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Home My WebLink About186-140CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector LGI-02 (PTD #186140) AOGCC MIT-IA Passed Date:Tuesday, May 30, 2023 9:15:42 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, May 26, 2023 12:00 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector LGI-02 (PTD #186140) AOGCC MIT-IA Passed Mr. Wallace, Injector LGI-02 (PTD #186140) passed AOGCC witnessed MIT-IA to 3362 psi on 05/26/23. The passing MIT-IA verifies two competent well barriers. The well is now classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Tuesday, May 23, 2023 6:56 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg@alaska.gov; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Injector LGI-02 (PTD #186140) Inconclusive AOGCC MIT-IA Mr. Wallace, Injector LGI-02 (PTD #186140) AOGCC MIT-IA failed to show stabilization on 05/23/23 during multiple MIT attempts. A 4° gas injection temperature decrease was observed due to ambient temperature shift during first 60 minutes of testing. The change of gas injection temperature does not conclusively explain the lack of stabilization. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: PPPOT-T 2. Fullbore: MIT-IA if pass repeat AOGCC MIT-IA 3. Well Integrity: Further action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 25, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC LGI-02 PRUDHOE BAY UN LIS LGI-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2023 LGI-02 50-029-21634-00-00 186-140-0 G SPT 8260 1861400 2065 2477 2480 2480 2481 19 29 31 29 4YRTST P Austin McLeod 5/26/2023 MITIA 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-02 Inspection Date: Tubing OA Packer Depth 125 3395 3370 3362IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230526162637 BBL Pumped:4.7 BBL Returned:4.5 Tuesday, July 25, 2023 Page 1 of 1           CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector LGI-02 (PTD #186140) Inconclusive AOGCC MIT-IA Date:Wednesday, May 24, 2023 10:16:17 AM Attachments:MIT PBU LGI-02 LGI-10 05-23-23.xlsx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, May 23, 2023 6:56 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Injector LGI-02 (PTD #186140) Inconclusive AOGCC MIT-IA Mr. Wallace, Injector LGI-02 (PTD #186140) AOGCC MIT-IA failed to show stabilization on 05/23/23 during multiple MIT attempts. A 4° gas injection temperature decrease was observed due to ambient temperature shift during first 60 minutes of testing. The change of gas injection temperature does not conclusively explain the lack of stabilization. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: PPPOT-T 2. Fullbore: MIT-IA if pass repeat AOGCC MIT-IA 3. Well Integrity: Further action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1861400 Type Inj G Tubing 2488 2488 2487 2487 2487 2487 Type Test P Packer TVD 8260 BBL Pump 7.1 IA 86 3200 3160 3136 3113 3088 Interval 4 Test psi 2065 BBL Return OA 27 43 43 43 42 41 Result I Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1861400 Type Inj G Tubing 2486 2487 2486 2485 Type Test P Packer TVD 8260 BBL Pump IA 3061 3040 3022 3005 Interval 4 Test psi 2065 BBL Return 4.1 OA 40 40 38 37 Result I Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1860690 Type Inj G Tubing 2667 2667 2667 2665 Type Test P Packer TVD 8261 BBL Pump 10.4 IA 58 3445 3429 3421 Interval 4 Test psi 2065 BBL Return 6.9 OA 14 40 41 41 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:4 Year AOGCC MIT-IA LGI-10 Notes:4 Year AOGCC MIT-IA Notes: Hilcorp North Slope LLC Prudhoe Bay / Lisburne / LGI Pad Sully Sullivan Ryan Holt 05/23/23 Notes:4 Year AOGCC MIT-IA Notes: Notes: Notes: LGI-02 LGI-02 continued Form 10-426 (Revised 01/2017)MIT PBU LGI-02 LGI-10 05-23-23 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-02 PRUDHOE BAY UN LIS LGI-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2023 LGI-02 50-029-21634-00-00 186-140-0 G SPT 8260 1861400 2065 2488 2488 2487 2487 27 43 43 43 4YRTST P Sully Sullivan 5/23/2023 75 min - T-2486, IA-3061,OA-40. Inspection supervisor determined test to be a pass after 75 minutes. Total pressure loss during 45 min. to 75 min. is 42 psi; initial pressure 3113 giving 1.3% pressure loss. 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-02 Inspection Date: Tubing OA Packer Depth 86 3200 3160 3136IA 2487 42 45 Min 3113 2487 41 60 Min 3088 Rel Insp Num: Insp Num:mitSTS230524081023 BBL Pumped:7.1 BBL Returned:4.1 Tuesday, July 25, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 MEU 9 9 Inspection supervisor determined test to be a pass after 75 minutes.Total pressure loss during 45 min. to 75 min. is 42 psi; initial pressure 3113 giving 1.3% pressure loss. James B. Regg Digitally signed by James B. Regg Date: 2023.07.25 15:29:00 -08'00' MEMORANDUM State of Alaska Type G�TVD Alaska Oil and Gas Conservation Commission 2868 286 za6z DATE: Friday, May 31, 2019 TO: Jim Regg / P.1. SuPervisore.N ll ., /I� SUBJECT: Mechanical Integrity Tests (� BP EXPLORATION (ALASKA)INC. 6.z iBBL Returned: LGI-02 FROM: Jeff Jones PRUDHOE BAY UN LIS LGI-02 Petroleum Inspector P Ste: Inspector Reviewed By: P.I. Supry —OL— NON-CONFIDENTIAL NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN LIS LGI-02 API Well Number 50-029-21634-00-00 Inspector Name: Jeff Jones Permit Number: 186-140-0 Inspection Date: 5/14/2019 Insp Num: mitJ1190531093635 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Lcl-oz Type G�TVD 8260 Tubing 'an 2868 286 za6z PTD 1861400 Type Test SPT Test psi 2068 - IA '296 3451 3439 - 3428 " BBL Pumped. 6.z iBBL Returned: 5.3 - OA 28 54 56 57 Interval Notes: I well inspected, 4YRTST P/F no exceptions noted. P Friday, May 31, 2019 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 61/51/ DATE: Monday,June 01,2015 SUBJECT: Mechanical Integrity Tests P.I.Supervisor 1.-- BP EXPLORATION(ALASKA)INC LGI-02 FROM: Matt Herrera PRUDHOE BAY UN LIS LGI-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN LIS LGI-02 API Well Number 50-029-21634-00-00 Inspector Name: Matt Herrera Permit Number: 186-140-0 Inspection Date: 5/30/2015 Insp Num: mitMFH150531153259 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well] LGI-02 • Type Inj G TVD 8260 ' Tubing 2845 - 2846 - 2846 - 2845 ' 1861400 SPT 2065 - 578 2500 2480 - 2470 ' PTD Type Test Test psi IA Interval 4YRTST P/F P OA 49 57 , 58 58 Notes: r SCANNED JUL1 3 2015 Monday,June 01,2015 Page I of 1 June 2011 AOGCC MIT Forms • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator@bp.com] 2 Sent: Sunday, July 03, 2011 3:34 PM `� 1 z ( To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: June 2011 AOGCC MIT Forms LC= - �Z Attachments: June 2011 MIT Forms.zip P 7 166- I40 Tom, Jim, and Phoebe, Please find attached AOGCC MIT forms for the following wells: NK -23 (PTD # 1940350) LGI -10 (PTD # 1860690) W -11 (PTD # 1891070) P2 -09 (PTD #1980660) M -18B (PTD #1930540) W -210 (PTD # 2061850) P2 -15A (PTD # 2070320) M -28 (PTD #1860740) Z -12 (PTD #1891020) MPE -03 (PTD #1890170) R -13 (PTD #1830440) MPS -04 (PTD # 2030520) x 2 R -32A (PTD #1980090) 13 -09 (PTD # 1811580) S -06 (PTD #1821650) E -103 (PTD #2012000) V -121 (PTD # 2070360) LGI -02 (PTD # 1861400) x 2 V -215 (PTD #2070410) «June 2011 MIT Forms.zip» 'MAW JUL 4 4 ZU'i Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 7/12/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reao alaska.gov; doa. aogcc.prudhoe.bavaalaska.gov; phoebe.brooks(rDalaska.aov: tom.maunderealaska.aov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT 1 PAD: Prudhoe Bay / PBU / LGI ( e�� 7 -12 - (( 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 Vanance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water 0 = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU LGI - 02 06 04 11.xis • • SMITE OF ARLSEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION 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# w ' a. JUN j 6 am 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 Area (GPMA) drillsites. This work is to occur during July 2011. BPXA's request to use PBU LGI -10 (PTD 1860690) is similar to a request in 2010 for LPC - approved by the Alaska Oil and gas Conservation Commission (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.regggalaska.gov should there be any deviation in the approved plan. Sincerely, Jl� 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 summer 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 1 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 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 1:21PM 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; howel these be adjusted to conform to AOGCC quirements? (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.regg 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 y Regg, James B (DOA) From: Gerik, Bob G [Bob.Gerik @bp.com] pr 14%. °GCS t f/3(4. , Sent: Thursday, June 09, 2011 4:04 PM 1 Igl by (f'&& LGr-cz 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, ✓ 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 t bp 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 /omsop /documentum /Default.aspx Print Date: 6/9/11 Page 1 of 11 • `4� GPMA Drill Sites Startup Procedure Procedure # by 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 • 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 p 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 • 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 • «* GPMA Drill Sites Startup Procedure Procedure # by Post 2010 Turnaround te 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 — P1 G 1 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 • ee GPMA Drill Sites Startup Procedure Procedure # bp Post 2010 Turnaround tte. 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 �" 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 # 1` bp Post 2010 Turnaround Issue Date: 07/01/10 Rev. Date: 07/02/10 Rev. 1 bring field 8.2 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 RGI 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 • r 1/4. GPMA Drill Sites Startup Procedure Procedure # bp Post 2010 Turnaround Nve 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 U PS- US -AK- ALL - ALL - HSE -DOC- 00313 -2 • PSM Restart Procedures for Planned & Emergency / Unplanned Shutdown UPS- US- AK -GPD- ALL - HSE -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 • ,,„44# GPMA Drill Sites Startup Procedure Procedure # bp Post 2010 Turnaround Nte 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 sy tem ,prior 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. ( -260 sig) ✓ The low- pressure shutdown switches for the reinjection compressors at LPC are set at 2300 psig an 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 # bp Post 2010 Turnaround Issue Date: 07/01/10 Rev. Date: 07/02/10 Rev. 1 NOTE: The LPP will be defeated until the u•stream choke •ressure exceeds 1500 •si: . 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 Follow -up to AOGCC questions(6- 30- eegarding LGI -10 • Page 1 Regg, James B (DOA) From: Gerik, Bob G [Bob.Gerik @bp.com] � (o�ll �� l Sent: Thursday, June 09, 2011 2:04 PM ( O L P; 1`26 I 4 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? l L I > S>>a tZ 1 Zoto Jim Regg per PIZAs r 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 Follow -up to AOGCC questions(6- 30- eegarding LGI -10 • Page 1 of 3 Regg, James B (DOA) From: Gerik, Bob G [Bob.Gerik @bp.com] f ��t.t - (D P 143 c. Sent: Tuesday, May 31, 2011 3:11 PM To: Regg, James B (DOA) F�� I Cc: Daniel, Ryan; Yeager, Kevin E; Garing, 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 Pipeline Simp Sys Dwg.doc; 40369132% 2OLGI %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 -30- 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 A ckk (. 1 ""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. b \t�\ ,/ 3) The LGI -10 1000 psi pilot has been reviewed with Operations and they have increased the pressure to a 1500 psi set point. ,i 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 \ a ,, 5) Operations will have a copy of the MOC at LGI - 10 v 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 - 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 -30- regarding LGI -10 Page 3 of 3 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. 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:iim.regqPalaska.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 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 ✓' ;;:: iN ;; 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 • Integrity Level Calculation / safety function? (e.g. modification of test y / ` o 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 I. delivered to another facility (inclusive of In addition to evaluation of above '� ``''' PSO1); 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 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 `r cs '' 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 BU 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 in the HAZOP (i.e. gas detection, HVAC, Conduct hazard review, update 4\(, 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 ✓No 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 `` No 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 - components or mechanical integrity (i.e. Add comments to this form and Yes 'N" 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. ✓1'c, 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 EO18SDV. These switches are not listed in the LPC HAZOP worksheets. Acronyms and reference docs 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 y Alaska Site Technical process conditions. Practice CRT- AK -48 -02 Discrete level for specifying the integrity requirements of Engineering Technical Practice 30 -75 / instrumented functions to be allocated to the instrumented IL Integrity level Alaska Site Technical systems Practice CRT- AK -30 -75 • Instrumented Safety function with a specified integrity level that is necessary to Engineering Technical IPF achieve functional safety by putting process to a safe state or Practice 30-75 / protective function maintaining it in a safe state under predefined conditions. Alaska Site Technical 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. Layer of protection Method for evaluating the effectiveness of protection layers in Engineering Technical LOPA reducing the frequency and /or consequence severity of Practice 48-03 / analysis hazardous events, Alaska Site Technical 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: Kiiand, Dan Date: 4/25/2011 additional reviews, as required Reviewed by Engineering Team Lead: 7,1 Kessler, Mark Date: 5/8/2011 j Reviewed by Process Berry, Jeff Date: 5/10/2011 1 r J Safety TA: Reviewed by n Whipple, Tracy Date: 5/10/2011 Engineering Authority: 1 " - Reviewed by OSM /OIM: 171 Clopton, Jeff M. Date: 5/10/2011 F • file: / /C: \Documents and Settings \gerikbg \Desktop \state temp \moc_decision_tree.htm 6/9/201 0 —oil 442' .. (....."- ...------ ......_,....... ------- Ertter/Exit ... A ..., _de.... 2 ,--..... \ r I 1 I -(:- 1 ' I I 16 n t I 0 ii \ ,,,,, ,F, ri I , 12 a L i I 101 I if if 1 i 10 A c I i . ,#. Jil I I 101 I , , 8s b Ii I 101 lif I co co , 6 A E 1 I 101 I 4 t s 11 I / ( t ' roi I ( f ----- I --,, 2 A , ; k _ Li 1 3 1 co ,) i Lc) 1 1 i , I I I . I __11 1 .1 I i I _ . , ...— ,.. I ___ - -or . Enter/Exit 111 WELL PRODUCER • or 0 WELL INJECTOR A DATE : 12/2/2010 SCALE : 1" = 100 MAP DATE : 2010 PBU - LGI WELL SLOT W/CONDUCTOR El bs14495.mxd TREE _ ? • WELLHEAD = FMC / /�� SAFETY S: WELL REQUIRES A SSSV. ACTUATOR= AXELSON L(V•� KB. ELEV = 52' BF. ELEV = - - KOP = __ 1300' Max Angle = 64 @ 9000' _ 14,302' I 2175' H5 -1/2" CAM/TRDP-1A-SSA-T SSSV, ID = 4.562" l Datum MD = Datum TVD = 8900' SS 13 -3/8" CSG, 68 #/72 #, K- 55/L -80, ID = 12.347" H 5367' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE f L 1 13215 8182 49 CA -MMI -G RKED Minimum ID = 4.125" @ 13388 CAMCO DB NIPPLE L _ 1 13319' J--I BROWN SEAL ASSY I �/ Zr-- 13335' H 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" li t 15 -1 /2" TBG IPC, 17 #, L-80, 0.0232 bpf, ID = 4.892" H I ( 1342$' H 5 -112" TUBING T A I LW / WLEG I I 13428' H ELMD TT LOG UNAVAILABLE I I TOP OF 7" LNR H 13364' I 9 -5/8" CSG, 47 #. L -80, ID = 8.681" I--I 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 I • I 14140' H 2' CCL - 26' OF 4" PERF GUN - 19" CABLEHEAD I PBTD H 14170' 1 ' +'�' ' A ' 1 ' 1 ' i ! 1 1 111 1 1 1 1 1 1 4 17" 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) TREE= 2 SAFETY WELL REQUIRESA SSSV. WELLHEAD = FMC It fl' CATI -S ip s : HES(PPM)140 ACTUATOR = AXELSON KB. ELEV = 52' 1 BF. ELEV KOP= ___ 3200' ! Max Angle = 3 @ 5_4_00' Datum M D = 972T il 2164 I-15 -112" CAMCO TRDP 1A -SSA -7 SSSV, ID = 4.562 Datum TV D = 8900' SS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 4058' 1 GAS LIFT MANDRELS ST MD ND DEV TYPE LATCH PORT DATE 1 8862 8170 21 CA /MMI -G RK Minimum ID = 4.125" @ 9012' CAMCO DB NIPPLE X g, I 8960' H 9 -5/8" BROWN 2 -B PKR, ID = 6.00" I I I 9012' I-1 5 -1/2" CAMCO DB NIP, ID = 4.125" I TOP OF 7" LNR IH 9018' I 5 -1/2" TBG -IPC, 17 #, L -80, 0.0232 bpf, ID = 4.892" H 9051' I • • I 9051' H 5 -1/2" TUBING TAIL W/WLEG I I 9051' H ELMD TT LOGGED 11/02/86 I 19 -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 _, I PBTD H 10100' 1 , ''W.W 1 17" LNR, 29 #, L -80, 0.0371 bpf, ID = 6.184" h I 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) • • • • _ _ „ - IF7.-Iffi. ittitiP Ctri ' hco, I - Wthe — — TO EMI f ,... 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' :. --- - - - -- - - . . • , ° -i. , A 11.01,1138 tYA0411.elin 1 .54 . ..2 44 CA 15.4 • 0 • • • • • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] f Sent: Thursday, June 09, 2011 4:46 PM Z%rl( 6I;c( 1( To: Regg, James B (DOA) Subject: RE: MIT and TIO Plot for LGI -02 (PTD 186140) Attachments: MIT PBU LGI -02 06- 04- 11.xIs; 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 110 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 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.redeaalaska.gov; doa .aogcc.prudhoe.bay phoebe.brooks(d)alaska.gov; torn maunderaalaska.gov 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 = Industnal 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.xIs Pis ( ULT- - -(- --- ‘ (4 ( tt PBU LGI-02 - PTD #1 861 400 6/9/2011 ITelei - 4/1Dlit TIO Pressures Plot Well: LGI-02 4,000 - rolom■ 3,000 - *1411[6.41"171°#4#f‘" ..._ I T A bg 00A III __•_ 000A 1,000 — On ., ..,„ IV 114 07/03/10 08/03/10 09/03/10 1010010 11/04/10 12/05/10 0145/11 02105/11 03/08/11 04/08/11 05/09/11 06/09/11 Injection Plot Well: LGI-02 — 1 4,000 - - 100,000 - 80,000 w — WHIP 1000 -. = a SW - 60,000 0 PW , 1,500 - 7 - 40,000 1--I GI -- o _ 1,0 - 20,000 C — Other .... On 500 1 ) 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 04108/11 05/09/11 06/09/11 : � ' � PBU L��I-10 - ��- ~ PTD 1860690 �~/ ' 6/9/2011 - `�- `J'1 ~T, // ( - ?Y ~'� '/ TI / /( ��o��a� Plot __ _�__ ____ ___ _________ __ __ _ ____ _ __ _ _ _ __ ___ _ _ __� Well: 161-10 4,0O0- . � 3,0O0' -4110 ' -1E--LA . -�--u� 2�00' ��k OOA -4-- 000A -- 1,00O- •■•■• On ~.`- . 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 05/21/11 05/28/11 06.104/ 11 . - '----------------'--- ------- -- ----------- ----------------------- ' ----- - -'--' .. - I �t _-- �-_�__ - -- -_-_' __'__ ' -� -__--__-�- __ ___ ---_ '_-- .--- _ - '_ '_'_--�-_-- - Well: 161-1 0 | ______ 4�00' . � . 80,000 ' 3,5 - 0U- -7OD00 ' ~ --- WHIP �UoU' ~GO�00 . 5-- b , - . � . ~ � 2�0 - -5�O� o pW �� ii . 2,000 -40�00 NU III �� - ' 3�0� GI 1�0O- 'n ' - ~ c, O�e � 1�U0� �z»�»v - On 500- / i -10�00 . . . . _ . . ,- . . � ' 03/12/11 03/26/11 04/88/ 1 04/23/ 1 05/O 7/ 1 05/1 06/04/11 , - - -_-----___-_ ____ __-_---_-___-_-_'__'__-_-__--_-__'-_ '-'_____------____ - - __ ' Ygafl ' eplit L c , i_ 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 /F 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 I 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 0 1 0 1 0 IN 4/28/2008 180 3 0 PRUDHOE BAY UN LIS LGI -10 1860690 1 1 1 0 1 0 IN 6/24/2008 Misc 3 1 PRUDHOE BAY UN LIS LGI -02 1861400 1 0 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 1861400 1 1 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 I 0 1 0 1 0 IN 5/11/2009 180 90 3 0 PRUDHOE BAY UN LIS LGI -06 1860670 1 0 I 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 I 0 1 0 OP 4/25/2010 180 3 0 PRUDHOE BAY UN LIS LGI -l0 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 1 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 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 -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 1of2 Regg, James B (DOA) — CC;%ri ( — From: Noble, Robert C (DOA) Sent: Tuesday, June 29, 2010 7:17 PM ;/ 6 /c' /7 4/( 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 ; 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? /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? /00 s y , 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 t' open. NitieC� I ask Dave about their remote shut down system. Our email states that it will be 25 -50 feet away. 10a4,6\ Dave told me it will be 100' away. He also showed me where they were going to be located. °Pen S. U 1-F I ask Dave what's the shut in pressure of LGI -10? , ,Sc Dave said he didn't know and we could not check right now because they were tied into the tree cap 1 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. Res ,/He told me he didn't like it and he would recommend some where from 1500 to 2000 psi set point. /509s le+ 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. Gc.0 +2c I told Dave we wanted to witness a SVS test. p 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 • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 13, 2011 To: Jim Regg t i �(l4 P.I. Supervisor jN SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC LGI -02 FROM: Matt Herrera PRUDHOE BAY UN LIS LGI -02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry . ' — NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN LIS LGI - 02 API Well Number: 50 029 - 21634 - 00 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH1 1 06092 12748 Permit Number: 186 - 140 - Inspection Date: 6/9/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well LGI -02 - Type Inj. G ' TVD 8260 ' IA J 970 I 2500 - 2480 2475 1 P.T.DI 1861400 = TypeTest SPT Test psi 2065 OA 50 75 75 75 Interval 4YRTST Pn`, P - Tubing 3320 3320 3320 3320 ■ Notes: IA tested to 2500 psi kC . t�'9'V q ] 11 Monday, June 13, 2011 Page 1 of 1 . • Page l of l Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelIlntegrityCoordinator @bp.com] Sent: Thursday, June 09, 2011 4:46 PM 6(1o( R 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) 4034,61) JUN 1 4 20Ei 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 PBU LGI -02 PTD #1861400 6/9/2011 TIO Pressures Plot Well: LGI -02 4,000 i +e r 3,000 - —- Tbg -U— IA 2,000 - —AI-- OA • 00A --.- 0 00A 1,000 On 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 Injection Plot Well: LGI -02 4,000 - - -: = 100,000 3,500 - 1 0,000 m WHIP 3,000 = - SW 2,500 - - 60,000 0 PW • 2,000 : - 40,000 C G I 1,500 - a Other 1,000 - = 20,000 p n 500 - 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 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaq(Dalaska.gov; doa .aogcc.prudhoe.bay(Dalaska.aov; phoebe.brooksc( alaska.gov; tom.maunder(Dalaska.uov t -=,e f 6, kit tl 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 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~ez'Í ~!7/07 DATE: Wednesday, June 06,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC LGI-02 PRUDHOE BAY UN LIS LGI-02 \ ~ \~O \'t~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv..Jl'92-- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN LIS LGI-02 API Well Number: 50-029-21634-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070606080341 Permit Number: 186-140-0 Inspection Date: 6/5/2007 /' Rei Insp Num: Packer Depth Pretest In itial 15 Min. 30 Min. 45 Min. 60 Min. Well LGI-02 Type Inj. G TVD 8260 IA 600 2500 2460 2460 P.T.D 1861400 TypeTest SPT Test psi 2065 OA 0 0 0 0 Interval 4YRTST PIF P / Tubing i 4000 4000 4000 4000 Notes: Pretest pressures observed and found stable. ¡/' ßCANNED JUN ·2 1 2DD7 Wednesday, June 06, 2007 Page I of I . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Lisboume I GPMA I LGI pad 06105107 Anna Cube Chuck Scheve 10' \ LVD \~ Packer Depth Pretest Initial 15 Min. 30 Min. t: Weill LGI-02 " Type Inj. I G TVD I 8,260' Tubing 3700 3700 3700 3700 Interval! 4 P.T.D.I 1861400 I/Type test I P Test psil 2065 Casing 400 2500 2500 2500 PIFI P Notes: A e witnessed MIT -IA for UIC OA 0 0 0 0 compliance. Weill LGI-10 I Type Inj. I G I TVD I 8,261' Tubing 4000 4000 4000 4000 Interval! 4 P.T.D.I 1860690 I Typetest I P I Test psil 2065 Casing 600 2500 2460 2460 PIFI P Notes: AOGCC State witnessed MIT -IA for UIC OA 0 0 0 0 compliance. Weill Type Inj. I TVD I Tubing Interval! P.T.D.I Type test I Test psil Casing PIFI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval! P.T.D·I Type testl I Test psil I Casing PIFI Notes: I OA Weill I Type Inj.1 TVD I Tubing I I Interval! P.T.D.I I Type test I I Test psi I Casing PIFI Notes: OA I TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Dìlferential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) 5~ JUN 1 2 2007 MIT GPMA LGI-û2, LGI-20 ()6.()!H)7.xls ~ .~ ~ @íF.11K\lfíÞ ciD U L#U U Lb / f { i í / i ! AI.ASIiA ORAND GAS ' CONSERVATION COMMISSION I ¡ ~n-ì r [I I 1 I .-' UdJU 1Jl~\ nLb'\ Lñ~û\ ~ G( I t\.\ ¡\ nJI \\"""\ u ~ uLJ u FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 12,2004 Mr. Bruce J. Williams GPB Operations Integrity Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage,AJ( 99519-6612 I ~.-fJfÐ Dear Ms. Williams: The Alaska Oil and Gas Conservation Commission ("Commission") performed 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 wells located on PBU LGI 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, Jf. Commissioner Attachment cc: AOGCC 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 I80-Day Well Number Permit Number Separ PSI Set PSI UP Trip Test Test Test Code Code Code Date SI Oil,WAG,GINJ, GAS,CYCLE, SI Inner PSI Outer PSI Tubing PSI YeslNo YeslNo LGI-06 1860670 4000 2900 2700 P P P lGINJ 0 0 3850 No No LGI-IO 1860690 4000 2600 1800 30 P P lGINJ 450 0 4150 No No LGI-02 1861400 4000 2900 2300 P 40 P lGINJ 200 0 4060 No No ~. ) Comments LGI-2 ssv initially failed - stroked valve, retested and passed, possibly hydrates LGI-IO pilot initially failed - cycled and retested ok at 2600psi Performance Wells 3 Components 9 Failures 2 Failure Rate 22.22% ) Wednesday, May 12,2004 MEMORANDUM TO: THRU: Randy Ruedrich Commissioner Jim Regg P.I. Supervisor FROM' State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 15, 2003 SUBJECT: Mechanical Integrity Tests BPX Prudhoe Bay Field LGI Pad John Crisp Petroleum Inspector NON- CONFIDENTIAL Prudhoe Bay Field Packer Depth Pretest Initial 15 Min. 30 Min. ] We,,ILo,-o2 IType,nj.I GI I ,ooo I ooo I,ooo I,ooo I,nterva, I 4 I P.T.D.] 1861400ITypetest] P ]Test psi] 2500 I Casing] 280 I 2500 I 2500 I 2500 I P/F ] _PI Notes: OA 240 psi. pretest 280 psi. during test. 9.1 BBL, Pumped, I Well] P.T.D.I Notes: WellI P.T.D.] Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: Type IN J. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Prudlaoe Bay to witness the 4 year MIT on LGI 02. Hard line to wellhead was used for this test as per BP policy. No failures witnessed. M.I.T.'s performed: 1_ Number of Failures: 0 Attachments: Total Time during tests: 2 hrs, cc: MIT report form 5/12/00 L.G. MIT PBU LGI 06-15-03 JC.xls 7/9/2003 ~CANtNED AUG 0 6 2003 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 (ft.) Pretest Initial 15 Min. 30 Min. P.T.D. I1861400 Type test Test psiI 2,0651 Casingl 2401 2,5001 2,4601 2,4601 P/FI P Notes: 4-year MITIA vv'"l'~'-~° I*~"~'"j' I ~ I ~'~V~l ~'~'1 ~'~°'1 'u~'n~l "'°°°1 ~'°°°1 ~'°°°1 ~'°°°1 Interva~ 4 P.T.D.I1860690 Type test I I Test psiI 2,0651 I Casin~l 2801 2,5001 2,5001 2,5001 P/FI P Notes: 4-year MITIA P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: Type Type Typel~. 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 2003-0615_MIT_PtMac_LG1-02_-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" <NSUADWWellIntegrityEngineer~BP.com> "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "AOGCC Field Inspectors (E-mail)" <AOGCC_Prudhoe_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, xl154 Emai 1: NSUADWWel 1 In tegri tyEngineer@bp, corn (Alaska) Inc. [-~MIT GPMA LGI-02, 10 06-15-03.xls Name: MIT GPMA LGI-02, 10 06-15-03.xls Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 ~:~'t Name: MIT PBU WGI-06, 07 06-15-03.xls ~__)MIT PBU WGI-06, 07 06-15-03.xls~ Type: Microsof~ Excel Worksheet (application/vnd.ms-excel) 1 of 1 6/25/2003 3:14 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Julie Heusser, DATE: Commissioner Tom Maunder ~~~SUB~CT , ~.,,,.- ...' ..~\ : P. I. Supervisor '~[ ~'5 John H Spaulding, Petroleum Inspector April 10, 2001 SVS Tests BPX PBU LGI & PM-01 April t'1,200!: I traveled to BPX's Lisbume Gas Injection (LGI) and also on to the Point Mcintyre 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, I failure, 11% failure rate PM-01, 11 wells, 33 components, 2 failures, 6% failure rate Attachment; Svs bpx Igi 4-10-0 ljs Svs bpx prn-01 4-10-01js Nqn Con.f. identi,al Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Mark Wysocki AOGCC Rep: J,,0hn ~. Spaulding Submitted By: Jo _h~,,. Spaulding Date: Field/Unit/Pad: Pt Mclntyre/PBU/PM-01 Separator psi: LPS 460 HPS 4/9/01 WeB Permit Separ Set L/P Test 'Test Test Date Oil, WAG, GIN J, Numbe, r Number PSI PSI Trip, Code Code Code Passed GAS or CYCLE 12 1910370 P 1-02 1880050 P1-03 ' '189013'0 460 ' 550 "310 P P P " OiL Pi-04" i930630 ' 460 700 700 P e ' 'P .... oiL P1-05 1930870 460 '350 300 P P 9 OIL P1-06' ' 1961370:' 4~i/ "'700 67~' e P'' ' P " OIL P1-07 1891340 Pi-08 1930980 ' 460 1500 '1260' P P '~ ....... oiL Pi-09 1961540 460 350 300 e p p OIL pl-11' 1920860 460 350 250 p' p e ..... oIL :Pl-12 1910130 Pi'-13 ' 1930740 '460 '15'00' '1156 P ' P e ....... OIL Pl-17 1930510 460 350 280 P P P OIL P1-20' 1920940' 460 350 175: 3 e '"P "4/9'/oi OiL Pi-23 1961240 .......... P1~24 1961490 PI'-GI' ' 192115'01 3600 2906 ' '"2850 P e' ' P GINJ Wells: 11 Components: 22 Failures: 2 Failure Rate: 9.09% r-190 my Remarks: P1-08 & P1-3 were choked back, hence the high, er. pilot settings P1-20 pilot reset and retested RJF 1/16/01 Page 1 of 1 010409-SVS PM-01 PBU-js Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Mark Wysocki AOGCC Rep: John H. Spa~ld~g_ Submitted By:. _John Spaulding Field/Unit/Pad: Lisbume/PBU/LGI Separator psi: LPS Date: 4/9/01 HPS 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 ~,a]~3 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: 16.670,~1~] 9o Day Remarks: LGI-02 Pilot tripped to low and was reset-retested and passed RJF 1/16/01 Page 1 ofl 010409-SVS LGI Lisburne-js DATE: 10-21-88 FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: Pressure Reports L1-9 9-5-88 Flowing Gradient Camco LGI-2 9-28-88 Flowing GRadient Camco , R EC E~//B'Y: .... . PLEASE SIGN AND RETURN TO: PAM LAMBERT ARCO ALASKA INC. 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES PLANO D&M EXXON TRANSMITTIAL # 578 STANDARD STATE OF ALASKA STATE OF ALASKA ALA,....A OIL AND GAS CONSERVATION CO, .ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] StimulateX] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska Inc. RKB 52 Feet 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, Ak 99510 Prudhoe Bay/Lisburn6 4. Location of well at surface 1365' FNL, 16321 FE1, Sec. 1, T11N, r14E, UM At top of productive interval 700 FSL, 500' FWL, Sec. 31, T12N, R15E, UM At effective depth 869' FSL, 667' FWL, Sec. 31, T12N, R15E, UM At total depth 882' FSL, 684' FWL, Sec. 31, T12N, R15E, UM 7. Well number L6!-2 8. Approval number 7-466 9. APl number 50--029-21634 10. Pool Lisburne Oil Pool 11. Present well condition summary Total depth' measured true vertical 10150' feet 9335' feet Plugs (measured) NONE Effective depth: measured true vertical Casing Length Structural 80' Conductor 4020' Surface Intermediate Production 9163' 1122' Liner Perforation depth: measured true vertical 10100 9290' Size 20" 13-3/8" feet Junk (measured) feet NONE Cemented 1750# Poleset 2200 sx AS III & 660 sx Class G Measured depth 110' 4058' 9-5/8" 800 sx class G 9198' 7" 380 sx class G 9018-10140' 9274'-9374' 8543'-8634' True Vertical depth 110' 3999' 8476' 8312-8326' ~bing (size, grade and measured depth) 5.5", L-80, 8883' Packers and SSSV(type and measured depth)Packers: 9-5/8" Brown @ 8966' SSSV: Camcc. 4..563" ID TRDP-1A 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. OiI-Bbl :' ':. Representative Daily Average Production or Injection Data .'-".',--'¢ Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 62000 0 50C 4400 Subsequent to operation 0 73000 0 50C 44 OC 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] 15.1hereby certify that the foregoing is true and correct to the best of my knowledge c~.-,,.,!' Signed O(~r~F-~ i_ aJ~l ~~ FoFm 10-404 Rev. 12-1-85 Title Technical ^~de Date 10-16-? Submit in Duplio; : .'~:~ LGI-2 ACID STIMULATION SEQUENCE OF EVENTS 8-17-87 RIG UP DOWELL SCHLUMBERGER TO PUMP 15% HCL DOWN 5-1/2" TUBING WHILE RE-INJECTING GAS AT 40 MMSCF/D AND 3900 PSI. 1045 PRESSURE TEST TO 5000 PSI 1103 PUMP 10 BBLS DIESEL W/10% MUTUAL SOLVENT AT 5 BPM AND 3855 PSI 1106 SWITCH TO ACID. PUMPED 50 BBLS 15% HCL* WITH 150 1.1 SG PERF BALLS. AVERAGE INJECTION RATE OF 4.8 BBLS/MIN @ 3700 PSI. 1117 SWITCH TO STRAIGHT ACID. PUMPED 101.6 BBLS 15% HCL* AT AN AVERAGE INJECTION RATE OF 4.5 BBLS/MIN AND 3700 PSI 1140 SWITCH TO 50/50 METHANOL-WATER MIXTURE. PUMP 6 BBLS @ 4 B/M AND 3575 PSI. SHUT DOWN FLUID PUMPER, CONTINUE DISPLACEMENT WITH RE-INJECTION GAS * ACID ADDITIVES INCLUDED 0.2% CORROSION INHIBITOR, 0.5% NON- EMULSIFIER, 0.5% NON-IONIC SURFACTANT, AND 100#/1000 GALS IRON CHELATING AGENT. LISBURNE ENGINEERING Date: 7 '3! 87 From' Pam Lambert Enclosed are the following: CH Final for LGI-2<f/ Engineered Production Log, Spinner 7-18-87 Run 1 5" Sch ~,Mudi:6g~'30!8~7~ Run ~. Westl°g CH Final for L2-6 Production Profile 7-!0-87 Run 1 5" Sch Received by: Please sign and return tolPam Lambert ARCO .AX INC. 700 G Street ATO 477 Anchorage, .AX. 99510 D & M STATE EFU<ON S T.~IDARD FILE ROOM CENTRAL FILES T P~A~N gM I TT~L # 282 ARCO Alaska, Inc Post Office ~× 1003.~0 Anchorage, Aiaska 9~5 Telephone 907 276 !215 'JULY 24, 1987 Mr. L. C. Smith - Commissioner Alaska 0il and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Smith: Attached is the Application for Sundry Approvals for the program which ARCO Alaska, Inc. proposes for restimu!ation of Lisburne well LGI-2. B. T. Kawakami Lisburne Operations Coordinator ARCO Alaska, Inc, is a SubsJdia¢'y of AtlanticRichfieldCompany STATE OF ALASKA - ALA~...A OIL AND GAS CONSERVATION CON .... ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing [] Change approved program [] Plugging~Stimulate,~ Pull tubing [] Amend order [] Perforate ~ Other Time extension 2. Name of Operator ARCO ALASKA, INC. 3. Address P.O.B. 100360, ANCHORAGE, AK, 995.10 4. Location of well at surface 1365' FI,IL, 1632' At top of productive interval FEL, Sec. 1, TllN, R14E, UH 5. Datum elevation (DF or KB) RKB 52 feet it o Pro er.y. na e, 7. Well number 8. Permit number LG'r -? 700' FSL, 500' FWL. Sec. At effective depth 869' FSL, 667' FWL, At total depth 882' FSL~ 684' FWL, 11. Present well condition summary Total depth: measured true vertical Sec. SRo. 31, T12N, 31, Ti2N, 31, TI2N, R15E, UH (app R15E, UM (app R15E, UH (app) Plugs (measured) 86-140 9. APInumber 50-- 029-21634 10. ~ol LISBURNE OIL POOL 10150' feet NONE 9 o..~,-., feet Effective depth: measured true vertical Casing Length Structural Conductor 80 ' Surface 4920 ' Intermediate Production Liner 9163 ' '~ 1 '-'~ © ' Perforation depth: mea~'u?~'d~ 9274-9374' true vertical 8543--8634 ' Tubing (size, grade and measured depth) 5. 5", L80, .,'2.,'3~¢3 ' Packers and SSSV (type and measured depth) 10100 ' feet Junk (measured) NONE ,~,,'*,-, ra, feet Size Cemented Measured depth True Vertical depth i750# POLESET 110' class G, TOP .lOB W/15O SX AS !10 ' 3999 ' III 9-5/8" 800 sx cJ. ass 7" 38e sx class G 9198 ' 8476 ' jul 2 8 1987 '-~laska 0il & Gas Cons. Commissto ;, Anchorage Packers: 9-5/8' BROWN O 8966' = ~ ID., SSSV: CAHCO 4 ~6~" TRDP-1A-SSA-T 12.Attachments Description summary of proposal/~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation 8111/87 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify thC the foregoin~ is true and correct to the best of my knowledge Signed ~'7. Title L!SBURNE OP. Commission Use Only COORD. Date 7~24/87 Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity F-} B~PTest ~ Location clearance, Approved by Commissioner the commission Date /"'.~' Form 10-403 Rev 12-1-85 ATTACHMENT i ARCO ALASKA, Inc. proposes to stimulate Lisburne well LGI-2 with 150 barrels of gelled HC1 acid with 15~ ball sealers. The acid will be pumped through tubing and the well will be re--evaluated for post injection performance. Depending on injection performance, a second stimulation using approximately the same treatment and a CTU may be done to improve injection performance, with the well being flowed back for load recovery. J ,.~ L 2 8 ~987 /~laska Oil & Gas Ctms. r.,ommisslo~ Anchoraga ARCO ALASKA i5'C. LISBURNB ~NGINBgRING Date~-9-87 From: Pam Lambert Enclosed are the following: Magnetic Tape for LGI-2 ~ ~37~_-/~/~/d OH LIS Unshifted 3-23-87 Run 1 Tape Number 71658 OH LIS Shifted 3-23-87 Run 1 Tape Number 71658 - These tapes re~ the OH LIS Tapes (Number 71658) dated 8-12-86. The density porosity and photoelectric factor curves were absent from the third logging pass high resolution LDT log data on the previous tape. J r~. ~ Received by: Please sign and return to~ Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D & M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 206 STATE OF ALASKA ALASKA ~.,~L AND GAS CONSERVATION Ot,,.MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well Gas Injector OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [~ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-140 3. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510-0360 50- 029-21634 4. Location of welt at surface 9. Unit or Lease Name 1365' FNL, 1632' FEL, Sec. 1, T11N, R14E, UH Prudhoe Bay Unit/Lisburne At Top Producing Interval 10. Well Number 666' FSL, 386' FWL, Sec. 31, T12N, R15E, UM LGI-2 , , At Total Depth 11. Field and Pool 893' FSL, 705' FWL, Sec. 31, T12N, R15E, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Li sburne 0i 1 Pool 52' RKBI ADL 34628 ALK 863 121 Date Spudded07/28/86 1~' Date T'D' R eached08/12/86 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re I 16' N°' °f C°mpleti°nsl 1/07/86* N/A feet MS L 1 · I 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)i 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10150'MD,9329'TVD 10100'MD,9285'TVD YES~[~] NO [] 2164 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run DLL/NGT/SP, LDT/GR/CNL/CAL/EPT, CET, CBL/GR/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD IAMOUNTPULLED 20" 91.5# H-40 Surf 110' 30" 1750# Pol eset 13-5/8" !68.0/72.0# K-55/L-80 Surf 4058' 17-1/2" 2200 sx AS Ill & 600 sx Class G Top job performed w/150 sx AS Ill 9-5/'8" ~7.0# L-80 Surf 9198' 12-1/4" 800 sx Class C & 300 sx CS I 7" 29.0# L-80 9018' 10140' 8-1/2" 380 sx Class G · 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET IMD) 9274'-9374'MD 8544 '-8634 'TVD 5-1/2" 9057' 8966' Perforated w/6 spf, 60° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached sequel/ce of events for Fracture data. ,. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR [OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OiL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor~) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None . · · / · /' · . , · Note: Drilled RR 08/15/86. Perforated well 11/02/86 ; : Form 10-407 DAM/WC1:156 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit indup)!/. ~ i: : i;i: 29. NAME Top Wahoo Zone 7 Top Wahoo Zone 6 Top Wahoo Zone 5 Top Wahoo Zone 4 Top Wahoo Zone 3 Top Wahoo Zone 2 Top Wahoo Zone 1 GEOLOGIC M A R I~E-R~3 .. MEAS. DEPTH Truncated 9276' 9402' 9495' 9693' 9770' 9906' 31. LIST OF ATTACHMENTS Sequence of Events TRUE VERT. DEPTH 8548' 8660' 8743' 8921' 8989' 9111' F~)RMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed_ /~-~ /~t/)OC/~_./ ~ x,'~//[ ~ Title Ass°ci ate Engi rleer Date 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- lng 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". ,rm 10-407 STATE OF ALASKA ALASKA ~J~L AND GAS CONSERVATION C.t,,¢IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVIC,E I~ Gas Tnjector 7 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-140 . 3. Address 8. APl Number P. 0. BOX 100360, Anchorage, AK 99510-0360 50- 029-21 4. Location of well at surface 9. Unit or Lease Name 1365' FNL, 1632' FEL, Sec. 1, T11N, R14E, UM Prudhoe Bay Unit/Lisburne At Top Producing Interval 10. Well Number 666' FSI, 386' FWL, Sec. 31, T12N, R15E, UM LGI-2 At Total Depth 11. Field and Pool 893' FSL, 705' F~L, Sec. 31~ T12N~ R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease Designation and Serial No. Li sburne 0i ] Pool I 52' RKB J ADL 34628 ALK 863 12. Date Spudded07/28/86 13. Date T~D. R eached08/1 2/86 14' Date C°mp" Susp' °r Aband' ~ 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns08/15/8~w N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(M~D)~ 19. Directional Survey ] 20. Depth where SSSV set 21. Thickness of Permafrost 10150'MD,9329'TVD 10100'MD,9285~TV~.. YES~ NO ~ I Z164 feetMD lqnn, (Apprn,) 22. Type Electric or Other Logs Run DLL/NGT/SP, LDT/GR/CNL/CAL/EPT, CET~ CBL/GR/CCL: Gyro 23. CASING, LINER AND CEMENTING RECORD -, SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 Surf 11 ~ ~ ~" ! 750~ Po] eset Tep job performed w/15O~'x AS 7" 29.0~ L-80 901~' 10140' ~-1/?" tRfl ~ c~,~ c 24, Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD ,. , interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None. ' 5-1/2" 9057 ' 8956 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL(MD) AMOUNT& KINDOF MATERIAL USED kl/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR IOIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubi'ng Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL el L GRAVITY-APl {corr) Press. 24-HOUR RATE ~ . , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chiC3. Form 10407 Submit in Rev. 7-1-80 CONTINUED ON REVERSE SIDE DAM/We1:156 / 29. ~, :? I-' 30.!' · : · GEOLOGIC MA R K~F~-~ " ~ ' ' . FORMATION TESTS '-.. · . . . - NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Wahoo Zone 7 Truncated N/A Top Wahoo Zone 6 9276' 8548' Top Wahoo Zone 5 9402' 8660' Top Wahoo Zone 4 9495' 8743' Top Wahoo Zone 3 9693' 8921' Top Wahoo Zone 2 9770' 8989' Top Wahoo Zone 1 9906' 9111' 31. LIST OF ATTACHMENTS Addendum (dated 11/15/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~ ~,'~~ Title Associate Engineer Date 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". 'orm 10~107 Sequence of Events LGI-2 (Wahoo 6 & 7) Gas Injector 11/03/86 Open well to tanks for a pre-stimulation flow test. Flow well 12 hours 45 minutes. WHP - 2400 psi. SI well (see attached flowback sheet for detailed production information). 11/07/86 19:01 hrs. to 20:17 hrs. SITP - 2800 psi. Rig up Halliburton to pump a perforation breakdown treatment across Wahoo 6 & 7 intervals. Pressure test lines to 4500 psi. Pump 10 bbl diesel w/10% Musol "A." Switch to 15% HCL. Total acid pumped ' 103 bbls. Displaced with 220 bbl diesel. Avg. Rate - 7 BPM @ 1200 psi. Excellent pressure break seen when acid hit peris: (2400 psi to 100 psi) Total Load - 333 bbls ISIP - 800 psi 4 mtn - well on vacuum WHP @ start of flowback - 1100 psi (21:15 hrs.) 11/07/86 21:15 hfs Open well to flow (frac tank). Recovered 173 bbl diesel at 21:50 hrs. WHP = 2400 psi. 11/09/86 03:00 Flow well through heater/separator for 27 hrs. Avg. Rate - 8 MMCFD, 400 BCPD, WHP 2 11/09/86 Well SI. Rig up Camco E-line unit RIH w/Seling pressure tool/CCL. Obtain pressure stops while RIH (outlined as follows). 09.26 hrs. 13:38 hrs. 100' MD = 2901 psi T = 42.8°F 2000' = 3159 T = 67.6° 5000' = 3527 T = 107.5° *9370' = 4011 T = 174.2° 9290' = 3980 T = 173.° 9160' = 3967 T = 170.9° 9000' = 3949 T = 168.6° 8900' = 3944 T = 167.4° Tool tied in w/short its w/0' correction. Set tool @ 9160' MD. P = 3970 psi Open well to flow, Avg. rate = 3.3 MMCFD Pressure stabilized at 3963 psi. 15:15 hrs. 16:28 17:28 LGI-2 Sequence of Events (contd) Increased choke Avg. flow rate = 9.4 MMCFD BHP = 3915 psi SI well for pressure buildup Final pressure reading = 3962 psi 47 psi drop while prod. 9.4 MMCFD POOH Job Summary The Seltng pressure gauge used in the bottom-hole pressure monitoring had a 10-15 psi pressure swing. This is the first recorded problem with this gauge. The step rate testing was cut short after the pressures would never completely stabilize. The bomb was pulled out of hole with the intent to rerun a new gauge. Due to weather and the scheduling of an offset LGI acid breakdown, the repeat survey has not yet occurred. The bomb was dead-weight tested after the job with no apparent problem. As can be seen, a "Level of Doubt" exists with the bottom-hole pressure data collected during this testing. · UB.$ URFA CE DIRECTIONAL SURVEY [~UIDANCE r~ONTINUOUS r'~OOL ~ECEIVED ~ ~p 5 0 1986 Alaska Oil & Gas Oons. {;ornmission Anchorage, Company m~co ALASKA, INC. Well Name LGI-2 (1365'FNL,1632'FEL, ! F~e~d/tocaflon PRUDHOE B, AY/LISBURNE POOL, SEC. 1, TllN, R14E, UM) NORTH SLOPE, ALASKA ! Job Reference No. 71714 Lo~3~3ed ay: SARBER Date 9/8/86 Commuted By.' KRUWELL GOT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. LGI-2 PRUOHOE BAY-LIS6URNE POOL NGRTH SLOPE,ALASKA SURVEY DATE: 08-SEPT-86 ENGINEER: SARBER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTEO ONTO A TARGET AZIMUTH OF NORTH 45 OEG 55 MIN EAST ARCO ALASKA, INC. LGI-2 PRUDHOE BAY-LISBURNE PDCL NORTH SLOPE,ALASKA COMPUTATION DATE: 22-SEP-86 PAGE DATE OF SURVEY: 08-SEPT-86 KELLY BUSHING ELEVATION: ENGINEER: SARBER 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 ~z'O0 FT VERTICAL DOGLEG RECTANGULAR COORDINA'TES dORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -52.00 0 0 N 0 0 E 0.00 0.00 0.00 N 100.00 100.00 48.00 0 6 S 74 17 W -0.04 0.56 0.10 N 200.00 200.00 148.00 0 18 S 5 7 E -0.36 0.12 0.28 S 300.00 300.00 248.00 0 19 S 13 52 E -0.65 0.07 0.83 S 400.00 400.00 348.00 0 19 S 16 53 E -0.93 0.05 1.38 S 500.00 499.99 447.99 0 19 S 19 31 E -1.18 0.08 1.92 S 600.00 599.99 547.99 0 20 S 22 24 E -1.40 0.08 2.46 S 700.00 699.99 647.99 0 16 S 30 46 E -1.57 0.04 2.95 S 800.00 799.99 747.99 0 22 S 13 29 W -1.88 0.09 3.48 S 900.00 899.99 847.99 0 17 S 25 47 W -2.42 0.06 4.04 S 1000.00 999.99 947.99 1100.00 1099.99 1047.99 1200.00 1199.98 1147.98 1300.00 1299.98 1247.98 1400.00 1399.98 1347.98 1500.00 1499.98 1447.98 1600.00 1599.98 1547.98 1700.00 1699.97 1647.97 1800.00 1799.97 1747.97 1900.00 1899.97 1847.97 0 14 S 25 10 W -2.85 0.12 4.46 S 0 11 S 30 19 W -3.20 0.06 4.78 S 0 4 S 51 57 W -3.47 0.20 5.01 S 0 8 N 43 57 E -3.42 0.23 4.97 S 0 23 N 44 55 E -2.94 0.21 4.65 S 0 27 N 29 38 ~ -2.19 0.08 4.04 S 0 29 N 27 38 E -1.40 0.05 3.30 S 0 28 N 57 12 E -0.58 0.02 2.67 S 0 24 N 54 30 E 0.20 0.17 2.23 S 0 20 N 13 11 E 0.77 0.10 1.74 S 0 20 N 11 16 E 1.26 0.03 1.16 S 0 20 N 12 43 E 1.75 0.08 0.57 S 0 18 N 58 25 E 2.32 0.18 0.19 S 0 22 N 14 44 E 2.84 0.07 0.30 N 0 25 N 13 57 E 3.44 0.08 0.99 N 0 24 N 11 6 E 4.08 0.11 1.73 N 0 20 N 5~ 47 E 4.65 0.25 2.31 N 1 9 N 43 0 E 5.62 1.48 2.95 N 3 45 N 49 15 E 10.06 1.44 5.84 N 5 36 N 48 51 E 18.38 0.99 11.47 N N 53 35 E 29.92 0.86 N 47 23 E 43.67 2.27 N 41 23 E 59.58 3.02 N 42 55 E 79.83 1.95 N 42 7 E 103.92 2.34 N 44 45 E 131.78 1.68 N 44 39 E 162.13 3.13 N 46 13 E 196.58 2.20 N 45 29 E 234.70 2.67 N 40 7 E 276.58 4.64 2000.00 1999.97 1947.97 2100.00 2099.96 2047.96 2200.00 2199.96 2147.96 2300.00 2299.96 2247.96 2400.00 2399.96 2347.96 2500.00 2499.96 2447.96 2600.00 2599.95 2547.95 2700.00 2699.95 2647.95 2800.00 2799.83 2747.83 2900.00 2899.48 2847.48 3000.00 2998.79 2946.79 7 32 3100.00 3097.84 3045.84 8 26 3200.00 3196.55 3144.55 10 12 3300.00 3294.46 3242.46 12 50 3400.00 3391.49 3339.49 15 18 3500.00 348].52 3435.52 16 55 3600.00 3582.80 3530.80 18 46 3700.00 3676.66 3624.66 21 19 3800.00 3769.10 3717.10 23 34 3900.00 3859.87 3807.87 25 59 0.00 E 0.15 W 0.22 W 0.11 W 0.O5 E 0.22 E 0.43 E 0.68 E 0.74 E 0.55 E 0.35 E 0.18 E 0.03 E 0.05 E 0.41 0.86 E 1.24 E 1.77 E 2.44 E 2.75 E 0.00 N 0 0 E 0.18 N 56 6 W 0.36 S 37 43 W O. 83 S 7 31" 1.38 S 2 1 '[~ 1.93 S 6 32 c 2.50 S 9 55 E 3.03 S 12 52 E 3,56 S 12 4 E 4.08 S 7 44 E 4.47 S 4 29 E 4.79 S 2 6 E 5.01 S 0 20 E 4.97 S 0 34 E 4.67 S 5 2 E 4.13 S 11 59 E 3.53 S 20 40 E 3.20 S 33 37 E 3.30 S 47 34 E 3.26 S 57 47 E 2.87 E 2.99 E 3.40 E 3.66 E 3.84 E 4.00 E 4.23 E W.97 E 8.35 E 14.48 E 3. I0 S 68 0 E 3.05 S 79 15 E 3.41 S 86 52 E 3.67 N 85 20 E 3.96 N 75 33 4.36 N 66 38 4.82 N 61 24 E 5.78 N 59 20 E 10.19 N 55 3 E 18.47 N 51 37 f 18.63 N 23.61 E 30.08 N 51 43 E 27.14 N 34.50 E 43.90 N 51 48 E 38.75 N 45.41 f 59.10 N 49 31 E 53.81 N 59.02 E 75.87 N 47 38 E 71.65 N 75.28 E 103.93 N 46 24 E 91.83 N 94.52 E 131.78 N 45 49 E 113.48 N 115.80 E 162.13 N 45 34 E 137.37 N 140.62 E 196.58 N 45 40 E 163.89 N 168.00 E 234.71 N 45 42 E 194.24 N 196.91 E 276.59 N 45 23 E COMPUTATION DATE: 22-SEP-86 PAGE 2 ARCO ALASKA, INC. DATE OF SURVEY: 08-SEPT-86 LGI-2 PRUDHOE BAY-LISBURNE POOL NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: SARBER 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 4000.00 3948.75 3896.75 28 22 4100.00 4036.30 3984.30 29 2 4200.00 4123.40 4071.40 29 47 4300.00 4210.01 4158,01 30 8 4400.00 4296.26 4244.26 30 38 4500.00 4382.23 4330,23 30 59 4600.00 4467.59 4415.59 31 35 4700.00 4552.54 4500.54 31 59 4800.00 4637.07 4585.07 32 37 4900.00 4721.10 4669.10 33 0 5000.00 4804.80 4752.80 33 23 5100.00 4888.05 4836.05 33 40 5200.00 4971.17 4919,17 33 59 5300.00 5053,86 5001.86 34 25 5400.00 5136.08 5084.08 34 49 5500.00 5218.16 5166.16 34 49 5600.00 5300.24 5248.24 34 42 5700.00 5382.69 5330.69 33 58 5800.00 5466.26 5414.26 32 33 5900.00 5550.91 5498.91 31 25 6000.00 5637.16 5585.16 30 9 6100.00 5723.14 5671.14 31 10 6200.00 5808.45 5756.45 31 19 6300.00 5894.14 5842,14 30 58 6400.00 5979.80 5927.80 31 12 6500.00 6065.00 6013.00 31 51 6600.00 6149.63 6097.63 32 30 6700.00 6233.79 6181.79 32 43 6800.00 6318.02 6266.02 32 23 6900.00 6402.81 6350.81 31 34 7000.00 6488.21 6436.21 31 10 7100.00 6573.94 6521.94 30 46 7200.00 6660.17 6608.17 30 3 7300.00 6747.08 6695.08 29 14 7400.00 6834.57 6782.57 28 37 7500.00 6922.72 6870.72 27 35 7600.00 7011.84 6959.84 26 37 7700.00 7101.37 7049.37 26 15 7800.00 7191,17 7139.17 25 57 7900.00 7281.26 7229.26 25 32 52.0o Fi VERTICAL DOGLEG RECTANGULAR CODRDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH PEET DEG/IO0 FEET FEET PEET DEG MIN N 35 20 E N 35 22 E N 36 5 E N 36 38 E N 36 55 E N 37 1E N 37 4 E N 37 17 E N 37 gE N 37 12 E 321.78 1.82 369.26 0.37 417.62 0.73 466.92 0.39 516.88 0.29 567.34 1.23 618.81 0.44 670.95 0.16 723.76 0.52 777.35 0.37 230.95 N 224.29 E 321.94 N 44 9 E 270.42 N 252.15 E 369.73 N 42 59 E 310.34 N 280.81 E 418.53 N 42 8 E 350.55 N 310.50 E 468.29 N 41 31 : 391.07 N 340.80 E 518.73 N 41 4 431.86 N 371.54 E 569.69 N 40 42 = 473.48 N 402.89 E 621.69 N 40 23 E 515.47 N 434.80 E 674.36 N,40 8 E 558.01 N 467.I3 E 727.72 N 39 56 E 601.22 N 499.88 E 781.88 N 39 44 E N 37 18 E 831.44 N 37 25 E 886.23 N 37 24 E 941.21 N 37 41 E 996.84 N 38 8 E 1053.21 N 38 28 E 1109.82 N 39 29 E 1166.51 N 40 49 E 1222.82 N 40 45 E 1277.53 N 40 31 E 1330.52 0.87 0.28 0.58 0.89 0.31 0.28 1.13 1.26 1.34 2.80 644.77 N 533.00 f 836.55 N 39 34 E 688.79 N 566.64 E 891.91 N 39 26 E 732.96 N 600.40 E 947.48 N 39 19 E 777.55 N 634.66 E 1003.68 N 39 13 E 822.48 N 669.63 E 1060.60 N 39 9 E 867,29 N 705.03 E 1117.70 N 39 6 E 911.80 N 740.84 E 1174.83 N 39 5 E 954.99 N 777.41 E 1231.41 N 39 8 E 996.46 N 813.39 E 1286.29 N 39 13 E 1036.85 N 848.06 E 1339.49 N 39 16 E N 42 8 E 1380.92 N 45 12 E 1431.95 N 47 39 E 1484.11 N 49 54 E 1535.59 N 49 43 E 1587.06 N 49 48 E 1639.29 N 49 49 E 1692.44 N 49 57 E 1746.33 N 50 41 E 1800,07 N 50 39 E 1852.88 2.11 1.66 1.84 0.36 0.66 0.61 0.51 0.47 0.78 0.54 1075.11 N 881.16 E 1390.08 N 39 20 E 1111.97 N 916.49 E 1440.98 N 39 29 E 1147.97 N 954.25 E 1492.79 N 39 44 E 1181.77 N 993.18 E 1543.69 N 40 2 E 1215.02 N 1032.62 E 1594.55 N 40 21 ~ 1248.84 N 1072.58 E 1646.21 N 40 39 1283.21 N 1113.28 E 1698.83 N 40 56 ~ 1318.05 N 1154.56 E 1752.22 N 41 13 E 1352.45 N 1196.06 E 1205.46 N 41 29 E 1385.98 N 1237.11 E 1857.79 N 41 45 E N 50 15 E 1904.74 N 50 2 E 1956.09 N 50 11 E 2006.60 N 50 14 E 2055.91 N 50 25 E 2104.20 N 50 26 E 2151.26 N 50 16 E 2196.49 N 50 18 E 2240.90 N 50 22 E 2284.76 N 50 12 E 2328.05 0.38 0.54 0.69 0.56 0.86 1.56 0.30 0.33 0.35 0.26 1419.09 N 1277.23 E 1909.23 N 41 59 E 1452.11 N 1316.74 E 1960.21 N 42 12 E 1484.57 N 1355.61 E 2010.38 N 42 24 E 1516.22 N 1393.61 E 2059.38 N 42 35 E 1547.15 N 1430.89 E 2107.39 N 42 45 E 1577.18 N 1467.30 E 2154.17 N 42 55 E 1606.14 N 1502.23 E 2199.18 N 43 5 E 1634.59 N 1536.49 E 2243.37 N 43 13 E 1662.67 N 1570.36 E 2287.03 N 43 21 E 1690.39 N 1603.77 E 2330.13 N 43 29 E COMPUTATION DATE: 22-SEP-86 PAGE 3 ARCO ALASKA, INC. DATE OF SURVEY: 08-SEPT-86 LGI-2 PRUDHOE BAY-LISBURNE POOL NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: SARBER 52.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR. COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 7371.59 7319.59 25 14 8100.00 7462.16 7410.16 24 55 8200.00 7553.03 7501.03 24 24 8300.00 7644.20 7592.20 24 3 8400.00 7735.83 7683.83 23 1 8500.00 7828.33 7776.33 21 33 8600.00 T921.81 7869.81 20 4 8700.00 8016.19 7964.19 lB 54 8800.00 8110.49 8058.49 20 16 8900.00 8203.74 8151.74 21 53 N 49 57 E 2370,82 N 49 48 E 2413.13 N 49 17 E 2454.78 N 49 20 E 2495.81 N 49 39 E 2535.75 N 51 17 E 2573.64 N 52 37 E 2508.94 N 53 58 E 2641.74 N 54 30 E 2674.61 N 53 25 E 2710.35 0.31 0.40 0.47 0.74 1.15 1.83 1.50 0.97 2.00 1.32 1717.91 N 1636.66 E 2372.74 N 43 36 E 1745.24 N 1669.10 E 2414.90 N 43 43 E 1772.30 N 1700,88 E 2456.42 N 43 49 E 1799.14 N 1731.99 E 2497.34 N 43 54 1825.12 N 1762.44 E 2537.17 N 43 55 1849.37 N 1791.69 E 2574.95 N 44 5 c 1871.20 N 1819.69 E 2610.11 N 44 12 E 1891.02 N 1846.17 E 2642.78 N 44 18 E 1910.32 N 1873.22 E 2675.50 N 44 26 E 1931.56 N 1902.40 E 2711.10 N 44 33 9000.00 8296.06 8244.06 23 22 9100.00 8387.28 8335.28 25 1 9200.00 8477.28 8425.28 26 17 9300.00 8566.95 a514.95 26 3 9400.00 8656.98 8604.98 25 44 9500.00 8746.98 8694.98 25 59 9600.00 8836.76 8784.76 26 14 9700.00 8926.40 8874.40 26 22 N 52 36 E 2748.49 N 52 20 E 2789.21 N 53 6 E 2832.50 N 52 37 E 2876.40 N 52 2 E 2919.67 N 52 18 E 2963.00 N 52 35 E 3006.74, N 53 8 E 3050.76 9800.00 9015.96 8963.96 26 28- N 53 35 E 3094.88 9900.00 9105.51 9053.51 26 21 N 53 56'E 3138.94 1.43 1.71 0.62 0.97 0.11 0.34 0.35 0.25 0.29 0.25 1954.68 N 1933.11 E 2749.13 N 44 40 E 1979.66 N 1965.50 E 2789.74 N 44 47 E 2006.17 N 2000.20 E 2832.93 N 44 54 E 2032.71 N 2035.60 E 2876.73 N 45 2 E 2059.39 N 2070.01 E 2919.93 N 45 8 E 2086.13 N 2104.43 E 2963.20 N 45 15 E 2112.98 N 2139.32 E 3006.89 N 45 21 E 2139.74 N 2174.68 E 3050.85 N 45 27 E 2166.31 N 2210.37 E 3094.93 N 45 34 E 2192.60 N 2246.25 E 3138.96 N 45 41 E 10000.00 9195.13 9143.13 26 20 10100.00 9284.65 9232.65 26 33 10150.00 9329.37 927T.37 26 33 N 54 10 E 3182.84 N 54 31 E 3226.95 N 54 31 E 3249.04 0.17 0.00 0.00 2218.63 N 2282.15 E 3182.85 N 45 48 E 2244.58 N 2318.41 E 3226.95 N 45 55 E 2257.55 N 2336.61 E 3249.05 N 45 59 E COMPUTATION DATE: 22-SEP-86 PAGE 4 ARCO ALASKA, INC. DATE OF SURVEY: 08-SEPT-86 LGI-2 PRUDHOE BAY-LISBURNE POOL NORTH SLOPE~ALASKA KELLY BUSHING ELEVATION: ENGINEER: SARBER 52. O0 FT INTERPOLATED VALUES FOR EVEN 1000 FmET DF MEASURED OEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTIC4L DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGUL4R COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST GIST. AZIMUTH PEET DEG/IO0 PEET PEET PEET OEG MIN 0.00 0.00 -52.00 0 0 1000.00 999,99 947.99 0 14 2000.00 1999.97 1947.97 0 20 3000.00 2998.79 2946,79 7 32 4000.00 3948.75 3896.75 28 22 5000.00 4804.80 4752.80 33 23 6000.00 5637.16 5585.16 30 9 7000.00 6488.21 6436,21 31 10 8000.00 7371.59 7319.59 25 14 9000.00 8296.06 8244.06 23 22 N 0 0 E 0.00 S 25 10 W -2.85 N 11 16 E 1.26 N 53 35 E 29.92 N 35 20 E 321.78 N 37 18 E 831.44 N 42 8 E 1380.92 N 50 15 E 1904.74 N 49 57 E 2370.82 N 52 36 E 2748.49 0.00 0.12 0.03 0.86 1.82 0.87 2.11 0.38 0.31 1.43 0.00 N 0.00 E 0.00 N 0 0 E 4.46 S 0.35 E 4.47 S 4 29 E 1.16 S 2.57 E 3.10 S 68 0 E 18.63 N 23.61 E 30.08 N 51 43 230.95 N 224.29 E 321.94 N 44 9 644.77 N 533.00 E 836.55 N 39 34 107:3.11 N 881.16 E 1390.08 N 39 20 E 1419.09 N 1277.23 E 1909.23 N 41 59 1717.91 N 1636.66 E 2372.74 N 43 36 E 1954.68 N 1933.11 E 2749.13 N 44 40 E 10000.00 9195.13 9143.13 26 20 10150.00 9329.37 9277.37 26 33 N 54 10 E 3182.84 N 54 31 E 3249.04 0.17 0.00 2218.63 ,N 2282.15 E 3182.85 N 45 48 E 2257.55 N 2336.51 E 3249.05 N 45 59 E COMPUTATION DATE: 22-SEP-86 PAGE 5 ARCO ALASKA, INC. DATE OF SURVEY: 08-SEPT-86 LGI-2 PRUDHOE BAY-LISBURNE POOL NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: SARBER 52.00 Fl INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA 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 0.00 0.00 -52.00 0 0 N 0 0 E 52.00 52.00 0.00 0 20 N 51 0 W 152.00 152.00 100.00 0 14 S 9 10 W 252.00 252.00 200.00 0 19 S 13 26 E 352.00 352.00 300.00 0 20 S 16 10 E 452.01 452.00 400.00 0 19 S 17 38 E 552.01 552.00 500.00 0 20 S 21 25 E 652.01 652.00 600.00 0 19 S 26 16 E 752.01 752.00 700.00 0 19 S 10 29 E 852.01 852.00 800.00 0 20 S 18 41 W 0.00 0.00 0,00 N 0.00 E -0.01 2.15 0.05 N 0.06 W -0.18 0.36 0.04 S 0.22 W -0.52 0.10 0.56 S 0.17 W -0.80 0.13 1.12 S 0.03 W -1.06' 0.10 1.6a S 0.13 E -1.29 0.03 2.20 S 0.33 E -1.51 0.15 2.74 S 0.55 E -1.65 0.72 3.18 S 0.79 E -2.17 0.08 3,80 S 0.65 E 0.00 N 0 0 0.08 N 53 17 W 0,22 S 80 44 W 0,59 S 17 16 "~ 1.12 S I 37 1.66 S 4 34 2.22 S 8 28 E 2.80 S 11 23 E 3.28 S 13 54 E 3.85 S 9 42 E 952.01 952.00 900.00 1052.01 1052.00 1000.00 1152.02 1152.00 1100.00 1252.02 1252.00 1ZOO.O0 1352.02 1352.00 1300.00 1452.02 1452.00 1400.00 1552.02 1552.00 1500.00 1652.02 1652.00 1600.00 1752.03 1752.00 1700.00 1852.03 1852.00 1800,00 0 15 S 25 2 W 0 12 S 29 56 W 0 10 S 29 33 W 0 I N 5 59 W 0 16 N 50 12 E 0 26 N 34 40 E 0 28 N 26 56 E 0 29 N 38 2 E 0 27 N 56 1 E 0 19 N 28 41 E -2,65 0.02 4.26 S 0.44 E -3.05 0.15 4.64 S 0,26 E -3.36 0.15 4.93 S 0.09 E -3.49 0.26 5.03 S 0.00 E -3,23 0.27 4.85 S 0.19 E -2.56 0.14 4.36 S 0.66 E -1.78 0.05 3.66 S 1.06 E -0.98 0.67 2.91 S 1.46 E -0.17 0.03 2.44 S 2.13 E 0.52 0.60 2.01 S 2.68 E 4.29 S 5 54 F 4.65 S 3 9 E 4.93 S I 5 E 5.03 S 0 2 E 4.85 S 2 17 E 4.41 S 8 35 E 3,81 S 16 7 E 3.25 S 26 36 E 3.24 S 41 9 E 3.35 S 53 3 E 1952.03 1952.00 1900.00 2052.03 2052.00 2000.00 2152.04 2152.00 2100.00 2252.04 2252.00 2200.00 2352.04 2352.00 2300.00 2452.04 2452.00 2400.00 2552.05 2552.00 2500.00 2652.05 2652.00 2600.00 2752.08 2752.00 2700.00 2852.31 2852.00 2800.00 0 19 N 10 35 E 0 21 N 10 59 E 0 20 N 57 43 E 0 20 N 21 16 E 0 24 N 13 49 E 0 26 N 12 29 E 0 23 N 14 25 E 0 27 N 53 13 E 2 42 N 50 25 E 4 53 N 46 24 E 1.03 0.09 1.43 S 2.82 E 1.52 0.04 0.85 S 2.94 E 2.05 0.16 0.33 S 3.16 E 2.58 0.54 0.00 N 3.58 E 3.15 0.08 0.65 N 3.75 E 3.79 0.06 1.38 N 3.93 E 4.37 0.19 2.07 N 4.07 E 4.97 0.93 2.48 N 4.51 E 7.25 3.82 4,04 N 6.18 E 13.97 2.04 8.49 N 11.23 E 3.16 S 63 2 E 3.06 S 73 47 E 3.18 S 84 7 E 3.58 N 89 58 3.81 N 80 13 4.17 N TO 40 4.57 N 63 1 5.15 N 61 8 E 7.38 N 56 51 E 14.08 N 52 54 E 2952.82 2952.00 2900.00 6 51 3053.69 3052.00 3000.00 7 57 3154.81 3152.00 3100.00 9 11 3256.52 3252.00 3200.00 11 54 3359.15 3352.00 3300.00 14 13 3462.93 3452.00 3400.00 16 20 3567.58 3552.00 3500.00 18 0 3573.55 3652.00 3600.00 20 %4 3781.37 3752.00 3700.00 23 7 3891.26 3852.00 3800.00 25 47 N 52 18 E 23.95 3.53 N 52 30 E 37.08 1.59 N 42 39 E 52.01 1.92 N 42 7 E 70.47 2.65 N 42 9 E 93.51 2.97 N 44 0 E 121.17 1.85 N 44 22 E 152.00 2.04 N 46 35 E 187.02 2.48 N 45 47 E 227.31 2.50 N 40 49 E 272.81 4.39 15.02 N 18.80 E 24.06 N 51 22 E 22.91 N 29.43 E 37.29 N 52 5 E 33.10 N 40.35 E 52.19 N 50 38 E 46.94 N 52.64 E 70.53 N 48 16 E 63.88 N 68.32 E 93.53 N 46 55 E 84.28 N 87.06 E 121.17 N 45 55 E 106.21 N 108.74 5 152.00 N 45 40 E 130.77 N 133.71 5 187.03 N 45 38 E 158.73 N 162.71 E 227.31 N 45 42 E 191.41 N 194.40 E 272.82 N 45 26 E COMPUTATION DATE: 22-SEP-86 PAGE 6 ARCO ALASKA, INC. DATE OF SURVEY: 08-SEPT-86 LGI-2 PRUDHDE BAY-LISBURNE POOL NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: SARBER 52. OD FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA 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/IO0 FEET FEET FEET DEG MIN 4003.70 3952.00 3900.00 28 26 4117.95 4052.00 4000.00 29 11 4232.99 4152.00 4100.00 29 55 4348.61 4252.00 4200.00 30 23 4464.82 4352.00 4300.00 30 43 4581.71 4452.00 4400.00 31 31 4699.36 4552.00 4500.00 3I 59 4817.72 4652.00 4600.00 32 42 4936.87 4752.00 4700.00 33 9 5056.67 4852.00 4800.00 33 40 N 35 18 E N 35 27 E N 36 21E N 36 47 E N 37 0 E N 37 I E N 37 17 E N 37 8 E N 37 14 E N 37 23 E 323.52 1.71 377.82 0.99 433.82 0.52 491.09 0.62 549.55 0.32 609.36 0.27 570.62 0.16 733.20 0.48 797.23 0.59 862.45 0.39 232.39 N 225.31 E 323.68 N 44- 6 E 277.51 N 257.20 E 378.37 N 42 49 E 323.59 N 290.52 E 434.87 N 41 55 E 370.18 N 325.14 E 492.70 N 41 17 - 417.50 N 360.69 E 551.73 N 40 49 465.85 N 397.I2 E 612.14 N 40 26 E 515.20 N 434.60 E 674.03 N 40 8 E 565.63 N 472.89 E 737.27 N 39 53 E 617.22 N 512.05 E 801.97 N 39 40 E 669.70 N 552.03 E 867.89 N 39 29 ~ 5176.90 4952.00 4900.00 33 52 5297.75 5052,00 5000.00 34 25 5419.40 5152.00 5100.00 34 51 5541.24 5252.00 5200.00 34 51 5662.90 5352.00 5300.00 34 24 5783.12 5452.00 5400.00 32 46 5901.27 5552.00 5500.00 31 23 6017.18 5652.00 5600.00 30 19 6133.79 5752.00 5700.00 31 26 6250.87 5852.00 5800.00 30 59 N 37 23 E 928.46 N 37 41 E 995.59 N 38 13 E 1064.19 N 38 43 E 1133.20 N 40 24 E 1202.07 N 40 49 E 1268.53 N 40 31 E 1331.17 h 42 42 E 1389.57 N 45 58 E 1449.51 N 49 8 E 1510,38 0.48 0.85 0.26 0.55 1.53 2.20 2.78 2.12 1.23 1.46 722.71 N 592.58 E 934.59 N 39 20 E 776.55 N 633.88 E 1002.41 N 39 13 E 831.19 N 676.48 E 1071.68 N 39 8 E 885.72 N 719.72 E 1141.27 N 39 5 E 939.17 N 763.83 E 1210.57 N 39 7 E 989.61 N 807.50 E 1277.25 N 39 12 E 1037.34 N 848.48 E 1340.15 N 39 16 E 1081.48 N 887.03 E 1398.72 N 39 21 E 1124.25 N ' 929.0b E 1458.45 N 39 34 E 1165.43 N 973.91 E 1518.79 N 39 53 E 6367.54 5952.00 5900.00 31 5 6484.71 6052.00 6000.00 31 46 6602.81 6152.00 6100.00 32 31 6721.64 6252.00 6200.00 32 40 6840.19 6352.00 6300.00 32 7 6957.65 6452.00 6400.00 31 19 7074.45 6552.00 6500.00 30 53 7190.56 6652.00 6600.00 30 7 7305.63 6752.00 6700.00 29 13 7419.83 6852.00 6800.00 28 26 N 49 48 E 1570.33 N 49 48 E 1631.25 N 49 49 E 1693.95 N 50 7 E 1757.99 N 50 46 E 1821.44 N 50 26 E 1882.84 N 50 2 E 1943.03 N 50 11 E 2001.88 N 50 15 E 2058.65 N 50 27 E 2113.63 0.27 0.49 0.50 0.60 0.70 0.47 0.48 0.52 0.55 0.91 1204.18 N 1019.83 E 1578.01 N 40 15 E 1243.64 N 1066.42 E 1638.26 N 40 36 E 1284.18 N 1114.44 E 1700.33 N 40 57 E 1325.57 N 1163.51 E 1763.77 N 41 16 F 1366.01 N 1212.68 E 1826.63 N 41 35 1405.07 N 1260.32 E 1887.49 N 41 53 ~ 1443.70 N 1306.71 E 1947.24 N 42 8 E 1481.54 N 1351.98 E 2005.70 N 42 22 E 1517.97 N 1395.72 E 2062.10 N 42 35 E 1553.17 N 1438.18 E 2116.76 N 42 47 E 7532.95 6952.00 6900.00 27 9 7644.91 7052.00 7000.00 26 28 7756.41 7152.00 7100.00 26 4 7867.56 7252.00 7200.00 25 38 7978.33 7352.00 7300.00 25 18 8088.80 7452.00 7400.00 24 58 8198.88 7552.00 7500.00 24 24 8308.54 7652.00 7600.00 23 59 8417.54 7752.00 7700.00 22 47 8525.40 7852.00 7800.00 21 10 N 50 23 E 2166.33 N 50 17 E 2216.52 N 50 20 E 2265.70 N 50 16 E 2314.08 N 50 0 E 2361.59 N 49 49 E 2403.42 N 49 17 E 2454.32 N 49 23 E 2499.27 N 49 51 E 2542.55 N 51 44 E 2582.83 1.13 0.47 0.32 0.40 0.30 0.36 0.48 0.81 1.40 1.64 1586.82 N 1478.95 E 2169.17 N 42 59 E 1618.97 N 1517.68 E 2219.11 N 43 9 E 1650.47 N 1555.64 E 226~l.05 N 43 18 E 1681.43 N 1593.00 E 2316.22 N 43 27 E 1711.96 N 1629.58 E 2363.54 N 43 35 E 1742.19 N 1665.49 E 2410.20 N 43 42 E 1771.99 N 1700.53 E 2455.96 N 43 49 E 1801.39 N 1734.63 E 2500.79 N 43 55 E 1829.52 N 1767.63 E 2543.95 N 44 0 E 1855.10 a 1798.93 E 2584.10 N 44 7 E COMPUTATION DATE: 22-SEP-85 PAGE 7 ARCO ALASKA, INC. DATE OF SURVEY: 08-SEPT-86 LGI-2 PRUDHOE BAY-LISBURNE POCL NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: SARBER 52.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL'VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES mORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8632.09 7952.00 7900.00 19 33 8737.87 8052.00 8000.00 19 11 8844.37 8152.00 8100.00 21 5 8952.12 8252.00 8200.00 22 37 9061.15 8352.00 8300.00 24 20 9171.81 8452.00 8400.00 26 9 9283.36 8552.00 8500.00 26 11 9394.47 8652.00 8600.00 25 44 3505.58 8752.00 8700.00 26 0 9616.99 8852.00 8800.00 26 16 N 52 57 E 2619.75 N 54 27 E 2653.91 N 54 1 E 2690.12 N 53 2 E 2729.90 N 52 23 E 2773.06 N 52 43 E 2820,11 N 52 49 E 2869.14 N 52 3 E 2917.28 N 52 18 E 2965.43 N 52 40 E 3014.21 1.72 1.32 1.74 1.91 2.05 1.17 1.13 0.10 0.33 0.40 1877.78 N 1828.37 E 2620.88 N 44 14 E 1898.19 N 1856.16 E 2654.89 N 44 21 E 1919.47 N 1885.96 E 2690.95 N 44 29 E 1943.36 N 1918.19 E 2730.59 N 44 37 ~ 1969.74 N 1952.74 E 2773.63 N 44 45 1998.65 N 1990.24 E 2820.57 N 44 52 ~ 2028.28 N 2029.80 E 2869.49 N 45 1 E 2057.91 N 2068.11 E 291?.55 N 45 8 E 2087.62 N 2106.37 E 2965.63 N 45 15 E 2117.54 N 2145.29 E 3014.34 N 45 22 E 9728.58 8952.00 8900.00 26 23 9840.27 9052.00 9000.00 26 24 9951.87 9152.00 9100,00 26 19 10063.50 9252.00 9200.00 26 33 10150.00 9329.37 9277.37 26 33 N 53 14 E 3063.35 N 53 45 E 3112.67 N 54 2 E 3161.73 N 54 31 E 3210.82 N 54 31 E 3249.04 0.21 0.44 0.16 0.00 0.00 2147.35 N 2184.84 E 3063.44 N 45 29 E 2176.94 N 2224.84 6 3112.71 N 45 37 E 2206.12 N 2264.87 E 3161.74 N 45 45 E 2235.i1 N 2305.i3 E 3210.82 N 45 53 E 2257.55 N 2336.61 E 3249.05 N 45 59 E COMPUTATION DATE: 22-SEP-86 PAGE 8 ARCO ALASKA, INC. DATE-OF SURVEY: 08-SEPT-86 LGI-2 PRUDHOE BAY-LISBURNE POOL NORTH SLOPEtALASKA KELLY BUSHING ELEVATION: ENGINEER: SARBER 52. O0 FT INTERPOLATED VALUES FOR CHOSEN HORIZONS MARKER MEASURED OEPTH BELOW KB SURFACE LocATION AT ORIGIN: 1365 FNLm 1632 FEL, SEC 1, TllNs R14E, UM ?VD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST TOP WAHOO ZONE 7 TOP WAHOO ZONE 6 TOP WAHOO ZONE 5 TOP WAHOO ZONE 4 TOP WAHOO ZONE 3 TOP WAHOO ZONE 2 TOP WAHOO ZONE 1 PBTD TD TRUNCATED 9276.00 9402.00 9495.00 9893.00 9770°00 9906.00 10100o00 10150.00 8547.55 8495.55 2030.85 N 2018.43 E 8660.2? 8608.27 2053.53 N 2064.30 E 8743.46 8691.46 2087.65 N 2098.16 E 8920.57 8868.57 2139.01 N 2170.24 E 8989.45 8937.45 2158.98 N 2198.27 E 9111,11 9059.11 2194.26 N 2247.78 E 9284.65 9232.65 2244.58 N 2318.41 E 9329.37 9277.37 2257.55 N 2336.61 E COMPUTATION DATE: 22-SEP-86 PAGE 9 ARCO ALASKA~ INC. LGI-2 PRUDHOE BAY-LISBURNE POOL NORTH SLOPE~ALASKA ~~$~ STRATIGRAPHIC MARKER MEASURED DEPTH BELOW KB DATE OF SURVEY: 08-SEPT-86 KELLY 5USHING ELEVATION: ENGINEER: SARBER SUMMARY 52.00 FT SURFACE LOCATION ORIGIN= 1365 FNL~ 1632 FEL, SEC I~ TI1N, RIAE, UM TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST TOP WAHOO ZONE 7 TOP WAHOO ZCNE 6 TOP WAHOO ZONE 5 TOP WAHOO ZONE 4 TOP WAHOO ZONE 3 TOP WAHOO ZONE 2 TOP WAHOO ZONE 1 PBTD TD 10150.00 9276.00 9402.00 9~95.00 9693.00 9770.00 9906,00 10100,00 10150.00 TRUNCATED 8547.55 8495.55 2030.85 N 2018.43 E 8660.27 8508.27 2063.53 N 2064.30 E 8743.46 8691,46 2087,65 N 2098,16 E 8920.57 8868.57 2139.01 N 2170.2~ E 8989.45 8937.45 2158.95 N 2198.27 E 9111,11 9059,11 2194,26 N 2247.78 E 9284.65 9232.65 2244.58 N 2318.41 E 9329.37 9277.37 2257.55 N 2336.61 E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 10150.00 9329.37 9277.37 3249.05 N 45 59 E SCHLUMBEROER O I RECT ~ ONAL SURVEY COMPANY ARCO ALASKA INC NELL LOI-2 F I ELD PRUOHOE BAY/L I SBURNE COUNTRY USA RUN 1 DATE LOOOEO 08 - SEP - 88 REFERENCE 000071714 WELL: LGI-2 (1365'FNL,1632'FEL, SEC.1,TllN,R14E,UM) HORIZONTAL PROJECTION zooo ISO0 ! ooo ~oo -~oo SOUTH - 1 DO0 WEST REF 0000717!4 SCALE = !/SO0 !N/FT - 1000 -SO0 0 SO0 -1000 1500 2000 2500 9000 EAS~ wj~ I ,I,: I .L~.L -Z (:L365~FNL~1632~FE1'., SEC.'I,TI'IN,RI4E,UM) VERTICAL PROJECTION SN -2000 -1000 0 0 I000 ZOO0 9000 4000 SO00 SOO0 NE PROJECTION ON VERTICAL PLANE NE - SW SCALEO IN VERTICAl- DEPTHS HORIZ SCALE = 1/1000 IN/FT Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, NAME -ANO NOMBER Reports and Materials to'be received by: Date Required Date Received Remarks , , Completion Report · Core Description Inel~nat~on 'Survey ........ , , Directional, Survey ' , Drill Stem Test Reports ~=o~'~o~ ~es~ ~or~ ~~ ~ ~/C' ,,, ARCO 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 1,3-11 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~i~: 7-19-86 Westlog Please sign and return to~Pam Lambert D&M STATE FILE ROOM TRANSMITTAL # 167 ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 Oil & Gas commission Cons, Anchorage EXXON STANDARD CENTRAL FILES - ARCO ALASKA INC. LISBURNE ENGINEF.~ING Date: 2-2-87 From: Pam Lambert Enclosed are the following: OH Finals for LGI-IO 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 I1-1-86 Run 1 5" Sch LGI-2 Perforation Record 11-2-86 Run 1 5" Sch Received by: Alas ~ & Gas Cons. Commission Anchorage Please sign and return to: Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D & M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 161 STATE OF ALASKA ALAS' OIL AND GAS CONSERVATION COMr SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~i~ Plugging ~,' Perforate~i~. Pull tubing [] Alter Casing ~ Other]~ 2. Name of Operator 5. Datum elevation (DF or KB) ARCO ALASKA, INC. RKB 52 Feet 3. Address 6. Unit or Property name P.O.B. 100360~ ANCHORAGE, AK. 99510 Prudhoe Bay/Lisburne 7. Well number LGI-2 4. Location of well at surface 1365' FNL, 1632' At top of productive interval FEL, Sec. 1, TllN~ R1AE, UM 8. Approval number 535 9. APl number 029-21634 50-- ?00' FSL, 500' FWL. At effective depth 869' FSL, 66'7' FWL~ At total depth 88P' FSL, 684' FWL, 11. Present well condition summary Total depth: measured true vertical Sec. 31, T12N, R15E,UM(app Sec. 31, T12N, R15E, UM(app Sec. 31, T12N, R15E,UM(app) 10. Pool LISBURNE CIE POnl 10150' feet Plugs(measured) NONE 9335' feet Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 4020 ' Intermediate Production 9163' Liner Perforation depth: measurea 92'74-93?4' true vertical 8543-8634' Tubing (size, grade and measured depth) 5.5"~ L80: 8883' Packers and SSSV (type and measured depth) 10100' feet Junk (measured) NONE feet 9290' Size Cemented Measured depth True Vertical depth 20" 1750# POLESET 110' 110' 13-3/8" 2200 sx AS III & 4058' 3999' 600 s× class G~ TOP JOB W/150 SX AS III 9-5/8" 800 sx class G 9198' 8476' ?" 380 sx class e 9018-10140' 8312-9326' Packers: 9-5/8" BROWN ~ 8966' SSSV: CAMCO 4.562" ID., TRDP-1A-SSA-T 12. Stimulation or cement squeeze summary Intervals treated (measured) SEE ATTACHED SUMMARY Treatment description including volumes used and final pressure 13. Prior to well operation Representative Daily Average Production or Injection Data ~' ;. ':~.: ~'i' .~:. : · OiI-Bbl Gas-Mcf Water-Bbl Casing Pre~sUr'e ..... Tubing Pi;essUre.:, :':-" , , N/A Subsequent to operation N/A ,70000 N/A O- 4000 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run the foregoing is true and correct to the best of my knowledge ,_,~,~ ./ 15. I hereby certify that LISBURNE OP. COORD. 12/2/86 Title Date Form 10-404 Rev. 12-1-85 Submit in Duplicate Sequence of Events LGI-2 (Wahoo 6 & 7) Gas Injector 11/03/86 Open well to tanks for a pre-stimulation flow test. Flow well 12 hours 45 minutes. WHP = 2400 psi. SI well (see attached flowback sheet for detailed production information). 11/07/86 19:01 hrs. to 20:17 hrs. SITP = 2800 psi, Rig up Halliburton to pump a perforation breakdown treatment across Wahoo 6 & 7 intervals. Pressure test lines to 4500 psi. Pump 10 bbl diesel w/10% Musol "A." Switch to 15% HCL. Total acid pumped = 103 bbls. Displaced with 220 bbl diesel. Avg. Rate = 7 BPM @ 1200 psi. Excellent pressure break seen when acid hit perfs: (2400 psi to 100 psi) Total Load = 333 bbls ISIP = 800 psi 4 min - well on vacuum WHP @ start of flowback = 1100 psi (21:15 hrs.) 11/07/86 21:15 hfs Open well to flow (frac tank). Recovered 173 bbl diesel at 21:50 hrs. WHP = 2400 psi. 11/09/86 03:00 Flow well through heater/separator for 27 hrs. Avg. Rate = 8 MMCFD, 400 BCPD, WHP 2 11/09/86 Well SI. Rig up Camco E-line unit RIHw/Seling pressure tool/CCL. Obtain pressure stops while RIH (outlined as follows). 09.26 hrs. 13:38 hrs. 100' MD : 2901 psi T = 42.8°F 2000' = 3159 T = 67.6° 5000' = 3527 T = 107.5° *9370' = 4011 T = 174.2° 9290' = 3980 T = 173.° 9160' = 3967 T = 170.9° 9000' = 3949 T = 168.6° 8900' = 3944 T = 167.4° Tool tied in w/short jts w/0' correction. Set tool @ 9160' MD. P = 3970 psi Open well to flow, Avg. rate = 3.3 MMCFD Pressure stabilized at 3963 psi. LGI-2 Sequence of Events (contd) 15:15 hrs. 16:28 17:28 Increased choke Avg. flow rate = 9.4 MMCFD BHP = 3915 psi SI well for pressure buildup Final pressure reading = 3962 psi 47 psi drop while prod. 9.4 MMCFD POOH Job S,u, mmary The Seling pressure gauge used in the bottom-hole pressure monitoring had a 10-15 psi pressure swing. This is the first recorded problem with this gauge. The step rate testing was cut short after the pressures would never completely stabilize. The bomb was pulled out of hole with the intent to rerun a new gauge. Due to weather and the scheduling of an offset LGI acid breakdown, the repeat survey has not yet occurred. The bomb was dead-weight tested after the job with no apparent problem. As can be seen, a "Level of Doubt" exists with the bottom-hole pressure data collected during this testing. ADDENDUM WELL: 11/1/86 LGI-2 RIH w/dummy perf gun, locate tbg tail @ 9072' SLM. Press tbg to 4000 psi. SI & monitor well f/24 hrs. Alaska Oil & Gas Cons. Commission Date · ~- STATE OF ALASKA -- ALASKA L AND GAS CONSERVATION COMMIL 3N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate Alter Casing ~ Other DC..X C0HPLETE Plugging ~- Perforate-~ Pull tubing 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 5. Datum elevation(DF or KB) RKB 52' 6. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 7. 1365' FNL, 1632' FEL, Sec. 1, T11N, R14E, UH At top of productive interval 8. Well number If, l-? Approval number Feet 666' FSL, At effective depth 880' FSL, At total depth 893 ' FSL, 386' FWL, Sec.31, 686' FWL, Sec.31, 705' FWL, Sec .31 , T12N, R15E, UM T12N, R15E, UM T12N, RISE, UM 378 9. APl number 50-- 029-21634 10. Pool Lisburne Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80 ' Surface 4020 ' I 01 50 ' MD 9329 'TVD I 01 O0 'MD 9285 'TVD Size 20" I 3-3/8" Production 9163' 9-5/8" Liner I I 22 ' 7" Perforation depth: measured .~on-e-." . true vertical N o n e feet Plugs (measured) None feet feet Junk (measured) feet N o n e Cemented Measured depth True Vertical depth 1750# Poleset 110'MD 110'TVD 2200 sx AS I I I & 4058 'MD 3999'TVD 600 sx Class G Top job w/150 sx AS Ill 800 sx Class G & 9198'MD 8475'TVD 300 sx CS I 380 sx Class G 9018'-10140'MD 8312'-9320'TVD Tubing (size, grade and measured depth) 5-1/2", L-80, tbg w/tail ~ 9057' Packers and SSSV (type and measured depth) 2B pkr @ 8966' & TRDP-1A-SSA-T SSSV ~ 2164' 12. Stimulation or cement squeeze summary N/ Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History) Daily Report of Well Operations ~ Copies of Logs and Surveys Run 15. I hereby certify that the foregoing is true and correct to the best of my knowledge orm 10-404 Rev. 12-1-85¢¢ Title Associate Engineer Date 11-17-gL, Submit in Duplicate ARC° Oil and Gas Comwany Daily We~, History-Final Report Instructions: Prepare and submit the "Final Report" on the first W'ednesday 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_ IAccounting cost center code State Alaska JWell no. LGI-2 District JCounty or Parish Alaska J North Slope Borough Field ILease or Unit Prudhoe Bay I ADL #34628 Auth. or W,O. no. ITitle AL0303 I Completion Nabors I-ES API 50-029-21634 Operator A.R.Co. W.I. ARCO Alaska, Inc. 50% Spudded or W.O. begun Date Complete 10/23/86 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our I Prior status if a W.O. 1730 Hrs. Date and depth as of 8:00 a.m. 10/24/86 10/25/86 thru 10/26/86 Complete record for each day reported 7" 9018'%~_0,140' 10,100' ~, Set BP 9.4 ppg Brine Acce~t ri~ @ 1730 hfs, 10/23/86. ND tbg head adapter & master vlv. NU & tst BOPE. RIH w/BP, displ top 400' w/9.4 ppg brine. Att to set BP; would not set. POH & wait on 2nd BP. 7" 9018'-10,140' 10,100'?aID, RR 9.4 ppg Brine w/30 bbl diesel cap Set BP @ 400', chg out tbg spools & tst to 5000 psi. NU & tst BOPE. RIH, retry BP. Tst csg to 3000 psi. RU DA, make gage ring/JB rn to 9006' WLM. Rn & set 2-B pkr. RU & rn 217 jts, 5½", 17#, 8RD AB Mod tbg w/SSSV @ 2164', 2-B pkr @ 8966', TT @ 9057'. Lnd tbg. Over displ tbg w/30 bbls diesel. Tst ann to 2500 psi. Tst tbg to 4000 psi. ND BOPE. NU & tst tree. RR @ 0530 hfs, 10/26/86. Old TD Released rig 0530 Hrs. New TD Date 10,100' lo/26/86 PB Depth Kind of rig Rotary Classifications {oil, gas, etc.) Oil Type completion (single, dual. etc.) Single Producing method Official reservoir name(s) Flowing Llsburne Potential test data Well no. Date Reservoir Produc ng 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 JDate I 1/04/86 Drillin~ Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. LISBURNE ENGINEERING Date: 10-30-86 From: Pam Lambert Enclosed are the following: OH Finals for LGI 2 Dual Laterolog/SGR 8-12-86 Run 1 2"&5" Sch Natural GR Spectroscopy 8-12-86 Run 1 2"&5" Sch EPT/GR 8-12-86 Run 1 2"&5" Sch LDT/CNL (Poro) 8-12-86 Run 1 2"&5" Sch LDT/CNL (Raw) 8-12-86 Run 1 2"&5" Sch CNL in 9 5/8 casing 8-12-86 Run 1 2"&5" Sch Cyberlook 8-12-86 Run 1 5" Sch CET 8-12-86 Run 1 5" Sch CBT 9-7-86 Run 2 5" Sch -, Received by: 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 # 085 ALASK~ OIL AND GAS CONSERVATION COMMISSION APPLICA_ ION FOR SUNDRY 2ROVALS feet ~.~ 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] 'rime extension [] Change approved program I'-1 Plugging [] Stimulatex{~ Pull tubing ~ Amend order [3 Perforate){~( OlherX[~ 2. I~ame of Operator 3./~ddress ARCO ALASKA, INC. P.O.B. 100360, ANCHORAGE~ 4. ~cationofwellatsurface 1365' FNL, 163e' FEL~ Attopofproductiveinte~al 700' FSL, 500' FWL. Ateffectivedepth 8~' FSL, 66?' FWL~ Attotaldepth 88E' FSL~ 684' FWL, AK. g~510 Sec. 1, TIiN~ Ri4E~ UM Sec. 31~ T1EN~ Ri5E~UM<app) Sec. 31~ TiEN~ RiSE~ UM(app) Sec. 31~ TIEN~ RI5E~UM(app) 5. Datum elevation(DForKB) RKB 52 6~Unit ,or Prop,.,erty ~rudnoe ~ayPt~%burne 7. Well number LGI-~ 8. ~rmitnumber 8~-140 9. APInumber 50-- 0E~-21~3~ 10. ~ol LISBURNE OIL POOL 11. Present well condition summary Total depth: measured true vertical 10150 ' feet Plugs (measured) NONE c~335 ' feet Effective depth: measured ! 0 l O0 ' true vertical ~IB~O' feet Junk (measured) NONE feet Casing Length Structural Conductor 80' 4020' Surface Intermediate Production ~ 1 ~ ' Liner 1 l ;E~ ' Size Cemented Measured depth True Vertical depth BO" I750# POLESET 110' 110' 13-3/8" 2200 sx AS Ill & 4058' 399~' 600 sx class G, TOP JOB W/150 SX AS III Perforation depth: measured WELL TO BE PERFORATED UNDER true vertical ~-5/8" 800 ~x ciasa G ~1~8' 8478' ?" 380 sx class G c~018-10140' 8312-c~386' RECEIVED THIS SUNDRY OCT 1 1986 Tubing (size, grade and measured depth) ~aska 0il & Gas Cons. Commission WELL CURRENTLY BEING COMPLETED Anchorage Packers and SSSV (type and measured depth) Packers: WELL CURRENTLY BEING COMPLETED SSSV: CAMCO 4.5~2" ID.~ TRDP-1A-55A-T 12.Attachments Description summary of proposalY~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver RUSS DOUGLAS Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~, .~_/Z~~4F Title Lisburne Dc>. Contd. Date IO/~g/fl/-, Commission Use Only Conditions of approval Notify commission so representative may witness ~ Approval No. /~ ~ ~ D Plug Integrity D BOP Test D ~cation clearance~ . ~ ~~ 9/2/2,1/_ Approvedbyt ~~. ~ ~('~~ Form 10-403 Rev 124~ ~ / / Commissioner by order of the commission Dst =>uDmlt in triplicate ATTACHMENT 1 ~LL LGI-2 ~CO Alaska~ Inc. proposes to conduct the following on Eisburne well LGI-2: Perforation of Wahoo interval between 9274' 9374' MD with 3-3/8 inch gun and 6 SPF. ~ll will be flo~=d back to clean up the ~Pforations= Stimulation of the perforations with 100 ~.erels of 15% HC1. Fluids will be pumped · ~ough tubing and the ~ell will be flowed to recover the load and clean up the ~ii~ Set pressure bomb in wel 1 and conduct i-rate §as deliverability test of the RECEIVED OCT 1 1986 Ataska Ot~ i Gas Cons. C;ornmission Anchorage To: State of Ak ~'rom: Pam Lambert OL\i John Boyle Date: 9-29-86 Transmitted herewith arm the following: GCT Directional Survey for LGI 2 9-8-86 Sch Return Receipt ~:o: ARco Alfska In~z. Alaska 0ii & Gas Cons. Pan La~bert ~O 477 Anchorage PO Box ~0 Anchorage, Alaska 99510 Transmittal No:_~~~ Lisburne Engineering To: State Qf Ak From: Pam Lambert John Boyle Date: 9-26-86 Transmitted herewith are :he following: Magnetic tape for LGI 2 GCT LIS 9-8-86 Run 1 Tape Number 71714 Sch Return Receipt to: ARCO Alaska Inc. Pam Lambert ATO 477 PO Box i00360 Anchorage, Alaska 99510 Transmittal No:O~ STATE OF ALASKA ALAS~,,-, OIL AND GAS CONSERVATION COMM.SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend -- Operation Shutdown ~ Re-enter suspended well - Alter casing - Time extension ~- Change approved program ~- Plugging ~ Stimulate- Pull tubing- Amend order-' Perforate ' Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P; 0. Box 100360 Anchorage, AK 99510 4. Location of well at surface 1365, FNL, 1632' FEL, Sec 1, T11N, R14E, UM At top of productive interval 700' FSL, 500' FWL, Sec. 31, T12N, R15E, UM (Approx) At effective dep, th 869' FSL, 667' FWL, Sec. 31, T12N, R15E, UH (Approx) At tgdtS~21'd~sPLth, 684' FWL, Sec. 31, T12N, R15E, UH (Approx) 5. Datum elevation (DF or KB) 52 ' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number LG1-2 8. Permit number 86-140 9. APl number 50-- 029-21634 10. Pool Lisburne 0il Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10150 'MD feet 9335 'TVD feet 101 O0 'MD feet 9290 ' TVD feet Plugs (measured) Junk (measured) None None Casing Length Conductor 80' Surface 4020' Production 9163' Liner 1122' Size 20" 13-3/8" 9-5/8" 7" Cemented Measured depth True Vertical depth 1750# Poleset 110'ND 110'TVD 2200 sx AS I11 & 600 sx Class G 4058'MD 3999'TVD Top job w/150 sx AS Ill 800 sx Class G 9198'MD 8476'TVD 380 sx Class G 9018'-10140'MD 8312'-9326'TVD Perforation depth: measured true vertical None None Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) None None 12.Attachments WELL H ISTORY Description summary of proposal..~ Detailed operations program C BOP sketch :-~ 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 Associate Engineer ~/ Commission Use Only (Dani) SA/103 Date Conditions of approval Notify commission so representative may witness I Approval No. ~ Plug integrity ~ BOP Test ~ Location clearancel ,:,~, ~ ~ ~. ~ ....... by order of Approved by Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate 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 Field Alaska ICounty, parish or borough North Slope Borough Lease or Unit Title ADL #34628 Drill IState Prudhoe Bay Alaska IWell no. LGI-2 Auth. or W.O. no. AFE AL0303 Rowan #41 AP1 50-029-21634 Operator IARCO W.I. ARCO Alaska, Inc. 50% Spudded OrspudW.O. begun IDate 7/28/86 JHour 1330 Hrs. JPr,orstatus if a W.O. Complete record for each day reported Date and depth as of 8:00 a.m. 7/29/86 7/30/86 7/31/86 8/01/86 T_.he above is correc~N i]rnf~~~ on 20" @ 110' 1896', (1786'), Drlg Wt. 9.4+, PV 12, YP 52, PH 9.2, WL 15, Sol 8 Accept ri$ @ 1030 hrs, 7/28/86. NU diverter sys. 1330 hfs, 7/28/86. Drl 17½" hole to 1896'. Spud well @ 20" @ 110' 3530', (1634'), DD Wt. 9.5+, PV 16, YP 32, PH 9.3, WL 25, Sol 8 Drl & surv 17½" hole to 3530'. 2700', Assumed vertical 2842', 4.5°, N45.4E, 2841.85 TVD, 5.57 VS, 3.91, 3.97 3303', 12.7°, N44.4E, 3297.55 TVD, 73.05 VS, 51.23, 52.16 13-3/8" @ 4058' 4060', (530'), Cmt 13-3/8" Wt. 9.5, PV 17, YP 26, PH 9.0, WL 25+, Sol 8 Drl & surv 17½" hole to 4060', 20 std short trip, CBU, POOH. RU & rn 99 its, 13-3/8", 72#, L-80 BTC csg + 2 its, 13-3/8", 68#, K-55 BTC csg w/FC @ 3977', FS @ 4058'. Prep to cmt 13-3/8". 3491', 16.9e, N45.4E, 3479 TVD, 121.06 VS, 85.24N, 86.05E 3990', 28.4°, N34.gE, 3940 TVD, 307.83 VS, 221.17N, 215.87E 13-3/8" @ 4058' 4060', (0'), Chg out BHA Gel wtr RU & cmt w/2200 sx AS III & 600 sx C1 "G" w/2% CaC12. Displ using rig pmps, bump plug. ND diverter sys. Perform 150 sx AS III top job. NU & tst BOPE. Chg out 17½" BHA to 12¼". JDate 8/28/86 ITit'e Drilling Supervisor 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 "lnlerim" 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 unlil completion. District Field Alaska North Slope Borough IState Alaska Prudhoe Bay Date and depth as of 8:00 a.m. ICounty or Parish L ..... r Unit ADL #34628 Complete record for each day while drilling or workover in progress no. LGI-2 8/02/86 8/03/86 8/04/86 8/05/86 8/06/86 8/07/86 13-3/8" @ 4058' 5562', (1502'), RIH Wt. 8.9, PV 4, YP 15, PH 8.3, WL 25+, Sol 5 RIH, DO flt equip & cmt + 10' new hole. Conduct formation tst to 12.9 ppg EMW. Drl & surv 12¼" hole to 5562'. 4245', 30.1°, N36.6E, 4163 TVD, 430.78 VS, 322.29N, 288.66E 4873', 32.9°, N37.0E, 4699 TVD, 753.26 VS, 584.14N, 483.85E 5492', 34.8°, N38.4E, 5213 TVD, 1094.80 VS, 857.81N, 693.85E 13-3/8" @ 4058' 6800', (1274'), Drlg Wt. 9.2 PV 5, YP 5, PH 9.5, WL 10.2, Sol 6 DD & surv 12¼" hole to 6800'. 5806', 32.3°, N40.1E, 5474 TVD, 1267.43 VS, 992.18N, 803.64E 6269', 30.9°, N49.6E, 5869 TVD, 1509.28 VS, 1164.56N, 973.14E 6611', 32.6°, N50.0E, 6160 TVD, 1688.78 VS, 1280.71N, 1110.59E 13-3/8" @ 4058' 7676', (876'), Drlg Wt. 9.4, PV 4, YP 4, PH 12.4, WL 12.2, Sol 8 Drl & surv 12¼" hole to 7676'. 6857', 32.1°, N50.3E, 6368 TVD, 1820.03 VS, 1365.06N, 1211.65E 7470', 28.0°, N51.0E, 6897 TVD, 2127.94 VS, 1561.71N, 1449.94E 13-3/8" @ 4058' 8250', (574'), Drlg Wt. 9.4, PV 4, YP 13, PH 12.2, WL 9.6, Sol 8 Drl & surv 12¼" hole to 8250'. 7717', 26.3°, N50.0E, 7117 TVD, 2240.36 VS, 1633.40N, 1536.91E 8024', 25.2°, N50.0E, 7394 TVD, 2373.40 VS, 1719.13N, 1639.08E 13-3/8" @ 4058' 8695', (445'), Circ 10.3 ppg mud Wt. 10.3, PV 10, YP 7, PH 11.4, WL 6.4, Sol 13 Drl to 8695', POOH 5 stds, well flowing. RIH to btm, SI. Circ well with choke open, raising mud wt (10.3 ppg in - 10.1 ppg out). 8333', 23.8°, N49.3E, 7675 TVD, 2501.31VS, 1802.10N, 1736.73E 13-3/8" @ 4058' 9070', (375'), Drlg Wt. 10.3, PV 10, YP 9, PH 11.8, WL 6.8, Sol 12.5 Circ, 10 std short trip, build mud wt to 10.3 ppg, POOH, chg BHA. drl 12~" hole f/8695'-9070'. 8640', 19.3°, N52.8E, 7960.36 TVD, 2613.24 VS, 1872.96N, 1824.39E 8856', 21.2°, N53.5E, 8163.00 TVD, 2687.34 VS, 1917.79N, 1884.22E RIH, The above is correct Signalur_e ,, ~.~ For form preparation and distribution see Procedures Manual ~ection 10, Drilling, Pages 8§ and ST IDate JTitle 8/28/86 Drilling S u_p e_rvi_s o_r ..... NkLklVkU S E P 0 9 1986 Alaska Oil & Gas Cons. Commission Am',hor~ge ARCO Oil and Gas Company Daily Well History--Interim Inslruclions: 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 "lnlerim" 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 Alaska I County or Parish Field Lease or Unit Prudhoe Bay ADL #34628 Date and deptl~ Complete record for each day while drilling or workover in progress as of 8:00 a.m. North Slope Borough IStale Alaska JWell no. LGI-2 8/08/86 8/09/86 thru 8/11/86 8/12/86 8/13/86 8/14/86 8/15/86 13-3/8" @ 4058' 9212', (142'), Rn'g 9-5/8" csg Wt. 10.3, PV 9, YP 7, PH 11.3, WL 6.4, Sol 13 Drl & surv 12¼" hole to 9212', CBU, POOH. RU & rn 235 its, 9-5/8" w/FC @ 9116', FS @ 9198'. 9100', 24.9°, N51.4E, 8387.48 TVD, 2782.42 VS, 1976.00N, 1959.94E 9162', 26.0°, N52.4E, 8443.47 TVD, 2808.89 VS, 1992.44N, 1980.91E 9-5/8" @ 9198' 9915', (703'), Drlg Wt. 9.4, PV 6, YP 5, PH 11.4, WL 8.6, Sol 6 Cmt 9-5/8" w/150 sx 50/50 Pozz w/8% D-20, .5% D-65, .5% D-112 & .2% D-46, followed by 650 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, did not bump plug. TIH w/8½" BHA, tst csg to 3000 psi. DO cmt & flt equip + 10' new hole. Conduct formation tst to 14.9 ppg EMW. Drl 8½" hole to 9915'. 9-5/8" @ 9198' 10,150', (235'), POH to log Wt. 9.4, PV 7, YP 6, PH 11.6, WL 10.0, Sol 6 Drl 8½" hole to 10,150', circ, POH to log. 9-5/8" @ 9198' 10,150', (235'), C&C f/lnr Wt. 9.4, PV 8, YP 7, PH 11.6, WL 12.2, Sol 6.5 POH. RU Schl, rn DLL/NGT/SP, LDT/GR/CNL/CAL/EPT & CET. Schl. RIH, wsh & rm 85' to btm, C&C. 7" f/9018'-10,140' 10,150', (0'), RIH w/bit & $crpr Wt. 9.4, PV 8, YP 8, PH 11.3, WL 12.0, Sol 6.5 Circ, POOH. RU & rn 28 its, 7", 29#, L-80 BTC csg f/9007'-10,140' 9971', FC @ 10,100', FS @ 10,140'. Cmt w/380 sx Pozz w/2% D-20, .8% D-112 & .2% D-46. Displ using rig pmps. PU BHA & RIH w/8½" bit & scrpr. w/Lc @ 7" f/9018'-10,140' 10,100', (0'), POOH, LD DP 9.4 ppg NaC1 Brine RIH, drl cmt to TOL, POOH. RIH w/6" bit, DO 7" lnr, tst csg to 3000 psi. Displ well to 9.4 ppg NaC1 brine. The above is correct For form preparation and distribution ~e~ Proccdur~ Manual Section Drilling, Pages 86 and 87 JDate ITitle 8/28/86 Drilling Supe~o~ E IV F D S F_P 0 9 1986 Alaska Oil & Gas Cons. 6ommissioo Anchorage 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. Accounting cost center code State Alaska JWell no. LGI-2 District IC°unty or Parish Alaska I North Slope Borough Field ~ Lease or Unit Prudhoe Bay I ADL #34628 Auth. or W.O. no. ITitle AFE AL0303 I Drill Rowan #41 Operator A.R.Co. W.I. ARCO Alaska, Inc. 50% Spudded or W.O. begun Date Spud 7/28/86 Date and depth Complete record for each day reported as of 8:00 a.m. 8/16/86 API 50-029-21634 Iot.l number of wells (active or inactive) on this ! DSt center prior to plugging and J bandonment of this well our I Prior slatus if a W.O, I 1330 Hrs. 7" f/9018'-10,140' 10,150' TD, 10,100' PBTD, (0'), RR 9.4 ppg NaC1 Brine ND BOPE. NU & tst master vlv to 3000 psi. f/freeze protection. RR @ 2400 hrs, 8/15/86. L3-2. Pmp 150 bbls crude Move rig to '-c'r'IVED Sr:.~ 0 9 1986 Alaska 0il & Gas Cons. AIR; Old TD Released rig 2400 Hrs. New TD Date 10,150' 8/15/86 PB Depth Kind of rig 10,100' Rotary Classifications (oil, gas, etc.) 0il Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Lisburne 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" I Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. JOate 8/28/86 JTit,e Drilling Supervisor ARCO Alaska Inc. Lisburne Engineering To: State of Ak John Boyle From: Date: Pam Lambert 8-29-86 Transmitted herewith are :he following: Magnetic Tape for Lisburne Well LGI 2 OH LIS Unshifted 8-12-86 Run 1 Tape Number 71659 Receipt Acknowledgement: Return Receipt to: ARCO Alaska Inc. Pam Lambert ATO 477 PO Box 100360 Anchorage, Alaska 99510 Transmittal No:_~ ~ A[~,ska Oil & Gas Cons, Commission Anchorage MEMORA>'OUM Sta*- of Alaska A~AS~_A OI~_ AND GAS CONSERVATION COYR~ioSION TO: C.V. /o~r~on DATE: August 11, 1986 F~LENO.: D.JFB.7 THRU: Lonnie C. Smit~h~{~,,-" TELEPHONE NO.' Commis s ioner / - c~ FROM: John F. Boy!e~j~..7 PetrOleum Engfn&er A~t SUBJECT: BOP Test (UIC) ARCO PBU LGI #2 Permit No. 86-140 Lisburne Oil Pool Thursday, July 31, ]986: Today I traveled to ARCO's proposed gas injection well', LGI #~,' to witness the BOP test on Rowan Rig #41. Due to cement problems, which required a top job, the test did not begin until 2:30 a.m. Friday, August 1. As the attached BOP inspection report shows, I observed no failures, and the test concluded at 4:20 a.m. It should be noted that this well will be classified as a service well. In summary, i witnessed the successful BOP test at ARCO's PBU LGi #2 well. Attachment 0-84) :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: !'~: :.': :-'.>-:: ':-~--.-- :: k.~.~.-'" :-. ,._....: '...:., :." i.__i - -. ::;::::">_::t~~:-~'.:::::>~::'>-.>_:iL. STAT~ 0F'~Z~A.':. .::::',.-:v'-' ::::-'_ ...-,,. ALASKA. 0IL &' GAS C0NSEKVATION COMMISSION ---:,.:..-,:. :" ~,0.P.E. Inspeution Report ' , .' ~)~'~!. OPerator ~ ~ C~ . . .:..: Drilling-. contractor ~ ~'F: Ri, D~ .~ ~- + /., Representative, ~. ~ ~¢c e~ /~ Casing Set ~ ~0:'-~ ft.' "- '-~: Location, GenerJl t~. ...... ,-.~:. ' "'-:::::~'(:' G~eral Housekeeping '¢A ... "-:.~ Rese~e Pit,, ~ ~ ~ Mud Systems Visual Well Sign¢~ Audio Trip Tank Pit Gauge Flow Monitor . Gas Detectors ACCUMULATOR SYSTEM. Full-Charge Pressure ,p~ ~ Pressure ~ter closure. /~E 0 Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: Controls: Master ~.~ psig . psig 3 min3~ sec. psig Remote~g , Blinds switch cover Annular Preventer O~.~- Pipe Rams&p' 0 :~. :Biind Rams O~ !1 P-'~ '" /I Choke Line Valves~,/-~'~]1 Kill Line Valves~ ~'(}l :Check Valve / O~ II . ,5o o0., :0o 0 ~-oo 0 :oo0 , :'-' Kelly and Floor Safety ":elves Uppe r KellY '~ .Test Pressure,, ... Lower Kelly '0~ Test Pressure Ball TYpe ~. Test Pressure Inside BOP ~ Test Pressure Choke Manifold ~ Test Pressure /:/ No. Valves / ,, No. flanges Test Results: Failures .~ ~epair or Replacement of failed equipment to be made within . Remarks: ~O 0 C~ , '/ Adjustable Chokes Hvdrauicall¥ operated choke Test Time ~- hrs. days and Inspector/ : % t. -I - Distribution orig. - AO&GCC cc - Operator c.c - Supervisor Inspector July 22, 1986 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Prudhoe Bay Unit LGI-2 ARCO Alaska, Inc. Permit No. 86-!40 Sur. Loc. 1365-'FNL, 1632'FEL, Sec. 1, TllN, R14E, Ult. Btmhole Loc. 1022'FSL, 833'F~rL, Sec. 31, T12N, R15E, Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The 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 equipment so that a representative o~ the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I~ere 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. Ve~ tr~!y~ ~z~urs, ~ M C. V. Ch~er~on Chai~an of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COM2~fISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery -- STATE OF ALASKA ALASKA _ .L AND GAS CONSERVATION Ct.,JMISSION PERMIT TO DRILL 20 AAC 25.005 (~Gas Injector la. Type of work Drill ,/~ Redriil []1 lb. Type of w, el,. Exploratory [] Stratigraphic Test E~ Development Oil Re-Entry [] Deepen[]1 Service ~ Developement Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Poo'l ARCO Alaska, Inc. RKB 52', PAB 13' feet Prudhoe Bay Field '3'i Address 6. Property Designation Li sburne 0i ] Pool P.O. Box 100360 Anchorage, AK 99510 ADL 3h628 ALK 863 4. Location of well at surface 7. Unit or property Name 11, Type Bond (see 2o AAC 25.o25) 1365'FNL, 1632'FEL, Sec.1, T11N, R14E, UN Prudhoe Bay Unit Statewide At top of productive interval ~ Target 8. Well number Number 700'FSL, 500'FWL, 5ec.31, T12N, R15E, UN L61-2 ¢8088-26-27 At total depth 9. Approximate spud date Amount 1022~FSL, 83~'F~L, 5ec.~1, T12N, R15E, UH 07/26/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(M~ and TVD) property line 1 0,227 feeti feet 0'¢ 72~4'TVD&6799'TVD 120' from LGI-~ ~ sur ace 2~61 f9332'TVD} 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 2800 feet Maximum hole angle 300 Maximum surface ~560 psig Al total depth CVD) ~490 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 12-1/4")-5/8" ~7.0~ L-80 BTC 92~0' ~8' ~8' 9268' 8502' 780sxCl assa&~OOsxAK I &A 8-1/2" 7" 29.0~ L-80 BTC 1259' 8968' 8242' 10227', 9332' $00sx6¢%Cla~sG/35%POZ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Intermediate Liner Perforation depth: measured Alaska 0ii & G~m Cons. C0r~mJssJ0~ true vertical A~';ch0rr~g¢ ~ BOP Sketch Sketch Iling program ~ 20. Attachments Fil fee ~ Property plat . ~ Diverter ~ Dri Drilling fluid program Timevs depth plot ~ Refraction analys~s ~ Seabed report ~ 20AAC25.050 requirements 21. I hereby certify that t~ foregoing is true and correct to the best of my knowledge Signed ¢~ ~ T,tle.,e~ional Dr~ll~n~ Ink,neet ~ Commission Use Only (JJC) PD/PD297 ~ ~-/¢o 50-- 6' %~'- ~/6-'J ¢ o~ 86 for other requirements Conditions of approval Samples required ~ Yes ~ No Mud Icg required ~ Yes ~ No Hydrogen sulfide measures Q ~ ~ No Dire~ional survey required ~Yes ~ No Required wor~~~~Z~ ~5M; ~ 10M; ~ 15M Other: by order of Approved by %/_. *~ ~ ~~~~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 LGI-2 DRILLING PROGRAM 1. Set 20" conductor and cement. A 20", 2000 psi annular diverter will be installed per the attached schematic. This is a variance from 20 AAC 25.035. 2. MIRU Rowan 41. Install 10" diverter lines and function test. 3. Drill 17-1/2" hole to 2800'MD(2800'TVD). Build 2-1/2° per 100' to 30°07' oriented N45o55'E to 4063'MD(4000'TVD). 4. Set 13-3/8" casing and cement to surface. Test casing to 2000 psi. Do top job if cement does not surface. 5. Install 13-5/8", 5000 psi, RSRRA BOP stack. Test BOP stack to 5000 psi, annular to 3000 psi. Test BOP stack weekly. Drill 10' of new formation and perform leakoff test. 6. Hold and drill 12-1/4" hole to 9268'MD(8502'TVD). 7. Set 9-5/8" casing and cement. Test casing to 3000 psi. 8. Drill 10' of new formation and perform leakoff test to 12.5 ppg EMW. 9. Drill 8-1/2" hole to approximately 10,227'MD(9332'TVD). 10. Run open hole logs. 11. Run and cement 7" liner. 12. Clean out cement and change mud out to brine with 400' diesel cap. 13. Secure well and release rig. 14. Run cased hole logs. 15. MIRU completion rig. 16. Run 5-1/2" 17.0#, L-80, AB-MOD tubing string with packer and subsurface safety equipment. Set packer above top of liner. 17. NU tree and test to 5000 psi. 18. Secure well and release completion rig. 19. Perforate and stimulate well. NOTE: a. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. b. The drilling fluid program and fluid surface system will conform to the regulations set forth in 20 AAC 25.033. c. Maximum surface pressure is based upon BHP of 4490 psi ~ 9332'TVD and a full column of gas (0.10 psi/ft). d. Existing wells within 200' of the proposed well are: LGI-6 120' at the surface and LGI-8 180' at the surface. There are no closer approaches anywhere downhole. PD/PD297a:tw ~_. Gas Cons. commissio~ Density Depth (TVD) #/gal LGI-2 HUD PROGRAM Plas Yield Visc. Point Initial 1OM FL % % (CP) #/100 ft2 Gel Gel CC/30M Oi 1 Sol ids . 40-60 20+ 40+ 20+ 0 8-10 Surf 8.8 Funnel to to 100- 13-3/8" 9.7 300 Csg Point pH and Type of Mud Spud Mud 13-3/8" Csg Shoe 8.3 Minimum 6 2 5 25 0 3 to to Possible to to to to to to K-lO 9.4 20 10 30 10 2 7 Low Solids Non-dispersed K-lO 9.2 10 4 4 8 8 2 4 to to to to to to to to to 9-5/8"Csg. Pt. 10.2 20 10 8 20 4 5 15 pH 9-10 Low Sol ids/Low Lime Non-di spersed 9-5/8" Csg. Shoe 9.2 4 6 2 8 10 2 4 to to to to to to to to to TD 9.6 10 10 8 20 4 8 8 NOTE: Exact mud properties will be selected by ARCO representative based on hole conditions. Low Solids/ Non-Dispersed Salt 15,000 - 30,000 ppm 1. Degasser 2. Shakers 4. EQUIPMENT - DRILLING FLUID SYSTEM Pit level indicator (with both visual and audio warning devices) Drilling fluid flow sensor (with read out convenient to the driller's console) 5. Trip tank 6. Agitators 7. Desander 8. Desilter 9. Centrifuge PD/PD297b:tw RECEIVED j U L 2 1986 Alaska Oil & 6~$ Cons. Commission ROWAN 41 MUD SYSTEM ! I mixing pit #1-145 bbls mixing pit #2- 145 bbls pill pit 60 bbls pit ~5 trip tank 145 bbls pit ~4 115 bbls pit ~3 suction 115 bbls 'njection pit 145 bbls pit ~6 -90 bbls pit~7- 90 bbls pit ~8 40 bbls Brandt Doub 1 e-Deck er 5ha 1 e 5hak ers-(3 ) Demco Desander with 3-12" diam. cones Demco Desilter with 14-6" diam. cones Dri lco Degasser Pioneer Centrifuge Main Pumps: National 12-P- 160, (2) Gasbuster well well i i i ! i I I I ! ! ! ! ! ! · ARCO ALASKA INC. ROWAN 41 , D I VERTER Fillup line 10" ball Riser I Flowline I 20" 2000 ps1 diverter ball vlv I Conductor Note: Only one valve opens automatically when diverter closes. The other will remain closed and be used only in case of emergency. This is avariancefrom 20 AAC 25.035 RNNULRR PREVENTOR PIPE RRHS BLIND RRMS DRILLING SPOOL PIPE RRHS 13- 5/8"ABOP STACK DIAGRAM :~zcumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 15-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid. 2. Check that all hold down screws are fully retracted. ~h~rk running joint with predetermined plug sea.ting depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and upstream valves. 4. Functionally test chokes. -5. _In each of the following tests, first hold a 250 psi low pressure test for a minimum of 3 minutes, then test at the high pressure. 6. Increase pressure to 3000 psi and hold for a mimimum of 3 minutes. Bleed pressure to zero. 7. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pressure to zero. 8. Close valves directly upstream of chokes and open chokes., Increase pressure to 5000 psi and hold for at least 3 minutes, Bleed pressure to zero, 9, Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 min- utes. 10. Test reamining untested manifold valves (i£ any) with 5000 psi upstream of valve and zero pressure downstream. 11. Bleed pressure to zero. Open bottom set of pipe 12. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 13. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non- freezing liquid and all valves are set in drilling position. 14. Test standpipe valves to 5000 psi. 15. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 16. Check operation of Degasser. 17. Record test information on blowout preventer test form. Sign and send to Drilling Supervisor. 18. Perform complete BOPE test once a week and func- tionally operate BOPE daily. Revised 2/21/84 L{31-2 looo 2000 3OOO 4000 SO00 6OOO 7000 8000 ~-,X~,.V~/8'CSG TVD AHOO7 TVD 9000 TOP ALAP TD-?'CSG PT 10000 u 1000 2000 3000 - 4000 5000 6000 7000 , , , , i i i i i I I I ' ' ' ' i 0 0 ......... ~'- ...... ' .............. ' ............ CONDUCTI)R TVD - 17.:1 1 . ARC13 AL/ ,SKA, INC. !~CALI= 1 IN, -lttO0 Fl'. SHL: 1365' FNL 1632' F=L SEC,1 I'11N RlqE UN (OP TVD = 28 DO TARGET: 700' FSL 500' '~L 2.5 .¢;FC 31 TI?N RI-~I= Ill~l '§ EOC TVD = 3950 MD = 4005 DEP =311 i3-3iG-S~RFA~'- ~vu"4000 MD--,063 DEP-33B N 45 DIG 65 MIN E 2968 F':{TO TARGET} A VERA(~ E ANGLE ;313 DI:G'~' MIN · ,,.-,u ,v~--';uu~ MD--7ET~i DEP--210~ K-5 TVD '= 7352 MD -- 7938 DEP '= 228," SAD .E~I~:)CH'~f-'r-v'I~' '-- 8022 MD K,~VlK TVD "8~ 22 MD = 9175 DEP = 2904 -- 8502 MD - 92 B8 DEP -- 2951 . 3 = 8532 MD = {~,302 DEP = 29118 \ TVD =' 9289 M D '= 10177 DEP == 3407 VD = 9332 MI) = 10227 DEP = 3432 ., ,-, /_',.:; ~.,, ~ _'.:.'-' _ ) , , , , , , , , , , , , , , , , , , r , 1000 2000 3000 4000 5000 11000 0 60O0 7000 8000 9000 lOOOO 11000 1000 2000 3000 4000 5000 6000 7000 VERT I CFIL SECT I ON D_ W W E - 14 COORDINFtTES -2000 -1000 0 1000 2000 3000 4000 5000 .~N~-I~RR'iNI 1Ra~'FFi SEC.1 Tl11~ RI~t~E UM TARGET: 70(~' FSL 500' Fi~IL SEC.31 T12~1 R15E UM - c-~ J TVD -- 853: !" ~ TMD -- 930 2" c_~o ~// N 2065 03 ~ ~= 2!32 I z ED , .. ED ~ 't ED .... - .'._ (~ .-! .. I ,- /-...,.;,! ,, J I i I i i I i I i i I I i I I t I I I I I I I I I I I I I I I I I I I I I I I I II I I I I I I I i ~ i i i i I I i I i I I 1 I -2000 -1000 0 1000 2000 3000 4000 5000 E - H COORD]'NRTES E - ~ OOOROINflTES -2000 -1000 0 1000 2000 3000 ~000 5000 L81-12 ~ , ~ /921/ . ~038 - . , ,'~ .~n54 ,~3~''~ / zt217 ~3.~ ~ 9!;01' L ' ' ' 'i i i ! i [ ] ] i i ! ] i i i I t i ! i i i t I i t ! ! , , ] i ] i[ i i i i i I t ! ~ i ! t ! I 1 i ! t i ] i ] i ! ! ] i i -2000 -1000 0 1000 2000 3000 4000 5000 E - N COOROINI:ITES f..O E - N COOROINRTES -200 - ! O0 0 ! O0 200 300 400 500 i i , i i I I I I , ~ ~ ] i t i i , i i , i , , I I I i I i i i i I .i t ~ I I i I i i i i ~ ~ , , ~ , , , i , , , s i , I I i2 t i t L~I-iO -8 / i / 2~~4E .2420/5769 ~ 370:' ~&21 ~831b / oacI , ~OS~ -~03 L8I-6 ~858 - 3~89 ' ,... - IA' ~z:.',::" ::.: I i ~ i i i i i i i i i i i i i i i i i i i i i iI I i i i i i i i I Il iI i i [ i i i i i i i i i i i i i i i i i ~ i , i , , , , i . 0 0 0 -200 - 1 O0 0 1 O0 200 300 400 500 600 E - N COOROINRTES ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1986 Mr. C. V. Chatterton Commissioner 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 Engineer JG/tw GRU13/L91 Enclosure If ARCO Alaska, Inc. is a Subsidiary o! AllanlicRichiieldCompany N · (i" /~ I I?OO.OO DS L.-t I~LU~( PIT I L ) / /--- #7125.00 // // // // // 1.6 · I0· I · 4 · 2: · (vlcml~ ~P) ARCO LISBURNE FACILI~ES PROJECT (~,~,Z.Sil.) LDC. ·SEC. I,TIIN, RI4E, UM.,AK NOTES- I.STATE PLANE COORDINATES ARE ZONE 4. Z. ALL SEOOETIC POSITIONS ARE BASED ON NAO 1127. :).OFFSETS TO SECTION LINES ARE COII- PUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. 4. PLANT COORDINATES AS PER Sir/BRAUN DIG, CED 4~7-17212, SI'IT 601, REY. I. .OC~TION N SECTION L~NE ) F.E. LINE i 2 ~.$65 Z632 4 1306 16.44 § 1247 1656 8 1188 1668 10 1129 1680 i2' 1070 1692 14 1012 1704 16 95.3 1716 STATE PLANE COORDINATES NORTHIN$ ASTING 5976296.53 689734.64 59763SS.05 689721.13 S976413.39 6~g707.41 S976471.94 689694.06 sg76s30.3S 689680.60 S976S84).86 6E19667.07 5976~47.2S ~89653.57 $97~70S.72 689640.08 GEODETIC POSITIO# A/B PLANT COORDINATES LATITUDE (N) l LONGITUDE (1) RT" I£AST '70.20t23.6~3, 148-ZTt36.823" ~.01 6487.58 70'~'24.~ 14r ~ ,37 .17 4" 81~.09 6487.58 70'~'24.~g" 1~'D7.~3~ ~.Ol 5487.33 70'~25.418" 148'~'BT.~B" ~0.07 6487.50 70'~25.~" 148'~'~8.228" ~.01 6487 70'~'~.!5~ 148'~'~8.9~1" ~40.~ 6487.48 70'~'~ .7~0" 148'~ '39.282" ~.01 6487.49 ~ HERE.~Y CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED lO PRACTICE LAND SURVEYING iN THE STATE OF ALASKA AND THAT THIS PLAT RE- PRESENTS A LOCATION SURVEY ImAADE ~Y kiE OR UNDER ~Y SUPERVISION, AND THAT ALL DlimIENStONS AND OTHER DETAILS ARE CORRECT. : 49'T AS-BUILT WELL LOCATION LGI PAD' SURVEYED FOR: ARCO :1, : I : 400 IOR'NaY:ICHK "Y.ISHEET: ......... ICO~MENTS: C~ ,tE~ LIST FOR NEW W~I,I. PFJ~rITS ITEM APP~IOVE DATE (2) Loc " r...~. 7- n,,,~'% ..... (':hru 8) (3) Adnrlnt(9't/~ -~/hru~7' z, J-~ k 10.9' ~(10 and ii) / 12. 13. (4> (14 tt~' 22) 14. 15. 16. 17. 18. 19. 20. 21. 22. (5) BOPE ,~.~.~. (23 thru 28 Company_ /~.i. ¢0 Lease & Well No. YES NO 'the permit fee attached /~2~_ "' IS · · · · · · · · · · · · · · · · · e · e · e e e · e e e e e e e e e e e e e e e e e 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 fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed eeeeeeeee eeeeeeeeeeeeeeeeeeeeeeeee Is the lease number appropriate ..................................... Does the well have a unique, name and number ......................... Is conductor string provided ~ **************************************** Will Surface casing protect freshwater zones ....................... /~f . Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ... ~7 Will cement cover all known productive horizons .................... /~ 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 ............................ 4~ 23¸. 24. 25. 26. 27. 28. Is a diverter system required *************************************** Is the drilling fluid'program schematic and'liSt of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached./~ Does BOPE have sufficient presstm-e rating - Test to .6-'DO~ psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. · Is the presence of H2S gas probable ................................. (6) O~ /V,A, (29 thr~ 31) For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented (6) Add: 32 Additional requirements - Ceology: ~gWB WVA .~ JAL rev: 07/18/86 6.01] POOL INITIAL CLASS STATUS GEO. AREA ~0 UNIT NO. ON/OFF SHORE Additional Remarks: 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. .VP OIO.H02 VERIFICATION LISTING PaGE 1, -~ Rr. EL HEADER E~VICE NAME :GCT ATE :86/09/,22 RIGIN : EEL NAME :R DEPTH ONT!NUATI,gN # :01 REVIOUS REEL OMMEN'TS :SCHLUMBERGER GCT LI$ .'-'-.,. TAPE HEADER-,~""'-,. 'ERVICE NAME :GCT ~'~TE :86/09/22 iRZGIN :0000 'APE NAME :1714 ,ONTINUATZDN ~ :01 'REVIOUS TAPE : OMMENTS :SCHLUMBERGER G C T L I S TAPE ~;~ FILE HEADER ILE NAME :GCT EDViCE NAME ERSION ~ : ATE : AXIMUM LENGTH ILE TYPE : REVI~US FILE .o001 1024 :::: INFORMATION R~CSRDS_ ...... ,-.,. NEM CONTENTS UNIT 'TYPE CATE SIZE CODE N : aRCO AL4SK4 INC 000 000 013 065 N : LGI-2 000 000 005 065 N : PRUDHOE 8AY/LISBURN~ 000 000 OZO 065 ANG: I4E 000 000 003 065 ~WN: lin 000 000 003 065 ECT: 1 000 000 001 065 ;]UN: N.SL~P= 000 000 007 063 TAT: ALAKSA 000 go0 006 065 TDY: USA 000 000 003 065 HEM CONTENTS UNiT TYPE CATE SIZ6 CODa VP 010.H02 VERIFICATION LISTING PAGE 2 SCHLUMGERGER ALASKA COMPUTING CENTER COMPANY = ARCO ~LASKA~ INC. WELL = LGI-2 FIELD = PRUDH~E B~Y,-LISBURNE POSL COUNTY = ~O:~'TH SLOPE ALASKA : ALASKA JOB NUMBER AT ACC: 7171~ RUN ~DHE, DATE LOGGED: OB-SEP'T-86 LOP: RICK KRU'WELL CASING : 9.625 ~ 10150 - BI'T SiZE : 8.5 TO 10150 AZIMUTH OF PLANNED VERTICAL PLANE: 45.916 SURFACE LOCATION: 1365' FNL, 1632' F:L,,. SEC I, T!IN, R14E, UM GYRO CON'TZNUOUS T-DOL (GC'T) ::~ ,VP 010.HOZ VERIFICATION LISTING PAGE ;:-' D E F f'N I T I 0 N S: -,- HLAZ= AZIMUTH "'-,- DEVI: DEVIATION .~-"~ GDEP: GYRO DEPTH .,."' ~: VDEP: TRUE VERTICAL DEPTH, ~: NSDR= NORTH OR SOUTH DEPARTURE '.¢-~ EWDR= EAST OR WEST DEPARTURE ;~ DGL = DOG LEG (CURVATURE ~F TH~ WELL) ~',~ :X: D~TA FORMAT RECORD :::~:: NTRY BLOCKS TYP~ SIZE REPR C~DE ENTRY 2 1 66 0 ~ I 66 i 8 4 73 60 9 4 65 .liN 15 1 66 1 0 1 66 0 ATUM SPECIFICATION BLOCKS NEM SERVICE SERVICE UNIT A~I API APl API FILE SIZE SPL REPR ID ORDER m LOG TYPE CLASS MOD NO. EPT FT O0 000 O0 0 0 4 OEP GCT FT gg 000 O0 3 0 4 OEP GCT FT O0 000 O0 0 O 4 LAZ GCT OEG O0 00~ O0 0 0 4 EVI GCT DEG 99 620 11 0 0 4 SDR GCT FT O0 000 O0 0 0 4 WDR GCT FT O0 000 O0 0 0 & GL GCT FT O0 000 O0 0 0 4 PROCESS CODE (OCTAL) 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 go000000000000 1 68 00000000000000 EPT 65535.5000 GDEP 40.0000 V'DEP 40.0000 HLAZ 305.9775 VP 010.HO2 VERIFICATION LISTING PAGE 4 EVI 0,..559~ NSDR ERT 65500.0000 GDEP EVI 0.1863 NSDR EPT 65400.0000 GD~P EV! 34.8286 NSDR EPT 65320.5000 GDEP EVI 26.6312 NSDR 0o0000 1101.7996 -4.7566 5452.2979 845.9625 10049.9961 2231.6108 EWDR VDEP EWDR VDEP EWDR VCEP EWDR FILE TRAILER ......-,--,- iLE NAME :GC'T .001 ERVICE NAME : ERSION ~ : E : AXIMUM LENGTH : 1024 ILE TYPE : EXT FILE NAME : , TAPE TRAILER ~:, ERVICE NAME :GCT ATE :86/09/22 RIGIN :0000 APE NAME :1714 ONTINUATION ~ :01 EXT TAPE NAME : DMMENTS :SCHLUMBERGER GCT LIS T~PE $ REEL TRAILER ~:~ ERVICE NAME :GCT ATE :86/09/22 RIGZN : EEL NAME :R 2:PTH -- ONTINUATION ~ :01 EXT REEL NAME : OMMENTS :SCHLUMSE2GER GCT LiS TAPE EO,m .............~ ............ :OF ' ' ' :~-~',:' '"' _ ;,~ ~'~ .,. 0.0000 110!.7852 0.1'727 5178.9873 688.130Z 9239.9180 2300.2095 DGL H LA Z O G~L HLAZ gGL HLA Z DGL 0.0000 210.~305 0.0486 38.3199 0.3676 54.4966 0.7493 ~jJjjjujj IJjjJJJJJJ fjJJJjjjJj 66 r-;. 666 o ,~, 655555 e_. 65 ~ .55 ;c, 6.55666 .~ ,55555 '.:,.; .5 $ 655. 556 .;, 66 ,:.. 656.5.56 :.:, ~ ,56. 556 ~ ;56 L ;":.3Ui ~'''-NT C2;-,pnR,~Ti'3N - V"X/V ''~,q V':' " ._, ~", RSi~N V4. q- 66666550665*'$'3 '3. 66 b 6,50566 d, .5,55.5 S 05 a 6,5 ,5.55,565.55.5 S 666 '355 '35 o 5 ~ 6 ~ .5 a .55 ,5 ~ ~ 5 ".5.5 O 5 ,.b ,S 566 7777 i 655 55555 7 i i 6 5 I ,,'3.. 55 5 7 i 5 6 5 7 'l 5 5 5 ~ v i i; 666 555 SSSSSSSS S.SSSSSSS SS &~ SS ,A~ SS ~A S~ 2& SSSSSS A.c SSSSSS AA SS CA SS ~ SS ~.~ :SS ~A SSSSSSSS ~ SSS.SSSSS A~ 3DD3DDOD AAAAAA TTTTTTT'TTT ;;;; C, ODDDDC!~, · ~, ,AA~A,&A TTTTTTTTTT ;;,; u :'DS A& AA TT ,,,, ,Db O~ ,~A Afl, TT DO DID ~,~ ~,a, TT C,D CD &A ~A TT 'DO D,D ~A~,~AA2AAA TT OD ~OD ~AA~A,~.~AAA T'T ;;;; OD 3D ,~A AA TT ;; DO DO AA A~ 'IT DDDODOOD AA fl~ T'T ;; DgDDDDOD ~A ~A I'l ;; JJJJJJj JJJJJJa JJJJJJj PP P~ ?P FiLE 3RAO:E]S4MLPO,DA'T;O (.4E'r71.,17.~O), LAST R~ViSED L?N '26-MAR-i987 08:25~ IS A 197 BLOCK S:EQUENTiAL Fi'LE 8Y UIC CACC,LUC, LAM3. THE REC:~"jR;'"~,S A'RE VARIA~:JLE L=NGTH 'WITH IMBEDBE~"J (<NONE>) CARRIAGt ~ONTRJL. TH'i L.2NGF, ST RECORD IS 84 BYTES. JJJJJJJJjj 65.5555666,56556x..665666.565~56566556~..55655565A56,55",~ .. ~ .' ,, ..... . ...... o,.,66,556,:66665.46565565.50.56~55~o.5~5555 jjjjJ'j, JJJJJJJ,jJ'J 6666566666655 015~ .= E.~UIPMENT CORPi2RATI~N - V~X/V:'4S VERS.13N 'V'4.~ ,5o06,5666.5556.~6 jJ,Jjdj, JJJJJJJJJJ ,56~65~,5~¥656565~5&5~5`~65,565666$66555~5~6~56556~6&~55~`~555~6~5~5~5.5~5~5~¥~ JJjdjJ, VAX/Vi,iS VAX/VMS VAX/VMS V&X/VMS VAX/V?,IS VAX/VMS V;iX/VMS VAX/Vyl,$ VAX/VMS VAX/VMS V AX/'VMS V,~ XfV ~,'~S V A X/V f,,1" V ~XIVM S V & XtV u;S V AXtV M S V A Xf'v MS V g X/V MS V AXfV f, tS 'v AX VAX/VMS VAX/VMS VAX/VNS V.~X/VMS V&X/V~4S VAX/VMS V.AX/VMS 'V',~X/VM S VAX/VMS VAX/VMS V A X / 'v' t,1 S '¢ .A X / V ~,i S V .,~ X / V M .S V A X / 'V H $ V .A X / V M S '¢ ~ X / V t.,'i S V A X / V .M S V A X / V M S V A X / V M S V A X ..... ¢ .... I ~ ,'" VAXIVtq S V AX I'V'MS V AX t'V MS V ~, XIV MS V,~ XtVX S 'v' A Xt"~ M S V AXIVM S V A X/V~ ~ V,~, X/'V MS V AX tv ., .JJ,jJ. JJ .JJJJJJJJ IJJJjjjjjj 7777 ! 556 5:,555 3'.3~ '7 L L 5 5 3 j 7 I ,5 .55 f.; !5 ~ 7 Z .5 5 5 ~ 8 7 ~ 1 'i 6 6 C 5 ~ ~ _ _ 8 JJJJJJ JJJJJJJ JjJJJj' SSSSSSSS S'SSSSSSS ~S 'SS SS .SS SSSSSS SSSSSS SS SS SS SSS,SSSSS SSSSSSSS DDDODDDD DDDDDDDD A~&~AA TT'TTT'TT'T'TT ;;;; 000000 DO OD &A AA TT ;;;; O0 O0 DO OD AA A~. TT :;;; O0 OO D3 DO AA AA TT O0 O00O OD DO AA .AA 'TT ;;;; O0 O0 CO DD DiD AA A.& TT :;;; O0 OO O0 DD DO hfi,fi~hA~A~ TT ;;;; O000 O0 !JD D:D AAAA.&AAAAfi 'TT ;;;; O00O 03 DO DD fi~ AA TT ;; O0 OO DC, ODODODO3 AA ~ TT ;; OOOOOO 033DDC, DD &A AA TT ;; O00CO0 F-'TLd, ..,,.. D'RAO' C]S~MLmO. ....... n;.NT ¢ 0 (4571,17,0), L~S'T :;.'r';VISED,. ON 25-M&R-"~. 987 08'25~ l~ A 15'7 '"":,L'3C K S; ;~ U E i'~.T z &',.... BY UI~ CACC~LUOLfiM]. THE RECI'RDS AR~ VhR!ASL;- LENGTH ~,~iTH IMBED'DE'2 (<:NON:E>) CARRIAGE C,'.]N'T'R3L. T'ME RECORD l.S 84 BYTES. JJJJJJJJJJ JJJJJJJJJJ JJJJJJJJJJ PILE, L ,.3 N .5 0 T d ~ R JJJJJJ JJjJJJ JJJdJJ ~:: .... S C H L U ?~, Fj E R G E R ..... ;:-' L ':' :$ T A m V~RIFZCAT'J:~N .... L'~S1''~''~. .~N~ .... .'v,~ O!O.m02 VERiP!CATiSN LiSTiN,3 o.'~GF_ i :;;: REEL HEA'OER ~;: iERViCE NAME :EOiT )AT= :,57103125 ~ONTiNU~TI~N ~ >REViOUS REEL : 'CMMENTS :L~R~RY TA~E ,:~:: TAPE ME ~ERVICE NAME :EDIT }ATE :~7/03/Z5 }RIGiN :0005 rAPE NAME ~ONTINU4TiCN ~ :01 ~REVIGUS TAPE : 'OM~CNTS .LibrARy TAp~ k;~: :, iL_~ HEADER -,--,- :ILE NAME :EDIT .OOl ~ERVICE NAME : ~ERSION ~ : }ATE : "lAX!MUM LENGTH : !024 :'IL~ TYPE : ~REVlOUS ,mlL~ : :::-I~ INFORMATION RECORDS ~;~ = N T S 14 N E M C 0 N T ,- CN : AR WN : LG FN : PR RANG: 14 TOWN: I1 SECT: 1 COUN: N. STAT: AL CTRY: US MNEM CO ~LASKA !NC I-2 UDHOE SAY/LISSURNE N SLOPE AKSA CONTENTS PRES: E · :;:':~ C 0 M M E N T S :¢ :',.: U N I T U N .i T ! I ! I TY 000 O0 O O 00 ,',,.30O 000 000 00 O TYPE CAT~ O00 O;3O 000 000 OOO 000 000 CA'T E SIZE 018 O26 004. 004 002 012 006 003 :S I ~_ CO DE O 6.5 0,5 .5 055 O6.5 055 O 065 055, C ,3 D:E : S CHLUM5 E R GE : ~L~SKA C:..3M;UTZNS CENTER ;:,, 0 M'~A;q Y = ARCO ~,---LL = LG2-2 :TEL~ : PRUD,'!,C}'-- B.~Y/LZSSURN:: 'OUNTY = NE, R'T'-! SL-PE ;TATE = ;UR=ACE LCCAT~'ON = ~ 3A5' FNL & ~5~'~'F''L SEC I 'r~ IN Ri4' 108 NUMBER AT .'ACC: 7!658 P~RMANENT SATUM: MSL =L~_VATiONS: ~UN ~I~ D,&T:E LOGGE3': ' 2-,&UG-3~ EL V OF PSRM ~,A - O~- L '3 CUDN=Y LOG F4EASdR~,O FR~;','~· RK5 OF: ~I.0 ~ DRLG MEAS;JR~D =RGM: RKB GL: 8.0 F NPI SERIAL N~: 5002921634 )EPTM-DRILLER = !0150 F CASING-DqiLL~R = 9198 = )EPTH-LOGGER = 1,0151 F C,&SiNG-L3Gi$'=R = ~i94 F ~TM. LOG INTERVAL= 10136 ',= 'CAS'lNG = '3.625 ~' FOP LOG INTERVAL= 9194 F WEIGHT 47.0 L6,/F 5ZT S;ZE CSPT~ 'YPE FLU13 = CONTR'2L..LED SAL!NZTY ;,.:NSZTY = 9.4 LB/S 'iSCCSiT'¥' : 3'~3.0 S ~n = 11.6 :LUiD LOSS = ll.l C3 'IMf Ci~C STCP°=D= 34:30 ~/12 'i~IF. L'-',SS=R ON ET'"' = IZ:""O :5II':' lA× REC. TEMP. = ".-51.3 :.OF .OGGiNG UNiT N'2:8334 .OGGiNG UNiT LOC: PRUDNOE 5.AY :!ELD =NGiNE7R: TTNKHAM ~ITTNESSE3 5Y: P,qZYSYSZ,~WSKZ 4A'T,RIX = LIMESTONE ,~OEN : 2.71 G/CZ )HC : NONE ~C = CALl :LUiD O NSITY = 1,0 GM/C3 ~.~:N~ARKS:... 1.5" ST&NDOFFS US£D ,~"N ........ DLL 2g,500 PmM Ci :"'~.LL :.'ASS DU'~ TEl MAX PdLL OFF 5'JTTOM, TARGET L'OCATION: '700'~St R?iPE~.T US ~'=_0 AS 'MA~-'N & :50O'FWL 3t-iZN-15E. VP 313.b02 V~q'FIC&TZ3''';., _l '.STZN5 P&G~ 4 ASZNG. LLD C:&L R'EL~Y NOT ~ORKENG FD~ AHT'":~ CALS~ -'3',~4HCLE ~LT AFTER CALS ~ - . ' ' ........... ~E&C;JSE "' = '",~.~X PULL ,Dh ~TALNE'D ZN C&SZNG LgT/CN=/EPT ~ZD N~T 3 TG ~6TT'"', ,,,' LL/NGT RUN. LDT/CNL/ZPT '3~ SP2K¢_ .~T ~O~O'. CUE T3 O~:NSZTY. SOURCE ~,CTTV~T~NG. , . QUi?i4ENT NUMBERS: OLE E 7'B'9 TCC A 107 C,L$ F 75 9 773 9 >4 G 2 S 7 ~, £ TO" ~D ~'13 ~LL iNT-P,,PR,-TATZONS, "' '~R~ OPINIONS 3ASZO .ON zNF,-;~" " 'N,"':S ',THE.k >IEASUREM~N'TS ~NO ./,.r: ~NNCT, ~NC g~ NOT G 'ORRECTNESS OF ANY 'NTERPR::T~TZSNS~ &NC wE SHALL NJT~ EXC=PT ZN T~'E C&SE OF ,'ROSS CR WILL=UL, NEGLI,;:NC'E~ ON JUR .PART~ 5E Li&BLE ~"R.. R~ESPG:.JSiSL: rO~ ANY .OSS, COSTS, DAMAGES OR 2XPEN:SES ZNCURRSD ER SUST&i~ED 5Y ~".~YONC R'E.SULTiNG :ROM &NY iNTCRPR~T.A'TiON M~IDE 6Y ~NY O'F OUR OFmlCS:RS, A,S.~N'TS~ OR EMPLOYEES. 'H2SS iNTERPR~TATTONS._ . .a~. . ALSO SO~JECT.. TO OUR ~S SET OUT iN OdR CURRENT PRICE SCHEDULE. THiS .DATA :HAS !:~EEN DEPTH .,, VP C, IO.HOZ VERZFiC&Ti'JN LiST!>:S ,s.&GE 5 :NTRY BLOCKS TY~E SIZE REP~ C~D~ ENTRY 2 ! 66 0 ,~ i 5 5 ! ~ 4 73 60 9 4, 65 .. ." iN 1,5 i 66, 0 I ,5,5 DATUM SPECiPICATZON BLSCKS 4NEM SERVICE SE~VIC5 UNIT AFi A?Z ,~PI APi ~ZLE SiZE SPL REP~ ?ROCESS ID ORDER ~ LOG TYPE CL,:SS MO2 NO. COOE (OCTAL) 3EPT PT O0 000 O0 0 0 ~ i ~8 OO000000000OO0 _LS ~LL JH~M O0 220 09 O 0 4 i 68 00000000000000 VP OlO.d02 VERiF'iCATiCN L'rSi"iN9 PA,3:: ,5 LD JR P VO i0 VO IO RES ENS :R AT ~N R A ,'CNL :CNL 'R FENS ,! T E M 'AL1 )PH ! .L .U .S .!TH 551 ~?SS FENS ~.RES ~,GR .~GR ~OT& FHOR ~3NG N'~NG ,~SNG ~ [NS SALi TENS OLL DLL 3LL C. LL SLL 3LL CLL 3LL 3LL CNL C NL CNL CNL C NL CNL CNL CNL CNL L3 T L D'T LJT LOT LOT LOT LDT L DT LDT LOT L3T LOT LOT LDT L3T LOT L 0 T NGT NGT N ST N G T N G T NGT N G'T NGT N GT NGT W GT NGT E P T EPT 2 ' M M O 0 2 Z 0 10 0 G .& P l 00 3 L 0 0 f.i V 0 O O I 0 ,31 0 Mv O 0 CO O OC O U & 00 003 0 'O O MV O0 000 .... ~0 :823 50 3 E G ~ 0 O 660 5 j O L~ O0 635 21 0 03 ~2J C.l :J O0 000 O0 P U :30 B 90 C~S O0 3~0 31 . C P S '~. 0 330 G ~ P l 00 '31 O 01 C L S 00 635 21 0 ,3 d M ~,l O C 823 5 3 ~GF O0 .560 5 O .3 G.&PI O0 310 O! i N 00 2 ~ 0 O I 3 g / C 3 O 0 3 50 02 O G/C3 O0 356 Oi 0 F U 0 O :~ 90 O 0 0 OD 35~ O1 0 CPS O0 354 O! C P S 'J 0 354 01 0 C PS O 0 354 0 i C P S 00 35,4 C PS 00 O00 0 CPS O0 000 O0 0 O0 000 O0 0 O0 000 O0 L8 O0 535 21 0 0 d M M 0 O 'B 23 5. 0 0 D:GF O0 560 50 G.': P l O0 310 O! 0 G~.Pi O0 310 O1 0 OU O0 719 50 0 P P M 00 79 O '50 0 PPM O0 792 50 0 C PS 00 3~ 0 01 0 C P S 00 .3 Z 0 0 ~ 0 · C P S 0 '0 31 O 0 i 0 CPS O0 310 O1 0 CPS O0 310 Oi 0 O H M M O 0 823 50 0 O~.GF O0 560 50 0 L5 O0 535. 21 0 G ~ P l 00 310 01 0 ; N n ,. 280 01 C, L 5 0 O ,535 2 i 0 1 68 O0000000'JOOO00 " 5.S "~O0'"'O00000'OO0 1 65, 053":3000000'"00~. i 6~ 1 6~. 03000000000000 i 68 O000OO000.~,3000 68 OJ33JO000 0000 i ~2 O0'O0008OO00000 ! 6~ 3000CO000JO00C i oS $OOOOOOOOOOOO0 1 6~ O000JO0000000O 1 63 O000008OOOO000 i 53 O00"'OnOOOOOOO0~, i 58 OCCO000,OOJ,~,OnO 1 62 OOJO00000'~OOOO~ i 88 O00000000OO000 i 68 OOOO0000OO0000 .~ o8 30000000000000 i 6':',., O00O300000000O i 65 O00000000OO000 I 68 O30000OOOOOOOO : 68 00000000000000 ~ 6S 00000000000000 Z 55 i 8¢ JO000000000000 i 68 00000000000000 ! 58 1 68 i 68 30000000C, OOOO0 1 68 i 68 00000000000000 i 88 I 8B 30000000000000 1 68 i 58 0n~O~,O000000000 I 58 O000000OO00000 i 88 1 58 00000000000000 i 68 0000000'0000000 I 68 00000000000000 1 68 00000000000000 i 6¢ 00000000000000 ! 68 ! 66 O000OO00000000 ! 68 1 6'a O00OO000000'O00 I 65 O0000OO0000000 1 ~'8 00000000000000 ! 5;¢ 00000000000000 i ,6, ':~ O0000OO0000000 2 68 00000300000000 )F-PT 10i60.0000 LLS io -999. Z500 SVO )lO -999.2500 ,RAT -9'9'9.2.500 ,iTEZ -g99.250J JR ~RH2 -9~9. 2500 DPt! ~52 -999.2300 QSS ,~R ES -999.25 O0 MT ~OT ~ - 999.2503 T 4~5 -999 2500 W3N" qR~S -999. 2500 M'T ~: M -ALl -'999.2500 TENS 35PT 10100.0000 LLS S? -42.4063 SVO 310 56. 8125 MRES '4RAT -999.2.500 ZCNL -999.2500 qTEM -999.2500 DR,'3 0.0093 OPHi LU 203.7500 tS SS2 281.7500 ~SS V~RES 0.0635 POT& 1.5625 ~2N G 69. :~ 125 MR~S 0.3688 MT~M CALl 4.5977 TENS DEPT I0000.0000 LL$ SP -35.6250 SVO DiO 247.5000 MR~S NRAT 1.5.293 RNR& FCNL 1~82.0000 GA MTEM 167.3750 GR DRHO 0.0239 DPHi LU 235.3750 LS SS2 Z97.7500 QSS MR~S 0.0640 MTEM POTA 0.7813 THCR WZNG 52.5525 W3NS MRES 0,05,88 NTEM CALl 9.3203 TENS OEPT 9900.0000 tLS SP -36.0000 SVO DiO 248.7500 MRE3 NRAT 1.5332 RNRA FCNL 1211.0000 GR MTEM 166.1250 G~ DRH3 0.0059 OPHI -995.2500 -9~9.250' -9~9.2500 -'999.25J0 -999.2500 -99~.2500 -999.2500 -999.25O0 -999.2500 -999.2500 -999.2500 -999.250C -999.2500 3'73.631~ '28.125C 0.0598 -9'}9.2500 113.5875 113..6575 2.1484 208..3750 0.0195 157.3750 5.2383 29.4063 155,0000 4904.0000 58.46,27 12.609~ 1.6845 29.8125 29.8125 6.5913 .2.43.12~0 0.0.322 167.3750 2.3125 19.5938 157.8750 71i2.00C0 37. 11'~5 8.0234 1.4297 1'9. 3594 i 9 · 3 ~ 94 5.9570 LLO SiS P; T E 71 N'P~i T CALl PEF LiTm ~4N'3 LLD SIO P, T E M NP;WI TENS CA Li PEP LiT~ '2LS SGR b R A N W 4 N G TTNS S£0 M T ~ M NPhI TENS CALZ 'P ~ F t i TH QLS $GR UR'AN W4 NG TENS LL~. SIO MT E~'q NPHi TEN S CALl PEF -:}5'~. 2500 -959.25'3.0 2, VO -999.2500 T'£NS -9'~9.25,30 NCNL -~95,2503 -999. 2500 RHCS -99~.2500 LL -999.2503 -999.2500 TEN - 999.2500 -999.2500 -999. 2500 4, 7 .B · 17 ! 4 S G "~ i'39.1 23C DVO i :59.000'2' TEN S - 999 o 25 O O NC,bt -999.2500 !..'IRES J, 5300 RHO2, 3.4304 LL 37.3125 SSi 0.0239 TENS 49.50 O 0 C-'$R 1.077 1 W i N $ 5.511'7 ;~ 5N G 5088.0000 GR 58,74! 8 SGi4: 267.0000 OVO i57. 8750 'TENS 6.7.871 NCN L 7112.0000 IqRES ~. 3, 594 R ~06 2,9082 LL 5,5.37 50 S51 O. O02,4 'TENS 28.6 553 CG'R 1.7705 W 1 N G O. 8"J11 WSNG 5 ~'72, O0 O0 G'R :,,50. 313.5000 155,5,'.}00 TENS 6.3 '-:) 65 N C N L 71,58.0,000 MRES 9.59 4.0820 LL -~9~. 25 O0 - $ '99. '25,30 -99'9.2.500 -999.2500 - 999.25 S 0 -999.2500 -9' !:..)'~. 2500 -999.2500 -999.250 O ~99. '*:500, - 999 . 25 O 0 -995.250,0 35.9062 5088.0000 -999.2500 -999.2500 2.6719 105,5525 2'15.3750 ~40:~,,0000 .4~.3750 128.6250 3.5'7~g 113.68'75 28,6563 16,3251 6172,0000 3340.0000 0.0640 2.5957 1124.93"75 228.5250 710~.0000 2!.0625 91.0625 0.~911 .35.468~ 20.0459 14.2103 1732.0000 0.0649 2.5074 117.3753 VP OlO.HO2 VERi;IC~T-3N LZSTiNG ?&GF 8 U 224.250',3 LS S2 283.2500 QSS RES 0.0S49 OTA 0. 3906 T ~t2, A lNG 33. 9062 W3NG RES 0.069,5 ALi 9.5.953 T-'NS IEPT 9&OO."JO00 LLS ,F -37.7500 SVO )lO 145. 502J MR'ES iRAT 1.2~61 :CNL 3938.0G00 ~T ~,1 15~.7500 GR )RHC 0 042~ DP~ U ~ 1 ~ O O 00 ~ .S ;52 2'93.0000 ,255 ,IR 5 S O. 0654 MT ~= M ~CTA O. 1933 THOR ~2NG 31.2127 W3NG ,!R E S O. 069 B MT ~M 'ALi 9. 8~Si~ TENS )EPT 9'700.0000 tLS iP -44.7158 SVO )IO 53. 5313 ,MRES ~RAT 1.0566 RNR.~ :CNL 5176.0000 SR ,iTEM 162.7500 GR }RHO 0.0034 DPHZ .U 207.~000 LS ~S2 277.7300 ~SS 4RES 0.0664 MT~M ~OTA O. 4395 THOR ~2NG 36. 6437 W3NG qR E S O. 070.3 MT E M ]ALi 9.6~8~ TENS )EPT 9600.0000 LLS ~P '-36. 7188 SVO ]i0 304-.2500 MRES WRAT !.2,617 RNRA =CNL 2922. OOOO GR ~TEM 161.3750 GR ~ R H 0 0. O. 59,5 D P H ,l -U 221 ·7500 LS SS2 299.5000 QSS qR 5S 0. 066'~ MT.=M ~'.O T A 1.1230 THOR ~2NG 74.5625 W3NS qR:'S O.OTOS Pi, T ~M SALi 9.2813 TENS 229. 5000 LiTm J. 0'532 WL S i6,5.0000 SSR 6.~141 155. ~OOO TENS 1.52. 2392 LL2, 21.7031 S-O 3.0695 !. 3337 NPHi 2!.7656 T'-NS 21. 7656 C.~LI i. 8555 PEP 2i9.2500 LiT~i 0.0332 ~LS i~4.7500 SGR I . 7'~ 52 UR 8.2578 ~4N' 155.5000 T" NS 72 O ~. 0003 590.0739 LLD 32. 71'88 SiO O. 0703 MT~M i . O 7 81 N P H i 21 .2793 'F L~ NS 2i. 2793 CALl 2.5879 PEF . ~- 50 L I T d 0.0190 ;~LS 162. 7500 SGR 1. 7861 UR~N 9.2109 W4NG t54.3750 TENS 63t2,0000 53.g~827 LLD 12.0547 SiO 0.0708 MTEM 1.262'7 NPMI 56.4375 TENS 56,. ~+37 5 CA LI !. 8066 PEF 225.2500 LITM 0,0361 ~LS 161.3750 S, GR 2.7109 UR 25.5313 W4'NG 153.3750 T~NS 6'980. 0000 155.5144 SSq 206.6250 CVO 155. 5000 TENS ~_? · 5,355 NCN' 7260.0000 MR/ES 9 . 7508 R ~.~5~ LL ¢5. 5938 SSi 8.0322 T~NS 23.609~ CGR 1.7520 !. S 359 63~8,0000 GR ,566. 5150 SGR 80.37:50 OVO 154.3750 TiNS 0. 7~13 NCNL 6740.0000 MRES 5.203! LL 40.2500 SSi 0.0005 T~NS 23. 5469 CG~ I. 1514 W 1 N G t. 84 Z 8 W 5 N G 40.0360 SGR 324.2,500 DVO :153.3750 TENS 2.929'7 NCNL 682,4.0000 MR~S 9.2813 RMOB 3.99~t gL 49.1562 SSI -0.0044 T~NS 45.7813 CGR 2.5273 W1NG 5.5234 WENG 6568.0000 GR Z 1 S. 6 Z 50 7360. '3 O O 0 15..007~ 56.3125 0. '300 O 23.5094 25.4375 5136,0000 2.675'$ 113.2500 22~.,5750 7260.0000 in 4141 86.3125 2.7539 21.7656. 23.5469 40.093~ 6'54~.0000 555~.0000 0.06~4 '2.6541 105.93'75 2!3.0'000 5~12.0000 14.0156 BI.0625 :3.6'855 20.9199 45.7813 13.5953 S565·0i]00 3692.0000 0.066'9 2.67'77 114.43'75 2.34.7500 6980.0000 27.9219 143.6250 1.8408 58.9062 DEP'T 9500.2000 tLS 12'77.85i8 LtD 3202.3115 SGR 23.843'7 i? ,~RAT :CNL :~ T =~ ~.", )RriO .U ~S2 qRES ¢2N.G :ALl )EPT }.p '~RAT :CNL q T E M _U vIRES JOT .a ~2NG DEPT SP =CNL -U ~2NG :qR ~S CALl DE:PT SP 3i0 NR A'T FCNL iq T E M LU SS2 MRES -35.'5052 SVO 1 ~ · 75,13 M R':: 3 t . J:'71 RNR '~ ,-~ 5564.0000 GR lSO,O000 GR 0.0073 ~PWI 217.3750 LS 278.7503 QSS 0.057 '~ M T E ~'.~ 0,2~41 T'?CR 29.0313 ,~3NG O. 0 7 i S M T E M 9.5751 TF~NS 9400.0000 LLS -24,0313 SVO 572,5000 MRL:S 3,9453 303.2503 GR 158,0000 0,198T OPHI 544,5000 LS 41-~,5000 ~,~SS 0.0688 MTSM 3,0.273 THOR 150.0000 '~3NG 0 · O 728 10.7556 TENS 9300. 0000 LLS -,~. I ~8 SVO 96,0625 MR~S' 1.3252 RNRA 3402.0000 GR 156. 2500 GR O . 0068 D P H l 24'3.7500 LS ~0.7500 QSS O. 0703 MT~M C. 537 L T M 0 29,4844 W3NG ~, 0732 MI~M 9.5'703 T~NS '9200. 0000 LLS -30.'3906 SVO 304.7500 MRES 4.0078 RNRA 267.0000 GR 15.4.. 3750 GR O. 1655 C, PHi ~0.7500 LS 402.. 0. OTOB 0.0718 1,1064 22,2'331 Z2,2031 22~o0000 0.0433 160,0300 3,3159 9. 9766 152.0000 5872.000U 4.0238 ~. ;1'91 0.0728 4,0742 ~8. 7500 95,7300 = 09'77 572.0000 0 ,. 0;511 i 58. 2500 9.382~ 61.6575 151.2500 6'744,0000 148,4178 20. :5938 0,0732 1,3809 30,9.453 30,9453 8. 3088 2.4..5.3 '75 O 0.0312 156. 2500 2,3.164 .15,5 '78 I I49.0000 6724.0000 4,8840 2,4043 0,073'7 4,1758 81,0892 8i,0892 23,4375 0.0'73,7 15,4.3750 SIO MTEM TENS C~LZ LiT~ QLS SGR ~4NS T2NS LLD SiO M T ~ M N? HI T '= N S CA Li LiTr~ QL S SGR URAN W4NG TENS' L L D MT EM N~HI 'T '~NS CALi L I 'TH ,;~L S 'SGR URAN W4NG T E N S LLD S!O NPriI TENS CALl PE F LITH ~ L S S G ~, 48,2187 DVO 152,0000 TuNS 0,'7324 NCNL 6~72.0000 FIRES 9.5797 RHJ5 5.3359 LL 43.3~3~ SSi 0.0205 TENS 23.n437 CGR 2.1575 WiNG 2,7207 WSN'.':~ ,5360.0000 GR 5. 9508 SGF; 763.5000 D VO 13!. 2.:500 T'-2N S ,+1.3574 NCNL 674 ,+. 0:30 O !',,~ R ":': S 3.2~Z LL 150.5000 SSI -0.0503 T~NS 95.3125 CGR 1,4473 N1NG 2.7517 NSNG 6332.0000 GR :£ '77,6 4 ,54 S G R 201,125,0 OVO 149.000 O TENS 3.4180 NCNL 6712,0000 MR'ES 9 · 5623 RHO'5 5,2344 LL 4B.5,525 SSI -0. 0337 T~NS 25. 703! CG~ 0.89 ~ 4 W I N G 2.7637 W 5 N G ,5165.0000 GR 11,3256 SGR 714 :CO,~ O · ~0 VO 148,$750 'T~NS '40.52'73 NCNL 54.B4,0000 MRES 15,23'44 RHOS 3.710'9 LL 1,2B.5000 S.Sl -0. 033.2 TENS 78. 6250 C 5272.0000 '~ 0679 2,6250 ii$,2500 5950.0O30 7,273.4 81.625~ 0,90'72 22,9941 95,3125 3.~28i 6332.0000 1224,0000 2.2793 319.75,30 6~12,0000 ~3.4375 319,5000 9.2031 98.7500 25,7031 29.9587 6165,0000 4700,00,00 2,5664 123,56,25 222.2500 6~12,0000 17,509~ 73,6875 3,6855 29,2~13 78.5250 3.88O9 60,64.0000 !i15.0000 0.0703 2,. 30,56 269,0000 305,7500 64,4375 V? C1~ HO2 V~RiFIC~ .... ..... , iCN L~$I~No PAg£:. i0 DTA 1.9043 THCR 2NG !1t.2500 ~3NG R F- S J 07 ~ 7 M T ~ .... ~kl 15.2344 TENS EOT P i0 R ,'~ T C NL T EM RaG .U ;Si !RES )EPT ~RAT :CNL .O ~S2 ~2NS ,1R~S ~ALi )EP T ~P ) i 0 :CNL ,t T E M .U ~S2 ~tRES ~ZNG ,1RES :ALi ]E,~T ~P ,~R .,~ T 9100.0000 LLS ~ .4688 SVC 9'97. O 30 O iN12-' S 2.6835 RNRA 550.0,$00 Gq 152.6250 -0.4541 ~?'~i 152. 5000 LS 99.5000 0.0713 MiEM 0.1455 54.1875 'WBN6 0.0737 MIeN 8.6563 TENS 9000. O0,OO LLS 25.2187 sro t011.0000 MRES 2.3a38 RNRA 733.500 O G R 150,5000 GR -0.5039 DPHi 137.$750 LS ,'S4. 0625 QSS 0.0723 0.6836 THCR 42.9375 W3NS 0.0767 MTL:M ~. 6172 'TENS 8900.0000 LLS -8.9297 SVO 979.0000 MRES I . 925 ~5 RNRA I025.0000 GR 148.2700 GR -0.4756 DPhi 153.2500 LS 97 . 3 125 ~ S S 0.0728 MTE~q 0. 4395' 'Tmi31~, 24.5469 W3NG O. 0781 ~iT~ M 8. F, 938. 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O0~ 18.9531 -999.2500 -999.2500 -999.2500 -999.2500 .Vm :)lO.mO! VERiFiCA'Ti2N 'mISTiNG PAGE Ii :CNL ,i T E M )RHC .U ~S2 '~RES ",RES ]'EFT qRAT :CNL ', T E M )RHJ -U ~ S 2 4RES ,~NG qRES .:AL]: DE PT ~P ~RAT =CNL .1 T E M )RHO _U ~S2 q2NG ,iRES :~LI -9S, 9.2500 GR -~9'9. 2500 -~99.2500 3PMi -999.2503 LS -999.2500 ,~SS -':99 ~SOO MTE" -999.2503 TmbR - 999. Z 50 O -999.2530 TENS 8700. 3000 LLS · -999.2500 SV3 -9'~9. £ 5'30 MRES -~99.2500 -999.2500 GR -999. 2500 -99'9. 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I0o O. i6. 16. 9531 3,567 7353 203i 3.408 8281 3667 2031 3765 ,~156 4424 4531 302. :' 7513 52 0781 3384 0313 5200 1562 :5181 5313 5156 ,_ATT E ,~, 'T T EA'TT F2 q T T' EATT E;~TT ~,TT E ~ T T ~ ~ TT E ;~ T 'T E ~ T T 10100.5320 TPL 0.3695 FVU 10000.1550 TPL 0.6191 FVU 9900.1660 TPL 0.3618 PYU 9800.1550 'TPL 0.4297 FVU 9700.!660 'f?t 0.4409 FVU 9600.1660 TPL 0.53,22 'FVU 9500.1560 'TPL 0.3574 FVU 9~00.1660 'fPL -0.~234 FVU 9300.1660 TPL 0.3418 FVU 9200.1660 T~L -0.5220 ~VU 9100.1660 TPL -0.5200 Fro 9000.1650 T~L -0.5195 FVU .lin SiZ~ SPL 4 i ~ i 4 I 63 4 i .~ 4 I 63 4 ! 84.1253 35. 6250 ~6.12.50 76.1250 93.6250 136.2500 62.56 '25 0.2002 7 '9. ,5250 0. ~ '996 0.0498 ~OC~SS, (3CTAL) 3JOCC'OOOCCOOOO 00000003000000 OOOg, OO'3OOOOOOO 000330000000'30 ~.7852 4.0527 ,.500 ~.IC'16 6.1523 4.63, i37 .2.0020 49.3t64 30.5371 39 · '79 49 ~ i, '~ ,~ 57 , .~, _ ~ ~ ~ · i~P? ,9.. S',..' 3. i 5 6 u TPL.. 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O09 S906 EATT 3567 8~05 EATT 3667 4531 EATT 4326 0781 EATT 3682 2656 EATT 3218 0156 EATT .4897 4531 E.&TT 4238 5781 EATT 3545 28t3 i~TT 5269 0156 ~T'T '3 7 94 £,81 3 E ~ T T 5229 6406 ~ATT 5229 85.1!50 '35..!2~0 93.8250 81.52.50 51,6250 107,6250 60,'3123 0.150~ '73,6Z50 0.0.50:3 0.0~98 6 S .. ~ ~PH! ~PHi EPMI EPHi EPHI fPHi E P H I PROC=SS (OCTAL) OO0000OO000OO0 OOO00000OO00OO COOO00'OC'OOOOOO 1,5065 5,5175 0.8301 5. 1270 !. '7090 2,6855 52,1484 5.i270 51,9531 VO 210,HOZ VE,q!~-iCATiCI'~ LISTING PAGE 37 AX.~.,U ,~ L ~:NGTH : i024 ]LE TY?5 =XT FZL.~ t~&:,IE : :;;~ TAPE TRAILER ;:-';;; AT',-- :8'7/03/25 Ri,SIN :OOOO APE NaME :165~ ONTINUATi3N ~ :01 EXT TAPE NAME : '2Mt,iENTS :LI~,ARY T,APc_ ;ERViCE NAME :~Z3iT )AT,": :87/03/25 )RIGiN : :ONTINUATiON ~ :01 ~XT RE~L N.~M~ ~ i!iiiilii Iilii'!ii ~5555~555~5~55555-5~55~5~5~5~5555555~5~5555~55555~55~5~55~55~5~55~5:~555~5~5~5~ 7 i 6 5 5 3 7 i ~ ,5 5 f. 3 7 ! Ii 665 55. 5 ~ S 8 iiiiil"] l!illl] IZilii] Flt..~. 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HC~ 8~Y/LISBURN~ Fi~L3 ,~UNTY = ?,~C'RTH SLZP~ ~T~TE = ALASK2 ~URPACE LSC&TZ2N = 1385' FNL ~ 1632'FEL~ Szu ~ TiZN~ 12,5 NUMBER AT ~$_,C: 7185S mER'~I,'-".N~=NT O;NTU~I: ~SL ELE'V~TiSNS: ',UN ~i, DATE LGGG~2: 1Z-AUG-86 ~LEV 'JF PERM. DATU~,~: ,3 F K~: 52.0 .OP: t. 8. CUDNEY L8'$ MEA:SUR~D 'R3M: RK~S DF: 51.0 ~RL~ . c SURE~ =RC~,~: qt<:: GL: 8.0 NPi SERIAL NS: 5002_~22153~ )EPTH-DRILLER = lO1SO F CA, Si,NG-[:'qILL~R = 9198 'F )EPTH-L'JG'$ER = 101.51 F- C~ASZNG-L,bGG~ER = 9194 F ~,TM. L~G INTERVAL 10135 F CASING = 9.625" ~OP LOG INTERVAL: ~!'~4 F W'~ZGHT ~'7.0 L~/F ¥~ 010,mOZ VS~2F[C~T'ON L~ST2NG P.aGa 3 ~LT S~ZE 'YPE =LUID = CONTqGLLE3 S.~LENiTY :ENS!T¥ = 9.4 L~/G "iSCOSZTY = 38.G S ~H = 11.5 :LUZD LgS~ = 11.2 C3 'iME CZRC STSPP~C= 04:30 5/12 'ZME L~25G~R TN STM.= i£:00 8/ii IAX REC. TEMP. = l~l.O 9F SOURCE SSURC-- .~ i"."~ ~, T R ~"~ C a, T 'J F S A i"! F" L ~: z: H F t :~ .'.I C 3HT -3bT .,]S,OING dNiT N'2: .OGSiNG UNiT LJC: PRUDhGE 5AY :iELO ~NGINE~R: TIHKHA~i iTTN~SSED ~Y: PRZY~YS,Z:~,JSKI ~.ATRiX : LIM~SI'ONE IJ~N = 2.71 G/C3 )HC : NJNE tC = C~LI :LUZD 2ENSZTY = 1.0 GMfC3 (EIqARKS: 1.3" STANDOFFS USED .'SN DLL. 29,530 PPM. CL. OLL )ASS DUE TO MAX PULL ~FF ~gT'T,']M. TARGET Li]CATi2N: 700'FSL = 101 513 ~= CIRCULATED .205 ~ 67.0 .314 ~ 72.0 MEAStM~AS · ~iO £ 1,5t, DF · 083 S 161. .i~,~ ~ 1,51. R~PEAT USED AS MA.IN & 5O9'FWL 31-12N-15~. VP OlO.HO2 V'ERZ~iC.&T'£~DN LiSTeNS PAGE &DZL~ACTZ'¢E !*I.&R.K, ER .AT ,353~'.,~ N'T SPZK;?JG (SO~O' & 896f.~')C&USE.'S, BY M~Si",~ETZZE~ ~SZNG. LLD C~L R=L.AY UCT C.R~.ZNG F3R AFTZx CALS, .iCV~ FiCLE 3LT A,--T-'.q' C~LS 6TAZN:-O iN CASZN3. LDT/CNL/EPT DiD NGT G~] TJ ECTTui~! .~E&C',JSE 3~: MAX PUL' CN LL/NGT RdN. L'3T/CNL/EPT .S.q SPIKE ST ~0~'0' D.U~ TG CENS"'TY qDURCF- &CTZVATTNr- JR!,t;1TT.3N .~,ND GF. S?lr<£ &T ~.3~.' iS CCL~LT "4ARKER. ' - '~ ~ TCC ,,A 107 iLS F 759 5LC $ 773 LCM 779 NG 2 5 7~'2 T C M .& 5 Z l 3 LL ZNTZ_RP2ETATZSNS ARE SPZNZGNS S$SED ON ZN~ER'=NCES F'R]~.I ':LECTRZC.&L T~R MEASUREMENTS ~ND ',~E C~NNJT, .eNO ~0 N~T GUAR&NTE~ 'ThE .~CCURAC¥ ORREC'TNESS ~F ANY ZNTERPRET&TIONS, AND ~E SMALL NOT~ EXC:PT IN THE CASE ROSS DR WILLFUL NEGLZGENC~E 8N OUR PART, SE LZfi'BLE ~]R RESPO~SZELE FOR ANY .aSS, CeSTS, 3~MAG~S :DR EXP~N.S~ ZNCURq'ED CR SUST~ZNE~ BY' ~NYONE RESULTING :RCM ~NY INTERPRETA'TIgN M~2~ BY ANY OF '3UR GFFICERS, AGENTS~ ~R 'HESE INTERPRETATIONS ARE ALSO SUSJECT T~$ 3UR GENERAL T:=RMS AND ~S SST OdT ZN OUR CURRENT Pq$CE SCHEDULE. VF OlO.M02 VEi~Z~ICA'l'=S!q LiSTiNG P~..GE 5 :;:: :.)ATA ,:C.'R-'N~ATi .., RECORP_, -,- ...... -..- :NTRY 5LOCKS T Y P E S .I Z E F', E P R C D.'2 ~ _; i'll T' k Y 2 1 65 0 4 I 66 8 :~ 73 6~ 9 , 65 · 1 iN ! 5 1 66 ! 0 i 6,6 0 )ATUM SPECIPICATiON BLOCKS ';NcM" S:RVIU'2~ " SERVICE .... UNIT AOl AP'Z APT_ iD O~DER ~ LOG TYPE CLASS MOD NO., CODE (OCTAL) )EPT ~T O0 000 O0 0 0 4 i 68 O0000OO0000000 .LS DLL 2HMM 00 220 09 0 0 4 i 6,~ O000000000000O .LO OLL OHMM O0 220 10 0 0 ~ 1 68 O000OO00000000 ~GR OLL SAP! O0 3i0 O1 0 O 4 V? 01'0.m0f Vf~i~!C~'l!Oq LiSTiNG P,~G~ ,'5 ¥0 !0 VO I0 f. N5 ;RAT ~N Ra ~PHi ICNL :CNL 'ENS 4RES 'I T ~ M ~R 'AL! .t .U _g _iTH ~SS ~LS T~NS qR ES q T E M PG 'T A THOR iRAN RING N2NG N3NG JSNG ~qRSS T~NS GR CALl T~NS ,.LL 3LL DLL DLL DLL DLL C. LL DLL CNL CNL CNL C N L CNL C N L CNL CNL CNL LOT LOT LDT LOT L D T LDT LOT LDT LOT LDT LDT LOT LDT L D'T LOT LOT LOT N G T NGT NGT NOT NOT NGT NOT NOT NOT N G'T N G'T X ST EPT EPT ~PT ~V MV MV CmMM L6 PU CPS CPS GAPi L5 C~MM G,~Pi iN G?C3 G/C3 PU CPS CPS CPS CPS CPS L~ DEGF GAP~ GAPI PPM 'PPM CPS C~S CPS C?S OHMM O~GP L5 GAPi iN DATA .... ,% '30 O.C, 00 "'sO 0,J 0 O 30 OC 00 00 00 09 0C 00 00 00 OO 00 0O ~0 00 00 O0 00 00 00 00 00 00 0O 00 00 00 00 00 O0 00 00 00 00 00 00 00 00 00 00 00 I0 000 000 JO 0 300 823 635 O00 ,690 330 330 3!0 635 823 560 310 356 ~ 90 3; 4 354 000 000 OOO 000 635, 560 310 310 ?i9 ? 90 7 '92 310 310 310 310 310 23 635 310 2BO Oi O0 O0 '5 C 5O 21 O! 0~ OO 3O Oi 21 SO O1 O! O1 Oi Ol Oi 0 t O! O0 O0 O0 O0 21 O1 Ot 50 O1 O1 O1 O1 SO 2! O1 O1 2 i i 55 OOO0000OOOOOO0 i 68 OOO000JOOOO000 ! 68 O00OO'JO0000000 I 58 OOOOOO000OO000 i 6~, i ~8 O0000COOOOO000 ~ 55 00003000000000 i 58 CO30OCO0,30OOOO I 6~ 00000030000300 i 6,8 OOOOOOO~O00000~ 1 5.~ 00000000000000 1 5~ 00000300000000 ! 68 OOO000OOOO0000 i 68 OOOOO0000CO000 i 5B 0OO00000000O00 i 68 C0000000000000 ! 68 OOCOOO000OO000 1 68 O0'OOOOO0000000 i 68 O00OO00000'O000 I 68 CCO000000'OO000 i 69 O000000000000O I 68 00000000900900 i 68 00000O00000000 ! 68 0"3000000000000 i 68 O0000000000000 i 68 O00000000OOOO0 I 68 1 68 OCOOOO00000000 1 ,58 .OOOOO0000000CO I 68 O00OOO000000'O0 i ,SS 00000000000O00 I 68 OO000000000000 ! 68 O00OO00OOO, O000 I 68 O000000OO00000 1 68 1 ~8 i 68 OOO0000000000O i 6S 30000000000000 t 68 30000000000000 1 6.:;3 00000000000000 1 68 OOO00000000000 i 68 O00000OOOOO000 I 68 OOO000000,O0000 1 68 O00000'OOO00000 I 58 O000OC'O00000OO i 6'a O00000CO00000O ! 68 0000O0O0000000 I 6:8 00000000000000 I 68 O00000OO00,JO00 i 68 OOOO0000000000 Vo OlO.dO2 VERIFICATION L!STiN" ?AGE 7 ~?T 10159.5000 P 21.~437 I0 1003.5000 MR'ES R~T -~99.2~00 RNR~ TEM -9~'9.2~30 GR R~O -999.2500 OP~i U -'~99.2500 LS S2 -999.2500 ~SS R f S - 999.2500 MT ~ M OTA 1,5502 THOR 2NO 97,7500 R E S 0 . 0574 M T ~L! -999,2500 TENS )5PT lOtO0,OOO0 tLS iP -42,4053 SVO )I0 66, 8125 MRES ~RAT 2,5098 RNRA :CNL 1004.~000 GR iTEM 167.3750 GR )RHJ 0.0093 OPHl .U 203,7500 tS ~32 281.7500 QSS '~RES 0,0635 MTEM )OTA 1.5625 THOR ~2NG 69.8125 W3NG ,IR ES O. 0 688 M'T :E M 'AL1 4. 5977 TENS ]EP'T 10000,0000 tLS ~P -3:5,6250 SVO ]i0 247,5000 MRES ~R~T 1.5293 RNRA :CNL 1982.0000 GR 'iTEM 167,3750 GR )RdO O. 0073 DPHI .U 229,5000 LS ~52 290.0000 Q.SS 'aRES 0.0640 MTEM -','OTA 0,7813 TH3R NZNG 52,5625 W3NG qRES 0.0668 MTEM $ALI 9,3203 T E?,iS 3EPT 9900,0000 tLS OP -35.0000 SV'O 310 24 $, 7500 MR.E:S NRAT 1,2793 RNRA FC NL 2496,0000 G'R ~,iT EM 156.0000, GR ORH'S 0.00.59 DPHi LU 224,2;300 tS SS2 263,2500 !QSS 0.1495 3.0503 3.0674 -~'59.2530 -99'9.2500 -9~9. 2500 -999..2500 -~99. 2500 -999.2500 -9 ~9. 2500 1.9199 37.12~0 159.0300 -999. 2503 373.6818 23.1250 0, C68~ 2. 648~4 113.6875 'i13.6875 2.1484 208.3750 O, 0195 167.3 750 5.2383 29.40 63 ! '~ ~. 0000 4904.. 0000 68.4627 12 ,. 5094 0.0688 1 · 68 ~6 3.5.4688 35.4688 6. 4941 23~.,6250 0,0234 167. 3750 2. 3125 19, c938 7112.0000 37.1185 $ · O234 i. Z 35 ,r.+ gO. 8750 20.8750 5,9570 229.5000 LLL) SiO M T E M NPhl TENS C,~Li P~F tlTm QLS SGR TENS LLO SIO MT EM NPHi T E N S CALl PEF LiT~ ~,LS ~R URAN WaNG TSNS LLO SIO MT EM N? hl 'TENS PE, F LiTH QLS SGR UR.&N WaNG T ,~ NS tLS SiO ,~T EM NP H.Z T f N S LiTH ,~LS 1.114.2 SGR 230,8. OOCO DVO 159.03'O 0 TEN S -999. 2500 NCNL -999.2530 MRiS -999. 2500 R'H'JS -999.2500 LL -'9'~ 9. 2500 SSi -999.2500 TENS 58.312~ CGR 4.7422 WiNG 2 . 47~6 W 57,i G 3574.0000 GR 47~.I'714 SGR 109.12~0 S'VO 159.0'303 TENS 26,0742 NCNL 4904.0000 M R!': $ 4 . 5 ~ 7 7 R ~ O S .3.2 ~ 3 '2 L L 37.3125 SS1 O. 0239 T l N S 49. 5000 CGR !,0771 WiNG 5 . 5 117 W 5 N G 5oa8.oooo GR 58. 7418 SGR 26'7. O0 O0 DY 0 157.8750 TEN S 6. 7871 NCNL 711£.0000 MR'ES 9,3203 R'HO f3 3. 5547 tt ~8.2500 SSi -0,0015 TENS 28.6563 CSR 1.7705 WING 6172,0000 GR 3!3.5000 OVO 2,5357 NCNL 7350,0000 :!qRES 9,6953 RHS~ 4,0B20 LL 44.1250 SSi 0.0044 T~NS 1.2559 3574.000J -999.2500 -999,25g0 -999.2500 -999.2500 -999.2m00 -999.2500 33.5525 238,7500 3.7109 -99~.2500 49.50'30 5088.0000 0,0635 2,$719 i06.562~ 216.37~0 4904.0000 44.3750 128.~250 3,6758 I13.687~ 28.6563 16.3281 5172,0000 3340,0000 0.0640 2,5'977 119,87~0 220,5000 7112.0000 21,0625 81,0625 0,,~911 33,,4688 .2 O. 0.469 1,4.21 O 9 6160.3000 3084,0000 0,06,49 2.6074 I i 7.3750 2i8,6250 7360 VP 010.,'t07 VEr-,'i'"'i'&TiSN Li':TiNG p,'~G~ ..~, P -37.7500 SVO ~I0 1~+5. 5003 MR'iS iRAT 1.E~&i RNR~ :CNL 393B.0000 GR )RHG 0.0~25 OP~i .U 212.0000 LS ;32 293.0000 QSS iRES O. 055~ MT.EM >CT& O. 1953 THOR ~2NG 31.218'7 W3NG IRES 3.0698 M'TEM ]~LZ 9.7500 T~NS }EFT :9700.0000 LLS ;P -44.7188 SVO }iO 53. 5313 MRES ~RAT 1,.0732 RNR:~ :"NL,,., 5028. Og'O0 4TEM 16.2.7500 JR )RHG 0.0334 .U 207.5000 L$ $S2 277. 7500 qRES O. 0654 MTEM )OTA O. 4395 THOR ~2NG 36.8437 W3NG qRES O. 0703 MTEM 'AL~ 9,6~8~ TENS CEPT 9600.0000 LLS $P -36. 7188 SVO DIO 304.2500 MRES NRAT 1 · 3701 RNRA FCNL 2914.0000 GR NITEM 161.3750 GR DRHO 0.059,5 OF'HI LU 221 .7500 LS 532 299. 5000 QSS HR ES O. 0559 MTEM POT& 1.1230 THCR W2NG 74.5625 W3NG MR E S O. 0708 MTEM CALl 9.2813 TENS DEP'T 9500.0000 LLS ,SP '-36.9052 SVO DIO i$.7S13 MRES lo6.0000 SGR 2.2559 UR~N ~.~141 44 155.5000 TENS 7~60.'"00,0~.,., 152.2.392 LLD 21.7031 SiO O. ,3598 M T EM I . :30 37 NPHi 21.7555 TENS 21. 76~6 C,~Li 1.8,555 '? iE F 219.2500 LiTm 0.0332 ~LS 164.7500 SG~ 1.7852 URAN 8. 257S W4NG 155. 5000 !~NS 7260. 0000 590. 072'9 LL D 32.71~5 O. 0703 MTEM 1. 1415 NgHI 22.i719 TENS 22. 171'9 CALI 2.5579 209.$250 L I'Y~ O. 0190 CLS 162.7500 SGR 1.7861 URAN 9. 2109 W4NG 154.3780 T~NS 581 2. 53 .. 12.054,7 StO 0 . 070 8 1 . 4 902 N P H I 54.5938 TENS 5'4, . 5938 CALl 1.8056 225.2500 Lilh O. 0351 QLS 1,51 · 3750 SGR 2 · 28.5313 W4NG 153.3750 T ~NS 5980. ~77 o518 LLG ¢2.5000 SIO 0.0718 MTSM 1.9;5'93 3.,5~5,3 .,.? I,,G 5l~C.OOOO jR 155.5144 SG'q 2'35.6250 CVO 155.5000 TENS 2.5~55 NCNL 7260.0000 ?iR=S 9.75 ~'0 R HO'5 4.49,51 L L 4 5.5 938 S S i O. O 32,2 TEN S 2 3 · 609~ CGR t. ? ~ 2 ~ W 1 N G i. 8339 W $ N 5 566.&150 SGR :~8.3750 JVC 15,4.3750 TENS 0.9277 NCNL 68!2,0000 MRGS 5.2031 LL 40.2500 SSI 23.5~69 CGR 1.1514 WiNG 1.8428 WS'N!3 6544.0000 GR 40.0350 :SGR 3,24.2500 DVJ 153..3750 TENS 4.4434 NCNL 69~0.0300 MRi~S 9.2813 RHG'~ 3.9341 LL 49.1,562 SS1 -O.O, Oa4 TENS 45.7813 CGR ,2.5273 ~iNG 5.52~4 NSNG =58.0000 GR 3202.3'! 15 S JR 4,5.2 i 8,7 OVO 132.00 O0 TENS 15.387 8 56.~!25 '3.0500 23.5094 25.4375 5i36.:3000 0.0554 2.67,58 113.2500 2,28.5750 7250.0003 10.4141 ~6.3125 2.7539 21.7656 23.:469 40.0938 5744.00,00 0.0664 2.664.1 105.9375 2!3.0000 6812.0000 14.0156 '81.0825 3.,5655 '?? 17~'9 45.7813 1.3.6953 5563.0000 4344.0000 0.06,59 2.5777 11~.4375 234.7500 6980.0000 27.9219 143.6250 '~. 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LOC, iNT'fRV.AL= 10135 F 'OP LOG iNTERVAL= 9194' F FYP~ FLUi2 = CONTROLLED )ENSITY = 9.4 LG/G F!SCCSiTY = 38.0 S ;H = i1. ,$ :LUID LOSS = 11.2 C3 RIME CIRC STOPPED: 04:30 6/12 FIME LOGGER ON ,BTM.= 12:00 8/12 qAX REC. TEMP. = 161.0 0,: .OGGING UNIT NO: 8304 163Z'F~L, SEC i, Ti1N, {14f :LFV_ _ OF P:RM. . OATuM'. 0 F LOG '.~EASUREC. FROM: RK8 DRLG MEASU~EC' :~:J~,'l: RK5 CASiNS-2,qZLL~R C~SiNG-LJGG~R CASING W~IGHT 'SiT :Si~ '~E D~PTM SALiNiTY SOURCE OF SAMPLE R M R M C SOURC~ RMF/RMC RM A'T :~,HT RMF AT 5MT RMC AT 5HT ~EVATICNS: DF: 51.0 GL': S.0 F 9198 = 9.625 47.0 LS/F = 5.5 = 10150 F : CIRCULATED = .2.05 S 57.0 DF : .!~3 2 ,55.0 DF = .3,14 21 72.0 OF = M:EAS/MEAS = .090 ~ 161. OF = .083 ~ 161. OF = .14~ ~ i61. DF VP OiO.M02 VEkZFZCATZGN LiST£NG ~.&GE 26 :iE,~ ENGiN:= _ ~ ~: T~NKHAki ;ZTTN-SS:3 5Y: i.~TR~'X : LZMESTCNE !DEN : 2.71 G/C3 )HC : NCNE ,, : CALl :LUTO O'-NSZTY : 1.0 C-..'.i/C3 ~EM,.IFqKS: 1.5" ST.~NOCFFS USE£, 3N DLL. 29,500 PPM. CL. DLL E~P.~AT USE3 AS >ASS Ob~ TO >~2X PULL OFF 5OTTCM. TiQR.SE'T LOCATi~ON: 700'FSL & 5OO'FWL S!-IZN-15E. ~&DiDACTiVE MA~K~R AT ~5~' NGT qPZKING (~O$A' ~ dg6~')CfiUSCD '5~ 'ASZNG. LLD C$.L R=LAY NGT ~.Ja'RKZNG FCR AFTER CALS, D2WNHCLE ~LT ~FTER CALS ]~TAZNED IN CASZNG. LC'T/CNL/ECT DZO NOT GO T~ 53TTgM -5~CUSE OF M~X PULL )LL/NGT RUN. LOT/CNL/'SmT GR SPZKE AT 90~0' DUE TO gENSZTY 'qgURC~ &CT]V&TZNG :JRMATigN .~Ng GR SPiK~ AT 8934' ZS COL~:~LT MARKER. :QUiPM~NT NUM6ERS: DLE " 759 TCC .a, 107 DLS F i'59 D i C g 77 '~ LCM 779 NGD S 7~2 "rM,~ .AB ~PI3 ~,LL INTERPRETATIONS ARE OPINIONS 5ASED ON ZNFFR~.NCES =R~2M ELECTRICAL OR ]THrR ..... MFASUREMFNTS AND W~ CANN,OT~ AND D''~ NOT GUAR~N'TEE TFE ACCU®:,.ACY L~,~' LiSTiNG o~GE .~7 ~ORR--CTNESS LOc- ANY iNT-'..RPR~,TAT!SNS, ANS' ~4E S',-tALL NOT, EXCEPT .... 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