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176-029
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU NGI-06 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 176-029 50-029-20206-00-00 9585 Conductor Surface Intermediate Production Liner 8617 80 2639 8437 1457 9500 20" 13-3/8" 9-5/8" 7" 8548 29 - 109 29 - 2668 27 - 8464 8123 - 9580 29 - 109 29 - 2668 27 - 7730 7469 - 8613 none 520 2670 4760 7020 none 1530 4930 6870 8160 8894 - 9479 7-5/8" x 7" 25 - 8126 25 - 7472 8063 - 8531 Structural 7" Baker S-3 8089 7444 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 PRUDHOE BAY / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028302 25 - 7419 0 0 180423 204917 0 0 40 40 3439 3306 324-070 13b. Pools active after work:PRUDHOE OIL 7" A-1 Injection SSSV STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations 8089 7444/ 2185 / 2185 By Grace Christianson at 9:26 am, May 21, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.05.21 05:28:51 - 08'00' Bo York (1248) RBDMS JSB 052824 DSR-5/21/24WCB 7-16-2024 ACTIVITYDATE SUMMARY 4/27/2024 T/I/O=2750/36/63 Water Wash TBG with 10 bbls 60/40, 100 bbls 180* diesel, 350 bbls fresh water/surfactant & 2 bbls 60/40. Allow soak for 2 hours. Pump 235 bbls fresh water/surfactant & 15 bbls 60/40 to flush. Turn well over to DSO to POI FWHPs=120/12/10 Daily Report of Well Operations PBU NGI-06 Water Wash TBG with 10 bbls 60/40, 100 bbls 180* diesel, 350 bbls fresh water/surfactant & 2 bbls 60/40. Allow soak for 2 hours. Pump 235 bbls fresh water/surfactant & 15 bbls 60/40 to flush. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU NGI-06 Water Wash Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 176-029 50-029-20206-00-00 ADL 0028302 9585 Conductor Surface Intermediate Production Liner 8617 80 2639 8437 1457 9500 20" 13-3/8" 9-5/8" 7" 8548 29 - 109 29 - 2668 27 - 8464 8123 - 9580 29 - 109 29 - 2668 27 - 7730 7469 - 8613 none 520 2670 4760 7020 none 1530 4930 6870 8160 8894 - 9479 7-5/8" x 7" 25 - 74728063 - 8531 Structural 7" Baker S-3 7" A-1 Injection SSSV 8089 , 2185 2185 , 7444 Date: Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 3-1-2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov L-80 By Samantha Coldiron at 1:58 pm, Feb 08, 2024 324-070 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.02.07 14:06:30 - 09'00' Eric Dickerman (4002) 10-404 DSR-2/13/24SFD 2/9/2024MGR13FEB24*&:JLC 2/15/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.15 15:02:31 -06'00'02/15/24 RBDMS JSB 021524 Well Work Prognosis Well Name:NGI-06 API Number:50-029-20206-00 Current Status:Gas Injector Leg: Estimated Start Date:March 1, 2024 Rig:N/A Reg. Approval Req’d?10-403 Date Reg. Approval Received: Regulatory Contact:Carrie Janowski Permit to Drill Number:176029 First Call Engineer:Dave Bjork Office: 907-564-4672 Cell: 907-440-0331 Second Call Engineer: Gas Injection Rate: ~220,000 Mscf/Day Injection Pressure: 3,400 psi Reservoir Pressure (Estimate): 3300 psi Program Objective(s): NGI-06 is a gas cap injection well that has demonstrated a decrease in injectivity. The well has not been water washed since 2018. Water washes are designed to dissolve salts and asphaltenes in the tubing and formation. The objective is to perform a tubing water wash to increase injectivity and perform a general maintenance on Gas Injection Wells. Proposed Program: Pump diesel followed by Fresh Water and Surfactant as per attached pumping template. Well Work Prognosis Well Work Prognosis H2S Value N/A H2S Date N/A Work Desc AFE Date Engineer Phone Job Objective Pump Schedule Stage Fluid Type Pump Into Vol (bbls) Rate (bpm)Max Pres (psi) 1 Spear Methanol / Water TBG 10 1-3 2500 2 Solvent Diesel TBG 100 1-3 2500 3 Over-Flush Fresh Water TBG 600 see below 1800 4 Spear Methanol / Water TBG 15 1-3 1800 5 6 7 Detailed Procedure David Bjork (907) 564-4672 Well NGI-06 GI Water Wash 01/27/24 Increase well injectivity by performing a water wash. -Use 2 full uprights of fresh water mixed with 0.02% F-103 surfactant. Use 100 bbls of diesel from COTU. -Heat diesel to ~120*F -Order FreshWater to be at ~160*F -Freeze Protect contingent on WSL and ambient temp/seasonal pumping 1.) 10 bbl 60/40 MeOH/water spear 2.) 50 bbls COTU diesel (heated to ~120 deg F)at ~1 to 3 bpm. 3.) Pump 600 bbls of fresh water with 0.02% F-103 surfactant per following: a.) Pump 350 bbls of fresh water with 0.02% F-103 surfactant at ~5 bpm. Max pressure during this pumping can reach 1800 psi. Once 350 bbls has been pumped, shut-down pumps and let diesel soak across perfs for 2 hours -this should allow ~ 50 bbls of diesel to be pumped into perfs and a remaining 50 bbls to soak outside the perfs. b.) After the 2 hour soak time, resume pumping at max rate/pressure (whichever is hit first) for next 250 bbls of fresh water with 0.02% F-103 surfactant. 4.) 15 bbls of 60/40 MeOH/water freeze protect. 5.) RDMO. Return well to gas injection. if well isnt going to be POI then FP See ~ pumping time schedule and notesbelow COTU diesel has xylene impurities left, treat with proper safety precautions Clear Well Work Prognosis Pump Time Fluid type vol (bbls)rate (bpm)Time (min) time (hours) methanol 10 1 10 0.17 diesel 100 1.5 67 1.11 FW flush 375 5 75 1.25 Soak 2.00 FW flush 225 5 45 0.75 methanol cap 15 1.5 10 0.17 5.44 Soak Time of Diesel/Xylene 1 2 Diesel/Xylene Notes Note 1 Note 2 Note 3 Hot fluids recommended: Note 1 Fresh Water and Surfactant Notes Note 1 Tubing has gas in it prior to pumping, any fluids pumped first will free fall. Soak time - keep at a minimum of ~2 hours; xylene works best with longer soak times (at least on asphaltenes) SBG treatments have a 3 hour soak time as well (just an FYI) Soak time is really a time for diesel/xylene to seep through the perfs vs pushing/rushing through Max pump rates creates turbulence and has contact with the tubing walls. Also cuts down on time Use COTU "diesel" only in these treatments if available. See Craig Graff explanation below. COTU technically can’t make diesel. On good days it can make Jet A or Heating Oil. Neither meet the specs for diesel. The reason they are different is that they have a lot more aromatics and sulfur in them than diesel. Road diesel and ULSD have most of those bad components taken out, which means that they can only dissolve straight chain hydrocarbons (paraffins), and not aromatics. These will make asphaltenes precipitate instead of cleaning them up.COTU “diesel” has enough things like xylene and toluene left in it to make it a pretty good solvent even for asphaltenes. A real refinery would take all of those out to be sold for higher margins in other products. If COTU "diesel"is not available, use other available diesel and xylene at a 50/50 mixture. As you read diesel in instructions below, can substitue with diesel/xylene If xylene is used for a 50/50 diesel/xylene mixture, heated xylene to 80 deg F or higher, use pump rates of 1 to 1.5 bpm. Injectivity results have improved when all fluids pumped are at warmer temps MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC NGI-06 PRUDHOE BAY UNIT NGI-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 NGI-06 50-029-20206-00-00 176-029-0 G SPT 7440 1760290 1860 3319 3316 3315 3313 107 116 135 148 4YRTST P Adam Earl 8/2/2022 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT NGI-06 Inspection Date: Tubing OA Packer Depth 79 2408 2342 2312IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220803174208 BBL Pumped:4.3 BBL Returned:3.6 Monday, August 29, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.29 15:24:25 -08'00' Regg, James B (DOA) I —2(.° (:)(;°/ From: AK, D&C Well Integrity Coordinator <AKDCWellInte rit Coordinator b .com> Sent: Wednesday, July 29, 2015 6:26 PM To: Regg, James B (DOA) .o f 1 OF)/i5 Cc: AK, D&C Well Integrity Coordinator Subject: RE: Permission to flow NGI-06 (PTD #1760290) for emergency gas field supply Jim, After further review on Injector NGI-06 (PTD#1760290) BP will not be using this well as a source for field fuel gas. Sorry for the confusion. Thank you, Kevin Parks SCANNEt) BP Alaska -Well Integrity Coordinator r Y C Iota' Wells V£' OrJan iaa1Iotr Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com From: Regg, James B (DOA) [mailto:jim.req @alaska.gov] Sent: Tuesday, July 21, 2015 3:28 PM To: AK, D&C Well Integrity Coordinator Subject: RE: Permission to flow NGI-06 (PTD #1760290) for emergency gas field supply TIO plot and passing MIT appear to show acceptable mechanical integrity for PBU NGI-06. I found very little information in AOGCC's files about NGI-01 and NGI-03 use as sources .r emergency gas supply; no approval. Discussing with others I understand swapping an injector to production 3! days or less does not require specific AOGCC approval; temporary conversions from injection to production t : exceed 30days require submittal of a Sundry Report (10-404) after production ceases. Refer to the attached Sundr atrix(page 4). You mention the SSSV will be defeated during gas production. Please -escribe how the surface safety system (pilot, SSV) will be addressed while this gas injector is swapped to production. so describe the signage/tag identifying the well being swapped to production. [This would also be a good oppor nity to address how the SVS and tagging of the other "approved" source wells for emergency gas supply are addre ed.] Operating without an operational SSSV is a concern. Al CC's Well Safety Valve System (SVS) regulations (20 AAC 25.265) allow the SSSV to be removed for up to 14dts when required by a tubing workover, well intervention, or by routine well pad operations; refer to 20 AAC 25.25'(j). This flowback does not appear to fall into any of the listed reasons for removal of the SSSV. There is opportunity for a variance as described in 20AAC 25.265(o)—BPXA must prove the alternative provides at least an equally effective means of complying with the SSSV requirement. Describe the flow path being used for,temporary production of the gas from NGI-01 or proposed from NGI-06. Jim Regg 1 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, July 21, 2015 3:28 PM 1-2,16. i(21IVS To: 'AK, D&C Well Integrity Coordinator' Subject: RE: Permission to flow NGI-06 (PTD #1760290) for emergency gas field supply Attachments: SundryMatrix - NS.pdf TIO plot and passing MIT appear to show acceptable mechanical integrity for PBU NGI-06. I found very little information in AOGCC's files about NGI-01 and NGI-03 use as sources for emergency gas supply; no approval. Discussing with others I understand swapping an injector to production 30 days or less does not require specific AOGCC approval; temporary conversions from injection to production that exceed 30days require submittal of a Sundry Report (10-404) after production ceases. Refer to the attached Sundry Matrix(page 4). You mention the SSSV will be defeated during gas production. Please describe how the surface safety system (pilot, SSV) will be addressed while this gas injector is swapped to production. Also describe the signage/tag identifying the well being swapped to production. [This would also be a good opportunity to address how the SVS and tagging of the other "approved" source wells for emergency gas supply are addressed.] Operating without an operational SSSV is a concern. AOGCC's Well Safety Valve System (SVS) regulations (20 AAC 25.265) allow the SSSV to be removed for up to 14days when required by a tubing workover, well intervention, or by routine well pad operations; refer to 20 AAC 25.265(j). This flowback does not appear to fall into any of the listed reasons for removal of the SSSV. There is opportunity for a variance as described in 20AAC 25.265(o)—BPXA must prove the alternative provides at least an equally effective means of complying with the SSSV requirement. Describe the flow path being used for temporary production of the gas from NGI-01 or proposed from NGI-06. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(A0GCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: AK, D&C Well Integrity Coordinator [mailto:AKDCWelllntegrityCoordinator@bp.com] Sent: Friday, July 17, 2015 9:34 AM To: Regg, James B (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: Permission to flow NGI-06 (PTD #1760290) for emergency gas field supply Jim, 1 • In the past, BP has used gas injectors NGI-01 (PTD#1750480) and NGI-03 (PTD#1750610) as approved sources for emergency gas supply. On November 14, 2014, injector NGI-03 had a straddle patch set in order to mitigate inner annulus repressurization suspected to be through the SSSV profile.This wellwork intervention decreased the attractiveness of using the well for field gas during a shutdown. At this time, BP would like to designate injector NGI-06 (PTD#1760290) as a gas source well in lieu of NGI-03. NGI-06 will be operated without a sub-surface safety valve with a locked open check upstream of the well to allow for in field gas production. This would be the same configuration as NGI-03. In addition to NGI-01, NGI-06 will be a secondary means of back flowing gas to the Central Gas Facility in order to provide field fuel gas and may be needed as early as August 20th, 2015. The last witnessed MIT-IA for NGI-06 was performed August 07, 2014 which passed with no issues. Enclosed for reference are copies of the MIT-IA performed August 07, 2014, the wellbore schematic, and associated TIO and injection plots for the past year. Please call with any questions or concerns. Thank you, Whitney Pettus f'arl\>) BP Alaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com 2 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Friday, July 17, 2015 9:34 AM 1/14(cTo: Regg, James B (DOA) � ,T? Cc: AK, D&C Well Integrity Coordinator Subject: Permission to flow NGI-06 (PTD #1760290) for emergency gas field supply Attachments: NGI-06 Wellbore Schematic.pdf; NGI-06 TIO and Injection Plots - 1 yr- 7-13-15.docx; MIT PBU NGI-06 08-07-14.xls Jim, In the past, BP has used gas injectors NGI-01 (PTD#1750480) and NGI-03 (PTD#1750610) as approved sources for emergency gas supply. On November 14, 2014, injector NGI-03 had a straddle patch set in order to mitigate inner annulus repressurization suspected to be through the SSSV profile. This wellwork intervention decreased the attractiveness of using the well for field gas during a shutdown. At this time, BP would like to designate injector NGI-06 (PTD#1760290) as a gas source well in lieu of NGI-03. NGI-06 will be operated without a sub-surface safety valve with a locked open check upstream of the well to allow for in field gas production. This would be the same configuration as NGI-03. In addition to NGI-01, NGI-06 will be a secondary means of back flowing gas to the Central Gas Facility in order to provide field fuel gas and may be needed as early as August 20`h, 2015. The last witnessed MIT-IA for NGI-06 was performed August 07, 2014 which passed with no issues. Enclosed for reference are copies of the MIT-IA performed August 07, 2014,the wellbore schematic, and associated TIO and injection plots for the past year. Please call with any questions or concerns. Thank you, Whitney Pettus BP Alaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 TREE= 7-1/16"CIW , WELLHEAD= GRAY GEN 1/MCEVOYGI-06 S. i Y NOTES: WELL REQUIRES A SSSV. ACTUATOR BAKER KB. ELEV = 47' BF.ELEV = ♦ / ♦ 24' —17"X 7-5/8"XO, ID=6.875" KOP= 4700' 7"TBG,26#, L-80, H 24' • ♦ Max Angle= 42 7600' ♦ .._m__ @ ....____ TC-II, .0383 bpf, • Datum MD= 9842' ID=6.276" •• IP 2036' -f NALCO ES CEMENTER Datum ND= 8800'SS ♦ ♦ ♦ ♦ • 9-5/8"CSG,47#,L-80,TC-II, ID=8.681" 2047' 2174' —1 7-5/8"X 7" XO,ID=6.276" 7-5/8"TBG,29.74,L-80,VAM TOP HC, 2174' .0459 bpf, ID=6.875" 2185' —7"CAMCO DB-6 NIP,ID=6.00" 7"TBG,26#,L-80,TC-II,.0383 bpf, ID=6.276" — 2197' 2197' —17"X 7-5/8"XO, ID=6.276 13-3/8"CSG,72#,MN-80.ID=12.347" —{ 2663' 7-5/8"TBG,29.7#,L-80 VAM TOP HC, —J 8052' \ 8052' —7-5/8"X 7"XO, ID=6.276 PC, .0459 bpf, ID=6.875" 8063' —)7"HES"R"NIP, ID=5.963" Minimum ID = 5.770" @ 8108' 7" HES "RN" NIPPLE 'Z ,, 8084' —9-5/8"X 7"BKR S-3 PKR, ID=6.00" 1 8108' J—7"HES"RN"NIP, ID=5.770" 7"TBG.26#.L-80,TC-II, .0383 bpf, ID=6.276" — 8121' TOP OF 7"LNR — 8123' / 8121' —17"WLEG. ID=6.276" J 9-5/8"CSG,47#,MC-9=80. ID=8.681" —I 8464' I PERFORATION SUMMARY I REF LOG:BHCS ON 04/28/79 ANGLE AT TOP PERF:37 @ 8894' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8894-8950 0 06/30/90I 3-3/8" 4 8999-9002 0 05/02/87 3-3/8" 4 9009-9028 0 05/02/87 3-3/8" 4 9036-9237 0 05/02/87 3-3/8" 4 9242-9282 0 05/02/87I 3-3/8" 4 9289-9299 0 08/06/78 3-3/8" 4 9322-9376 0 05/02/87 3-3/8" 4 9387-9415 0 05/02/87 3-3/8" 4 9419-9434 0 08/06/78I 3-3/8" 4 9460-9469 0 08/06/78 3-3/8" 4 9473-9479 0 08/06/78 PBTD —I 9412' 1♦ 111♦ 7"LNR, 294, N-80, .0371 bpf, ID=6.184" —I 9580' ►1�+i;an �; DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/05/76 ORIGINAL COMPLETION WELL: NGI-06 02/07/88 LAST WORKOVERPERMIT No: 1760290 11/14/06 N4ES RWO API No: 50-029-20206-00 12/07/06 DCR/PJC DRLG DRAFT CORRECTIONS SEC 12,T11N, R14E 1217.37 FEL 3791.89 FNL 10/14/07 DDK/PJC ACTUATOR CORRECTION 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) Injector NGI-06(PTD#1760290) TIO Plot(1 yr) July 13, 2015 Well NGI-06 • D9 11111 �-Tb; f IA DOC, -a-OA OOA -0-000A �On I 1 000 Injection Plot(1 yr) Well MGI-06 3.800 - 3.600 f' -T60000 3400 ,.,•�\ 1 .240000 3200 I 220000 3 009 2830200009 2.600 -780.000 240 160000 3 —WHOP 2200 3 __S17 2000 -140.000 -PO ,.800 ; -Ml 7.600 -120.000 -GI 08m 14'00 -100000 On ,200 -80.000 1000• 0%y -60000 690- 40000 4080- -- 20.000 011 174 061314 09+1314 101414 11;1414 121.514 011015 021515 031015 01.18155 091910 061315 a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to jim regq((dalaska qov AOGCC Inspectors(rDalaska gov phoebe brooks(aDalaska qov Chris wallace@alaska cloy OPERATOR: BP Exploration(Alaska),Inc. FIELD/UNIT/PAD: PBU/GPB/NGI DATE: 08/07/14 OPERATOR REP: Jack Disbrow AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min 45 Min 60 Min. Well NGI-06 Type Inj G TVD 7,440' Tubing 3,378 3,377 3,376 3,371 Interval 4 P T D 1760290 Type test P Test psi 1860 Casing 56 2,506 2,493 2,482 P/F P Notes: Standard 4 yr test OA is cemented to surface OA 29 20 26 29 9 56 Pumped 2 7 bbls of methanol and bled back 2 9 bbls of fluid Well Type Inj TVD Tubing Interval P T D Type test Test psi Casing P/F Notes: OA Well Type In). TVD Tubing Interval P T D Type test Test psi Casing P/F Notes: OA Well Type In) TVD Tubing Interval - P T D Type test Test psi Casing P/F Notes: OA Well Type In) 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 Monitonng I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=lndustnal Wastewater R=Internal Radioactive Tracer Survey V=Required by Vanance N=Not Injecting A=Temperature Anomaly Survey 0=Other(descnbe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT PBU NGI-06 08-07-14 xls Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, July 29, 2015 6:26 PM To: Regg, James B (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: RE: Permission to flow NGI-06 (PTD #1760290) for emergency gas field supply Jim, After further review on Injector NGI-06 (PTD#1760290) BP will not be using this well as a source for field fuel gas. Sorry for the confusion. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator G� Global Wells `SCONE® AUG 1 02015 Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: Regg, James B (DOA) [mailto:jim.regg@lalaska.gov] Sent: Tuesday, July 21, 2015 3:28 PM To: AK, D&C Well Integrity Coordinator Subject: RE: Permission to flow NGI-06 (PTD #1760290) for emergency gas field supply TIO plot and passing MIT appear to show acceptable mechanical integrity for PBU NGI-06. I found very little information in AOGCC's files about NGI-01 and NGI-03 use as sources for emergency gas supply; no approval. Discussing with others I understand swapping an injector to production 30 days or less does not require specific AOGCC approval; temporary conversions from injection to production that exceed 30days require submittal of a Sundry Report (10-404) after production ceases. Refer to the attached Sundry Matrix(page 4). You mention the SSSV will be defeated during gas production. Please describe how the surface safety system (pilot, SSV) will be addressed while this gas injector is swapped to production. Also describe the signage/tag identifying the well being swapped to production. [This would also be a good opportunity to address how the SVS and tagging of the other "approved" source wells for emergency gas supply are addressed.] Operating without an operational SSSV is a concern. AOGCC's Well Safety Valve System (SVS) regulations (20 AAC 25.265) allow the SSSV to be removed for up to 14days when required by a tubing workover, well intervention, or by routine well pad operations; refer to 20 AAC 25.265(j). This flowback does not appear to fall into any of the listed reasons for removal of the SSSV. There is opportunity for a variance as described in 20AAC 25.265(o)—BPXA must prove the alternative provides at least an equally effective means of complying with the SSSV requirement. Describe the flow path being used for temporary production of the gas from NGI-01 or proposed from NGI-06. Jim Regg 1 Supervisor, Inspections • AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: AK, D&C Well Integrity Coordinator [mailto:AKDCWelllntegrityCoordinator©bp.com] Sent: Friday, July 17, 2015 9:34 AM To: Regg, James B (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: Permission to flow NGI-06 (PTD #1760290) for emergency gas field supply Jim, In the past, BP has used gas injectors NGI-01 (PTD#1750480) and NGI-03 (PTD#1750610) as approved sources for emergency gas supply. On November 14, 2014, injector NGI-03 had a straddle patch set in order to mitigate inner annulus repressurization suspected to be through the SSSV profile. This wellwork intervention decreased the attractiveness of using the well for field gas during a shutdown. At this time, BP would like to designate injector NGI-06 (PTD#1760290)as a gas source well in lieu of NGI-03. NGI-06 will be operated without a sub-surface safety valve with a locked open check upstream of the well to allow for in field gas production. This would be the same configuration as NGI-03. In addition to NGI-01, NGI-06 will be a secondary means of back flowing gas to the Central Gas Facility in order to provide field fuel gas and may be needed as early as August 20th, 2015. The last witnessed MIT-IA for NGI-06 was performed August 07, 2014 which passed with no issues. Enclosed for reference are copies of the MIT-IA performed August 07, 2014,the wellbore schematic, and associated TIO and injection plots for the past year. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com 2 Injector NGI-06(PTD#1760290) TIO Plot(1 yr) July 13,2015 WW1 NGI-06 ?00 Tb; -f- ✓70 -••-OA 00A 000A On 1000 'Li L L • R j al= its amok _ --••1•••--.4•••••/641111111111141,... 6. _ - M,15'15 02'1515 °.15 0611015 .. . • Injection Plot(1 yr) WWI:NG106 260 000 440#0000104‘.. :a.a0 2X1.00 • X0.000 • • 18000 16000 0 -WHIP S% 140.600 -FW -M 120.00 -aNr 10.00 Q 8000 60000 BOO 1000 2000 1114 001118 10'4'14 11.1514 1211514 01115415 0211515 011815 0411815 05'1915 06 19 15~_ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Toy Jim Re DATE: Thursday, December 02, 2010 P.I. Supeervisor ) A 1 �' ��'�� SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI -06 FROM: Bob Noble PRUDHOE BAY UNIT NGI -06 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 1�— NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT NGI -06 API Well Number: 50- 029 - 20206 -00 -00 Inspector Name: Bob Noble Insp Num: mitRCN101121162847 Permit Number: 176 -029 -0 Inspection Date: 11/21/2010 Rel Insp Num: Packer Depth Pretest I nitial 15 M in. 30 Min. 45 Min. 60 Min. Well NGI -06 Type Inj. G TVD 7440 ' IA 2440 i 2505 ✓ 2495 2480 2470 2482 P.T. 1760290 Ty SPT Test psi zsos OA Is 20 zz 24 25 27 I P/F P �-Tu bin 3300 3300 3300 3300 3300 3310 Notes: This was the sec test we did on this well today. It still didn't stabalize very well. 1 Thursday, December 02, 2010 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Re gg IZ � I 1 / V DATE: Wednesday, November 24, 2010 P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI -06 FROM: Bob Noble PRUDHOE BAY UNIT NGI -06 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT NGI -06 API Well Number 50- 029 - 20206 -00 -00 Inspector Name: Bob Noble Insp Num: mitRCN101121162112 Permit Number: 176 -029 -0 Inspection Date: 11/21/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI-06 , Type Inj. G �TVD 7440 IA 180 2510 2480 2440 P.T_D 1760290 / TypeTest SPT Test psi 2510 OA 15 14 15 18 Interval4Y P/ F Tubing 00 3300 3300 3300 Notes: Faile to stabli Torin wanted to do the test again. re a 4ee�- 1g�C1P5i Wednesday, November 24, 2010 Page 1 of 1 MEMORANDUM . TO: Jim Regg .I\e¡f¿,' ./,:;,11)0; P.I. SupervIsor {t /Z II FROM: Chuck Scheve Petroleum Inspector Well Name: PRUDHOE BAY UNIT NGI-06 Insp Num: mitCS061208154247 ReI Insp N urn Packer Well i NGI-06 ¡Type Inj. I G ! TVD ". P.T. 1760290 1TypeTe~t¡ SPT i Test psi State of Alaska . \1(,-"Ddß1 Reviewed By: P.I. Suprv :1512- Comm Inspector Name: Chuck Scheve Inspection Date: 12/8/2006 Depth 7439 2480 15 Min. 30 Min. 45 Min. 60 Min. 2460 2420 2420 ~-+-......~- o i 0 n_··___ 3325 1859.75 ! OA ! Tubing i 3325 Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 13, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-06 PRUDHOE BAY UNIT NGI-06 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-20206-00-00 Permit Number: 176-029-0 ---- o o Pretest Initial !~!"'o --~----' ! 2500 i ...L 0 I I Notes 3325 ¡" 3325 I 3325 . 3325 _~___ I _. ---L__~~~_~ Initial test following Rig Work-over Pretest pressures observed and found stable. Test extended to ensure IA pressure stabilization. ./ .._.--.-~ Interval INITAL P/F P Wednesday, December 13, 2006 o 'J' . It! ~J Page I 0 f I i . STATE OF ALASKA RECEIVED ALAsrà OIL AND GAS CONSERVATION COMalON DEC 0 4 2006 REPORT OF SUNDRY WELL OPERATIOf1~ k as a Oil & Gas Cons Com . . mISSIOn 1. Operations Performed: AnChorage o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. o Development o Exploratory 176-029 3. Address: o Stratigraphic 181 Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20206-00-00 7. KB Elevation (ft): 47' 9. Well Name and Number: PBU NGI-06 8. Property Designation: 10. Field / Pool(s): ADL 028302 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9585 feet true vertical 8617 feet Plugs (measured) None Effective depth: measured 9412 feet Junk (measured) None true vertical 8477 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1530 520 Surface 2668' 13-3/8" 2668' 2668' 5380 2670 Intermediate 8464' 9-5/8" 8464' 7730' 6870 4760 Production Liner 1457' 7" 8123' - 9580' 7469' - 8613' 8160 7020 ~':'>Ch~~~f;n 0 F' \Ji .' .....-. cl Perforation Depth MD (ft): 8894' - 9479' Perforation Depth TVD (ft): 8063' - 8531' 7",26# x 7-5/8", 29.7# L-80 8121' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 7" Baker 'S-3' packer 8084' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing. Cut and pull 9-5/8" casing from 2047'. Run 9-5/8" tieback. Cement w/151 Bbls Class 'G' (62 cu ft /53 sx). Run new tubing to surface. 13. ReDresentative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory o Development 181 Service 16. Well Status after proposed work: 181 Well Schematic Diagram o Oil o Gas o WAG 181 GINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or NIA if C.O. Exempt: Contact David Reem. 564-5743 306-310 Printed Name Terrie Hubble Title Technical Assistant ~III~I riMf-e ~1f~/~ Prepared By Name/Number: Signature Phone 564-4628 Date Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 ORJGfNAL RBDMS BFt Submit Original Only {j b 20Dfi . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-06 NGI-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 1 0/25/2006 11/14/2006 Spud Date: 4/9/1976 End: 11/14/2006 10/25/2006 14:00 - 16:00 2.00 MOB P PRE Scope down & lower derrick. 16:00 - 19:30 3.50 MOB N WAIT PRE Wait on trucks to move rig. 19:30 - 21 :30 2.00 MOB P PRE Hold pre-move safety meeting. Move rig off well. Clean location. P/U matting boards & Herculite. 21 :30 - 00:00 2.50 MOB P PRE Begin rig move from G-03a to NGI-06. Layout Herculite & matting boards. 10/26/2006 00:00 - 02:00 2.00 MOB P PRE Move from G-03a to NGI-06. 02:00 - 07:00 5.00 RIGU P PRE Spot in rig sub, Pipe Shed & Pits. Level up same. Spot camp. Berm up around rig. 07:00 - 09:00 2.00 RIGU P PRE Raise & Scope up derrick. Con't to R/U equip. Accepted rig @ 0600 hrs. 09:00 - 11 :00 2.00 RIGU P DECOMP Spot in Tiger tank. Layout lines & take on hot seawater.. Install 2nd valve on IA. 11 :00 - 13:00 2.00 WHSUR P DECOMP P/U lubricator. R/U to test. Attempted to pressure up, No good. Replace "0" ring in lubricator. Pressure up to 150 psi. Pull BPV. 13:00 - 13:30 0.50 WHSUR P DECOMP Install pump in XO. Test lines to 3500 psi. 13:30 - 16:00 2.50 KILL P DECOMP Circulate hot seawater down tubing & take retums to Tiger tank. Pumped 5 BPM @ 1000 psi, 6 BPM @ 1150 psi. SID & monitor well 20 min. Well dead both sides. Test tubing tail plug to 2000 psi. tested good. 16:00 - 18:00 2.00 WHSUR P DECOMP P/U lubricator. Set Dart Pressure up on top of dart to 4000 psi. pressre bled off. Pressure up from bottom side to 1000 psi & test for 10 min. Charted same. 18:00 - 21 :00 3.00 WHSUR N SFAL DECOMP Con't to attempting to test TWC from top. No good, Pull dart * inspect same. "0" Rings damaged. Replace "0" Rings. Reset Dart. Pressure up to 4000 psi & attempt to test. Pressure bled off several times. Slower each time, possibly forcing grease into valve voids. Repressured up to 4000 psi. On 4 th attempt pressure held & got 10 min test. Charted same. 21 :00 - 23:00 2.00 WHSUR N SFAL DECOMP Drain tree & noticed fluid entry from below plug. Check lA, no flow. Well possibly out of balance & trash in valve. Notifiy town engineer. Agree to pull plug & circulate well. Pulled dart & noticed flow up back side. SI & monitor while waiting on DSM. 23:00 - 23:30 0.50 N SFAL DECOMP P/U lubricator & pull BPV. Inspect same. Could not see any external problems or damage. Send DSM for re-dressed plug. 23:30 - 00:00 0.50 WHSUR N SFAL DECOMP Circulate bottoms up while waiting on DSM. 10/27/2006 00:00 - 00:30 0,50 WHSUR N SFAL DECOMP Con't to circulate bottoms up. Pumped 6 BPM @ 1100 psi. Pumped total of 200 bbls.. SID well static. Monitor well. OAP went from 600 to 850 psi during circulation. 00:30 - 02:30 2.00 WHSUR N SFAL DECOMP P/U lubricator & attempt to set BPV. Would not set. Pull BPV & check same. Send BPV to shop for 2nd re-dressed plug. Wait on DSM. 02:30 - 03:30 1.00 WHSUR N SFAL DECOMP Wait on DSM. Pressure up & test TIP & monitor OA. Test to 4000 psi. Lost 50# in 15 min. OAP went from 700 psi to 1000 psi. Held steady. Bled off pressure OAP dropped to 750 psi. 03:30 - 04:30 1.00 WHSUR P DECOMP P/U lubricator & install BPV. UD lubricator. Dry rod Dart in plug. Pressure up & test from top to 4000 psi for 10 min. Bleed off & pressure. Pressure up from bottom of plug to 1000 psi. Hold for 10 min. Both tests good. Charted same. 04:30 - 06:00 1.50 WHSUR P DECOMP Monitor Well. Slight flow still observed above BPV/Dart. 0 psi on Tbg/IA. Bleed off pressure from OA. Suspect flow coming Printed: 11/20/2006 10:35:49 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-06 NGI-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 1 0/25/2006 11/14/2006 Spud Date: 4/9/1976 End: 11/14/2006 04:30 - 06:00 DECOMP from pack-off failure. 06:00 - 07:00 DECOMP Rig-up Bleed Trailer. Bleed OA down 0 psi. Monitor. 07:00 - 09:00 DECOMP Nipple down Injection Tree and Adaptor Flange. 09:00 - 11 :30 DECOMP Nipple up Test Spool and BOP Stack. 11 :30 - 14:00 DECOMP Changeout VBPRs to 7" Pipe Rams. Make-up 7" Test Joint. 14:00 - 18:00 DECOMP Rig-up test equipment. Test BOPE per BP/AOGCC requirements at 250/4000 psi. Test Hydril at 250/3500 psi. State's right to witness test was waived by C. Sheve. 18:00 - 18:30 0.50 DECOMP Check PVT equip. Perform derrick inspection. 18:30 - 20:30 2.00 DECOMP Con't to test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 4000 psi. No failures. 20:30 - 21 :00 0.50 BOPSU P DECOMP RID test equip. Blow down lines. Drain BOP stack. 21 :00 - 21 :30 0.50 WHSUR P DECOMP Pull dart. P/U lubricator & pull BPV. UD BPV & lubricator. 21 :30 - 22:00 0.50 PULL P DECOMP P/U & M/U 7" double grapple spear on single jt of 31/2" DP. 22:00 - 22:30 0.50 PULL P DECOMP RIH & engage spear in thru hanger into 7" tubing. BOLDS. Attempt to pull hanger. No Luck. Hanger stuck.. no stretch in tubing. Work & attempt to pull to 265K. 22:30 - 00:00 1.50 PULL N DPRB DECOMP M/U steam lines to wellhead & RlU steam blanket. Heat wellhead. 10/28/2006 00:00 - 00:30 0.50 PULL N DPRB DECOMP Con't to heat up wellhead. 00:30 - 01 :00 0.50 PULL N DPRB DECOMP P/U & work pipe to free hanger. Work up to 270K. No movement. Rotate steam lines 90 degrees. 01 :00 - 03:00 2.00 PULL N DPRB DECOMP Con't to heat up wellhead w/ steam. 03:00 - 03:30 0.50 PULL P DECOMP P/U & work pipe hanger, came free @ 255K. Pull hanger to floor. P/U wt = 240K. UD spear. Cut control lines. 03:30 - 04:30 1.00 PULL P DECOMP RlU circulating head. Circulate bottoms up. 5 BPM @ 230 psi. Pumped 200 bbls. SID monitor well. Well Static. RID circulating equip. 04:30 - 05:00 0.50 PULL P DECOMP Break out & UD hanger. Connect control lines to spooling unit. 05:00 - 06:00 1.00 PULL P DECOMP POOH & UD 7" tubing. 06:00 - 06:30 0.50 PULL P DECOMP Service Rig. Inspect Derrick. Check PVT Alarms. 06:30 - 10:30 4.00 PULL P DECOMP Continue to single down 7" Tubing in Pipe Shed. Stop at SSSV. Recovered Control Lines and Bands complete. Rig down Spooling Unit. 10:30 - 18:00 7.50 PULL P DECOMP Continue to single down 7" Tubing in Pipe Shed. Average Jt lenght = 28.37' 18:00 - 18:30 0.50 PULL P DECOMP Crew change, PJSM. Check PVTs. Inspect derrick. 18:30 - 19:00 0.50 PULL P DECOMP Finish POOH & UD 7" casing. RTotal recovery: 282 jts 7" 26#, L-80 AB Mod tubing, SSV Assy, 7" Tbg Pup, 7" x 5 1/2" XO & 1.82' 5 1/2" cut off tbg pup. Cut was uniform & belled -OD = 6.25". 19:00 - 20:00 1.00 PULL P DECOMP P/U Tubing spear & break all connection. 20:00 - 21 :30 1.50 PULL P DECOMP RID 7" handling equip. Clear & clean rig floor. 21 :30 - 22:00 0.50 WHSUR P DECOMP P/U test plug & install same. UD running jt. 22:00 - 22:30 0.50 BOPSU P DECOMP Change out 7" pipe rams to 3 1/2" x 6" VBRs. 22:30 - 23:00 0.50 BOPSU P DECOMP RlU test equip. Install 3 1/2" test jt. Test VBRs. LP 250 psi. HP 4000 psi. Chart test. RID test equip. 23:00 - 00:00 1.00 CLEAN P DECOMP P/U & M/U BHA #1 to spear & recover locator sub as follows: Bull Nose, 5 1/2" Type "D" Spear, XO, Pump Out Sub, XO, Bumper Sub, Oil Jars, XO, 9 * 6 1/4" DCs, XO. TL = 307.86'. 10/29/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP Finish P/U & M/U BHA # 1 to fish locator sub. BHA #1 TL = 307.86'. 01 :00 - 06:00 5.00 CLEAN P DECOMP P/U 3 1/2" DP, 1x1 & RIH w/ BHA #1. Printed: 11/20/2006 10:35:49 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-06 NGI-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 10/25/2006 11/14/2006 Spud Date: 4/9/1976 End: 11/14/2006 10/29/2006 06:00 - 06:30 0.50 CLEAN P DECOM Lub Rig. Inspect Derrick. Check PVT alarms. 06:30 - 08:00 1 .50 CLEAN P DECOM Continue to single in with 3 1/2" Drill Pipe from Pipe Shed (244 Jts). 08:00 - 08:30 0.50 CLEAN P DECOM Pick-up a 3 1/2" Drill Pipe Pup Joint (23.86'). Pick-up Kelly. 08:30 - 11 :30 3.00 CLEAN P DECOM Swap Wellbore ove to 10.2 Iblgal Brine at avg rate 4.0 bbpmnOO psi. Total Brine pumped 570 bbls. Take Sea Water returns to Tiger Tank. 11 :30 - 14:30 3.00 FISH P DECOM PUW = 137K. SOW = 118K. Plant Spear in top of 5 1/2" jet-cut Stump at 8,062' 4esmd. Jar (with much gusto) Baker SBE Assembly free from Packer. Monitor Well fluid lever remains at surface and static. 14:30 - 15:00 0.50 FISH P DECOM Monitor Well. Fluid level at surface and static. 15:00 - 17:30 2.50 FISH P DECOM Trip out with 3 1/2" Drill Pipe and BHA. 17:30 - 18:00 0.50 FISH P DECOM Lay down BHA #1 and Fish...Seal Assembly. 18:00 - 18:30 0.50 FISH P DECOM Crew Change. Pre-tour mtg. Check PVTs. Inspect derrick. 18:30 - 19:00 0.50 FISH P DECOM Con't to Break out & UD BHA #1. 19:00 - 19:30 0.50 FISH P DECOM Clear & clean rig floor. 19:30 - 20:00 0.50 FISH P DECOM PIU & MIU BHA #2 to mill FB-1 packer as follows: PRT Spear wI Ext, Packer Mill, Triple Connect Sub, 2 Boot Baskets, BS, Bumper Sub, Oil Jars, Pump Out Sub, XO, 9 * 6 1/4" DCs, XO. TL = 330.95'. 20:00 - 22:30 2.50 FISH P DECOM RIH wI 81 stands of DP & BHA #2. 22:30 - 23:00 0.50 FISH P DECOM PIU single jt & kelly. Break circulation 3 BPM @ 380 psi. 23:00 - 00:00 1.00 FISH P DECOM Tag up on FB-1 Packer @ 8062'. (81 stds + 1jt +23' of kelly) Establish milling parameters & begin milling packer. PIU wt = 135K, S/O Wt = 115K, Rot Wt = 125K. 3 BPM @ 440 psi. 60 RPMs, Torq = 4-6K ft-Ibs. 10/30/2006 00:00 - 01 :00 1.00 FISH P Con't to mill FB-1 Packer from 8062 to 8064'. Lost total returns. PIU wI 230 K packer free. Weight dropped off to 175K. PIU Wt = 135K, S/O Wt = 115K, Rot Wt = 125K. 3 BPM @ 440 psi. 60 RPMs, Torq 4-8K ft-Ibs. 01 :00 - 04:00 3.00 FISH P Packer free. PIU to tool jt. Pump 100 bbls of 10.2 ppg brine down hole. No returns, unable to see any fluid. Discuss wI town engineer to reduce fluid weight to 9.8 ppg. Call for 9.8 brine. Con't to pump the remaining 10.2 ppg brine while waiting on fluid. 04:00 - 05:00 1.00 FISH P DECOMP Begin taking on 9.8 ppg brine. Finish pumping 10.2 ppg brine. 05:00 - 06:00 1.00 FISH P DECOMP Begin to displace hole with 9.8 Iblgal Brine at 4.0 bpm. 06:00 - 11 :00 5.00 FISH P DECOMP Service Rig. Unable to catch fluid with 9.8 Iblgal. Discuss plan forward with Anch Eng. Maintain 9.8 Iblgal Brine at -1.5 bpm with charge pump while building enough 9.0 Iblgal to sweep hole. Receive one more Vac Truck. Now have three Vac Trucks. 11 :00 - 14:00 3.00 FISH P DECOMP Continue to fill hole with 9.0 Iblgal Brine with Charge Pump while waiting for remaining Brine. 14:00 - 15:00 1.00 FISH P DECOMP Bring Pump on line at 6.5 bpm. Fluid to surface after 44 bbls (-705'). Maintain fluid in sight at 3.0 bpm. 15:00 - 15:30 0.50 FISH P DECOMP Pick-up single joint of Drill Pipe. Pick-up Kelly. Push Fish to top of 7" Liner at 8,123'. Set back Kelly. Lay down two singles with fish hanging-up. Fish freed-up however Iqst sight of fluid level. 15:30 - 16:00 0.50 FISH P DECOMP Attempt to regain a visual on fluid level at 6.5 bpm. After 50+ bbls no-joy. Reduce rate to Charge Pump again to conserve Printed: 11120/2006 10:35:49 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-06 NGI-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rjg Number: 1 0/25/2006 11 /14/2006 Spud Date: 4/9/1976 End: 11/14/2006 10/30/2006 15:30 - 16:00 0.50 FISH P DECOMP fluid in Pits. Discuss plan forward with Anch Eng. Send the 3 Vac Trucks to load up with Sea Water and 1% KCL. 16:00 - 18:30 2:50 FISH P DECOMP Maintain hole fill with 9.0 Iblgal Brine at - 1.5 bpm with Charge Pump while re-Ioading Vac trucks with Sea Water and 1% KCL. 18:30 - 20:30 2.00 FISH P DECOMP Begin filling hole wI 8.5 ppg seawater. Pump 4 BPM @ 100 psi. After pumping 435 bbls Fluid level was seen slowly rising in BOP stack. 20:30 - 21 :30 1.00 FISH P DECOMP Con't pumping seawater, slowed rate to 3 BPM & fluid level dropped below stack & down in wellbore.Discussed wI town engineer & recieved permission to POOH wI a continuous fill rate of 2-3 BPM. 21 :30 - 00:00 2.50 FISH P DECOMP RlU & POOH wI stands of 3 1/2" DP. Fill hole @ 2 1/4 BPM. Pulling wI 5-15K drag. occasional hang up while pulling thru connections. OOH wI 40 stands. 10/31/2006 00:00 - 02:00 2.00 FISH P DECOMP Con't to POOH & stand back 31/2" DP. 02:00 - 04:00 2.00 FISH P DECOMP Stand back DCs. BO& UD BHA. Recovered milled packer, SB Extension,Conc. coupling, MlO Extension, XO, 2 jts 4 1/2" tbg, XN Nipple wI plug, 4 1/2" Pup Jt & S/O sub. 100% recovery. Clean out boot baskets. Recovered scale & gunk. Con't to fill hole wI seawater. 04:00 - 05:00 1.00 FISH P DECOMP Clear & clean rig floor. Con't to fill hole wI seawater. 05:00 - 06:00 1.00 DHB P DECOMP MIU CBP & running tool & RIH on 3 1/2" DP. 06:00 - 06:30 0.50 DHB P DECOMP Lub Rig. Inspect Derrick. Check PVT Alarms. 06:30 - 09:30 3.00 DHB P DECOMP Continue to trip in with 3 1/2" Drill Pipe from Derrick. Pick-up 19 singles from Pipe Shed. 09:30 - 10:00 0.50 DHB P DECOMP Set Halco 7" Composite Bridge Plug at 8,256' (center of element). 10:00 - 11 :30 1.50 DHB P DECOMP Fill well bore with Sea Water. Circulate bottoms up at 6.0 bpm/1250 psi. 11 :30 - 12:00 0.50 DHB P DECOMP Pressure test Bridge Plug at 1450 psi for 15 minutes. OAP = 1350 psi. 12:00 - 12:30 0.50 DHB P DECOMP Bleed O/A to 0 psi, prep to POOH. 12:30 - 14:30 2.00 DHB P DECOMP PJSM. POOH wI 3 1/2" DP, UD running tool. 14:30 - 16:30 2.00 CLEAN P DECOMP PJSM. Change out oil jars, MIU 9 5/8" casing scraping BHA. 16:30 - 18:00 1.50 CLEAN P DECOMP RIH wI BHA #3 to scrape casing. 18:00 - 18:30 0.50 CLEAN P DECOMP Check PVT alarms. Inspect derrick. 18:30 - 19:30 1.00 CLEAN P DECOMP Con't to RIH wI BHA #3 on 3 1/2" DP. 19:30 - 21 :00 1.50 CLEAN P DECOMP PIU kelly, TIH & tag top of liner @ 8125'. 82 stands + 21' of kelly. PIU Wt = 146K, S/O wt = 116K, Rot Wt = 125K. Circulate bottoms up. Pump 5 BPM @ 860 psi. Pumped total of 235 bbls. Set back kelly. Blow down lines. 21 :00 - 00:00 3.00 CLEAN P DECOMP POOH & stand back 82 stands of 31/2": DP. 11/1/2006 00:00 - 01 :30 1 .50 CLEAN P DECOMP Break out & UD BHA #3. Empty boot baskets. recovered scale & gunk. 01 :30 - 02:00 0.50 DHB P DECOMP PIU setting tool & RBP. 02:00 - 04:30 2.50 DHB P DECOMP RIH to 8100' wI RBP. 04:30 - 05:00 0.50 DHB P DECOMP Set Halliburton 9 5/8' 3L RBP @ 8100'. PIU & verify set wI 15K down wt. 05:00 - 06:00 1.00 DHB P DECOMP RlU test equip. Pressure test RBP to 1000 psi for 10 min. Charted same. OAP = 500 psi. 1 st valve on IA had drip on valve stem. Greased same. 06:00 - 06:30 0.50 DHB P DECOMP Service & lub rig, check crown-o-matic, OK. Printed: 11/20/2006 10:35:49 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-06 NGI-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 1 0/25/2006 11/14/2006 Spud Date: 4/9/1976 End: 11/14/2006 1111/2006 06:30 - 09:30 3.00 DHB P DECOMP PJSM. POOH wI 3 1/2" DP & running tool, UD runnning tool. 09:30 - 11 :00 1.50 EVAL P DECOMP PJSM. Rig down flow nipple, nipple up shooting flange. 11 :00 - 13:00 2.00 EVAL P DECOMP PJSM. Rig up Schlumberger E line. Pressure test lubricator I pack off to 500 psi, OK. 13:00 - 18:00 5.00 EVAL P DECOMP Run US IT log on E line from 8100' to surface. Repeat pass across questionable corroded area & across suspected top of cement to surface. Send info to town for review by engineers. 18:00 - 18:30 0.50 EVAL P DECOMP Check PVT alarms. Inspect derrick. 18:30 - 19:30 1.00 EVAL P DECOMP Finish running USIT log. logged interval 8080' to surface. TOC @ 2086'. Collar to backed off @ 2046'. Cut @ +1-2021' .AII depths derrick floor measurements. 19:30 - 20:30 1.00 P DECOMP Re-head E-line for string shot. 20:30 - 21 :30 1.00 EVAL P DECOMP MIU string shot. RIH & fire 3 strand shot from 2040-2052'. Collar @ 2046' DFM. POOH WI same. 21 :30 - 22:30 1.00 EVAL P DECOMP RID E-line equip. Clear rig floor. 22:30 - 00:00 1.50 EVAL P DECOMP NID shooting flange. NIU flow nipple & air boot. 11/2/2006 00:00 - 01 :00 1.00 EVAL P DECOMP Finish NIU flow nipple. RlU to RIH w/3 1/2" DP. 01 :00 - 02:00 1.00 EVAL P DECOMP MIU RTIS & running tool. RIH to 1992'. 02:00 - 03:00 1.00 EVAL P DECOMP Sett RTTS @ 1992'. PIU wt = 39K, S/O Wt =30K. S/O wI all wt. Pressure up to 4000 psi & test for 30 min. Charted same. Tested good. Bleed off pressure. PIU & unset RTIS. Allow rubbers to relax. Monitor well. 03:00 - 04:00 1.00 EVAL P DECOMP POOH & UD RTIS. Take on 9.8 ppg brine. 04:00 - 06:30 2.50 DHB P DECOMP MIU setting tool & 9 5/8" RBP. RIH to 4000'.. 06:30 - 07:30 1.00 DHB P DECOMP PJSM. Presure test from surface to top of bridge plug @ 4000', 2000 psi 110 minutes, observe O/A pressure track up & all pressure leveled off @ 1800 psi, OK. Bleed pressure. 07:30 - 08:00 0.50 DHB P DECOMP Service rig, check PVT equipment, OK. 08:00 - 10:00 2.00 DHB P DECOMP Dump 2200 Ibs of 20/40 river sand, circulate (1) DP volume, tag sand top @ 3926'. 10:00 - 12:00 2.00 FISH P DECOMP PJSM. Line up & circulate 120 degree 9.8 ppg brine @ 43/4 bpm I 525 psi till clean 9.8 returns, 285 bbls total pumped. 12:00 - 14:00 2.00 FISH P DECOMP PJSM. POOH w/3 1/2" DP & UD running tool. 14:00 - 15:00 1.00 FISH P DECOMP PJSM. Pick up 9 5/8" casing cutter assembly. Cutter dressed wI 11 1/4" blades. 15:00 - 16:30 1.50 FISH P DECOMP RIH wI cutter assembly on 31/2" DP. 18 stands & 15.85' of DP pups. Pick up kelly. 56K up wt, 56K down wt. 16:30 - 18:00 1.50 FISH P DECOMP PJSM. Bring on pump @ 55 spm I 300 psi & slack off, see 9 5/8" casing collar 30' in on kelly @ 2047'. Shut down pump & pick up 20' to 2027'. Bring on rotary table @ 50 RPM, 1200 ft/lbs torque. Bring on pump eventually to 80 spm, (4.7 bpm), 525 psi. Comence cutting ops. Observe pressure drop from 800 psi on the O/A to 50 psi, indicating casing is cut. After 15 minutes, observe rotary table stall wI 9000 ft/lbs. Shut down pump, no flow. Bring on rotary table, observe jump wI 8000 ft/lbs, appears 9 5/8" casing may have been set in compression and blades are being squeezed after making cut. Rotary table engaged, brought up to 50 rpm, pump brought up again to 4.7 bpm I 525 psi, torque eventuall climbed again after 10 minutes to 9000 ft/lbs and stalled. Shut down pump, engaged rotary table, 9000 ft/lbs & stalled. Picked up wI 5 - 8K over pull & observed blades pulled free. 18:00 - 19:00 1.00 FISH P DECOMP Pump 50 bbls of heated 9.8 ppg brine down DP & out 9 5/8" X Printed: 11/20/2006 10:35:49 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-06 NGI-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 10/25/2006 11 /14/2006 Spud Date: 4/9/1976 End: 11/14/2006 11/2/2006 18:00 - 19:00 1.00 FISH P DECOMP 133/8" annulus. Took returns to tiger tank. Pumped 6 BPM @ 1050 psi. SID & monitor well. Small amount of gas breaking out, then stopped. 19:00 - 21 :00 2.00 FISH P DECOMP Wait on 155 bbls of diesel to flush out Arctic Pack. Service & maintain rig. Monitor well. Annulus dead. 21 :00 - 00:00 3.00 FISH P DECOMP Heat diesel & pump 50 bbl pill down DP & spot in annulus.2 BPM @ 360 psi. Wait 30 min. Pump 2nd 50 bbls heated diesel pill & spot in annulus. 2 BPM @ 280 psi.Allow to soak 30 min. Pump remaining diesel after heating (65 bbls) & spot in annulus. 2 BPM @ 200 psi. SID. 11 13/2006 00:00 - 01 :30 1.50 FISH P DECOMP Allow diesel to soak in annulus. Circuate annulus until clean. Pumped 125 bbls of 9.8 ppg brine & displace diesellArctic Pack out of annulus 6 BPM @ 760 psi. SID & monitor well. Arctic Pack was dark oily & gritty, thinner than on previous wells wI no large clumping. 01 :30 - 02:00 0.50 FISH P DECOMP Open annular preventer & circulate small amount of diesel off the DP x 9 5/8" annulus. SID & monitor well. Well static. Prep to POOH wI Cutting assy. 02:00 - 03:00 1.00 FISH P DECOMP POOH & stand back DP & DCs. 03:00 - 03:30 0.50 FISH P DECOMP UD BHA #4. Inspected knives & show good indication of cut. All blades recovered. 03:30 - 04:00 0.50 FISH P DECOMP M/U Spear Assy to Pull 9 5/8" casing. 04:00 - 04:30 0.50 FISH P DECOMP Spear into hanger. PIU & pull 9 5/8" fluted hanger up into stack. BOLDS. Open annulus. PIU & pulled hanger & csg string free wI 175K. Weight then dropped to 130K. Prep to Circ. 04:30 - 06:00 1.50 FISH P DECOMP Circulate well. Pump 6 BPM @ 190 psi. got very little Arctic Pack! diesel to surface. RlU tools To pull & UD 95/8" casing. Pull hanger to floor, 90K up wt. 06:00 - 17:00 11.00 FISH P DECOMP PJSM. POOH wI 9 5/8" casing & UD same. Connections very tight, over 27,000 ft/lbs. Requiring rig tongs for initial break out. Recovered 49 full jts & partial. Length 0 fpartial = 22.94'. Recovered (6) centralizers. 17:00 - 19:30 2.50 FISH P DECOMP Clean rig floor. & 9 5/8" handling equip. Arctic Pack All over handling tools & rig floor. 19:30 - 20:30 1.00 BOPSU DECOMP Set test plug. RlU test equip. 20:30 - 21 :00 0.50 BOPSU DECOMP Crew change. Hold PJSM & review BOP testing procedures. 21 :00 - 00:00 3.00 BOPSU DECOMP Test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 4000 psi. Lou Grimaldi wI AOGCC witnessing test. Found stem leak on Choke side HCR valve. H2S sensor on shale shaker needs replacement by electrician. 11 14/2006 00:00 - 04:00 4.00 BOPSU P DECOMP Con't testing BOPE as per BP/AOGCC requirements. Lou Grimaldi wI AOGCC witnessed test. Found drip on flange below #12 valve on choke manifold. tightened flange. Dart leaked & replaced "0" ring. Noticed fluid coming from relief valve on side of annular. Need to research relief valve operation & wheather this is a threat to integrity. Need determination prior to pulling RBP @ 8100'. 04:00 - 06:00 2.00 BOPSU P DECOMP Change out HCR valve on choke side of BOP stack. Old HCR valve had leaking stem. 06:00 - 08:00 2.00 BOPSU P DECOMP PJSM. Pressure test new HCR & breaks, @ 250 I 4000 psi, OK. UD test equipment. 08:00 - 10:30 2.50 CLEAN P DECOMP PJSM. Load BHA in pipe shed, remove ice from derrick. Printed: 11/20/2006 10:35:49 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-06 NGI-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 1 0/25/2006 11/14/2006 Spud Date: 4/9/1976 End: 11/14/2006 11 14/2006 10:30 - 13:30 3.00 CLEAN P DECOMP PJSM. Pick up washpipe, shoe, 133/8" scraper & junk subs. 13:30 - 16:00 2.50 CLEAN P DECOMP RIH wI washpipe assembly on 3 1/2" DP, slowly due to fluid running over. 16:00 - 17:00 1.00 CLEAN P DECOMP PJSM. Circulate out remaining arctic pack. 17:00 - 18:00 1.00 CLEAN P DECOMP Continue in hole. 18:00 - 18:30 0.50 CLEAN P DECOMP Crew change. Check PVT alarms. Inspect derrick. 18:30 - 19:00 0.50 CLEAN P DECOMP P/U kelly break circulatio. RIH & tag up on casing stub @ 2025'. 19:00 - 20:00 1.00 CLEAN P DECOMP Circulate, rotate & wash over casing stub. Wash from 2025 to 2080'. Found some junk @ 2044-2045'. Work thru several times. Push from 2045 to 2050' Then gone. PIU Wt = 60K, S/O Wt = 60K, Rot Wt = 60K. 3 BPM @ 110 psi. 55 RPMs, WOB = 2-4K. Torq = 3-4.5K ft-Ibs. 20:00 - 21 :30 1.50 CLEAN P DECOMP Circulate hole clean. Mixed & pumped 40 bbl Hi-Vis sweep & clean hole. Pumped 21 :30 - 22:00 0.50 CLEAN P DECOMP Set back kelly. Blow down lines. 22:00 - 23:00 1.00 CLEAN P DECOMP POOH wI Wash pipe assy. 23:00 - 00:00 1.00 CLEAN P DECOMP Break out & UD Wash Pipe assy. 11/5/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Finish laying down BHA # 6, Wash pipe assy. 00:30 - 02:00 1.50 CLEAN P DECOMP Clear & clean rig floor. 02:00 - 04:00 2.00 CLEAN P DECOMP PIU BHA #7, as follows: Bull Nose, XO, 9 * 6 1/4" DCs, XO, XO, Blanking Sub, Lowèr Back Off Assy, Power Section, Upper Back Off Assy, XO, Pump Out Sub, XO. TL = 319.65'. Fill BHA wI diesel. 04:00 - 06:00 2.00 CLEAN P DECOMP RIH wI BHA #7 on 3 1/2" DP. Fill DP every 5 stands while running in hole. 06:00 - 06:30 0.50 CLEAN P DECOMP Service rig. 06:30 - 08:00 1 .50 CLEAN P DECOMP Continue in hole, 18 stands. 57K up wt, 55K down. Stack out wI 10K @ 2026'. Attempt to work thru top of 9 5/8" casing stub, rotating & stacking, no go. 08:00 - 09:00 1.00 CLEAN P DECOMP PJSM. Drop bar & open pump out sub, circulate out diesel. 09:00 - 10:00 1.00 CLEAN N DPRB DECOMP POOH wI 31/2" DP. 10:00 - 12:30 2.50 CLEAN N DPRB DECOMP PJSM. UD back off assembly. 12:30 - 15:30 3.00 CLEAN N DPRB DECOMP PJSM. Clear Iclean rig floor. PIU Taper mill I string mill assembly. 15:30 - 17:00 1 .50 CLEAN N DPRB DECOMP RIH, kelly up on 17 stands & (2) singles. 57K up wt, 55K down. Bring on pump @ 5 bpm I 400 psi. See small bobble slacking off thru 2026', but nothing significant. 17:00 - 17:30 0.50 CLEAN N DPRB DECOMP Con't to RIH wI mill to 2421'. No problems. 17:30 - 18:00 0.50 CLEAN N DPRB DECOMP Circulate well. 5 BPM @ 440 psi. 18:00 - 18:30 0.50 CLEAN N DPRB DECOMP Crew change. Check PVT alarms. Inspect derrick. 18:30 - 19:00 0.50 CLEAN N DPRB DECOMP Con't to circulate well. 5 BPM @ 440 psi. Set back kelly. Blow down lines. 19:00 - 19:30 0.50 CLEAN N DPRB DECOMP POOH & stand back 31/2" DP. 19:30 - 20:00 0.50 CLEAN N DPRB DECOMP Break out & UD BHA # 8. 20:00 - 20:30 0.50 CLEAN N DPRB DECOMP Clear & clean rig floor. 20:30 - 22:00 1.50 FISH P DECOMP PIU & M/U BHA #9 to Back Off casing as follows: Tapered Mill, XO, XO, 9 * 6 1/4" DCs, XO, XO, Blanking Sub, Lower Slip Assy, Power Section, Upper Slip Assy, XO. Pump Out Sub, XO. TL = 322.87'. 22:00 - 23:30 1.50 FISH P DECOMP RIH wI BHA #9. Fill 1st stand of DP wI diesel, then fill every 3 rd stand wI brine while RIH. 23:30 - 00:00 0.50 FISH P DECOMP Space out tool. MIU circulating head. PIU & S/O Wts = 59K. Printed: 11120/2006 10:35:49 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-06 NGI-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 10/25/2006 11/14/2006 Spud Date: 4/9/1976 End: 11/14/2006 1115/2006 23:30 - 00:00 0.50 FISH P DECOMP 21 stands + 25' of single jt. Bottom slips @ 2063' Top slips @ 2037'. Collar @ 2047'. 11/6/2006 00:00 - 01 :00 1.00 FISH P DECOMP Pressure up to 1000 psi & set lower blocks @ 2063'.S/0 wI 22K. Bleed off pressure & close stroke 3". Pressure up to 1700 psi & set upper blocks. Hold pressure & S/O string wt. Bleed off pressure & allow tool to cycle. Pressure up to 1400 psi & casing turned 1/2 turn. Con't to cycle tool. pressures dropped off to 500 psi & then began to increase to 650 psi. Got total of 4 1/2 revolutions in casing stub. BFT elected to quit to avoid possibility of galling threads. Cycled tool total of 8 times. Unset tool. 01 :00 - 02:00 1.00 FISH P DECOMP Drop bar & shear out pump out sub. Circulate out diesel. 5 BPM @ 440 psi. 02:00 - 02:30 0.50 FISH P DECOMP UD head pin & single jt. POOH & stand back 31/2" DP. 02:30 - 03:30 1.00 FISH P DECOMP Break out & UD BHA #9. POOH & stand back DCs. 03:30 - 04:30 1.00 FISH P DECOMP Clear & clean rig floor. 04:30 - 05:30 1.00 FISH P DECOMP PIU & MIU BHA #10 to fish casing stub as follows: Bull Nose, ITCO Spear, Spear Extension, Stop Sub, XO. TL = 11.0'. 05:30 - 06:30 1.00 FISH P DECOMP RIH wI BHA #10. 06:30 - 07:30 1.00 FISH P DECOMP PJSM. Pick up kelly & establish parameters. 41K up wt, 40K down wt. Tag top of 9 5/8" stump with stop sub, 23' in on kelly, pick up 3 -5K over up wt to verify spear engaged. Rotate to the left observing max torque of 1500 - 2000 ft/bs, rotate 11 -13 turns, pick up, fish free. Stand back kelly. 07:30 - 09:00 1.50 FISH P DECOMP POOH w/3 1/2" DP & spear assembly. Recovered 19.18' of 9 5/8" casing. Pin end looked good, threads in good shape. UD same. 09:00 - 10:00 1.00 FISH P DECOMP PJSM. MIU 11 1/4" magnet assembly. (Some concern that a centralizer bow spring may have fallen down onto casing collar looking up). 10:00 - 11 :30 1.50 FISH P DECOMP PJSM. RIH wI magnet assembly. Lightly tag 9 5/8" collar @ 2047'. 11 :30 - 13:00 1.50 FISH P DECOMP PJSM. POOH w/3 1/2" DP & magnet assembly. No recovery of any centralizer pieces, only a few metal shavings. 13:00 - 16:00 3.00 CASE P TIEB1 PJSM. Rig up to run 9 5/8" TCII, 47#, L-80 casing. 16:00 - 16:30 0.50 CASE P TIEB1 Pre jopb with all associated parties on running of casing & ES cementer. Identified all potential hazards and reviewed mitigation plans. 16:30 - 18:00 1.50 CASE P TIEB1 Picked up tail pipe assembly including Baker triple connection screw in sub, baffle plate wI cement inside, 9 5/8" pup, Halliburton ES cementer, 9 5/8" BTC pin x TCII x/over jt. Making up all TCII connections to 17,500 ft/lbs of torque, torque turning each connection, free floating straight vane centralizer on each jt. Using Jet Lube Seal Guard pipe dope on all TCII connections. 18:00 - 18:30 0.50 CASE P TIEB1 Change crews. PJSM. Check PVTs. Inspect derrick. 18:30 - 00:00 5.50 CASE P TIEB1 Con'to RIH wI 9 5/8" Tie-back string. Torq turn connections to 17500 ft-Ibs. Used Jet Lube on connections. Installed free-floating turbolator on each jt. Had to change out power unit for tongs due to mechanical problem. Ran 40 jts in hole 11m2006 00:00 - 01 :00 1.00 CASE P TIEB1 Con't to run 9 5/8" Tie-back string. Ran 49 jts total. Torq turned connections to 17500 ft-Ibs. Used Jet Lube on connections. Installed free floating turbolator on each jt. Printed: 11/20/2006 10:35:49 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-06 NGI-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 10/25/2006 11/14/2006 Spud Date: 4/9/1976 End: 11/14/2006 11m2006 01 :00 - 02:00 1.00 CASE P TIEB1 Tagged up on collar @ 2047'. PIU jt #50 as landing jt. PIU & S/O Wts = 62K. Slowly MIU screw-in sub. Made 13 turns & bumped final torq to 17000 ft-Ibs. PIU & pull test casing to 250K. Held OK. S/O & MIU X-over & circulating head on string. 02:00 - 03:00 1.00 CASE P TIEB1 RlU lines & pressure test casing to 2000 psi for 30 min. Test Held OK. Charted same. Bleed off pressure & blow down lines. 03:00 - 03:30 0.50 CASE P TIEB1 RlU cementing head. 03:30 - 04:30 1.00 BOPSU P TIEB 1 NID BOP stack & PIU off spool. 04:30 - 05:00 0.50 BOPSU P TIEB1 PIU & set Vetco Gray emergency slips wI 150K. 05:00 - 06:00 1.00 BOPSU P TIEB1 NIU BOPE. 06:00 - 07:30 1.50 CEMT P TIEB1 PJSM. Rig up lines to mudcross, prep to circulate. 07:30 - 09:00 1.50 CEMT P TIEB1 PJSM. Line up & pressure up to 2800 psi & observe ES cementer open. Circulate well @ 5 bpm I 200 psi until 80 -85 degree 9.8 ppg brine coming back. 09:00 - 09:30 0.50 CEMT P TIEB1 Conduct pre cementing safety meeting with all associated hands. Review all aspects of the job. 09:30 - 10:00 0.50 CEMT P TIEB1 Finish rigging up cementers, prime up unit, pump 5 bbls 9.8 brine ahead. 10:00 - 11 :30 1.50 CEMT P TIEB1 Pressure test lines to 4000 psi, OK. Mix cement, 15.8 ppg class G wI D-600 Gas Block. 6-8 hrs thickening time. Pump cement @ average rate of 5.7 bpm, average pressure of 500 psi. Take returns thru choke to pits & hold back pressure to keep cement from falling down 9 5/8" casing, holding up to 350 psi back pressure. With 135 bbls cement pumped, shut down cement pump & close choke, SICP = 525 psi. Drop wiper plug, bring on pump & open choke, holding 350 psi back pressure. 2 1/2 bbls cement on top of plug. Displace cement wI 9.8 ppg brine @ average rate of 5.7 bpm I 500 psi. WI 70 bbls displaced, open choke all the way, still about 100 psi back pressure from line friction. WI 125 bbls displaced, take returns to outside tank. WI 135 bbls displaced, good indication of cement back. Slow down rate to 2 bpm wI 145 bbls away. Observe plug bump wI 151 bbls away & pressure up to 2175 psi & hold for 5 minutes. Bleed off & check for flowback, no flowback, total displacement after flowback = 149 bbls. Estimated displacement during pre job = 149 bbls. CIP @ 11 :15. 11 :30 - 12:30 1.00 CEMT P TIEB1 Blow down lines, rig down cementers. 12:30 - 15:00 2.50 BOPSU P TIEB1 PJSM. UD Halliburton cementing head, split stack, make rough cut on casing, stand back BOPE. 15:00 - 16:30 1.50 WHSUR P TIEB1 PJSM. Make final cut on casing, install 9 5/8" pack off. 16:30 - 19:00 2.50 WHSUR P TIEB1 PJSM. NIU tubing spool. 19:00 - 19:30 0.50 WHSUR P TIEB1 Pressure test new Packoff to 3,800 psi for 30 mins with Cameron rep - OK. 19:30 - 21:00 1.50 BOPSU P TIEB1 PJSM. NU 13 5/8" BOPE. 21 :00 - 22:00 1.00 BOPSU P TIEB1 Pressure test body break to 250 psi low and 4,000 psi high - OK. 22:00 - 23:00 1.00 CEMT P TIEB1 PJSM. PU and MU BHA #12 as follows with Baker rep: 8 1/2" Bit, Boot Basket, Boot Basket, 95/8" Scraper, Bit Sub, Bumper Sub, Jars, XO, (9) 63/8" DCs, XO. OAL = 314.81'. 23:00 - 00:00 1.00 CEMT P TIEB1 TIH with BHA #12 on 3 1/2" DP from Derrick. 11/8/2006 00:00 - 01 :00 1.00 CEMT P TIEB1 Tag hard at a depth of 1,967'. ES Cementer depth is 2,036'. Printed: 11/20/2006 10:35:49 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-06 NGI-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 10/25/2006 11/14/2006 Spud Date: 4/9/1976 End: 11/14/2006 11 1812006 00:00 - 01 :00 1.00 CEMT P TIEB1 Call SWS and confirm strength on both samples. The one at 100 degrees is at 1,800 psi and the one at 65 degrees is at 325 psi. Per Anchorage Engineering, 500 psi is all that is needed before drilling out and pressure testing. 01 :00 - 04:30 3.50 CEMT P TIEB1 PU and MU Kelly. UW = 55K, DW = 55K. Break circulation at a rate of 5.5 bpm I 325 psi. Engage Rotary Table at 60 RPM. Begin milling up shoe track maintaining 5-10K WOB. At 02:00 hrs, the sample at 65 degrees rose above 500 psi. According to the analysis, it took 12.5 hrs to reach the 500 psi. 04:30 - 05:00 0.50 CEMT P TIEB1 Stop milling just above the Baffle Plate. Circulate a hi-vis sweep around to help clean up the shoe track. Chase the sweep with 9.8 ppg brine at a rate of 5.5 bpm I 325 psi. 05:00 - 05:30 0.50 CEMT P TIEB1 Continue milling up the rest of the shoe track per Baker rep. Fell through Baffle Plate with no problems. 05:30 - 07:00 1.50 CLEAN P TIEB1 TIH with BHA #12 to top of RBP @ 4,000' on 3 1/2" DP from Derrick. 07:00 - 09:00 2.00 CLEAN P CLEAN PJSM. Tag top of sand @ 3926'. Pick up 2' & displace 9.8 ppg brine with seawater @ 6 bpm I 880 psi. 09:00 - 10:00 1.00 CLEAN P CLEAN PJSM. Close pipe rams & test 9 5/8" casing from surface to top of sand @ 3926'.4000 psi test, 30 minutes, charted, no bleed off, no indication of communication to O/A, good test. Bleed off all pressure. 10:00 - 11 :30 1.50 CLEAN P CLEAN PJSM. POOH w/3 1/2" DP. 11 :30 - 13:30 2.00 CLEAN P CLEAN PJSM. UD cleanout BHA, pick up reverse circulating basket BHA. 13:30 - 17:00 3.50 CLEAN P CLEAN RIH wI reverse circulating junk sub assembly on 3 1/2" DP. 17:00 - 18:00 1.00 CLEAN P CLEAN PU and MU Kelly. UW = 82K , DW= 82K, RW = 82K. Engage Rotary Table at 25 RPM with 1000 ft-Ib of torque (65 Amps). Break circulation at a rate of 3 bpm I 2,100 psi and begin to rotate and wash down through sand. Work RCJB from 3,926' - 3,931'. 18:00 - 19:00 1.00 CLEAN P CLEAN Pre-tour safety meeting and checks on the Rig. Continue circulating unitl bottoms up reached. Sand returns across the Shaker and no signs of metal. 19:00 - 20:30 1.50 CLEAN P CLEAN Blow down and set back Kelly. TOH with BHA #13 standing back DP in the Derrick. 20:30 - 22:00 1 .50 CLEAN P CLEAN On surface with BHA #13. Empty and inspect all junk baskets. One of the jets on the RCJB was completely plugged off. Recovered complete bottom rubber cone from Plug plus about another two big pieces of rubber. Small shavings of metal were recovered but not much. Recovered about half a 5 gallon bucket of what appears to be mainly scale with little sand. Re-make up BHA to RIH. 22:00 - 23:30 1.50 CLEAN P CLEAN TIH with BHA #14 (same as BHA #13) on 31/2" DP from Derrick. 23:30 - 00:00 0.50 CLEAN P CLEAN PU and MU Kelly. UW, DW and RW all = 82K. Engage Rotary Table and begin to wash down through sandlfill. Break circulation at a rate of 6 bpm I 2,200 psi. Tag fill at 3,927' (4' shallower than where we washed down to). Work RCJB per Baker rep down 10' to a depth of 3,937' (Kelly completely swallowed). 11/9/2006 00:00 - 00:30 0.50 CLEAN P CLEAN Continue circulating at 6 bpm I 2,200 psi until clean returns. Lots of sand and small pieces of rubber seen across the Printed: 11/20/2006 10:35:49 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-06 NGI-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 10/25/2006 11/14/2006 Spud Date: 4/9/1976 End: 11/14/2006 11/9/2006 00:00 - 00:30 0.50 CLEAN P CLEAN Shakers. The rate was sufficient to lift the sand to surface. Pumped a total of 412 bbls. 00:30 - 02:00 1.50 CLEAN P CLEAN Blow down and set back Kelly. TOH with BHA #14 standing back in the Derrick. 02:00 - 03:00 1.00 CLEAN P CLEAN On surface with BHA #14. Recovered in two pieces the ring where the rubber cone sits from the plug. Also recovered 7 big pieces of cement and the boot baskets were somewhat filled with sand/shale. Re-make up BHA components to re-run. 03:00 - 04:30 1.50 CLEAN P CLEAN TIH with BHA #15 on 31/2" DP from the Derrick. 04:30 - 06:00 1.50 CLEAN P CLEAN PU and MU Kelly. UW, DW and RW all = 82K. Total of 38 stands (114 Joints) in the well. Tag fill @ 3,943' (6' deeper than we cleaned out). Break circulation at 5 bpm I 1,750 psi. Work the RCJB down 10' to a depth of 3,953'. CBU at a rate of 5.5 bpm I 2,000 psi until clean returns seen on surface. Got sand returns across the Shakers. 06:00 - 06:30 0.50 CLEAN P CLEAN Lubricate rig. 06:30 - 08:00 1.50 CLEAN P CLEAN PJSM. POOH wI 3 1/2" DP & reverse circulating junk sub assembly. 08:00 - 10:30 2.50 CLEAN P CLEAN PJSM. UD BHA. RIH wI 6 1/4" drill collars & UD same. 10:30 - 12:30 2.00 CLEAN P CLEAN PJSM. RIH wI Halliburton bridge plug retrieving tool on 3 1/2" DP. 12:30 - 14:30 2.00 CLEAN P CLEAN PJSM. M/U head pin. 64K up wt, 62K down. Tag sand top @ 3959'. Line up, close bag & reverse circulate sand out, stripping on down to top of bridge plug fish neck @ 3993'. Reverse circulate Hi vis sweep around @ 5 bpm I 550 psi. Sand back over shaker, no other significant tid bits. 14:30 - 15:00 0.50 CLEAN P CLEAN PJSM. Latch up bridge plug & release same. 15:00 - 17:30 2.50 CLEAN P CLEAN PJSM. POOH w/3 1/2" DP & UD bridge plug, rubbers torn up a bit, but nothing missing. 17:30 - 18:00 0.50 CLEAN P CLEAN Pre-tour safety meeting and service Rig. 18:00 - 20:00 2.00 CLEAN P CLEAN TIH with Halliburton RBP retrieving tool on 3 1/2" DP from Derrick. 20:00 - 21 :00 1.00 CLEAN P CLEAN In with 85 stands and a single (256 Joints). MU Headpin. UW = 115K , DW = 104K. Dry tag @ 8,090'. Line up to circulate and work onto fish neck. Latch and release RBP per Halliburton rep. Confirm by TIH to 8,110 with no weight stacked out. Monitor well and well is static. 21 :00 - 23:00 2.00 CLEAN P CLEAN CBU to confirm no trapped gas beneath RBP. Break circulation at a rate of 5 bpm I 675 psi. Pumped a total of 500 bbls with no gas or abnormalities seen in returns. 23:00 - 00:00 1.00 CLEAN P CLEAN Lay down 1 Joint of DP. Cut and slip Drilling Line. 11/10/2006 00:00 - 03:30 3.50 CLEAN P CLEAN TOH with 9 5/8" RBP from 8,100' standing back DP in the Derrick. Lay down RBP with Halliburton rep. The RBP looked really good, the rubber was completely intact and looked new. 03:30 - 05:30 2.00 BOPSU RUNCMP PJSM. Pull Wear Ring and set Test Plug. Change out Pipe Rams from 3 1/2" x 6" to 7 5/8". RU Test Equipment. 05:30 - 11 :00 5.50 BOPSU RUNCMP Test BOPE per BP/AOGCC Regulations to 250 psi low and 4,000 psi high. The state's right to witness the test was waived by Jeff Jones at 03:00 hrs on 11/10/2006. 11 :00 - 13:00 2.00 RUNCMP PJSM. Rig up floor to run 7 5/8" tubing. 13:00 - 13:30 0.50 RUNCMP Pre job on running 7 5/8" completion string. Reviewed individual duties, proper torque and potential hazards. 13:30 - 14:30 1.00 RUNCMP Pick up & make up tailpipe assembly. All connections below Printed: 1112012006 10:35:49 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 16:30 - 00:00 11/11/2006 00:00 - 06:00 06:00 - 06:30 06:30 - 11 :00 NGI-06 NGI-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES RUNCMP RUNCMP RUNCMP RUNCMP 11 :00 - 13:00 RUNCMP 13:00 - 18:30 RUNCMP 18:30 - 19:00 0.50 RUNCMP 19:00 - 19:30 0.50 RUNCMP 19:30 - 22:30 3.00 RUNCMP 22:30 - 00:00 1.50 RUNCMP 11/12/2006 00:00 - 00:30 0.50 RUNCMP 00:30 - 02:00 1.50 RUNCMP 02:00 - 04:00 2.00 RUNCMP 04:00 - 07:00 3.00 RUNCMP 07:00 - 10:00 RUNCMP 10:00 - 12:00 2.00 RUNCMP 12:00 - 14:00 2.00 CLEAN P CLEAN 14:00 - 18:00 4.00 CLEAN P CLEAN 18:00 - 20:00 2.00 CLEAN P CLEAN 20:00 - 21 :00 1.00 CLEAN P CLEAN Start: Rig Release: Rig Number: Spud Date: 4/9/1976 End: 11/14/2006 10/25/2006 11/14/2006 packer Baker Locked. Wait on 7 5/8" Yam Top HC x 31/2" IF XO for TIW Valve that is being used by Nabors 27E - only one on the Slope. RIH with 7 5/8",29.7#, L-80 Yam Top HC Completion. Using Torque Turn for all connections. Make up torque for 75/8" Yam Top HC = 14,450 ft-Ibs. Using Stabbing Guide to make up connections and Jet Lube Seal Guard for all threads. Continue RIH with 7 5/8" Completion. Service & lubricate rig. PJSM. Continue runnnig in hole wI 7 5/8" Yam Top HC 29.7# IPC L-80 tbg, torque turning to 14,500 ft/lbs & using Jet Lube Seal Guard pipe dope. Tag top of 7" liner 37.5' in on jt # 197. Up wt = 222K, down wt = 187K. PJSM. UD (2) jts, make up 9.75' space out pup & jt # 196. M/U hanger wI pups. Land hanger, OK. UD landing joint & run in lock down screws. PJSM. Line up & reverse circulate heated seawater @ 3 bpm I 60 psi, 200 bbls. Line up & reverse circulate 250 bbls of heated seawater wI corrosion inhibitor, 3 bpm 1150 psi. Blow down lines and RU Little Red on the IA. Freeze protect the IA with 45 bbls of diesel. Pumped down the IA with Little Red at a rate of 2 bpm I 800 psi. PU Joint of DP. Drop Ball and Rod. Lay down Joint of DP. Allow Ball and Rod to fall for 30 mins to ensure on seat. Pressure up on Tubing to 4,000 psi and test for 30 mins charted - OK. Bleed pressure off to 1,500 psi. Pressure up on IA with Little Red to 4,000 psi and test for 30 mins charted - OK. It took 4.3 bbls to achieve test pressure. Bleed IA pressure to zero and then Tubing pressure to zero. PJSM. Change out Pipe Rams from 75/8" to 3 1/2" x 6" VBRs. Test to 250 psi low and 4,000 psi high - OK. RD Test Equipment. ND Flow Riser and NU Shooting Flange. PJSM with Schlumberger Slickline. RU Slickline to Shooting Flange. Pressure test Lubricator to 500 psi RIH with Ball and Rod pulling tools on Slickline, POOH, no recovery, redress tool, RIH, latch up @ 8126', POOH, UD rod I ball assembly. RIH wI slickline, attempt to pull RHC-M plug body @ 8126', sheared off, no retrieval, POOH, redress tool, RIH, POOH, UD plug body. PJSM. Rig down Schlumberger slickline, nipple down shooting flange, NIU flow nipple. PJSM. Pick up BHA to mill up 7" composite bridge plug. RIH wI composite bridge plug milling BHA on 3 1/2" DP. In with 83 stands (249 Joints) of DP. PU and MU Kelly. UW = 130K , DW = 116K. Tag Fasdrill Plug 31' in on the Kelly = 8,251'. Engage Rotary Table at 80 RPM with 3,000 ft-Ib of torque (160 Amps). Break circulation at a rate of 4 bpm I 600 psi. Maintain 3-5K WOM and work down 2 1/2 ft and fell through (8,253.5'). Blow down and set back Kelly. PU 2 remaining stands of DP from the Derrick and RIH. Final depth reached = 8,411'. Keep Printed: 11/20/2006 10:35:49 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-06 NGI-06 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 10/25/2006 11/14/2006 Spud Date: 4/9/1976 End: 11/14/2006 11/12/2006 20:00 - 21 :00 1.00 CLEAN P CLEAN charge pump on and monitor well for 15 minutes to gauge loss. 15 min loss = 12 bbls = -50 bph. 21 :00 - 00:00 3.00 CLEAN P CLEAN TOH with BHA #16 laying down DP 1 x 1 in the Pipe Shed. Keep charge pump on while TOH to keep the hole full. Current losses are - 68 bph including pipe displacement. Take another load of seawater into the Pits to fill them completely. Round trip the truck for another load. 11/13/2006 00:00 - 03:30 3.50 CLEAN P CLEAN Continue TOH with BHA #16 laying down DP in the Pipe Shed. Losses are steady at around 68 bph. Maintaining constant hole fill with charge pump as TOH. 03:30 - 04:30 1.00 CLEAN P CLEAN On surface with BHA #16. Break down and lay down components with Baker rep. Recovered (1) button slip and small chunk of rubber. 04:30 - 06:00 1.50 DHB P INTERV PJSM. ND Flow Riser. NU Shooting Flange. 06:00 - 07:30 1.50 DHB P INTERV Wait on wireline unit. 07:30 - 08:00 0.50 DHB P INTERV Pre job meeting wI Schlumberger regarding plug running & subsequent testing of same. 08:00 - 11 :00 3.00 DHB P INTERV PJSM. Rig up Schlumberger wI full BOPE. Test lubricator to 500 psi, OK. 11 :00 - 12:30 1.50 DHB P INTERV RIH, set RHC-m plug body in RlN nipple @ 8130', POOH. 12:30 - 14:00 1.50 DHB P INTERV M/U equalizing prong & RIH to 8000'. 14:00 - 17:30 3.50 DHB P INTERV PJSM. Test Little Red lines to 2000 psi, OK. Pump diesel down 75/8" tbg @ 2 bpm, max pressure = 1400 psi. Pumped 115 bbls total. Seated equalizing prong in plug body. Sheared off & pulled back to 8000'. Pressure tested plug wI Little Red to 1500 psi, 15 minutes, charted. Good test. Bleed all pressure. POOH with Slickline. RD Little Red. 17:30 - 18:30 1.00 DHB INTERV RD Slickline. 18:30 - 19:30 INTERV PJSM. ND Shooting Flange. 19:30 - 20:00 INTERV Set TWC with Cameron reps. It took 71/2" turns. Pressure test with diesel to 1 ,000 psi from above for 10 mins, charted - OK. 20:00 - 00:00 4.00 BOPSU INTERV PJSM. ND Test Spool. ND Annular Preventor - model GK, and take out of service. 11/14/2006 00:00 - 02:30 2.50 BOPSU INTERV PU and NU new Annular Preventor - model GX. Set back BOPE. 02:30 - 05:30 3.00 WHSUR P INTERV NU Adapter Flange and McEvoy Tree with Cameron reps. 05:30 - 06:00 0.50 WHSUR P INTERV Pressure test void to 5,000 psi for 30 mins with Cameron reps. 06:00 - 08:00 2.00 WHSUR P INTERV PJSM. Rig up lubricator, pull two way check valve, set BPV. Secure well, rig released @ 08:00, 11/14/2006. Printed: 11/20/2006 10:35:49 AM · Page 1 of 1 Digital Wellfile I wêll Events for SurfaceWell - NG -06 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS1 -> NGI -> NGI-06 Date Range: 15/Sep/2006 to 25/0ct/2006 Data Source(s): DIMS, AWGRS Events Source DIMS A'tfLGRS AWGRS Well NGI -06 NGI -06 NGI -06 Date 10/25/2006 10/25/2006 10/20/2006 AWGRS NGI-06 10/19/2006 AWGRS NGI-06 10/19/2006 AWGRS NGI-06 10/03/2006 AWGRS NGI-06 09/22/2006 AWGRS NGI-06 09/21/2006 AW,GRS NGI-06 09/16/2006 AWGRS NGI-06 09/15/2006 AWGRS NGI-06 09/15/2006 Description RDMO. Move to NGI-06. Beging RU. Set bpv for the rig to move on T/I/0=950/175/0 CMIT TxlAxOA to 2000 psi, PASSED (Rig prep) - Getting TP off SSSV control line, Pump 8.7 bbls (total) meth to pressure T/I/O to 2500/2200/2010 psi, 1st test; T/I lost 0/20 psi & OA increased 10 psi in 15 min, T/I/O lost 0/10/0 psi in 2nd 15 min, Carried test out 45 min, T/I/Olost 0/0/0 psi in 3rd 15 min, PASSED, Bleed WHP's Final WHP's=900/0/0 T/I/0=950/175/0 CMIT TxlA to 2000 psi, (Rig prep) - Getting tubing pressure off SSSV contolline, Pump 6 bbls meth down IA to pressure TxlAxOA to 2240/2000/125 psi, SD, OAP slowly tracking up w/ TxIAP's , Let WHP's equalize ---n-In PROGRESS--nn(Continued on 10- 20-06 WSR) Load & road for CMIT, Job postponed, WH needs scaffolding T/IA/OA = 0/0/0 (Pre Rig Inspection) PPPOT-T = Passed Bled tubing hanger voids to 0 psi. Torqued lockdown screws to 550 ft/lbs. Rigged up test equipment and pumped until clean ftuid returns were achieved. Pressured up void to 5,000 psi. for 30 mins. - Passed Continued from 9-21-06 Cire-out CMIT TXIA 3500 psi FAILED MIT. MITOA INCOMPLETE F- protect TBGxIA Pumped 64 bbls of 80* 60/40 down IA for F-Protect pumped 8.1 bbls of meth down TBG for CMIT TxlA to reaeh 3400 psi OA psi rising MIT OA canceled OAP rising with CMIT TxIA. Final Whp's=O/O/O T/I/0=800/450/450 Circ Out CMIT TXIA 3500 psi MIT OA 2000 psi F-Protect TBGxIA (PRE RWO) Spear in to IA w/8 bbls of neat methanol followed by 14 bbls of 2% KCL and psi up TBG and IA to 1000 psi to confirm TBG plug holding followed by 707 bbls of 110* 2% kcl taking returns up TBG to surface tanks pumped 157 bbls of 80* 60/40 down TBG for F- Protect job in progress **CONTINUED FROM 15-SEP-2006** T/I/O 1700/2000/50. 5.5" TUBING CUT AT 8061 FT WITH 4.15" SLB POWERCUTTER. DEPTH TIED TO TUBING DETAIL DATED 7-FEB-1988. DEVIATION AT CUT 41 DEGREES. RIG UP FOR JETCUT OF 5.5" TUBING **CONTINUED 16-SEP-2006** *** WELL SHUT IN UPON ARRIVAL *** (pre rwo) RAN 4.5 CENT,S.B.,SAT DOWN @ 8077 SLM. ALL CLEAR.RDMO. *** LEFT WELL SHUT IN,TURNED WELL OVER TO PAD OPER.*** http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 11/30/2006 TREE = JlVELLH.EAO = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Datum MO = Datum TVO = . PJC DRAFT NGI-06 . I SAFETY NOTES: 9-5/8" CSG, 47#, L-80, TC-II, 10 = 8.681" I 2047' 113-3/8" CSG, 72#, MN-80, 10 = 12.347" I 7-5/8" TBG, 29.7#, L-80 V AM TOP HC, IPC, .0459 bpf, 10 = 6.875" Minimum ID = 5.770" @ 8108' 7" RN NIPPLE 17" TBG, 26#, L-80, TC-II, .0383 bpf, 10 = 6.276" 1 TOP OF 7" LNR 19-5/8" CSG, 47#, MC-9=80, 10 = 8.681" I PERFORATION SUMMARY REF LOG: BHCS ON 04/28/79 ANGLEATTOPPERF: 37 @ 8894' Note: Refer to Production OB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 3-3/8" 4 8894 - 8950 0 06/30/90 3-3/8" 4 8999 - 9002 0 05/02/87 3-3/8" 4 9009 - 9028 0 05/02/87 3-3/8" 4 9036 - 9237 0 05/02/87 3-3/8" 4 9242 - 9282 0 05/02/87 3-3/8" 4 9289 - 9299 0 08/06/78 3-3/8" 4 9322 - 9376 0 05/02/87 3-3/8" 4 9387 - 9415 0 05/02/87 3-3/8" 4 9419 - 9434 0 08/06/78 3-3/8" 4 9460 - 9469 0 08/06/78 3-3/8" 4 9473 - 9479 0 08/06/78 PBTD I 17" LNR, 29#, N-80, .0371 bpf, 10 = 6.184" I 9412' 9580' OATE 05/05/76 02/07/88 11/14/06 11/22/06 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOV ER N4ES RWO ?/ PJC DRLG DRAFT CORRECTIONS OATE REV BY -I HALCO ES CEMENTER I -17" CAMCO DB-6 NIP, ID = 6.00" 2197' -17" X 7-5/8" XO, ID = 6.2761 8052' -17-5/8" X 7" XO, 10 = 6.2761 8063' H 7" HES "R" NIP, ID = 5.963" I 8084' -19-5/8" X 7" BKR S-3 PKR, ID = 6.00" I -17" HES "RN" NIP, 10 = 5.770" I 8121' -17" WLEG, 10 = 6.276"1 COMMENTS PRUOHOE BA Y UNIT WELL: NG "06 PERMIT No: "1760290 API No: 50-029-20206-00 SEC 12, T11 N, R14E 1217 .37 FEL 3791.89 FNL BP Exploration (Alaska) 11/28/06 Sc~lumbepger NO. 4058 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth 170-0éP7 U'lê Field: Prudhoe Bay Well Job# Loa DescriDtion Date BL Color CD H·34 11477963 LDURST 11/07/06 1 Y-01B 11485468 MPPROF W/DEFT & GHOST 11/07/06 1 2-08/K-16 11487771 LDL 11/12/06 1 X-03A 11485772 MPPROF W/DEFT & GHOST 11/09/06 1 DS 09-51 11477933 INJECTION PROFILE 11/06/06 1 15-45A 11485469 MPPROF & INJECTION PROF 11/09/06 1 N-O'7A 11296715 PROD PROFILE W/GHOST 09/10/06 1 DS 09-31C 11483591 INJECTION PROFILE 11/20/06 1 G-06A 11422979 SCMT 11/01/06 1 P2-59A 11414775 SCMT 11/05/06 1 NGI-06 11414773 USIT 11/01/06 1 A-43 11414774 USIT 11/03/06 1 01-26A 11001225 RST -SIGMA OS/24/05 1 1 . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 900 E. Benson Blvd, Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell S~ S"~ g_ A~ho",', AK "'''l ATTN: Beth ê Received by: I / ~, NOV 9,' 9 70or; Date Delivered: \~ -- . ;',~\ ""',' ',? , ,r;;"\ð', ¡ k;-;;1I, ' ~F'" lI'~',u "I! Hi t, ij, Ii II ;, 'I it, ,I", 'j 'I ">b... "'",' ~,i nv i\ ',! ';;;J -.\~;, ¡i f" ~ li ¡ ~ il l!J,I 'I iiU"", q ~ Ii-, ~~ ~!bj Y:w ~ '~~ J rF u " ' ' I' I-, iL; J ,fi\ ,I;" , ¡fI,'" ,y --. " r-1 Ùu ~) l'"1j'7 ,fT~ ~ \'-' )111/, f, i,t' \," '~ ¡ i¡ I '\,''c, \\~, /L\ n ; 1 : ij' ~~ ¡II \ >, U ¡ ~ "I, n \ '~~ l-W U FRANK H. MURKOWSKI, GOVERNOR AI,ASIU. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 SCANNED SEP 1 3 2006 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU NGI-06 Sundry Number: 306-310 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this/Yday of September, 2006 Enc!. r--:t-Cc - Öd-~ ~ \, . f/t 9J¡J)t?b Ó7--- cA·'+i(IIID/' \ \O'f STATE OF ALASKA:S 9/1~ ~I (\ ALASKA OIL AND GAS CONSERVATION COMMI!I!ION \ APPLICATION FOR SUNDRY APPROVAL 20 MC 25 280 HklGlc 1\fe&Ð(P SEP 0 B 2006 Alaska Oil & Gas Cons Comn'" . I\,.L " IssIan 1. Type of Request: 0 Abandon o Alter Casing o Change Approved Program o Suspend 181 Repair Well 181 Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time Extension o Re-Enter Suspended Well o Other -g' 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? 0 Yes ~ No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028302 47' Prudhoe Bay Field / Prudhoe Bay Pool ..... ,.<,..<li.v\.)I'iIUI ..., .......'.. ........./ >.>.;·Y.iY< Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8617 I 9412 / 8477 8165 None Lenoth Size MD / TVD Burst CollaDse 4. Current Well Class: ./ o Development 0 Exploratory o Stratigraphic ~ Service 5. Permit To Drill Number 176-029 /' 6. API Number: ./ 50-029-20206-00-00 ./ 8. Well Name and Number: PBU NGI-06 ,/' I? ' ,"'-. Total Depth MD (ft): 9585 Casino Structural Conductor Surface Intermediate Production Liner 80' 20" 80' 80' 1530 520 2668' 13-3/8" 2668' 2668' 5380 2670 8464' 9-5/8" 8464' 7730' 6870 4760 1457' 7" 8123' - 9580' 7469' - 8613' 8160 7020 Perforation Depth MD (ft)/I Perforation Depth TVD (ft): I Tubing Size: / Tubing Grade: Tubing MD (ft)~ Below PluQ: 8894' - 9479 I 8063' - 8531' 7",29# x 5-1/2",17# x 4-1/2", L-80 8177' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'FB-1' packer I Packers and SSSV MD (ft): 8066' / 13. Attachments: 14. Well Class after proposed work: /' ~ Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program /'.. 0 Exploratory 0 Development ~ Service 15. Estimated Date for I I 16. Well Status after proposed work: Commencinq Operations: Octo~r 5, J006 0 Oil 0 Gas 0 Plugged 0 Abandoned 17. Verbal Approval: Da~/ Commission Representative: 0 WAG ~ GINJ 0 WINJ 0 WDSPL 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Na'~ David Reem Title Drilling Engineer Il () Prepared By Name/Number: Signature AA ß~ þ[) ('./ [(.0 u>-. Phone 564-5743 Date C¡-~-Oh Terrie Hubble, 564-4628 Commission Use Onlv Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test ~echanicallntegrity Test 0 Location Clearance Other: Test- BO Pi: +0 4--000 f-k. Subsequenl Form Requ'red, \0 - 4-0~ Approved By: ---r.J 01SSIONER Form 10-403 Revised 06/2006 \../' V ORIGINAL I Sundry Number: _~ IJ r 2, I () APPROVED BY THE COMMISSION Date 9,./1/,0,6 RBDMS 8Ft ., ~ t\; ft,_ SEP J t; ZDD6 Submit In Duplicate . . Well Status: Shut-in gas injector. Well has confinned inner x outer annulus communication. The well is secured with a tubing tail plug. Proiect: Retrieve existing 7",29#, L-80 IPC ABM 8rd completion including the packer and tail-pipe. Cut and pull ~2300' of9-5/8". ?e-back in with 2300' of new 9-5/8", 47#/ft, L-80 TC-II casing and cement in place. Re-complete with 7", 26#/ft x 7.625", 29.7#/ft, L-80 Vam Top HC IPC tubing, pennanent packer with tail-pipe ~2' above existing 7" liner-top packer. Provide AOGCC field inspectors 24-hr notices as required to witness BOP tests and MITIA post packer setting. PRE-RWO · Set TTP in "XN" nipple to secure well. . Jet cut 5-1/2" tubing in pup joint above the packer. · Circulate the well over to seawater with diesel freeze protect. CMIT to 2500 psi to verify tubing tail plug integrity. MITOA to 2500 psi to verify 13-3/8" shoe /' integrity. Set and test BPV in tubing hanger. RWO 1. MIRU workover rig. Circ out diesel freeze-protect and verify well is dead. Set TWC in tubing hanger and test. 2. ND tree, NU~IY test BOPE per BP and AOGCC regulations (250 psi low~ pressure test! 00 si high pressure test (test the annular to 3500 psi). 3. Pull 7" x 5-1 . tubing down to the cut. 4. Spear tubing stub and jar seal nipple free from packer. 5. RIH w/packer milling BHA, turn well over to 10.2 ppg brine, mill over packer and POH with same. 6. RIH and set 7" composite bridge-plug in 7" liner ~50' below liner top. PT plug to 2500 psi to prove up barrier. 7. Run 9-5/8" scraper to the liner top. 8. Set retrievable 9-5/8" bridge-plug ~30' above 7" liner top. 9. Run 9-5/8" USIT to locate top of cement in 9-5/8" x 13-3/8" annulus. / 10. Set 9-5/8" RBP ~ 1000' below the TOC indicated on the USIT log. Spot 30' of sand on RBP. 11. Mechanically cut the 9-5/8" casing in the 2nd full joint above the TOC. 12. Mobilize and circulate out all ~tic Pack from the 9-5/8" x 13-3/8" annulus. 13. Pull 9-5/8" down to the cut. 14. Run wash shoe and 13-3/8" scraper down to the 9-5/8" stub. Ensure wash shoe is able to get beyond the next 9-5/8" collar by ~6'. Reverse circulate the wellbore clean. 15. Back-off 9-5/8" casing stub. 16. RIH with new 9-5/8", 47#/ft, L-80 TC-II casing, shoe-track and over-shot guide- sub. Screw into existing 9-5/8" casing. Pull test casing to 250K. Pressure up to open ES-cementer. Verify communication up 9-5/8" x 1/3-3/8" annulus. 17. Pull 250K tension on 9-5/8" casing. . . 18. Cement 9-5/8" in place with target top of cement = SURF ACE. Close ES- cementer. 19. Split stack below BOPs and install 9-5/8" emergency slips and primary pack-off. Slack off ~ lOOK to fully engage slips and energize pack-off Wachs cut 9-5/8". ~ Set back BOPs. Make final dressing cut on 9-5/8" if required and NU tubing spool with secondary pack-off. NU BOPs. Test spool/BOPs to 4000 psi. /' 20. Drill out shoe-track down to sand top on RBP. PT casing to 4000 psi. 21. Retrieve the 9-5/8" RBPs. Stand back drill-pipe. 22. RIH with 7" WLEG, 7" 26#/ft L-80 tail-pipe, 7" x 9-5/8" L-80 S-3 packer, 7" crossed over to 7", 26#/ft x 7-5/8", 29.7#/ft, L-80, VamTop HC completion. Will have a 7" DB-6landing nipple at ~2100' for A-I injection valve installation after the rig moves off. 7-5/8", 29.7#/ft, L-80, VamTop HC tubing will extend up from the DB-6 nipple to surface. 23. Tag top of existing liner-top packer, PIU 2-3', reverse in packer fluid and freeze protection. Set S-3 packer. MIT-T to 4000 psi, MIT-IA to 4000 psi. 24. RIH w/5.625" milling assembly on drill pipe to the 7" composite bridge-plug. /' Mill up plug. POH and LDDP. 25. RU slickline and set plug in "RN" nipple. Test plug to 1500 psi to prove up b~~ / 26. Set BPV. ND BOP, NU and PT adapter flange and tree to 5000 psi. 27. RDMO. POST-RWO · Pull ball&rod from RHC sleeve. Pull RHC sleeve. Pull RN plug. · Set 7" A-I injection valve in "DB-6" nipple. · Tie-in injection lines, re-set wellhouse and instrumentation. /~ · POI. MIT-IA w/AOGCC witness. 'TREE=' GRAY GEN 2 WELLHEAD = GRA Y ACTUA TOR = AXELSON KB. ELEV = 47' BF. ELEV = ? KOP = 4700' Max Angle = 42 @ 7600' Datum MD = 9842' Datum ND = 8800' SS NGI-06 . 113-3/8" CSG, 72#, MN-80, ID = 12.347" I Minimum ID = 3,75" @ 8165' 41/2" OTIS XN NIPPLE 17" TBG-NPC, 29#, L-80, .0371 bpf, ID = 6.184" H S05S' I TOP OF 5-1/2" TBG-NPC I 15-1/2" TBG-NPC, 17#, L-80, .0232 bpf, ID = 4.892" H SOS5' TOP OF 4-1/2" TBG-NPC I TOPOF7" LNR I 14-1/2" TBG-NPC, 12.6#, L-80, .0152 bpf, ID = 3.958" 19-5/8" CSG, 47#, MN-80, ID = 8.681" I PERFORA TION SUMIV1ARY REF LOG: BHCS ON 04/28/79 ANGLE AT TOP PERF: 37 @ 8894' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 8894 - 8950 C 06/30/90 3-3/8" 4 8999 - 9002 C 05/02/87 3-3/8" 4 9009 - 9028 C 05/02/87 3-3/8" 4 9036 - 9237 C 05/02/87 3-3/8" 4 9242 - 9282 C 05/02/87 3-3/8" 4 9289 - 9299 C 08/06/78 3-3/8" 4 9322 - 9376 C 05/02/87 3-3/8" 4 9387 - 9415 C 05/02/87 3-3/8" 4 9419 - 9434 C 08/06/78 3-3/8" 4 9460 - 9469 C 08/06/78 3-3/8" 4 9473 - 9479 C 08/06/78 IPBTD I 9412' I 7" LNR. 29#, N-80, .0371 bpf, ID = 6.184" H 95S0' DATE 05/05/76 02/07188 07/17/01 08/23/02 07/04106 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER RNlTP CORRECTIONS JB/TP CHANGEXN NIP 10 SIZE GJF/PAG SET PXN PLUG DATE REV BY COMMENTS I SAFETY NOTES: -17" CAMCO BAL-O SSSV NIP, ID = 5.937" I 8058' -17" X 5-1/2" XO I -1 5-1/2" BA KER SBE A SSY I -1 9-5/8" x 5-1/2" BA KER FB-1 PKR I 8085' -15-1/2" X 4-1/2" XO I 8165' 8165' 8176' 8177' 8179' -14-1/2" HES PXN PLUG (07/04/06) -14-1/2" OTIS XN NIP, ID = 3.725" I 1-14-1/2" BAKER SHEAROUT SUB -14-1/2" TUBING TAIL I H ELMD TT LOGGED 06/30/90 I PRUDHOE BA Y UNIT WELL: NGI-06 PERMIT No: '1760290 API No: 50-029-20206-00 SEC 12, T11N, R14E 1217.37 FEL 3791.89 FNL BP Exploration (Alaska) TREE= · W8..LHEAD= ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum IvIJ = DatumlVD= CW Iv1cEvoy AXELSON 47' ? 4700' 42 @ 7600' 9842' 8800' SS NGI-06 Proposed 113-3/8" CSG, 72#, MN-80, D = 12.347" I 9-5/8", 47#/ft, L-80 TC-II Fully cemented to surface from original TOC in OA Min"ID = 5,,770" @ -8110' 7" HES "RN" NIPPLE 17-5/8",29.7#, L-80, VamTop He, IPC (TK-7) TOPOF7" LNR 19-5/8" CSG, 47#, MN-80, ID = 8.681" I PERFORA TION SUMMA RY REF LOG: BHCS ON 04/28/79 ANGLEATTOPÆRF: 37 @ 8894' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8894 - 8950 C 06/30/90 3-3/8" 4 8999 - 9002 C 05/02/87 3-3/8" 4 9009 - 9028 C 05/02/87 3-3/8" 4 9036 - 9237 C 05/02/87 3-3/8" 4 9242 - 9282 C 05/02/87 3-3/8" 4 9289 - 9299 C 08/06/78 3-3/8" 4 9322 - 9376 C 05/02/87 3-3/8" 4 9387 - 9415 C 05/02/87 3-3/8" 4 9419 - 9434 C 08/06/78 3-3/8" 4 9460 - 9469 C 08/06/78 3-3/8" 4 9473 - 9479 C 08/06/78 ¡PBID I 9412' 17" LNR, 29#, N-80, .0371 bpf, 10 = 6.184" H 9580' DATE 05/05176 02/07/88 07/17/01 08/23/02 07/04/06 REV BY REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER RI'VrP CORRECTIONS JBfTP CHANGEXNNIPDSIZE GJF/PAG SET PXN PlUG DATE COMMENTS H7" CAMeO DB-6 NIP, ID = 6.000 I H7" HES "R" NIP, 5.963"10 I -i 9-5/8" x 7" BAKER S-3 PKR 1-17" HES "RN" NIP, 5.770"ID I PRUDHOE BA Y UNIT W8..L: NGI-06 ÆRMIT No: "1760290 API No: 50-029-20206-00 SEC 12, T11N, R14E 1217.37 FEL 3791.89 FNL BP Exploration (Alaska) 5 ~ ~~ ~~ v lr ,._.7 Y-9 L1 ~Y 'y t 3 3 ~ "s P`t f.-. CO1~T5ER~~ ATIO CO1~II IIS5Ip1~ August 18, 2006 /f Y ~/~ FRANK H. MURKOWSK/, GOVERNOR l~ I 333 W. 7'" AVENUE, SUITE 700 1 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 Ms. Anna Dube, WeII Integrity Coordinator ,, ba"~ BP Exploration (Alaska) Inc. ~ n Attn: Well Integrity Engineer, PRB-24 1 P.O. Box 196612 Anchorage, AK 99519-6612 RE: Cancellation of Administrative Approval AIO 04E.005 (Well PBU NGI-06) Dear Ms. Dube: Pursuant to BPXA's request dated August 12, 2006 AOGCC hereby cancels Administra- tive Approval AIO 04E.005, which allows gas injection in well PBU NGI-06. This well exhibited IA x OA pressure communication, and BPXA did not at the time propose re- pairing the well to eliminate the problem. The Commission determined that gas injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. Since then, BPXA has determined that PBU NGI-06's condition has deteriorated to the point that safe operation is no longer supported. The well is shut in awaiting a rig work over. Consequently, Administrative Approval AIO 04E.005 no longer applies to opera- tion of this well. Instead, injection in well PBU NGI-06 will be governed by provisions of the underlying Area Injection Order No. 4E. ~~~ JAN ~ 200 Cathy oerster, Co ssioner Chairman Commissioner~af~~ ~~TT ~~11 p~-~at7~~~~y ®~ ~~~a ADldINISTR.ATIVE APPI~®VAL, 4E.005 y1r. Steve Rossberg Vti'eIls Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99~ 19-6612 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 RE: PBU NGI-06 (PTD 176-029} Request for Administrative Approval Dear IVfr. Rossberg: Pursuant to Rule 9 of Area Injection Order ("AIO") 04E.000, the Alaska Oil and Gas Conservation Commission (`'AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue gas injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU NGI-06. The Commission further finds that the well exhibits slow IA x OA pressure communication, that can be safely managed with infrequent pressure bleeds. However, the Commission acknowledges that events such as SSSV control Line failures may allow the well's tubing pressure to communicate with the IA. Accordingly, the Commission be- lieves that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety, if the well's operation is subject to the con- straints enumerated below. AOGCC's administrative approval to continue gas injection in PBL7 i`iGI-06 is condi- tioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates, and shall flag the w-ell's periodic pressure bleeds on the report; FR,(~PlK fd. fl/lURPC0~1SiCl, GOI/ERMOR 3. BPXA shalt perform anMIT - IA every four years to the maximum anticipated injection pressure, the anniversary date of which shall be this approval's effective date; _'~ir. Steve Rossberg May 31, 2006 Page 2 of 7_ • 4. BPXr1 shall limit the well's OA pressure to 1000 psi: ~. SPXA shall install and operate remote pressure monitoring equipment on the well's OA; 6. BPXA shall immediately shut in the well and notify the _=~OGCC if there is any change in the well's mechanical condition; and 7. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection. As provided in AS 3I.0~.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Done at A Drag ,Alaska and dated May 31, 2006. /'-~ JJ i '~~iy r / / ~~ 1 'orman Dan T. Seamount Cath . Foerster ha an/ .Commissioner Commissioner r ° ' ~: r, ;~,,,: MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ..--, I ") ('...., , '~¡"') I....... fJ,¡";' 'I f ,":) L." "V¡"I " ~ DATE: Tuesday, July 25, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORA,TION (ALASKA) INC NGI-06 PRUDHOE BAY UNIT NGI-06 \1(,./orCi FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: ".--::~.;? P.I. Suprv '- \ b¡::;:-- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT NGI-06 API Well Number 50-029-20206-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060714063938 Permit Number: 176-029-0 Inspection Date: 7/13/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i NGI-06 'Type Inj. I N !TVD 1 8066 ! IA ! 20 I 4300 ! 4280 ! 4240 ! 4230 i 1 ! i ! I 1760290 ¡TypeTest I SPT ! Test psi I ¡ ¡ I P.T. 2016.5 OA 0 4300 ! 4240 4200 4190 ~ I I i ¡ I I Interval REQVAR P/F F Tubing I 2000 i 2200 2200 I 2180 i 2180 I I Notes This well has rapid IA x OA communication either through the packoff or very near surface. Fluid could be heard entering the OA while pressuring the IA. ~[:;4 .~~~.¡.;;;.r; ytrf,íJ\h,\;\¡j,., ..; r,j Tuesday, July 25, 2006 Page I of I Re: WGI-06 (PTD # 1900300) Slow IA Repressurization e e Pm.¿ Iff, --OLD¡ BP notified the Commission about varying degrees of pressure communication affecting 6 PBU gas injectors. Wells are: AGI-06¡ TxIA NGI-01¡ TxIA NGI-06¡ IAxOA NGI-10¡ IAxOA NGI-13¡ TxIA WGI-06¡ TxIA BP intends no repairs to correct the pressure communication, instead relying on human intervention to manage the pressures. The correct mecha~ism for reviewing continued operation of these wells is the administrative approval process under AIO 4D Rule 9. Please submit admin approval requests to the Commissioner's attention. Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Hello Jim and winton. Well WGI-06 (PTD # 1900300) is exhibiting indications of pressure communication between the tubing and IA, as noted on the attached TIO plot. An MITIA on 6/15/03 passed to 2500 psi. The field Operators safely manage this repressurization by bleeding the IA pressure approximately once every 30 days. This pressure management maintains the IA pressure below BP's maximum allowable annular surface pressure limit of 2000 psi. Current plans are to continue gas injection operations. No repairs are planned at this time. Attached is a TIO plot and wellbore schematic. Please call with any questions. «WGI-06.pdf» «WGI-06 TIO Plot.jpg» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 Email: NSUADWWellIntegrityEngineer@bp.com ~~~~~~-=~§Y!:\.PYJ_ì'!~~~_£r:.~~9Egï~?9i!:l~~E~ÞE:<::~n~.? 1 of 1 3/24/2006 9:36 AM NGI-06 (PTD #1760290) OA Repressurization e e Hello Jim and Winton. Well NGI-06 (PTO #1760290) is exhibiting indications of pressure communication between the IA and OA, as noted on the attached TIO plot. An MITIA on 8/23/05 passed to 2200 psi. The field Operators safely manage this repressurization by bleeding the OA pressure approximately once every 13 days. This pressure management maintains the IA and OA pressures below BP's maximum allowable annular surface pressure limits of 2000 psi and 1000 psi respectively. Attached is a TIO plot and well bore schematic. Please call with any questions. L0~y.d--- ~ S(j.).J(,e òf- rssa re \ Ä. . . 7 54- ð Current plans are to continue gas injection operations and no repairs are planned at this time. «NGI-06.pdf» «NGI-06 TIO Plot.jpg» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllnteqrityEnç¡ineer@bp.com ,,' Content-Description: NGI-06.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: NGI-06 no Plot.jpg TIO Plot.jpg Content-Type: image/jpeg Content-Encoding: base64 1 of 1 3/20/2006 10:35 AM TREE = GRAY GEN2 I I WELLHEAD = GRAY NGI-06 SAFETY NOTES: AC1UATOR= AXELSON KB. ELEV = 47' BF. ELEV - ? KOP- 4700' Max Angle = 42 @ 7600' . Datum MO = 9842' H 2177' T' CAMeO BAL-O SSSV NIP, ID = 5.937" Datum ND= 8800' SS 113-3/8" CSG, 72#, MN-80, ID= 12.347" 2663' µ ~ -> Mktp ~ 538ûps ¡ Co! ¥9Z.. ~ Lb"70 psI Minimum ID = 3.75" @ 8165' I 41/2" OTIS XN NIPPLE 7"TBG-NPC, 29#, L-80, 0.0371 bpf, ID=6.184" I 8058' I- ITOP OF 5-1/2" TBG-NPC 8058' -H 8058" 7" X 5-1/2" xo I I J I I 8065' 5-1/2" BAKER SBE ASSY I 5 ~~ ---i 8066' 9-518" x 5-1IZ' BAKER FB-1 PKR 1 15-1Iz' TBG-NPC, 17#, L-80, 0.0232 bpf, D =4.892" I 8085' ITOPOF 4-1/2" TBG-NPC 8085' 5-1/2" X 401IZ' XO 1 8085' I I TOP OF 7" LNR 8123' r-I I I . 8165' 4-1/2" OTIS XN NIP, D = 3.725" I I 8176' H 4-1/2" BAKER Sl-EAROUT SUB I 4-1/2" TBG-NFC, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 817T 817T 4-1/2" TUBING TAIL 1 19-518" CSG, 47#, MN-80, ID = 8.681" I 8464' ~ ~ I 8179' H ELMO TT LOGGED 06130/90 I ÆRFORA llON SLMMARY L-y JvUt{ P =: 69J 7ÜfS,' REF LOG: BHCS ON 04128/79 ] Cet lqpse- z- 415Ör5; ANGLEA TTOP PERF: 37 @ 8894' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE ] 3-3/8" 4 8894 - 8950 0 06/30/90 3-3/8" 4 8999 - 9002 0 05/02187 3-3/8" 4 9009 - 9028 0 05/02187 3-3/8" 4 9036 - 9237 0 05/02187 3-3/8" 4 9242 - 9282 0 05/02187 3-3/8" 4 9289 - 9299 0 08/06/78 3-3/8" 4 9322 - 9376 0 05/02187 3-3/8" 4 9387 - 9415 0 05/02187 3-3/8" 4 9419-9434 0 08/06178 3-3/8" 4 9460 - 9469 0 08/0617 8 3-3/8" 4 9473 - 9479 0 08/06/7 8 RHD 9412" I 7" LNR, 29#, N-80, 0.0371 bpf, ID= 6.184" 9580' I I)A. TE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY lJ'o rr 05105/76 ORIGINAL COMPLETON WELL: NGI-06 02107/88 LAST WORKOVER PERMT 1'«>: 1760290 01/11/01 SIS-CS CONV ERTED TO CA NIl AS AA No: 50-029-20206-00 01/26/0 1 SIS-LG REVISON SEC 12, T11N, R14E 1217.37 FEL 3791.89 FNL 07/17/01 RNITP CORREC1lONS 06123/02 JB/ìP CKð. NGE XN NIP D SIZ E BP Exploration (Alas ka) MEMORANDUM TO: ~f1 q 1/3/0<; Jim Regg P.I. Supervisor FROM: John Crisp Petroleum Inspector Well Name: PRUDHOE BAY UNIT NGI-06 Insp Num: mitJCr050825 110522 Rei Insp Num Packer - Well NGI-06 [Type Inj. --.-.-.-.-,---..-- .._---.- .. - _,~~.!~__~760290 ITypeT!_~,!. Interval 4~!_S:~__ P/F Notes 3 bbls pumped for test P ------.----_..- ""._-" --- Tuesday, August 30, 2005 State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 30,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-06 PRUDHOE BA Y UNIT NGI-06 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-20206-00-00 Permit N urn ber: 176-029-0 Depth Pretest Initial 15 Min. 7426 '----T-------', 'I 2220 2210 i IA ~ 220 : 1856,5 "lOA 80 I 80 80 Tubing 3500 3500 :' ,"',. .:, ' .' , . . ì" t.. E ~I) ('~ q f 0 P j;" .....~. 1' '~ kl\~!\\E:., .) ,-" -; (, ';; c_ ,J,,' '~;." '~I 'J 't~ ,J ~ ~ "'1 ,~ ~'.... ,\.r!i... JI ¡; ~'" ,I . ) \ 1 G7.1 0 ~ Reviewed By: -(p/J P.I. Suprv..... jJ)!~ Comm Inspector Name: John Crisp Inspection Date: 8/23/2005 30 Min. 45 Min. 60 Min. 2205 _.:_..~~[-=--== 80, I 3500! --I' ..__..._._._...~_~,__,.,L..,._______,_.J..____,,_ Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser Commissioner THRU: Tom Maunder P.I. Supervisor FROM: Jeff Jones Petroleum Inspector DATE: August 20, 2001 SUBJECT: Mechanical Integrity Tests BPX NGI Pad NGI-06, 07, 08, 10, 12 PBU PBF NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. walI ~i(~lm ITypelnj. I (~ I T.V.O. 1742S I Tubingl 345O '1 34~0 '1 34s0 I '34,~ li.t~a~l 4 "~T,D,i ~'Ts0~0 IT~et~l P IT~.~I ~.7 I Ca~r~l ~ I ~0.~0 I ~ I,~000 I "~ I -" Hales: Pre-test pressures monitored 30 minutes & stable. , ...... wall N~l-07 I T~,e~n~.l s I T.V.D.'I 7398 ITuUngl 3300 ! 3300 I 33OO133o0 I I.l~vall 4. ' .P.T,D.I ~7s0380 IT~,et~! P IT--t,~il ~.. l Ca~"~l ~0 I20,10I ~o~0. I ~o~o I Pa: ! -" Notes: Pre-test pressures monitored 30 minutes & stable. ,w,~'l "~'~ I T'"e'nJ'l ~'1 T.V.O. i ~.~ ITu~.~l ~00 '1 ~00 I ~ I~°° I'"'~'1'4 ,. P.T.D.I 1760520 IT~pete~tl P IT'~t~.'l, !855' ICasingl'110 I 2015 I .2O20 120~S I'P~F I' E' Holes: Pre-test pressures monitored 30 minutes & stable. ' We.I :NGl~'~:0 I Typelnj. I (~ '1T.V.D.I7327'lTubin9 I' 3400I 3,mo I 3,mol 34oo I~nt'""ql4" P,T.D.I 1760690 ITypet~! P IT=~I ~-= I c.a~ir~l 28o I 20~0, I 20'z0 I 2= I,, PA: I _Pi Notes: Pre-test pressures monitored 30 minutes & stable. . . . w~'i "°'~= I~";e'"~'l ~ I~'v'°' I ~=" I'u="~l ~°1 ~1 ~01 ~o I,...v=,l 4 P.T.D:I ~770a~0 ITypetestI P' IT~p~iI ~S'~ I Casingl 54O I 2040,1 2000 I 2000, I P~ I _P Notes: Pre-test pressures monitored. 30 minutes & stable. . . Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Suney D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required byVariance W-- Test during Workover O= Other (describe in notes) Tsst's Details Monday, AuRust 20~ 2001: I traveled to BPX's NGI Pad to witness 4 year MIT's on wells NGI-06, NGI-07, NGI-08, NGI- 10 and NGI- 12. Scott Lyon (BPX representative) performed the tests today. The pre-test pressures were monitored for 30 minutes and observed to be stable. All five wells passed the ~T's and are suitable for continued injection. Summary.: I witnessed 5 successful MIT's at BPX's NGI Pad in the Prudhoe Bay Field. M.I.T.'s performed: 5_ Number of Failures: 0 Total Time during tests: 3.S hm. Attachments: CC:. MIT repOrt form 5/12/00 L.G. MIT PBU NGI-06,07,08,10,12 8-20-01 JJ.xls 8127/01 STATE OF ALASKA ALASK~ AND GAS CONSERVATION C(~"~IlSSiON REPORT SUNDRY WELL OP -]ATIONS 1. Operations performed: Operation shutdown Stimulate ~ Plugging .... Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 332' FNL, 1014' FWL, Sec. 12, T11N, R14E, UM At top of productive interval 1264' FSL, 980' FEL, Sec.2, T11N, R14E, UM At effective depth 1452' FSL, 1185' FEL, Sec. 2, T11N, R14E, UM At total depth 1488' FSL, 1220' FEL, Sec. 2, T11N, R14E, UM 5. Type of Well Development Exploratory . Stratigraphic Service X 6. Datum of elevation(DF or KB) 47 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number NGI-6 9. Permit number/approval number 76-92/90-298 10. APl number 50 - 029-20206 11, Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9585 feet Plugs(measured) true vertical 8617 feet Effective depth: measured 9479 feet true vertical 8533 feet ~'±11(measured) 9479' Casing Length Size Cemented Measured depth True vertical depth Conductor 67' 20' 240 sx AS 80' 80' Surface 2646' 13-3/8" 6100 sx PF II 2668' 2668' Production 8442' 9-5/8" 750 sx CIG & 155 sx PF II 8464' 7730' 155 sx PF II Liner 1457' 7" 360 sx CIG 8123-9580' 7469-8613' Perforation depth: measured 8894-8950'; 8999-9202'; 9009-9028'; 9036-9237'; 9242-9282'; 9289-9299'; 9322-9376'; 9387-9415'; 9419-9434'; 9460-9469'; 9473-9479' true vertical 8070-8109'; 8143-8145'; 8151-8166'; 8172-8333'; 8337-8369'; 8375-8383'; 8402-8445'; 8454-8477'; 8480-8492'; 8513-8521 '; 8524-8529' Tubing (size, grade, and measured depth) 7"/4-1/2", L-80 tbg w/tail @ 8177' MD Packers and SSSV (type and measured depth) FB-1 pkr @ 8066' & Bal-0 SSSV @ 2177" MD 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) Treatment description including volumes used and final pressure Prior to well operation Representative D~ilv Average Produ~ion or Ini~tion Data Refe~eace OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tub~ag ~essu~e - - 236M - - 0 3900 Subsequent to operation 236M - - 0 3900 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Gas Injection 17. I hereby ce~ thee foregoing is true and correct to the best of my knowledge. Signed 7.-~ ~ Title Senior Area Engineer Form 10-4b¢4 ReV 06/15/88 ~- Date SUBMIT I!~ DUPLICATE NGI-6 Work Summary On June 30, 1990 the following perforations were added in Well NGI-6. Interval, MD Interval, MD (BHCS 4/28/76) (Tie-In) 8894-8950' 8894-8950' Interval Length Formation Name SPF 56' Sag River 4 ARCO ALA3'KA: t~NC~ P.O. BOX ANCHORAGE ALA~'KA °':'~' i ,"-~ DA TE · '7-'7- 9¢, REF'ERENCF' ARCO CA~::ED HOLE F-"INAL,~,': ,x~, G .1; -- i 6 -.-..... '-~ 8 .--- 9 ,":,... C O. L t_ A R / P E R F' R U N i: ..,':".'" NG.I..-..Z 6 .... 28-9,:?,, COLLAR/F'ERF-' F;:tJN i , 5" i'..~G I - 3 6 - '::' ':;' -. '::;' ,':~ COLL. AR,/F:'ERF RLtN i '":" · '- - :-- · · ;: . ,, ,i .,.:' NF:. :[ -4 6 .... 29-9,::) I":I"iLJ AR,."F'E~:F RIjN 'i ':"" ~ ', '.,~ .... l... , , ,~ .,,:, NG I-6 6--5':.~,--9(i.~ C'OLLAR/F'ERF RLIN i , ..,.':~'" NGI'-7 7-i'-9~3 COI_LAR/F'ERF RUN i , 5" NC-; I--8 7-i ... c-_.,,.:,, ... F:OLL~R/F'ERF... F;..' IJ i",~. i , ..,."""" NG:[-9 7"-2'-"i.'-:'":",.~ COLLAR/F'ERr-' PUN i., .~':"" N(:.;.]: .... i ,:.:) 7-.,':.~.--9(:, COLLAR/F'ERF RL1N i , .5:" F'LEA::.:'E :~'IGN AND F:ETURN THE A'FTA~F'Y AZ RECEIF'F 01-- DATA, HAVE A NICE DAY! :']'ALLY HOF'FECKER A'FO- i 529 1990 · z - · ,' '" ' :;'F'IV .~~.,.....:_" Co.s. Comm " k[:Af'- ,, F A/Ichoi'ag8 iq;..' ~ N ~.;' :. 9,~,2 ';:' 2 r::~ i"!... A Z r::', i" L. A Z A 'F L. A 5' A'I' i... ,':~ ;i':,' A'FL_A:? DTS'TRIBUT~'ON., ,. C:F_"N TRAi_ F- I I_E:~' C' H E V R 0 N .11. ', ,' · ,,. E,,, i" E N.? i Oi'-~ EXPLORATION EXXON MARATHON · ,- MOBTL · ,- F'H I L L I e,,:,'::' F'B WELl.. F'ILE~-? Iq:& D ~ BPX :~- 5'TATE OF ALA:~'I<A TExAco STATE OF ALASKA ALASK~-"~ AND GAS CONSERVATION (~'~-'~IISSION APPLICAI iON FOR SUNDRY API-'ROVAL0 1. Type of Request: Abandon :1 ,~ ' ~Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 332' FNL, 1014' FWL, Sec. 12, T11N, R14E, UM At top of productive interval 1264' FSL, 980' FEL, Sec. 2, T11N, R14E, UM At effective depth 1452' FSL, 1185' FEL, Sec. 2, T11 N, R14E, UM At total depth 1488' FSL, 1220' FEL, Sec. 2, T11N, R14E, UM operation shutdown Re-enter suspended well . Plugging Time extension Stimulate Pull tubing Vadance Perforate X Othe'r 5. Type of Well 6. Datum of elevation(DF or KB) Development 47 RKB Exploratory Stratigraphic 7. Unit or Property Set, ce x Prudhoe Bay Unit 8. Well number NGI-6 (44-2-11-14) 9. Permit number 76-29 10. APl number 50 - 029--20206 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured RECEIVE?, 9585 feet Plugs(measured) true vertical 8617 feet Effective depth: measured 9500 feet !~.~,~ ;' 0 3 lJ9~!-~I true vertical 8548 feet Junk(measured) ,~\.J~$k.~ 0JJ & Gas ConS, C0mmissi0~ Casing Length Size Cemented Measured cl~::)ral~i~Je vertical depth Conductor 67' 20" 240 sx AS 80' 80' Su dace 2646' 13-3/8" 6100 sx PF II 2668' 2668' Production 8442' 9-5/8" 750 sx CIG & 155 sx PF II 8464' 7730' Liner 1457' 7" 360 sx CIG 8123-9580' 7469-8613' Perforation depth: measured 8999-9002'; 9009-9028'; 9036-9237'; 9242-9282'; 9289-9299'; 9322-9376'; 9387-9415'; 9419-9434'; 9460-9469'; 9473-9479' true vertical 8143-8145'; 8151-8166'; 8172-8333'; 8337-8369'; 8375-8383; 8402-8445'; 8454-8477'; 8480-8492'; 8513-8521 '; 8524-8529' Tubing (size, grade, and measured depth) 7"/4-1/2", L-80 tbg w/tail @ 8177' MD Packers and SSSV (type and measured depth) FB-1 pkr @ 8066' & Bal-0 SSSV @ 2177" MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation .~: May 1990 16. If proposal was verbally approved Oil Name of approver Date approved Service 17. I hereby certify that.t,he foregoing is true and correct to the best of my knowledge. Signed 4;~~~~ Title Operations Engineering Manager 15. Status of well classification as: Gas Suspended gas injection FOR I~OMMI~ION H~l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- YO¥ Approved by order of the Commissioner Orlglnal ~'"'~'~ David W.. Form 10-403 Rev 06/15/88 .... ~C~.~ssioner App~ '-'""'" %-' ' Returnee J Approval No. ~ ~ -. ~ ~; d~ SUBMIT IN TRIPLICATE NGI-6 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations in Well NGI-6. The proposed perforation intervals are as follows: Interval, MD Interval, MD Interval Formation (BHCS 4/28/76) (Tie-in) Length Name 8872-8888' 8872-8888' 16' Put River 8894-8950' 8894-8950' 56' Sag River A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized for this work. All perforations will be made with hollow carrier type guns at 4 shots per foot. All perforations will be made with the wellbore loaded with sea water. After perforating, gas injection will resume with the wellbore load fluid being displaced into the wellbore formation. No flaring is anticipated. ARCO Alaska, Inc. ~ Prudhoe BaY Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager January 27, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS NGI-6 Approval No. 8-892 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JCB/jp At t a chment CC: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS NGI-6)W1-3 detailing work per- RECEIVED AJa$ .ka DJ! & Gas ~n~ C0mm/ssi0~ WELLS3/101 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C .," ~- '- ~--~ STATE OF ALASKA AL, ~. OIL AND GAS CONSERVATION COMML )N - REPORT OF SUNDRY WELL OPERATIONS 1. Ope~at'i'°ns performed: Operation shutdown _._ Stimulate ~ Plugging ._.. Pedorate Pull tubing ._. Alter casing __ '2.' Name of OPerator ' ARCO Alaska, Inc. 3. Address 1:'. O. Sox 100360, Anchorage, AK 99510 4. Location of well at surface 332' FNL, 1014' FWL, Sec. 12, TllN, R14E, UM At top of productive interval 1264' FSL, 980' FEL, Sec. 2, TllN, R14E, UM At effective depth 1452' FSL, 1185' FEL, Sec. 2, TllN, R14E, UM At total depth 1488' FSL, 1220' FEL, Sec. 2, TllN, R15E, UM Repair well __ Pull tubing __ Other 5. Type of Well: Development 6. Datum elevation (DF or KB) 47' RKB Exploratory __ Stratigraphic _._ Service ~ 7. Unit.or Prp, perty name ~ruanoe Bay Unit feet 8. Well number NGI-6 9. Permit number/approval number 8-892 10. APl number 50-- 029-20206 11, Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9585 feet Plugs(measured) 8617 feet Effective depth: measured 9500 feet Junk(measured) true vertical feet 8548 Casing Length Size Cemented Measured depth . True vertical depth Conductor 67' 20" 240 sx AS 80' 80' Surface 2646' 13-3/8" 6100 sx PF II 2668' 2668' Production 8442' 9-5/8" 750 sx Cl G & 8464' 7730' 155 sx PF II Liner 1457' 7" 360 sx Cl G 8123-9580' 7469-7730' Pedorationde~h: measured 8999-9202'; 9009-9028'; 9036-9237'; 9242-9282'; 9289-9299' 9322-9376'; 9387-9415'; 9419-9434'; 9460-9469'; 9473-9479' truevertical 8143-8145'; 8151-8166'; 8172-8333'; 8337-8369'; 8375-8383' 8402-8445'; 8454-8477'; 8480-8492'; 8513-8521'; 8524-8529' ~bing(size, grade, andmeasumddepth) 7"/4½", L-80 tbg w/tail @ 8177' MD Packers and SSSV (type and measured depth) FB-1 pkr @ 8066' & Bal-0 SSSV @ 2177' MD 13. Stimulation or cement squeeze summary At tached Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED ,daskA.O~! & Gas Cons. Commissio[t ', '.Anchorage 14. Representative Daily Average ~or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 172M -- 0 3900 Prior to well operation -- 200M -- Subsequent to operation 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run __ ! Daily Report of Well Operations ~ Oil __ Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 06/15/88 3900 Service T~e Operations Engineering Manager Date WELLS3/101 J. C. Braden, 263-45368 SUBMIT IN DUPLICATE NGI 6 12% HCI-3% HF Matrix Stimulation 4 January 1989 ARCO Alaska, Inc. performed the following stimulation treatment: I. The following fluids were loaded: a. 180 b. 300 c. 300 d. 2 e. 140 f. 1 g. 2 00 gal 12% HCI with 15% dispersed xylene and with additives. 00 gal 12% HCl-3% HF with additives. 00 gal 2% NH4Cl water - for overflush of mud acid. 00 bbl hot water (140OF to 150OF) - for first stage hot water wash. 00 gal 2% NH4Cl water gelled with 40 Ibs/Mgal of HEC polymer and containing a foaming agent. 50 bbl of 50/50 methanol/water. 49 MSCF N2 - 229M for foam and 20M for warmup. 2. MI&RU pump trucks, transports and N2 unit. 3. Pumped the following fluids: ~ 200 b. 6000 c. 6000 d. 6000 e. 200 f. k. m. n. O. 2OOO 400O 8000 8000 150 1000 4000 8000 8000 150 p. 1000 q. 4000 r. 8000 s 8000 t. 150 bbl of hot water gal of 12% HCI with dispersed xylene and additives gal of 12% HCl-3% HF with additives gal of 2% NH4CI water bbl of 50 Quality Foam consisting of the following: 4000 gal of 2% NH4Cl water with 40 Ibs/Mgal HEC polymer and foaming agent 115MSCF of N2 injected at 1200 SCF/bbl of 2% NH4Cl water gal of 2% NH4Cl water with 40 Ibs/Mgal HEC polymer and a foaming agent gal of 12% HCl with dispersed xylene and additives gal of 12% HCl-3% HF with additives gal of 2% NH4Cl water bbl of 50 Quality Foam consisting of the following: 3000 gal of 2% NH4CI water with 40 Ibs/Mgal HEC polymer and foaming agent 86MSCF of N2 injected at 1200 SCF/bbl of 2% NH4CI water gal of 2% NH4CI water with 40 Ibs/Mgal HEC polymer and a foaming agent gal of 12% HCl with dispersed xylene and additives gal of 12% HCl-3% HF with additives gal of 2% NH4CI water bbl of 50 Quality Foam consisting of the following 3000 gal of 2% NH4Cl water with 40 Ibs/Mgal HEC polymer and foaming agent 86MSCF of N2 injected at 1200 SCF/bbl of 2% NH4Cl water gal of 2% NH4Cl water with 40 Ibs/Mgal HEC polymer and a foaming agent gal of 12% HCI with dispersed xylene and additives gal of 12% HCI-3% HF with additives gal of 2% NH4Cl water bbl of 50/50 methanol/water 4. RD and released the equipment. 5. Returned the well to injection immediately. ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager November 28, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS NGI-6 Permit No. 76-29 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JMV/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 PI(DS NGI-6)W1-3 RECE IVED NOV ,$ 1 ]ge~~ .0ii & Gas Cons. Commission WELLS2/179 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ~'"~ ALASKa-, OIL AND GAS CONSERVATION COMM,._$1ON 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 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 47' RKB feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 332' FNL, 1014' FWL, Sec. 12, TllN, R14E, UM At top of productive interval 1264' FSL, 980' FEL, Sec. 2, TllN, R14E, UM At effective depth 1452' FSL,. 1185' PEL, Sec. 2, TllN, R14E, UM At total depth 1488' FSL, 1220' FEL, Sec. 2, TllN, R14E, UM 7. Well number NGI-6 (44-2-11-14) 8. Permit number 76-29 9. APl number 50-- 029-20206 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 9585 feet Plugs (measured) 8617 feet RECEIVED Effective depth: measured 9500 feet Junk (measured) NOV 3 ;,) '~9~ true vertical 8548 feet l~liSS[0[[ - . AI~s~ [iii &,Gas Cons. C0,m Casing Length Size Cemented Measured d~.~h ~ch0rag~'rue Vertical depth Conductor 67 ' 20" 240 sx AS 80' 80' Surface 2646' 13-3/8" 6100 sx PF II 2668' 2668' Production 8442' 9-5/8" 750 sx Cl G & 8464' 7730' 155 sx PF II Liner 1457' 7" 360 sx C1 G 8123-9580' 7469-8613' Perforation depth: measured 8999-9002'; 9009-9028'; 9036-9237'; 9242-9282'; 9289-9299'; 9322-9376'; 9387-9415'; 9419-9434' 9460-9469'; 9473-9479' true vertical 8143-8145'; 8151-8166'; 8172-8333'; 8337-8369'; 8375-8383; 8402-8445'; 8454-8477'; 8480-8492'; 8513-8521'; 8524-8529' Tubing (size, grade and~ measured depth) 7"/4½", L-80 tbg w/tail @ 8177' MD Packers and SSSV (type and measured depth) FB-1 pkr @ 8066' & Bal-0 SSSV @ 2177' MD 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation July 1988 14. If proposal was verbally approved Name of approver Subsequent Work BeP°rted (m Form No. - (~~ Dated-J-/~E~t~-~ Date approved 15. I hereby,certify that the foregoing is true and correct to the best of my knowledge Sig.ned ~"~¢"~fd~~ Title Operations Engineering Manager Commission Use Only Date Conditions of approval N otifycommissionsorepresentativemaywitness i Approval No. ~) (¢~/72~, [] Plug integrity [] BOP Test [] Location clearance[ '" ApProved by . 0RI61NAL SIGNED BY LONNIE C, SMITH Approved Copy Returnea ~ Commissioner by order of comm, ,o Submit in triplicate Form 10-403 Rev 124'-85 WELLS2/179 J. M. Vitucci, 265-6358 6 4 2 C0~L£D TUBING UNIT BOP EC)U ! PHI;NT 1. 5000 PSi ?" W[LLH[.AD CONNE:CTOR IrLAhG£ 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" I"IYD~LIC SLIPS 4. SO00 PSI 4 1/6-SHE:AR R~S 5. SO00 PSI 4 1/6" BLIND RAMS 16.$000 PSI 4 1/16" STUFFING BOX H]REL]NE BOP EOU]PHENT 1. 5000 PSI ?" WELLHEAD CONNECTOR IrLANG[ 2. 5000 PSI WIR[LIN[ RAIDS (VARIABLE: SIZE:) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUB[ PACK-Orr NGI 6 12% HCI-3% HF Matrix Stimulation ARCO Alaska, Inc. proposes to perform the following stimulation treatment: 1. Load the following fluids: a. 1 800 0 gal 12% HCl with 15% dispersed xylene and with additives. Concentration specification is 10.5% to 13.0% HCl and less than 300 ppm Fe. b. 30000 gal 12% HCl-3% HF with additives. Concentration specification is 10.5% to 13.0% HCl, 2.4% to 4.0% HF and less than 300 ppm Fe. c. 30000 gal 2% NH4Cl water - for overflush of mud acid. d. 200 bbl hot water (140OF to 150OF) - for first stage hot water wash. e. 1 4000 gal 2% NH4CI water gelled with 40 Ibs/Mgal of HEC polymer and containing one of the following foaming agents: B J/Titan Dowell Halliburton FAW-16 at 5-10 gal/Mgal F75N at 3-5 gal/Mgal Pen-5 at 1% by volume f. 150 bbl of 50/50 methanol/water. g. 249 MSCF N2 - 229M for foam and 20M for warmup. 2. MI&RU pump trucks, transports and N2 unit. 3. Pump the following fluids: ~ 200 b. 6000 c. 6000 d. 6000 e. 200 f. k. m. n. O. 2000 4000 8000 8000 100 2000 4000 8000 8000 100 bbl of hot water gal of 12% HCI with dispersed xylene and additives gal of 12% HCl-3% HF with additives gal of 2% NH4Cl water bbl of 50 Quality Foam consisting of the following: 4000 gal of 2% NH4Cl water with 40 Ibs/Mgal HEC polymer and foaming agent 115MSCF of N2 injected at 1200 SCF/bbl of 2% NH4Cl water gal of 2% NH4Cl water with 40 Ibs/Mgal HEC polymer and a foaming agent gal of 120/o HCl with dispersed xylene and additives gal of 12% HCl-3% HF with additives gal of 2% NH4Cl water bbl of 50 Quality Foam consisting of the following: 2000 gal of 2% NH4Cl water with 40 Ibs/Mgal HEC polymer and foaming agent 57M$CF of N2 injected at 1200 SCF/bbl of 2% NH4Cl water gal of 2% NH4Cl water with 40 Ibs/Mgal HEC polymer and a foaming agent gal of 12% HCI with dispersed xylene and additives gal of 12% HCI-3% HF with additives gal of 2% NH4Cl water bbl of 50 Quality Foam consisting of the following 2000 gal of 2% NH4CI water with 40 Ibs/Mgal HEC polymer and foaming agent 57M$CF of N2 injected at 1200 SCF/bbl of 2% NH4Cl water p. 2 O0 0 gal of 2% NH4Cl water with 40 Ibs/Mgal HEC polymer and a foaming agent q. 4 0 0 0 gal of 12O/O HCl with dispersed xylene and additives r. 8000 gal of 12% HCl-3% HF with additives s 8 0 0 0 gal of 2% NH4Cl water t. 150 bbl of 50/50 methanol/water 4. RD and release the equipment. 5. Return the well to injection immediately. 6. Note the injection rate, pressure and temperature on the wireline report. STATE ANNULUS TESTING DATABASE FOR PRUDHOE/LISBURNE INJECTION WELLS tO&9 AHNULAR TESTS TU~IHG PACKER TEST LAST TEST ~NEI. L ANNULUS FLUID _ SIZE MD'/TVD' CASING PRESS. D~TE Il I -- -- I I Ill , Ill ' I -- I I ~ Ill Il ' I ~Jll -- IIIIII ' ..... ~ -- III L I -- -- ,~.6 / ~_ht~_. dies~ + 10.4 CaCI2 5-$,r2..".. !_0.487_/.7.834 .9-5,,'B', 47#, kiN-e0 .... 15.0.0 . 1./8/88 -- ..12.2 "' t:)iesei. . ..... _7.: ........... 1167.3t6464 9-5/8", __47#, L-80 3064 2,/28./88' )~.~.~,~, .~ _~.~_..~_~.~:,,.s.S,.N,~ ~ s-~2'.... s. ooo~.s3~4 ...~.:s~=, .4.7,#, L-m) _ 2sos ~/~ 9-18 51 ~ d-'~-'~, +,, ,6,.5 NaCI... 87_05:B4.82 . ~. ..9:.. 5/8',. 47#, L-~._. NS. CC to 221~, N-.BO. ILo_7064' 2493 = 3/30/88, . is- 16 "~ 7s ~, di,~ + 8.6.._~ 5:!./2' .ge26./.e4,3. s ,,.9-5m', 47;i, L-BO _ 2423 .., 3/8./_88 · ,,_ 1_:;-10 '~ D'__~..~_=L ...... .. 2:7/8' ..956.9..!8..575 9-5./8', 47#, L-BO 3t04 . ~/.6./86. ........... - !_~__.~.$.~..~, ~ ~ ....... ~. + e.s.~.a~... .r 3' ~ /2' ...... !O.293."a5.35 .7'S~.',...29..?#' L'SO 2~,.O.a..3/.~./"S ... _ L~...24./ ,:' .C.r'~'~'~- ........... 2-?,,a: . es.40/,~..o$. ..... ~-,~.-,... 47#., L-sO. ............... 2e'~.5, _ NG;.~=, 51 ~d' ,te~ ,+ 9.4 N:=Ci 7" ...... 8066/7426 9-518,, 47#, IdN..80 1950 2/8/,88° 5-1,'2' below Page 8 Revised 4,~14/88 ~ ~ STATE OF ALASKA ~ ~ ' ALASKA'uiL AND GAS CONSERVATION CL,,~MISSION W_ELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ~ GAS INJECTOR 2, Name of Operator 7. Permit Number ARCO Alaska, Inc. 76-29 3. Address ~ 8. Apl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20206 4. Location of well at surface 9. Unit or Lease Name 332' FNL, 101/+' FWL, Sec.12, TllN, R14E, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1264' FSL, 980' FEL, Sec. 2, TllN, R14E, UM NGI-6 At Total Depth 11. Field and Pool 1488' FSL, 1220' FEL, Sec. 2, TllN, R14E, UM Prudhoe Bay Field ' I 5. El'ovation in feet (indicate KB, DF, otc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i l Pool RKB /+7' ADL 28302 1 ~. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 1 ~. No. of Completions 04/09/76 04/28/76 05/05/76~ N/^ feet MS L 1 9585'MD, 8617'TVD 9500'MD, 8548'TVD YES ~ NO [] 2176' feet MD 1900' (approx) ,, 22. Type Electric or Other Logs Run D IL/SP, BHC/GR, GR/VDL/CBL, GR/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED ZO" 94# U-40 Surf 80' 32" 240 sx AS cmt 13-3/8" 72# MN-80 Surf 2668' 17-1/2" 6100 sx PF II 9-5/8" 47# MN-80 Surf 8464' 12-1/4" 750 sx Class G & 155 s~ PF II 7" 29# L-80 8123' 9580' 8-1/2" 360 sx C1 ass 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 (MD) See attached sheet 7"/4-1/2" 8177' 8066' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See Sundry Notice d~ted 8/14/78 for fracture data. 27. PRODUCTION TEST Date First Production Method of Operation (Flowing,. gas lift, etc.) inject i on Date of Test Hours Tested pRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-oIL RATIO 10/77 24 TEST PERIOD I~ 0 100,000 MS£ F/D 0 N/AI N/A , 'ii~'ject. " Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 4300 -- 24-HOUR RATE ~ 0 100,000 MSC F/D 0 N/A ~ 28.' ' " CORE DATA Brief description of lithology, porosity, ~ractures, apparent dips and presence of oil, gas or wate r. Submit core chips.I EI2ElYED ~one .... MAR 0 .~ !988 Alaska 0il & Gas Cons. Comm~lori Anchorage WNote: Workovers performed 11/15/76, 1/10/77, 7/28/78 & 2/7/88. Perforated well 12/16/76, 8/6/78 & 5/2/87. Submit in duplicate(~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE '~ NAMe. " . In~ludetinterval ~ested, pressu're data, all fluids ~ec~vered'~b'd ~avitY, ' MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochtt 8979~ 8131 ~ N/A Base Sadl erochi t 9505 ~ 8552 ~ 31. LIST OF ATTACHMENTS Non~ 32. I hereby certify that the fo'~goi~g'is ~:u~"a~d correct to the best of m~ knowledge 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 Serv~ce~,~e!ls:'Ga? ~nject~on, water ~nject~on, steam injection, air injection, salt water disposal, water supply fo~ ihj~c{i~n,' °l~servation, 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 s completed for separate prbd~icti0n fro.m: more than one interval (multiple comPletion), so state ih item 16; and in item 24 show theProduCing in'{~'~va'lS for only the interval rffl~O[ted m ~tem 27. Submit a separate form' f~r each ad~l~t~onal ~nterval to be separately produced, shov~Irt~'the data pertinent to such interval. ,.Item 21 :..Ir~licate 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 cem,ent- lng and the location of the cementing tool. I,tem~ 2~7:. MbtflOd of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: I f n o,-.'co re Form 10-407 WELL COMPLETION OR RECOMPLETION REPORT AND LOG NGI-6 Item #24. Perforation depths: Perforated w/4 spf and 2 spf MD TVD ,. 8999 9009 9036 9242 9289 9322 9387 9419 9460 9473 -9002 -9028 -9237 -9282 -9299 -9376 -9415 -9434 -9469 -9479 8143 -8145 8151 -8166 8172 -8333 8337 -8369 8375 -8383 8402 -8445 8454 -8477 8480 -8492 8513 -8521 8524 -8529 WC4/72a 2/23/88 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALAS. OIL AND GAS CONSERVATION COM. SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other I~ W0RKOVER 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360~ Anchorage, AK 99510-0360 4. Location of well at surface 332' FNL, 1014' FWL, Sec.12, T11N, R14E, UM At top of productive interval 1264' FSL, 980' FEL, Sec. 2, T11N, R14E, UM At effective depth 1452' FSL, 1185' FEL, Sec. 2, TllN, R14E, UM At total depth 1488' FSL~ 1220' FEL~ Sec. 2~ T11N~ R14E~ UM 11. Present well condition summary Total depth: measured 9585'MD true vertical 8617 'TVD . Datum elevation (DF or KB) RKB zf7 ' Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-6 (44-2-11-14) 8. Approval number 7-89.~ 9. APl number 50-- 029-20206 10. Pool Prudhoe Bay 0il Pool feet feet Plugs (measured) None Effective depth: measured 9500 'MD true vertical 8548 'TVD feet feet Junk(measured) None Casing Length Size Conductor 67 ' 20" Surface 2646' 13-3/8" Producti on 8442 ' 9-5/8" _ Liner 1457' 7" Cemented Measured depth Rue Vertical depth 240 sx AS 80'MD 80'TVD 6100 sx PF II 2668'MD 2668'TVD 750 sx Class G & 8464'MD 7730'TVD 155 sx PF II 360 sx Class G 8123'-9580'MD 7469'-8613'TVD 12. Perforation depth: measured true vertical 8402 ' -8445 ', 8454 ' -8477 ' Tubing (size, grade and measured depth) 7"/4-1/2", L-80 tbg w/tai 1 ~ 8177' Packers and SSSV (type and measured depth) FB-1 pkr (~ 8066' & Bal-0 SSSV (~ 2176' Stimulation or cement squeeze summarY N/A Intervals treated (measured) 8999'-9002', 9009'-9028', 9036'-9237', 9242'-9282', 9289'-9299', 9322'-9376', 9387'-9415', 9419'-9434', 9460'-9469', 9473'-9479' 8143'-8145', 8151'-8166', 8172'-8333', 8337'-8369', 8375'-8383', , 8480'-8492', 8513'-8521', 8524'-8529' RECEIVED Alasi~a Oil & Gas Cons. Commission Anchorage Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover We~l 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 Signed Form 10-404 Rev. Title Associate Engineer Date (Dani) 5W03/52 Submit in Duplicate ARCO Oil and Gas Company Well History- Initial Report - Dally Instate:tiDal: Prepare and submit the "lflilili RII~H" 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 ARCO Alaska, Inc. Field PRUDHOE BAY Auth. or W.O. no. AS1878 lCounty, parish or borough NORTH SLOPE Lease or Unit APL: ,28302 Title WORKO~R JState NGI-6 JWell no. Operator A~CO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 01/27/88 ( TD: 9585 PB: 9500 SUPV: JH 01/28/88 ( TD: 9585 PB: 9500 SUPV:DL/RS 01/29/88 ( TD: 9585 PB: 9500 SUPV:DL/RS 01/30/88 ( TD: 9585 PB: 9500 01/31/88 ( TD: 9585 PB: 9500 SUPV: DL/RS API: 50-029-20206 Date 01/26/88 ]Hour 0900 IARCO W.I. 22.0000 Prior status if a W.O. Complete record for each day reported WESTWARD RIG 1 MIX HEC PILL MW: 9.7 NaC1 MIRU. ACCEPT RIG @ 0900 HRS 1/26/88. KILL WELL. GIH. PERFORATE TUBING FROM 7867'-7865' AND 7870'-7871' AT 4 SPF. CIRCULATE OUT WELL TO 9.7 BRINE. LOST RETURNS. MIXING HEC PILL. DAILY:S109,894 CUM:$109,894 ETD:S109,894 EFC:$700,000 NU BOP'S MW: 9.4 NaC1 MIX AND PUMP HEC PILLS. WELL STABILIZED THEN WHEN ON VACCUM. TOOK 4.5 BBLS TO PILL. SET BPV. ND TREE. NU BOP'S. DAILY:S120,158 CUM:$230,052 ETD:S230,052 EFC:$700,000 TESTING-BOP'S MW: 9.4 NaC1 SET TREE OFF WELL HEAD. NU BOP'S. TEST 9-5/8" PACKOFF TO 3500 PSI. TEST 13-3/8" PACKOFF TO 2000 PSI. BOTH TESTS GOOD. INSTALL TEST DART. TEST BOP'S. TEST DART WOULD NOT HOLD PRESSURE. PULL SAME AND LOOK AT SEALS. SET DART AND TRY AGAIN. NO SUCCESS. PULL DART AND BPV. PU LANDING JOINT. MU SAME AND TEST UPPER PIPE RAMS AND CHOKE MANIFOLD, KILL AND CHOKE LINES, AND BOTTOM RAMS TO 5000 PSI. DAILY:S45,970 CUM:$276,022 ETD:S276,022 EFC:$700,000 JARRING ON FISH MW: 9.4 NaCl TESTED HYDRIL & KELLY VALVES. REPLACED BOTH MANUAL VALVES ON KILL LINE, TESTED-OK. RU TO PULL TUBING. PULLED BPV. MU LANDING JT. PULLED HANGER FREE. ATTEMPTED TO SHEAR PBR-PULLED 300,000#. RU CAMCO. RIH WITH RETRIEVING TOOL & RETRIEVED SSSV PRONG, POH. RD CAMCO. CHANGED RAMS TO 3-1/2" & TESTED- OK. TIH WITH FTA ~1. CUT DRILLING LINE & SLIP 40'. CONTINUED TO TIH WITH FTA ~1. TAGGED FISH @ 2214' STING IN. JARRED ON FISH. DAILY:S28,650 CUM:$304,672 ETD:S304,672 EFC:$700,000 CHASE FISH TO BOTTOM MW: 9.4 NaC1 JARRED ON FISH. SERVICED RIG. TOH, LD SPEAR, STRAP & NU NEW BHA. TIH ON 3-1/2" DP, MILLED ON FISH @ 2214'. TOH WITH MILL, STRAP & MU NEW BHA. TIH ON 3-1/2" DP. SPEARED FISH @ 2215', JARRED ON FISH. RELEASED SPEAR. TOH & LD SPEAR. MU NEw BHA, TIH & TAGGED PISH. PU KELLY, MILLED ON FISH. FISH FELL THROUGH. SET KELLY BACK, TIH & CHASED FISH TO BOTTOM PICKING UP PIPE FROM SHED. DAILY:S28,750 CUM:$333,422 ETD:S333,422 EFC:$700,000 The above is correct Signature ~ d,~/~,,_,~ For form preparation e~ distribution, see Procedures Manu~l/Section 10, Drilling. Pages 86 and~7. Date ARCO 011 and Gas ComPany Dally Well History--Interim nstr-ctions: This form is used during drilling or workover operations, If testing, coring, or perforating, show formation name in describing work performed. umber all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlsril~" sheets until final completion. Report official or representative test en "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 rcounty or Parish J State NORTH SLOPE J AK 'Lease or Unit ADL: 28302 NGI-6 Field ARCO Alaska, Inc. PRUDHOE BAY Date and deptl~ as of 8:00 a.m. 02/01/88 ( TD: 9585 PB: 9500 SUPV:DL/RS 02/02/88 ( TD: 9585 PB: 9500 SUPV:DL/RS 02/03/88 ( TD: 9585 PB: 9500 SUPV:DL/RS 02/04/88 ( TD: 9585 PB: 9500 SUPV:DL/RS 02/05/88 TD: 9585 PB: 9500 SUPV:SH/JS The above is correct For form preparation and~d~stribution see Procedures Manual ~e~;tion 10, Drilling, Pages 86 and 8~J Complete record for each day while drilling or workover in progress WESTWARD RIG 1 TOH W/7" TUBING MW: 9.4 NaCl TIH, CHASED FISH TO 7853' TOH WITH MILL, CHANGED BHA & TIH WITH CASING CUTTER TO 7836'. BREAK CIRC. & CUT 7" TUBING @ 7836' TOH WITH CASING CUTTER CUTTER DIDN'T OPEN-NO CUT ON TUBING. LD CUTTER & JARS. MU NEW CUTTER. TIH W/CUTTER ON 3-1/2" DP. PU KELLY & CUT TUBING @ 6014.51' SET KELLY BACK, TOH & LD CUTTER. MU LANDING JT. AND VERIFY THAT THE TUBING IS CUT. CHANGED PIPE RAMS FROM 3-1/2" TO 7". TESTED TO 5000 PSI. TOH & LD 7" TUBING AND SPOOLING CONTROL LINE. DAILY:S49,305 CUM:$382,727 ETD:S382,727 EFC:$700,000 TOH W/FISH MW: 9.4 NaCl TOH. LD 7" TUBING & SPOOLING CONTROL LINES. LD SSSV NIPPLE. RD CONTROL LINE SPOOLING UNIT. CONTINUED TOH & LD 7" TUBING. CHANGED PIPE RAMS FROM 7" TO 3-1/2". TESTED PIPE RAMS TO 5000 PSI. RU TO RUN DP. STRAP & CALCULATE NEW BHA. TIH WITH FTA ~7. PU KELLY & STING INTO TUBING WITH SPEAR @ 6018'. PU OUT OF PBR & OBSERVED WELL. TOH WITH FISH. DAILY:S28,650 CUM:$411,377 ETD:S411,377 EFC:$700,000 MILLING PACKER MW: 9.4 NaC1 POH W/FISH. LD TRI-STATE TOOLS. TOH, LD 7" TUBING-TUBING STAYING FULL. RU TO PUMP. ATTEMPTED TO OPEN HOLES IN THE TUBING. UNABLE TO CIRC. CONVENTIONAL BUT WAS ABLE TO REVERSE. TOH LD 7" TUBING (WET STRING). CHANGED BOTTOM RAMS FROM 7" TO 3-1/2" & TESTED. (DOOR SEAL LEAKING) CHANGED DOOR SEALS & TESTED 3-1/2" PIPE RAMS TO 5000 PSI-OK. PULLED TEST PLUG & INSTALLED WEAR BUSHING. STRAP & PU NEW BHA ~8. RIH ON 3-1/2" DP. SLIPPED 40' DRLG LINE. MILLED ON PACKER. DAILY:S50,115 CUM:$461,492 ETD:S461,492 EFC:$700,000 POH W/3-1/2" DP & RTTS MW: 9.4 NaCl MILLED ON PKR. POH WITH MILL. RIH WITH NEW MILL ON 3-1/2" DP. MILLED PKR F/7906.5'-7908'. POH WITH MILL & PKR. RECOVERED 3" OF PKR BODY AND 9.58' SEALBORE EXTENSION (FULL RECOVERY). RIH WITH RTTS ON 3-1/2" DP. TESTED 9-5/8" CASING @ 2820' & 8105' POH WITH 3-1/2" DP & RTTS. DAILY:S28,750 CUM:$490,242 ETD:S490,242 EFC:$700,000 POOH W/3-1/2"'DP MW: 9.4 NaC1 POH WITH RTTS. PU & RIH W/RTTS & FO CLOSING FINGERS, SET RTTS @ 2726'. TESTED FO'S TO 3000 PSI-OK. POH. LD RTTS & CLOSED FINGERS. RIH WITH 6" MILL & BHA. WASHED FILL F/9357'-9500' PUMPED HIGH-VIS PILL. MONITORED WELL. POH. WELL SWABBED IN WHILE MILL WAS ACROSS PERFORATIONS. CIRC. W~LL FOR i5 HiNUiES. CONiibUED POH WiYH 3-i/2~: DP AND hiLL JWell no. Oil & Gas Cons. Anchsr:~ Daily Well History--Interim ARCO Oil and Gas company ~) ~ ~ - m tion name n describln~ work performed, · rkO rations, if testing,.cor'~g, or perfor.atlng,~?_h.?_w, fwoi~t ~. ~e~o.ed o~ "l.~rim" sheets until final . · dr~ttmg or wo, .var ope ores Wor~ ~ermrmed by Produc n~ ~.u.u,, ...... Ire ueml then every 30 days, or (2) I~lt~ctlOal: Th s form ~s used du[*~g ~-~ch descnpt on of.all c .. ~..hm~, I~tlH~" sheets when f ed out but not.l~ss ~ .... Y Number all drill stem tests sequentially. ~.:- "Flail" lotto. [~ ~u-T'- __ ._~ ~..~;n...rune nf oil strin~ until comp]euu-. i n Re o~ oftic al or representative test ~ ~.hm weekl ~or worKover~ a.u .v,,~-,.~ ...... ~ - complet'o · P ~ is s .__ t on Wednesday of the week in which otl string ~.. ~ Field Date as of 8:00 a.m. arish ~oka Inc. ~ SLOPE ARCO Alas[a l~. ~ea~ orUnit ~ ADL: 28302 02/06/88 ( TD: 9585 PB: 9500 SUPV:SH/JS 02/07/88 ( TD: 9585 PB: 9500 SUPV:SH/JS )late record tot each day while drilling or workover m progress WESTWAR___~_DRIG 1 State no, ' ASSEMBLY- DAILY:S63,843 CUM:$554,085 ETD:S554,085 EFC:$700,000 RIH W/7" COMPL. ASSY MW: 9.4 NaCl POOH. MU 9-5/8" FB-1PKR. RIH. SET PACKER ~ 8057' WLM. TESTED TO 3000 PSI. POOH. LD 3-1/2" DP. CHANGED RAMS TO 7" & TESTED TO 3000 PSI. RIH WITH 7", 29%/FT, L-80 COMPLETION ASSEMBLY. DAILY:S31,864 CUM:$585,949 ETD:S585,949 EFC:$700,000 MW: 9.4 NaC1 INSTALLED BPV RIH WITH 7" COMPLETION ASSY (TAIL @ 8177', SSSV ~ 2176', @ 8066'). SPACE OUT. TESTED SEALS TO 2000 PSI. INSTALLED 7" GRAY TUBING HANGER. SPOTTED 2000' DIESEL CAP IN TBE TUBING & ANNULUS. LANDED TUBING. TESTED HANGER SEALS TO 5000 PSI. TESTED ANNULUS TO 3000 PSI. TESTED TUBING TO 3500 PSI. PULLED LANDING JT. INSTALLED BPV. DAILY:S172,674 CUM:$758,623 ETD:S759,123 EFC:$699,500 RECEIVED The above is correct Signature F~r form preparation anl~~is'(ributi°n see Procedures Manual/~ection 10. Drilling, Pages 86 jTitle ARCO Oil and G~s Company Da.y Well History-Final Report Instructione: 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" lorn1 may be used for reporting the entire operation if space is available. District ICounty or Parish NORTH Lease or Unit ,, AD~,: 28302 Title NORKOVER I Accounting cost center cOde Stat~ NGI-6,IWeH no. Field ARCO Alaska, Inc. PRUDHOE BAY Auth. or W.O. nm AS1878 Operator A~CO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 02/08/88 ( TD: 9585 PB: 9500 SUPV:SH/JS 50-029-20206 IA.R.Co. W.I. 22,0OOO JOate 01/26/88 Complete record for each d~y reported WESTWARD RIG 1 Old TD J New TD 1 Released rig J Date I Classifications (oil, gas, etc,) I otal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our J Prtor status if a W,O, I 0900 RELEASED RIG MW: 9.4 NaCl/DIESEL ND BOPE. NO TREE & TESTED TO 5000 PSI. SHEARED OUT SHEAR-OUT SUB. SET BPV. RD CELLAR. SECURED WELL & RELEASED RIG @ 1800 HRS, 2/7/88. DAILY:S34,410 CUM:$793,033 ETD:S793,003 EFC:$700,030 Producing method Potential ~est data IPB Depth Kind if rig JType completion (single, dual, etc,) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gas Test time Production Joil on test Gas per day ,, , , Pum~ size, SPM X length Choke size T P C.P' WaTer % GOR Gravity ,~llowable Elfe;:tive da~e -- corrected _ The above is correct For form preparation Ft~d distribution, see Procedures Manu~[~ SectiOn 10. Drilling, Pages 86 an~'87. JDate JTitle ASSOCIATE ENI31Ni~.R F'. R.. RFIX '1 f)O~AO " ,,---. ANCHORAF.;E . Al .A..~K A 99~-i1 ~ DATE:~ ~-t-RR REFERENCE' ARCO RASED HnI..F FINAl.. COl I. AR/F'FRFRRA'FTON ROI I. AR' ¢ PAP. KFR') CF)I_i. AR" ROI. 1. AR/F"ERFFIRTTFIN FtOI..I.. AR/PERFORATT. ON RFII..I. AR/F'FR'FFIRAT T F}N P. rll..I AR/PF. RFnRAT T. RN 6nl...I . AR/PFRFFIRAT T FIN t'7, FIi ..I... AR/PERFFIRAT T. ON .F:nl. I AR'/F"ERFF1RATTON .C.,O !..!.. AP/I:"ER FE1RA T T ON COl .i.. AR/PERFFIRAT T ON C[}I .I AR/F'ERFORAT I .FIN COl... 1.. AR'/F'FR'FRRA T 'r ON RI'II ..1.. AI-~' / I::' F. fi' Fl] R A T T. r}N ---- l,Jg.T.-4 5-25-87 A CFI, J,,~..AR/PF. FeFORATTFIN F'I.EA,~E Xt~i"J AND 17. ED .? F'E f-. g Y BENNETT AT[]- t 529 TRANX ~ .RRC). 7S APPROVED D]'~TRTDI.ITTON RIJN R'I IN RI IN R'l IN RI.IN R'l IN RI IN RIIN R! IN R'I IN RUN RI IN RI IN Fei IN RI,IN RI IN RECEIPT OF DATA.. 5' 5' 5' .5" 5' DRFXXFR DRF~XFI:? DR~XFR DRtr~FF~ DRF~FR DRF~FR DRI:~ER DRFX~FR DRE~FR DRF~FR CENTRAl_ FTI..EX D & M EXTENXTON FYF't...RRATTON ExYnN MARATHON PH .T. !. I... l F'.~ F'R WFI..I FTI.. F.'-: ,,' .?APC -'-,,-.~TATF F1F AI..A,S'KA ~ '/FYARR XEROX TELECOP t ER F E'. 0 M 296 ; 9072r6r,-,4~ ; # I . tq~[:. ~ ". '.~:. ,i )ec tot .,M:ICO Alaska, In/''-'- Prudhoe B~,y Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager November 11, 1987 C. V. "Chat" Chatterton Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: NGI-06 Sundry, Permit #76-29 Dear Mr. Chatterton: Please find attached the Application for Sundry Approvals form for well NGI-06 as required per Rule 7 of Area Injection Order No. 4. As stated in the 10/28/87 conversation between II. T. IIong (ARCO) and M. Minder, the SSSV was dropped while running it in the hole. The valve packing is not sealing and therefore, the valve cannot be hydraulically controlled from the surface. Several attempts to pull the valve have been unsuccessful. A rig workover has been scheduled. Very truly yours, D. F. Scheve Attachment cc: SAPC L. L. Gantt- ATO 1520 R. M. Lemon - ATO 1492 T. V. Marshall- ATO 1568 G. D. Herring/H. G. Limb - PRB 24 H. T. Hong/E. W. Skaalure - PRB 20 PI(NGI-06)WI-3 RECEI EI NOV Z 7 1987 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ~,~"'~" STATE OF ALASKA AL~-,_.~A OIL AND GAS CONSERVATION COIv,,v,.,.,SION 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. O. BOx 100360, Anchorage, Alaska 99510 4. Location of well at surface 332' FNL & 1014' FWI,, Sec. 12, TllN, R14E, UM At top of productive interval 1242' FSL & 988' FEL, Sec. 2, TllN, R14E, UM At effective depth 1452' FSL & 1185' FEL, Sec. 2, TllN, R14E, UM · ? At-total depth 1488' FSI. & 1220' FEI., Sec. 2, 711:N, R14F,, UM 5. Datum elevation (DF or KB) 47' 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-6 (44-2-11-14) 8. Permit number 76-29 9. APl number 50-- 029-20206 10. Pool Sadlerochit feet 11. Present well condition summary Total depth: measured true vertical 9585 feet 8617 feet Plugs (measured) 9500' - Cement Effective depth: measured 9412 feet true vertical 8474 feet Junk (measured) 9412' - Fill Casing Length Size Structural Conductor 67',' 20" Surface 2=646 ' 13-3/8" Intermediate Production 8442 ' 9-5/8" Liner 1457' Perforation depth: measured 10 separate intervals between 8999' true vertical Cemented Measured depth True Vertical depth 240 sx Arcticset cmt 89' 5700 sx Permafrost II 2668' 89' 2668' 2nd Stg:155 sx Permafrost II-750 sx Class 6 cmt 8464' 7730' - 9479 ' NOV i ? 1987 10 separate intervals between 8143' - 8529' Alaskn,0il & Gas Cons Commission Tubing (size. grade and measured depth) 7", 29#, T.-80, A3MOD 8rd @ 7857 1vid 5-1/2", 17#, L-80, ABMOD 8rd @ 7857~nc-h°~5' MD Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker FB-1 Packer @ 7904' MD/Otis SSSV @ 2212' MD 121Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation N/A 14. If proposal was verbally approved Name of approver Mike Minder Date approved 10/28/87 15. I hereby/~ertify that tJ;~e fo_regoj,ng is true and correct to the best of my knowledge /I s,,ned Commission Use Only Conditions of approval Approved by //~/f, ~//. Form 10-403 Rev 12-1-85 Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI ~ ~ Approved Copy Returned by order of ,er the commission Date Submit in triplicate(~ INJECTION V'E-R"AI' NOTI'N'N- UI'AR COMMuNICATi 'r~4ECTION AOGcc DATE: October ~, 19~? ORDER #4 TIME: ~: 30 a.m. NOTIFIED REAsoN: . I~n_Jee!ion Well Z~G~-6 AOGcc CO CT: Hi]~e ~equ~rements .~ An ~.. ~ ~A "~roer No. 4 ..~. per Rule 7 Wlth no sUeee ~ e s · .,~, Ute fr- ' cS~v_ -- ,209 . n-]ol- or re ds le · w~tn -,ade . ~ro D ~ed' _ avln ess _ to fa ~ ~.. ~d ~al wo~u g the w~, and wo~,~ s. Val~ -"' ' "=~a on gas ~3~ not hold '"3ection AOGcc RESPONSE: o,-' to ' SSSV. u~P~issi°n tj -~';eed to continue s.~.:;lit a SUndry notice 1n3ecti°n and OUtlining Sundry Notice ~qrd at this tirne~ YES · SIGNED: / /~ t ~ Supt ~ ' ~ie~ Ar;a ~s NOV [ 7 ]987 vmS. S~C. Alaska Oil & Gas Cons. Commissio~ ~e~~z ~' H~,'~j ~ Anchorage " ~C /-'/-"" STATE OF ALASKA ~ AL/-,..,.',,~ OIL AND GAS CONSERVATION COM[v,,..,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program -] Plugging E: Stimulate [] Pull tubing ~.k Amend order [] Perforate .rq. Other 2. Name of Operator ARCO Alaska, Inc. 13 MIK)hank3aJ Integrity Test 3. Address P. 0. Box-100360 Anchorage, AK 99510-0:360 4. Location of well at surface 332' FNL, 1014' FWL, Sec.12, TllN, R14E, UM At top of productive interval 1264' FSL, 980' FEL, Sec. 2, TllN, R14E, UN At effective depth 1423' FSL, 1158' FEL, Sec. 2, T11N, R14E, UM At total depth 1488' FSL, 1220' FEL, Sec. 2, T11N, R14E~ UM 11. Present well condition summary Total depth: measured 9585 'MD true vertical 8617 ' TVD Effective depth: measured 941 2 ' MD true vertical 8474 ' TVD Casing Length Size Conductor 67 ' 20" Surface 2646' 1 3-3/8" Production 8442 ' 9-5/8" 5. Datum elevation (DF or KB) RKB 47 ' 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-6 (44-2-11-14) 8. Permit number 76-29 9. APl number 50-- 029-20206 10. Pool Pr,,,.u,i;I,l'~a,¢ta,3~,l~i 1 Pool feet Liner 1457' 7" feet feet feet feet Plugs (measured) None NOV 3. 6 Junk (measured),, --~!~ Aias~ u ~, ~ O'ohMCOi~¢r~ Cemented 240 sx AS 5700 sx PF II 155 sx PF II & 750 sx Class 6 360 sx Anchorage Measured depth True Vertical depth 89 ' MD 89 ' TVD 2 668 ' MD 2668 ' TVD 8464 'MD 7730' TVD 8123'-9580'MD 7469'-8613'TVD 14. If proposal was verbally approved Name of approver Perforation depth: measured 8999'-9002' 9009'-9028' 9036'-9237' 9242'-9282' 9289'-9299' 9322'-9376', 9387'-9415' 9419'-9434' 9460'-9469' 9473'-9479' truevertica{B143'-8145', 8151 '-8166' 8172'-8333' 8337'-8369' 8375'-8383' 8402'-8445' 8454'-8477', 8480'-8492' 8513'-8521 ' 8524'-8529' Tubing (size, grade and measured depth) 7", 29~, L-80, AB-Mod 8rd ~ 7857'MD; 5-1/2", 17~, L-80, AB-Mod 8rd ~ 7857'-7895'MD Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker FB-1 okr ~ 7904'MB~ O~{~ gggV ~ ??1?'MD . .. 12.Attachments Description summaw of proposal ~ Detailed operations program ~ BOP sketch ~ 13. Estimated date for commencing operation ~ [~ November 21, 1987 '.~O ,~:.~.[~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢~,.~]_~4,L/ Title Asso~i~t~ Engineer ' Commission Use Only ( DCS ) 5A3/20 Conditions of apprOval Notify commission so representative may witness I Approval No. ~ ~=~; [V[('i~- [] Plug integrity [] BOP Test [] Location clearanceI Approved Copy //..~¢~ ~. Mech'a~icaJ Integrity Test Approved by ~~ ~issioner Form 10-403 Rev 12-1-85 Date by order of the commission Date ~¢llS~SW-- Submit in triplicate(~ NGI-6 PRELIMINARY WORKOVER PROCEDURE OBJECTIVE: Replace the damaged SSSV, mill up packer, and clean out to PBTD. A 7" completion string and 9-5/8" packer assembly will be run. 1) Run isolation sleeve in SSSV. Shoot circulation holes in 5-1/2", 1 joint below sliding sleeve. Pull isolation sleeve. 2) Kill well with bridgesal pill and circulate out annulus to saturated NaC1 brine. 3) MIRU WW1. ND tree. NU BOPs and test same. 4) Pull 7" x 5-1/2" completion string. 5) Mill up Baker 9-5/8" packer. 6) TIH with 9-5/8" squeeze tool. Pressure test 9-5/8" casing to 2500 psi for 30 min. 7) TIH with 6" bit. Clean out fill to PBTD. 8) Run 7" completion string and 9-5/8" packer assembly. Install 7" SSSV at +2200'. 9) Test tubing to 3000 psi for 30 min and annulus to 2500 psi for 30 min. 10) ND BOPs. NU tree and test. 11) Release rig. Workover fluid: 10.0 ppg NaC1 BHP: 3900 psi RML/42 11/12/87 ANNULAR PREVENTER PIPE RAHS 5 BLIND RAMS 4 TUBING HEAD 5 2 1. t3-3/8" CASING HEAD 2. 9-5/8" CASING HEAD '~ 5(300 PSI TUB'~''' '~ ..... ,,,,_~ Hr'AD 4. 15:: ..... -a/o -5000Pal BLIND RAMS ....... - ...... m,D~ PAMS 6. 15-5/6" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID, 2.ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSt WITH 1500 PSI DOWNSTREAM OF THE RECULATOR. NO~ ~' 6 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED, PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT tN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD, 5. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES, 5, INCREASE PRESSURE TO 2500 PSi AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSi AND HOLD FOR I0 MINUTES, 6. CLOSE VALVES DIRECTLY UPSTREAM OFCHOKES. BLEED DOWNSTREA?': PRESSURE TO ZERO PSi TO T~¢T VALVES ~EST PEMAINING UNTESTED MANIFOLD VALVES. iF ANY. WiTH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSiDOWNSTRE&M. BLEED SYSTEM TOZEROPSI. 9. OPEN PiPE RAIDS. BACK. OFF P. UNN~NG JT AND PULL OUT OF HOLE, ~ nc: BL' .... " TEST TO . , . L.L.~, . ,ND AND , 50¢'~0 PSI FOR ~0 ~'~ I ~ ~,~r',5 I,NL T,.~ BLEED TO ZERO PSi. tO. OPEN BLIND RAMS ANDRECOVEP. TE~TPLUG MAKE ~LPE MANIFOLD ANF;, LINES APE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN ThE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12 z~¢~ COCKCj . , ~a~ KELLY AND INSIDE BOP TO 5000 PSt WITH KOOMEY PUMP !5. PECORD TEST iNFOPMAT ON ON BLOWOUT PREVENTER TEST FORM. AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE COPE . Eb ~ ONCE A WEEK AND FUNCTIONALLY OPERATE COPE DALLY. d6 NOVEMBER 21, 1986 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM,,,,dSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska~ Inc. 3. Address Post 0ffice Box 100360, Anchorage, AK 99510 4. Location of well at surface 332' FNL & 1014' FWL, Sec. 12, TllN, R14E, UM At top of productive interval 1264' FSL & 980' FEL, Sec. 2, T11N, R14E, UN At effective depth 1423' FSL & 1158' FEL, Sec. 2, T11N, R14E, UM At total depth 1488' FSL & 1220' FEL, Sec. 2, T11N, R14E, UN 11. Present well condition summary Total depth: measured true vertical 9585 feet 8617 feet Plugs (measured) 5. Datum elevation (DF or KB) 47' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well n~T~_e~ (44-2-11-14) 8. Approvalnumber 7-223 9. APInumber 5O-- 029-20206 10. Pool Sadlerochit Effective depth: measured 9412 feet true vertical 8474 feet Junk (measured) Casing Length Size Conductor 67' 20" Surface 2646' 13-3/8" Production 8442' 9-5/8" 9500' - Cement 9412' - Fill Liner 1457' 7" Cemented Measured depth Rue Vertical depth 240 sx Arcticset Cmt 89' 89' 5700 sx Permafrost II 2668' 2668' 2nd Stg: 155 sx Permafrost II 8464' 7730' 750 sx Class C Cmt 360 sx 8123'-9580' 7469'-861~ Perforation depth: measured 8999-9002' 9009-9028' 9036-9237' 9242-9282' 9289-9299' 9322-9376' 9387-9415' 9419-9434' 9460-9469' 9473-9479' true vertical 8143-8145' 8151-8166' 8172-8333' 8337-8369' 8375-8383' 8402-8445' 8454-8477' 8480-8492' 8513-8521' 8524-8529' Tubing (size, grade and measured depth) 7", 29#, L-80, ABMOD 8rd @ 7857'MD 5½", 17#, L-80 ABMOD 8rd @ 7857'-7895'MD Packers and SSSV (type and measured depth) 9-5/8" X 7" Baker FB-1 Packer @ 7904'MD/0tis SSSV @ 2212'MD 12. Stimulation or cement squeeze summary ~ )~'; ~ ~ ;;~ ~l-~ ~ Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data 13. OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 5/1/87 -- 158782 .... 3983 Prior to well operation Subsequent to operation 5/11/87 -- 174053 .... 3768 14. Attachments 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 ~ y '"(~.~" ~:~'.,~ Title Form 10-404 Rev. 12-1-85 MOrt Oper. Engr. Mgr. Date ~/Z ~'~,,) Submit in Dupli.cate NGI-6 DAILY OPERATIONS REPORT ADD PERFORATIONS 4~30~87 PT lub to 4000 psi. OK Pulled SSSV RIH w/3-3/8" dummy gun, TTL & bailer Tagged PBTD @ 9326' SLM 5/2/87 PT hardline to 4000 psi. OK Pump in xylene wash w/methanol SD for 45 min. soak time PT wireline equipment to 4000 psi - replace O-ring Retest to 4000 psi. OK RIH w/gun #1, 3-3/8" x 22', 4 SPF @ 120° phasing Perf 9222'-9237' and 9036'-9043' Tag PBTD @ 9413' POOH - all shots fired RIH w/gun #2, 3-3/8" x 24', 4 SPF @ 120° phasing Perf 9342'-9356' and 9272'-9282' POOH - all shots fired RIH w/gun #3, 3-3/8" x 22', 4 SPF @ 120° phasing Perf 9178'-9197' and 8999'-9002' POOH - all shots fired RIH w/gun #4, 3-3/8", 4 SPF @ 120° phasing Perf 9137'-9153' and 9009'-9018' POOH - all shots fired RIH w/gun #5, 3-3/8" x 20', 4 SPF @ 120° phasing Perf 9087'-9107' POOH - all shots fired RIH w/gun ~6, 3-3/8" x 24', 4 SPF @ 120° phasing Perf 9073'-9087' POOH - all shots fired 5/3/87 PT lub to 4000 psi. OK Set SSSV at 2189' PT. OK POOH RD Flow tested. Good ' STATE OF ALASKA ~ ALASK~ OIL AND GAS CONSERVATION COMM.~$1ON 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 I~ Other [] 2. Name of Operator ARCO Alaska_. Inc. 3. Address Post Office Box 100360~ Anchorage~ AK 99510 4. Location of well at surface 332' FNL & 1014' FWL, Sec. 12, T11N, R14E, UM At top of productive interval 1242' FSL & 988' FEL, Sec. 2, T11N, R14E, UM At effective depth 1452' FSL & 1185' FEL, Sec. 2, T11N, R14E, UM At total depth 1488' FSL & 1220' FEL, Sec. 2, T11N, R14E~ UM 5. Datum elevation (DF or KB) 47' RKB 6. Unit or Property name Prudhoe BaS Unit 7. Well number NGI-6 (44-2-11-14) 8. Permit number 76-29 9. APl number 50-- 029-20206 10. Pool Sadl erochi t feetd 11. Present well condition summary Total depth: measured true vertical 9585 feet Plugs (measured) 8617 feet Effective depth: measured 9500 true vertical 8548 Casing Length Size Conauctn-r - 67' 20" Surface _ 2646' 13-3/8" Production_ 8442' 9-5/8" 9500' - Cement feet Junk (measured) None feet Cemented Measured depth True VertiCal depth 240 sx Arcticset Cmt 5700 sx Permafrost II 2nd Stg: 155 sx Permafrost II 750 sx Class C Cmt Liner · -- 1457' 7" 360 sx 8123'-9580' 7469'-8613 . 89' 89' 2668' 2668' 8464' 7730' Perforation depth: measured 9018-9028' 9043-9073' 9107-9137' 9153-9178' 9197-9222' 924;'- 9272' 9289-9299' 9322-9342' 9356-9376' 9387-9407' 9419-9434' 9460-9469' 9473-947!' true vertical 8162-8170' 8181-8205' 8232-8256' 8269-8289' 8304-8324' 834 - 8364' 8378-8386' 8405-8421' 8432-8448' 8457-8473' 8483-8495' 8516-8523' 8526-853 ' Tubing (size, grade and measured depth) 7", 29#, L-80, ABMOD 8rd @ 7857'MD Packers and SSSV (type and measured depth) 5½", 17#, L-80 ABMOD 8rd @ 7857'-7895'MD 9-5/8" x 7" Baker FB-1 Packer @ 7904'MD/Otis ~.~SV Fa ??1?'Mil 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation May, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby~certify that J, be foregoing is true and correct to the best of my knowledge signed,,~/~//~"/,4~~ Title Operations Engineerin.cj Mana.qer Date.. Commission Use Only Conditions of approval Notify commission so representative may witness ~ Approval No. ~ Plug integrity Q BOP Test ~ Location clearance~ . Approved by ~ Commissioner the commission Dat~_ Form 10-403 Rev 12-1-85 MR0 (265-6810) Submit in triplicate NGI-6 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations within the Sadlerochit interval in Well NGI-6. The proposed perforation intervals are as follows' Existin9 Perforations 9018-9028 (10') 9043-9073 (30') 9107-9137 (30') 9153-9178 (25') 9197-9222 (25') 9242-9272 (30') 9289-9299 (10') 9322-9342 (20') 9356-9376 (20') 9387-9407 (20') 9419-9434 (15') 9460-9469 (9') 9473-9479 (6') TOTAL = 250' Proposed Perforations 8999-9002 (3') 9009-9018 (9') 9036-9043 (7') 9092-9107 (15') 9178-9197 (19') 9222-9237 (15') 9272-9282 (10') 9342-9356 (14') 9449-9454 (5') TOTAL = 97' Reference BHCS of 4/28/76 A 5000 PSI WP wireline lubricator, tested to working pressure, will be utilized for this work. All perforations will be made with hollow carrier-type guns at 4 shots per foot. All perforations will be made with an appropriate fluid, the perforating performed, and gas injection resumed with the wellbore load fluid being displaced into the wellbore formation. No flaring is anticipated. ~'-'~ WELL: NGI ~6 ~-"tSPUD DATE: 4/9/76 SURFACE LOCATION: 332'S & 1014'E of NW ct. Sec. 12, TllN, R14E, UM BOTTOM HOLE LOCATION: ' 1488'N &'1220'W of SE ct. Sec. 2, TllN, R14E, UM ORIGINAL RKB': 47' RKB TO Gray HANGCR 22' TOP OF SADLEROCHIT: 8979' , MD ALL DEPTHS ARE RKB MD Depths are to TOP of equipment L 89' 20", 94#, H-40 Vetco (19.124" ID) 2212' Otis RB 7" Landing Nipple (5.963" ID) ' Howco 9-5/8" FO Howco 9-5/8" FO 2668' 13-3/8", 72#, N-80 BTC {12.347" ID) w/ 5700 sx 2705' Bottom of 9-5/8", 47#, SOO-g5 BTC (8.681" ID) AVERAGE HOLE ANGLE: 35° MAXIMUM ANGLE: '41'75° g 7200~ ANGLE AT TD: 36o ANNULUS FLUID: 10.8 ppg CaC12 -1 -l -l 7857' Bottom of 7", 29#, L-80 ABMOD 8rd (6.184" ID) 7882' Otis S½" Sliding Sleeve {4.562" ID) 7895' Bottom of 5½", 17#, L-80 ABMOD 8rd {4.892" ID) NO TUBING TAIL 7898' Baker G-22 Locator Sub 7904' Baker FB-! Prod. Packer 7914' Baker Seal Bore Extension (6.032" ID) w/ Mule Shoe (4.125" ID) 8123' Top of Liner, BOT HC Hanger 8464' 9-5/8", 47#, MN-80 BTC (8.618" ID) w/ 730 sx WORKOVER-STIMULATION 27'77 Chemical Squeeze o¢ Liner 9018' - 9043 - 9107 - 9153 - 9197 - 9242 - 9289 - 9322 - 9356 - 9387' - 9419, - 9460' - 9473' - 2028' 9073' 9137' 9178' 9222 9272 9299 9342 9375 9407 9434 9469 9479 7/25/78 Recompletion due to wireline fish removal and to increase injection capability with large bore completion and additional perforations. 9500' PB'FD 9580' 7", 29#, N-80 8TC (6.184" ID) w/ 360 s~ 9585' TO 1/84 i ii i iiii i · i i i 3 iI 2 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 pSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF I 1 I W I REL I NE BOP EQU I PMENT AtlanticRichfieldCompany North American Producing Division North Alas/Y~/"~"t rict Post Office b,,^ 360 Anchorage, Alaska 99510 Telephone 907 277 5537 December 20, 1978 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcuping Drive Anchorage, Alaska 99501 Subject: ~Permit No. Permit No Dear Sir: Enclosed is a Completion Report Very truly yours, P. A. VanDusen District Drilling Engineer PAV:mr Attachments 75-61 76-29 for the above-mentioned wells. Form. P---7 'i- ~ SUBMIT IN DUr,,k~ATE* STATE OF ALASKA : (See other In- st ructions on reverse side) OIL AND GAS CONSERVATION COMMITTEE ~ . WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* ,'*'ELL WELL DRY ['-I Other Gas Injection b. TYPE OF COMPLETION: .~Ew -- wo~:~ [] D~EP- []] P~ []] ~I~,. ~ ' Perforated WELL OVER ES B~CK RESVR. , Other .. ~. ,,~, o~ O~*To~ , Prudhoe Bay Atlantic Richfield. ~Company .... -.~ ,.W~,L~O. ~. ~,o~SO~OP~,TO~ NGI #6 (44--2-11--14) P.O. Box 360, Anchorage, Alaska 99510 10. FIEL3) A.NDPOOL. ORWII_J3CAT ~. LOCATION OF WELL (Re~ort location c~early and in accordance withany ,State requirem,nt~)* At surface 332'S & IOI4'E of NW cc Sec 12, TllN-RI4E, OM At ~o~2%r~% interval reported below & 972~W of SE cr Sec 2, TllN-Ri4E, UM Sec 2, TllN-R14E, UM At total depth 1488'N & 1220'W of SE cr Sec w, TllN-R14E, UM '=.P~.m~T~O. .Y6-29 4-9-76 ~] 4-28-76 . [ 5-5-76(perf'd 8-8-~8) 18.4' Pad elev: .47'R _K/t · I'~Ol/V l%ffl~Y* ROTARY T CABLE TOOLS 958 ' & 8617' .9500' & 8548' ~]ng~e 1 NONE 22. PRODUCING INTERVAL(S), OF THIg~ COMPI_,ETIO/N'---rlY)P, BOTTOM, NAME (iVID AND TVI))* 23. WAS DIRECTIONAL ! SURVEY NLADE Top Sadlerochit 8979' MDB131' TVD Base Sadlerochit 9505' MD' 8552' TVD .i Yes 5. AP1 N~CAL CODE 50-029-20206 , , 8. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF IND1AIq', AJ-J,~TTEE OR TRIBE NAME Prudhoe Ba¥-~F.i el d-Prudhoe SEc., T., a., ~., (~OTT~lUOp~01 OBJECTIVE) ': 9419'-9434' 9387' -9407' 9356'-9376' 9322' -9342' ,~9289' -9299' 24. TYPE ELECTRIC AND OTHER I. A3GS RUN DIL/SP, BHC/GR, FDC/.GR, _GR/VDL/CBL, GR/CCL ~5.. CASn~G RECORD (Report all strings set in well) CASING SIZE ! " 20" [94~:-VetO°EH'40" 80' be) pd[ 32" 13-3/8" ~2~ - B'utt:[MN 80 2663' ' ]7~" ~ 9-5/8. [47~ -'BUtt [MN-80 8464' ]2~" [ - &s0 .-95 I ' LINE~ ~CO~ "- 7r' ~-- :8123' ' [ ~o~o~(~m s~c~scm~.~ 28. PERORATIONS OP~ TO PRODU~ON iinterv~, size ~d number) ~ 9242"92~2' w/4 shots. pe~eft. N/A DATE OF TEST, I}{oURS TESTED '[CHOI{E SiZE [PROD'N FOR I I IamST t~mUOD 0% i 1977 '[II 24 i N/A I ---*' I n ~ ~.t ow, ~um~a ~c~smG r~s~ ~c~~ o~ Press 4300 psi I - ] ' ~ [ 0 2ll. ImS~OSITW~ OV ~aa (~old, ~,ed ~o~ ~el, ~ented, etc.) Rei njected 32. LIST 0~' ATTACHMENTS .. CEAILN TING REC Ott,D 240 sx Arcticset cmt AiVIOUNT PULLED 5700 sx PF II cmt 750 sx Class ¢ cmt 2nd sta,~e 155 sx PF II ,, , SCREEN {Mn) SIZE [ DEPTI-I SET (MD) ~ PACI(ER SET (MD) 7" 8032.5 7888' 29. ACID, SHOT, FZA~CZ['LrRE, CF~'~E:NT SQUEEZE, ETC, D]~TII INTEI{VAL (MD) AMOUNrl' 2~ND KIND OF M.a~T~R/AL USED 30. PRODUCTION DATE FIRST PrtODUCTION I PRo'D/JcTION METHO'D (Flowh*.g, gas lift, pumping~size and type of pump) '~-e xq~V Injection o,~-~.. G~0~,1300 I 0 I MSCF/n I :MSCF/n IWELL STATUS (Producing or ~'m[-in)N/A WA~IS~R'~B~' ! GAS-OIL l%.~TIO V~ATEl%--BBL. l OIL GRAVITY-APl (COlq~,) I TEST WITNESSED BY ' Production 13oe. ratinq 33. I hereby certify that the foregoing and attached information is complete and correct as determined from alYavailable records SIONED ~ TITT,E District Drlg. Engineer ~TS~. I iiii *(Si, Instruction, and Spaces [or AdditiSnal Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion ~re'port end to9 on all types of lands and leases in Alaska. Item: 16: Indicate whic~ elevation is used as reference (whe,'e riot otherwise show~) for depth measure- merits given in ether'spaces on this form and in any attachme,,-~ts Items 20, and 22:: I,f this well is completed for separate prcd:.¢ction from more than one interval zone (multiple completion), so state ~n item 20, and in item 22 show the prcJuci~:(.~l interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interv,¢l reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately producer'l, show- ing the ad(Jitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing anc~ the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 35 ~; I~X"'~I.,OG 1 C WATI~H. AND MUF) .~ ,. NAM~ Top Sadleroch~t 8979' 8131 ' Base Sadl eroch~ t 9505' 8552' Ill I I I I II I I II II I AND I>~'EC~'~) SIIOWS O~' Ol1., GAS , , , ,~.me,. i Producing Division Alaska Regi Post Office Box 350 Anchorage, AIaska 99510 Telephone 907 277 5637 November 30, 1978 TO: Reference: GAS ~nelosed are/~.cop±~s of the following Cased Hole :Logs~ Engineered Production Log 9-30-78 5" D.S. #5-1 Differential Temperature Log 10-12-78 5" Please sign and return the attached copy of t.ransmi'ttal ~"~~ as receipt of data. Very truly yours, R.A. Logue Nort:h Operations Engineering Transmittal #580 AtlanticRichfieldCompany North Amerf/'''~ Producing Division Alaska Re~ Post Office BOX 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 8, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' NGI #6, Permit No. 76-29 Dear Si r- Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned well. Very truly yours, Frank M. Brown Di stri ct Dri 11 i.ng Engineer FMB-jh Enclosure Form 10-403 REV. 1-10~73 Subml t "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~V~L[--1WELLGAS r'] OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360 Anchorage, Alaska 99510 4. 'LOCATION OF WELL At Surface 332'S & 1014'E of NW cr Sec. 12, T11N, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18' gravel pad 14. Check Appropriate Box To Indicate Nature of Notice, Re APl NUMERICAL CODE 50-029-20206 LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NGI #6 (44-2-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudh0e 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 2, T11N, R14E, UM 12. PERMIT NO. 76-29 )ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTER lNG CAS lNG SHOOTING OR ACIDIZING ABANDONMENT* (Other) Perforate (NOTEt Report results of multiple completion on Well Completion or Recompletion Report and Log form.) ].5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Pertinent ;letall~, and give pertinent dates, Including estimated date of starting any proposed work. Began operations @ 1700 hrs'8/4/78. RU & tstd surface equip. Palled ball valve. Perfd intervals 9419:' - 9434,., 9387' - 9407',-9356' - 9376', 9322' - 9342', 9289' - 9299', 9242-' .... 9272'.:w/4 shots*per ft. Flowed well. Ran & set ball valve. Tstd ok. Released well @ 2400'hrs'8/8/78. 16; I hereby certify that the fPreg~ing Is true and correct (This space for State office use) APPROVED BY.. CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side AtlanticRichfieldCompany · North Amer~ .~roducing Division North Alasl [strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 7, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' NGI #6 Permit No· 76-29 Dear Si r- Enclosed please find our Sundry Notice of Subsequent Report detailing the work done On'the'above-mentioned wel 1. Very truly yours, Frank M. Brown District Drilling Engineer. FMB:jh Enclosure Form 10-403 REV. 1-10~73 Submit "I ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (DO not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL[--J OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska LOCATION OF WELL RFC= 99510Ait6 [l 6 !978 At surface .. Division of Oil and Gas Coas~n;atio,' 332'S & lO14'E of ~ cr Sec. 12, TllR, 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18' Gravel Pad ~4. Check Appropriate B(~x To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20206 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudh0e Bay Unit 9. WELL NO. NGI #6 10. FIELD AND POOL, OR WILDCAT Prudh0e Bay Field-Prudh0e 0il P001 11, SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 2, T11N, R14E, UM 12. PERMIT NO. 76-29 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL - CHANGE PI_ANS (Other) SUBSEQUENT REPORT OF-' WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well ComPletion or Recompletion ReDort and Log form,) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all I)ertln®nt gletells, and give pertinent dates, Including estimated date of starting any proposed work. Began operations @ 0600 hrs 7/16./.78. Set BPV ND tree. NU BOP. Pumped 120 bbls high vis pill then 250 bbls 10.8 ppg CaC12 wtr w/Dril-S. Pulled BPV. Pulled 7" tbg. Rec ~3500' of wireline & all wireline tools. RIH w/overShoi;'& grapple. POH.w/PBR & K anchor. Milled pkr & POH w/same. Tstd FO's. Circ.hole clean to top of'lnr @ 8123' Set 7" ret @ 8450'. Tstd 9-5/8" csg ok. Set RBP & tstd. Instal led'new'tbg spool & pkof~. Tstd ok. NU BOP POH'w/RBP. Tstd csg, ok. Drld ret, Ran gauge'ring&~junk bskt. Ran pkr on wireline & set. Ran 7" tbg compl assy set @ 7914', w/Pkr'@ 7904,. 'Pulled'dummy valve. Ran CCL log. Ran & set ball valve. Tstd ok. NU & tstd tree;' 'POH w/ball valve. Opened sliding sleeve. Displ Dril-S treated CaC12 wtr w/70 bblS high vl*s pill then '581 bbls'clean CaC!2 wtr. Displ t.bg w/diesel. -Closed.-sliding sleeve. Ran & set'ball valve' @ 2212'. Tstd ok. Released rig @ 1200 hr.s 7/28/'78.. 'Moved out rig & eqUip. 'Installed flow!ine manifold. ~e-mov~d tree & installled perf manifold. Opened'well' to burn pit. Flowed well to CU @ 2850 psi on 48/64 choke. SI well. Ran injectton'tst, 'SI well. RU equip. Pumped 200 bbl fresh wtr treated w/0.2% F75N Surfac'tant,:fo!lowed'.by' 15,000 gal 15% HCL w/0.5% A200 Inhibitor, 0.2% F75N Surfactant &'0.2% W35Antisludge.' Displ 'aCid w/lO0 bbls diesel. SI well. Flowed well for CU. ReleaSed'well to CCP @ 1'400 hrS 8/2/78. 16. I hereby certify that the foregoing is true and correct SIGNE TITLE District Drilling Enginee.r mATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: T IT LE DATE See Instructions On Reverse Side HoyleD~H. F~miit~n~ July l9, 1978 Harold R. Hawkins Witness BOP Test Aroo NSI No. 6 Sec. 2, TI1N, R14E, ~4. Pexmit No. 76-29 ~, J.ulY. 14, !~8_- I left my house at 9:30 AM for a 10:00 AM ~ in With ~ ~, f~r a flight to ~ At 11:00 AM. Purpose of t~ip was to Witness a BOP test c~ NGI No. 6 woxkover. I arrived in Prudhoe at 12:30 PM ar~ arrived at NGI No. 6 at 2:30 PM. When i arri%~d ~ ~ ~ Pamker rig 141 was being set c~er the well. ~y,..._Ju!Y 1..6, ~,78 - ~ ~ . .started at 3:00 PM and f~ upper pipe rams, inside kill 'and t~side choke were tested %o 5000 psi. next to 5000 psi. With -the upper pipe rams still closed, the check were tested se~sz~ly to 5000 psi. ~heze w~s a m~ual d~ke that opera~ freely. The lower pipe rmm were tested ~o 5000 psi. ~ preparer was tested to 3000 psi. With the test stem pulled kelly were ~ to 5000 psi. The well sign was up with all data OK. test, 1350 ps/was left cn master, gauge after full closures of all BOP's with om~plete ~ off~. Ni~ backup had 1900, 1800, 1800, 1650~ e~ in ~ ~. ~w~s a dart and a drill stem Attac/m~t ~rlgo Permit No.7___~'--~ Opera tor_~:L~f x~- ~ Sati sTac~ory Type Inspection Yes No Item ~(:) Location,General () () (.~'! ( ) (X; ( ) () () () () () () () (.) () () () () () () () () Al~ ~, Oil and Gas Conservation Commi! ~ Field Inspection Report _.Z~_~ Well/Platfm Sec~, T ~__~__R/~',u~M Represented by-.._Z.m~.~,., C,..¢~..~_~e & Number .,C,, ~;/ ,V~ ~' (~') () (~) () ~ () (~) () l l. P&A Marker (M) ( ) lZ. Water well-( )capped( )plugged ~') ( ) 1. We~l Sign 2. General Housekeeping ~.. Reserve Pit-~)open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells -- 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , 8. Hrs. obser ;__, , 9. BS&W , i~.., , 10. Gr. Bbls. (.) Final Aba~donm~-n~: Satisfactory Type Inspection Yes No Item ()0 BOPE Tests (~) ( ) .15. ~-"Casinq set 0 (,ND ( ) 16. lesL fluid-( )wtr.-----T )mud (~')oil (~) ( ) 17. Master Hyd. Control Sys.-~'~ psig (:x) ( ) 18. ~'!2 btls~L~_.~.,~/?~/~"~psig (~) ( ) 19. Remote Controls (%k) ( ) 20 DrillinQ spool- :$~ "outlets (X) ( ) 21 Kill Line-(~(1) Check valve (,X) ( ) 22 Choke Flowline ( ) HCR valve 23 Choke Manifold No. valvs~__flms 24 Chokes-Oc)Remote(J~Pos.(~TAdj'i ' 25 Test Plug-( )Wellhd~)csq( )none 26 Annular Preventer~(~_~psi.~ 27 B1 ind P,.ams,~'~psi~ 28 Pipe Rams ~apsiq 29 Kelly & Kelly-cock~(~'~' psig ( ) ( ) 13. Clean-up (X) ( ) 30 Lower Kelly valve~"~m~sio ( ) ( ) 14. Pad leveled ~, (~) ( ) 31 Safety Floor valve~z(~E)-BV ~K,)Dart numbe a ~,~ ~/~ Total eaks nd/or equiP, failures Total inspection observation time~~/days r Remarks ~O~Z~A~ ~ /(~~V, ~ ~ P~ ~~/~ ~~ f~ ~,~(~z ~ ~pu~A~.~.,~ ~ Pdt; ~?~) ~/'~e ~~.~F~,~ / ~ ..... NotifY in -- ~day-s or when ready---- Inspected Da t e/~-/-~._ Atla~ticRichfieldCompany North Ame} ': Producing Division North Ala~ .~istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 11, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: NGI #6 (44-2-11-14) Permit No. 76-29 Dear Sir: Enclosed please find a MonthlyReportof Drilling Operations for the above-mentionedwell. Very truly yours, Frank M. Brown District Drilling Engineer FMB:cks Enclosure Form No. P--,~ STATE OF ALASKA sus~rr IN ~rUPLZCA~ OIL AND OAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS API NUMERICAL ~ODE 50-029-20206 6 LEASE DESIGNATION AND SERIAL NO. ADL 28302 1, ? IF INDIALT, ALOTTEE O]~ TRIBE NAME OXL [] o,. [-] o,.z, Gas Injection WKLL W~:LL 2. NAME OF OPEI~TOR Atlantic Richfield Ccmlaany 3. AbDRESS O~ O~'ERATOIR 4. LOCATION OF WELL 332' S & 1014' E of NW or SEC 12, T 11 N, R 14 E, UM 8. L,~IT FAR{VI OR LEASE NAT4iE Prudhoe Bay Unit 9 WELL NO NGI ~6 (44-2-11-14) 10. 1~'~ A_ND POOL, OR %VILDCAT Prudhoe Bay Field-Prodhoe Oil Pool ii. SEC., T., R., M.. (BOTTOm' HO~a: Sec 2, TllN, R14E, UM 12. PER,MIT NO. 76-29 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-IA~NGES IN HOLE SIZE, CASING AND CI~.VIENTING JOBS INCLUDING DEPTH SET AND VOLUIVIES USED. PF_A{FOHATIONS, TESTS ~ HESULTS FISHING JOB~. JUNK IJ~ HOLE A/kID SIDE-TRACKED HOLE A~D AJaY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for the Month of June, 1978. As of June 30, perforating operations still suspended pending evaluation of well. 14. I hereby~, ~t th and correct S,GN~ ,, , ,,n'n..,~ District Drilling En~inee&k~ Jul~ 11, 1978 NOTE'"'RII)ort on this form is required for each calendar month~ regardless of the status of operations, and must I)o flied in duplicate with the otl and gas conservation committee by the ISth of the suaceeding month, unle~ otherwise directed. Atlanticl:lichfieldCompany North Ameri'~"k'Producing Division North Alaska. ~trict Post Office BOx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 21, 1978 Mr. Hoyle Hamil ton State of Alaska Department of Natural Resources DiviSion of Oil' and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' NGI #6 Permit No. 76-29 Dear Sir' Enclosed please find a Sundry Notice outlining our plans for the above-mentioned wel 1. Very truly yours, Frank M. Brown District Drilling Engineer FMB- j h Enclosure Form ,10-4,0,3 REV, 1-10-73 Submit *'Intentions" in Triplicate & "Subsaquent Report~" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---~° for such prol~OSals.) WELL' ' OTHER .Go5.. Injection NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At sUrface 332'S & 1014'E of NW cr Sec. 12, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18' Gravel Pad i4,~. ...... Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) 5. APl NUMERICAL CODE 50-029-20206 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME ... [;rudhoe Bay Unit 9. WELL NO. NGI #6 10. FIELD AND POOL, OR WILDCAT Prudh0e Ba Field Pnnl 11. S£C..,-T;[~[., ~.; (BOT'rbM HOLE OaJECTIVE) Sec. 2, T11N, R14E, UM 12. PERMIT NO. 76-29 ~ort, or Other Data SUBSEQUENT REPORT OF= PULL OR ALTER CASING WATER SHUT-OFF REPAI RING WELL MULTIPLE COMPLETE FRACTURE TREATMENT ALTER lNG CASING ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* CHANGE PLANS (Othar) (NOTEI Report results of multiple completion on Well Completion or Re¢ompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to repair downhole tubing leak in well. A 13-5/8" 5000 psi RSRRA BOP stack will be used. It will be pressure tested each week and operationally tested each trip. A string of 7" - 29# N-80 tubing, packer, and necessary provisions for subsurface safety equipment will be re-run. A 5000 psi WP wireline lubricator, tested to working pressure will be utilized with all wireline work. Well will be back flowed to burn pit for removal of workover fluid then water washed with treated water for removal of chloride build-up in formation and back- flowed again to burn pit for final clean-up. Well will then be reconnected as gas injection well. Work will begin approximately July 5, 1978. 16. I hereby certify that the foregoing iy2true and correct TITLE.D. istrict Drilling Engineer (This space for State office use) CONDITIONS OF APPROVAL, IF AN"~ U TITLE PETROLEUM ENGINEER See Instructions On Reverse Side OA?S,,,JUNE 22, 1978 Approved Copy Returned Atlanti;RichfieldCompany North American Producing Division North Alask~-/--~strict Post Office ,, .360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 31, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 6-5 Pe.rmit No. 78-20 ~44- 2-11-14) No. 76-29 Dear Sir: Enclosed please find the Monthly' Report of Drilli.ng Operations for the above-mentioned wells. Very truly yours, Frank M. Brown District Drill i.ng Engineer FMB: j h Enclosures ~ No. P-~ STATE ALASKA REV. &- 1-70 SUBMIT ~ DUPLICATE OIL AND GAS CONSERVATION COA/V~ITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS o,L []] o,, []] aT,-., Gas Injection WKLL Wl~LL ~, NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL 332'S & 1014'E of NW cr Sec. 12, T11N, R14E, UM AP1 NU~{ERICA~ CODE .gn-n?q-2o2o6 6 LEASE DESIGnAtION AXD SEI~IAL NO. ADL 28302 ? IF INDIAI~T, ALO¥1E~ OR TRIBE NAME 8. L,~IT FAP~ OR LEASE NAME Prudhoe Bay Unit g WELL NO NGI #6 (44-2-11-14) 10. FI~.T~D AND POOI~ OB_W~LDCAT ~rudhoe [~oX [ield - vruano¢ UI-~ voo~ 11. SEC.. T., R., 1%~.. CBO~I'OM HO~ Sec. 2, T11N, R14E, UM 1~-. PERMIT NO. '76-29 13. REPORT TOTAL DEPTH AT END OF MON'I'H, CHA~NGES IN HOLE SIZE, CASING AI~D CEMENTING JOBS INCLUDING DEPTH SET ~ VOLtrMES USED. PEH.~O~TIONS, TESTS A.N'D P,.ESULTS FISHING JOBS. JUnK IN HOLE AND SIDE-TRACKED HOLE A~TD A_~TY OTHER SIGNIFICA/qT C'H.A.NI3ES IN HOLE C'ON-DITIONS. Report of Operations for the Month of May, 1978 Perforating operations still suspended pending evaluation. JUN - 6 D;vision of Oil and Gas gu,, ..... n,';.i:~', Anchorage. 14. I he.by c~l'tt~that_~ /~-~.-~th-/~reK°ing is ~e ~ ~ S~G~ //~~~~ :~ District Drill lng Enqine~ 5/31/78 NOTE--Report on this fo~ is required for ,each calendar ~th~ regardless of the status of operations, and mast ~ flied in dupli~t/ with tbs oil and got conservotlon commi~ee bythe 15~ of the suoc~ding mon~, ~le~ otherwise directed. AtlanticRichfieldCompany North Ameri"'~"Producing Division North Alask" strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 10, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AlaSka 99501 Subject 4-2-11-14) ~-Pt~t No. 76~29 DS 1-18 Permit No. 78-29 Dear Sir' Enclosed please find the Monthly Report of Drilling Operations for the above-mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer /am EnclPsUres Form No. ~q7. ~- I-?0 STATE OF ALASKA SUBMIT 12~ DLrPLICAT~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS oil [-] o,, []] o,,, Gas Injection WKLL w~LL 2.NAME OF OPERATOR Atlantic Richfield Company P.O. Box 360; Anchorage, Alaska 99510 4. LO~A~ON OF W~T.T~ 332'S & lO14'E of NW cr Sec. 12, TllN, R14E, UM ~-AP! NUXEmCAL CODE 50-029-20206 6 LEASE DESIGNA~ON AND S~IAL NO. ADL 28302 IF INDIAN, AL,OTiEE OR TRIBE NAME 8. L,~IT FARM OR LEASE NAME Prudhoe Bay Unit NGI #6 (44-2-11-14) 10. ¥i~.!,r) AND POOL, OR W. ILDCAT Prudhoe Ba Field ., Cl~/ Pnnl D~,,,~hn,~ if. ~T~'~-~ 1%, RZ CB6~'6~ HOt~ o~zrrv~ Sec. 2, TllN, R14E, U~ 1~.. PER.MIT NO. ? -29 '13. REPORT TOTAL DEPTH AT END OF MONTIt, CHA. NGF-,S IN HOLE SlZlg, CASING AND CEMENTING JOBS INCLUDING DEPTH SET A/qD VOLU1VIES USED. PERFOi:L%TIONS. TESTS ANT) iqIgSULTS FISHING JOB~. JU'NK IAI HOLE A.ND SIDE-/RACKED HOLE A~D ANY OTHEi~ SIGNIFICANT CH. ANGI~ IN HOI.2i: CONDITIONS. Report of Operations for the Month of April, 1978 Perforating operations still suspended pending evaluation. Gas injection has been resumed. 14. 1 hereby certif.Y that th~ fore~,oing is true a.nd correct s~G,,'~. .. _~ ~.~:~_~District Drilling Enqinee~^~ May 10, 1978 NOTE -- Report on this form is required for each calendar month~ regardless of the status of operations, and must I)e flied in duplicate wit/I the oil and gos conservation commiftee bythe 15th of the succeeding month, unlee8 otherwise directed. Atl~nticRichfieldCompany . North Ameri~Producing Division North Alasl(~' ~strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 7, 1978- Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' NGI #6 (44-2-11-14) Permit No. 76-29 Dear Sir' Enclosed please find the Monthly Report of Drilling Operations for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosure Form No. P-4. REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS OIL [--] ~ELL GAS C] Gas Injection WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360; Anchorage, AK 99510 4. LOCATION OF WELL 332'S & lO14'E of NW cr Sec. 12, TllN, R14E, UM 5. APl NUMERICAL CODE 50-029-20206 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN'ALOTTEE OR TRIBE NAME. 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. NG I #6 (44-.2-11-14) 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 2, T11N, R14E, UM 12. PERMIT NO. 76-29 13. REPORT TOTAL DEFI'H AT END OF MONTH, CHANGES IN HOLE SIZE. CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED~ PERFORATIONS, TESTS .SAND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDn-IONS. · Report of Operations for the Month of March, 1978 . Rig...ged up to perforate 3/24/78. Ran in hole to pull ball valve, unable to retrieve it. Left fishing tools and some wireline in hole. After several unsuccessful attempts to retrieve fish, well suspended 3/31/78 to evaluate well condition. Ball valve is in place and operational. 14~ · S,CNED~/'~~ g...~ '., TITLE District Drlg. Engineer '.ATE _ '.NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the s~cceedin9 rnonth.,nless otherwise directed. Aflantic~hfieldCompany North Amerjp,~, Producing Division North Alas:/' .~trict Post Office Box 360 Anchorage, Alaska 99510. Telephone 907 277 5637 February 23, 1978 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject~o-2-11~4). 76- NGI 2 (11-7-11-15) Permit No. 75-52 Dear Sir- Enclosed please'find a Sundry Notice outlining our plans for the above-mentioned wells. Very truly yours, F. M. Brown District Drilling .Engineer /am Enclosure Form 10-403 REV. 1-10-73 Submit "! ntentlons" in Tripllcate & 0'Subsequent Reports" in Duplicate STATE OF ALASKA O! L AND GAS CONSERVATION COMMITTEE . . SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICAT ION..FOR PERMIT---" for such proposals.) WELL! I WELL OTHER Gas Injection - ~- NAME Of OPERATOR - . · 3. ADDRESS OF OPERATOR i. ' P~0. Box 360; Anchorage AK 99510 4. -LOCATION OF WELL. . - . At surface ~332'S & lO14'E of NW cr Sec. 12, TllN, R14E, _ - 13. ELEVATIONS {Show whether DF, RT, GR, etc.) ' - ' i.- ::', 18' GraVel. Pad . . . 14. Check Appropriate Box To Indicate Nature of Notice,' Re 5. APl NUMERICAL CODE 50-029-20206 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN., ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAi~/IE Prudhoe Bay Unit 9. WELL NO. NGI #6 (44-2-11-14) 10. FIELD AND POOL, OR WILDCAT ! Prudhoe. Bay ~ Sadlerochit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec.. 2, T11N,. R14E, UM 12. PERMIT NO. 76-29 )crt, or Other Data NOTICE OF INTENTION TO; TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS Perforate SUBSEQUENT REPORT OF-' WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate additional selected intervals within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. ~ A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. All perforations will be made with hollow carrier type guns at 4 shots per foot. After setting and testing the downhole safety valve, the well will be blown down and flared to the pit for cleanup only. A static bottom hole pressure will then be taken. Estimated Start Date- 3/14/78 REC[IVED I hereby certify that the foregoing Is true and correct SIGNED ~ ~ (This space for State office use) CONDITIONS OF.~'APPROVAL, IF ANY: District Drilling Engineer TITLE DATE TITLE .... : .,,4__ .- DATE See Instructions On Reverse Side 2/23/78 ,3/-V 7, Approved Copy O. K. ~th, Jr~~ Di~ Ben T,,~,tulmen Subm=fa~ Safety valve (SSS~ and Surfac~ Safety Val~ (SSV) Tests Arco' s NGI-5 . ~ at BP ~.ton~ ~ 11,15 AM. Wea~ +35~ F, clear skies, no wnm. I977 - ~ SSSV and SSV c~ BP's J-7. ~ ~ N~I-5. Tests ~ at 9:~ ~ ~ ~ ~ ~ ~~~~ ~0 ~ig. ~~ ~ ~ ~ ~ ~ ~ ~ ~ 4~ p~g ~~~ f~ ~~. ~~ ~~ at 10:30 ~ ~ a fie~ I ~ Deedhorse via ~ ~ at 1:30 PM, arriv/n~ in Anchor~ at 3:05 PM andat my ~ at 3:35 PM. ~...s,.:~: ~ wi~ ~sf.l ss~ ar~ ssw tests c.. Arco's NG~-5. Satisfactory.-. ~.:-Type Inspecti. on.- .' Satisfactory ~Type Inspection Yes N° .... Irem (.)Location,General Yes No 'Item. ( ) BOPE Tests (). ( ) -..;.1.~'~'Well Sign .... ( ) ( ) 15 "Casing set ~ ( )- ( ) 2. General Housekeeping ( ) ( ) 16. Tes~ fluid-( )wt,)mud ( ) oil ( ) ( ) ~. Reserve Pit-(. )open( )filled ( ) ( ) 17. Master Hyd. Control Sys.- .psig (-,~ ( ) ( ) 18. N2 btls , psig .~ ( ) -4~:Rig · '~ · (~Safety Valve Tests ( ) ( ) 19. Remote Contr~'ls (~ ( ) 5. Surface-No. Wells ~ ( ) ( ) 20. Drilling spool- "outlets (~ ( ) -~ 6. Subsurface-No. Well~~ ( ) ( ) 21. Kill Li.ne-( ) C~valve ( ) Well Test Data ( ) ( ) 22. Choke Flowline ( ) HCR valve ( ) ( ) 7. Well Nos. , , , () ( ) 23. Choke Manifold No. valvs fl~s ( ) ( ) -8. Hrs.. obse~.~ ~ ~ ( ) '( ) 24. Chokes-(. )Remote( )P.os.(~dj.- ( ) ~,~:.~' ) 9. BS&W. , , , ( ) ( ) 2.5. le'~t Plug~( )Wellhd( )csg( )none ( )~ ) 10. Gr. Bbls. , , ~ ( ) ( ) 26. Annular Preventer,~sig - ( ) Final A~andonment ( ) ( ) 27. Blind Rams,~psiq ( ) (). tl. P&A Marker ( ) ( ) 28. Pipe Rams ~psiq ( ) (') 12. Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock psig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve psi¢ . ( ) ( ) 14. Pad leveled ( ) ( ) 31. Safety Floor valve~~BV '( )Dart Total inspection observation time/~hrs/d~ Total number leaks and/or equip, failures 'Remarks . cc' '~¢~.~ .~¢~¢~_,~¢..~ Notify in days or when ready Inspected by R E C E IV E D ATLANTIC RICHFIELD COMPANY, PRUDHOE BAY FEBRUARY, 1977 DMsien cf Oi~ ~ C~ C~nse~;ation The first flow of gas to the Field Fuel Gas Unit commenceid on February 6 from the NGI (North Gas Injection) Well #6 after a six-hour cleanup flow to the well pad burn pit. Initial gas into the plant was flared from the inlet separation facilities for approximately 18 hours while liquid levels were being established. On February 7 gas was opened through the dehydration and hydrocarbon conditioning equipment and flared while plant operating conditions were being established. On February 8 specification gas was turned to the Field Fuel Gas System for delivery to the BP Power Generation Plant. I SEC CONFER: FILE: ~' -- The attached report shows a flared vOlume of 390,013 MCF. Further identification of this volume is as follows: 281,531 MCF - Flared downstream of FFGU process 81,732 MCF - Flared from Natural Gas Liquids (NGL) flash drum 26,750 MCF - Initial flare to burn pit and from separation facilities 390,013 MCF Other volumes shown on the report are 16,890 MCF "Used" in the Central Compressor Plant and FFGU fuel systems and 89,724 MCF "Sold" into the Field Fuel Gas System for delivery to the BP Power Plant (An additional volume of. gas was delivered from the Crude Oil Topping Plant for use in the BP Power Plant - See COT report). NGI Well #7 was originally planned as the startup gas source for the FFGU. This well is equipped with 4 1/2" tubing and a warm glycol circulating system to prevent formation of hydrates through the permafrost zone at lower rates. Downhole problems, however, delayed the use of this well and it was necessary to use the"standby" NGI Well #6 during the month of February~ NGI #'6 is equipped with 7" %ubing (tubing size in all the "injection" wells) and~does not have a glycol circulation system. While this well is in use it is necessary to maintain flows in excess of 20 MMCF/day to prevent the "loading up" of liquids in the ~arge tubing, string. Excessive slugging of liquids cannot be handled in the separation equipment at the FFGU. Flared volumes from the FFGU during the month of February were therefore in excess of our planned operation due to the problems encountered with NGI #7 well. E. L. Berdon ~*!;?'~ii:?=" ~ ..,,.'"' DEPAR1TIEHT OF HATURAL RESOURCES ?;!!?.~;~'"* ' Divtston of 0il a~ Gas Conservation .'[ . ~?.~':- : ':- :' Di~c~r ' ' ~~ ~"' .... for Paying Quantities Tes~ ..... ?:At your request we. have revtewed the t~iG! Ho. 6 well on the captfoned ;.?: l ease . to .:~termt ne if It ts ~pab!.e:.of p...ro, ductng, in paying quantities, No~'~'is Uell is cempleted ~n the' gas cap of the Prudhoe Bay ' * 'Sadlerochtt" Pool. A large pay section ts perforated, tubing is installed and the well is reported by the operator to have produced at a rate of 35 r~4CF of gas per day preparatory to t ts use tn conetsstonlng the P~udhoe 8aye. central compressor plant. A State 1nspector witnessed a surface tubing p~essure of 3050 pstg and a short duration gas flow to a ptt~wh.tle testtng the subsurface safety ~Valve on ~tanuary 10, 1977, This well is capable of producing gas .-- ,: . . · - .. ~4~1B STATE Division 'of _Minerals & Energy Management J / ~g,, File: 3.14 500.41 · to, J'-- Hoyle Hamilton, Director Division of Oil and Gas mo~ Pedro Denton Sectio~,~'~~,~ Chief, M/nerals DATE : SUBJECT: February 1, 1977 ARCO's ltr. of '1/26/77 reques Enclosed is a copy of a letter frc~n Atlantic Richfield ~y that lease ADL 28302 be put on a rain/mum royalty paying status. Please confirm whether the well identified in the letter attachment is capable of producing in paying quantities. RECEIVED FE6 - 1977 Dlv~lon of Oil and Gas Conservation North Alaska District Post Offic(~'%~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 26, 1977 State of Alaska DePartment of Natural Resources Division of Minerals and Energy Managemen.t 323 E. 4th Avenue Anchorage, Alaska 99501 Attention' Mr. Pedro Denton, Minerals Officer Leasing Section Re- Request for Minimum Royalty Status ADL-28302 Dear Mr. Denton- A well has been completed on State of Alaska Oil and Gas Lease ADL-28302 which is capable of oroduc- ing oil and/or gas in paying quantities, as evidenced by data furnished to the State. Attached for your .information is a copy of such data. In accordance with the lease terms, it is now appropriate that we pay minimum royalty on. this lease, rather than annual delay rentals. We ask that you furnish us with a Decision Letter to that effect. Very truly yours, ATLANTIC RICHFIELD COMPANY C. R. McClain Senior Landman CRM/gr Attachment RECEIVED FEB s Anchorage HGi ~=r [,_,.., U,,.,,fL & CLEA~i-..UP O~ 12/G/76 br<,;'n~.,., installing & tstg sur'Fac:n,_ equip. RU lubricator. Retrieved dummy valve, Press tstd wire!ine uni[:. Per-F'd 2 holes per ft 9z$73' - 9479' & 9460' - 9q.~' Tb9 press after shooting 900 psi. Displ 15 bbls diesel, max press, ~ ~700 .usi 5 ed to 1400 psi slowly. Displ ~"-itional~,,~ 45 bbls 0 2400 psi, Perf'd 9202' - 9222', 9163' - 9t78', 9159' - 9163', 9197' - 9202', 9127' - 9137', 9107' -9127', & 9053' - 9073' w/2 holes per ft, total of 5 gun runs. Tbg press 1350 psi, Perf'd 90q-3' - 9053' & 90!E"., - 9028' w/2 ho]es per ft. Press tstd lubricator. Lower master valve leaked thru stem. Energized stem packing. Leak stopped. RU surface storage & pumping equipment to kill well w/CaC12 wtr & chgd lower master val~,p.~. _~nstall~J=~, lubricator & tstd against swab valve to 4100 psi OK. Ran 5~" XN plug. Stopped in XA sleeve. Tool coated w/heavy thick substance resembling cosmoline. Attempted to run 4~" PX plug & stopped ~ top of tail pipe. Dry ga~ m surface, Bled gas press off lubricator & displ tbg w/diesel followed by 340&hls of 'lo.9 CaCt9 wtr. Displ salt wtr to perforations. RU slick line, ~ lu$~,c~tor tD 4000. Attempted to run 7" bushing for hall valve. Fei! s-lowi~fo 347'.. POH. Had same heavy waxy material ~ -qualizing pr....~ & aro~:. :ys. Ran parafin cutter to 202' & jarred out of ~le. Tbg press 350 psi. Sled off dry gas. Made 2nd attempt ~ 4~" X : ~ug. Stopped in top of isail pipe. Had to jar out of hole. Ve. ry tight .or first ~0'. Plug totally covered w/waxy material. Bled off dry gas from llO0 to, 550 psi. RU Halliburton & pulled ahead of lO 8 ppg CaCl~. Pumped 365 bols. Press went from 2100 to 1600 psi ~ end o~ job. Shu~ in pumps. Press bled off to lO0 psi in 5 minutes. Bled off dry gas. Pressure went to zero. ND wireline unit & bled off dry gas intermittently & had press ~ 300 psi w/CaCl in tree. Intermittently bled dry gas.~: ga.s cut ?,C1e wtr. Pumped bac~ equivalent volumes ~aCt2 wtr w/pressure~ varying ]'rom'-300 psi to 850 psi ~',/Tlnal press 600 psi.. Press declined from 600 to zero (J 0500 on 12-16-76. Well dead. ' STATE of ALASKA DEPARTMENT OF NAl~URAL RESOURCES Division of Oil and Gas Conservation TO: V Hoyle H. Hamilton ~,'~ ~., ~ Director Thru: Lonnie C. Smith Chief Petroleum Engineer FROM: Ben Le~4orman ~_~ Petroleum Inspector DATE : January 26, 1976 SUBJECT: Sub-surface Safety Valve and Surface Controlled Safety Valve Test On Arco's NGI-6 Friday, Janua. ry. 7, 1977 - I departed my home at 7:30 AM for a 8:00 AM ~OWu~ 'and 9:00 AM deParture via BP charter for Deadhorse. The flight was delayed due to loading of cargo and departed at 9:45 AM, arriving in Deadhorse at ll:lO AM. My utilization of BP's charter and subsequent checking into BP operations was precipitated by a phone call to my home on the evening of January 6th from Swede Swenson, BP drilling superintendent, advising herculite would be laid on the pad of their Sag Delta #3 on the following day. This was not to occur as winds were sustained 25 mph on arrival in Deadhorse. Temperature-8°F, ceiling lO00. ~tu~day, Jan~ry._8_,_ 1977- Standi~ by at BP operations. Sunday,.. January 9, 1977 - Witnessed partial laying of herculite on BP's Sag Delta #3. Monday, JanuaKy~ lO, 1977,- Ken Jones, Arco drilling foreman, picked me up-atBP ope'~ions at--B,30 AM and we arrived at NGI-6 at 9:05 AM. Drilling rig on location was Challenger #51 whose toolpusher was Ray Moore. Tests began at 9:30 AM with the ball valve set at 4031' and open. Shut in pressure was 3050. SCS¥ was then closed and pressure bled to zero and monitored for five minutes. SCSV was then opened and tubing pressure returned to 3050. Control line was then bled to zero, indicating ball valve had closed. However, subsequent bleeding to pit did not reduce pressure, indicating ball valve had not closed. Control line was repressured to 4000 psig and balance line to 3000 psig. Control line was then bled to zero and tubing pressure bled to 2700 pstg through choke in manifold to flare pit and monitored for five minutes. Subsequent bleeding to 2500, 2000, 1000 and zero, each step monitored in excess of five minutes, indicated full closure of SSS¥. Tests were concluded at 12:00 noon. A field inspection report was prepared with the original going to Ken Jones, a copy mailed to Bob Hines, 'and a copy attached to this report. ~* ~!1~ -2- Arco's NGZ-6 January 26, 1977 l~hfle stt1~ on ~oca- t~on crew ~as butto~ng up t~he tree ~n pr~p~ratJon f~r mo~lng tim ~lg Mgm tt ~s dlscoverc~l the $C$V ~mu]d not close, ATthough wellhead pressure was. zero and pilot pressu~ ~as zero, the $CSV remt~ open, Co.c~ns.s of eplnto, tins that the sprtng tn the actuator ~s broke, am] Arco's Am:borage offJce ~s contacted fo~ a repat~ma~ to deten~,e ~ exact cause of thts m]fu~ct~o, and effect repairs, ! asked fer .Ke~ ~lones to advJse me as soon as these repairs Before leavtng the locat1~m ! con.tactod Arky Franklln, dr~111ng forerun at Gull ;slamJ f2, Mm adV~ tmmr kelly valve and 3" Shaeffer gate valve ~ust upstream fram ~ '~ superc~e ~, the choke manlfold h~d been repa~d ami success~lly tested t~ 5000 ps~g. Tuesday., Janu~y 11, 19~- Sta~1~g b~ at BP operations, -_ ....... . . ._ ~ .... _:=: _ - .. .;_, . ~,= ~~'' r'~~r~!2.,....1977- Standfng by at BP operations. ~Thu~~~..~ry 13, 19,.7~' - Heathered tn at BP opera.tlons. Temperatur~ -21'~ F,-S:~ta'f~'wi~s--.~- 50 FIPH from EWE, blo~tng sno~, chtll factor -850F. ~F~Iday.,___-da~ry 14, t977 -.! departed Deadho~se vfa BP charter at 1:20 a~Jvlng 'In ~~~"'a;~,- 2.45 PH and at my home at 3:15 :b~Z ~tnessed successful test of SSSV on Ar~o's NGZ-6. H(w~ver, ~ 'i c~ked by Axelson repalman to deto~mlne If a malfunction exists. Attacheent ' .~'~.~]Ope~o~" r*~'.- ~.~~ -~' "~ ' ..................... ........ Represen~e~' D. y~. ~ -~~ -Name.~-&_ . .... Number_ .~.~_ __-_ ,~..... .SatiSfactory Type Inspection Satisfactory ' ~S~' Inspection ..-.:~Y.~ -No:' Irem (') Location,General. : Yes- No Item--().e '~ BOPE Tests '(~) .]~(), 1 Well.Sign . (.) ( )~;- 15.- "Casing set ~ ' (~.) ( ) 2. General Housekeeping (.) (-) 16' Test fluid-( )wt,)mud ( ) Oil .( ) ( ) 3. Reserve P~it~(' )open( )filled- ( ) ( ).- 17.. Master. Hyd. Control Sys.- psig ( ) ( ) 4. Rig . - '. ,. (') ( ) 18-N~ btls. , , , ]sig ' (.~Safet~.Valve Tests ( ) ( ) 19 R~mote ContrOls (~-' ( ) 5. Surface-No. Wells~ ( ) ( ) 20. Drilling spool- "outlets (~-~)-- ( ) 6. Subsurface,No. Wells / ( ) ( ) 21. Kill Line-( ) Check valve ( ) Well Test Data ~" ( ) ( ) 22. Choke Flowline ( ) HCR valve ( ) ( ) 7. Well Nos. , .. ,__,__ ( ) ( ) 23. Choke Manifold No. valvs flgs (). ( ) 8. Hrs. obser .,~, ,~ ( ) ( ) 24. Chokes-( )Remote( )Pos.(~dj. ( ) ( ) 9..BS&W ,_ , , ( ) ( ) 25. Test Plug-( )Wellhd(')csg( )none ()- ( ) 10. Gr. Bbls. , , , ( ) ( ) 26. Annular Preventer, psio ( )Final Ab~nd6nment -- ( ) ( ) 27. Blind Rams, psig ( ) ( ) 11. P&A Marker ( ) ( ) 28. Pipe Rams psig ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock ~psig ( ) ( ) '13. Clean-up ( ) ( ) 30. Lower Kelly valve ~sig ( ) ( ) 14. Pad leveled ( ) ( ) 31. Safety Floor valves-( }BV ( )Dart Total inspection observation time~hrs/d~ Total number leaks and/or equip, failures Remarks ,- days or when ready Inspected by ~.~, ATLANTIC RIC~IFI£LD CO~,~' North Alm~ka District Engineez -~' CONFIDENTIAL DISTRIBUTED T~ STATE OF ALASKA TRAN SM I TTAL From: J.A. Rochon/p. Hells~rom Date: Jan. 4, 1977. .- Well N~_~,.e' NGI # 6 Transmitted herm~ith are the following for the subject well' No. Scale Xerox . Sepia BL Line BHC Sonic/Caliper Log BHC Sonic/Caliper - Garana Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutro~ Log Core Analysis - Interval Core No. Core Description (SWC) ' Interval 'Core Description [Cony.) - Core No. Directional Survey - Gyro Single Shot Multishot Drill Stem-Test - Test No. Dual Induction Laterolog Formation Density Log Fomation Density Log/Gamma Ray Gm~a Ray/CCL/Neutr0n Laterolog Location Plat Microlat~rolog ~ ~iicrolog Mudlog- Inter~al ' Sample Log (A.R.Co'.)-Interval) Synergetic Log TVD-DIL TVD-Porosity Log -_ St! ~Receipt Acknm~ledged For' Date' · Please .return receipt to: .' ,, Atlantic Richfield Company North Alaska Engineering blanager~[~"~ P. o. Anchorage, Alaska 99510 .~tlanticRichfieldCompany .---., North AmerF"-~Producing Division North Alask strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 11, 1977 Mr. Hoyle Hamilton State o f Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: NGI #6 (44-2-11-14) Permit No. 76-29 Dear Sir: Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned well. Very truly yours, F. M. Brown Dis trict 'Dri 11 ing Engineer FMB/jw Enclosure RECEIVED Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10~73 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE O~L I--1 GAS I---I WELLi~J WELLL..J OTHER~-~S Tnj ection SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 2. NAME OF OPERATOR Atlantic Richfield Company 5. APl NUMERICAL CODE 50-029-20206 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 360, Anchorage, Alaska 99510 NGI #6 (44-2-11-14) 4. LOCATION OF WELL At surface 332'S & 1014'E of NW cr Sec 12, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18' Gravel Pad 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 2, TllN, R14E, UM 12. PERMIT NO. 76-29 )ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF L_._.J REPAIRING WELL FRACTURE TREATMENTH ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Wash tubing~ set ball. valve~ te.st (NOTE: Report results of multiple completion on Well well Completion or Recompietion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. See Attached. RECEIVED JAN 1 31977 Dtvi$1on ol 0il and Gas Conservation Anahorage 16. I hereby certify that the foregoing is true and correct S,GNED ~~ ,,_T,TLE Dist, Drilling Engineer (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side NGI #6 Recompletion Sundry Notice of Subsequent Report Accepted ri9 @ 1800 hrs 12-19-76. PU & stand back 2-3/8" tbg. Mixed mud. RU snubbing unit. Press tstd BOPE, choke, kill lines, & manifold. Tstd xmas tree valves, choke & kill lines, connections on stand pipe, & lower kelly valve. Opened master valve, press 2100 psi. Bled dry gas to 1700 psi. Pumped 370 bbls CaCI~ wtr, max press 2300 psi final press 0 psi. RIH w/2-3/8" tbg to 9496'. Ch~d over from CaCI~ wtr to 10.3 ppg mud. POH w/2- 3/8" tbg no mud gain or loss. Make up washlng tools & 7" cs9 scraper. Washed down w/2-3/8" tbg to 4025'. Circ & cond mud. Observed well for flow prior to POH. No flow back. Very little rec @ completion of wash @ 4025' POH w/2-3/8" tbg after washing 7". Make up 6" brush & washing tools'& RIH w/2-3/8" tbg to 4211' Displ wtr base mud w/CaCl~ wtr after pumping 135 bbls press increased ~nd circ decreased. At 140 ~bls had no returns. Shut down pumps, found evidence of freezing in circulating head. Pulled & LD 3680' of frozen tbg, pulled & stood back bal of 2-3/8" tbg string. Reran 2-3/8" tbg to 4201' & rev circ warm CaC1 wtr w/full returns. Circ & cond 10.9 ppg CaC1 wtr through 2-3/8" tbg @ 42~1'. POH. RU & press tstd lubricator. Ra~ & set Otis RB ball valve in RB nipple. Press tstd cont lines to 5000 psi. Opened & closed ball valve several times, operation OK. Closed ball valve. Observe well for flow. Installed Gray BPV in wellhead. ND xmas tree & replaced lower master valve. RU & press tstd xmas tree 5000 psi. All valves OK. RU lubricator & retrieved ball valve asbly. RD lubricator. RU & press tstd snubbing unit. Dropped 2 jts of 2-3/8" tbg thru snubbing unit slips. Chgd over from CaCl~ wtr to 11.1 ppg wtr based mud @ 4201 '. Ran 3-1/8" x 20" dummy gun, tagged top offish @ 7770', worked down to 7838'. POH. RD wireline unit. RIH w/2-3/8" tbg & spear asbly. Engaged fish @ 9429'. POH. LD fish. RIH w/2-3/8" tbg. Displ mud w/lO.9 ppg CaCI~ wtr @ 9429'. Breakthru @ 348 bbls. POH. RD snubbing equip. RU wirel~ne unit. Ran 7" ball valve. Flushed control lines. Ball valve did not seat. POH w/ball valve in closed position. Dressed ball valve. Tstd lubricator to 5000 psi. RIH w/7" ball valve asbly, run #2. Could not set. POH. RU to run 7" x 4-1/2" insert. Lubricator leaked. Repaired & press tstd lubricator. Run #3 w/7" insert could not set. Run #4, redressed & reran & set 7" insert. Run #5, ran 4- 1/2" ball valve. Could not set. Run #6, redressed & reran & set 4-1/2" ball valve. Could not press tst. Run #7, RIH to retrieve 4-1/2" ball valve. Retrieved 4-1/2" ball valve asbly w/evidence of packed sand. Run #8, RIH retrieved 7" x 4-1/2" insert. RD wireline equipment. RU & press tstd snubbing equipment. RU & RIH w/2-3/8" tbg. Washed & brushed 4030' - 4066'. RIH to 43!6' & circ CaCle wtr. No excess sand in returns. POH. RD snubbing equip. RU & press t§td lubricator. Run #9,'RIH w/7" RB ball valve asbly. Could not set. POH. Run #10, RIH & set 7" x 4-1/2" RB insert. Ran & set 4-1/2" Otis ball valve "RB" nipple @ 4031'. Press tstd balance_ & control lines to 5000 psi. Left ball valve closed w/3500 psi on balance line. RD lubricator. RU & press tstd snubbing unit. RIH w/2- 3/8" tbg & chgd over from CaC12 to diesel @ 3970'. LD tbg & RD snubbing unit. RU flow line & tstd manifold. Opened ball valve & flowed well, unloaded diesel then CaCl2 wtr w/gas to surf after 65 minutes. Flowed well RECEIVED JAN 1 51977 Division of 011 and Gas Conservation Page 2 NGI #6 R-C on various chokes. Final choke size 48/64". Upstream 2600 psi, downstream 950 psi, temp ilO°F. Stabilized shut in press, 3025 psi. Installed & tstd Otis lubricator. Ran press recorder. RD lubricator. NU xmas tree. RU & pumped methanol in well. Opened & closed ball valve. Bled press to zero & observed for 30 minutes OK. Secured well. Released rig @ 1400 hrs 1-10-77. REC, EIVED Division of Oil atld Gae C, on~ew~tton Atla. nticRi~fieldCompany . ~ North Amerr,"'"~ Producing Division North Alask, strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 3, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- NGI #6 (44-2-11-14) Permit No. 76-29 Dear Sir- Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned well. Very truly yours, C. R. Knowles District Drilling Engineer /jw Enclosure RECEIVED DIYtlI~ E~ 0tl ~ I~ . Form 10-403 REV. 1-10-Y3 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELL L.J OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 332'S & lO14'E of NW cr Sec 12, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18' Gravel Pad 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20206 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. NGI #6 (44-2-11-14) 10. FIELD AND~'OOL, OR WILDCAT Prudhoe Bay - Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 2, TllN, R14E, UM 12. PERMIT NO. 76-29 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) Perforati no (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. See Attached. RECEIVED rJAN ' 6 1977 I)ivlml~ et 0ti ;nd Grot Can~rvatlon 16. IherebycertifythattheT~olngistrue/~dcorrect SIGNED · . _ (This space for State office use) APPROVED BY. CONDITIONS OF APPROVAL, IF ANY.- TITLE DATE See Instructions On Reverse Side NGI #6 PERFORATE & CLEAN-UP On 12/6/76 began installing & tstg surface equip. RU lubricator. Retrieved dummy valve. Press tstd wireline unit. Perf'd 2 holes per ft 47~Z~__- 9~_479'._ & 9460' -~ Tbg press after shooting 900 psi. Displ.15 bbls ~~-~ss 2700 psi. Bled to 1400 psi slowly. Displ additional 45 DDls @ 2400 psi. Pe~rfId 920~' -.92~2', 9163 ~._-_ 9178'~' 9159' - 9163', 9197' ' ' ' ' '~--~ __-_.~202~.~.,_~..9].272~9]_.~.37'.~~~9!27 , &~9053 - 9073 w/2 holes per f---~-~, .{otalf~.~f 5 gun r~ns. Tbo~'-p~'eS"~"~'1350'psi'. Per'f,'d 9043' .... ~...90_5.3.! & 9018' - 9028' w/2 holes per ft. Press tstd lubf~Ea'i~'6~"~'"-L6wer m~ster valve ~-ked thrU--~-tem. Energized stem packing. Leak stopped. RU surface storage & pumping equipment to kill well w/CaClp wtr & chgd lower master valve. Installed lubricator & tstd against swaD valve to 4100 psi OK. Ran 5½" XN plug. Stopped in XA sleeve. Tool coated w/heavy thick substance resembling cosmoline. Attempted to run 4½" PX plug & stopped @ top of tail pipe. Dry gas @ surface. Bled gas press off lubricator & displ tbg w/diesel, followed by 340 bbls of 10.9 CaC1, wtr. Displ salt wtr to perforations. RU slick line. Tsts lubricator t~ 4000.. Attempted to run 7" bushing for ball valve. Fell slowly to 347'. POH. Had same heavy waxy material @ equalizing ports & around keys. Ran parafin cutter to 202' & jarred out of hole. Tbg press 350 psi. Bled off dry gas. Made 2nd attempt @ ~" X plug. Stopped in top of tail pipe. Had to jar out of hole. Very tight for' first 40'. Plug totally~covered w/waxy material. Bled off dry gas from 1100 to 550 psi. RU Halliburton & pulled ahead of 10.8 ppg CaC1,. Pumped 365 bbls. Press went from 2100 to 1400 psi @ end of job. Shu~ in pumps. Press bled off to 100 psi in 5 minutes. Bled off, dry gas. Pressure went to zero. ND wireline unit & bled off dry gas intermittently & had press @ 300 psi w/CaCl~ in tree. Intermittently bled dry gas & gas cut CaCI~ wtr. Pumped bacl~ equivalent volumes CaCI~ wtr w/pressures varying fromm300 psi to 850 psi w/final press 600 psi. ~Press declined from 600 to zero @ 0600 on 12-16-76. Well dead. ._ /~tlanti~lRichfieldCompany North Ame~'~'~'"'~ Producing Division North Alas. ..,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 22, 1976 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: NGI No. 6 (44-2-11-14) Permit No. 76-.29 Dear Sir: Enclosed please find a Sundry Notice outlining our plans for the above-mentioned well. Very truly yours,. C. R. Knowles District Drilling Engineer CRK/jw Enclosure Form 10-403 REV. 1-10-73 Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use ,'APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-029-20206 4. LOCATION OF WELL At su trace 332'S & lOl4'E of NW cr Sec 12, TllN, R14E, UM 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOI WEE OR TRIBE NAME 1. OIL r-] GAS N WELLI I WELL L--J OTHER Gas Injection 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company P'rudhoe Bay 3. ADDRESS OF OPERATOR 9, W~-LLNO. P. 0. Box 360, Anchorage, Alaska 99510 NGI #6 (44-2-11-14) 10, FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit Pool 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18' Gravel Pad 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: 11. SEC.,T, R., M., (BOTTOM HOLE OBJECTIVE) Sec 2, TllN, R14E, UM 12. PERMIT NO. 76-29 )orr, or Other Data SUBSEQUENT REPORT OF.- TEST WATER SHUT-OFF ~ FRACTURE TREAT ~ SHOOT OR ACIDIZE ~._ REPAIR WELL ~ (other) Wash tubing PULLOR ALTER CASING L-~ MULTIPLE COMPLETE ABANDON* CHANGE PLANS erforate WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) ..... (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCR starting IBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of any proposed work. Wire line work during the perforating completion encountered fouled tubing, making installation of the subsurface safety valve impossible. Atlantic Richfield company proposes to run 2-3/8" wash pipe in the 7" tubing and to PBD to clean out residue. A 6" 5000 psi Cameron QRC system and snubbing unit, tested to working pressure, will be utilized to run the wash pipe. After washing the 7" tubing, the sub- surface safety valve will be run and tested to certify its performance. The well will then be flowed to the burn pit for clean-up only. Bottom hole static pressures will be measured with down hole pressure bombs run on wire line. Estimated start date is December 22, 1976. certify that the for going is true d correct SIGNED --. ,'_ (This space for State office use) TITLE CONDITIONS OF2R'oVAL, IF ANyT See InStructions On Reverse Side _ DATE 12- Approved · '~: Returned ATLANTIC RICHFIELD C(tx~?A\]' ~ North Alaska District Engineerin~ '-IDENTIAL DISTRIBUTED TO: STATE OF ALASKA DIVISION OF OIL'& GA~ To: From: TRAN S M I TTA L OEO 1 '7 1976 DM$10N OF OIL ,,tiddD ANCHO~A~ J. A. Rochon/P. Heltstrom Date' Dec. 14, 1976 Well N~..e' NGI# 6 Transmitted herewith are the follc~ving for the subject well' Run No. Scale Xerox BHC Sonic/Caliper Log BHC Sonic/Caliper -' .Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VOL Compensated Formation Density Log Compensated Neutron-Fomation Density Compensated Neutron Log Core Analysis - Interval Core No.. Core Description (SWC) - Interval Core Description (Cony.) ~ Core No. Directional Survey- Gyro Single Shot Mul tishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma. Ray Gmmma Ray/CCL Laterolog Location Plat Microlaterolog ~iicrolog Mudlog- Interval Sample Log (A.R.Co~.)-Inierg'al) Synergetic Log TFO-DIL TVD-Porosity Log Sepia BL Line Receipt Acknm~ledged For' Date' Please return receipt to: By' Atlantic Richfield Company North Alaska Engineering Manager P. O. Box 360 Anchorage, Alaska 99510 # 94 AtlanticRichfieldCompany ~ North Ameri, e,-~. Producing Division North AlasI~ .~trict Post Office bux 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 20, 1976 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- NGI #6 (44-2-11-14) Permit No. 76-29 ....... 2 E"qG 3 .r. NG ....... 4 't'. ~':.~ ......... 5 ....... ~ 3 ....... DRAFT i ....... CONFER= FILE: Dear Sir- Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned well. Very truly yours, ¢. R. Knowles District Drilling Engineer /jw Enclosure Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10~73 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL I~-I OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 332'S & lO14'E of NW cr Sec 12, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 47'RKB 14, ' CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20206 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT,.FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. NGI #6 (44-2-11-14) 10. FIELD AND POOL, OR WILDCAT ~rudhoe Bay - Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 2, TllN, R14E 12. PERMIT NO. 76-29 )ort, or Other Data NOTICE OF INTENTION TO; TEST WATER SHUT-OFF F RACTU RE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSE(~UENT REPORT OF= WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) ].5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Accepted rig @ 1800 hrs 11-9-76. NU BOPE. Press tstd pipe rams. Unlanded tbg. Sheared out PBR. Displ ,d, iesel w/CaClp wtr. Pulled & LD 7" tbg. Set BP @ 90'. Chgd & press tstd 5 pipe rams. ~Retrieved & reset BP @ 1027'. ND BOPE. Installed new 9-5/8" csg pkoff & press tstd to 5000 psi OK. NU BOPE. Retrieved BP. Ran wireline junk bskt & gauge ring. Ran 247 its 7" 26# L-80 A-B modified tbg. Stabbed into PBR @ 7851' w/XA nipple @ 7773', ~le ~. Landed tbg @ press tstd tbg hgr to 5000 psi. ND BOPE. NU & pre~td xmas tree to 5000 psi OK. Pulled dummy valve. RIH. Opened sliding sleeve. Displ tbg w/294 bbls diesel, 5 bbls down anul. Closed sliding sleeve. Press tstd tbg to 3000 psi w/200 psi on anul. Reran dummy valve. Ran GR/CNL/CCL logs & dummy gun. RU for long term press tst. Released rig @ 1300 hrs 11/15/76. SIGNED (This space for State office use) TITLE APPROVED BY. CONDITIONS OF APPROVAL, IF ANY: TITLE DATE. -76 DATE See Instructions On Reverse Side AtlanticRichf..jeldCompany North Ameri~a~. Producing Division North Alas[ strict Post Office box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 23, 1976 Mr. Hoyl e Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 t:~- NGI No. 6 ~44-2-11 14) Subjec d~' ~ ~~'11-12-1 ~-14) NGI No. 8 (21-11-11-14) P I:' ,,' --. CONFER: FILE: Dear Sir: Enclosed please find a Sundry Notice outlining our perforating plans for each above-mentioned well. Very t~ulf yours, C. R. Knowles District Drilling Engineer CRK/jw Enclosures % Form 1 ~-403 ~ Subml t "1 ntentions" in Triplicate REV. 1-10-73 ~, & "Subsequent Reports" In Duplicate STAT E O F .A LAS KA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-029-20206 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 1. O,L F1 GAS FI WELLL_-d WELLL--J OTHER Gas Injection 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudh0e Bay 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, A1 aska 99510 4. 'LOCATION OF WELL At su trace 332'S & lO14'E of NW cr Sec 12, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18' Gravel Pad Check Appropriate Box To Indicate Nature of Notice, Re 14. 9. WELL NO. NGI #6 (44-2-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadler0chit Po01 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 2, TllN., R14E, UM 12. PERMIT NO. 76'29 )oft, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L.__a FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) Perforate PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL , FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates~ including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate the intervals as follows: 9003' - 9028', 9043' - 9073'; 9107' - 91 37'; 9153' - 9178'; 9197' - 9222'; 9242' - 9272'; 9288' -9298'; 9322' - 9342'; 9356' - 9376'.; 9387' -9407'; 9419' - 9434'; 9460' - 9464' and 9473' - 9479'. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. All perforations · will be made with 3-1/8" JumboJet hollow carrier guns at 2 shots per foot. The downhole safety valve will be installed upon conclusion of perforating. Well will then be flowed to burn pit for clean up only. Bottom hole static pressures will be measured with downhole pressure bombs run on wireline. Estimated start date, November 28, 1976. i6, i3ereby.S./~rtify th~wthe foregoing is true and correct ~- ~ 7 ~'", TITLE ,-- . ~")' . .' (=F:hiS Space for State of~ use~ o? · ~e Instructions On Reverse Side DATE ..... ' '~<¢ DATE AtlanticRic~hfieldCompany North Amer~"~.Producing Division North Alask ~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 29, 1976 Mr. O. K. Gilbreth - State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: NGI #6 (44-2-11-14) Permit No. 76-29 Dear Mr. Gilbreth- Enclosed please find a Sundry Notice outlining our plans for the above-mentioned well. Very truly yours, m~nowl es District Drilling Engineer CRK/jr Enclosure LUG 1976 Form 10-403 REV. 1-10-73 Subml t "1 ntentlons" In Triplicate & "Subsequent Reports" In Duplicate ~ STATE 0'F ALASKA OIL AND GAS CONSERVATION COMMITTEE · SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) O,L F-1 GAS I--I WELL' ' WELL' ' OTHER Gas Tnjection 2. NAME OF OPERATOR Atlantic' Richfield Company 3. ADDRESS OF OPERATOR ?. 0. ;Box 360, Anchorage, Alaska, 99510 4, LOCATION OF WELL Atsurface 332'S & 1014'E of ~ cr Sec 12, TllN, R14E, UM At TD: 1488'N & 1220fw of SE cr Sec 2, TllN, R14E, UM 1.3. ELEVATIONS (Show whether DF, RT, GR, etc.) 47' RKB " ¸14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: · FRACTURE TREAT ' MULTIPLE COMPLETE SHOOT OR ACIDIZE 'ABANDON* REPAIR WELL CHANGE PLANS (Other) 5. APl NUMERICAL CODE -. 50-029- 20206 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe. ~ay 9. WELL NO. NGI No. 6 (44-2-11-14) i0. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit Pool 11. SEC., T., R.,.M., (BOTTOM HOLE OBJECTIVE) Sec. 2~ Ti.i.N,. R14E 12. PERMIT NO. 76-29 3ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF r'~ REPAIRING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* _ (other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Company proposed replacing the 9-5/8" x 13-3/8" wellhead packoff in NGI No. 6 in September, 1976.' A rig utilizing a 13-5/8" 5000 psi BOP stack with annular preventer, pipe and blind rams will be used. A plug w~ll be set in the tail pipe below the .permanent packer. Weighted CaC12 water will be circulated before the 7" tubing is pulled for access to the wellhead packoff. A 9-5/8" retrievable bridge plug will be set at 100'~ while replacing the packoff. The same tubing string will be: used.t° recomplete the well. 16. I hereby certify that the foregoing is true and correct SIGN ~" ~--(~.,';~t4' TITLE District Drilling Enginemr. DATE .. (This SDa[~ for State office use) July 28, 1976 · CONDITIONs oF~PPROVAL, tF ANY: See Instructions On Reverse Side APp~,vod ,.Opy Ag~ci:{|chfieldCo,,,~.any North Amet~ .~ Producing Division North Alask~, .~strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 17, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Oil and Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 L c. 3 ~N~ ........ 5 ENG 1 GEoL NGI #6 (44-2-1i-14) Permit No. 76-29 Dear Sir: We are enclosing the Well Completion Report along with the Well History and Directional Survey for the above mentioned well. Very truly yours, C. R. Knowles District Drilling Engineer CRK/j r Enclosures DIVISION O~ 011, AN~. GAS Form P--7 STATE OF ALASKA OIL AND GAS CONSERVATION i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* ii i la. TYPE OF WELL: on, [] SAS [] Dar [] Other Gas Injection WELL WELL . b. TYPE OF COMPLETION: NEW ~OVERWORK~']~ DEEP'EN ['---] BAcKPLUG['--]DIFI~. [----]EESVR. Other Susoended. WELL ~. NAME OF 0PERATOIT Atlantic Richfield Company SUBMIT IN D~ .... kTE* (See other in- structions on reverse side) a. AP1 NlrM. F,~C.&L CODE CO MM ITTEE 5 0-029 -202 06 6. LEASE DESIGN~iTION AND SERIAL NO. ._ APL 28302 7. IF INDIA_N', AJ.~;.~O~ OR TRIBE NA2A~ 3. ADDRESS OF OPERATOR P. 0. Box 360~ Anchorage, Alaska 4. LOCATION OF WELL (Ref~ort location clearly and in accordance with any State requirements)* At surface 332'S & 101.4'E of b~ow cr Sec 12, TllN-R14E, UM At tOp prod. in-t-ervai reportea A~Co~a~'fd~ep& 972'W of SE cr Sec 2, TllN-R14E, UM 1488'N & 1220'W of SE cr Sec 2, TllN-R14E, UM 8. UNIT,FAIR1VI OR LEASE NAME Prudhoe Bay I. WELL NO. it6 )(44-2-11-14) 1-07~FIEI~'~ POOL, OR WILDCAT 'rudhoe Bay - Sadlerochit u. SEC., r., R., ~., (BOTTO~ ~OLE~oo~. m OBJECTIVE) Sec 2, TllN-R14E, UM 12. PEmVIIT 76-29 4-~'7~ i 4-28-7:6 ! 5-5-76 ! 18.4' Pad elev. ~7'"I:LT<B J IS. TO~fm~L!;b~, IV~ a TVDIlg. PLUG, B~CK MD & TVD~~). IF 1VZULTIPLE COMIC., 21. INTERYALS--DRILLED BY · / · ] HOW 1VLA.NY* ROTARY TOOLS '[ CABLE TOOLS 9585' & .8617' ! -9500' & 8548' / N/A All ~ None ' 22. PRODUCING INTERVAL(S), O~ TIiISCOMPLETION--ZlND~, ~d)TTOM, NA/~E (MD AN]) TM;T))* [2~. WA~ DIREC'FIONA_L I SURVEY NIADE None i Yes 24. TYPE ELECTRIC AND OTHER LO~S I%LTN DIL/SP, BHC/GR,. FDC,,/GR, GR/VDL/CBL 25. - ".CASING R~"OBX) (RepOrt all strings set in well) C~SING SIZE DEPTH SET (1VID) HOLE SIZE 20" 13-i CFA~NTING RECO1R~ I Ad. CUNT p.~LLED SIZE 28. PERFORATIONS LINER RECOtR~3 TOP (MD)i [' 'BOTTOM (MD) SACKS L 8123', 19580' 360 OPEN TO PRODU~OH (In~rv~, size ~d numar) 30. PRODUCTION DATE FIRST Pi%ODUCTION [PRODUCTI°N METHOD (Fl°wh~g' gas lift' pumping-sIze and type °f pump)N/A ] V¢'ELL STATUS (Produch~4/ or sLut-in). DATE OF TEST, II-iOIJ-RS TE~TED ' [C~-IO!~IE SIZE [PROD'N FOR OIL---BBL. GAS~iV~CF. WATER--BBL. [ GAS-OIL R_&TIO ~ J I 'I {TEST PEI~I. OD ---* I. I 1 FLOW,~. TUBING l[C~Sl3q G PliES S~.. [ICALCirI~TED~'HOLrR ~I~TE ;[OIL~BBL'GAS---1V~CI~. WATEP,~--BBL. ] OIL GRAVITY-APl ( COP~. ) ~1,. DISPOSiTiON OF GAs (~0ld, ,,ed ~ol, )~,el, ~ent,dTctc. ),_ I I J ..-- I TEST WITNESSED BY o~" 32. LIST ATTACHMENTS , Drillin~ HistorV~ mhd Gvrn ,q,,rvmv 33. I hereby ce}tify that th6 foregOing ~nd attached information is complete and correct as determined from all:available records Instructions and Spaces For Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion r~.lSort end log on all types of lan:is and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in other sp~ces on this forn~ and in any c')tt,]chr~ents. Items 20, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p~cJucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, acteclu,~tely identified, for each addil:~or~,~l ir~te~w'~l to be seperately produce:'l, show- ing the adlditional data pertinent to such interval. It~,rn26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing anci the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~l. (See instruction for items 20 and 22 above). , i , WATER AND MUD NA~ .... -~ ....... Top 8ad,crochet 8979 ~ 8131~ Base 8adleroch~t 9505 'D~~S OP 'LITllOgOGY, PORtia. FRA~. A~~ ., AN~ I~D ~t.l~ 'O~ OIL. G~ OR i i i i [i _ ,.. ,~,,,, ,, ....... , r ~-~. . , ........ ATLANTIC RICHFIELD COMPANY NGI #6 (44-2-11-14) API 50-029-20206, ADL 28302, Permit No. 76-29 Drilling History Spud @ 0300 hrs 4-9-76. Drld 17-1/2" hole to 2680'. Ran 13-3/8" 72# MN-80 butt csg to 2663', FC @ 2582'. Cmtd w/5700 sx PF II. Washed & blew dry 13-3/8" x 20" anul, landed 13-3/8" csg & cmtd w/300 sx PF II cmt. NU & test BOPE. Drld out FC, cmt, Shoe & tested form to .65 gradient. Direction- ally dr!d 12-1/4" hole to 8501', POH w/multi-shot. Ran 9-5/8" 47# MN-80 & SOO-95 butt csg w/shoe @ 8464', FC @ 8381', and FO tools @ 2685' & 2395'. Cmtd w/750 sx Class G cmt. Installed & tested pk-off, cmtd thru lower FO @ 2685' w/155 sx PF II cmt. Closed & tested FO @ 2500 psi. Open upper FO @ 2391', circ 9-5/8" x 13-3/8" anul, placed 292 bblsArctic Pack. 0% wtr contaminated @ end of job. Closed & tested FO.. RIH w/8-1/2" bit, drld & cleaned out to 8466', test form to .62 gradient. Drld 8-1/2" hole to 9525', dropped multi-shot, POH. Ran DIL/SP, BHC/GR, FDC/GR and caliper logs. RIH w/8-1/2" bit, drld to 9585', POH. Ran 7" 29# MN-80 butt lnr w/shoe @ 9580', FC @ 9499' & top @ 8123'. Cmtd w/360 sx Class G cmt. RIH w/8-1/2" bit & 9-5/8" csg scraper, dr!d 192' of cmt on top of lnr, POH. RIH w/6" bit, cleaned out to.,9500'. Tested casing to 3000 psi okay. Ran WSO test okay. Ran GR/VDL/CBL'.and Gyro survey. Reversed out mud to water to diesel, checked well for flow after each reversal. RU and ran 7" 26# L-80 TC4S tubing w/tail @ 8032.5', Baker pkr @ 7888', ?BR @ 7838' an.d SS~~~~i le ~@ 3995'. Tested control lines and packing to 50Q0 psi. ND BOPE, install and test xmas tree. Pulled and reran dummy ball valve. Set 9-5/8" x 5-1/2" Baker SAB packer. Sheared out ball, ran dummy gun and casing collar log. Released ri.g @ 1830 5-5-76. Well suspended. /Eastman/ '. ~ Whipstock l)~ A PETROLANE COM~ REPORT of SUB-SURFACE DIREC TIONA L SURVEY Atlantic Richfield COMPANY N. G. I. #6 WELL NAME Prudhoe LOCATION JOB NUMBER A476 G0116 TYPE OF SURVEY Gyro-scopic Jay SURVEY BY Martin OFFICE Alaska DATE 5-5-76 C'OMPLETION REPORT ...................................................................... ~ ....................................... MAY.___~__197_6 ATLANTIC RICHFIELD CO, W.E_L_L__.N_O.L.N.~,I__.~. GYROSCOPIC SURVEY _L/_.~' ~ KB ELEV, 47 FT, -RX'D ! U~-'OF'-CO'R-~'YU-R~E-T~D --OF COMPUT AT ~ ON ~ -C'OMPUTED-'-FOE"-~'A'~'TMA-~--~-H'IPSTOCK'~' INC'~-~B'Y .... F. Mm LINDSEY AND ASSOCIATES RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE -MEAS, DRi-FT--9-ER'T-I-C'A'L ......... SUB ........DR-I'F"? TOTAL COORDINATES C L 0 5 U R g 5 D M DEG, ~ o--'0' o o,o~' ........ ~-4~'-oo'-~-~670o..[. ....... ~.~8:...~_.~__~.~__~._~.,...oo .... W ............ 6o1,13 100 0--3'5 99-~-9'9 ...... :' 52,99 546,00E 587,64 N 124,62 W 600,71 N 11 58 26 W --2-00 0-35 f99';-9'9: ......... Z52';'99 sa5'~-o-o-'~--5'S-'6%-86 N ~Z~%-'9~ ~ ~9~.~0 N 600 0-30--599,98 552'98 ....... 5b3';-O~W ...... 5'8'4%-B6 N [2~;~8 ~ 597"7~'--~--'~Z 5~ ~7 W ...... 700 ...... 0 -30 .... ~-99'~-97 ......... 652 ~ ~7 53 7','OOW ........ 5'8'~-~-"ig~ .... Ti2~'"94--~ ...... 597 ['-i'9'-N--[-[ .... 58 ~ w 900 0--30 899,9'7~85Z-'-9'7 .... S'1'7-;-0-0W--58'~;-~'7 N Z2~.79 W 5-95.88 N Z2 5 ~8 W "' XO00 ...... 0 30 ......... %99-;9.6 ......... 952,96- S O',O-QW~ ..... 5'81'~'81-'-N- .... i2~-~-92 W .......... :-- 595-~-07--N--[~2 ..... 7 ~ w lloo 0'~5 ...... 1'099~-96 ...... 1052,96 S[-3,00E'~ ..... 580~87'-N .........I2~-"8'i--'W ......... 59~"i~ N 12 7 36 w --1'2'00 0 30 1199,95 115Z,95 S29~E .... 579'~'9'8--~ .....f2~'~47 W-- 593'"['9 N 1~ 6 45 W-- 1300 0--~5 ....... 1-299", 95 ......... 1252.95 .... S['9~'O'OE ........... 5'79';-1"~N ......124'"08 -W ........ 592"-~ 6--'-N '-'~z .... ~---'~'7 w [50'0--0~5 [~'99,9~ r~'5'z;9~ ~[%";-Obw 57'7,08 N' ZZ~,09 w-- 5'90;-f'~ ~ [l 8 9 w ~[900 0---0 i8'9~'9'~ [852.9[ .... 5'-O"OOW ......... 57'3-;~-~ .... i26~-28-W ....... 587~-1-i N 2000 0 z5 [999.9~ z95~,gz ..... sgo-;'oo[, ~7a.~a N [~.[~ W ~8~'~'4-'N 2%00 0 30 20~9%-9'1 2052"91 N82'.O'OE 5-7-~'~7-N 1-2'5%'49 w 5~'~-'8'5 N ...... 2200 ...... 0'"~0 2'19~;9'1 215'2.9~ ..... N78~-OOE 57~-;~-"-~---1-2~-~ W 58'6-"81 N 12 15 ~5 W 2300 1 0 2'299%~0 2252.90 N26"O'OE 57~,20 N i2 ~-; 6~--W 587" 3~--N-i-2- 2~'00 1 5 2399.88 2352'*88'--'N14%-OOE ~575.91 N' i'~-3%~1 W 588.90 N 12 3 26 W '-,,.___ 0..000 0.590 506.84 0.113 505,8~-- 0'090 504*87 0.330 504.28 0,080 50~.0~ 0,250 50~e99 0.052 ~03,90 0.122 503.~1 0,1~8 502.88 0,090 502.__13 0,090 5C '~___~_ 0,090 50~"~ 37 0.225 499.55 0.113 498.93 0.080 498.62 0,170 498,62 0,090 ~98.23 0,750 497.81 0.250 ~9736_~_~ 0.250 497,19 0,035 496,70 0.500 496.55 0,090 ~97,3~ RECORD OF SURVEY DRIFT VERTICAI.--$UB-- DRIFT TOTAL COORDINATES C L 0 & U R E $ SEVERITY SF-CTION DEPTH A-N'G'-'~ DEPTH SEA DIREC --D I ST AN-C-E D M DEG. D M S 270.0__2 .... 4,0.__269,9_,._7.__[___~_~..5_2.,__7_l__N_~_~_tO_OE- ..... 5_8_,5..,..6.6..__N .... __~_.2_:1.,_9..~__W_: ..... :~_~ .,. 22...N.. _1_!_.4.~___~_~ W 2800. ,.2_2_5 2.7_9_?_,._6._:[___2..75~_,_6_[.. _N....!_~_,_O_O_.E.____5.9.0_,_O? N [2:i..:1.8 W' 602..,_~.6 N [[-36 2[ W 2900 2 30 2899.52 2852.52 N[5.00E 594,.18 N [20'.03 W 606.[9 N 1[ 25 [5 W 3100 3 0 3099.30 3052.30 N32.00E 602.85 N 1t6.71 W ....... 3-200 3 2,5 3].99,[4, ~[52-'-~,'4,"-N'40.OOE 60¥'""38 N ~.~2 W ~300 3 5 ~298.98 ~25~,98 N~O.OOE 6~.7~ N '~09.76 W 6[4.04 N ~0 57 26 W 623..51 N 10 lO 21 W 627*%'6-'-N 9 29 6 W 630,02 N 9 ~0 ~ W 0.410 ~_9 ~,~ 6.2_ __0,750 5~ ~.68 __o. zo ;,. o. 2 ~ [__ 0.0 '7 0 __ 0 · o 9 o 5_1_0,._/.,._.% __o_,.ff_L~ 0,4, 3, [ 0,_~/,0__ 5 [ 3,.6_5_ 0,~50 514,.~8 0,~4,o .5 ;i.. ~_,_6_~_ 0.4,[0 5[4,,4,4, 5;I. 4,,[5 513,4,7 3'7-00 [---'50'--3'698,60 365Y;-60 .... NS"[,OOE . 62z~;-[3-'N ....... 97,8z+ W 63[.76 N 8 '" 3-9'0'0 ..... [ "5 ~8'98,53 3_8:5__!_.,_5.~.__N8[-.':'0:0'~ .... .6-_~:::6::*'_2'5._-_-.'~ ........ 9.~ ;._-!~8__~,__ .6_3_3.':;.'.[_5__N. 4-000 1 .... 5 3998-,-5'1 3951.5[ $89.00E 626.38 N 91.29 W ~ 633.00 N 8 17 31 W 0,190 42-0'0 3 20' A"~-98.37 4151,37 N82.0QW 628.36 N--95.76 W 635.62 N 8 39-'5~ W-------~.500 ~-0-0 4 50 4'2-98'1~ 4251-.-~-F'--NS-3-;b'O'W' 631,06-'N [02.28 W 63'9-.-~0--'~ 4,400 5 30 -- ~'3-9%-,-~-[---~350-~'~'[ N'5- X-" 5-0W---6'-3'6- ;-5 8- N ..... i09-.-~%--W .... 6"4,'~';"9-~-N .... 4,600 8--~5 4,596-,-05----4,5~-9-;05--N'52-j-~-b-vi/----65-$--e--iS-'N- .... [2.-8 '-6-9 W 66-5'";72F-~---1"[ 512.40 5 [! ._[6. ~, [ 531.13 572_, 23 5.9.0 ./+~ 4,900 14, :~0 4,889.9/+ 4.84,2,94, N63.00W 6~...8:N .......... W 703.02 N [5 [ 2.9 W 2.,006 6[2"*,4,0. ~5-0-~):0 3,7 0 4,'98-~-;-[-$ ~9-~9-"1-~'--N-~-0'-*-0-0-~' 6.9~Nfi_-:' 2"06,10 WD 72"l.97'-J~-'~,-6--~'~-~.Z W~.,5_.13 6..38_._3_5. 5[oo ].9 ~.5 5o8]..2[ '5'0'~%-;'2'3: i~'6'b:-b'i~'w .... _ -' ' 3 · "- w - ...... 668,3]. b'r-~o0--2~O 526--7-~--50----5-2~"(J'50 N58'O-~W' '~74--~'--"'-~' N 2"95'48 W--80:1'i5 N 2]. 38 ~4, W --[-"5].7 738'58 RECORD OF SURVEY E-~-~-~-~-¥-I-~N-$--P-ER-FOR~-~D BY I B M ELECTRONIC COMPUTER T R U E DO.G_LE~ MEAS. DRIFT VERTICAL SUB ............. DRIE,T ............... ~9.TAL..¢OORDINA.T,E.S ............... 'C__L__O_._.$..,_..U__,g ..... E...._~_ ............... SEV.E,g]_I%__ _ D E-P-T i:t" -A~i'~-I~-E ......... DEPT-H .............. $.~A .......... P. IREC ........................... _D_~ _S_T._A. N_~ ........ _A_..NG g E._.; ...... D.E_G/L_O_O F T D M DEG. D M S .... 5500 29 0 5447,18 5400,18 N58.00W 791.10 N 369.80 5600 ~1 ~0 5533,55 5486.55' N56.00W 818.5~ N ~12.0~ ...... ~700-'-~ 45 561'~'~ ........ 5570'77 ........... N57';'oow ......... 848.29'-N ...... 457.00 '--6i00"'40"15'- -'5--9~3-;"5"~ ....... 5886.50 N55.00W 987.20 N 658.80 W 1186.84 N 33 43 1 W 0.487 6300'40 .....~'0---~'0-8"~;-;'~"8 ........ 6039';-~8 .....NS-~';"OOW .......... ~062"47'-N ....... 7'63.~6 W 1508.27 N 35 ~Z 47 W 0,170 ....... 6~00 39-55 .....-61-6'~;0'2 ........ b116""02 ........... NS~'-50W ......... 1100'07 N ........... 815.58 6500'--39--~"5 --- 6'~39~-8"l--"b'~gZ,'8'~'~'N55""00W .... 1137'0-~ N-- 86~;~"0 W f4~-~"'i-~"'~--N--~-7 21 -"~5-'W 0.272 ---6600'~9 .......... 0 .... 6'~I7.~ ~2.70"~ ....... N55'.S0W ......... ZZT~.20 N ...... 920";03--W ..... 6700 ~8--~0--'-6395';'~0 .........63'48,%0 ..... NS~.00W .... ~209,33' N ........ 971"."1~ W 6800-39--30--64-72";'81 '-'6425"8~-~-NS'4"J'00W--'-1246',32 N 1022T05--W .... 6900 40 ...... 15~6-5'4'9-;-55 6502.55 ........ N54',00W ...... 1284"00 -N 7200'-~-1 ~5 6775V~0 .... 6728'i0' NS'~';00W .....~'4'02.'58 .... N ...... ~232'*~3 W 7'~-oC-4-f-ao ..... ~-81-9-,-'8-5- 68-0z*-85 N'S-~s-0W' ~'~-42'-~z ..... N ...... i 2-8 5-'. 4-5 W-- ' 76'00--4~-45 "7'0-7~%-39 ..... 7027,39' 'N52-';'-00W .... ~-5'~',20- N .....1'~43-~6 W .250 '7800--~-1- 0 -7224-.-90 7177'90 ..... NSL%OOWL--L-645,6~"-'N ..... 15 46 '-1' 7 --W ' 2f581-05 N-'~-'3--~2 5~ W. 0.000 7900--4'1 5 73-0'0 .'32 ..... 7253.32 .... N52 "OOW .... I686.51 N 159 7;-5'6~-- 8 ~'00--~ 0-45 7'~51'.-6~ 7 ~ 0 ~ ,6-~-'~- N'~9,70~-W- ~~~~4-~ 15-5-i';-o'o N -3'8'-4-5--5 7""W .............. 0 · 7 6 7 1'6-1-1-;-80--N--59--21 13 W l .000 -I~-73";"9-1--N--39--"5'F--~'l .... W 0 . 750 --].737,/+2 N 40 .... 2-4' .... 52 W 1.0co 1801.99 N /+0 52 20 W 0 1932.02 N ~i /+2 ~0 W 0,33~ 2,0-6'2-;-i~-'-N--4Z-25 i' 7--'W--0 2 z 2 7-,'7'2--N -42-%S-- ~ W --0 2193,06 N ~2 58 58 W 0 1229,5~ ~293,08 1~56,48 1~81.82 L~b8,68 1733.1/+ LTl 1929.8~ 20~0e91 2126.76 2~92.36 2257~53 2322.70 2387.55 2/+52.39 25~7.12 RECORD OF S~JRVEY ALL CALCULATIONS'PERFORMED B.Y I B M ELECTRONIC COMPUTER T R U E ' MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH 'D M SUB DRIFT TOTAL COORDINATES SEA DIREC DEG.. 'CLOSURES ~ 5EVER I TY SEC TI_ON DISTANCE ANGLE DEG/IOOFT DISTANC( D M $ .. 83-0'0'-~,-~: ~----76-~'~-;:~'~- ...... 17'5'57~"i5 ......... NSO.OOW 1851.92 N L798,.26 W 2581.35 N 44 9 28 W __8400 ~9 50 7680.84 76_3.~3_~.~=~NS.0.?OQW- ~_893.17 N 1847.42 W 2645.~9 N 44 17_57 W 8500_~9___._0 : 7.~.5_7 ,_5..~ ...... ~.7 ~ 0.53 N~8.50W ......... !.9.35...996 ~.,_~.9.6_,_O_3 .... W 2_7_O3._.3_D_~.__9~....~.~__5_9 W 0,640 8600 39 50 783~,23 7787,23 N~7,00W 1978,20 N 19~3,53 W: 27.73,19 N ~4 29 36 W 0,636__ 8900 37 30 8067.99 8020.99 N44.00W 2110.32 N '2077.25 W 2961.15 N 4/+ 32 51 W 9000 .... 37-30 8-'3:-~'~';-~2---"8-!00-'3~ .......... N~+Z,''ooW~_]]~i:~I;'s-3 w 3ofz'%-Z']'~---~-~-'~ ~ ~ w~ ..... 91'O'O--3 7--'1-5 ........... ~'2%-,-79--8'179-"79 ...... N~.~;'00~ ...... ~9~_'_Z!..'~4 :..,:.~.....2_~.6~3_7_Q__W· ._~.d..:~2 ::~ ~-~ ~'i 33 w ..... 9200 .... 37 0 83-06;"52 ....... 825'9',5~ ..... N~3,00W 22~,55 .N 2203,25 W 31~3,07 N ~ 30 22 W~ BOTTOM-NOL-E--C'L-C)'$URE ...... 3370-;-70-'FEET--AT'"-N 44 24 i6 w 0 .~83 2 5 P '~I)_2 2773_._1__9 283!,00 __2899.7k 0 · 8_3 7 2 9 6 0.000 3022.02 0.250 3082,72 0.440 3143,07 0.750 3202.70 0,000 3261~_8_~ 0,250 3320.75 0.000 . '3370.70 -'C~E MEASURED DEPTH TRUE VERST I CAL D-EPTH TOTAL COORDINATES D M $ ~ 8889 805-~i,...2_6 21.05.50 N__2072,59 W 295~.,!.,~.5 N 44 .,32 55 W 80].2j_2_6 , . ........... $ 892 8061,6 ~ ....... 21..0 678.! ...... N .............. 2.0_?~13...,_.86_..w ............ 2956,.Z8 .N_.~__32 .... 5'~_.._~ ....... 8953 ....................... 81'TO,O~ 2133,53 N ' 2099,66 W 2993,._4i ..... N_~.4__32___29_..W 89'67- 8'121,14 ....... 21. '3'9'~66'- N----_~_~-2-:[i-0'-5~'58 w__:3001.,..9~ ......... ~__~4_..,~,2__Z.~_W_ 699~ 8].40,98 z1.5o,6o N Z1.~,.1..~ w 'a..O_],.7._,_Zg.___N___~4 az 1.~ w 9'6"8-~~ ............ ~ z ~.'~ '-~ 6'~'~_',~.,Z-i-~0-,3 7 N__Z..1._~A,.~.,~_W .... aO.? Z,..~..~__~,_~.~_.~.L_~_9_ w .............................. 9~33 ................. 8494,05 2342,69 N__ 2297156 W 3281,30 N 44 2.6 323 W. 9505 8552,24 ....... 2'3-~'3"~-'70 N__2326,~7 W__3'3'2~,69 N 44 25 27 W 8.5.05,24 _~_N? E. RR,..o_ ~.A!.E_ ~_VAL_U E S_ E_C!_R__F,_~/_~.N _10 00_E E ET__. OE MEASURE D _DEP_TH_, TRUE MEASURED VERT ! (:AL ,SUB. ........... DEPfH ........ i~'E~P"'~t:t ...... SEA TOTAL COORD INATE,S ~ od6 -- ....................... ~000 .5000 · 999.--9.52. ~-i',81 N 1~24`792 W 1999' ..... --1-9 52-. 2"999",- ...... 2]9'52. 5' 9 8'-~" 4/.~"'-'N 118-,-77 W --:~998~. :~951. ~z6-*'~8 N 9].. :~0--~-'---;-~ 60:00 ...................... 585"'/', ....... 5-8"1'0-, ....................... 94,9 .'.59 N 7000 ......................... 6625",' .............. 6'5'7 8'~ ............ 1' 32'2"~;'8'":~ N 80'0'0 ............................... 7 :B 75', ............... 7-~'28', ................... 1726'~3 8--N .... ' 9 00'0' 8i"4'7',- ...... --~-i-O-O'; ......... 2'1'-5'4-,-1-'i-N .... -2-1]].-9-'-52.' w NEASURED DEPTH-AND' OTHER DATA FOR EVERY EVEN 100 FEET OF.SUB SEA D_E_P_T~_, TRUE ....... MEASORED VERT'rCAL SUB ND-TVD VERT I CAI..-~ DEP'TH DEPTH SEA DIFFERENCE CORRECTION 1/+7 147, 100 0 0 247 347 ~+47 647 --74-7 847 9/+7 1047 12/+7 13/+7 247, 200 0 0 3~'~';-~ .......... 3'00 ............... o ....... o 4~-7-,-' ,400 ........ 0 0 547, .500 0 0 647, ~00" 0 .......................... 0 747, 700 0 0 847, 800 0 0 9/+7. ......... 900 ................ o O. lo47'; .... ~-0~o~ .............. o o 11/+7, 1100 0 12Z',,'7. ............. 1200 .................. 0 .............. 1347"' ........ i-300 ........... 0 ............ . 0 0 0 587_.2_9_~..___!_2.~_ 586,49 N 123,68 W 585,86 N 123,12, W 585,55 N 122,91 W 585,16 N 123,12 W 584,55 N 123,66 W 583,85 N 12~+,18 W 5'83',10 N--124,62 W 582,27 N 124,88 W 581,38 N 124,89 W 580,42 N 124,67 W 578,65 N 123,97 W 15/+7 -i- 6-/.,,' 7 1847 2'0'4,-7 ............ 21/+7-- ................... 22'/+'7 2-3~-7 .................. 2'5,~--/ 1447, 1400 0 1'5~7' .......... i'500 ..................... o ......... --1647-, ....1'6'00 .......... 0 ..... S7~'7. -i'"700 o 18~'7. ...... i'800 ............... 0 2O¥7° 2'000 0 --2147. 210'0 ............ 0 2'2/+'7'; ..... 22oo ......... o 2Y~. z3oo o 24/+7, 2400 ................ 0 ........................... 25~7, 2500 0 600 ............. 0 .............. 27'4-;/ '~'7-~ 7--, ........ 27 oo ....... 0 ........... 2~4-7 2847, 2800 0 2~)4-8 29'Z~7"' 2900 0 3'0~ 8 3047. ...... 3'000 0 ............ 3-148 --31~'7, ...... 3100 .............. 0 32-~-8 3247'~3'2 O0 ~~ 33~8 3'3~7', 3300 3 ~ 4'8 3'5~'7, 3500 ..... 0 577,62 N 123,99 o ..... .......... 0 575.72 N 125,03 o 57~';-6~ N --125.~7 o 5-Y3&-5~-~ 0 ............................. 5~'37,-32-"'N ............. 0 573,23 N 125,89 W 0 5'73,33 N 125,09 W .................... --0 ............................... 573'''--6 3'--N ........ 1,2 ~', 1'7' '-w -- 574,97 N' 123,31W 579,49 N 122,~1 W 587,79 N 121,69 W ........................... 591,96 N 120,6~ W 596,20 N 119,46 W 600,52 N 117,96 W 6b~-99-N ..... i15'~2-7 w ................................. 609.52 N 111,63 W 6~i3TTO--N ......... 1~08;-1~ w 6~7~57-N ............ 105'bg'-W 620,6~ N 101,99 W .................................. _.M_EA.$UR.[iD_.?E P__T,H, AND__9_T,.HER_DA~A_f. OR. _E V.E R .Y__E,V. EN___IO_O__E E.E_T_OF `SU B_,.%F.A_DERZH, TRUE MEASURED .......... DE P'T'H VERT!CAL ,SUB MD-TVD 'VERT!CAL DE P-TH ,~'E ~--D~i'"F FER'EN (:E ..... --~J'I~R-E'C T ! ON TOTAL; COORDINATES 3648 3647. 3600 1 0 3748 3747. 3700 1 O' 3848 3847, 3800 3'9 4~ ~ 9-~7 * .... -~b O' ............... A,-O'~'8 '4'0'~-7 .. 400'0 ~3~9 ~7~ ~00 623.03 N 99.18 W 624'.98 N 96,64 W 626.02 N 94,25 W 6 2 g~'~'--N ........... 9 2.2 8 w 625.'71 N 90.60 W 628.10 N 93.12 W 629.18 N 98.79 W 633.66 N 105,67 W 648,60 N 122.96 W 657.71N 135.50 W W .............. 5-5-0 o -5'4W7, ......... 54'0-0 ............. 5 2 ...................... i-2 5-6-i 6 5-5'4-7. 5-5-o'0 6'8 i 6 5-7~-5 ....................... 5'64-7' ..... 5-~00 ........... 88- 2 o 5858 5747, 5700 111 23 .5-9-8 6 5'~-47, 5800 ......... 139 z 8 .................... 6-1-i-8 -5-9-47-~-- 59Oo ' -171 ................... 3"2--- 6248 6-0'4'-7; ..... 6000--201 30 6-3-7-9 6 i%-7' 6 i o o 2 3 2 ............ '6-509 ................ -6-2-4-7" ..... 6 2 O0 ...... 2 62 823.1'7 N 418.93 W ~'5~,"0-1'-~ ........... ~7'3'-, 3 ~ w 898.71 N 532.62 W --:944.29 N 59~.72 W 993.76 N 668.14 W 1042,78 N 736,25 W iog"Z%~'-N .............. 8o~. 50 w 30 1140,34 N 872.61 W ............. 663-8 -- 63-4-'/' ....6 300- '2'91 2 9 6 76-6 6-4-4'7, 6400 ...... 319 28 .............. 689-6 65'4-7 · ........ 6'500 .... 349 '3-0 .......... -7029 66'4-7 . ...... 6'600 '-'3-81 32 7 ~-~ ~6'7 ~-7'. ......... ~ 700 ~ 15 3'~ .......... 72'9-6 --6847. .....6800 ........ ~9 .%~ ................. 743'0 --69'~7 * ..... 6900 ......... ~-83 75'~3 70~7. '7000 ........ ~'f~ - 33 .......... fi'8'6-,'96-N ........ 939;'53 w 1282-,-~+g-'N ......1071-'-83 W 1334';-2'9--N ..... i'i~'i-; 6"6 .... W 1387.37 N 1212,04 W 1-'+4'o--'-9-~ a .... i'~'8-~"i6 w 1'548~05 N 1424.06 W 'MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN ilO0 FEET OF,SUB SEA DEPTH, ........... MEASOR-ED ............... DEPTH TRUE V ERTI c'A-~--$ UB- ............ MD' TV D DEPTH SEA DZFFERENCE ~ERTI~AL CORRECTION TOTAL COORDINATE5 7697 7'1%-7~ ........ ~b~ ............ 550 34 7"82~ ~2"~7" .... 7200 ....... 582 32 7952 ....................... 7347' ............. 7300 ......615 33 809~-- ................. :74'~'7' .......... 7400 ........... 647 32 82'~'~ 754:7, 7500 ....... 678 31 8356 76~7i 7600 .709 3~ 1657,58 N 1560,99 W 1711,30 N 1629,6~ W ?' i-'-, '3J£ w 1820,'63 N 1761,46 W 1874,99 N 1825,76 W .............. 8-4'$'-6 .......................... 7747'; 770'0 ..... 739 .................................. 3-6 ................ 192.9_.,..~6_N ,!28.8..93...! 4 W 86~6 7"~'~7'; ......... 7800 ........ 7'~9 8 ......................... ?46 ~'9~'7"' .......... 7900 ........... 799 88-7-3 ...... --~'~-j ........ 8000 ........... 826 899"~ 8147' ......8100 852 9~25 82~7''' ........... 8200 878 9250 83~7, 8300 903 9375 8447, 8400 928 9~98 8547, 8500 951 3o ~98.5, z..~:_.N ........ ~5~_?.00__.~ .................... 30 2042,99 N 2010,29 W 27 2098,49 N 2065,77 W 2.6_ ............................. 2153.,.6_7_N ............. ,z 6 ...... Z z o.8...6.!_~ ...... ~_l~ 2_,_1.~ ..... w · .25 z.z 6. 3_, .4~_.~ .... ~Z~.~..,..~ 8 w Z 5 ...... 23 ~ 7, ~_.N ......... ZZ.14.., 05 W 23 2370,69 N 2323,67 W -- .--.] 1---'--- ........ { ~ . Ir ~ ~__ r____ .-- l-ALL DEPTHS SHOWN' ! !' __ !__' -- ...... :-,J ............. i_- .....:. --_.-_ - ..... ' .......... -+ ...... .... -- ..... i --7- ......... : ...... , . . · . ,..- ............ : .......... :--:-~ ....... 4 ......... ,,.8oo-t-.- I ' "f' . = .... j ................. . ......... ;_'-:' '.-'-7;i !!::-!.~i' :;_-_-::; ';;. -'-! '" -- ;._- " ' ~ ' ' ' ,' ' ' " -''" .... .... :-:-~--;-*~ ..... :--~ - ~"-;---:--i ............... 5,oo~ .... , .... · ..... ?. ..... { ............ ! ....... I ........ ', - _ i ...... ......................................................... -: -- - ' ........ t-.'..- ..... ~---[.-: ..... .:-- - --' ..... · i ' ' ' ' , ---"-'/'---:'- .......... , .- -. ........ ;-~' .... I ........ ; ................ t-- ..... 1-: -- i'- .----:*'-----'~-t . - i ' ~ - , ' - ' ,- _:__ ..... .~__.___~__ ; J . ~ _~ .' ~ ' _ - L · I · ~ _ ' _~ : ' ' " ' ' J~ ~'. _;-_-L_~ .-- ....... -r ....... ~ ............ -4 ................. 7-- ...... '--c---F-~- .......... ~---.,- +--- ...... -..,--~---~--,r-- ................................. --~ -~.' -+---~--- .... - ......... ~ ........ : i ' :-:'-: .... i-- -:~ ...... ' .... :-_~,_... _:-_;_ ~ !__.:_,..__'_~ ................ ;.-:----:-4 -,-4_: .... -t ............ ......... ',-- .......... :- : :- ....... ',- .......... -- --:----:--I .....,: t -,- :- ~- +----~i-- '.~ -. : ! ; . - ; · '..!- - . ~ .~ : i - ' t · - ..................... i ..................-' -'- ,, ............ -~ ........ ! 680(} '~'-'"- .... J -- '-- ! .......I~ ..................................... ' ! ~-I ......... r · - i ! , ;' - , -, ...... , ........ ~ : ,~ . ~ · . ! ! - ! . ' : ! ! ;~ . . , I ':"- :- ; .......... i ......... *-¢; ...... "~-~ ........... F-:-;' - ;'~ --i-;-i ...... "~-~' ........... ~-- -.: i ..... :-' t ........... i-":-',-'-:l--~ ....... -7-t-;-7---- -- ....... ! ............... ! ........-'i'--; : --;-~---7-7---.F'- ...... '1--7--: ''~ : .... -r ...... \7 ........ i .........;-' ......... i .......... i ........--I--;-7-'-F,'7-F-'~--F- .... --: ....... ~ ....... .~__, ............. ?~_ ....... ~ .__:_~C_F_% ..... , ..... ;--:---~" 7__._~. ............ L ........ ' .......... ............ ~-'7 ..... ! ........ --'7 ........ ;1-':-- ~.--7-F'-'~I --- ~ ........... i ........... '"- -~%^"'~' ~ ........i '-','-:.--I-'*'-: ..... --~ .......... ~ - ,, .......... ~ .......... ~ , ................ ~ ......... -.' .......... ----[- --~ .... ~--= .......... ~ ........... ~ ........................ ~ ............ '--|.-' .... TVD =-8617'- ....... l .........[ ...... : ........ ~.._!__ ~L__ ..... ~_ ....... · .... "-, ........... ! ........... -" ......... ~ ....'--: ..... 7- ..... , ....... -. ............ ~- -'i--t-]---~ ..... 7 TMD = '9585 --'-'-i ......... .................... ~ ...... 'f ............ ~ ' .'- ...... = .......... ' ........... '~ ..... '--:-'! ..... ' ..... I .....: ..... ,, .... ! .......... i'-':--~'-~ ,- -i:-,'. .... ~f ' ~ .~ - - .,7- - -- - ~i l_ i , , ................................. i- ....... l ..... ....... ~ ' . .... Z_._~;~-'_.___I_,_:__:...I ....... t-~-- --' .... -I-, ;----'- ! - -: ATLANTIC- RICHFIELD RADIUS DF CURVATURE GYROSCOPIC -SURVEY ..... ........................... 5600: ............... . ...... ' ~---~ ...... ~- ~ ....... t .......... { AtlanticRichfieldCompany North Amer: ~ Producing Division North Alaska ~strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 5, 1976 Mr. O. K.'Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 RE: NGI #6 Permit No. 76-29 Dear Sir: Enclosed please find the Monthly Report of Drilling Operations for the above mentioned well. Very truly yours, C. R. Knowles District Drilling Engineer Enclosure CRK/BDR/j 1 FILE: Form No. ~.~'Y. 3-1-70 STATE OF' ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICA'I~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS O,L ~ G*' [] OT"~' Gas Injection WELL W[:LL 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF oPEI{ATOR P. O. Box 360. AnchoraGe. Alaska. 99510 4. LOtA~ON OF . 332!S & 1014'E of NW cr Sec 12, TllN, R14E, UM AP1 NLrMERiCAL CODE 50-029-20206 LEASE DESIGNATION AND SEI~IAL NO. ADL 28302 IF INDIAN, ALO7 ik~ OR TRIBE NAME 8. L.~IT FARM OR LEASE NAME Prudhoe Bav 9 WELL NO NGI ~6 (44-2-11-14) 10. FLELD A-ND POOL. OR WILDCAT Prudhoe Ba¥-Sadlerochit Pool II SF, C., T., R., M. (BOTTOM HOLE o~mcnv~ Sec 2, TllN, R14E, UM 12. PEP,.MIT NO. 76-29 "13. REPORT TOTAL DEPTH AT END OF MONTH, CHA.NGF-,S IN HOLE SIZE, CASING AND C~LMENTING JOBS INCLUDING DEPTH SET AND VOLUMI~ USED, PERFORATIONS. TESTS ANT) i~ESULTS FISHING JOB~ JITNK IAI HOLE AND SIDE-TI~ACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOL~ CONDITIONS. Report of O~erations for the Pbnth of April Spud @ 0300 hrs 4-9-76. Drld 17-1/2" hole to 2680'. Ran 13-3/8" 72~ MN-80 butt csg to 2663' FC @ 2582.' Cmtd w/5700 sx PF II. Washed & blew dry 13-3/8" x 20" anul, landed , . · 13-3/8" csg & cmtd w/300 sx PF II csg. NU & test BOPE. Drld out FC, cmt, shoe & tested form to .65 gradient. Directionally drld 12-1/4" hole to 8501', POH w/multi-shot. Ran 9-5/8" 47~ MN-80 & SOO-95 butt csg w/shoe @ 8464', FC @ 8381', and FO tools @ 2685' & 2395'. Cmtd w/750 sx Class Gcmt. Installed & tested pk-off, cmtd thru lower FO @ 2685' w/155 sx PF II cmt. Closed & tested FO @ 2500 psi. OPen upper FO @ 2391', circ 9-5/8" x 13-3/8" anul, placed 292 bbls Arctic Pack. 0% wtr contaminated @ end of job. Closed & tested FO. RIH w/8-1/2" bit, drld & cleaned out to 8466', tested form to . 62 gradient. Drld 8-1/2" hole to 9525', dropped multi-shot, POH. Ran DIL/SP, BHC/GR, FDC/GR and caliper logs. RIH w/8-1/2" bit, drld to 9585', POH. Ran 7" 29# MN-80 butt lnr w/shoe @ 9580', FC @ 9499' & top @ 8123' Cmtd w/360 sx Class Gcmt. RIH w/8-1/2" bit & 9-5/8" csg scraper, drld 192' of cmt on top of lnr, POH. Prep to run 6" bit on May 1. 14. I hereby certify ~t ,~e~and eorr%'c% sm~ ~z District Drlg Engineer DA~ May 6, 1976 NOTE--Report on this form is required for each calendar month% regardless of the status of operations, and must bo filed in duplicate with the oil and gas conservot/on committee bythe 15th of the SuQcNding month, unlel~ Otherwise directed. A~anti~ichfieldCom pany (. NorthAme' ,n Producing Division North Alask.. ;pistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 30, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject- NGI No. 6 (44-2-11-14) Dear Sir' Enclosed please find Sundry Notice describing a change in the measured depth of the above mentioned wel 1. Very truly yours, C. R. Knowles District Drilling Engineer /jl Enclosure MAY 1976 DIVISION OF OI/. AND GAS ANCHO~A~ Fo rr,~ 10-403 REV. 1-10-~3 Submit "1 ntentions" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use ,'APPLICATION FOR PERMIT--" for such proposals.) o~- [--1 GAs [~] OTHER Gas Injection WELL~ ~ WELL 2. NAME OF OPERATOR Atlantic Richfield Company. 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL Atsurface 332'S & 1014'E of NW cr Sec 12, TllN, R14E, UM At -8300'ss Target: 120, N & ll20'W of SE cr, Sec 2, TllN, R14E. UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18' Gravel Pad 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20206 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Baj/ 9. WELL NO. NGI No. 6 (44-2-11-14) 10. FIELD AND POOL, OR WILDCAT Prudh0e Baj/ - Sadler0chit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 2, TllN, R14E~ UM 12. PERMIT NO. 76-29 )ort, or Other Data SHOOT OR AClDIZE REPAIR WELL (Other) NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER sHUT'OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING REPAIRING WELL ALTERING CASING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The Atlantic Richfield Company proposes extending the measured depth of this well from 9500' to 9600'. Although the course length is greater, the True Vertical Depth of 8630' will remain the same. The remainder of the proposed well program will be unchanged. Above discussed by C. R. Knowles/0. K. Gilbreth on 4/28/76. DtVI.~ION 0~' OIL AND OAS certify that the for going is true and correct SIGNED . TITLE District Drillinq Engineer DATE - 4/36)/76 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side STATE A KA D~PART~4ENT OF NATURAL RESOURCES iDivision of Oil and Gas TO.. ~-- O, K. Gilbreth, Jr. Director H oyle H. Ham!lton /,~'/ Chief PetroleUm EnaineerJv~ LonnieC. Smith Petroleum Engineer DATE , April 28, 1976 SUBJECT: Witness BOP test;~,.Arco's Seal bypass Preliminary inspection at Arco's Able State #1 Monday, April 12, 1976 - I departed Anchorage by commercial air carrier ~-t~-7:"3J] AM',' arriving~-~t Deadhorse on the North Slope at 9:00 At.~ where I caught the Arco bus to their .base camp. I contacted the NGI drilling supervisor, Tom Webster, by phone and made arrangements to be picked up when he needed m~ that afternoon. I then contacted Dan Roberts, super- visor of the COT plant and discussed the use of the bypass valves and the operational problems of the previous weeks at the COT plant when they had COT-1 shut down. The plant was now back in full scale operation at peak efficiency. I was introduced to Tom.. Bradshaw, a new COT supervisor, who took me out to seal the three bypass valves that had the seals broken during the operational shutdown. I replaced the seals on valves at meter run #1, #2 and one between the tanks and rechecked the seals on the other six valves to be sure they were intact. Dan assured me he would get in a report covering the amounts of fluid bypassed during operational shutdown of COT #1 plant for my approval. He showed me the tank gauge record that would be the basis of this report. I pointed out to him that, after check- lng it over, if we ~reed with it .then there would have to be an additional ticket written, a run ticket, for that amount to include it in the total runs into the plant. (I subsequently notified Ed Hartig of this pending adjustmient. ) t discussed operational problems with drilling coordinator, Gil Meyer, who informed me that Buck Rice would soon be ready for a BOP test on the DS 3-2 well. I told him I would stay in contact with Buck and possibly catch it before I left the slope. Mr. Heyer also inquired if I could inspect the abandoned location clean work which was in Progress on Able State #1. I assured him I would be able to do this, so he agreed whenever the work was complete the next day we could make arrangements to get me by there. I had lunch with Arco operation engineer, Gene Griffin, who informed me that flow tests from DS 1-7 well were still very disappointing and the recent solvent treatment didn't appear to be very effective. They were still severely hampered by production flow rate, but it appeared that they had opened up some new perforations, but possibly there were still perfora- tions that weren't open. We also discussed the upcoming flow test on the gas well, NGI #7, of which he informed ~m that the primary reasons for these tests were first, how deep to set the subsurface safety valve to get safely below the hydrate point and secondly, the concern for the hydrate formations at the low flow rates and ~hether or not their circu- lation ~ystem would be adequate to prevent the hydrate formation or un- block it if they did get formation. His indications were that they will be attempting to flow at maximum flow rates as limited by the 4 1/2 tubing to assure that the w~ll cleans up properly and then at low rates for hydrate testing. L. C. Smith 2- April 28, 1976 After lunch ! ~as driven t~ the 1~! locatl~ ~ ~ C~11~r rtg ~51 ~ A~ drt11~,g s~v~, T~ ~s~. ~y tnfo~d ~ ~at ~ey ~ ~- s~ ~~-~t~.ng ~ t~ kelly ~ kelly ~k and choke rant- fold sys~, ~~, ~ ~_ st111 ntppl1~ .ep ~ ~P sys~. Ftnally, at 3:~ ~ ~ s~r~ ~s~ ~tJ'~ the test. mn~.fold sys~ ~tch ts a ~ ta~ mn~fold c~ts.t~ of !9 vale, all thee Inch Hellburton L~-T~ t~ vales, l~.a~iy ~ ~essur~ ~ to 2~ pst t~ plug bl~ ~t of ~ ~t~ of ~ ef ~ ~1~. ~ all--rely p~ssure t~~ ~d ~t~ ~1~ ~tll 5:~ ~. At that tt~ ~ ~d 4 valves leakt~ a~ ~r ~Ir. At 8:15 ~ ~ p~ssu~ t~ kelly ~ck valve ~ ~ pst a~ tt ~ld o~. ~ ~ ~s~. ~ l~r kelly ~al~e and tt ~s ~y. At 10:45 ~ ~ ~d ~ftnt~!y ~-~t~d ~t ~e~ ~ 4 valv~ st111 leakt~ ~ ~ c~ mntfeld and ~ ~1~ ~ld ~ n~essary. Tues,,_ Apr11.13,.__!976 - ?he four remalntng val~es In the test mntfold ~-t~l'lY-~l~d'by 1:~ ~ a~ all ~s.~ sattsfac~r11~. ~ rest of ~ ntght ~s s~t t~~ ~. bl~ut p~ven~r s~ck, A leak In t~ ~ 1~ to ~ t~t ~Ifold ~ fm~d and repat~d. ~veral hydraulic leaks ~ ~co~~ aP~ t~ w~ test pl'~ ~s ~ and requt~d an hour o[~ ~la~ ~ ~n~ a~ ~t ~e ~~ ~st plug. ~e ~ sets of pt~ ~ and 't~ blted r~ ~e s~c~sfully ~d to ~ pst. ~ backup ntt~ ~ttl~ ~ ~t~ and ~d g~ ~ss~ In 6 ~ttles. All ~sttng ~s c~le~ a~t 4:45 ~. ! completed afteld Inspection report, attached, showing 14 total hours of observation ttae and uncovering and repatrfng of 12 leaks. ! left a copy of thts wtth Tom gebster and sent the other copy to B. T. Laudermllk. ! called $tl l~a~yer at the Arco's base cmap and tnformed him the testing was completed at ~gG! and that ! was ready to tnspect the locatton .clean-up on Arce's Able S~ ge. 1, GI1 picked me up and we drove to the Able State locatton ~re a cat was st111 on the locatlon draggtng to smooth down the rough places. 1T~ lecattea was already fna very good condition as sho~n tn Photos. No. I and 2'. The P & R marker ~rlth the well slgn mounted on tt ts s~ tn~th 'p~t~s. The well marker alse has the correct data bead welded on tr. I~e ctrcled the per~eeter of the location. ! looked tt over carefully and filled out the fteld InsPection report, attached, sho~tng that the f~nal Inspection wtlt be requtred foltowlng braak-up. ! tnfor~ed that It was t~posstble to gtve flnal approval untt1 the snow had melted and we could be sure that there was satisfactorily clean-up all around the perimeter of the locattoe. He agreed to thts and carried me back to the math camp ~here ! ate lunch, caught the bus for the atrport and returned to Anchorage on the 1:25 I~t flt'ght. ! arrived back tn Anchorage about 4:00 On this field trtp I travel_ed to the North Slope, resealed three bypass valves at the COT plant, witnessed BOP test on the NGI No. 6 and made a preliminary ftnal inspection on the Able State ~.~o. 1. The COT report of by-passed crude should be reviewed for adequacy when received and the Able State final inspection should be scheduled for this suneer. Sa>,tisfactory Type Inspection.. · SatisfactorY T~pe Inspection NO. item C)<):-,LOCa~,ion~',General- : Yes No'~ I:tem (~Y~ BOPE Tests (~,']:'](~) 1. Well Sign:::'~<' l~vq,, ( ) · (v)-,:( ) 2. General H°useke~eping ,~ ( ) (v~ .( )" 3. Reserve-.Pi.t,(~open(~.)filled (N~)~" ( ) ('~ ( ) 4.~R~g -".".,':.-. :'.. ' . , (~ ( ) ~- ~ ( ).S~fety'va:lve Te~s - (~ ( ) (..)~) 5.. Surface-No. Wells~ - (~ ( ) (:~) ~ - 6. SubsurfaCe-No.~611s _ . . (~. ( ) : ~(~ ~~ ()Well:Te~Data.--'. ~ ( ) ,(..')..() ..- q Wel'l NOS./ , ." ~ ,' :" ' (':) (~') ( ) '8.~s. o~~~';'-' (~ .( ) ( ) ( ) 9'..BS~m.~-'/ ~,~, , ....... (~)' () () '() -lO.,~Y~]s,' ', -'. ~l'"- '~) ~.() . .~-' ()F~~a~m~ ...... (v) ( ) '(.-) '::" (~) ./Z]l. P&A-Marke~' (~.~' ' (..':) ()' ~' 12. Water'weli-~capped( )plugged.-(~ ( ) ( ~ (:) -13. Clean-Up -~ ' - '(~ ( ) ~/) (') 14. Pad'leveled ~ .. (v)" ( ) 15. 16 17. 18 19 20. 21. 22. 23. .24. 25 26, 27. --~__~'Casing set @. 2~[o -Test fluid:( )wtr.-~--[ )mud (~..oil' Master 'Hvd. Control Sys.-;2i~ psig' N~ btls.~o,/~J,/~,'~..,~~...', R~mote C~~ Drilling spool- ~ "outlets Kill Line-(~ Check valve Choke Flowline (~)-'HCR valve Choke Manifold No. valvs/~ flgs.~?.. Chokes-(/)Remote(~) ~os. (~d,i · Test Plug.-(; )Wellhd(k)csg(' )fione Annular Peeventer,3a~sie" · B1 i nd 'Rams ,~,,,~ ps i g 28. F'i~e' R~ms ~,.~,:, psig~'~') . 29. KellY &' Kelly-cock '~,~ psig 30. Lower Kelly valve ~o~opsig' 31 safety Flo.or valves~(~'BV ~'Dart Total inspection observation time /~ i]hrsyLda'~S Remarks Total number leaks and/or equip, failures Notify in days ,.~r when 'r~eady . InsPected by ~ 4, 197~ ~: P,.ud~ Bay N61 ~ 6 (44'24]-1'4) Atlantic Richfield ~y State Perm1 t Noo 76-29 C. R. l~nowles Otstrtct Ortlltng Engtneer Atlantic Richfield Company P. O. Box 360. ~chorage, Alaska 99510 Dear $tr: Enclosed is the approved appllcatton for permit to drt11 the above refe~l~cedr wet1 at a location tn 5ectton g, Township 1114, Range 14E, Well samples, core chips anda mud log are not required. A directional survey is required. {Many rivers tn Alaska a~ thelr dratnage systees have been classified as l~rtant for the spawning _or migration of anadromous fish.. OperaUons tn these areas are subject to AS i6.50.870 and the regulations promulgated there~r (Tttte 5, Alaska Rdm!ntstrettve Code). Prtor to coeeenctng operations you my be contac*~ed by the Habttat Coordinator's oiftce, Depart- ment of Fish and ~. Pollut!on of any waters of the- State is proht.bt~ by AS 46, Chapter 03, Article 7 ~ the ~laU~S prot~l~'~d ~~r (Ttt~e.~St.Ala~ka' . ~fntstrati-~ C~, C~~ 70) a~ by ~e F~eral ~a~r POIlU:I~ ~ontre~ ~t, as ~~d, Prt~ ~ ~ing ~ti~s you my be ~c~d by a ~:~t~ve ~ ~ ~pa~t of Envt~~l C~se~atton. Pursuant to RS 38.~, Local Xtre Tinder State Leases, -the Alaska Department of Labor is being notified, of the tssuance of thls permit to dr111. To aid us ~n sch~u11~ fleld.=.work, we would appreciate your notifying thts offtce- within 48 hours after the well is spb~. We would also llke to be notified so tt~t a representatt, of the 1)Ivision may be present to witness ~stlng of' blowout preve~ equipment befo.~ surface casing shoe is drilled. C. R. Knowl~ 2- I~rch 4, 1976 In ~ event of sus~~ or eba~~nt Please g~ve thts of~Ice adequate advance notification so ~hat we .ma~ halve a wttness present. Enclosure Department of Fish and Game, Habttat Sectlon w/o encl. Oepartnent of Envlroneenta'l Conservation w/o enc l. Oepartnumt of Labor, Supervisor, Labor .Law Compliance Division w/encl. AtlanticRichfieldCompany North An/~ ;an Producing Division North AlasKa District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 25, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99504 RE: North Gas Injection Well No. 6 (44-2-11-14) Sec 2, TllN, R14E, UM Dear Si r: Enclosed is our Application for Permit to Drill the above-mentioned well, together with the $100 application fee; and required survey plat. Since this is the sixth well drilled from this drill site, we request the waiver of the double diverter line requirement of CO 137, Rule 4. This well will be directionally drilled. The surface and bottomhole locations are located on lease 28302, having an effective date of October 1, 1975 and a termination date of March 27, 1984. The information in the above paragraph will be helpful to the State Department of Labor. Very truly yours, C:, R. Knowles District Drilling Engineer CRK/JMM/cs Enclosure Form I 0-401 · REV. 1-1-?1 SUBMIT IN 'fRIP~ .ATE (Olher instructions on reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYFE OF WORK DRILL [X'] DEEPEN F1 b. TYPE OF WELL OIL GAS WELL[]]] '~LL [~ OTm:R GasInjection 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, A1 aska, 99510 ~,,u,om~, ^,, ~.. 4, LOCAHON OF WELL I~IT~IIUII ur Atsurface332 S a lO14'E of NW cr Sec 12 TllN RI4E, At proposed prod. zone -8300'SS, !120'N & l120'W of SE cr Sec 2, TllN, R14E, UM API # 50-029-20206 5. 6. I, EASE I)I£SIGNATION AND SERIAL NO, ADL 28302 7. IF INDIAN, ALI.OI'rEE OR TRIBE NAME - - - ' :ll~f~dhoeBay I NO. r~Dat into NGI //6 (44-2-11-14) 10, I:IELD AND POOL, OR WILDCAT P:~uldhoe Bay-Sadl erochit I 1. SEC., T., R., M., (BOTTOM ItOLE OBJECTIVE) Sec 2, Tl lN, R14E, UM 13. DIST/~NCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. Approx. 8 miles northwest of Deadhorse 14. BOND INFORMATION: ,wEStatewides,~re,y,nd/orNo. Federal Insurance Co. //80113840 AmountS100,000 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit. ff any) 4160' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. ____, 3bOO 16. N OF' ACRES IN LEASE 2560 A'OSED DEPTH 9500' 17. NO,ACRES ASSIGNED TO THIS WELL 320 20. ROTARY OR CABLE TOOLS ~tary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. DATE WORK WILL START 18' Gravel Pad March 30, 1976 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOO'F GRADE SETTING DEYrH Quantity of cement . , , 32" 20" 94# H-40 100' Circ to surf. -+500 sx PFII 17-1/2" 13-3/8" ~ 72# MN 80 2700' Circ to surf. -+4000 sx PFII 12-1/4" 9-5/8" ' 47# MNT80 8240' -+1500' cmt column 1st stq -+1000 .< ' & S00-95 +300' cmt column 2nd stg _+125 sx ,, , 8-1/2" 7" lnr 29# MN-80 TD _+1300' cmt column -+3.00_sx . The Atlantic Richfield Company proposes to directionally drill this well c.'' 'MD (8630'TVD), for future use as a gas injection well into the Sadlerochit gas cap. Log, ,1 be run over selected intervals. A 20-3/4" Hydril and single 4" diverter line will be t;.'.::d on the 20" conductor. A 13-5/8" 5000 psi Hydril, and 13-5/8" 5000 psi pipe and bl'ind rams will be used on the 13-3/8" casing. The BOP equipment will be tested weekly, and operationally each trip. A non-freezing fluid will be left in all uncemented annuli in the permafrost interval. Seven inch 29# MN-80 tubing with a Baker SAB packer assembly and a 7" safety valve landing nipple will be run as completion assembly. The well will be shut in pending perforating. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on. present productive zone and proposed new productive zone. If proposal is to drill or deepen dixectionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby certify that t~ Fqre~oing is True aj~d Correct (This space for State office use) SAMPLES AND CORE CttlPS REQUIRED [] yES ~ NO DIRECTIONAL SURVEY REQUIRED ~ yES [] NO CONDITIONS OF APPROVAL, IF ANY: MUD LOG [] YES [~ NO OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE 50-029-20206 PERMITNO 76-29 APPROVAL DATE March 5, 1976 ~' *See Instruction On Reverse Side SEC I 915' section 965' ' ,' 989' 1014' 1059 !114' II ,.,¢ 07,4/._ ~ .~.~..-.......:.,.4 ~. CERTIFICATE OF SECTION 12 .SURVEYOR ! HEREBY CERTIFY THAT ! AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT TI{IS PLAT REPRESENTS A LOCATION sURVEY, MADE .,BY ME OR UNDER MY SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. OCT 4 , 1975 - . - :- ~ ...., , :~ -_- DATE Dl¥1~iOi~ Of . ,,S-BUILT WELL ~VO.I LAT. 70°19'36.129'' LONG. 148°26'50.016" ' · -:ti ',T -1' - - .1 £7'. _:- - - Y 5 971 400.07 X 667 350.54 WELL NO. 2 .L A T. zo° 19' :32284:: LONG. 148° 28'50.762 Y 5 971 516.90 'X 687 322.06 WELL NO. 3 LAT. 70° 19':38.441" LONG. 148°28'51.493" · Y 5 971 633.76 X 687 294.09 WELL NO, 4 LAT. 70° 19'59.596" LONGi 148° 2.8'52.223" Y 5 971 750.62 X 687 266. I8 WELL NO. 5 LAT. 70° 19'40.749" LONG. 148 °28'52.947" Y 5 971 867.11 X 687 238.47 LAT. 7:'.'" ':' 19' 41. 908''~ LONG. I ' 28'55.682" Y 5 971 984.28 X 687 210,34 WELL i',; ? 7 ,, i II LAT. ' 7U" 19,43.052,, LONG. 148°28 54.412 .,. WE~L L 'NO. 8 LAT. 70° 19'44.210" LONG. 148°28'55.126'' WELL.NO. 9. LAT. LONG. Y 5 972 099.94 X 687 182.47 Y 5 972 217.07 X 687 I55.06 70° 19'45.,370"" . ' Y 5 972 334.31 148° 28'55.850" X 687 127.31 WELL NO. I0 LAT. 70° 19'46.519" LONG. 148°28'56.589" Y 5 972 450.53 X 687 099.14 EXISTING WELL OR ' . CONDUCTOR PIPE ' ! ':"'WELL NO. I TOP PAD ~: .... ELEV. = 18.4 FT. MLLW ARCO~ AFE 292265 HVL -ff. "- ' _ ATLANTIC RICHFIELD CO. ........ .,;, ., ,~ ,., , _,, - AS -BUILT 'WELL I T HUR I0 NORTH INJECTION SITE LOCATED IN PROTRACTED SECTIONS I &I2~-TtlN, RI4E~ U.M. PREPARED BY HEWlTT V, LOUNSEtURY ~ ASSOC, 72:3 W. 6TH.AVE., ANCHORAGE, ALASKA LOOSE CHKD. BY G. D. FIELD BK__LEAF CHECK LIST FOR NEW WELL PERMITS Company /z~C~ Yes No Remarks 1. Is the permit fee attached ..................... 2t~ Lease & Well No. /~WO//~o~ /~~ 2. Is well to be located in a defined pool .............. ~ 3. Is a registered survey plat attached ................. ~ 4. Is well located proper distance from property line ......... ~ 5. Is well located proper distance from other wells ........ ~ 6. Is sufficient undedicated acreage available in this pool ..... ~ ~f Is well to be deviated ...................... ~ 8. Is operator the only affected party ................. ~,j~ 9. Can permit be approved before ten-day wait ............. ~Ac 10. Does operator have a bond in force ............... -.. ~a~ ll. Is a conservation order needed ................... 12. Is administrative approval, needed ............... 13. Is conductor string provided ..................... ,~ ~,'~) 1~. Is enough cement used to circulate on conductor and surface . . . ,~-~C~i~ 15. Will cement tie in surface and intermediate or production strings . Will cement cover all known productive horizons .......... 17. Will surface casing protect fresh water zones ........... 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure ratin~ ............. Additional Requirements' Approval Recommended' Geoloqv Engineering' TRM __ HWK ,,,,,~(-~,/< OKG_. I~HH ~ JAL ~[~ LCS-~<--~r~ JCM. ~~ Revised 1/15/75
