.6191 20.7080 46.9727 30.5674 42.6758 22.6611 40.9668 16.6924 44.0430 45.1055 43.5059 37.3242 44.3359 34.4492 38.0859 38.4492 39.3066 35.2930 41.4551 44.1680 50.0000 33.7617 36.9141 25.0674 44.4824 38.8242 41.2598 30.0361 40.8203 38.8242 NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT R'NRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA 3.3108 3.5374 3.7288 4.3132 3.5237 4.0476 3.5491 3.5002 4.2039 4.3015 3.9749 3.7756 3.8831 3.7014 4.0476 4.6414 ,4.0203 4.7781 4.0632 4.2625 3.7307 3.5530 3.7952 4.7312 3.9104 4.7312 4.3640 4.2937 3.6682 3.5979 4.0710 4-2742 3.9006 4.3015 3.8752 3.8479 FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FC:NL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS 399.1406 4081.5000 301.6406 4021.5000 316.8906 4081.5000 349.1406 4005.5000 31T.3906 3945.5000 296.3906 3745.5000 329.1406 3665.5000 229.9375 3695.5000 285.6406 3691.5000 302.1406 3615.51000 286.3906 3631.5000 246.4375 3605.5000 246.9375 3551.:5000 279.3906 3575.5000 328.6406 3545'5000 296.3906 3555-5000 329.1406 3501.5000 328.6406 3471'5000 LVP 010.H02 VERIFICATION LISTING PAGE 18 DEPT 7900.0000 NPHI NCNL 1191.6875 GR DEPT 7800.0000 NPHI NCNL '1205.6875 GR DEPT 7700.0000 NPHI NCNL 1211.6875 GR OEPT 7600.0000 NPHI NCNL 1037.6875 GR DEPT 7500.0000 NPHI NCNL 1242.6875 GR DEPT 7400.0000 NPHI NCNL 1349.6875 GR DEPT 7300.0000 NPHI NCNL 1174.6875 GR DEPT 7200.0000 NPHI NCNL 1021.3125 GR DEPT 7100.0000 NPHI NCNL 1208.6875 GR DEPT 7000°0000 NPHI NCNL 1023.3125 GR DEPT 6900.0000 NPHI NCNL 11.91.6875 GR DEPT 6800'0000 NPHI 'NCNL I262-6875 G'R DEPT 6700.0000 NPHI NCNL 1310.6875 GR DEPT 6600.0000 NPHI NCNL 1157.6875 GR DEPT 65.00.0000 NPHI NCNL 1070.6875 GR DEPT 6400.0000 NPHI NCNL 1200.6875 GR DEPT 6300.0000 NPHI N~CNL 1286.6875 GR DEPT 6200.0000 NPHI NCNL 1130.6875 GR 41.2598 53.6367 37.0117 45.6992 41.2598 31.8643 59.4238 44.3555 42.2852 25.6455 39.1602 36.9805 45.7520 25.1611 55..3711 45.2305 40.0391 21.4736 61.4258 43.7930 46.1914 50.3555 56.2988 27.0674 35.3027 33.2930 45.9473 44.1992 42.7734 41.9180 44.8730 18.2080 56.5918 43.9492 46.3379 43.6992 NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NEAT RNRA NRAT RNRA NR'AT RNRA NRAT RNRA NRAT RNRA NRAT RNRA NEAT ENRA NEAT ENRA NEAT RNRA NEAT RNRA NEAT RNRA NRAT RNRA NEAT RNRA 3.9006 4.6648 3.6741 3.7366 3.9006 3.9436 4.8640 4.5007 3.9553 3.8420 3.7874 4.0984 4.1375 4.9265 4.6492 5.4539 3.8342 3.9436 4.9695 6.0007 4.1609 4.6648 4.6960 6.1648 3.5842 3.3479 4.1492 4. 5320 3.9807 3.9358 4.0906 ,4.2468 4.7117 5.2117 4.1687 4.0007 FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS 255.3125 3511.5000 322.6406 3381.5000 307.1406 3405.5'000 230.4375 3351.5000 323.3906 3391.5000 329.1406 3265.5000 238.3125 3261.5000 187.1875 3305.5000 306.3906 3201.5000 170.5625 3211.5000 255.3125 3165.5000 204.6875 3145.5000 391.3906 31~05.5000 255.3125 3075.5000 271.8906 30,05.5000 282.6406 3005.5000 246.6875 2981.5000 282.6406 2951.5000 LVP OlO.H02 VERIFICATION LISTING PAGE 19 DEPT 6100.0000 NPHI NCNL 1236.6875 GR DEPT 6000.0000 NPHI NCNL 1116.6875 GR DEPT 5900.0000 NPHI NCNL 1165.6875 GR DEPT 5800.0000 NPHI NCNL 1229.6875 GR DEPT 5700.0000 NPHI NCNL 1079.6875 GR DEPT 5600.0000 NPHI NCNL 1122.6875 GR DEPT 5500.0000 NPHI NCNL 1165.6875 GR DEPT 5400.0000 NPHI NCNL 1150.6875 GR DEPT 5300.0000 NPHI NCNL 1026.6875 GR DEPT 5200.0000 NPHI NCNL 1098.6875 GR DEPT 5114.0000 NPHI NCNL 1100.6875 GR ':~* FILE TRAILER ** FILE NAME :EDIT. .003 SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : NEXT FILE NAME : ~:~ FILE HEADER ~, FILE NAME :EDIT .004 SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : 48.0957 NRAT 39.6055 RNRA 41.2109 NRAT 30.4424 RNRA 51.7578 NRAT 33.3867 RNRA 56.2988 NRAT 27.1768 RNRA 37.5488 NRAT 38.4492 RNRA 39.2578 NRAT 35.9805 RNRA 54.7852 NRAT 34.4805 RNRA 43.5059 NRAT 40.1055 RNRA 50.9766 NRAT 21.8174 RNRA 49.7070 NRAT 24.9580 RNRA 43.2129 NRAT 19.6299 RNRA EOF ~****~ 4.2625 4.6687 3.8967 4.0632 4.4578 4.7117 4.6960 5.1531 3.7034 4.0671 3.7932 3.3772 4.6179 4.7117 4.0203 5.0007 4.4148 5.2703 4.3484 4.6140 4,0046 4.2820 FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS FCNL TENS 264.8906 2905.5000 274.6406 2831.5000 247.1875 2775.5000 238,5625 2745.5000 265.3906 2735.5000 332.3906 2731.5000 247.1875 2665.5000 230.0625 2655.5000 194.6875 2575.5000 237.9375 2495.5000 256.8906 2551.5000 LVP OIO.H02 VERIFICATION LISTING PAGE 20 PREVIOUS FILE : · ~ COMMENTS ~ °,- -,- MAIN LOGS ~--,- o,--~, ~- ~-~-~-~-~- THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDED IN THIS FILE: HTEN.CHL · ~ DATA FORMAT RECORD ~ ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 ~ 66 0 4 1 66 1 8 4 73' 5 9 ~ 65 .lIN 16 I 66 1 0 1 66 0 D~TUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT AP.I API API API FILE SIZE SPL REPR PROCESS LVP 010.H02 VERIFICATION LISTING PAGE 21 ID ORDER ~ LOG TYPE DEPT FT O0 000 HTEN CHL LB O0 000 CLASS O0 O0 · ~ DATA ~ OEPT 13578.4570 HTEN 814.3125 OEPT 13500.2910 HTEN 1143.6875 DEPT 13400.2910 HTEN 1144.6875 DEPT 13300.2910 HTEN 1150.6875 DEPT 13200o2910 HTEN 1136.6875 DEPT 13100.2910 HTEN 1129.6875 DEPT 13000.2910 HTEN 1155.6875 DEPT 12900.2910 HTEN 1151.6875 DEPT 12800.2910 HTEN 1122.6875 DEPT 12700.2910 HTEN 1140.6875 DEPT 12600.2910 HTEN 1112.6875 DEPT 12500.2910 HTE:N 1085.6875 DEPT 12400.2910 HTEN 1086.6875 DEPT 12300.2910 HTEN 1088.6875 DEPT 12200o2910 HTEN I074'68'75 DEPT 12100.2910 HTEN 1075o6875 DEPT 12000.2910 HTEN 1075.6875 DEPT 11900.2910 HTEN 1075.6875 DEPT 11800.2910 HTEN 1062.6875 DEPT 11'700.2910 HTEN 1055.6875 DEPT 11600.2910 HTEN 1068'6875 DEPT 11500.2910 HTEN 1092.6875 DEPT 11400.2910 HTEN 1063.6875 DEPT 11300.2910 HTEN 1045.6875 MDD 0 0 NO. 0 0 CDDE (DCTAL) 1 68 00000000000000 I 68 O000OO00000000 LVP OlO.H02 VERIFICATION LISTING PAGE 22 DEPT 11200.2910 HTEN DEPT 11100.2910 HTEN DEPT 11000.2910 HTEN DEPT 10900.2910 HTEN DEPT 10800.2910 HTEN DEPT 10700.2910 HTEN DEPT 10600.2910 HTEN DEPT 10500.2910 HTEN OEPT 10400.2910 HTEN DEPT 1.0300,2910 HTEN DEPT 10200.2910 HTEN DEPT 10100.2910 HTEN DEPT 10000.2910 HTEN DEPT 9900.2910 HTEN DEPT 9800,2910 HTEN DEPT 9700,2910 HTEN DEPT 9600.2910 HTEN DEPT 9500-2910 MTEN DEPT 9400.2910 HTEN DEPT 9300.2910 HTEN DEPT 9200,2'910 HTEN DEPT 9100-2910 HTEN DEPT 9000.2910 HTEN DEP'T 8900'2910 HTEN DEPT 8800.2910 HTEN 3EPT 8700.2910 HTEN 3EPT 8600.,2910 HTEN 1050, 1048, 1039. 1031, 1021. 1032, 1035, 1047. 1031. 1033, 1034. 1045. 1023, 1039, 1026. 1046. 1040. I 045. 1045. 1009. 979. 937. 949. 957. 959. 957. 947. 6875 6875 6875 6875 3125 6875 6875 6875 6875 6875 6875 6875 8125 6875 6875 6875 6875 6875 6875 8125 8125 8125 3125 3125 8125 3125 8125 LVP OlO.HO2 VERIFICATION LISTIN~ PAGE 23 OEPT 8500.2910 HTEN 969. DEPT 8400.2910 HTEN 985. DEPT 8300.2910 HTEN 986. DEPT 8200.2910 HTEN 994. DEPT 8100.2910 HTEN 987. DEPT 8000.2910 HTEN 983. DEPT 7900.2910 HTEN 1022. DEPT 7800.2910 HTEN 986. DEPT 7700.2910 HTEN 994. DEPT 7600.2910 HTEN 981. OEPT 7500.2910 HTEN 1028. DEPT 7400.2910 HTEN 991. DEPT 7300.2910 HTEN 993. DEPT 7200.2910 HTEN 1027. DEPT 7100.2910 HTEN 1010.. DEPT 7000.2910 HTEN 1028. DEPT 6900.2910 HTEN 1023. DEPT 6800'2910 HTEN 1044. DEPT 6700.2910 HTEN 1029. DEPT 6600-2910 HTEN 1038. DEPT 6500.2910 HTEN 1013. DEPT 6400.2910 HTEN 1038. DEPT 6300.2910 HTEN 1036. DEPT 6200.2910 HTEN 1033. DEPT 6100.2910 HTEN 1013. DEPT 6000.2910 HTEN 1022. OEPT 5900.2910 HTEN 1028. 8125 3125 3125 8125 3125 8125 8125 ,8125 3125 8125 6875 8125 3125 6875 3125 6875 3125 6875 6875 6875 3125 6875 6875 6875 3125 3125 6875 LVP 010.H02 VERIFICATION LISTING PAGE 24 DEPT 5800.2910 HTEN DEPT 5700o2910 HTEN DEPT 5600.2910 HTEN DEPT 5500.2910 HTEN DEPT $400°2910 HTEN DEPT 5300.2910 HTEN DEPT 5200°2910 HTEN DEPT 5113.9990 HTEN 1030.6875 1012.8125 1029.6875 1011°8125 1006,3125 1010o8125 990.3125 99~°3125 ~ FILE TRAILER~-'"'~.- FILE NAME :EDIT °004 SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE' : NEXT FILE NAME : ~ FILE HEADER FILE NAME :EDIT .005 SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE COMMENTS MAIN LOGS ~**~ THIS DATA HAS BEEN DEPTH SHIFTED **~** BASE LOG: DLL '~~ LVP OIO.H02 VERIFICATION LISTING PAGE 25 SCHLUMBERGER LOGS INCLUDED IN TMIS FILE: ~' HTENoDLL = · HTEN.LDT ~ ~ ~.. HTEN. CNL ~ ~ HTENoNGT · ~ HTEN.EPT ~ ~ DATA FORMAT RECORD *~ ENTRY BLOCKS TYPE SIZE REPR CaDE ENTRY 2 1 66 0 4 1 66 1 8 4 73 5 9 ~ 65 .~IN 16 I 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT AP1 AP1 AP1 API FILE SIZE SPL REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NO. CODE (OClTAL) DEPT FT O0 000 O0 0 0 4 1 68 00000000000000 HTEN DiLL L8 O0 000 O0 0 0 4 1 68 O00000000OO000 HTEN LOT LB. O0 000 O0 0 0 4 [ 68 O~O00OOOOO, O00OO HTEN CNL LB O0 000 O0 0 0 4 i 68 00000000'000000 HTEN NGT LB O0 000 O0 0 0 4 i 68 00000000000000 HTEN EPT L8 O0 000 O0 0 0 4 I 68 00000000000000 LVP 010.H02 VERIFICATION LISTING PAGE 26 DATA DEPT HTEN 14247.4570 -999.2500 14200.2910 1068.6875 14100.2910 1062.6875 14000.2910 1070.6875 13900.2910 1110.6875 13800.2910 1041.6875 13700.2910 992.8125 13600.2910 1055.6875 13500.2910 950.3125 '13400.2910 942.3125 13376.0410 -999-2500 DEPT HTEN DEPT HTEN DEPT HTEN DEPT HTEN DEPT HTEN DEPT HTEN DEPT MTEN DEPT HTEN DEPT HTEN DEPT HTEN ~ FILE TRAILER FILE NAME :EDIT SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : FILE TYPE NEXT FILE NAME : HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN MTEN MTEN -999.2500 -999.2500 1068.6875 1316.6875 1062.6875 1395.6875 1070.6875 1255.6875 1110.6875 1375.6875 1041.6875 1282.6875 992.8125 1300.6875 1055.6875 1260.6875 950.3125 -999.2500 942.3125 -999.2500 -999.2500 -999.2500 HTEN HTEN HTEN HTEN HTEN HTEN HTEN H TEN HT EN HTEN HTEN .005 1:024 -999.2500 1316.6875 1395.6875 1348.6875 1315.6875 1290.6875 1310.6875 1260.6875 -999.2500 -999.2500 -999.2500 HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN -999.2500 1339.6875 1314.6875 1286.6875 1375.6875 1264.6875 1310.6875 1260.6875 '-999.2500 -999.2500 -999.2500 $$ FILE HEADER $$ FILE NAME :EDIT SERVICE NAME : VERSION ~ : .006 LVP OlO.H02 VERIFICATION LISTING PAGE Z7 DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : ~- COMMENTS ~"~ MAIN LOGS THIS DATA HAS BEEN DEPTH SHIFTED BASE LOG: DLL SCHLUMBERGER LOGS INCLUDED IN THIS FILE: ELECTROMAGNETIC PROPAGATION TOOL (EPT) SAMPLED AT o12" RATE · = DATA FORMAT' RECORD ~i ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 i 66 0 LVP 010.H02 VERIFICATION LISTING PAGE 28 'DATUM MNEM 4 8 9 16 0 SPECIFICATION BLO SERVICE SERVICE U ID OROER # DEPT F TPL EPT N EATT EPT O EPHI EPT P FVD EPT V FVU EPT V NVD EPT V NVU EPT V T S/M B/M U 66 73 65 66 66 CKS NIT API API API API FILE LOG TYPE CLASS MOD ND. O0 000 O0 0 0 O0 132 O1 0 0 O0 130 01 0 0 O0 890 O0 0 0 O0 000 O0 0 0 O0 000 O0 0 0 O0 000 O0 0 0 O0 000 O0 0 0 1 20 .liN 1 0 SIZE SPL 4 1 4 1 4 4 1 4 4 4 1 4 REPR PROCESS CODE (OCTAL) 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 DATA DEPT FVD 14247.3320 TPL -999.2500 FVU 14200.1660 TPL 0.2964 FVU 14100.1660 'TPL 0.3652 FVU 14000.1660 ?PL 0.5181 FVU 13900.1660 TPL 0.8643 FVU 13800'1660 TPL 0.3892 FVU 13700.1660 TPL 0.8955 FVU 13600.1660 TPL -0.5273 FVU 13500.1660 TPL '-999.2500 FVU 13400.1660 TPL -999.2500 FVU 13376.0000 TPL -ggg.2500 FVU DEPT FVD DEPT FVD DEPT FVD DEPT FVD DEPT FVD D E P T FVD DEPT FVD DEPT FVD OEPT FVD DEPT FVD -999.2500 -999.2500 9.7676 0.2827 12.0801 0.3896 11.6426 O. 4404 9.6426 0.6172 9.5176 0.3511 11.0801 0'6528 12.9551 -0.5269 -999.2500 -999.250'0 -999.2500 -999.2500 -999.2500 -999.2500 EATT NVD EATT NVD EAT'T NVD EATT NVD EATT NVD EATT NVD EATT N'V'D EATT NVD EATT NVD EATT EATT NVD -999.2500 EPHI -999.2500 -999.2500 NVU -999.2500 72.6523 EPHI 3.7109 0.6460 N¥'U 0.7578 182.3125 EPHI 15.7715 0.8696 NVU 0.6968 195.3125 EPHI 12.9883 1.5850 NVU 1.2676 59.2617 EPHI 3.0273 1.8008 NVU 1.9932 61.:0742 EPHi 2.3438 · 0.7642 NVU 0o7251 294.6406 EPHi 6.7871 2.4690 NVU 1.9405 0.1504 EPHI 21.6309 -0.5269 NVU -0.5269 -999-2500 EPHI -999.2500 -999.2500 NVU -999.2500 -999.2500 EPHI -999.2500 -999.2500 NVU -999.2500 -999.2500 EPHI -999-2500 -999.2500 NVU ,-999.2500 LVP 010.H02 VERIFICATION LISTING PAGE 29 =~ FILE TRAILER ~= FILE NAME :EDIT .006 SERVICE NAME : VERSION e : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : NEXT FILE NAME : · ~ FILE HEADER ~ FILE NAME :EDIT .007 SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : COMMENTS * SCHLUMBERGER , ~ ALASKA COMPUTING CENTER ~ COMPANY = ARCO ALASKA INC WELL = LGI-iO FIELD = PRUDHOE BAY/LISBURNE FIELD COUNTY = NORTH SLOPE BORDUGH STATE = ALASKA !$UR'FACE LOCATION = li29' FNL ~& 1680°FEL, SEC l, TZINt R14E LVP OlO.M02 VERIFICATION LISTING PAGE JOB NUMBER AT ACC: 71614 RUN ~1~ DATE LOGGED: 23-JUL-86 LOP: L. B. CUDNEY API SERIAL NO: 5002921573 PERMANENT DATUM: MSL ELEV OF PERM. DATUM: 0.0 F LOG MEASURED FROM: RKB DRLG MEASUREO FROM: RKB ELEVATIONS: KB: 52.0 F DF: 51.0 F GL: 13.0 F DEPTH-DRILLER = 14216 F DEPTH-LOGGER = 14225 F BTM. LOG INTERVAL= 14210 F TOP LOG INTERVAL= 5300 F CASING-DRILLER CASING-LOGGER CASING WEIGHT BIT SIZE DEPTH = 13581 F = 13586 F = g.625 " 47.0 LB/F = 8.5 = 14,216 F TYPE FLUID = BALANCED SALINITY SOURCE OF SAMPLE = CIRCULATED DENSITY = 9.30 LB/G RM = 2.170 @ 71.0 DF VISCOSITY = 40.0 S RMF = 1.560 @ 70.0 DF PH : 10.9 RMC = 2.890 @ 64.0 DF FLUID LOSS : 9.6 C3 SOURCE RMF/RMC = MEAS/MEAS TIME CIRC STOPPED= 0630 (7-23) RM AT BHT = 1.058 @ 153. DF TIME :LOGGER ON BTM.= 1313 (7-23) RMF AT BHT = .751 @ 153. DF MAX REC. TEMP. = 153.0 DF RMC AT BHT = 1.282 @ 153. OF LOGGING UNIT NO: 8266 LOGGING UNIT LOC: PRUDHDE BAY FIELD ENGINEER: RUBENSTEIN LVP 010.H02 VERIFICATION LISTING PAGE WITTNESSED BY: PRZYBYSZEWSKI MATRIX : LIMESTONE MDEN : 2.71 G/C3 DHC : NONE HC : CALI FLUID DENSITY = 1.0 GM/C3 REMARKS: 1.5" STANDOFFS USED ON DLL. 30000 PPM CHLORIDES. TARGET LOCATION: 1100'FSL [ IO0'FEL 30-12N-15E. MAXIMUM DEVIATION : 61 DEG AT 5800 FT. NGT TELEMETRY SPIKES AT 13926' [ 13850' ON REPEAT DID NOT OCCUR ON MAIN PASS. LOGGED NGT THROUGH CASING UNTIL A COBALT MARKER WAS LOCATED AT 13~07 FT. EQUIPMENT NUMBERS: DLE E 789 NGC H 1905 AMM A 870 DLH CB 2725 NGD B 7~6 TCM AB 95 AH 169 722 GPIC A 718 LCM 799 DLS F 754 TCC A 123 ALL INTERPRETATIONS ARE OPINIONS BASED ON INFERENCES FROM ELECTRICAL OR OTHER MEASUREMENTS AND WE CANNOT~ AND DO NOT GUARANTEE THE ACCURACY OR CORRECTNESS OF ANY INTERPRETATIONS~ AND WE SHALL NOT~ EXCEPT IN THE CASE OF GROSS OR WILLFUL NEGLIGENCE ON OUR PART, BE LIABLE OR RESPONSIBLE FOR ANY LOSS, COSTS, DAMAGES OR EXPENSES INCURRED OR SUSTAINED BY ANYONE RESULTING FROM ANY INTERPRETATION MADE BY ANY OF OUR OFFICERS~ AGENTS~ OR EMPLOYEES. THESE INTERPRETATIONS ARE ALSO SUBJECT TO OUR GENERAL TERMS AND COMDITIDNS LVP OlO.H02 VERIFICATION LISTING PAGE 32 AS SET OUT IN OUR CURRENT PRICE SCHEDULE. REPEAT LOGS THIS DATA HAS BEEN DEPTH SHIFTED BASE LOG: DLL SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: DUAL LATERLOG CDLR) LITHO DENSITY COMPENSATED LOG CLDR) COMPENSATED NEUTRON LOG (CNR) ELECTROMAGNETIC PROPAGATION TOOL NATURAL GAMMA TOOL (NGR) GPIT (DIRECTIONAL DATA~ GPR) LVP OlO.H02 VERIFICATION LISTING PAGE 33 '~*-.~. DATA FORMAT RECORD.."~. ENTRY BLOCKS TYPE 2 4 8 ].6 0 DATUM MNEM DEPT LLS LLD SGR SP SVO SIO DVO DIO MRES MTEM TENS NRAT RNRA NPMI NCNL FCNL GR TENS MRES MTEM GR CALI RHOB DRHO DPHI PEF LL LU LS LITH SS1 SS2 ~SS QLS TENS MRES MTEM SGR CGR SPECIFICATION BLOCKS SERVICE SERVICE UNIT API ID ORDER # LOG FT O0 DLR OHMM O0 DLR OHMM O0 DLR GAPI O0 DLR MV O0 DLR MV O0 DLR UA O0 DLR MV O0 DLR UA O0 DLR OHMM O0 DLR DEGF O0 DLR LB O0 CNR O0 CNR O0 CNR pU O0 CNR CPS O0 CNR CPS O0 CNR GAPI O0 CNR LB ~00 CNR OHMM O0 CNR DEGF O0 lOR GAPI O0 LDR IN O0 LDR G/C3 O0 LDR G/C21 00 LDR PU O0 LDR O0 LDR CPS O0 LDR CPS O0 LOR CPS O0 LDR CPS O0 LDR CPS O0 LDR CPS O0 LDR O0 LDR O0 LDR LB O0 LDR OHMM O0 LOR DEGF O0 NGR GAPI O0 NGR G~PI O0 SIZE 1 ! 4 ]. ! AP1 TYPE 000 220 220 310 010 000 O00 000 000 823 660 635 42O 000 8'90 330 2130 310 635 66 2110 3~6 890 2154 000 O0 0 O0 0 000 6 3 5 660 2110 310 A CL REPR PI API ASS MOD O0 0 og 0 10 0 O1 0 O1 0 O0 0 O0 0 O0 0 O0 0 50 0 50 0 21 0 01 0 O0 0 O0 0 3'1 0 30 0 01 0 21 0 ~0 0 50 0 01 0 01 0 02 0 01 0 O0 0 01 0 01 0 01 0 01 0 01 0 O0 0 O0 0 O0 0 O0 0 21 0 50 0 50 0 01 0 01 0 CODE 66 66 73 65 66 66 FIL NO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .0 0 ENTRY 0 1 60 .lIN 1 0 SIZE SPL REP COD 4 I 68 4 I 68 4 I 68 4 I 68 4 I 68 4 1 68 4 1 68 4 I 68 4 I 68 4 I 68 4 i 68 4 i 68 4 I 68 4 I 68 4 I 68 4 I 68 4 1 68 4 I 68 4 1~ 68 4 I 68 4 '1 68 4 1 68 4 I 68 4 1 68 4 I 68 4 I 68 4 i 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 I 68 4 1 68 4 1 68 4 1 68 4 t 68 4 1 68' R PROCESS E (OCTAL) 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00~000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00.000000000.000 00000000,0000~00 00000000:0000'00 0000000000,0000 00000000000000 00:00000000'0000 00000000000000 00000000000000 00000000000000 ':0000000000.0000 00000000000000 00000000000000 00000000000000 '00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00~000000000000 00,000000000000 00000000000000 00000000000000 LVP OlO.H02 VERIFICATION LISTING PAGE 34 POTA NGR PU O0 THOR NGR PPM O0 URAN NGR PPM O0 WING NGR CPS O0 W2NG NGR CPS O0 W3NG NGR CPS O0 W4NG NGR CPS O0 WENG NGR CPS O0 MRES NGR ~ OHMM O0 MTEM NGR DEGF O0 TENS NGR LB O0 GR EPR GAPI O0 CALI EPR IN O0 MRES EPR OHMM O0 MTEM EPR DEGF O0 TENS EPR LB O0 AZIM GPR DEG O0 DEVI GPR DEG O0 RB GPR DEG O0 719 790 792 310 310 310 310 310 823 660 635 310 280 823 660 635 630 620 631 DATA DEPT 14247.0000 LLS SP -999.2500 SVO 010 -999.2500 MRES NRA'T -999.2500 RNRA FCNL -999.2500 GR MTEM -999.2500 GR DRHO -999.2500 DPMI LU -999.2500 LS SS2 -999.2500 QSS MRES -999.2500 MTEM POTA -999°2500 THOR W2NG -999.2500 W3NG MRES -999'2500 MTEM 'CALI 8.5020 MRES AZIM -999.2500 DEVI -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 '-999..2500 -999.2500 -999.2500 -999- 2500 -99'9. 2500 O. 0684 -999.2500 DEPT 14200.0000 LLS SP 78.2148 SVO DIO 460.3906 MRES NRAT 3.0100 RNR'A FCNL 520'3125 GR MTEM 158.8125 GR DRHO 0.0532 DPHI ~LU 261-6406 LS SS2 311'1406 QSS MRES 0.0684 MTEM POTA 0.3418 THOR W2NG 33.6055 W3NG MRES 0.0752 MT.EM CALI 9.2363 MRES AZIM 41.5742 DEVi 7.4183 3.2620 0.0752 3.2756 25.4893 25.4893 9.4238 270.1406 0.0269 158.8125 1.2774 14.7832 150.1'875 :0.0684 39.5117 50 50 50 01 01 01 01 01 50 50 21 01 01 50 50 21 O1 01 01 LLD SI 0 MTEM NP.HI TENS CALI P EF LITH QL S SGR URAN W 4 N G TENS MTEM RB LLD SIO MTEM NPHI 'TENS CALI PEF LITH QLS SGR URAN W~NG TENS MTEM RB 0 4 I 68 0 4 1 68 0 4 I 68 0 4 1 68 0 .4 I 68 0 4 I 68 0 4 i 68 0 4 I 68 0 4 ! 68 0 4 I 68 0 4 I 68 0 4 1 68 0 4 ! 68 0 4 I 68 0 4 I 68 0 6 1 68 0 4 1 68 0 4 I 68 :0 4 1 68 -999.2500 SGR -999.2500 DV0 -999.2500 TENS -999.2500 NCNL -999.2500 MRES -999.2500 RHOB -999.2500 LL -999.2500 SSi -999.2500 TENS -999.2500 CGR -999.2500 WING -999.2500 WENG -999.2500 GR 158.8125 TENS -999.2500 11.5262 SGR 637.8125 DY0 150.1875 TENS 29.0039 NCNL 6927.2500 MRES 9.1270 RHOB 3.3245 LL 69.9648 SS1 -0.0039 TENS 21.317~ CGR 1.4278 W1NG 0.0000 WSNG 6051.2500 GR 158.8125 TENS 76.6523 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000.000000000 00000000000000 00000000000000 00000000000000 00000000000000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2955.5000 21.2598 5.9617 6071.2500 1704.6875 0.0684 2.5471 139.0625 228.9375 6991.2500 10.7910 64.5273 4.0320 25.4893 7135.2500 LVP OlO.H02 VERIFICATION LISTING PAGE 35 DEPT SP DIO NRAT FCNL MTEM DRHO LU SS2 MRES POTA W2NG MRES CALI AZIM DEPT SP DIO NRAT FCNL MTEM DRHD LU SS2 MRES POTA W2NG MRES CALI AZIM D E P T SP OI 0 NRAT FCNL MTEM DRHO LU SS2 MR E S POTA W2NG MRES CALI AZIM DEPT SP DIO NRAT FCNL 14100.0000 LLS 94.3398 SVO 161.3125 MRES 1.2803 RNRA 3133.5000 GR 159.1875 GR 0.0098 DPHI 205.6875 LS 272.6406 QSS 0.0688 MTEM 0.5650 THOR 44.0078 W3NG 0.0752 MTEM 9.1035 MRES 41.1367 DEVI 14000.0000 LLS 116.2773 SVO 72.2148 MRES 2.0081 RNRA 1240.6875 GR 158.0625 GR 0.0132 DPHI 217.1875 LS 271.8906 QSS 0.0698 MTEM 0.1736 THOR 35.5313 W3NG 0.0757 MTEM 9.2520 MRES 41.2617 DEVI 13900.0000 LLS 56.0117 SVO 37'2383 MRES 1.3848 RNRA 2513.5000 GR 156'6875 GR -0'0034 DPHI 220'6875 LS 268.8906 QSS 0'0708 MTEM 0.1519 THOR 18.3203 W3NG 0.0767 MTEM 9.3770 MRES 41.4180 DEVI 13800.0000 LLS 68.9648 SVO 51.5742 MRES 1.7413 RNRA 1790.6875 GR 110.2557 16.9893 0.0752 1.2549 24.7676 24.6836 2.3438 205.0625 0.0225 159.1875 2.0859 13.2031 150.3481 0.0688 40.3867 234.2067 23.5049 0.0757 2.2131 26.3643 26.3643 4. 2969 218.1875 0.0459 158.0625 1.6660 8.9,453 149.4653 0.0698 ~1.6680 583.1562 0767 1.4776 12.9368 12.9368 6.3965 223.68'75 0.0283 156.6875 0.5700 8.3359 148.5625 0.0708 42.7930 303.6064 25.9424 0.0771 1.7774 14.4395 LLD SIO MTEM NPMI TENS CALI PEF LITH QLS SGR URAN W4NG TENS MTEM RB LLD SIO MTEM NPHI TENS PEF LITM QLS SGR URAN W4NG TENS MTEM RB LLD SO M~EM NPHI TENS CALI PEF kITH QLS SGR URAN W4NG TENS MTEM RB LLD SIO MTEM NPHI TENS 116.7903 223.4375 150.3125 3.3691 6863.2500 9.1035 4.6648 38.5742 -0.0127 26.7969 1.3252 1.8301 6491.7500 159.1875 80.0898 402.4608 145.5625 149.5625 13.9648 6515.2500 9.2129 3.2385 46.3867 -0.0117 21.9180 1.7175 3.9077 6414.8125 158.0625 79.1523 1163.8750 81.24~22 148.6736 4.5898 6535.2500 9.3770 4.9304 43.6680 -0.0015 14-3076 1.2949 3.8730 6382,3594 156.6875 81.2148 690.6274 123.9023 148.0625 10.2051 6307.2500 SGR DVO TENS NCNL MRES RHOB LL SS1 TENS CGR WING WSNG GR TENS SGR DVO TENS NCNL MRES RHOB LL SSI TENS CGR WING WSNG GR TENS' SGR DVO TENS NCNL MRES RHOB LL SS1 TENS CGR WING WSNG GR TENS SGR DVO TENS NCNL MRES 26.7969 21.1768 6503.2500 3933.5000 0.0688 2.6682 102.2148 205.0625 7043.2500 17.0313 85.1875 2.0957 24.7676 7043.2500 20.968'7 32.6367 6391.2500 2747.5000 0.0698 2.6350 109.5898 209.3125 6655.2500 9.2734 74.9687 0.6250 26.3643 6515,2500 14.6367 48-6,646 6358'3750 3715.5000 0.0708 2.59:99 113.3398 201.3125 6615.2500 4-7637~ 47.8437 .88'09 I .9368 6615.2500 15.3320 40'0117 6243.25100 3183.5000 0.0723 LVP OlO.H02 VERIFICATION LISTING PAGE 36 MTEM DRHO LU SS2 MRES POTA WZNG MRES CALI AZIM DEPT SP 010 NRAT FCNL MTEM DRHO LU SS2 MRES POTA W2NG MRES CALI AZIM DEPT SP DIO NRAT FCNL MTEM DRHO LU $S2 MRES POTA W2NG MRES CALI AZIM DEPT SP DIO NRAT FCNL MTEM DRHO LU SS2 MRES POTA 155.3125 GR 0.0054 OPHI 273.6406 LS 293.3906 Q$S 0.0723 MTEM 0.2694 THOR 25.5977 W3NG 0.0771 MTEM 9.1191 MRES 41.6680 OEVI 13700.0000 LLS 60.0117 SVO 70.0000 MRES 1.1827 RNRA 3119.5000 GR 154.0625 GR 0.0146 DPHI 201.5625 LS 263.1406 QSS 0.0728 MTEM 0.4883 THOR 62.3242 W3NG 0.0776 MTEM 9.1738 MRES 41.1367 DE¥I 13600.0000 LLS 35.0234 SVO 453.6563 MRES 3.8206 RNRA 367°3906 GR 151.9375 GR 0.0713 DPHI 346.6406 LS 343,3!906 QSS 0°0776 2.5195 THOR 172.3438 W3NG 0.0781 MTEM 14.9629 MRES 36.6367 DEVi 13500.0000 LLS -999.25~00 SVO -999.2500 MRES 3.5706 RNRA 315.6406 GR 151.4375 GR -0.3516 DPHI 221.1875 tS 132.0625 QSS 0.0771 M'TEM -999.2500 THOR 14. 15. 288. O. 155. O. 8. 148 · O. 44, 4395 0391 3906 0415 3125 4111 8516 0563 0723 0117 378.0000 21.0625 0.0776 1.2315 38.0938 38.0938 0.7813 198.5625 0.0493 153.9375 1.2491 21.7549 147.3125 0.0'728 45.1055 4.0961 2.1654 0.0781 3.8440 96. 0361 96.0361 19. 0430 1406 151.8125 10.6582 55.7031 146.0625 0. 0776 45. 6367 -999.2500 '-999.2500 -999.2500 3.840'1 50.6680 50.6680 28.4668 225.0625 -0.0918 151.4375 -999.2500 CALI PEF LITH QLS SGR URAN W4NG TENS MTEM RB LLD SlO MTEM NPHI TENS CALI PEF LITH QLS SGR URAN W4NG TENS MTEM LLD SIO MTEM NPHI T:ENS CALI PEF LiTH QLS SGR URAN W4NG TENS MTEM LLD . SIO MTEM NPMI TEN S CALI :PEF L I TH QLS SGR URAN 9.0723 RHOB 4.7742 LL 59.4805 SS1 0.0205 TENS 16.5977 CGR 1.3995 W1NG 1.0068 WSNG 6231.9062 GR 155.3125 TENS 87.9648 457.0000 SGR 101.5000 DVO 147.3403 TENS 2.0508 NCNL 6255.2500 MRES 9.1504 RHOB 4.7976 LL 37.8867 SS1 -0.0269 TENS 37.9492 CGR 3.4006 WING 0.9888 WSNG 6187.2500 GR 154.0625 TENS 94.4648 9.0029 SGR 766.9219 DVO 146.0625 TENS 37.1582 NCNL 6231.2500 MRES 14.9629 RHOB 3.4788 LL 96.5273 SS1 0.0015 TENS 101.8047 CGR 2.9434 WING 9.9453 W5NG 6177.5000 GR 151'8125 TENS 208.3125 -999.2500 SGR -999.2500 OVO -999.2500 TENS 37.74~1 NCNL 5855'2500 MRES '9.0332 RHOB 21.7080 LL 23.5986 SS1 0.0044 TENS -999.2500 CGR -999.2500 W1NG 2.4514 151.5625 216.5625 6307.2500 6.2871 57.6250 0.5488 14.4395 6467.2500 37.9492 28.9219 6271.2500 3841.5000 0.0728 2.6956 97.8398 206.0625 6347.2500 12.9004 117'.7148 2.9670 38.0938 6163.2500 101.5625 4.5880 6173.75.00 1412.6875 0.0776 2.3831 194~6875 6115'25'00 80.1406 326.0000 11.2187 96.0361 6115.2500' -999.2500 -999.2500 -999.2500 1212.6875' 0.0771 2,2209 114.5273 83.2148 5907.2500 -999.2500 -999.2500 LVP 010.H02 VERIFICATION LISTING PAGE 37 W2NG -999.2500 W3NG MRES -999.2500 MTEM CALI 9.0332 MRES AZIM -999.2500 DEVI DEPT 13400.0000 LLS SP -999.2500 SVO OIO -999.2500 MRES NRAT 2.5042 RNRA FCNL 580.8125 GR MTEM 150.9375 GR DRHO -0.4893 DPHI LU 162.6875 LS SS2 BB.1523 QSS MRES 0.0776 MTEM POTA -999.2500 THOR W2NG -999.2500 W3NG MRES -999.2500 MTEM CALI 8.7910 MRES AZIM -999.2500 DEVI DEPT 13370.5000 LLS SP -999°2500 SVO DIO -999.2500 MRES NRAT -999.2500 RNRA FCNL -999.2500 GR MTEM -999.2500 GR DRHO -999.2500 DPHI LU -999.2500 LS SS2 -999.2500 QSS MRES -999.2500 MTEM POTA -999.2500 THOR W2NG -999.2500 W3NG MRES -999.2500 MTEM CALI -999.2500 MRES AZIM -999.2500 DEVI -999.2500 -999.2500 0.0771 -999.2500 -999.2500 -999.2500 -999.2500 2.8303 15.7754 15.7754 22.8516 160.6875 -0.1260 150.9375 -999.2500 -999.2500 -999.2500 0.0776 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25-00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 W4NG TENS MTEM RB LLD SIO MTEM NPHI TENS CALI PEF LITH QLS SGR URAN W4NG TENS MTEM RB LLD SIO MTEM NPHI TENS C ALI PEF L I TH QL S SGR URAN W4NG TENS M T E M ~* FIiLE TRAI,LER *~ FILE NAME ,:EDIT .007 SERVICE NAME :: VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : NEXT FILE NAME : ~ FILE HEADER ~* FILE NAME :EDIT SERVICE NAME : VERSION # : .008 -999.2500 WENG -999.2500 GR 151.4375 TENS -999.2500 -999.2500 SGR -999.2500 OVO -999.2500 TENS 21.9238 NCNL 5767.2500 MRES 8.7910 RHOB 30.7549 LL 17.8643 SS1 0.0322 TENS -999.2500 CGR -999.2500 WING -999.2500 WENG -999.2500 GR 150.93'75 TENS -999.2500 -999.2500 SGR -999.2500 DVO -999.2500 TENS -999.2500 NCNL -999.2500 MRES -999-2500 RHOB -'999.2500 LL -999.25'00 SS1 -999.2500 TENS -999.2500 CGR -999.2500 W1NG -999.25:00 WSNG -999.2500 GR -999-25,00 TENS -999.25!00 -999.2500 50.6680 5907.2500 -999.2500 -999.2500 -999.2500 1643.6875 0.0776 2.3186 79.2773 57.0430 5847.2500 -999.2500 -999.2500 -999.2500 15.7754 5847.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 '-999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 LVP OIO.H02 VERIFICATION LISTING P4GE 38 DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : ~-~ COMMENTS REPEAT LOGS THIS DATA HAS BEEN DEPTH SHIFTED BASE LOG: DLL SCHLUMBERGER LOGS INCLUDED IN THIS FILE: * HTEN DLR :~ HTENoLDR · HTEN .CNR * HTEN.NGR -~ HTEN.EPR ~ LVP OlO.H02 VERIFICATION LISTING PAGE ~ DATA FORMAT RECORD = ENTRY BLOCKS TYP E SIZE REPR CODE 2 I 66 4 I 66 8 4 73 9 4 65 6 I 66 0 I 66 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT ID ORDER ~ DEPT FT HTEN DLR L~ HTEN LDR L~ HTEN CNR LB HTEN NGR LB HTEN EPR LB DATA DEPT HTEN 14247.4570 -999.2500 14'200.2910 989.3125 14100.2910 1067.6875 14000o2910 1066.6875 13900.2910 1095o6875 13800.2910 1063.6875 13700'2910 1098.6875 13600.2910 1080.6875 13500.2910 -999.2500 13400.2910 -999.2500 DEPT HTEN DEPT HTEN DEPT HTEN DEPT HTEN DEPT HTEN DEPT HTEN DEPT HTEN DEPT HTEN DEPT H~TEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN API API API API FILE LOG TYPE CLASS MOD NO. O0 000 O0 0 0 O0 000 O0 0 0 O0 000 O0 0 0 O0 000 O0 0 0 O0 000 O0 0 0 O0 000 O0 0 0 -999.2500 HTEN 813.3125 1005.8125 HTEN 1454.6875 1057.6875 HTEN 1369.6875 1056o5000 HTEN 1288.6875 1095.6875 HTEN 1329.6875 1055.0000 HTEN 1332.6875 1071.0000 HTEN 1272.6875 1151.3750 HTEN 1317.6875 -999.2500 HTEN 1194.6875 -999.2500 HTEN 1196.6875 ENTRY 0 1 5 .lIN 1 0 SIZE SPL 4 1 4 1 4 4 4 4 -999.2500 1384.6875 1369.6875 1349.6875 1329.6875 1278.6875 1306.6875 1317.6875 1194.6875 1196.6875 REPR PROCESS CODE (OCTAL) 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 HTEN- -999.2500' HTEN 1372.6875 HT'EN 1325.68'75 HTEN 1288.6875 HTEN 1324.6875 HTEN' 1278.6875 HTEN 1286-6875 HTEN 1268.6875 HTEN 1204.6875 HTEN 1199.6875 LVP OlO.HO2 VERIFICATION LISTING PAGE 40 DEPT HTEN 13376.0410 HTEN -999.2500 HTEN -999.2500 HTEN 1204.6875 1204.6875 HTEN -999.2500 -~, FILE TRAILER ~,- FILE NAME :EDIT .008 SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : NEXT FILE NAME : · ~ FILE HEADER ~ FILE NAME :EDIT .009 SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : COMMENTS REPEAT LOGS THIS DA'TA HAS BEEN DEPTH SHIFTED BASE LOG: DLL. SCHLUMBERGER LOGS INCLUDED IN THIS FILE: ELECTROMAGNETIC PROPAGATION TOOL (EPR) SAMPLED AT ..12' RATE LVP OIO.H02 VERIFICATION LISTING PAGE 4i · = DATA FORMAT RECORD ~ ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 I 66 0 4 1 66 1 8 4 73 20 9 4 65 .liN 16 1 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API API API API FILE SIZE SPL REPR ID OROER ~ LOG TYPE CLASS MOD NO. DEPT FT O0 000 O0 0 0 4 TPL EPR NS/M O0 132 01 0 0 4 EATT EPR DB/M O0 130 01 0 0 4 EPHI EPR PU O0 890 O0 0 0 ~ FVD EPR V O0 000 O0 0 0 4 FVU EPR V O0 000 O0 0 0 4 NVD EPR V O0 000 O0 0 0 4 NVU EPR V O0 000 O0 0 0 4 PROCESS CODE (OCTAL) I 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 i00000000000000 i 68 00000000000000 I 68 00000,000000000 i 68 00000000000000 DEPT 14247. 3320 TPL 9. 7051 EATT FVD ~0' 6997 FVU O. 6196 NVD DEPT 14200.1660 TPL 9.9551 EATT FVD 0.3120 FVU 0.2793 NVD DEPT FVD 14100.1660 TPL -0.5283 FVU 12.6426 EATT -0.5283 NVD DEPT 14000'1660 TPL I1.:0801 EATT FVD 0.3457 ~FVU 0.3184 NVD DEPT 13900.1660 TPL 9.7051 EATT FVD 0.2.339 FVU 0.2725 NVD 236.3125 EPHI 1'5899 NVU 77.1523 EPHI 0.5513 NVU 232.3125 EPHI 1.0381 NVU 127,152.3 EPHI 0.6973 NVU 58.0742 EPHI 2.4221 NVU 0.4883 2.03t5 4.7852 0.7520 18.0176 -0.5283 10.7910 0.9829 3.4180 1-1563 LVP OlO.H02 VERIFICATION LISTING PAGE 42 DEPT 13800.1660 TPL FVD 0.3862 FVU DEPT 13700.1660 TPL FVD 0.3657 FVU DEPT 13600.1660 TPL FVD -0.5264 FVU DEPT 13500.1660 TPL FVO -0.5229 FVU DEPT 13400.1660 TPL FVD -0.5229 FVU DEPT 13376.0000 TPL FVD -0.5229 FVU 9.2051 0.3091 8.2676 0.5288 17.0361 -0.5234 14.1426 -0.5215 15.9473 -0.5215 17.6611 -0.5215 EATT NVD EATT NVD EATT NVD EATT NVD EATT NVD EATT NVD ~ FILE TRAILER FILE NAME :EDIT .009 SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH : 1024 FILE TYPE NEXT FILE NAME : ~ TAPE TRAILER SERVICE NAME :EDIT DATE :86/08/13 ORIGIN :716I' TAPE NAME : CONTINUATION # :01 NEXT TAPE NAME COMMENTS :LIBRARY TAPE ~ REEL TRAILER ~ SERVICE NAME :EDIT DATE :86/08/13 ORIGIN : REEL NAME : ZERO CONTINUATION # :01 NEXT REEL NAME : CDMMENTS :LIBRARY TAPE 52.324Z 0.6313 130.3125 0.9302 0.2002 -0.5249 0.1494 -0.5215 0.1494 -0.5215 0.1494 -0.5215 EPHI NVU EPHI NVU EPHI NVU EPHI NVU EPHI NVU EPHI NVU 0.5859 0.5718 -5.3711 0.7090 44.7266 -0.5229 28.3203 -0.5215 38.4766 -0.5215 48.0957 -0.5215 rE, D LIS TAPE VERi;ICaTION LiSTiNG P Pl0.H02 V~RiFiGATZO:'.4 LISTING RVlCE NAME :EDII TE : :~6/07/30 !GIN : ~L N~ME : lf:RO NTINUAT~CN ~ :01 ~VIOUS REEL : MM2NTS :LIBRARY T4P~ T~PF HF~D'ER ::~;:.' RVICE NAME :EDIT TE :86/07/30 iGIN :F31A ~E N~ME : NTiNU~TiON ~ :0i EV!DU$ 'T~P5 : MM~NI3 :Li{R~:Y T,~ FILE LE N~ME RViCE NAME : RSiON ,~ : TE : XiMUM L!~NGTH L~ TYP~ : ~VIOU5 FiLE INFDRMATi]!i .00i : 1024 = .v, - FJ N T S : ARC3 ALASKa, fi,~'~. : LGi-!O : '~RODHO~ S.gY/LiSEURNE NJ: 14 E WN: lin CT: 1 UN: NORTH SLOP~ ~ M C 3 N T =~ ~ P'CL -- UN iT TYP:- 000 000 000 000 C~TE O00 000 000 000 000 000 000 C ~ T E 000 SIZE 006 02 6 0O4 004 OO2 012 .SIZE 001 F & G E 065 055 065 rC2E ',., 065 &L.,~SK.& CCMPUTING CE'iiTE~ ',IPANY : A~.~'~ A~,&SKA iNC LL : LGT-ZO ELD = ~RUr~'4~i. ~ ,,_, ~:AY/LISSURNE FIELD JNTY : NORTd SL~PE AT: : RF~,CE LSCATI:SN = 1129' FNL ~ 1680'FEL~ SEC l~ TZ!N, R14E ~ NUM,~ AT ACC: 7161~ ~. L. ~.. ~U~,N;~Y i S~RiAL_ NO'. 5~0292i~'7~~, ~LEVATIDNS: KB: 52.0 F OF: 51.0 F GL: 13.0 F PTH-DRiLLSR = 14216 PTH-LJGGER = !42'~'5~ L,2G i,NTERVAL 1~ :21 i) LOS iNTERVaL= 5300 C~SiNG-D~iLLER CaS~N L ~ . ~ G- OGGER CgS~, - W~GHT : 13581 F : 13586 : 9.625 " 47.0 ~ OiO.H02 VERIFICATID?i LiSTiNG SiZE : DEPTH = 14216 F FLUig = ~,ALA!",,~CED SALiNiTY SOURCE DF S&MPLE : CIP, CUL,~TED ~SiTY = ~..~r'O L~/G R'~t. = Z.170 ~ 71.0 D~. ~CgSZTY = ~O.O S ~4F : 1.560 ~ 70.0 DF = 10.9 R~aC : 2.890 ~ 54.0 DF LOSS : CiRC STSP~ O= 0630 (7-2~).~ Rm,, ~T. 5HT : 1.058 ;,~ 153. OF LDGGER 3N ,~;TM.: 1313 (7-23) RM¢ AT '~HT = .751 ~ 153. DF REC. TEMP. = 1FD.O OF Rt,!C ~T ~HT = 1.282 ;~ 153. DF $GING UNiT NO: 13255 $G!NG UNiT LOC: :LD ENGINEER' ~' - . FTNESSED E,Y: P~ZY6YSZEW.SKi FR!X = LIME:STSN = 2.71 G/C3 : NONE : C£~Li JID DENSITY = i.O qARKS: 1.$" STANb'"C~:F-S USE3 DN 2Lt, :~0000 PPM CHLORIDES. TAF:]SET L~CATZCN: 30'FSL & iO0'F~.-~L 30-12N-15E. ,.,',!$XI?~U?! ,SEVZ~TZ:"JN = 51 3EG AT .5600 FT. NGT ,..E~',I~TRY SPIKES ,:~7 13925' & 13!5~0' ]N ~.:P-AT L}i3 NOT r~CCU~~' ON MAIN PASS. D 010.HOZ V~Ri~C~yi~N~ L~STiNG~ P~GE 4 SGED NGT THRGdGd C.~Si?.~G UNTIL A COE~ALT !',I.~RKER WAS LOCATED .~T 13407 FT., OLH C.~: 2725 N :,S C~ B TCv, ~ A5 95 &H 169 722 GPiC ~ 71~ LCd, 79 ~"LS,. F 754 TCC A 12'3 iNTERPRETATIONS ~RE CPT?..~'"'ON:S.,. ~ASEO ~...,CN .,.'rNFERENCEc,.., F~,C~,~,, ELECTRIC.~L mR,.... ~ER MEASUREMENTS AND ,4E C'~NNCT~ &ND DO NOT GUARANTE~ THE ACCURACY OR RRECTN~SS CF .&NY iNTERPRi~TATiONS~ ND WE SH~LL NCT,~ EXCF-'PT IN THE CAS= O DSS OR WILLFUL Nf~SLIG~NC~z :3N OUR P~RT, BE LiaBLE OR RESPONSIBLE FOR ANY SS, COSTS, DAM&:$~S SR EXP~NSES iNCUR~qEO :OR SUST~INEO BY ANYONE RESULTING DM ANY tNTERPRET~,TION MAD~ ~Y .ANY OF OUR CFFICERS~ AGENTS, OR EMPLOYEES, ESE INTERPRETATIONS ARE aLSO SUBJECT TO 3UR GSNERaL TERMS ~ND COMDITIONS SET OUT iN OUR CURRENT nRICE SCHEDULE. ........ M A I N L C L, S '" "~ "' ",' ", :;'-¥.$' 'THIS OAT& H,'~,.S NuT XEEN DEPT~ SHIFTED - OVERLAY:3 F~ELD PRINTS ............ -t~ ............................... :',= ;k ;:-. :;= .............. ::.~ .~:: :~;= :;= .~;: .......... ...... ";',~. '" ::~. ............................ -,- -,- ,,,, -,, -,- ,,.. -,- -,- 4', '-',~ -I= -';.~ -I~. ' .................. "' '"' '-1-' -';~. ;',-,' ::-' ;','- P OiO.H02 VERiFiCATI2, i:~ LiSTiNG PAGE 5 ~;-' DUAL LATERLOG (/ILL) ;x LZTfiD~'"'E NS ZT ¥ C-~3M ° E ~! q ~TE,...,., .-, " '"" Lr"i G,.., (LuT)"' .,. · ~;~ C~3.~4PENS&I'iED NEU'TR'3N L~t.].., (CNL) .... ., , ;.., , ---;-: NATUR!,,~L~ G&~M& T,3CL (.~,:GT) .-.;.- ~:-' COMP~ SATED NEUTR3N IN C.~SZ!',J,S (GR -,- H~T (CAL;..P?.~ & ';..;.~E ZONAL -,- (SHI=L.ST ?ASS~ SHZ:ZND P&SS) ',- . . - .-.- GPT) DAT~ FORM,AT TRY EL3CKS Ty~, ,~qiZ~:. ~., qSPq reDE~ ~NTRY 2 1 9 4 65 .lin 15 i 66 0 'I 6 ~ ,- ," ~" ""' N TUM S P,: C I F-~. C~ T ~. ~ EL~.CKS Ef,'t SERVIC- S~RVIC~ UNIT &mZ &PI 2~I APl FiL~, SiZE SPL R~P;: - ' . , ,~ ~ ~ COnE PT S R PROCESS (OCTAL) FT O0 000 OO 0 0 ~ I 58 00000000000000 ~LL ~H¢~:~ O0 220 O~ 0 0 ~ Z 68 30000000000000 3LL 0~'~ ........ 0 ~ i ~ 00000000000000 DLL GAP' CO 310 O1 3 0 4 ! 68 00000000000000 3LL ~,:V 03 01,3 Ol 0 0 ~ 1 6~ O000OO00000000 O~L i'-'~V JO OOS 30 0 0 4 I 6B O00OO000000000 P OlO.H02 ¥'~RZ'~~'~ ~ . . iw.~ T l O !'~i LT. STiN] PAGE 6 DLL DLL DLL D LL OLL DLL CNL CNL CNL CNL CNL CNL C N L CNL CNL LDT LDT LCT LDI LOT L3T LDT LOT L3T LDT LOT LDT LOT LDT LDT ! ,_DT LDT NGT NGT N S T NGT NGT NGT NGT N GT N GT NGT NGT NGT H ,$ T -"-PT EPT G ~ 'T S;~T u~ 00 O0 0 00 UA 00 000 :~0 420 O0 000 O0 P U 0 0 ~ ~ 0 0 0 C P S 0 0 330 3 i CPS O0 330 30 G A P ! O 0 310 O i L ~ 00 .63 5 2 i O~:'4M OO 82~ ' OEGF O0 660 50 G& P. ~ 00 _,~ 1 O O! l N 00 280 O! G t C: O 0 3 ~ 6 0 l PU OO 890 O0 O0 35B Ol C P S 00 3 5 4 01 C P S ,30 3 ~ 4 01 CPS 0"~ 354 Oi CPS OO 35~ Ol C~S GO SOO O0 0 0 0 J 0 0 0 0 0 0 0 O 0 0 ~ ~',. 3~ 2 ,D S ~ 00 66 0 5 O .: ~ l 00 310 01 G 4 ~ l 0 0 3 1 C 0 1 ~ U 00 7 i '9 5 O P P ~,I 0 J 7 90 5 O C ~ S 0 O 3 1 '3 O ! - ~ S 30 31 3 O i C ~ 3 0 S 3! O r'j i C~S '3C 21e 0 E G ~= 0 O 6 ~ 0 5. ! ?4 3 n 2 ~, C 0 ~ { S F '3 O 660 5 O L ' 3 C 63 f 2 1 "= 3 l 0 n l ~ ~ Z U v . 4 4 4 4 4 4 4 4 4 4 4 4 4 & 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 68 00000000000000 O0000OO0000000 68 00000000000000 68 OOO00000000000 68 00000000000000 68 00000000000000 6S O0000000OO0000 68 00000000000000 00000000000000 68 00000000000000 68 00000000000000 00000000000000 00000000000000 68 00000000000000 68 00000000000000 1 1 t 1 t I ! 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I~2. 2. 5737. 49'32 1035 t L O SiO T :' NS CALl <G~ 22,5351 OVn~ .~0 · 9B93 TE~iS 6587.2500 NCNL 3459.5000 MR~$ 0.0703 PHC?, 2.6565 LL 103.7773 ~ 0~0.. .HO2 VERZFrCATI~3N. ~. LZSTZN,3 P~G~'- 8 209, '9375 LS ;: 26'}.1,,~06 eSS :S 0.0703 MTS?; r.a 0.2.930 THQ, R :S 0.0737 . Z 9.1035 [M 39. 2517 D~VZ Ii 40. 4180 ~T 14000.0000 LLS 49.4492 } 75.4648 MRES qL 2221.5000 GR ~;q 157.3125 Gq ~0 -O.OOgO DPHi 215.8125 2 270.6406 QSS IA 0.24~I THOR NG ~8.2617 W3NG ES 0.0747 MTEM Li 9.1516 IN 39.2930 9~Vi VI 41.6992 Vi 4~ ~0~ PT 139~0~ .OOJ:~ LLS 40.9492 O 36.0430 ~RES ~T !,43~6 NL, 2~05~ . 5000 G~ EM 155.3i25 ~3 -0.033~ DP~i ~15.157~ L$ 2 2.58.640,5 ~SS E S 0. O 7 2 3 TA 0,2~I NG I~. 767,5 ES J.0752 MT'ZM LZ 9,369i ZM 39,2930 VZ ~2.7~17 PT 13500.0000 LLS 5 ~. 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QLS TE%S LI SiO NPHI TrOiS ~&L~ 40 · 2 ?, 0 :.5 S S 1 -0.0210 TENS :; 2. f- "~- 51 C G R 1.7149 WING 2,9729 WSN6 5597.2500 GR 153.8125 TENS 172,0625 GR 40.6992 GP 4!. 3867 379,9084 SGR 152,6875 DVO 151.4375 TENS 7.6172 NCNL 6455.2500 MRES 9.1~16 RHC3 5.2000 LL 41.9492 SSl -0,0249 TENS 28.1455 CGR 2.6565 W1NG 2 955~ 64~3.2500 GR 157.3125 TENS ~'~ 9375 OR ~0,5742 GR 4!.3242 1201.70~2 SGR 82.2148 PVO 150,6.375 TENS 5. 2223 NCNL '453.2300 MRES 9,3591 RHC8 5,1~53 LL 40,7~30 SS1 0.0058 TiNS 14.6735 CGF; 1.2979 WIN,3 3.15&3 WSNG 155.8125 173.!575 GR ~1.3555 632,87-3~ SGR 121,2145 CVO 149.5625 TPNS i O, =~92 NCNL ~43 · 2500 v ~. O ~ ~ ~ ~ Hr ::: ~ .32~9 LL 205 437= 6787.2500 9.9004 72,3398 O,O00O 25.301~ 6787.2500 27.5361 31.5830 28,1455 32,1992 6483.2500 '3467.5000 0.0718 2,6272 106.8398 200.3125 6455.2500 8.5'723 88,6523 0.9549 2!.9893 6455.2500 30,4893 28.8799 14,5738 48.5367 6535.2500 3547.5000 0,0723 2,6096 11! .6523 200.~125 6483.2500 5.1140 50.6367 2.1096 13.9082 1.5.2090 15.9160 la 197~ 38.9492 6203,2500 2939.5000 0.0732 2,4417 147.9375 .o 010, HO 2 v; R. i F iC AT T ON.. LISTING~ ,PA~E~ 9 2 7 ~, 3 906 L S 2 239,8906 QSS ES 0,073£ NTEM Tn 0,2441 Tii'OR NG 23.2236 W3NG _cS O. 07~2 MT E M L! 9,0~88 MRES ~" 39,1035 DEV ! VI 43,9805 Rg VI 44,0430 Pe~ PT 13700.0000 LLS 43.8242 SVO 0 74.964~ ~RE5 AT 1. 2501 RNRA NL 3'i 4!. 5000 GR EM 153.0625 Gq HO 0 0015 201.8125 LS ~ 2 66. 890~ ~.S S ES 0.07 ~2 MT~M TA 0.439~ TH NG 54.7305 W3NG Li 9,1735 MR~S iM 3~,3555 VI 45,1357 VI 45, i$.~~ PT 13600.0,300 LL$ 43. 5357 SVC 0 360.8505 ~T 3. 5763 NL 343,1406 Ef,1 1~1.1A75 GR HO O.n:~6~. DP~I, 379.6~06 LS 2 331.6405 NG I '7.3i25 W3N$ ~S O.C7~l ~.~T ~M Li 16.5~30 MRZS IM 35.7305 Vi -9~$9.2500 ~'5 Vi a~,5742 ;236. 8906 0.0234 11.54,6575 0,70=i_. 7.3914 !40, 5625 0.0732 43,9180 i~0,9375 92,6523 369,0727 27,4111 0,0767 i. 3321 32.2930 32. 2930 1,6602 199.5 ;575 0. 0137 i:~ 06~ ! . 9971 ",,~ nsf8 146.8125 0,0742 45.0742 181,51'25 93._,P~ 48 2,2453 0,0781 '~., 1921 96,2773 96,2773 2~ 53:2 0,0~22 151.1375 10,5535 52.1580 4 3. ~43,0 - 9 g ¢.~° .5 'O 0 90. 2773 O. I'~96 O O · 0775 ,.. ... -999 . ?500 -S ~'P. 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"' SC-~LU:~'inF-RGEq Ln~jS ~.NCLUC~[~, ~.N 'THIS :1: SHDT~ 1.25" SAMPLE R~TE (C.~LiPER [ gIR~CTiJN~L ¢~.Tg) ~:~ - ~ S~2: 2 ~-' "~ S) 'P OIO.H02 V~RIFiCATiCN LISTiN'~ PAGE 12 DATA FORMAT RECORD-,-.,. iTRY BLOCKS TYPE $ 16 0 T UM E M PT OAT A -' PT 14188.8750 Ci -999.2~00 14100.2500 C1 9.0566 mT 14000.2500 C1 8.88'91 PT 13900.2S00 Ci 9 . PT 13800.2500 PT 13700.2500 PT 13600.2500 CI 11.g551 PT 13560.0000 CI 8.6035 ~-iLE TR&ILE~ NAME :EDIT R¥ICE NA :.i E : RSiSN ~ : SiZE ! 1 1 i 66 66 73 65 ~6 ~?l ~Pl ~Pl Lmr_ TYm: CL~qS O0 000 O0 vO 80 13. O0 280 24 O0 ZSO 13 O0 280 24 ~NTRY 1 . lin ! 0 4.3992 CZ 8 · :337 '9 C 2 8o947~ C~ 8.8613 C2 9.1595 C2 -999.2500 CZ -~)).2500 CZ AP1 FILE SIZE SPt MOO NO. 0 0 4 I 0 0 4 i 0 0 4 i 0 0 4 t 0 0 4 1 4.3540 C! 8. 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ST~NS FAm~ ~ PT 10300.2:310 PT 10200.2~I0 HT:=N PT 10100.2910 ~TEN ~T 10000. 2910 ~TEN ~T ~00.2910 ~TEN PT :~00.2~10 PT 9700.29i0 ~TEN PT 9500.2910 HTEN PT 9~00.2'910 HTEN PT 9~0 O. 2910 ~T EN PT 9300.2910 HTEN PT 9200. 2910 HTEN PT ~100.2910 HTEN PT 9000. 2910 HTEN PT 8900. 2910 HTEN PT 8800.2910 PT 8700.2910 HTEN PT 8600. 2910 HTEN PT 8500.2910 PT 8400. 2910 HTE~,~ :PT 3300.2910 HT~N :PT ggOO.29!O HTEN :PT 8100.2910 ~TEN ' PT 8 O00. 2910 HT EN 'PT 7'9 O0.2910 :PT 7500.2:~I0 :PT 7700.2910 I033.&$75 1034.6875 1045.8875 1023. ~125 1039 .&875 1025.6375 ~ 046 · 6~75 1040.6875 1045.5875 ~. 04, = ~$75 !009.~3125 979. 8125 937. 8125 949.3125 957.3125 959.8125 957. 312-5 947, 3125 969.8125 9~5.3125 9~6.3125 994.8125 937.31,!5 1022. 3125 986. B 125 994. 3125 ~P OiO.HOZ VSRIFICATiON LISTING P~G~ 23 :PT 7600.2~I0 :PT 7500.2910 :PT 7400.2910 mTSN :PT 7300.2910 HT~N :PT 7200.2~10 HT~N :PT 7100.2910 ~T~N PT 7000.2910 HTE~ :PT 6900.2910 HTEN :PT 6800.2~!0 :PT 5700.2910 MTEN :PT 5600.2910 HTEN :PT 6500.2910 HTEN !PT 6400.2910 HTEN :PT 6300.2910 HT~N !PT 6200.2910 HTEN :PT 6100.2910 HT~N :PT 6000.2910 HTEN :PT 5900.2910 ~TEN !PT 5800.2910 HT~N !PT 5700.2910 HT~N :PT 3600.2910 HTEN !PT 3500.2910 :PT 5400 ~ . _ .~910 HTFN !PT ~300.2910 5200.2910 HTEN 5113.9990 HT~N 931.~!25 1'3215.5875 991.9i25 25 i027.6875 1028.5875 1023.3125 I0~4.6375 1029.6875 1038.6875 1013.3125 1038.6375 1036.6875 1033,6875 10t3,3125 1022.3!25 1025.6375 1030.6875 ~I~ ~1~5 i011.~125 1006.3125 1010.8125 990.3125 ~4.'~I~5 FiLl TRAiLE~ ¢~ LE N~M~ :~DiT .O0~ RVIC5 N~M~ RSiON ~ T- ° XIMUM LEN3TH : 1024 LE TYPE : XT ~!Lf NAM5 : : FILF, HE.AOER LE NAME :EDIT .003 :RVICE NAME : ~RSION ~ : ,TE : ~XiMUM LENGTH : 102,~ 'LE TYPE :EVIOUS FILE : : COMMENTS-,--,- :~-~k;;:' THIS DATA HAS NOT 3fEN DEPTH SHzFT:.D" -'- OVERLAYS FTELD.,. PRINTS ......... -,-,,--,-;:-'"' :1 .? : ........ ..,..,.., ..... ,..,.., .... , ..... ,.., ...... , ..... ,.-, ...... ,..,. .... ,..,..,..,: ;,: :,~ ~,.. ,-.~ .,. .,..,..,..,..,..,..,..,. ¢~: ~,~.,. .,..~..,..,..,..,..,..,..,..,. ;:~ .,..,..,.., .,..,..,..,..,..,..,..,.., ..... ,. 'P OiO.H02 VERIFiC,&TiCq LCSTZNG m~GE 23 : DATa F3RMAT tTRY BLSCKS TY?E 2 15 0 ~TUM SPECIFIC~TIGN BL3C IEM SERVICE S~RViCE UN ID ORDER ~ !PT FT 'EN DLL LS 'EN LOT LS 'EN CNL L5 'EN NGT LB 'EN EPT L~ DATA ...... :PT 14246.4570 HTEN 'EN - 999.250 O HT-EIq !PT 14200. 2910 MTEN 'EN 1068.6875 HT~N :PT 14100.2910, MTiN 'EN 1062.6575 HTEN 'PT 14000. 2910 MTEN r EN 10'70. 6575 MTE:N :PT 13900.2910 'EN II10.6875 HT~N :PT 13~00.29!0 HTEN KS IT SIZE i ! 4 1 1 APl AP1 L~G TYPE O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 CODE 73 66 65 -999.2500 -9~9.2500 1058.6875 1280,6875 1062.6875 1395.6875 1070.6575 1255.6875 1110,6875 1375.6B75 i041.6975 ENTRY 0 I 3 . lin 1 0 AP1 ~PI FIL~ SIZE SPL CLASS MOO NO. O0 0 0 4 1 O0 0 0 4 1 OO 0 0 4. 1 O0 0 0 4 1 O0 0 0 ~ 1 O0 0 0 4 1 HTEN HTEN H T E N HTEN -999.2500 1280.6875 1395.6875 1255.6875 13'75,6875 1290.6875 REPR PROCESS COOE (OCTAL) 68 00000000000000 68 00000000000000 68 00000000000000 O00OO000000000 00000000000000 58 00000000000000 HTEN -999.2500 HTEN 1280.6875 HT~N 1395. 6875 HTEN 1255.6875 HT:N ~-~' 1~75.-~ · 6875 HTE N 1290,6875 ,o. Ot,~.HjR, V-REFZC;TIC;4 LIST',~43,~ Da'GE 25 'EN 104!.5875 HT~N ! -'_' :~ 0.5875 PT 13700.2910 HTEN 992. :~I25 HT~ ~On 657= PT 13600.2910 HT'-ZN ~N 1,355.687.: 1055.6875 1260.6S75 PT 13500.2910 HTEN EN 950.3125 ~T~N '750.3125 ~T~,i PT 13400.2910 ~T~N EN 942.3125 HIEN ~47_.~,~12~.. HTr-N -999. 2500 PT 13376. 0000 hTEN EN -999.2500 HTEN -9~9.2500 H T ~t~.i FILE TRAILER ~:~i= :LE NAME :EDIT .005 [RVICE NAME : :RSZON ~ : E : ~XiMUM LENGTH : 1024 :LE TYPE : !XT FILE NAM~ : I ~ 00. f 375 1250,6:375 -9'.:'9'3.25 O0 -9'~9. 2500 -999.252.0 HT~ N HTEN HTEN i~00 6~75 1260.5875 -999,2500 -999.2500 - 999.2500 FILE HEADER,,- ...... LE NAME :EDIT RVICE NAME : RSION ,~ : TE : XIMUM L~NGTH : LE TYPE : EVZOUS FILE : .005 1024 : COMM:NTS~ ...... .,..,. P OlO.HO2 V~!~IC~71[~ ClSTIN!$ ~G~ 27 : D,~TA FORMAT R--CORu .... ,- TRY 8LCCKS TYP~ SIZE REPR COSE ~NTRY 2 1 ~6 0 ~ i 66 1 ~ 4 73 ZO 1 ~ i 86 1 0 1 66 0 TUM SPECiFiCaTION BLSCKS iEM SERVICE SEF:VIC~ UNIT AP1 ~Pi AP1 ~Pl FILE SiZ~ SPL R~PR ID ORDER ~ LOG 'TYPe CL6S'S MOD PT FT O0 000 O0 0 0 4 ~L ~PT NS/M O0 132 O1 0 O TT EPT D~/M O0 130 Oi 0 0 4 'Hi EPT PU O0 890 O0 0 0 4 O EPT V O0 000 O0 0 0 4 U EPT V O0 000 O0 O D EPT V O0 000 O0 0 0 'U EPT V 30 000 O0 0 0 =SS CCDE (OCTAL) 1 58 O00OO000000000 1 68 000'00000000000 1 6a 00000000000000 1 88 00000000000000 1 6~ 00000000000000 I 58 00000000000000 I 68 OOO00000000000 I ~8 00000000000000 PT 14246.3320 TPL -999.2500 FVU -999. 2500 EATT -9::~5;. 2500 NVD -9~9.2500 EPHZ -999.2500 NVU -999.2500 -=~9.2500 PT 14200.1560 TPL 'D 0.3203 FVU PT 14100.1660 TPL 3 0.3652 FYU PT 14000.1660 TPL 3 0.5181 ~VU PT 13900.1660 TPL D 0,8643 FVU PT 13500.1660 D 0.4067 FVU PT 13700.1660 TPL O 0.8955 FVU PT 13600,1650 TPL 'O -0.5273 FVU PT 13500,1660 TPL ~O -999.2500 FVU PT 13400.1660 TPL 'O -999.2500 FVU 'PT 13376.0000 TPL ~D -999,2500 FVU : FILE TRAIL:R " LE NAMF :EDIT RViCE NAME : RSION ~. : TE : XIMUM L-EiNGTH : LE TYPE : XT FILE NAME FTLE HEADER ..... LE Nfl~qE :En~Tu~ RVICE NAM:~ : RSION ~ : TE : XIMUM LENGTH : LE TYPE : EVISU:S FiLE : ~.~301 E&TT 0 3477 NV~ 12.0801 EATT 0.3896 i1.5426 ~ATT 0.4404 9.5426 0.6i72 I1.0501 EATT 0.3887 NVD 11,0501 E~TT 0.6528 NVD 12.9551 -0.5269 NVD -999.2500 EATT -999.2500 NVD '-999.2500 EATT -999.2500 NVD -99~,2500 EATT -999,2500 NVD .006 1024 .007 1024 71.6523 0.6934 182.3125 195.3!25 !.5850 59.2617 I.$008 93.5523 0.8276 294.6406 2.4690 0.1504 -0.5269 -999.2500 -9'99.2500 -999.2500 -999.2500 -999..2500 -999.2~00 EPHi N VU EPHi NVU EPHi NVU EPHI NVU EPHi NVU EPHI NVU EPHI NVU 5'PHI NVU EPHI NVU EPHi NVU 4.10!6 0.71~3 15.7715 0.69~ 12.9883 1.2676 3.0273 1.9932 11.0352 0.8262 6.7871 1.9405 21.6309 -0.5269 -9~9.2500 -999.2500 -999.2500 -999o2~00 -999.2500 -999.2500 P OiO.H02 VSRIEiC~TiON LI3TiNG O~S~ ~L~SK.~ CCM~UTZNG CENTEq )MP&NY = ~CO SLASKA INC ~LL = LGi-iO 'ELQ : $RO~HOE B2Y/LI~q~.,jRNE FIEL2: }UNTY = NORTH SLOPE 'ATE : ALASKA JRFAC5 LSC~TZ~ ..... ~N = 1129 FNL ~ 1~.50 FEL, SeC )B NUMSER AT ACC: 71614 ~N ~1, DATE LOGGiEg: 23-JUL-B5 )P: L. 5. CUONEY SERiaL NO: 500292157'3 :PTH-DRILLER = 14216 F :PTH-LGGGER = 14225 F FM. LOG iNT[RVAL: i~210 F C~SiNG-ORiLLSR CaSINS'-LOGGER CASING : 13581 F = 13586 F = 9.625 " ELEVATIONS: KS: 52.0 DF: 51.0 GL: 13.0 'P 010.~102 VERI;:ICATi,SN LISTING o-~GE 30 LOS iNTERVAL: F, 300 F 'P~ F :NSZT :SCOS I 'ME C ',ME L iX tGGIN IGGZN :ELD ]TTNE ,TRIX lC U T ~ LUiD : 3&L&NCEO SaLiNiTY Y : '~.30 LS/G ITY : 40.0 S : 10.9 LOSS : 9.6 C3 IRC ST;DPP~O: 0630 (7-23) OGGER 2N 5TM.: 131~ (7-23) C. TEMP. = 153.0 CF G UNZT NO: 8256 G UNZT LgC: PRUGHOE 5AY ENGINEER: RUB~NST£ZN SSED BY: PRZYBYSZ~WSKZ : LIMESTONE : Z,71 G/C3 = NONE : CALi DENSITY : 1.0 5 M 1 C 3 5IT SZZ~ : 8.5 " C~PTH : 14215 F SSURCE ~]F S~PLS~ : ~ZmCULATFO,, _ RM = 2.170 ~ 71.0 DF R~F : 1.560 S 70·0 DF ~MC : _?.~90 ~ 5,~.0 DF SSU~CE RMFIRF~C : ME,SIMOnS RM ~T 5HT = 1.053 ~ 153, DF NMF ~T SHT = .751 ~ 153. CF RMC ~T ~HT = 1.282 ~ 153. DF M~RKS: 1.$" STANDOFFS USED SN DLL. 30000 PFM CHLC'R:ZDES. T~RGET LCC~TZON: O0'FSL E IO0'FEL 30-12N-15E, MAXZMUM ~VZ~TZON : 61 S~5 ~T 5800 FT, NGT ~ 010.~02 V~i~ICATICN LISTiNS ~55 31 ....... "' M "!1 PASS IGC, ED NGT THrOUGh, C~SiNG UNTIL A C:35~LT ~iRKER ;'J~S LOCATED ~T 13407 FT. tUiPMENT NUMBERS: DLE E 789 NGC m 19~5 AMM A 870 OLM C~ 2725 NGC 5 A~ 16~ 7~ ,3~iC A 718 LCM 799 3LS F TCC A t23 ,L INTERPRETATIONS ARE OPINIONS ~SED ~N INfEReNCES FROM ELECTRICAL SR 'H~R ME~SIJR~M~NTS_ AND W~ CANNOT, AND ~,nC NGT GU~RANT:~.~ THE aCC'~R~CY~ 2R tRRECTNESS OF ANY iNTERPReTaTiONS, aND WE SH~LL NOT, EXCEPT iN THE CASE OF iDSS OR WILLFUL NEGLiGENC~ ON OUR PART, 8E LiabLE GR R~SPgNSIBLE FOR ANY ISS, COSTS, DAMAGES DR EXPENSES ZNCURRE~ gR SUSTAINED 3Y ANYONE R~SULTING :OM ANY INTERPRETATION F'~A~E 5Y ANY OF ~U~ G;FICERS, AGENTS, OR ~MPLOYeES. iESE INTERPRET~T!ONS ARE ~LSO SUBJECT TC OUR GENERAL TERMS AND CGMDITIONS ; SET OUT IN OUR CURR~NT PRICE SCHEDULE. ,.,-., .... THIS DAT.~ HAS NOT B=EN. O~PTH ..q,HIFT':O. - GV:RLAYS FIELD PRINTS .~-"'.,--,."-,..,. ""-,- SCHLUMSERGr-R,. Lt]$S INCLUDED WITH THIS M~GNETIC T~.PE'. ;:~ 'P 010.r102 VzRiFICATISN L"$TTN$ cAGE 32 ;:: 3UAL LATERLOG (3LR) ::: ~:: LiTHO 3:NSITY C'2~'P~Nq,&T~5, ~ L~¢~',¢ (LO~)~, :;: :;= NATURAL G,&~M,& TQCL (NOR) ~:: N~ OmIT (DireCTIONaL DATA, GPR) =:: : DATA :ORMAT RBCORD ...... ITRY BLOCKS TYP~ SIZ~ R:~OR CGJ~ 2 1 86 4 i 66 8 4 73 16 1 66 0 I 6~ ENTRY 0 I 6O .lin TUM SPECiFICATiON BLOCKS EM SERVICE S~=RVTCE... ~ UNIT AP*, ~ APl AP1 APl. F~LE. S*ZE~ SPL REPR ID ORDER ~ CODE LOG TYPE CLASS MOO NO. PT F'T O0 000 O0 0 0 4 S OLR C{HMM O0 220 09 0 0 ~ D OLR CHMM O0 220 10 0 0 4 R DLR GAOl O0 310 O1 0 0 4 DLR MV O0 010 Ol 0 .0 4 0 DLR MV O0 000 O0 0 0 4 0 DLR UA O0 .000 O0 0 0 4 0 OLR MY O0 000 O0 0 0 ~ 0 DLR UA O0 000 O0 0 0 4 ES DLR O~fi~i",~ O0 823 50 0 0 4 PROCESS (OCTAL) 6,8 00000000000000 58.00000000000000 68 00000000000000 68 00000000000000 58 O000OO00000000 O0000000000000 68 00000000000000 00000000000000 00000000000000 55 00000000000000 VERiFIC~TiCN L!ST!NS PEG= O0 6.60 50 0 L5 O0 535 21 O0 420 0~ 0 O0 000 PU O0 590 O0 J CPS O0 330 31 0 CPS O0 330 20 G~Pl O0 31'3 L3 O0 535 21 ~'~M~ OC ~3 50 O GAPI O0 310 gl 0 IN O0 280 Ol G/C3 O0 350 02 0 G,'C~ O0 355 01 0 PU O0 390 O0 0 O0 358 Ol 0 CPS O0 354 O1 0 C~$ O0 354 O1 0 CPS O0 354 O1 0 CPS O0 35~ O1 0 CPS O0 000 O0 O C~S O0 000 O0 0 OO 000 O0 O0 OOO O0 L~ O0 5,3'5 21 0 :HMM '~ 823 50 0 OEGF O0 550 50 0 GAPI O0 310 O! 0 GAOl O0 310 O1 0 PU O0 719 50 0 :~oM O0 7'90 50 0 PPN O0 792 50 0 CPS O0 310 Ol fPS O0 310 O1 0 CPS O0 310 O! 0 CPS O0 310 Oi 0 CPS O0 310 Ot 0 ~0 ~2'~ 30 0 OEGF O0 560 50 0 L;3 O0 635 21 0 GAPI O0 310 O1 0 IN O0 280 Ol 0 ~HMM O0 823 50 0 ~EG:F go 660 50 0 L~ O0 535 21 0 OEG O0 530 01 O~G O0 620 Ol 0 OEG O0 531 Ol 0 ! 65 4 i 6 ~ 4 1 4 1 5 B 4 1 6 B 4 i 68 z, 1 4 i 68 4 1 68 4 1 68 ¢ 1 58 4 1 58 ~ I 68 4 ! 68 4 1 68 4 1 68 4 1 68 4 1 68 4 I 68 4 I 68 4 1 68 4 1 68 4 ! 68 4 1 68 4 1 C 1 63 4 1 68 4 I 68 4 1 68 4 i 68 4 1 68 4 1 6 8 4 I 68 4 1 6B 4 t 68 4 I 68 4 1 68 4 1 65 4 I 6B 4 ! 6 8 4 1 68 4 1 68 4 i 68 4 I 4 t 68 4 1 4 I 68 P'~GE 33 O000000000OO00 00000500000000 00000000000000 00000000000000 300OO0000000OO 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 O0000000000OO0 00000000000000 00000000000000 OOOOO000000000 O000000000000O 00000000000000 00000000000000 0'0000000000000 00000000000000 00000000000000 00000000000000 00000000000000 O000OO00000000 00000000000000 00000003000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 O00000000OO000 00000000000000 00000000000000 O0000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 DATA ...... PT 14246.0000 LLS -999. 2500 LLD -999.2500 SG~ -999.2500 ' -999,2500 SVO 0 -999,2500 MRSS iAT 2.5557 7hqa NL 554,3125 GR 'EM 155.8125 GR HO 0.0972 DPHI 307.1406 L3 2 323.6405 QSS ES O,O~E& MT~M TA -999,2300 THO~ NG -999,£500 W3NG ES -999,2300 MT~M Li 8,5020 MRES IM -999,2500 D~VZ PT 1~200,0000 LLS 65,2148 SVO 0 465,890a MRES AT 3.1194 NL 495.1406 EM 158.8125 GR HO 0,0532 DP~i 261.6406 LS 2 3t1,1406 QSS ~S 0,0.684 MT~M TA 0.3418 THOR NG 33,5055 W3NG ES 0,0752 MTEM Li 9,1270 MR~S IM 41,5742 DEVI PT 14100.0000 LL.S 94.3398 SVO 0 161. 3125 MR:S~ AT 1,4044 RNR~ NL 2030,6875 GR EM 159.1875 GR HO 0.0098 DPHI 205,6875 LS 2 272,6406 ~SS ES 0,0688 MT:2M TA 0,5859 THOR NG 44,5430 WSNG ES 0.0732 MTEM LI 9,1035 M~$ IM 41,1367 C~Vi PT 14000,0000 LLS 1!6,0Z73 SVB 0 58,3242 MR~S AT 2.0081 RNRA NL 1240,6875 GR EM 158.0625 GR HG 0.0137 ~P~ - 9 ~9 - 9 ) 9 3 25 25 325 0 158 -599 - 399 - 9 ~ ~ -9'59 7 3 0 3 25 2~ 9 270 0 158 1 14 150 0 39 110 1.6 0 1 27 27 2 205 0 i59 2 13 1.50 0 40 24 0 2 23 pm 4 ,2500 ,2500 .0120 ,4293 ,4893 .0371 ,0674 ,8125 ,2500 .2500 .2300 ,0684 ,2500 .3338 .2346 .0752 .2209 .4893 .4893 ..4238 .!406 ,0259 ,8125 ,2774 ,7832 .1875 ,0684 .5117 ,2557 ,9593 ,0752 ,5362 ,9580 ,9580 ,3438 .0225 .!875 .1311 .86i3 .3125 .0688 ,4478 ,5Z05 .0757 ,213t ,6143 .6143 .3945 SIO ~TEM NPHI TENS C~tl LiTH QLS SGR UR.aN TENS MTEM LLS SlO MTEM N~H i TENS CALl PEF LI TH QLS SGR URAN W 4 N :3 TENS MT[M R.B LLD M T E M NPHZ TENS C AL! PEF C ITH QLS SGR URAN ~4NG T~NS MT EM LLD SIO MTEM NPHi TE~JS CALl P~F -~99,2500 -999,2500 27,4902 2955,5000 8,5020 47,6580 103.2148 0.0151 -999,2500 -999.2500 -999.2300 -999.2500 158.8125 -999,2500 11.2032 639. $125 130.1875 30.7129 6991.2300 9,1270 3.3245 ~ 9,9648 -0,0039 21.3174 1,4278 0.0000 6051.2500 158,8125 76, 6523 116,7903 223,4375 !50,3125 5,1758 7047,2500 9,i035 4,6848 38,5742 -0.0i27 27,3486 1,3419 1,9796 5503,2500 15~ 187: 80.0898 546,8030 123,7t4~ 149,5625 13,954:5 6515,2500 9,2520 4,2507 TENS NCN L MRE S LL SSI T=N S CGR WiNG WSNG GR TENS SGR DVO TENS NCNL MRES RHO~. LL SS1 TENS CGR WING WSNG GR TENS SGR DVO TENS NCNL MRES RHO~. LL S S .1 TENS CGR W1NG ~SNG GR TENS DVO TENS NCNL MRSS RHOE LL -999,2500 -999.2500 1669,5875 0,0684 2,4866 172.4375 249.0525 29~5.5000 -999.2500 -999,2500 -999.2500 Z5.48~3 2955.5000 21.3174 5,8601 6051.2500 1595.6375 0.0684 2,5471 139.0625 228,9375 5991,2500 10,7910 64.5273 4,0320 25.4893 5991.2500 27.3486 21,1768 6503.2500 3121.5000 2,6682 i02,2148' 205.0625 7043,2500 17.4580 87.1523 1.9796 27.9580 7043,2500 20,3018 35.82&2 6427 ~ ,~500 2747.5000 0.0598 2.6331 109.3398 'P OiO,HJ2 VER:FiCATION LiST:NS $~GE 35 t 216.5525 ~2 266.3906 ~ES 0.0698 tTA 0.0977 :NS 31.5674 ~ES 0.0757 ,Li 9.2520 ,IM 41.2617 PT 13900.0000 56.0117 0 37.4180 AT 1.4600 NL 2325.5000 EM 156.6875 HO -0.0034 I 220.6875 2 268.8906 :ES 0.0708 iTA 0.1465 .NG 25.4736 ES 0.0767 Li 9.3770 IM 41,4180 PT 13800,0000 70.8398 0 51.3555 AT 1.8008 NL 1583.6875 EM 155.3125 HO 0.0073 ' 281.3906 2 296.3906 ES 0,0723 ,TA 0.2441 NG 28,7080 ,ES 0.0771 ,L! 9.0488 IM 41.6680 PT 13700.0000 59.7930 ,0 140.3125 :AT 1.1827 :NL 3119.5000 'EM 154.0525 :HO 0.0117 I 201.9375 ,2 265,3906 'ES 0.0'728 ITA 0.5371 ,NS 47.6880 'ES 0.0776 LS ,,SS M T E M THOA W3NG MTEM MR2S DEVZ LS VO RES PHI S SS TEM NOR 3 N :S TiM RES EVi LS VO NRA R S SS T~M 3NS TEM ~Vi LS VO RES NRA R R PHI S SS TEM 3NS 217.5x25 0.0630 158.0525 ;o06 5.5710 149.5625 0.0698 581.9567 32.6680 0.0767 1.4971 16.1143 16, t143 6.3965 223.6875 0.0283 156.8575 0,7173 ~.4941 148.587:5 0.0708 ,42. 7930 291. 7191 24.8643 0. $ 771 1.8311 13,4082 13. 4082 15.4785 292.8~06 0,0415 155.3125 0.~204 4,9500 t 47.9375 0.0723 A, 4.0i17 123,1228 17.7705 0,0775 1.2315 35.8867 38.5867 1.123.0 199.9.375 0.0381 t54.0625 I. 1788 23.'~018~ 147.4375 L!TH ~LS SGR UR~N N4NG TENS MTEM LL2 MTEM NPH! TENS C~LI LITH QLS SGR URAN W4NG T~NS MT~M LLD SIO MTEM NPHI TENS CALI PEF LITH QLS SGR URAN W~NG TENS MTEM RB LLD SIO M T E M NPHI TENS CALl PEF LITH QLS SGR URAN W~NG TENS ~!,7~30 SSi -0,0107 TENS 20,3018 CGR 1,6~85 WINS 2,7131 WENS 5427.2500 158.0625 TENS 79,1523 I'~7.P7P2 SG~ 81.4023 148.6375 TENS 5.6641 NCNL 6615.2500 MRES 9.3770 4.9304 LL 43,6680 SSl -0.0015 TENS 15,8535 CGR 1.3965 WING 1,0618 WENG 6355,2500 GR 156.6875 TENS 81,2148 664,0739 SG~ 123,589~ DVO 147.9375 TENS 11,1328 NCNL 6143.Z5~00 MRES 9.0488 RHS~ 4.8601 LL 59,8242 SSl -0.0010 TENS 16.6299 CGR 1.4454 W!NG 0.0000 WSNG 6223.2500 GR 155.3125 TENS 87.9548 14t.0397 SGR 209.3125 DVO 147.4~75 TENS 2.0508 NCNL 6255.2500 MRES 9.1660 RHO~ 5,067! LL 40 1680 ~S' · -0.0195 TENS 37.6~67 CGR ~.~ ~,~5i8 WiNG 7,4148 WENG 8271.2500 GR 209.5625 651=,2500 8.16,50 66.8398 2.7854 23.6143 6515.2500 15.8535 48.6357 6355.2500 3~81.5000 0.0708 2.5999 113.3398 201.3125 6615.2500 5.5710 5~.1367 1.0616 16.1143 6615.2500 16,6299 38.3242 6223,2500 Z901.5000 0.0723 2.4436 152.1875 218.4375 6143.2500 5.9~90 60'3867 0.0000 13.4082 8143,250.0 37,6367 22.2393 5.271.2500 3841,5000 0,0728 2.6897 99.0273 204.6875 6255,2500 12.,9395 133,~375 2.1174 38.8867 P OiO,H02 VERIFZCATZSN LZSTZNG P~GE 26 Li 9,1660 MRZS IM 41,1367 DEVZ PT i3500,0000 LLS 37.7305 SVO 0 220,0825 MRES AT 3,72~9 RNR& ,NL 328.8906 GR EM 151.8125 GR HO 0,0713 ~PmZ ~ 3~6.,6406 LS 2 343,3906 ';SS ES 0.0776 MT~M TA 2,5391 THOR NG 155.6875 W3NG ES 0.0781 MTEM LI 14.9629 iqRE.S IM 38,8367 OEVi PT 13500,0000 LLS -999.2500 SVO 0 -999,2500 MRES AT 3,3870 RNR~ NL 365.1406 GR EM 131.4375 GR HO -0,3515 DP~I 221,1~75 LS 2 132.0625 ~SS ES 0,0771 MTEM TA -999-2500 THOR NG -999.2500 W3NG ES -999,2500 MTE~ LI 9,0332 MRES iH -999,2500 DEVI PT 13400,0000 LLS -999,2500 sro 0 -999,2500 MRES AT 2.5159 RNRA NL 580,8125 GR EM 150,9375 GR HO -0.4893 DPHI 162,6675 LS 2 88,1523 ~SS ES 0,0776 MTEM TA -999,2500 'TH~ NG -999,2500 W3N3 ES -999,2500 MT~M Li 8,7910 MR~.S IM -999.2500 DEVI PT 13376,0000 LLS -999.2500 SVO 0 '-99'9,2500 MRES 0.0723 45. 1055 '.~5 4,1911 LLJ 2,3059 SiO S,OT~l MTEM 4.0476 NPHI 100,C023 TENS I00,4023 CALZ 19,0430 PEF 368.!406 tll~ 0,03~7 ~LS 15!.~125 I0,650~ U2AN S9,9023 1.~6,0625 TENS 0,0776 MTEM 45.6367 -9'?9,2500 LLD -999,2500 SIO - 9 ~ 9 · 2500 3,2737 39,1367 TENS 39,1.3 57 CAL 29, ~668 ~5.0625 LiTH -0,0918 QLS 151,4375 SGp, -9:99.2500 ORAN -999.2500 W4NG -999.2500 TENS 0,0771 MT EM -999.2500 -999,2500 LLD -999,2500 SIO -999.2500 MTEM 2,8303 NP~i 15.7754 TENS 15.7754 CALl 22,85i6 PEF 150,6575 LiTH -0,1260 QLS 150,9375 SG~ -999,2500 URAN -999.2500 ~4NG -999.2500 TENS 0.0776 P~TEM -999.2500 R5 -929,2500 LLD -999.2500 -999.2500 MT~M 154,0525 TENS 94.454~ 9.0369 SGR 798,8125 DVO 146,0625 TENS 36.3281 NCNL 61i5.2500 MR~S 14,9629 RHE~ 3.4788 th 95.5273 SSI 0 . 0 O 15 T E N S 103,2773 CGR 3,0510 WiNG 10.5879 WENG 5915,2500 GR 151.8125 TENS 208,31.25 -999.2500 SGR -999,2500 DVO -999.2500 TENS 34,9609 NCNL 5907,2500 MRES 9,0332 RHO~ 21,7080 LL 23.5986 SS! 0.0044 TENS -999.2500 CGR -999.2500 WING -999.2500 WENG -999,2500 GR 151,4375 TENS -999.2500 -999.2500 SGR · -999.2500 OVO 999 2500 T:NS 22,0703 NCNL 5847.2500 MRES 8.7910 RHO~ 30,7549 LL 17.8643 SS1 0,0322 TENS -999.2500 CGR -999,2500 WiNG '-999.2500 WSNG -999.2500 GR 150.9375 'TENS -999,2500 -999.2500 SGR -999.2500 gVO -999.2.500 TEHS 6255.2500 103.2773 2.2346 5915.2500 1331.6875 0.0775 2.3831 194.6875 248.9375 6115.2500 80.8398 345.3906 10.5879 100,~023 5115.2500 -999.2500 -999,2500 -999.2500 !195,6875 0.0771 2,2209 114,5273 83.2148 5907,2500 -999.2500 -999.2500 -999,2500 39.1367 5907.2500 -999.2500 -999.2500 -999,2500 1643,6875 0,0776 2,3186 79,2773 57,0430 5847,2500 -999.2500 -999.2500 -999,2500 15.7754 5847.2500 -999,2500 -999.2500 -999,2500 'P OlO.dO2 VF~IFiCATIQN LiSTiNg P,~GE 37 iAT 2.7249 RNRA ,NL 535.3125 GR 'EM 150.$123 GR :H~ -0.4697 DP~i I 162.1875 LS :2 90.7148 QSS ,ES 0.0776 MTEM ITA -999.2500 THOR ,NG -999,2500 W3NG :ES -999.2500 MTEM ~LI 8.7832 MR~S IM -999.2500 DEVi .6194 NPMI 18.0205 T~NS 1~.C205 CALl 21.4355 PEF 158.6875 LiTH -0.1157 QLS 150.8125 SGR -9'99.2500 ~RAN -999.2500 W4NG -9~9.2500 TENS 0.0776 MTEM -9~9.2500 R~ 23.1'253 >iCNL 3795.2500 NRES 8.7332 26.$543 LL 16,0361 SS1 0.0171 TENS -999.2500 CGR -999.2300 ~iNG -999.2300 WSNG -999.2500 GR 1~0.5125 TENS -999.2500 1410.6875 0.0776 2.3420 77.5890 59.4180 5795.2500 -999.2500 -999,2500 -999.2500 15.0205 5795.2500 :FILE TRAILER' LE NAME :EDIT .007 RVICE NAME : RSION # : TE : XiMUM LENGTH : 1024 LE TYPE : XT FiLE NAME : FILE H=ADER~ ~.-,-"' !LE NAME :EDIT RV!CE NAME : ~RSION ~ : TE : XIMUM L~NGTH : LE TYPE : EVIOUS FILE : .008 1024 , COMM=NTS .... ~. "~ ...... REPEAT LOGS -,- -'--' .... .. ~"' _ OVr'RL~YS ~IeLD PRINTS :.,..,..,- T~IS DAT~ ~S NOT 3E~N D:PTH SHiFTFD -, ~ . " -,-'" :,, .,..,..,..,..,..,..,..~..,..,..,..,.., ..... ,..,.., ...... ,..,. ,;,..,..,..~..~ ..... ,, .,..,..,..,..,..,..~..,..,..,..,..,..,. ::~ ,:~ SCHLUMSERGER LOGS iNCLUDeD IN THiS FILE: : DATA FORNAT RECORD i'TRY ~LOCKS TYFE SiZE iqEPR C!3OE =NTRY 2 1 ,5 6 0 4 1 66 I '~ 4 ~ 5 · I I N t~ 1 66 1 0 i 66 0 iTUH SPECiFICaTiON 8:LOCKS tEM SERVICE SERVICE UNIT APl APl AP1 APl :iLE SiZE SPL REo~ ID ORDER ~ LOG TYPE CLASS M~O NO. CODE ~PT 'EN DLR EN LDR 'EN CNR 'EN NGR EN EPR PEOCESS (OCT&L) FT O0 000 O0 0 0 4 I ~ 00000000000000 L5 O0 000 O0 0 0 4 I 68 00000000000000 LB O0 000 O0 0 0 4 ! 68 00000000000000 L8 O0 000 O0 0 0 4 ! 68 00000000000000 LB O0 000 O0 0 0 ~ 1 58 00000000000000 L5 00 000 00 0 0 4 I 68 00000000000000 PT lq, 245.4.570 HTEN -999.2500 HTEN EN -999.2500, HTEN :~13.3125 ~13.3125 HT~N ~t3.3125 ip 010.H02 VERI=iCATiON LISTING PAGE 39 :PT 14200.2910 HTEN 'EN 939.3125 HTFN 'PT 14100.2910 HTEN 'SN 1067.6875 HTEN PT 14000.2910 HTEN EN 1066.6875 HT~!~ PT 13900.2910 HTEN EN 1095.6:375 HTEN PT !3800..2910 HTEN EN 1053.6875 HTEN PT 13700.2910 HTEN EN 1098.6875 HTEN PT 13600.2910 HTEN EN 1080.6875 HTEN PT 13500.2910 HTEN EN -999.2500 HTEN PT 13400.2910 HTEN EN -999.2.500 HTEN !PT I3376.0000 HTEN ,EN -999.2500 HTEN : FILE TRAILER gg 'LE NAME :EDIT .008 ~RVICE NAME : :RSION ~ : TE : XIMUM LENGTH : 1024 LE TYPE : XT FILE NAME : : ~"'LE HEADsR LE NAM~ :EOIT RViCE NAME PSION ,~ : TE : XIMUM LENGTH LE TYPE EVIOUS FiLE .009 1024 C 0 M M E N T S ~:~:~ 959.3125 MTEN 1334.6875 1067.5875 HTEN 1369.6875 1066.6875 NTEN 1288.6875 1095.6875 HTEN 1329.6875 106B.6875 HTEN 1254.6875 1098.6875 HTSN 1286.6875 1080.6875 HTEN 131'7.6875 -9'99.2500 H'TEN I19,4.6875 -999.2500 HTEN 1196.6875 -99'9.2500 HTEN 1189.6875 1384.6B75 1369.~£7~ 1280.6~75 1329.6875 1254.6875 1286.6875 1317.6;375 1194.6875 1196.6875 1189.6875 HTE N HTEN H T E N HTEN H T E N MTEN HTEN HTE N HTEN 1384.6875 1369 · 6875 1288.6875 1329.6875 1254.6875 1286.6875 1317.6875 1194.6875 1196.6875 1189.5875 P OIO.HO2 VEriFiCaTiON LISTING :~:~',~ REPEAT LnGS .......... THIS DATA .~AS N~T :,==N.-, . DEPTH S~iFT=2:. - OVERLAYS ;ZELC PRINTS SCMLUME. ERGER LOGS INCLUO.=D IN TMIS FILE: ;1: ELECTRL]M~GN.ETIC PqgPAGaTION *C,.'SL (EPR) '"-,- SAMPLED '~T .12" RATE DATA FORMAT RECORD Y;::~ TRY 6L~CKS TYPE SIZE REPR CO~E ENTRY 2 1 66 0 4 i 66 1 8 4 73 20 '~ 4 6 5 .1 1 N 1 6 1 6 6 1 0 1 66 0 TUM SPECIFiCATiON BLOCKS iEM qERVZCE SERVICE UNIT API ~P~ AP~ APl FILE SIZE qPL REPR ID ORDER ~ LOG TYPE CLASS MOD NO, CODE PROCESS (OCTAL) ~P O1c~,.riO2 VERIF-ICATI~3N~. LT~TiNG._ PHGr_-. ~1 [PT FT 30 003 O0 'L ~PR NS/NJ O0 132 0.1. ~TT 5PR D:~/M CO 130 01 'Hi EPR PU O0 290 O0 ~D EPR V O0 OOO ~U ~PR V O0 000 'D ~=PR V OO 000 n,~ ~ : DATa ...... !PT 14246,3320 TPL ~D 0,6997 FVU !PT 14200,1650 TPL 'O 0.Z903 F'V~J :PT 14100.1560 TPL ~D -0.5283 FVU !PT 14000.1560 TPL rD 0.3457 FVU !PT 13900.1560 TPL FD 0.2339 F~VU :PT 13800,1660 TPL FD 0,3555 'FVU iPT 13700.1660 TPL ID 0.552'/' FVU !PT 13600.1660 TPL tD -0.5264 FVU ~PT 13500.1650 TPL ~D -0.522'-) FYU !PT 13400.1,550 TPL ~D -O.~Z2:~ FVU !PT 13376.0000 TPL /D -0. 5229 FVU 9.7051 EATT 0.6196 NV9 9 · ~.., 301 E A T T 0.Z583 NVD 1 Z. 6,4 26 E 4 T'T - 0 · :5 Z :33 i1.0001 EA'TT 0,3184 NVO :~.7051 '£ATT 0.2723 NVD 10.0176 EATT 0.3364 NVO 12.1a25 EATT 0,6011 NV 17.0361 ~ATT -0.5234 NVD 14. 1426 EATT -0.~215 15.9473 EATT -0 · 52t~ NV9 17.66!1 EATT -0,5215 ~ FILE TRAILER, ~':-' 'LE NAME :EDIT .009 !RVICE NAME : !RSION ¢ NTE : NXIMUM LENGTH : 1024 'LE TYPE : :XT FILE NAME : 4 1 66 00000000000000 4 1 63 00000000000000 4 I 68 00000000000000 4 i 68 O00000OO000000 ~ 1 68 00000000000000 4 1 68 00000000000000 ~ 1 63 00000000000000 ~ 1 65 00000000000000 236.3125 EPMi 0.4883 !.51~99 ~' ~VU 2.0315 74.1523 EPHi ~.1016 0.6440 NYU 0.6943 232.3125 ~PHI 18.0176 1.0381 NVU -0.~283 127.1523 5mHI 10.7910 0.6973 NVU 0.9829 58.0742 ~PHI 3.4180 2.4221 NVU 1.1563 94.1523 ~PHi 5.0293 0.74~7 NYU 0.7368 348.6406 EPHI 11.1816 2.4553 NVU 2.0823 0.2002 ~PHI 44.7266 -0.5249 NVU -0.5229 0.1494 EPHi 28.3203 -0.5215 NVU -0.5215 0.!~94 5PMI 38.4766 -0.5215 NYU -0.521~ 0.1~94 5PHi 48.0957 -0.5215 NVU -0,5215 ~P OiO.H02 VERiFICATiON LiST'NG ~,~GE 42 TAPE TR~ILER :::~:: !RVICE NAME :EDIT ,TE :85/07/30 ~IGIN :FS1A ,PE NAME : iNTINUATZON ~ :01 :XT TAPE NAME : tMMENTS :LIBRARY TAPE : REEL TRAILER !RVZCE NAME :EOII ~TE :85/07/30 ~ISIN : INTINUATION ~ :01 !XT REEL NAME : IMMENTS :LIBRARY TAPE IdlCtt( EILMED LIS TAPE VERIFICATION LISTING LVP 010.H02 VERIFICATION LISTING PAGE ~ RE:EL HEADER ~'= SERVICE NAME :GCT DATE :86/08/13 ORIGIN REEL NAM~E : P P CONTINUATION # :01 PREVIOUS REEL : COMMENTS :SCHLUMBERGER GCT LIS TAPE · ~ TAPE HEADER SERVICE NAME :GCT DATE :86/08/13 ORIGIN :0000 TAPE NAME :1650 · CONTINUATION ~ :01 PREVIOUS.TAPE COMMENTS :SCHLUMBERGER GCT LIS TAPE ~ FILE HEADER FILE NAME :GCT .001 SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : 1024 FILE TYPE PREVIOUS FILE : INFORMATION RECORDS MNEM CONTENTS UNIT TYPE CATE SIZE .CODE CN : ARCO ALASKA INC 000 000 015 065 WN : LGI-iO 000 000 006 065 FN : PRUDHOE BAY/LISBURNE POOL 000 000 025 065 RANG: 14E 000 000 0,03 065 TOWN: 11N 000 000 003 065 SECT: 1 000 000 001 065 COUN: N SLOPE 000 000 007 065 STAT: ALASKA 000 000 006 065 CTRY: USA 000 000 003 065 MNEM CONTENTS UNIT TYPE CATE SIZE CODE O65 LVP OlO.HOZ VERIFICATION LISTING PAGE 2 SCHLUMBERGER ALASKA COMPUTING CENTER COMPANY = ARCO ALASKA~ INC. WELL = LGI-IO FIELD = PRUDHOE BAY/LiSBURNE POOL COUNTY = NORTH SLOPE ALASKA = ALASKA JOB NUMBER AT ACC: 71650 RUN #TWO, DATE LOGGED: 03-A.UG-86 LOP: T' HALSTEAD CASING ;CASING 9.625 @ 13586.0 - ~IT SIZE = ~2.25 7.0 @ 14216.o0 - BIT SIZE = 8.5 AZIMUTH OF PLANNED VERTICAL PiLANE: 40.6 SURFACE LOCATION: l[2g' FN~L~ 1680' FEL~ SEC 1, TI1N, RI4E~ UM * GYRO CONTINUOUS TOOL (GCT) * LVP OlO'H:02 VERIFICATION LISTING PAGE * DE:FINITIONS: * 'HLAZ= AZIMUTH DEVI= OEVIATION GDEP= :GYRO DEPTH VDEP= TRUE VERTICAL DEPTH , NSO~R= NORTH OR SOUTH DEPARTURE EWDR= EAST OR WEST DEPARTURE DGL = DOG LEG (CURVATURE OF THE WELL) ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 ! 66 0 4 1 ,66 1 8 ~ 73 60 g 4 65 .liN 16 1 66 t 0 1 66 0 DATUM SPECIFICATION B,LOCKS MNEM SERVICE SERVICE UNIT A.PI API API API FILE SIZE SPL REPR ID ORDER # LOG TYPE CLASS MOD NO. DEPT FT O0 000 O0 0 0 4 GOEP GCT FT 99 000 O0 0 0 ~ VDEP GCT FT O0 000 O0 0 0 4 HLAZ GCT DEG O0 000 O0 0 0 4 DEVI GCT OEG 99 620 11 0 0 4 NSDR GCT FT O0 000 O0 0 0 4 EWDR GCT FT O0 000 O0 0 0 4 DGL GCT FT O0 000 O0 0 0 4 PROCESS CODE (OCTAL) 68 00000000000000 68 00000000000000 68 00.000000000000 68 00000000000000 68 00000000000000 68 000000.00000000 68 00000000000000 68 00000000000000 ** DATA ** .VP OlO.H02 VERIFICATION LISTING PAGE 4 )EPT )EVI 65536.5000 GDEP 0.0000 NSDR 0.0000 VDEP 0,0000 EWDR )EPT )EVI 65500.0000 GDEP 4.5564 NSDR 957.5497 VDEP 6.0551 E~DR )EPT ]E:V I 65400.0000 GDEP 56.7475 NSDR 6881.9473 VDEP 3229.2544 EWDR ]EPT ~EVI 65300.0000 GDEP 49.3468 NSDR 13246.1445 VDEP 7304.4463 EWDR DEPT DEV'I 65264.0000 GDEP 40.3540 NSDR 14111. 8437 VOEP 7774. 3262 E~DR ~ FILE TRAILER ~.~ FILE NAME :GCT .001 SERVICE NAME : VERSION ~ DATE :: MAXIMUM :LENGTH : 1;024 FILE TYPE : NEXT' FILE NAME ~, TAPE TRAILER ** SERVICE NAME :GCT DATE :86/08/13 ORIGIN :0000 TAPE NAME :1650 CONTINUATION NEXT TAPE NAME : COMMENTS :SCHLUMBERGER GCT LIS TAPE · ~ REEL TRAILER ,~ SERVICE NAME :GCT DATE :86/08/13 ORIGIN : REEL NAME : P P PT\ CONTINUATION # :01 NEXT REEL NAME : COMMENTS :SCHLUMBERGER GCT LIS TAPE EOF **~*~ EOF **~***~* 0.0000 HLAZ 0"0000 DGL 957.2454 HLAZ 10.0806 DGL 4777.9082 HLAZ 2600.2427 OGL 8200.6445 HLAZ 6069.8203 OGL 8804.4629 MLAZ 6472.lgg2 DGL O. 0000 0.0000 40.4362 1o0234 38. 8698 1.8149 39.9486 0 -4400 41.4868 3.9140
