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Home My WebLink About177-040Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:177-040 6.50-029-20260-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11934 10700 8443 11054 none none 8663 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 75 20" 33 - 108 33 - 108 1530 520 Surface 2715 13-3/8" 32 - 2747 32 - 2747 4930 2670 Intermediate Production 11874 9-5/8" 31-11905 31-9226 6870 4760 Perforation Depth: Measured depth: 11576- 11638 feet True vertical depth:9003 - 9045 feet Tubing (size, grade, measured and true vertical depth)5-1/2" 17# L-80 29 - 11166 29 - 8734 11054 8663Packers and SSSV (type, measured and true vertical depth) 5-1/2" Baker FB-1 Packer Liner 590 3-1/2" 9.2# L-80 11150 - 11740 8723 - 9114 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2317004115 00 0 44279 0 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Travis Smith Travis.smith@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 350-9119 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ 5 WAG GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9245 Sundry Number or N/A if C.O. Exempt: Junk Packer Printed and Electronic Fracture Stimulation Data 5 pack-off repair Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028327 PBU 09-19 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations inconclusive 320-305 On 9/6/2020, Hilcorp pumped a Greenstick treatment in the IC packoff void of PBU well 09-19 per Sundry #320-305. Following this treatment, but prior to pulling the TTP, Hilcorp attempted an MITIA to give an initial indication if the treatment was successful. This MITIA failed due to pressure loss in the IA with no OA response, indicating some sort of communication other than through the IC packoff void. Because of this, Hilcorp will discontinue the remaining steps of Sundry 320-305. The well will remain shut-in and Not Operable. By Samantha Carlisle at 1:29 pm, Sep 24, 2020 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.09.24 09:31:50 -08'00' Bo York SDR-9/24/2020 RBDMS HEW 9/28/2020 SFD 9/25/2020 MGR28SEP2020 ACTIVITYDATE SUMMARY 9/6/2020 T/I/O = SSV/0/0. Temp = SI. Green stick (eval IAxOA) Stung into test void 0 psi on void. Monitor for 30 min, no change in pressure. Remove test fitting, R/U packing gun. Sting into test port on back side to remove any water and air. S/I bleed pressure test void to 3,000 psi for 1 hour. Monitor once a week, pump up as needed. 9/18/2020 T/I/O= 10/20/0. MIT-IA FAILED to 2500 psi. (Wellhead repair) Failed to achieve test pressure with19 bbls of diesel. Established a LLR of 0.6 bpm at 2240 psi for the last 6 bbls. Bled pressures. RDMOL. Final T/I/O= 20/110/24. Daily Report of Well Operations PBU 09-19 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:177-040 6.API Number:50-029-20260-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028327 Property Designation (Lease Number):10. 8. PBU 09-19 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Packoff Repair Op Shutdown GAS 5 GSTORWAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11934 Effective Depth MD: L-80 11. 7/27/2020 Commission Representative: 15. Suspended Contact Name: Travis Smith Contact Email: Travis.smith@hilcorp Authorized Name: Stan Golis Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9245 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 11054, 8663 No SSSV Installed Date: Liner 590 3-1/2" 11150 - 11740 8723 - 9114 10160 10530 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 32 - 2747 32 - 2747 14. Estimated Date for Commencing Operations: BOP Sketch 33 - 108 Structural Proposal Summary 13. Well Class after proposed work: 5-1/2" Baker FB-1 Packer 11576- 11638 9003 - 9045 5-1/2" 17#29 - 11166 Production 11208 8761 11208 none 33 - 108 520 13-3/8" Contact Phone:907-350-9119 Date: 75 153020"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2715 4930 Intermediate 11874 9-5/8" 31-11905 31 - 9226 6870 4760 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Jody Colombie at 10:50 am, Jul 19, 2020 320-305 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.07.17 15:28:08 - 08'00' Stan Golis DSR-7/20/2020SFD 7/20/20MGR20JUL20 10-404Yestion Required? Comm. 7/21/2020 JLC 7/20/2020 RBDMS HEW 7/24/2020 09-19 IC Packoff Repair Integrity Engineer: Travis Smith (907) 350-9119 Ops Engineer: Torin Roschinger (406) 570-9630 Ops Manager: Bo York (907) 777-8345 Expected Start Date: July 27, 2020 History 09-19 is an injection well that has been Not Operable since failing an MIT-IA in April 2018. During this MIT-IA, the IA pressure loss itself would not have failed testing criteria, but the OA pressure exhibited an increasing trend and the test was determined to be a fail. After the failing MIT-IA in 2018 diagnostics indicated a very low liquid leak rate between the IA and the OA of approximately 0.12 gpm. Hilcorp proposes pumping sealant into the packoff void in order to address any possible communication through the IC packoff seals and returning the well to injection service. Current Status The well is currently offline and has been classified as Not Operable by Hilcorp. Objective Use “green stick” plastic packing (or other sealant) to seal the inner casing packoff void and eliminate the IAxOA communication. Overview Procedure 1. Bleed pressure from IA and OA. Verify no-flow from each annulus. 2. Treat the inner casing packoff void with “green stick” style packing (or WellLock resin, or other sealants as necessary) through the lockdown screw and/or test ports. 3. Slickline: pull PX-plug from 11,208’ MD. 4. Return well to water injection service. As soon as well has stabilized on water injection, provide AOGCC with notification for witnessed MIT-IA. 2 Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, November 26, 2018 7:32 AM To: AK, GWO Well Integrity Engineer, Wallace, Chris D (DOA); AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS Pipeline Compl Specialist; AKOpsProdEOCTL; Alatalo, Travis; G GPB FS2 Drillsites; Rupert, C. Ryan Cc: Regg, James B (DOA); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R, Tempel, Joshua; Worthington, Aras J; Bronga, Jaime Subject: NOT OPERABLE: Injector 09-19 (PTD #1770400) Slow IAxOA confirmed with extended MIT -IA All, Injector 09-19 (PTD #1770400) was made under evaluation on 11/8/2018 in order to perform warm diagnostics to determine if IAxOA communication had successfully been mitigated. On 11/17/2108 DHD performed an inconclusive AOGCC witnessed MIT -IA with slow pressure build up in the OA. Follow up diagnostics performed on 11/23/2018 confirmed a liquid leak rate from the IA to OA of approximately .12 GPM. -Warm diagnostic work is now complete and the well is shut in and freeze protected. At this time the well is reclassified as Not Operable and will remain shut in. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED U HL,' I A From: A , O Well Integrity Engineer Sent: Thursday, ember 8, 2018 7:29 AM To:'chris.wallace@alasv' <chris.waIlace @alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKO SOpsLead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityOTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2FieId6_T_p,com>; AK, OPS FS2 OSM <AKOPSFS20SM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp corn>;,AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AK, OPS Pipeline Compl_Specialist <AKOPSPipelineComplSpecialist@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; Rupert, C. Ryan < Ryan. Rupert@BP.com> Cc:'Regg, lames B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCP rojectsWe I I I ntegrityE ngi nee r@ bp.com >; AK, GWO SUPT Well Integrity 1 F IMEMORANDUM • TO: Jim Regg P.I. Supervisor IIIA"' '-,^A' is Gt r 0 40 , FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 21, 2018 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 09-19 PRUDHOE BAY UNIT 09-19 Src: Inspector Reviewed By: P.I. Supry .� F Comm Well Name PRUDHOE BAY UNIT 09-19 API Well Number 50-029-20260-00-00 Inspector Name: Austin McLeod Permit Number: 177-040-0 Inspection Date: 11/17/2018 t Insp Num: mitSAM181117142237 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -- --- — --------- Well 09-19 Type Inj W TVD 8661 Tubing 1245 1245 1254 - 1253 1253 PTD 1770400 Type Test SPT Test psi 2165 IA 85 2499 - 2452 2433 - 2420 '! -- BBL Pumped 6.5 ' BBL Returned: 6.4 OA 571 683 726 767 795 Interval OTHER P/F I Notes' Well was tested and failed in April. As per the IA the test passed. But with a consistent increase on the OA I was not going to pass it in the field. High bbl in/out count. Did not feel I could make an issue out of that as a completely topped off backside only behooves the operator. I calculated 4.5 bbls to pressure using 11,050' MD. 9-5/8 x 5-1/2 Wednesday, November 21, 2018 Page 1 of 1 Nk oci- —Ity PIt i,-70 Regg, James B (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, November 19, 2018 1:23 PM To: Regg, James B (DOA) ►`'�� I �� l F` Cc: Wallace, Chris D (DOA); AK, GWO SUPT Well Integrity Subject: RE: PBU 09-19 (PTD 1770400) Inconclusive MIT Mr. Regg, The current status of the well is online under eval undergoing additional warm diagnostics. The plan forward is to validate if the well has IAx0A communication in order to aid in determining if the witnessed MIT -IA was a pass or fail. The OA pressure increase seen on 11/17 is suspected not to be caused by IAxOA communication for the reasons below 1. The pressure pumped in the well and bled from the well was within .10 bbls which is within error for tank strap volumes. 2. When the inner annulus was bled back to the original starting pressure the OA pressure was within 10psi of the starting pressure. ( IA/OA = 80/570psi). 3. After the inner annulus bleed was shut in the OA pressure continued to climb an additional 50psi and was 470psi above the IA pressure. While I can't offer an explanation for the strange behavior of the OA pressure during and after the MIT I can say that it isn't indicative of what we normally see with wells that have IAx0A communication. The plan forward is to do an extended liquid leak rate test on the IA to see if the OA pressure continues to climb or stabilizes. If IAx0A communication is confirmed the well will be shut in and freeze protected. However if the LLR test does not show communication further work will need to be considered in order to determine the source of the OA pressurization. Meanwhile, leaving the well on injection adds little to no risk as the MITIA indicates integrity of 2 barriers to formation. Please advise if in conflict, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 S .. From: Regg, James B (DOA) <jim.regg@alaska.gov> Sent: Monday, November 19, 2018 11:09 AM To: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Cc: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: PBU 09-19 (PTD 1770400) Inconclusive MIT 1 L..J An AOGCC Inspector witnessed an MIT on 11/17 deemed by him to be inconclusive due to steady increase of pressure in the OA — see attached. This well was shut in during April 2018 following a failed MIT (IAx0A communication). What is the status of this well? 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 (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.reggealaska.gov. 1 9 MEMORANDUM TO: Jim Regg P.l. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL 0 State of Alaska Alaska Oil and Gas Conservation Commission DATE: Saturday, November 17, 2018 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC, 09-19 PRUDHOE BAY UNIT 09-19 Src: Inspector Well Name PRUD14OF BAY UNIT 09-19 API Well Number 50-029-20260-00-00 Inspector Name: Austin McLeod Permit Number: 177-040-0 Inspection Date: 11/17/2018 Insp Num: mitSAM181117142237 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-19 Type Inj w TVD 8661 Tubing 1245 1245 1254 1 1253 1253 PTD 1770400 Type Test 1 SPT Test psi 2165 1 JA 85 I 2499 I 2452 2433 2420 BBL Pumped: 6.5 BBI, Returned: C 6.4 OA 571 683 726 ✓ 767 795 Interval Other (describe in notes) P/1F 1 Inconclusive Notes: Well was tested and failed in April. As per the IA the test passed. But with a consistent increase on the OA I was not going to pass it in the field. Saturday, November 17.201& Page I of I Wallace, Chris D (DOA) • • From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, November 8, 2018 7:29 AM To: Wallace, Chris D (DOA); AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS Pipeline Compl Specialist; AKOpsProdEOCTL; Alatalo, Travis; G GPB FS2 Drillsites; Rupert, C. Ryan Cc: Regg, James B (DOA); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity, AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R, Tempel, Joshua; Worthington, Aras J; Bronga, Jaime Subject: UNDER EVALUATION: Injector 09-19 (PTD #1770400) put on injection to verify IAxOA communication is mitigated All, Injector 09-19 (PTD # 1770400) was made Not Operable after it failed an AOGCC witnessed MIT -IA on 04/10/18. During the test, fairly rapid IAxOA communication was observed. Follow up diagnostics indicated the wellhead seals were the source of communication and the lockdown screws were torqued to re-engage the seal. A shut in MIT -IA passed to 2,720 psi and MIT -OA passed to 1,838 psi. The State has agreed to let BPXA bring the well online so it can thermally stabilize, then do follow up diagnostic work to ensure the IAxOA communication has been mitigated. The well is now classified as UNDER EVALUATION. If the communication is mitigated, an AOGCC witnessed MIT -IA will be performed with the well online before it is classified back to Operable. Please note the fluid packed annulus when bringing the well online. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 %ate JjCiV Z � ZUlh. From: AK, GWO Well Integrity Engineer Sent: Tuesday, April 10, 2018 3:14 PM T� , S EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2D iad@bp.com>; AK, OPS FS2 Facility OTL <AKOPSFS2FacilityOTL@bp.com>; AK, OPS FS2 Field OTL <AKOPSFS2FieldOTLbp. • AK, OPS FS2 OSM <AKOPSFS20SM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellOptEngr@bp. AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.c6`" G_GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; Stechauner, Bernhard <Bernhard.Stechauner@bp.com>; 'ch ris.wallace@alaska gov' <chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWe I I I ntegrityE ngi nee r@ b p.co m>; AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel @bp.com>; Dempsey, David G <David.Dempseyl@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau • Regg, James B (DOA) 0 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, November 19, 2018 1:23 PM To: Regg, James B (DOA) Cc: Wallace, Chris D (DOA); AK, GWO SUPT Well Integrity Subject: RE: PBU 09-19 (PTD 1770400) Inconclusive MIT Mr. Regg, The current status of the well is online under eval undergoing additional warm diagnostics. The plan forward is to validate if the well has IAx0A communication in order to aid in determining if the witnessed MIT -IA was a pass or fail. The OA pressure increase seen on 11/17 is suspected not to be caused by IAx0A communication for the reasons below 1. The pressure pumped in the well and bled from the well was within .10 bbls which is within error for tank strap volumes. 2. When the inner annulus was bled back to the original starting pressure the OA pressure was within 10psi of the starting pressure. ( IA/OA = 80/570psi). 3. After the inner annulus bleed was shut in the OA pressure continued to climb an additional 50psi and was 470psi above the IA pressure. While I can't offer an explanation for the strange behavior of the OA pressure during and after the MIT I can say that it isn't indicative of what we normally see with wells that have IAx0A communication. The plan forward is to do an extended liquid leak rate test on the IA to see if the OA pressure continues to climb or stabilizes. If IAx0A communication is confirmed the well will be shut in and freeze protected. However if the LLR test does not show communication further work will need to be considered in order to determine the source of the OA pressurization. Meanwhile, leaving the well on injection adds little to no risk as the MITIA indicates integrity of 2 barriers to formation. Please advise if in conflict, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 'tet From: Regg, James B (DOA) <jim.regg@alaska.gov> Sent: Monday, November 19, 2018 11:09 AM To: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Cc: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: PBU 09-19 (PTD 1770400) Inconclusive MIT 1 An AOGCC Inspector witnessed an MIT on 11/17 deemed by him to be inconclusive due to steady increase of pressure in the OA — see attached. This well was shut in during April 2018 following a failed.MIT (IAx0A communication). What is the status of this well? 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 (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 jim.re�@alaska.ov. Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Thursday, November 1, 2018 7:26 AM To: 'AK, GWO Well Integrity Engineer' Cc: AK, GWO Well Integrity Well Information Subject: RE: Injector 09-19 (PTD #1770400) Request permission to bring well on injection Under Evaluation Joshua, Plan as below is approved. After stabilization, if all looks good, an AOGCC witnessed (or waived) should also be completed to continue injection. Please ensure that AOGCC is provided with the recent passing mics before the 5tn Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.sov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, October 31, 2018 6:57 PM To: Wallace, Chris D (DOA) <chris.waIlace@alaska.gov> Cc: AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Subject: Injector 09-19 (PTD #1770400) Request permission to bring well on injection Under Evaluation Chris, Injector 09-19 (PTD #1770400) was made not operable on 4/10/2018 immediately following a failed AOGCC witnessed MIT -IA. The well was shut in immediately due to fairly rapid IAxOA communication during the test and as a precaution after the L5-13 failure. later diagnostics indicated that the wellhead seal were the source of the IAxOA communication and the lockdown screws were torqued to re engage the seal. The well passed a shut in MIT -IA to 2,720psi and MIT -OA to 1,838psi. BPXA believes the IAxOA communication has been mitigated and is requesting permission to bring the well online Under Evaluation to perform further diagnostics while the well is warm. If this is permissible or if you would like any further information to make a decision please let us know. Thanks, SCANNED Nov 0 7 L 16 Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,May 03,2018 TO: Jim Regg -� P.I.Supervisor C' zj SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 09-19 FROM: Guy Cook PRUDHOE BAY UNIT 09-19 Petroleum Inspector Src: Inspector Reviewed B.y::p� P.I.Supry 5R-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-19 API Well Number 50-029-20260-00-00 Inspector Name: Guy Cook Permit Number: 177-040-0 Inspection Date: 4/10/2018 • Insp Num: mitGDC180410150835 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-19 Type Inj W `TVD 8661 - Tubing 1763 1760 PTD 1770400 Type TestfSPT Test psi 2165 . IA 716 2730 BBL Pumped: BBL Returned: I OA 70 230 Interval 4YRTST 1P/F F v Notes: While pressuring up the IA to 2800 psi,the IA breeched and started to pressure up the OA. When we reached 2730 psi on the IA is when the breech occurred. I witnessed the OA pressure at 230 psi and climbing. The pumping was stopped and the IA and OA were bled off to 500 psi. 5 barrels were bled off the IA and the OA combined to get the pressure down to 500 psi. We monitored the annulus pressures after they were shut in to ensure there was no communication with the tubing. The well was shut in and would be freeze protected within a couple of hours. SCANNED Thursday,May 03,2018 Page 1 of 1 * S Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, April 10, 2018 3:14 PM To: AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; G GPB FS2 Drillsites; Stechauner, Bernhard;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A;Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J; Regg,James B (DOA) Subject: NOT OPERABLE: Injector 09-19 (PTD#1770400) Secondary barrier failure during pressure test Attachments: 09-19.pdf All, Injector 09-19 (PTD#1770400)was undergoing its 4 year AOGCC MIT-IA when the secondary barrier failed resulting in rapid lAxOA communication. There was no release to surface and no indications that the primary well barrier was compromised. The well was immediately shut in and freeze protected and efforts are underway to secure the well with a down hole plug. At this time the well is reclassified as Not Operable and will remain shut in. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 suo1 Cell: 907-341-9068 t M++wmpas yah++ 1 • • a) D ~ n Z O C? 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Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Re-enter Susp Well 0 Other Set Scab Liner p 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 177-040 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service lid 6. API Number: 50-029-20260-00-00 7. Property Designation(Lease Number): ADL 0028327 8. Well Name and Number PBU 09-19 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 11934 feet Plugs measured feet true vertical 9245 feet Junk measured feet SEP 14 2017 Effective Depth: measured 10700 feet Packer measured 11054 feet /�/�/� true vertical 8443 feet Packer true vertical 8663 feet 1 b/AA VC Casing: Length: Size: MD: TVD: Burst Collapse: Structural Conductor 75 20"94#H-40 33-108 33-108 1530 520 Surface 2715 13-3/8"72#N-80 32-2747 32-2747 4930 2670 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 590 3-1/2"9.2#L-80 11150-11740 8723-9114 10160 10530 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet � � E� 01 � Tubing(size,grade,measured and true vertical depth) 5-1/2"17#L-80 29-11166 29-8734 Packers and SSSV(type,measured and 5-1/2"Baker FB-1 Packer 11054 8663 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11334'-11350',11366-11386,11414'-11454',11465'-11505',11528'-11532%11576'-11606,11621'-11638'. Treatment descriptions including volumes used and final pressure: 8.9 Bbls 50/50 Methanol/Water,17.4 Bbls Fresh Water,45.6 Bbls 15.8 ppg Class G Cement,25.5 Bbls Fresh Water w/Inhibitor,38 Bbls 1%Slick KCL,11 Bbls PowerVis,72.2 Bbls Diesel, 830 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 19270 280 1508 Subsequent to operation: 4090 160 1528 14.Attachments:(required per 20 SAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 0 Service Q Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG Id GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-414 Authorized Name: Stechauner,Bernhard Contact Name: Stechauner,Bernhard Authorized Title: FS ad P Contact Email: Bernhard.Stechauner@bp.com Authorized Signature: Date: .2/1471 Contact Phone: +17 907 564 4594 Form 10-404 Revised 04/2017 �q� 7 VEL 10 /I7i i 1 R D D M S t�L P,-77) 2 5 L U 1/ • • • Alaska Oil and Gas Conservation Commission RECEIVED 333 West Seventh Avenue Anchorage, AK 99501-3572 SEP 1 4 2017 AOGCC RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary September 7, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Repairing of Well with a Scab Liner and then Perforating for Well 09-19, PTD # 177-040. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. 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(-- E 2 ``) 0 QNz 0.. 0 O co c`o COI ... o dZ . 1- Q = ' S 4'm v ) 0 0 O Q� � c�i w Cua Ftp Via ,- � u) cr° � C� * '+- a) .c c aCo II * ai .CO ,co,- II a- - ' o6 u/) I * off N m o 3 E o0 -i m ^Q ~ a� Q `zr � 2I- L- , wNa o r a v cQ a) oo › p HBO L-- taco o0 n '' 02 * 1 � DcoD N O C - O o = C) N p2 • t Q 2 = -, n " Q 0 � U * oml- D W ZO 0. a) 3 3 U Co - ,c o cn "- o °- - z 1L Cn h" � CLCD • » CL a, Q `o N ~ * 3 0 � 11 c°)ip as _13a) c�nD � � i °O � QmQ (� Q A 8 m o aaim � n Q 3a= 'a o n CI- 0 JC� w0N' 8 - wQ > po) a) E oao - co. moo m = > a_1 48., co > 5 � UOCYIoory = Z Cti c v3, � � cn oN I- L2 a) I- E V FE2Q � F- w Z 0 13 n m � � N i t 0 E E o a . - . � D v O � � O � O z � w co) - 3 to)� a m c `o * CO CU cu - U QOM m0OaD (n E0 � Q C - � `- a, o -, a oat to � m � � p � w t ' °oto o- •-0 0 Sao 3 mupw > - 0co > p � < ciww0HE- Z1- 1- o M O O Q a) = C 1 N Q U 0,(/) � N C ,C U) N N = = W w < H - Z ` = ACV = 7 N - N E O E Q m (n CO N O ._ C) (n x > Z_ Z J am = Cn p d. a, 2 o cz'm � ' v ao > l- N II Q J - coWI- HZJ (n = N0 C = � .QOCO N •� 00 N � II II 0 0w W MCLOOO ~ wm Jm _ _ O > 1- N - N * 1— ,- a) - � > - Cu � > j < Q = Vit U0 > 0 > CC � U � 2 2 a E * U o f .- * H O v) F- 1- co O co * CC CC Z * * U * N- N- 1 r ,- � ti 0 0 CN N N N O o O CO .cr N- a) N N N N N CO I� co N- N- N- N co co co 0 0 u > / a z 2 2 ' � _ Z Ili cc 0 co k ten / Z d o O 2 ƒƒ f / f E g 02 z E o L 0. W k WO 0 o / o co o 9 E CO co -2 k % / { a O 7 / k / ~ k c � al i / / E CL E ! 7 2 2 & 3 U- M � CO / / < I- / 7MRke ~ / ~ 1 < Cl) ✓ O. 7771_ 0m WM D o fc `- - « — OW (9 W , , om , / -1R / oOrt@ 2Q me o L _ o m 2 $ ,_ RI ow � 2 ¥ Z O E2 • / / -I / 2 / S ® / k \ 3 / 2@ryN- 2p q � 22 2 0 £ • q_ e � 0 o cn ~ O > < DZI— R . ccUU � k / Uw7 ± ow26r) & �Om� q O _1E $ � Eb � � � 22 / / � ƒ kƒ aoo � : z / w ƒ ° w ƒ 0 ƒ 2 ml- Lo _ « § @ § i � I CL CL Et a a -1 CC ! 5 2 2 ƒ $ Q 2 ¥ � / \ 2 % 2 = m n o Na) a co -T2 2 III TREE= RC GEN 1 silky NOTES:I$2S READINGS AVERAGE 125 ppm WELLJ-EAD= FMC 09-1 9 WHEN ON MI. WELL REQUIRES A SSSV WHEN ON ACTUATOR= AXELSON MI. OKB.ELEV= 54' BF ELEV= KOP= 3139' I 2215' -15-1/2"CAM BAL-0 SSSV NP,ID=4.562' Max Angle= 52',;', 10238" Datum MD= 11308' 0 I Datum TVD= 8800'SS' 13-3/8"CSG,72%,N-80,ID= 12.347" —I 2714' -4 i11049' —15-1/2"BOT SEAL ASSY 11061' ---is-5/8-X 5-1/2-BAKER F13-1140R,0=6.00' Minimum ID = 2.813" a 11208' NSAK SLIDING SLEEVE I 11160' ,Hc —_EEVE.El=3-375' 11154' H4"DEPLOYMENT SLV,ID=3.00" 5-1/2'OTIS XN NP,ID=4,455'(BOUND LNR) H 11152' 11156' —4.562"OD NSAK NO/GO SWEDGE "'LOGGED @ 11156'ON 05/04/17*" SEAL SUB,ID=2.920" 1116.4' —15-1/2"BAKER SI-EA ROUT SUB 5-1/2"TBG-F ,17#,N-80,.0232 bpf,ID=4.892" — 11166' (---------. 1116f j--15-1/7 TUBING TAL FERFORATION SUMARY 11155' Ha/AC/TT LOGGED 04/04/88 I REF LOG.E11-02S on 12/21/1977 -11208' --1TOC(05i08,17) ANGLE AT TOP PEW: 48'4-, 11334' Note:Refer to Production OB for historical perf data II.0 Fri ... 11208' —NSAK SLIDING SLV 9-CR,ID=2.813' 444 MI '444 (CLOSED) SIZE SW INTMVAL Opn/Sqz DATE 3-3/8" 6 11334-11350 S 05/07/17 ....4.4. 04...... 4.1 #4. ... 3-1/8' 4 11337-11346 S 02/05/88 44 '444 444 044 3-118" 4 11366-11386 S 02/05/88 44 '444 444 444 3-1/8" 4 11414-11454 S 02/05/88 4444 '444 4 444 3-3/8" 6 11465-11505 S 05/07/17 $44 444 444 3-1/8" 4 11528-11532 S 02/05/88 044 V/ 044 44 '444 3-3/8" 6 11532-11542 S 05/07/17 444 444 44 444 3-3/8" 1 11576-11606 S 05/07/17 444 444 44 '444 2-112" 6 11576- 11606 0 08/09/17 ••• 6.. 44 '444 44 044- 3-3/8' 4 11621 - 11638 S 05/07/17 444 '444 444 2-1/2' 6 11621 -11638 0 08/09/17 44.#4 '•.I 444 041 444 44 44 '444 4 4* '444 444 444 1 [3-1/2"NSAK 450-350 ORCA ClAT VALVE 9-CR 1 11722' 44 '444 444 444/ 13-1/2LNR,9.2#,L-80 STL, H 11740' •:4.PairA4A•7•• -11700' —TOC(COL MI_LED CMT 06/01/17) 1.0087 bpf,D=2.992" v4it44_ee/4.1V-44A444v•ve• 404 FelD -- 11130T21.4.4-4..4. 44••••••••• 4444444444i 4444444444 4•444444441 9-5/8"05G,47*.N-80 RTC,0=8.681'1-1 11906' 14444444444 Ma.•••••••••••tt4 4*4.44**AVM 44444444444 TD —{ 11934' o.....11.104.41.114.11A1 DATE REV BY COMENTS [ATE REV BY COMMENTS PRWAIDE BAY UNIT 12/28/77 ORIGINAL COMPLETION 06/08/17 ATO/JM) COL PALLED CMT(06/01/17) WELL 09-19 02/09/88 LAST WORKOVER 08/10/17 BTN/JMD REPERF(08/09/17) FERMT No. '1770400 04/22116 JM) I•VBS CLEAN UP PER TALLES , AR No: 50-029-20260-00 05/24/17 TA/JM) COL SCAB LINER(05/07/17) Sec. 1,TION,R15E,524'FSL&250'FWL 05/30/17 JM/JM) CORRECTED SVVEDGE 05/30/17 JDINJAC FNAL AFFROVED BY COL ,.. BP Exploration(Alaska) '11 -D'to • 'WELL LOG TRANSMITTAL#904017850 To: Alaska Oil and Gas Conservation Comm. July 3, 2017 Attn.: Makana Bender RECEIVED 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 JUL 0 7 2017 DATA A A L LOGGED E Ivl.K.BENDER RE: Coil Flag Log: 09-19 AO G C C Run Date:5/4/2017 V The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari,Halliburton Wireline&Perforating, 6900 Arctic Blvd.,Anchorage,AK 99518 09-19 Digital Data(LAS),Digital Log file(Field Data) 1 CD Rom 50-029-20260-00 Coil Flag Log(Field Print) 1 Color Log 50-029-20260-00 SCANNED JUL 1 72017 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:idIviltigatossoksaltzat Or •7.4 . • g-��ly/�� THE STATE Alaska Oil and Gas ti 'i �, of Conservation Commission .,.„ ALASI<;A Lit : t i �� y 333 West Seventh Avenue O 'A 9'F' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov David Wages N�E Well Interventions Engineer D' FEB I 6201Z BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-19 Permit to Drill Number: 177-040 Sundry Number: 316-414 Dear Mr. Wages: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, /3e--.--7 Cathy . Foerster Chair DATED this/9""day of September, 2016. RBDMS l.A/SEP 12 2016 • STATE OF ALASKA ' •ALASKA OIL AND GAS CONSERVATION COMMI ON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1/ 1. Type of Request: Abandon ❑ Plug Perforations"� Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 4tVOtherp( Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑'0'401e-enter Susp Well 0 Alter Casing 0 Other Set Scab Liner H• 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 177-040 • Exploratory 0 Development ❑ 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-20260-00-00 ' 99519-6612 Stratigraphic 0 Service H- 7, If perforating: 8. Well Name and Nu r: What Regulation or Conservation Order governs well spacing in this pool? d.D,...35/7e--- RECEIVED Will planned perforations require a spacing exception? Yes ❑ No H PBU 09-19 9. Property Designation(Lease Number): 10. Field/Pools: AUG 0 9 2 016 ADL 0028327. PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY AOGCC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): vi- Plugs(MD): Junk(MD): 11934 • 4/Z75.9?..45-1.--A 4.q a. 11862 9197 2 SZ 0 Casing Length' Size MD TVD Burst Collapse Structural Conductor 75 20"94#H-40 33-108 33-108 1530 520 Surface 2715 13-3/8"72#N-80 32-2747 32-2747 4930 2670 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment LinerI Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 5-1/2"17#L-80 L-80 29-11166 Packers and SSSV Type: 5-1/2"Baker FB-1 Packer Packers and SSSV MD(ft)and TVD(ft): 11054, 8663 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary H Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service H• 14.Estimated Date for Commencing Operations:�/ /j � ( 115. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG H ' GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Wages,David be deviated from without prior written approval. Email David.Wages@bp.com Printed Name Wages,David Title Well Interventions Engineer f Signature Phone 907.564.5669 Date0::1 (b COMMISSION USE ONLY ll Conditions of approval:NVoti y Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test V Mechanical Integrity Test 0 Location Clearance 0 Other: 50P -kr 5t pre55v`'L 1`0 4-1) P 5 � R>f 9holvo A-,,,, - I-a Z -c c) p 5 r frvPost Initial Injection MIT Req'd? Yes 0 No 0 w / 5l b �C e ✓ �c' V�� Spacing Exception Required? Yes 0 No IV Subsequent Form Required: 1 0 — 4 0 4-- �/U� APPROVED BYTHE Approved by:/ (1`� COMMISSIONER COMMISSION Daten�/c�_/, «( VrL 17,c/6 ORIGINAL RBDMS ( VSEP 2 2 2016 Submit Form and Attachme is in Duplicate Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. 4 i Q o 0 0 0 0 0 0 0 co N (O CO CO (o CO 00 CflO N- O N- O N U n 0 0 0 0 0 0 0 0 i M M IC) N- LO N- (O 3 1.0 d) c 00 N- CO c- N- m op co OO CO co N- 00 I"- co CO Nt C) CP V N- N- O M M N- M CO N- co N N N- 00 CO O) 00 C) II I P H CO CO M N •- V N- N- O O) M M M M (0 N- o0 N N- CO (O I. CD M V N N TD;N O V- C.) 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Loepp, Victoria T (DOA) From: Wages, David <David.Wages@bp.com> Sent: Wednesday, August 10, 2016 10:20 AM To: Loepp, Victoria T (DOA) Cc: Meixueiro, Paulina; Dickerman, Eric Subject: RE: PBU 07-04A(PTD 192-067, Sundry 316-363) Scab Liner Follow Up Flag: Follow up Flag Status: Flagged Victoria, Below is the MPSP for our list of wells (in order of priority) 1) 3-12: Reservoir pressure @ 8800'TVD: 3300 psi, MSPS:2420 psi 2) 9-19: Reservoir Pressure @ 8800'TVD: 3400 psi, MPSP: 2520 psi ,,,A3) 7-04: Reservoir Pressure @ 8800'TVD: 3270 psi, MPSP: 2390 psi Per BP's standing orders: The BOP rams will be tested to 4000 psi every time on every well The Annular will be tested to MPSP Thank you, please let me know if you need anything else. David Wages o. 907.564.5669 c. 713.380.9836 WIE-AK From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, August 10, 2016 9:25 AM To: Meixueiro, Paulina Cc: Wages, David Subject: RE: PBU 07-04A(PTD 192-067, Sundry 316-363) Scab Liner MPSP is the maximum potential surface pressure based on a pressure gradient to surface of 0.1 psi per foot of TVD depth. See 20 AAC 25.280(b)(4)for definition. BOP schematic for BOP intended to use. From: Meixueiro, Paulina [mailto:�aulina.meixueiro@b .com] Sent: Wednesday, August 10, 2016 9:09 AM To: Loepp, Victoria T(DOA) Cc: Wages, David Subject: RE: PBU 07-04A(PTD 192-067, Sundry 316-363) Scab Liner Hi Victoria, We will get you the post-work schematic and the more detailed procedure. Can you elaborate more on the MPSP and the BOP schematic? I want to make sure we understand what's the request. Thanks, 1 • Paulina Meixueiro Production Engineer (907)564-5971 From: Loepp,Victoria T(DOA) [mailto:victoria.loeoo@alaska.gov] Sent: Wednesday, August 10, 2016 9:03 AM To: Meixueiro, Paulina Cc: Wages, David Subject: RE: PBU 07-04A(PTD 192-067, Sundry 316-363) Scab Liner I have not heard back on this. Please also provide a BOP schematic, MPSP and BOP test pressure. From: Loepp, Victoria T(DOA) Sent:Thursday,July 28, 2016 11:22 AM To: 'paulina.meixueiro@bp.com' Subject: PBU 07-04A(PTD 192-067, Sundry 316-363) Scab Liner Paulina, Please provide a post-work schematic. The setting depths for the liner are not clear. Please provide this as well as a detailed word procedure. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(c�alaska.gov 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 2 bp • 0 0 09-19 WSO with Scab Liner Wel!work Procedure Request R. Mielke/C. Olsen: Coil and Well Testing Supt. Date: Sept 9, 2016 To: L. Seymour/ R. Burnett:Well Support Supt. T. Roschinger/E. Townsend: Eline and Pumping Supt. AFE: SAK000000323 From: Eric Dickerman IOR: 50 Est. Cost: $370K Subject: 09-19 WSO with scab liner Revision: Job Sequence WBL Steps Completed (mm/dd/yy) 1. S Drift. 2. V Remove swab. 3. C/WWP Schmoo-B-Gone. Make up liner. Deploy liner. Cement liner. 4. V Install swab. 5. F WOC 3 days. Pressure test TBG and liner 6. S Drift. 7. E Adperf 1 Job Objective: Specific Well Objective 1 Shut off Zone 3 that is taking —90% of injection. 2 Reperf target injection zones. Program Contacts: Contact Work Phone Mobile Phone Interventions Engineer David Wages 564-5669 713-380-9836 Interventions Engineer Eric Dickerman 564-4277 307-250-4013 Pad Engineer Bernhard Stechauner 564-4594 907-360-7485 Schlumberger Liam Zsolt 907-227-3562 907-227-3562 Baker Elliot Tuttle 907-252-3347 907-252-3347 Northern Solutions Jon Milne 564-4951 Northern Solutions Carl Diller 307-258-6679 307-258-6679 Northern Solutions Bob Harris 564-4080 907-240-0427 • • 1 Scope of Work 1.1 Well Summary 09-19 is currently online injecting about 17,000-19,000 BWPD with wellhead pressures of about 1,450psi. Most of the injection going into zone 3. Injection into Zone 3 in this well supports a minimal amount of oil. On an IPROF in July 2006, the spinner data indicated that almost all of the injection was going into Zone 3 perfs at 11,366— 11,386', with only the temperature profile indicating that some fluid injection below 11,386'. The well has a history of Schmoo, however coiled tubing schmoo-be-gone's have been able to clean out to 11,800' in the past. The secondary IC packoff seals have failed indicated by a failed PPPOT-IC and a subsequent LPE performed in April 2014. 2 Critical Issues 2.1 Tree Configuration 1. Due to the current tree configuration, the swab valve, and the MI line injection line will have to be removed. 2.2 Key Risks and Mitigation Strategy 2. Well has confirmed tubing and packer integrity by passing MIT-IA to 2500psi on 04/07/2014. It has 2 annuli, IA and OA. Do not exceed 1000psi on the OA, or 2000psi on the IA. 3. Adjacent Well Shut-in Requirements: NONE — The adjacent wells, 09-18 and 09-20, are on 120' spacing. There is adequate room to rig up the Klondike without removing the well houses from 09-18 and 09-20. Supporting injectors do not have to be shut in. 2.3 Pressure Prediction 1. Reservoir pressure — BHP is expected to be 3400 psi (7.4 ppg) @ 8800' TVDss. Maximum surface pressure with gas (0.10 psi/ft) to surface is 2520 psi. A full column of 1% KCI (8.4 ppg)will provide a —440 psi static overbalance. 2. Fracture pressure — For the PBU main area the FG is estimated to be 0.65 psi/ft. This equates to 5,720 psi. Or 12.5ppg EMW. 2.4 Well Control and Hole Monitoring See Schlumberger's procedure Klondike Well Control and Monitoring Guidelines, it was designed to agree with BP procedures. Maintaining fluid level at surface If fluid is at surface, continuously pump across the top monitoring in/out micro motions to ensure fluid level stays at surface. The max hole fill up rate should be around 5BPM. At 5 BPM the constraint is the logistical concern of being able to keep enough fluid on location. Constant fill up details, fluid level not at surface Min hole fill up rate: 2000 ft/hr(gas migration rate through water) Min pump rate for 9-5/8" completion: (2000ft/hr/60min/hr)*0.0732bb1/ft=2.5 BPM Minimum Fluid volume required on Location 1.5 times the wellbore volume to top perf= 1.5 x 271 =407 bbl Well:09-19 Version:3 2 Operations Program • 410 3 Well Specific Information 3.1 Wellbore Volumes Top Bottom Size ID Capacity Volume MD MD TBG 0 11166 5-1/2" 17# 4.892" 0.0232 bbl/ft 259 bbl LNR 11051 11807 9-5/8" 47# 8.681" 0.0732 bbl/ft 55 bbl IA 0 11051 9-5/8"47# x 5-1/2" 17# - 0.0438 bbl/ft 484 bbl Total TBG volume 259 bbl Total IA volume 484 bbl Wellbore Volume to Top Perf 271 bbl 3.2 Cement Requirements 1. Cement Volume—Contingent on final liner set depth Volume Note 9-5/8" 47#LNR x 3-1/2" 9.3#scab 40bbI Volume from PBTD to TBG tail (11800'— liner annular fill up volume 11152') Total cement to pump 50bbl 25%excess 2. Cement Properties Ppg 15.8 ppg Glass G. Field blend to be +/-0.1 ppg of lab blend. Slurry Temp Between 80deg F and 110 degF API Fluid loss 50-100 ISO cc/30min Thickening Time 8 hrs Free Water 0 mL Compressive strength 2000psi at 24 hrs Batch mix 3. Cement Thickening Time Activity Time (hrs) Shearing time, quality control, PJSM 1 Cement displacement 1 Cement contamination 5 Safety 1 Minimum required thickening time 8 4. Cement Ramp Time Temp (deg F) Pressure 0:00 90 0 1:00 90 0 3:00 110 3000 4:00 125 4000 4:30 140 3000 5:30 150 3000 8:00 150 3000 Well:09-19 Version: 3 3 Operations Program • 4 Procedures Reference Documents • Well Entry SOP • Coiled Tubing 'Klondike' Overview RP • CTU Operations -Squeeze Cementing RP • CTU Operations—Cleanout Procedures RP • SLB and CH2 Klondike specific procedures • Reference MoC 10155 —Workover and WWP Operations — Continuous hole fill, but fluid level below surface. 4.1 Slickline — Drift. 1. Drift to XN Nip at 11,152' for No-Go seal sub to be installed in liner(OD—4.56"). 2. Drift and tag TD with sample bailer 4.2 Valve Shop 3. Set BPV. 4. Remove swab valve. Well:09-19 Version: 3 4 Operations Program i 4.3 MIRU Klondike and CTU Well Barriers Tubing MV, SSV Inner Annulus Tubing/packer, Production casing, IA casing valve 5. MIRU Klondike. 6. NU 7-1/16" BOPE to swab flange per attached BOP diagram. 7. Valve shop pull BPV. 8. Rig up CTU. 9. Function and pressure test BOPE per SWS Klondike BOP test procedure. • Pressure test rams to 4000psi, and annular to maximum anticipated surface pressure (MASP). 10. Rig up the remaining CT equipment and pressure test PCE against the top of the SSV. Well:09-19 Version:3 5 Operations Program • • 4.4 Schmoo-Be-Gone, Well Kill Well Barriers after CT RU OOH at surface In hole Tubing Primary: MV, SSV Primary: DFCVs, Lubricator, Stripper, Kill line check valve Secondary: BOPs Secondary: Inner reel valve, BOPs, Choke line HCR Inner Annulus Tubing/packer, Production casing, IA casing valve 11. MU MHA for running liner, GR/CCL, pressure sub, and 3.51" JSN. • Making up MHA for running liner, will minimize open hole time. • Running GR/CCL will give exact depths for cleanout. This will aide in determining liner lengths. • The 3.51" JSN will serve as a drift for the 3-1/2" liner. 12. RIH performing a Schmoo-be-Gone treatment on the TBG and production liner, may want to bullhead some SBG prior to RIH to ensure CT does not out run leading edge of SBG. Try to cleanout to 11,800' (see WSR 7/14/2006) but at least to 11,700' MD. • Slickline tagged 11,468'MD with a 3.50" Cent. and recovered a sample of schmoo on 8/15/16. • TBG— 11,164' at 80fpm = 140bbl x 1.2 = 168 bbl of SBG • Production liner — 11,800 — 11,164- = 636' at 20 fpm = 32bb1 x 1.2 = 38bbl of SBG 13. Pull up into TBG, wait 3hrs (per RP)and Bullhead —340bb1 1% KCI. Please note injectivity rate at 0.5, 1.0, and 2.0bpm. 14. Dry tag TD, and perform a fill cleanout as necessary. 15. While on bottom, perform a flow check. 16. Log GR/CCL from new PBTD to approximately 11,000' while POOH,jet XN to cleanup for landing liner, and flag CT around 100' above the XN Nipple 11,152'. 17. POOH pumping displacement,jet the XN nip at 11,152' to clean up for landing the liner. 18. Flow Check Well when at surface — assess losses and communicate plan to keep well dead. 19. Lay down injector and install slip bowl. • Or may be able to trolley injector/lubricator to back deck while loading liner. T-bar may be in the way. Well Barriers after laying down injector Tubing MV, SSV Inner Annulus Tubing/packer, Production casing, IA casing valve Well:09-19 Version: 3 6 Operations Program • i 4.5 Make Up Liner 20. Flow Check Well—assess losses and communicate plan to keep well dead 21. Make up 3-1/2" liner assembly, according to Northern Solutions and Baker specifications. Drift and tally all liner and completion components. Record ID's, OD's, lengths, and relevant fishing specs of all equipment. • Final liner length will be dependent upon the final cleanout depth. Try to run liner as deep as possible. • Confirm pressure/torque chart is on location for liner makeup. • Ensure stage cementing collar is installed in the "Open" position, and is oriented to close by shifting up. Well Barriers while MU liner Liner KWF, BOPs, Safety joint/TIW valve Inner Annulus Tubing/packer, Production casing, IA casing valve 22. After liner has been made up, hang liner off in 3-1/2" pipe/slip rams by closing the rams on the deployment joint. 23. Pick up injector and lubricator and make up liner running BHA as follows: • Baker External slip CTC for 2" coil • Baker Swivel • Baker Dual Back Pressure Valve • Rig—Landing Joint(as required) • Accelerator • Hydraulic jars • Baker Disconnect(3/4" ball) • Baker 4.0 Hydraulic GS Spear 2/3.00" Nose Seal Well:09-19 Version: 3 7 Operations Program • i 4.6 Deploy Liner 24. Position injector, strip over the liner and make up CT to the liner, and make up QTS. • Liner weight is approximately 6,030 lbs in air. • Liner weight is approximately 5,260 lbs in 1%KCI. • Liner weight is approximately 4,575 lbs in 15.8ppg cement. Well Barriers after CT make up QTS OOH at surface In hole Tubing Primary: KWF Primary: KWF Secondary: BOPs Secondary: BOPs Inner Annulus Tubing/packer, Production casing, IA casing valve 25. RIH at 60fpm getting good up/down weights. Note injectivity down CT backside prior to landing liner for comparison. Land Baker Deployment Sleeve on No-Go in XN Nipple at 11,152' MD. Prior to setting down liner, for weight checks note speed, keep same packoff pressure, pick up at least 100' to help prevent bringing liner back OOH. 26. Land Baker Deployment Sleeve at 50 fpm on No-Go in XN Nipple at 9,266' MD 27. Jar down to wedge No-go seal sub per Baker, attempt overpull to 13,000 lbs over previous pick up weight. 28. Pressure up down the CT backside to test seals in polished bore. Compare this to backside injectivity recorded prior to landing liner. 29. Establish circulation down CT and PU to release Hydraulic Spear. Pick up —50' and flag pipe. Note EOP depth. • This will put TOL at 11,547'. (Note circulation path will be bullheading into formation during release). 30. POOH. Well:09-19 Version:3 8 Operations Program • • 4.7 Cement Liner 31. Make up cement stinger BHA: NS Snap Latch Cement Stinger NS 2-1/8"Weight Bar- 1-1/2" MT NS 2.75" Centralizer- 1-1/2" MT Hydraulic disconnect(5/8" ball)- 1-1/2" MT Baker HB-3 Shifting Tool -(Set for Mechanical Up- Brass Pins)- 1-1/2" MT Baker 2.70-2.75 Centralizer- 1-1/2" MT-(Maximize flow by area) Hydraulic disconnect(3/4" ball)-1-1/2" MT Baker External CTC w/ 1-1/2" MT threads 32. Displace CT to diesel at surface prior to RIH, then RIH and circulate or bullhead the well to diesel. 33. RIH watching for flag indicating TOL with ORCA cementing valve stinger assembly. Get good up and down weights about 100' above ORCA valve. While stopped, establish circulation rates at 0.5 and 1 BPM and note pressures. Circulate around 15bbl of gel to fill the 3-1/2" scab liner. Shut down pumps. • The 15bbl of gel will serve as contaminate for the excess cement that may be circulated through stage cementing collar. 34. RIH at 30'/min tag ORCA valve and slack off 5000#, hold set down weight for remainder of cementing operation. 35. Pressure up to 2,500psi to rupture disk and regain circulation, indicating correct valve engagement cement circulation path. Note any circulation variances from previous baseline circulation. 36. Attempt to establish 1:1 returns up the CT backside. 37. Begin mixing cement. 38. Cement liner with 50bbl of 15.8ppg cement maintaining 1:1 returns(if possible) -If cement top reaches stage collar with cement still at nozzle, shut in CT backside and attempt to squeeze the rest of the cement away. If a squeeze is achieved, the squeeze pressure will need to be trapped on the backside for the remainder of the lob to prevent pushing the liner up hole (example: squeeze pressure is 1500psi, maintain 1500psi WHP for the remainder of job). If the well locks up while attempting squeeze, unstinq and lay in remaining cement while pulling up hole to shift stage collar closed • Worst case top of cement(no cement behind 3-1/2" liner) = 8,729' • May want to chase cement and fresh water spacer with gel followed by 1% KCI in the CT to assist in cleanout. Pump Schedule Spacer 5 bbl Freshwater Cement 50 bbl 15.8ppg Cement Cement volume may change depending on cleanout depth Cement 5 bbl Freshwater Displacement Contaminate -50 bbl PowerVis mixed in Contamination from WCTOC to Freshwater flag 10' above ORCA. 39. SD pumping down the CT. Unsting from cementing valve with -1bbl of cement left in the CT. Weight check to confirm unstung from ORCA cementing Valve and released from liner. Flag pipe -10' above ORCA cementing valve. Well:09-19 Version:3 9 Operations Program • . • • After unstinging from ORCA cementing valve, Do not pump any fluid until the stage cementing collar is closed, to avoid pushing cement away. 40. PUH and shift mechanical stage collar closed with HB-3. Watch weights carefully in case sleeve does not shift easily. 41. Continue to PUH to 8,729' (WCTOC), then begin RIH contaminating to flag. 42. POOH. 4.8 Cleanout 43. RIH with 2.50" - 2.70" JSN to -8,700' and make three passes (down, up, down) from WCTOC (8,729') to flag indicating bottom of liner. 44. At bottom, POOH at 80% making repeat passes across all jewelry, tree, and BOPE. 45. Freeze protect well with 60bbl of diesel or 50/50 Meth. 46. RDMO CTU and Klondike. 4.9 Valve Shop 47. Install swab valve. 4.10 Fullbore - WOC. PT. 48. WOC 3 days. Then pressure test TBG and 3-1/2" scab liner to 2000psi 4.11 Slickline - Drift. 49. Drift and tag TD with 20' 2.5" DMY guns. 4.12 Eline - Perforate 50. Log GR/CCL/SCMT from PBTD to 11,000'. 51. Perforate target injection zones per Perforating form in SOR. Well: 09-19 Version: 3 10 Operations Program • S 5 Current Wellbore Configuration W- MDGM 1 E /�/� SAFETY NOT :425NA(INGSAVERAGE126ppm WH I I HMO= 14. 09-19 WREN ON MI. WELL REQUIRES A SSSV WHEN ON ACTUATOR= AX E 50I1 V�R ML 0103.ELEV- 5T DV.LLD/- KOP- 3122' -- - ---- I 2216' I-,5-1R'CAmBAL-0555VNP,;P=4.562' Abn Angla 1,:.,0. 0 110:13 (Mum RL)- 11343 muff,1Jr1= 1<1101r(IS 13 2.10'{SG 72X.N U0.O-12.347' - 2714' 1:16 iI 11045' I IS-112-aO15b#L ASSY I Minimum ID=4.45S"4211162' 11051' H9-efr x 5-1,2'OAKETtIIT-1 PI;R.D-8.00' I 6.112"OTIS XN NIPPLE ' I 11152' I 5-112'OTIS XN NP,D-4A55• —I 11164' H5 112'BAKERS'CAROLIT SUB I 15 112'TSG PC,174,N 62,.0232 bpf,0-4.633 j- 1115r I---71------- -- / I tiler H ry/IiNt rn I I I 111'53' I I tLkEU I I Luustu 041X!611 PCPCORRTITN SUNIRRY Ill I1-LOU:ki1-M on 1221!11)/t ANSI FATTDPPFRP 49.@ 11:!94' I me:14eter lo Hothmb n t5!for III6tor,M pert data 512E SPF HTER'AL 0prV5qz GATE 1 3-348' 0 11x"34-1135) 0 05,25 O9 1 3.110" 4 11'337-11346 S 0245861.1 31,1!' 4 MSG 11393 S 024)6.128 2-1.11T 4 11414-11454 S 024)6128 I .3,31R• F 114Fi!,-11!41, C) 04411A44 i 3-1x8` 4 11t28-11Gu S U2Cd(458 3 SB` 6 11532 11542 0 10122196 I 3 315* 1 11576 11656 0 03125192 3 343' 4 11621 11638 0 07118190 lam H 11607' I 1/44!!14!1 f+fi+*•f4fffifiitf4 I p ShR'C:Y:.AN 1s•R1 RTC;Irl-R Mit' 11996' 1f1•14fff 441414)1% ,f f.1.1.to.f.4 f., Yif+fF/lfk4 444 444 Ito hi 11934. I &&&:4r/A4i kV IIATF RP/ITY COIN41!lTlt PAW RFV ITV COMAvFNITS FR111117Fnnv INT 12125(77 Op(iN#L COMPLETION 64(99116 A1) WITS t7 FA.N LIP FFRTN I VVR I 09-19 62101429 LAST W081(OVER PENN N):'1770400 09.12.2121 IINTAK * CIK)tii AIINo: 60-029-202.60-02 0641109 MV/71.11 ADPCRT)051251[9] Sec.1..TICN.R1:T.,524 ISL a 251:r NUL 09111111 um"lAnnpn IS.S,SV SAFTTV NOTE 0111 V19 T61Y,1142 A0DFD ICS SAFFIY NOW i EP apbratian(Alas km) Well:09-19 Version: 3 11 Operations Program • 0 6 Planned Wellbore Configuration TREE- RO GEN 1 SAFETY NOTES:1MS NFA0lNGS AVERAGE 126 ppm , l.HEA 1FMC 09-19 I WHEN ON MI. WELL REQUIRES ASSW/WHEN ON ACTUATOR- AXELSON ML OKT3.ELEV- 54 BF.ELLV= KOP= 3139 Max Angle-.... 52• 10230 2215' 5-1/r GAM BAL-0 SSSV rip,D=4.562' Datum M3= 1130E Datum TVD= MO'SS I 13-3/8'CSG,724.r480,U-12.34T I--I 2714' I•-4 i11049' 5-1/2 BOT SEAL ASSY Minimum ID=4A66"@ 11162' 1 11061• H9-5/6 -1 w x 5-1,7"BAKERFBvt 13=boo I 6-1/2"OTIS XN NIPPLE ■ — I 11152' 1-15-1/2"011S XN NP.D=4 455'J 4• s2• 11161BAKERSI£AROUT SW I 15-1/T T G-PC.IT4.N-80..0232 bot.ID=4.8921-1-1 11166' -s-1 rr 11 PUNA TAO I 11156' I—IEL O 1T LOGGED 04/04/88 'PERFORATION SOM4A RY Mg LOG:L9*J;on 12/2111911 Cemented 3-1/2"scab liner. ANGLE Al TOWI1 :49,es 11334' Perforated target injection zones. Note:Neter b Poducllon DB tot Nslorfcal pert dais SIZE SPF SOCRVAL Opn/Sqc DATEI I 3-3/8' 6 11334.11350 ; 0 05/25/09 3-1/8• 4 11337-11346 " S 02/05/88 in 3-1/0' 4 1130G-11306 0 02)05/00 3-1/8' 4 11414-11454 S 02/05/88 3-318' 6 11465-11505 0 04/01/94 3-118' 4 11528-11532 S 02/05/88 I 1 3-3/8' 6 11532-11542 0 10/22/96 I 3-3/8' 1 11576-11606 0 03/25/90 3-318' 4 11621-11638 0 07/18/90 pi CM 444444114 444444.444446444444• 9 5/8'CSG,474,N-80 BTC,D= 119066.681' ' 144414441444444444444 I H � mI.f.eccat 1444444444444444444441 ITD I-{ 11934• j ta4t4M444s4teV Well:09-19 Version:3 12 Operations Program • S 7 09-19 Tree / BOP diagram EllPlatform Floor Riser to platform floor !! Annular I 1 1 NN f Hi .■ Iii�� mt IUli i Blind/Shear Hydraulically Actuated Valve 'ImM'� ;0' In' illI, i ,iiCoil Pipe/Slip • r insmo • Choke Line II!' © 'I,IlliRs%AII [''°°" 11:7'�rill!'Z'��>,0Z11 ,/ Kill Line X101 NOB� I: .Iuuuil ) Liner Pipe/Slip so Ii II. �I Il Coil Pipe/Slip t -,,Wm 7 x 7 Spool as needed Co'l.e° Flow Cross Op SSV /Iu fio��i Master Valve 44116.0 THA 'ill...i .a I ... • J1111.: y 11+ � • I Tubing Head I Ground Level Well:09-19 Version: 3 13 Operations Program • • Summary of Proposed Work BP Exploration Alaska (BPXA) 09-19 Scab Liner PTD — 1770400 API No. —50-029-20260-00 Engineers: Eric Dickerman (907) 564-4277 Dave Wages (907) 564-5669 Bernhard Stechauner (907) 564-4594 Well History: 09-19 is currently online injecting about 17,000-19,000 BWPD with wellhead pressures of about 1,450psi. Most of the injection going into zone 3. Injection into Zone 3 in this well supports a minimal amount of oil. On an IPROF in July 2006, the spinner data indicated that almost all of the injection was going into Zone 3 perfs at 11,366 — 11,386', with only the temperature profile indicating that some fluid injection below 11,386'. The well has a history of Schmoo, however coiled tubing schmoo-be-gone's have been able to clean out to 11,800' in the past. The secondary IC packoff seals have failed indicated by a failed PPPOT-IC and a subsequent LPE performed in April 2014. Objective: Shut off Zone 3 thief injection by running and cementing a scab liner. Reperforate - target injection zones. The procedure includes the following steps: 1 . Slickline Drift to TD. 2. Valve Shop Remove swab valve, leaving flow cross, and two master valves. Coiled 3 Tubing / Wellwork Schmoo-B-Gone cleanout. Make up 3-1/2" scab liner. Deploy liner. Platform Cement liner. Cleanout cement. 4. Valve Shop Install swab valve. 5. Fullbore WOC 3 days. Pressure test TBG and scab liner. 6. Slickline Drift and tag TD. 7. Eline Perforate target injection zones. r„ciei— cisme `Se,-,4d Io • • Current Wellbore Configuration I 1RCL- 18C 50J I SAFETY NOM:pas READINGS AV ERAC£125 ppm %RHIIb51T= tell: 09-19 -- - WREN ON MI. WELLREQ GUAESASSSVWHEN ON ACTUATOR= AXEL5CNj KL jIT.P w 5i39 yyI Max Anglo- 5J•421W:i3S rif 22'16' —lv-1R"CAM BAL-D 555/r F iQ=4.562'I Q�1un11D- 113x5. Da1lanivr m691PSS{ 1?166,C 72:0.N iti} U-i2-347' 37'14' 11041r I la-V2-601*CALAs5Y I II Minim u m ID=4.486"6)11162` 1 y11061' —19-s1s•x 5-1.'r oA1012113-I PM 13-8.00- I 16-1J2"(TIB XN NIPPLE • I 1115T I5-1112-rms)(54 NP.13-4A55- ,I 11184' I-5 5f2'6AKERSIEAFJTSLL I 1 5 112'13G PC,i74.N aC,.0232 tsr1 17-4.632- -I 11168' I - l t I 17158 Fie-V,.11-4414C4 1.d0 I 11153' 1 Itutu l I Ltx;rsto tt4t04,65 I FIna-+RATIur,slAIMaaY I 1±1-LOU:NI L5 on 121211161/1 ANtI FAT TCPPF F`49'@ 11:114' We:h70tar lo Rod6cll}n 1,18 for historical pert data 512E SPF NTEFE'A1 Op ru5i32. DATE 5-S'8' 8 11534-11350 0 CrEt,5109 3-116' 4 11537'-11346 S 6210566 3116' 4 11u4E 11360 S 62,51.5138 3-1.13' 4 11414-11455 S 024.35138 :k.3JR^ 6 1141it,-11!vlka n (14111144 3-1)6` I 11`C18-11532 5 112/036138 3 313" 6 11532 11542 0 1i0P12A9i6 3 318" 1 11576 11696 0 04/25/50 3 Y 4 11621 11636 0 6711849 1P15—T-16 1— 11807 I 4M*4.1k4i*t 4444*44444+ 0,04...4,401.4I A 51-3 r-5a:47Y r€41 run.k5-R 661' H 11986' ri##+*1*4�4 4,4 4+4� I ,},4,4*,*,40,+,4,4 1i4444r4.0 444.4441 1JATF RR(11Y`` comma's j 17ATF RFV RY c7 R.; 1 IRtfClFRAY t*1T 12125(77 1OIIGIII4L COMPLETION 311X7116 an AILS t7 FAN UPEMTAJ IFS! WR I• 0949 4?109f&8 MAST WORKOVER FERE No:'17701400 09122411 144SIAI0ICYJN141116.1145 I ' AMNO: :50-t129-2026(1.00 16101,09 h F1U- AUER-05'25JL9) i1 I Get:.1,DON,MEC,524'FSL 3 25[P rum_ 97/11111 miss)Imam SS.SV S/,F1-lY NITF 51/11117 ThINLI 7I.AEIDFD I GS SAFFIY NOTF BP Exploration(Alaska) o • • Planned Wellbore Configuration TREE= RCGEN 1 , SAFETY— WELLHEADRoC NOTES!142S READINGS AVERAGE 126 ppm O V-1 9 i WHEN ON ML WELL REQUIRES A USW WHEN ON = ACTUATOR- AXIS SON OIB.B.EV= 54 — 8F.BkV= KOP= 3139' PAN Angle= —533-6-10236; 2215 JH 5-12"CAM 3AL-0 SSSV NP.D=4.562'I finnan MD= 11305' Datum WO= 8800'SS 13-3/8-CSG.720.1+80,D=12.34T j--+ 2714'J--4 L 11049" 5-!12 BOT SEAL ASSY Minimum ID=4.466" 11162" l^3 to yam- 1 11061• 1--I9-5/6"X 5-1,?'BAKER FB-1 RAR.ID=6.00- 8-1/'2"0118 XN NIPPLE 111'2' f5-1l2-0118 XN NP.D=4.455' 11164' 5112-BARER SFEARPoOUT SLB 5-1/2"TF3G-PC.170.N-80..0232 bor.D=4.892- --f 11186 11166' --{±A-1rr 11 Ran rn1 1118S7-1Ha c TT LOGGED 04/04188 PERFORATION SLIANNIA7 REF LOG_efts on 121211197" Cemented 3-1/T scab liner. ANGLE AI TOPFERF. 49°@ 11334 Perforated target injection zones. Noce:%far b Production OB or historical port data SIZE SF'F{ INTERVAL Opn/Sqz PATE I I 3-3/r 1 6 1 11334-11350 0 05/25/09 3-1/8-i' 4 i 11337-11346 S 02/05/68 3-110' 4 4 ; 11300-11300 G 0246/00 3-l/8" 4 i 11414-11454 S 02/0508 3378'f 6 1 11465-11505 0 04/01/94 3-1/8' 4 11528 11530 S 02/05/88 ( I 3318'' 6 11532 11542 0 1W22/96 '3-3/8"( 1 11576 11606 0 03/25/90 3-3/8.1 4 i 11621 11638 0 07/18/90 11667 1114.1/111 /11s/A/4/A/1(•`////A, �545f8' • ASG.470,N-80 BTC,D- 6 681' 111106' 111//111/111114/1/11 .1.1.1.1.1.1.1,1.1,►, 111 .1111:/11111401/11 TD-1-F-11934._ ,11.0.141.0.144,11,1,4 • • Loepp, Victoria T (DOA) From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Monday, September 12, 2016 9:02 AM To: Loepp,Victoria T(DOA) Cc: Dickerman, Eric Subject: RE:09-19 Procedure for Sundry Victoria, Just wanted to also mention that we are hoping to execute the work by the end of the month, so please expedite. Thanks, Joe From: Lastufka, Joseph N Sent: Monday, September 12, 2016 8:22 AM To: Victoria.Loepp@alaska.gov Cc: Dickerman, Eric Subject: FW: 09-19 Procedure for Sundry Victoria, Please look over the attachment and let us know if you have any questions or need additional information. Thanks, Joe From: Dickerman, Eric Sent: Monday, September 12, 2016 8:10 AM To: Lastufka, Joseph N Subject: 09-19 Procedure for Sundry Hey Joe,attached is a copy of the wellwork procedure for 09-19 scab liner. Can you please forward to the AOGCC as they requested it as part of the sundry approval. I will stop by today and see if you have any questions. Thank you, Eric Dickerman 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIAN APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other Scab Liner 0 • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 177-040 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic 0 Service 0. 6. API Num. r::' 50-029-20260-00 00 • 7, If perforating: 8. Well - d Numat F e F I V F What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 P=, 0• < 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028327 • PRUDHOE BAY,PRUDH e %`L • 11. PRESENT WELL CONDITION SUMMARY f Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk18AD7C I 11934 - 9245 • 11862 9197 Casing Length Size MD 'h% Burst Collapse Structural Conductor 75 20"94#H-40 33-108 .` "33-108 1530 520 Surface 2715 13-3/8"72#N-80 32-2747 if 32-2747 4930 2670 Intermediate Production See Attachment See Attachment See Attachiny See Attachment See Attachment See Attachment Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: / Tubing Grade: Tubing MD(ft): See Attachment See Attachment 5-1 "1,#L-80 L-80 29-11166 Packers and SSSV Type: 5-1/2"Baker FB-1 Packer ' Packers and SSSV MD(ft)and TVD(ft): 11054, 8663 No SSSV Installed dr No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore en. 0 13.Well Class after proposed work: Detailed Operations Program 0 BO 4,),, 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: . GAS 0 WAG 0 • GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the pr. edure approved herein will not Contact Stechauner,Bernhard be deviated from without prior written approval. Email Bernhard.Stechauner@bp.com Printed Name Stechauner,Bernhard Title FS2 Lead PE Ai Signature �` Q _ ►/ �► Phone +1 907 564 4594 Date 7//I/f {f or `)Csn Y. 1 COMMISSION USE ONLY Conditions of approval:Notify Commissio so that a representative may witness Sundry Numb/eer::Q- Plug Integrity 0 BO•Test 0 Mechanical Integrity Test Location Clearance 0 ` `^ �� Other: SCA Post Initial Injection MIT Req'd Yes No ❑ / NNED V DJ Spacing Exception Require.. Yes 0 No Subsequent Form Required: f1.9 4.0 4. APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: ORIGINAL RBDMSI, `' AUG 152016 l Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate L `7. /6"- /G • . m ,o000000CI co N N- 00 O 00 IT Cfl O Ln O O N N to 'Cr LO 'Cr LO CO U u) Oo000000 CO CO LU I- LO N- In 'Cr LU 6) c- 00 - CO c m V CO CO 00 CO CO N O N- CO CO O t N- N- O CO CO N- CO CO N- CO N N- N N- 00 CO O CO • i H CO CO CO N "cf N- N- O O) M M M M CO I� CO N N- CO CO CO N N CO 00 c ,r N N O) • N S r r N- C.) Q I I I I i +�+ o) QCO N N �- CO M 6) C)0 MMMMf � � N M CO Cl. O OO CO O CO cc 00 Z Q Z ; Z ,N N N V Cn CO N-RI _ 4t N- U oc71- � O CO a)Ln r V O) N C N- N- M V N- M d N C) �- O J Z Z Z Z Z 0)0 00000 CHLi] F- I- HHH 'N 0 0 0 0 0 0 0 O 0 w 0 0 0 0 0 Z Z c 0 0 0 0 0 m UCf) CI- ddwdH • • a, N N m N- CO N Lo O) IC) N M M N CA CO CO O V' Lo (N M 0 p_ V' O N (fl N to M O M a to Ln N- N LC) I- CO N CO CO CO CO CO CO CO CO CO 0 O I- a O F' I,- co 1.0 a0 •H Lt) co M « M N V' O I- O Co co COin CO CO co CO 0) 0) 0) O) O > 0 CO CO CO CO CO CO CO CO 0) 0 w 0 C w 0 0 Z W W a 0 w 0 HJ w g g Y 0 0 CO 0 0 W Y Y H I� CO O CO Lo t0 N N CO CO - J U U W w W CO V LC) CO to Cb O M V' O M J J J a s (n w QM M M M V' to Ln Lc) (O CO U2220 -1 -1 :1011_U U_ J W W 0 Z 0 G) rn Z Z Z 0 0 J 0 J co = a w a 2 O O 0 W eH W W W CL H H a J a 2 2 2 0 to to Cn (n (n r QCD 0 12 = t I� CO CO V 10 LC) CO N CO i CO CO V' CO c- CO CO (N CO N QM Q CO co M CO') V' V' to to to O te13- s- 0 L0 ac_n Y 0 0 to 2 2 2 O c) u~) can cJn can a) 0.. O .2 0 c LL LL LL LL N LL LL N LL LL LL (10- a- 0- 0100- 0_ 00- 0_ a Q < < < WCCCCu) < < 0 a, a m H 0000000 coCDrnrn 0 0 COC 0000 ) ) °) � rnrn w z 0) 0) rn O N N N N Z a LLI LO t) L) O N N LO 00 0 W 0 N a N N N N N V- cr 0 0 (�\I Z a W C) OW w u_ w Oa LO LC) LC) M I` < 0 0 W J J J 0 tY a a s a. co 7_ tai cn a cc at E m 0) a) 0) 0) o) 0) a) a) 0) a) rn ( LL a w 0 LL N CY LL 0 0 00 0 0 a) 0) OCA CA CO a a a C) J 0 0 w a 0 0 0 O 0 000000 a s CCl a) LL LL Co (/) a • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V20,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: 09-19 Well Type: Water Injection Well API Number: 50-029-20260-00 Well Activity Conventional 3 Classification: Activity Description: WSO Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Profile Modification Estimated Cost, $K: AWGRS Job Scope: SCAB LINER Other regulatory requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Bernhard Stechauner Contact numbers: (907) 564-4594 (907)360-7485 Well Intervention Engineer: Eric Dickerman Contact numbers: (907) 564-4306 (307)250-4012 Lead Engineer: Bernhard Stechauner Contact numbers: (907) 564-4594 (907)360-7485 Date Created: June 22, 2016 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate FTP or Injectior Date (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Pressure Cut(%) (Mscf/Day) (psi) 4/7/2016 13,049 1,277 Current Status: Operable Flowing Inclination>70°at Depth(ft) N/A Recent H2S (date, Maximum Deviation(Angle and 52° ppm) 10/27/1982 5 ppm Depth) 10,238' MD — Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 9° 4,925' MD Reservoir pressure(date, 10/30/2005 3,400psi Minimum ID and Depth psig) P 4.455" 11,152' MD Reservoir Temp, F 152° F Shut-in Wellhead Pressure 1,900 psi Known mech. integrity Likely failure of secondary wellhead seals. MIT-OA failure with tiny leak rate. problems(specifics) Last downhole operation (date, operation) 9/8/2015 Gyro Survey. Log from 11,450' MD to surface Most recent TD tag (date,depth, toolstring OD) 9/1/2015 11,513' MD 20'x2.5" Dummy Gun. Tagged thick schmoo Surface Kit Fit-for-Service? YES If No,Why? Comments,well history, Well currently online with most injection going into zone 3. Injection into zone 3 in this well supports background information, almost no oil, and does not do much good for production. etc: The objective of this job is to run a scab liner and cement it. Zone 2 would be re-perforated to keep Zone 3 be shut off and force injection into Z2. • Well Intervention Details Suspected Well Problem: Zone 3 Thief injection Specific Intervention or Well Objectives: 1 Shut off Zone 3 that is taking—90%of injection. 2 Reperf target injection zones. 3 Key risks,critical issues: Mitigation plan: 1 Schmoo at 11,500' pump SBG and cleanout to target cleanout depth 2 3 Summary Service Line Activity Step# 1 S Drift. 2 V Set BPV and blanking plug. 3 C/WWP Schmoo-be-Gone. Make up liner. Deploy liner. Cement liner. 4 V A/CT-pull blanking plug and BPV. 5 F WOC 3 days. Pressure test TBG and liner. 6 E Jewelry log. Be-perf. Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 See following Word document for detailed procedure. 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: Expected Production Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • • 0 Teclilo Injector MinilO9 Last!PROF 7/20/2006 g Prosect PBU EWE Well: 09-19 Author Laura J Larson State 1 700 Cate 44 2016 . +..an 64 X reuse sPoo 7i►$97#1241744#4.40$97#1241744#4.40 .n 4f Co .r,tlu frr _.-. f row4m.41.-".S ♦SKIMS Com mem#20#461/4464614641600 $u PnraN:+d:r, s..n•- tt#34 I.anrahik 4641# Siam Sum Mai ‘MX/MFT 4,44644.7S3441 Operas YX Corm-4 IMMA ,C �� 4tIS„4R77/ ht , 1 it ! PE Notes "#� ttAlitial atom1 Y, CAtt >,.` .. PHIT a 11 t MS DtP rvoss sw v0R `X C) . n 11,.. � k,,. r,i... ......r.. .•x.4fs.rn. « Nr.�= rr ;/4 r 4:t ' MOOIIII Vit. i Stat "'1" lit r ___.._.� .....__. _...._.,.__. _ ' 4 90+96 injection II # #ttSO going into ',5w . t 11366'-113$6` since 1990 OIIII .'r i Ir s.•• X4444,, 34II -�> V Re-Perforate: MSO 4,+440{ 11,576-11,606'MD 11,621-11,638'MD sox IIII IP ; ''''''''—:1 1 a . .. . 40 laaa t.� ONO lit ) 11! .........:,,, „„,,,0„..,,,.. .,..„ ..: ::*'17 ,,. o y sss t ., _,_ _._. _ ___ __— — . . s M "TREE= FMC GEN 1 ! SA 11 hrO ES:H2S READINGS AVERAGE 125 ppm WELLHEAD= FMC 09-19 WHEN ON MI. WELL REQUIRES A SSSV WHEN ON ACTUATOR=� AXELSON MI OKB.ELEV= -54_ BF.ELEV KOP= 3139' Max Angle= 52'©10238 [1.___i__ 2215' —j5-1/2"CAM BAL-O SSSV NP,ID=4.562" Datum M)= 11308' Datum TVD= 8800'SS 13-3/8"CSG,72#,N-80,D=12.347" H 2714' 11049' H5-1/2"BOT SEAL ASSY Minimum ID = 4"455" a@ 11152' :"."i411051• —19-5/9"X 5-1/2"BAKER FB-1 RCR,D=6.00" 5-1/2" OTIS XN NIPPLE 11152' —5-1/2"OTIS XN NP,D=4.455" 11164' H 5-1/2'BAKER SHEA ROUT SUB 5-1/2"TBG-PC,17#,N-80,.0232 bpf,D=4.892" H 11166' 11166' —{5-1/2"TUBING TAIL 11155' --i ELMO 7T LOGGED 04/04/88 FG FORAT1ON SUMMARY REF LOG:BI-CS on 12/21/1977 ANGLE AT TOP PERF: 49"@I 11334' Nate:Refer to Production DB for historical perf data I SIZE SPF INTERVAL OpntSgz DATE 3-3/8" 6 11334-11350 0 05/25/09 -' 3-1/8' 4 11337-11346 S 02/05/88 3-1/8" 4 11366-11386 S 02/05/88 — 3-1/8" 4 11414-11454 S 02/05/88 I 3-3/8' 6 11465-11505 0 04/01/94 3-1/8' 4 11528-11532 S 02/05/88 3-3/8" 6 11532-11542 0 10/22/96 3-3/8" 1 11576-11606 0 03/25/90 3-3/8" 4 11621-11638 0 07/18/90El PBTO —j 11807' •1V•1.1.1.1.1.1.1•i 11111111111/111111111 9-5/8"CSG,47#,N-80 BTC,D=8.681" H 11905'_J ►1111111111111111111.' 111111111111111111111 TD H 11934' �1 s.s.s.e.s.s.s.a�t DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDNOE BAY MT 12128177 ORIGINAL COMPLETION 04/22/16 JMD WBS CLEAN UPPERTALLB WELL 09-19 02/09/88 LAST WORKOV ER FERMI-No: '1770400 09/22/01 RWKAK CORRECTIONS API No: 50-029-20260-00 06/01/09 MV/TLH ADPERF(05/25/09) Sec.1,110N R15E 524'FSL&250'FWL 02/11/11 MB/JM) ADDED SSSV SAFETY NOTE 01/11/12 TMAYJM)ADDED HRS SAFELY NOTE BP Exploration(Alaska) • • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday,August 10,2016 9:02 AM To: Stechauner, Bernhard (Bernhard.Stechauner@bp.com) Subject: RE: PBU 09-19(PTD 177-040, Sundry 316-365)Scab Liner I have not heard back on this. Please also provide a BOP schematic, MPSP and BOP test pressure. From: Loepp, Victoria T(DOA) Sent:Tuesday,July 26, 2016 9:53 AM To: Stechauner, Bernhard (Bernhard.Stechaunerftbo.com) Subject: PBU 09-19(PTD 177-040, Sundry 316-365) Scab Liner Bernhard, Please provide a post-work schematic. The setting depths for the liner are not clear. Please provide as well as the detailed word procedure. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(..alaska.gov 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 Victoria Loepp at(907)793-1247 or Victoria.Loepo@alaska.gov 1 Carlisle, Samantha J (DOA) From: Loepp,Victoria T (DOA) Sent: Monday, August 15, 2016 11:07 AM To: Carlisle, Samantha J (DOA) Subject: FW: PBU 07-04A(PTD 192-067); PBU 09-19(PTD 177-040) Please handle. From: Wages, David [mailto:David.Wages@bp.com] Sent: Monday, August 15, 2016 8:45 AM To: Loepp, Victoria T(DOA) Subject: RE: PBU 07-04A(PTD 192-067); PBU 09-19(PTD 177-040) Sounds good to me! Thanks, David Wages o. 907.564.5669 c. 713.380.9836 W I E-AK From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, August 11, 2016 10:27 AM To: Wages, David Subject: PBU 07-04A(PTD 192-067); PBU 09-19(PTD 177-040) Dave, Please confirm withdrawal of the following sundries since replacement sundries were submitted: PBU 09-19 (PTD 177-040,Sundry 316-365)Scab Liner PBU 07-04(PTD 192-067, Sundry 316-363) Scab Liner Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage;AK 99501 Work: (907)793-1247 Victoria.Loepp(cilalaska.ciov 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 Victoria Loepp at(907)793-1247 or Victoria.Loedp@alaska.dov 1 k11- 134 O Gyrodata Incorporated • • -G.5 23000 Northwest Lake Dr. çJ3ft'O/cIAta Houston, Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 DATA LOGGED I nyi2O15 M. K.BENDER RECEIVED OCT 12 2015 AOGCC SCANNED SEP 1 41CiE SURVEY REPORT BP Exploration Drill Site 09 #09-19 Wellhead Prudhoe Bay, North Slope Borough, AK AK0915GCM170 7 September 2015 RIGHT PLACE FIRST TIME (6- www.gyrodata.com Gyrodata Incorporated • • 23000 Northwest Lake Dr. gyro/data Houston,Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 October 8, 2015 State of Alaska -AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: Drill Site: 09, Well # 09-19 Prudhoe Bay, Alaska Enclosed, please find one (1) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. 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Nt N i �� , I ' � ca, s I „:"'Z 01 IO ! � L 1 ;p 1 - O LAO i C • i 1-i• a'" o ' W p U 1 1 1 i i I 1 ' I I i 1 ' 1 1 1 1 ' 1 I 1 I 1 1 1 1 ilii 1 1 1 1 i 1 i 1 ' I 1 I-1 -'O m - I I I I -1 1 I I I 01 00 N IO U1 d' M N +-I 0 (3400T/6ap) Anlian3S s isoa • • Survey QC - RGS-CT Specification Sheet g • • • n` SURVEY QUALITY CONTROL-SPECIFICATION DATA PRE-]OB CALIBRATION VERIFICATION CHECK(ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 64 270.49 249.65 0.00006185 0.52 63 270.49 249.97 0.00006193 0.81 62 224.54 461.58 0.00011542 -0.44 61 224.54 462.76 0.00011572 0.16 60 45.03 478.23 0.00011957 1.14 59 45.03 478.26 0.00011958 0.96 58 358.92 129.61 0.00003272 -1.37 57 358.92 133.70 0.00003375 -0.76 56 328.77 -124.86 -0.00003136 -1.02 55 328.77 -118.10 -0.00002967 -0.40 54 299.42 -63.17 -0,00001572 0.20 53 299.42 -62.58 -0.00001558 0.41 52 270.33 272.32 0.00006747 -0.01 51 270.33 278.25 0.00006894 0.56 50 239.08 491.22 0.00012228 -0.11 49 239.08 493.58 0.00012287 0.26 48 209.47 432.37 0.00010864 -0.42 47 209.47 431.87 0.00010851 -1.15 46 180.28 191.70 0.00004840 -0.34 45 180.28 202.44 0.00005111 0.01 44 148.67 -58.84 -0.00001478 1.62 43 148.67 -52.35 -0.00001315 0.80 42 119.30 37.50 0.00000934 2.64 41 119.30 35.89 0.00000893 2.52 40 89.62 356.08 0.00008823 1.72 39 89.62 363.90 0.00009018 1.93 38 59.40 549.50 0.00013680 1.12 37 59.40 553.65 0.00013783 1.44 36 28.77 432.08 0.00010859 -0.06 35 28.77 436.83 0.00010978 -0.20 34 358.02 127.39 0.00003216 -1.84 33 358.02 133.31 0.00003365 -2.38 32 269.95 279.72 0.00006930 0.69 31 269.95 287.69 0.00007128 -0.32 30 225.25 455.75 0.00011394 -7.04 29 225.25 458.11 0.00011453 -9.59 28 45.14 486.02 0.00012152 0.50 27 45.14 494.38 0.00012361 0.95 26 0.17 120.38 0.00003039 0.18 25 0.17 125.40 0.00003165 -0.23 24 329.49 -130.24 -0.00003272 0.23 23 329.49 -126.38 -0.00003175 1.89 22 298.38 -29.35 -0.00000730 2.48 21 298.38 -23.53 -0.00000586 2.82 20 270.55 305.04 0.00007558 1.25 19 270.55 320.90 0.00007952 2.25 18 241.59 503.14 0.00012517 0.02 17 241.59 512.84 0.00012759 -0.42 16 209.86 430.27 0.00010810 -1.51 15 209.86 436.47 0.00010966 -0.93 14 180.74 173.55 0.00004381 1.18 13 180.73 178.82 0.00004515 0.22 12 150.02 -36.14 -0.00000908 4.22 11 150.02 -27.07 -0.00000680 4.56 10 120.33 79.09 0.00001970 5.57 9 120.33 78.72 0.00001960 5.14 8 90.49 431.56 0.00010696 5.01 7 90.49 439.08 0.00010882 4.18 6 59.63 599.84 0.00014933 1.30 5 59.63 606.90 0.00015109 0.93 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 1 of 6 AK0915GCM170 • • Survey QC - RGS-CT Specification Sheet gy . 0 - 4 30.43 436.03 0.00010953 -1.67 3 30.43 440.45 0.00011064 -1.24 2 358.58 87.24 0.00002202 -3.45 1 358.58 91.36 0.00002306 -2.72 MBO= -0.07 Gravity Error= 257.34 Scale Factor Uncertainty= 0.00006425 Rate Error= 0.39 POST-30B CALIBRATION VERIFICATION CHECK(ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 17021 270.65 214.31 0.00005309 -6.50 17020 270.65 217.05 0.00005377 -9.09 17019 226.31 437.54 0.00010934 -14.56 17018 226.31 432.28 0.00010803 -23.79 17017 45.31 462.37 0.00011559 1.76 17016 45.31 464.15 0.00011604 2.60 17015 0.16 126.57 0.00003195 -2.76 17014 0.16 129.39 0.00003266 -0.59 17013 330.53 -133.99 -0.00003367 -2.80 17012 330.53 -126.66 -0.00003183 -1.44 17011 299.48 -92.82 -0.00002310 -2.20 17010 299.48 -95.89 -0.00002386 -3.10 17009 270.33 223.35 0.00005533 -7.18 17008 270.33 233.66 0.00005789 -8.05 17007 240.60 443.84 0.00011043 -7.07 17006 240.60 448.34 0.00011155 -8.18 17005 210.15 405.69 0.00010191 -5.03 17004 210.15 403.36 0.00010132 -7.77 17003 181.02 167.90 0.00004239 0.83 17002 181.02 171.98 0.00004342 -2.73 17001 150.97 -69.54 -0.00001748 1.79 17000 150.97 -64.50 -0.00001621 2.63 16999 121.25 -16.49 -0.00000411 2.89 16998 121.25 -13.45 -0.00000335 2.91 16997 91.29 289.52 0.00007174 2.52 16996 91.29 293.50 0.00007272 2.22 16995 60.45 500.33 0.00012451 1.55 16994 60.45 510.69 0.00012709 2.45 16993 30.83 408.05 0.00010248 0.55 16992 30.82 415.65 0.00010439 0.50 16991 0.51 112.48 0.00002839 -3.50 16990 0.51 114.89 0.00002900 -0.38 16989 270.37 202.58 0.00005018 -1.63 16988 270.37 219.48 0.00005437 -0.37 16987 270.37 225.22 0.00005580 -2.43 16986 226.20 426.71 0.00010664 -12.22 16985 226.20 421.60 0.00010536 -14.13 16984 45.84 446.79 0.00011167 -0.74 16983 45.84 445.54 0.00011136 -1.29 16982 359.81 74.34 0.00001876 -1.29 16981 359.81 77.91 0.00001967 -2.15 16980 331.08 -176.98 -0.00004448 -0.22 16979 331.08 -169.33 -0.00004256 -0.37 16978 299.42 -104.63 -0.00002604 1.19 16977 299.42 -103.34 -0.00002572 -0.15 16976 270.95 215.92 0.00005349 -0.68 16975 270.95 219.79 0.00005445 -0.11 16974 241.16 433.17 0.00010776 -3.23 16973 241.16 435.26 0.00010828 -3.01 16972 210.61 380.76 0.00009563 -0.72 16971 210.61 387.24 0.00009726 -0.15 16970 181.12 119.56 0.00003018 2.66 16969 181.12 118.30 0.00002986 -0.46 SURV-Q167(OPS SUR-MA-003) 19`h Nov 03/Rev 15 Page 2 of 6 AK0915GCM170 • • , Survey QC - RGS-CT Specification Sheet gy • f # > 16968 149.52 -93.67 -0.00002354 1.87 16967 149.52 -94.25 -0.00002368 2.29 16966 122.18 -35.49 -0.00000884 3.16 16965 122.18 -33.26 -0.00000829 2.59 16964 91.78 273.68 0.00006781 3.85 16963 91.79 274.23 0.00006795 5.55 16962 63.40 498.10 0.00012386 1.10 16961 63.40 517.40 0.00012866 0.53 16960 30.93 387.56 0.00009733 -1.98 16959 30.93 386.02 0.00009694 0.51 16958 2.28 100.08 0.00002526 -2.06 16957 2.28 99.92 0.00002522 -2.70 MBO= -0.23 Gravity Error= 209.07 Scale Factor Uncertainty=0.00005219 Rate Error= -1.82 INITIALISATION Gyro Compass Reading/Station Raw Inclination Raw Azimuth Abs(ERMeae-ERTheo) 128 10.11 138.47 0.0223 129 10.11 138.48 0.0074 130 10.11 138.44 0.0098 131 10.11 138.37 0.0196 132 10.11 138.33 0.0093 133 10.11 138.40 0.0018 Average 10.11 138.42 0.0117 Tolerance on Average* 0.0824 Standard Deviation 0.00 0.06 0.0078 Tolerance on St.Dev.** 0.10 0.20 0.0387 Advanced Initialisation Azimuth Advanced Initialisation Standard Deviation Tolerance=TBA * Tolerance on Average of earth horizontal rate difference Is given by (1/Cos1)*J[(CosA*Sinl*0.1)2+0.0821 0/hr ** Tolerance on Standard Deviation of earth horizontal rate difference tolerance Is given by (1/COSI)*J[(CosA*SinI*0.1)2+(0.082/(n-1))] °/hr DRIFT TUNES Drift Tune Ending Ending Ending Ending Residual Gx Bias Residual Gy Bias Number Time Depth Inclination Azimuth Start End Start End 1 1218.52 4260.30 31.91 153.95 0.003 -0.002 -0.001 0.002 2 1235.43 5380.12 46.54 133.37 0.001 -0.000 -0.001 0.002 3 1264.09 6600.18 51.21 137.86 -0.002 0.002 0.000 0.001 4 1376.81 7895.12 48.54 137.89 -0.000 0.001 0.000 0.001 5 1535.88 9390.02 48.91 141.06 0.003 -0.002 0.000 0.001 6 1278.54 10650.18 52.07 146.60 0.000 -0.000 -0.000 0.001 7 966.71 11450.10 48.85 150.93 0.002 -0.001 0.001 -0.001 8 977.11 10650.82 52.09 146.49 -0.001 0.002 0.000 -0.000 9 1319.66 9390.58 49.09 141.31 0.001 0.000 0.001 -0.001 10 1489.68 7895.60 48.62 138.27 -0.002 0.004 0.001 -0.001 11 1320.79 6600.78 51.26 138.09 0.003 -0.002 0.000 0.000 12 1261.92 5380.68 46.74 133.52 0.002 -0.001 0.000 0.000 13 1255.26 4260.98 32.12 154.24 0.003 -0.002 0.000 0.000 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 3 of 6 AK0915GCM170 • • j. Survey QC - RGS-CT Specification Sheet •grrq . 14 1374.43 3130.80 10.21 138.66 -0.002 0.003 0.001 -0.000 Average 0.001 0.000 0.000 0.000 Standard Deviation 0.002 0.002 0.001 0.001 Tolerance for both the Average and the Standard Deviation 0.033°/hr 0.033°/hr 0.033°/hr 0.033°/hr INCLINATION AND AZIMUTH INRUN AND OUTRUN COMPARISON I Depth Corrected Inclination Corrected Azimuth I Inrun* I Outrun* I Difference Inrun* I Outrun * I Difference 100.00 0.12 0.19 -0.06 204.51 236.63 -32.13 200.00 0.24 0.20 0.04 171.44 213.71 -42.27 300.00 0.27 0.28 -0.02 201.16 217.93 -16.77 400.00 0.29 0.36 -0.08 232.30 219.61 12.69 500.00 0.47 0.50 -0.03 215.37 222.95 -7.58 600.00 0.54 0.57 -0.03 210.38 216.36 -5.98 700.00 0.56 0.56 0.00 222.56 218.84 3.72 800.00 0.50 0.46 0.04 217.51 219.18 -1.66 900.00 0.36 0.35 0.01 240.91 214.58 26.33 1000.00 0.20 0.20 0.00 273.55 221.89 51.67 1100.00 0.12 0.03 0.09 333.42 127.07 -153.65 1200.00 0.11 0.10 0.00 44.08 24.47 19.61 1300.00 0.12 0.12 0.01 146.07 275.71 -129.64 1400.00 0.14 0.15 -0.01 231.43 145.13 86.30 1500.00 •0.06 0.14 -0.08 240.82 214.29 26.52 1600.00 0.18 0.19 -0.01 150.04 155.24 -5.20 1700.00 0.17 0.15 0.02 . 206.50 199.55 6.94 1800.00 0.25 0.30 -0.05 145.63 165.53 -19.90 1900.00 0.50 0.48 0.03 101.87 100.58 1.28 2000.00 1.36 1.31 0.05 81.91 89.62 =7.71 2100.00 1.57 1.65 -0.08 68.03 67.25 0.78 2200.00 1.84 1.85 -0.01 53.54 53.42 0.12 2300.00 2.13 2.15 -0.02 55.29 60.24 -4.95 2400.00 2.15 2.15 -0.00 72.37 72.71 -0.34 2500.00 1.90 1.87 0.03 81.75 81.32 0.43 2600.00 1,60 1.63 -0.03 89.06 87.90 1.15 2700.00 1.50 1.50 0.00 92.46 85.88 6.59 2800.00 1.21 1.14 0.07 87.79 90.21 -2.42 2900.00 1.49 1.73 -0.24 114.20 113.10 1.10 3000.00 8.34 7.91 0.42 132.20 131.49 0.71 3100.00 9.64 9.70 -0.06 136.14 136.83 -0.69 3200.00 11.35 11.27 0.08 139.80 139.81 -0.01 3300.00 13.36 13.34 0.02 141.14 141.52 -0.38 3400.00 15.18 15.14 0.04 143.94 144.27 -0.33 3500.00 17.05 17.04 0.00 144.39 144.74 -0.35 3600.00 18.65 18.59 0.07 145.67 146.01 -0.34 3700.00 19.79 19.77 0.02 146.72 147.06 -0.34 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 4 of 6 AK0915GCM170 x • • Survey QC - RGS-CT Specification Sheet ,• - 3800.00 21.09 21.14 -0.05 148.29 148.72 -0.43 3900.00 23.39 23.34 0.06 149.04 149.32 -0.28 4000.00 25.39 25.36 0.02 150.33 150.66 -0.33 4100.00 27.83 27.79 0.04 151.74 152.03 -0.30 4200.00 30.15 30.14 0.02 153.37 153.67 -0.30 4300.00 32.80 32.80 0.00 154.28 154.59 -0.31 4400.00 34.73 34.71 0.02 155.70 156.00 -0.30 4500.00 36.80 36.76 0.03 156.53 156.84 -0.31 4600.00 40.08 40.04 0.04 156.63 156.91 -0.28 4700.00 42.27 42.24 0.03 157.17 157.47 -0.29 4800.00 44.42 44.39 0.03 157.96 158.24 -0.27 4900.00 44.56 44.53 0.03 156.16 156.43 -0.27 5000.00 42.15 42.17 -0.02 155.52 155.76 -0.24 5100.00 44.33 44.29 0.04 150.58 150.89 -0.31 5200.00 45.71 45.67 0.04 144.34 144.64 -0.30 5300.00 47.88 47.85 0.03 138.99 139.25 -0.25 5400.00 46.85 46.82 0.03 133.15 133.48 -0.33 5500.00 47.26 47.24 0.01 133.28 133.61 -0.33 5600.00 47.88 47.85 0.03 133.52 133.84 -0.32 5700.00 48.22 48.19 0.04 133.65 133.98 -0.33 5800.00 48.71 48.67 0.04 133.96 134.28 -0.32 5900.00 49.39 49.36 0.03 134.30 134.64 -0.34 6000.00 49.65 49.62 0.03 134.73 135.05 -0.32 6100.00 49.01 48.99 0.02 135.34 135.65 -0.32 6200.00 49.30 49.27 0.02 135.79 136.09 -0.30 6300.00 49.85 49.84 0.02 136.57 136.88 -0.31 6400.00 49.72 49.70 0.02 136.92 137.22 -0.30 6500.00 50.89 50.87 0.02 137.35 137.63 -0.28 6600.00 51.28 51.23 0.06 137.86 138.15 -0.29 6700.00 51.47 51.42 0.04 137.99 138.27 -0.27 6800.00 51.05 51.02 0.04 138.18 138.43 -0.25 6900.00 50.74 50.69 0.05 138.33 138.57 -0.24 7000.00 50.34 50.34 -0.00 138.05 138.27 -0.22 7100.00 50.09 50.04 0.05 138.12 138.32 -0.20 7200.00 50.07 50.12 -0.04 138.10 138.33 -0.24 7300.00 49.77 49.78 -0.01 138.24 138.47 -0.23 7400.00 49.58 49.60 -0.02 138.47 138.70 -0.23 7500.00 49.38 49.37 0.01 138.17 138.37 -0.21 7600.00 49.13 49.12 0.01 138.04 138.22 -0.18 7700.00 49.04 49.04 -0.00 138.24 138.40 -0.16 7800.00 48.78 48.79 -0.01 138.05 138.23 -0.18 7900.00 48.62 48.64 -0.01 138.00 138.16 -0.16 8000.00 49.39 49.38 0.01 137.85 138.04 -0.19 8100.00 49.53 49.53 0.00 137.89 138.06 -0.17 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 5 of 6 AK0915GCM170 r S Survey QC - RGS-CT Specification Sheet gr yra • * 8200.00 49.91 49.87 0.04 137.91 138.12 -0.21 8300.00 50.38 50.33 0.04 137.95 138.08 -0.14 8400.00 50.93 50.87 0.06 138.43 138.55 -0.12 8500.00 51.19 51.15 0.04 138.02 138.20 -0.18 8600.00 50.67 50.64 0.04 137.64 137.79 -0.15 8700.00 50.54 50.52 0.02 138.08 138.12 -0.04 8800.00 50.48 50.45 0.02 138.56 138.63 -0.07 8900.00 50.34 50.33 0.00 138.14 138.26 -0.12 9000.00 49.98 50.00 -0.02 138.69 138.73 -0.05 9100.00 49.85 49.82 0.03 139.64 139.80 -0.16 9200.00 , 49.40 49.36 0.04 139.65 139.80 -0.15 9300.00 48.72 48.74 -0.02 140.83 140.94 -0.11 9400.00 49.08 49.07 0.01 141.24 141.31 -0.07 9500.00 47.73 47.68 0.04 141.64 141.78 -0.14 9600.00 47.85 47.79 0.06 142.04 142.14 -0.10 9700.00 48.91 48.85 0.06 142.19 142.35 -0.16 9800.00 49.91 49.87 0.04 141.97 142.08 -0.11 9900.00 50.18 50.16 0.01 142.64 142.70 -0.06 10000.00 51.06 51.02 0.04 143.35 143.47 -0.12 10100.00 51.69 51.66 0.03 143.50 143.60 -0.10 10200.00 52.14 52.11 0.02 144.56 144.63 -0.07 10300.00 52.16 52.12 0.04 145.50 145.66 -0.15 10400.00 52.22 52.21 0.01 145.61 145.71 -0.11 10500.00 51.95 51.93 0.03 146.44 146.60 -0.17 10600.00 51.54 51.55 -0.00 145.70 145.87 -0.17 10700.00 52.28 52.30 -0.02 145.81 145.93 -0.12 10800.00 51.96 51.94 0.02 146.66 146.82 -0.16 10900.00 51.96 51.98 -0.02 146.71 146.82 -0.11 11000.00 51.19 51.24 -0.05 147.99 148.12 -0.13 11100.00 50.90 50.86 0.05 148.95 148.98 -0.04 11200.00 50.22 50.21 0.01 149.58 149.57 0.01 11300.00 49.30 49.28 0.03 150.52 150.56 -0.04 11400.00 48.84 48.84 0.00 150.63 150.69 -0.06 Average 0.0155 -0.2100 Standard Deviation 0.0557 0.0992 Tolerance for both the Average and the Standard Casing 0.30 Casing 0.50 Deviation Drillpipe 0.30 Drillpipe 0.75° * Inclination and Azimuth interpolated to same depths as shown. SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 6 of 6 AK0915GCM170 Y li ID Survey QC - RGS-CT Analysis Sheet gy # , I , • „„,",PfNttt •01--- .,,- Grid System I I Grid Correction I 0.00 Azimuth reference:Grid/True North TRUE NORTH Vertical reference: RKB/MSL/Other RKB I If other give details I ..- . ., ., . Depth 0.00 Inclination 0.00 Azimuth 0.00 I TVD I 0.00 Northings 0.00 Eastings 0.00 Latitude 70.2441 Az. Ref:Grid/True True Grid Corrected YIN? N Description I I Tool Number I F0052 I Calibration Date I 17 May 2014 Calibration range From 50.48 To 120.02 Gyro operating range From 65.27 To 71.99 I Spec'-Within calibration range Only valid on fixed structures. When not ossible input roll test data performed after return to base) Cal value Pre job offset Post job Abs dif.cal.post Abs dif.pre.post Spec' offset Accel Scale 0.000056 0.000064 0.000052 0.000052 0.000012 Cal/Post-0.00015 Mass Unbalance 0.53 -0.07 -0.23 0.23 0.16 Pre/Post-0.4°/hr Depth (Approx) 3130.06 No of stns 6 Spec'-Min No.-6 Azimuth Mean 138.42 Std deviation 0.06 Spec'-Azi SD 0.2° Inclination Mean 10.11 Std deviation 0.00 Spec'-Inc SD 0.1° Earth Horizontal Rate Mean(Abs(meas-theor)) I 0.01 Std deviation 0.01 Spec'-See Q167 Residual x gyro bias Mean 0.000 Std dev' 0.002 ' Spec's-Mean and SD-0.333°/hr Residual y gyro bias Mean 0.000 Std dev' 0.001 Spec's-Mean and SD-0.333°/hr .0--a-t.. ...... I Maximum toolface rate I 149.59 I Spec'-400°/sec Inclination Difference Mean 0.02 Std dev' 0.06 Spec's-Casing 0.3°/Drill pipe 0.3° Azimuth Difference Mean -0.21 Std dev' 0.10 Spec's-Casing 0.5°/Drill pipe 0.75° Lateral Divergence/1000 1.82 Spec-5.0/1000 Vertical Divergence/1000 0.19 Spec'- 2.0/1000 Wireline Company Halliburton I Line type 7/32" Encoder SF I Halliburton Max Depth (TD) 11450 CCL Corrected NO Zero Depth(Rig up) RKB @ 54 ft AMSL Rezero Depth -7 Given pup joint depth NA Measured P.I NA Strech cor.At TD divided by TD/1000 .8734 Spec'-1.5/1000 Dif. Between rigup and rezero depths divided by TD/1000 .6114 Spec'-2.0/1000 Dif. Between given and meas depth divided by meas/1000 NA Spec'-2.0/1000 SURV-Q165(OPS SUR-MA-010)22nd Jan 2004/Revision 20 Page 1 of 1 AK0915GCM170 r • • gyro • Survey QC - RGS-CT Acceptance Sheet Operator BPXA Field/Platform Wellhead Well Number Prudhoe Bay Drillsite:9 Well:9-19 Survey section From 0.00 ft. to 11450.00 ft. Date 07 Sep 2015 Gyrodata Job No AK0915GCM170 Gyrodata Surveyors Adam O'Connor,Henry Drew,Ian Squier Job Objective High Accuracy Gyro Survey In Spec' QC Parameter Yes/No/NA Possible Actions Contact Duty Engineer to discuss options: Operational temperature within Yes 1. Recalibrate tool to higher temperature specification 2. Resurvey with backup tool 3. Resurvey'Hot'section at higher speed Roll test data within specification Contact Duty Engineer to discuss options: Only valid on land/fixed installations Yes 1. Recalibrate tool and reprocess survey 2. Resurvey with backup tool Continuous initialisation within Take new initialisation,after three failures: specification Yes 1. Contact Duty Engineer or, 2. Resurvey with back up tool. Contact Duty Engineer to discuss options: Toolface rate within specification Yes Resurvey section from previous bias check Investigate and comment if effects are negligible Contact Duty Engineer to discuss options: Drift tunes within specification Yes 1. Reprocess with different software settings 2. Resurvey with backup tool Inrun/Outrun comparison within Contact Duty Engineer to discuss options. specification Yes Resurvey is usually not required if either lnrun or outrun meet all other QC parameters Depth control within specification Yes Contact Duty Engineer to discuss options. Action taken: Note: Provided satisfactory action has been taken,parameters out with specification will not necessarily fail a survey. SURVEY ACCEPTED Gyrodata Representative Client's Representative SURV-Q166(OPS SUR-MA-003)13th Nov 03/Revision 12 Page 1 of 1 AK0915GCM170 Y bp RECEIVED 0 AUG E 12014 Avli`sC BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA LOG DATA) Date 21 -Aug -2014 Transmittal Number: 93373 If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents gEVI 1 CD-ROM Containing OPEN HOLE Digital Log Data: 01-14, 03-20, 04-03, 04-09, 04-10, 04-24, 06-03, 06-04, 06-04A, 09-01, 09-02, 09-03, 09-04, 09-05, 09-08, 09-09, 09-10, 09-11, 09-12, 09-13, 09-14, 09-15, 09-161, 09-17, 09-18, 09-19, 09-20, 14-26, 16-07, A-031 B-11, B-241 B-25, C-10, L2 -07A, 0-02, M-04, M-05, U-14 The information on this CDY�� is to be used for BP Exploration (Alaska) Inc. business only. If you are not the owner licensed ✓� � user of this CD, any disclosure, copying or use of the information on this CD is prohibited. If you obtain this An g ela I�. SI CD by error, please return the CD to the address shown below. BP will pay the postage. Thank you. Please Sign and Retul gancpdc@bp.com Doug Dortch Petrotechnical Data I If found please return CD to: BP Exploration PO Box 196612 Anchorage, AK 99519-6612 r by 0g For External Distribution Attn: State of AlaskaV CD 1 of 1 ! Attn: Makana Bender BPXA OH Log Data 333 W. 7th Ave, Suite 1 01-14, 03-20, 04-03, 04-09, 04-10, 04-24, 06-03, 06-04, Anchorage, Alk99501 �, 06-04A, 09-01, 09-02, 09-03, 09-04, 09-05, 09-08, 09-09, g Alaska 09-10, 09-11, 09-12, 09-13, 09-14, 09-15, 09-16, 09-17, 09-18, 09-19, 09-20, 14-26, 16-07, A-03, B-11, B-24, B-25, C-10, L2 -07A, 0-02, M-04, M-05, U-14 18 -AUG -2014 Petrotechnical Data enR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 177-077 183-101 171-005 176-030 176-042 185-301 175-073 175-062 200-102 175-076 176-016 176-035 176-040 176-047 176-070 176-076 176-082 176-084 177-007 177-008 177-025 177-036 177-037 177-038 177-039 177-040 177-041 181-110 185-204 171-038 178-069 182-140 182-151 179-035 204-053 186-154 171-023 176-110 193-100 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg j�t -! (�1 �DATE: Tuesday, June 17, 2014 P.I. Supervisor ' `Fjj �� SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-19 FROM: Johnnie Hill PRUDHOE BAY UNIT 09-19 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry S4— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-19 API Well Number 50-029-20260-00-00 Inspector Name: Johnnie Hill Permit Number: 177-040-0 Inspection Date: 4/7/2014 Insp Num: mitJWH140407143951 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-19 Type Inj W' TVD 8689 IA 649 2512 2482 2474 TD 1770400 Type Test I SPT Test psi 2172 OA 451 576 592 618 - nterval 4YRTST p/p P Tubing 1431 1430 1427 1426 Notes: OA psi was coming up Operator is going to do a further investigation on it SCMNEU 0 C T 0 J 2014, Tuesday, June 17, 2014 Page I of 1 Wallace, Chris D (DOA From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] Sent: Friday, March 21, 2014 4:52 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites'- rillsites;Wallace, Wallace,Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA) Subject: UNDER EVALUATION: Injector 09-19 (PTD #1770400) Possible Inner x Outer Annulus Communication During MIT -IA Attachments: Injector 09-19 (PTD #1770400) TIO Plot.docx; Injector 09-19 (PTD #1770400) Wellbore Schematic.pdf All, Injector 09-19 (PTD #1770400) exhibited signs of outer annulus pressurization during an MIT -IA on 03/20/2013. A subsequent MIT -OA failed on the same day. The well is reclassified as Under Evaluation, added to the Monthly Injector Report, and placed on a 28 day clock to facilitate evaluation. Plan forward: 1. Wellhead: PPPOT-IC A copy of the TIO plot and wellbore schematic are included for reference. Thank you, Jack Disbrow BP Alaska - Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email: AKDCWellintegritvCoordinator@bp.com SCANNED 4.000 3.000 2,000 t.Ow Injector 09-19 (PTD #1770400) TIO Plot wall -09-19 Olr&14 C7A1114 OW4 Mn5114 02,22114 03101;14 OMI4 0371514 t Tbg f IA —� OA DOA t DOOA On TREE- FMC OM 1 ,WaLHMD- FMC ACTUATOR- AXELSM ICL a.a1- w BF. ELHf- 6 Mw ■ 31NF NhIK Ards - 63' o l0 DW=ND- 113W OdLnnTVD- 88W 813 134W CM 7M, WSO, ID = 12.34T' H 2714' Mlnlmum ID m 4..466" @ 11162' 644 OTIS XN NIPPLE 1 5-1/2'-rBG-PC,17#, N-M..aM bpi, ID=4.982" H 11166' PERF+OMMM SINLMRY ISS: LOQ BKM an 12011677 ANG EATTOPPERP 40' o 11994' NAA Rdw to Rodtrobn M iar hIAoriotipwfdWm 8QE 8PF NIEWAL Op d8 DOTE WW 6 11334-113W O c5c5m 3-1A' 4 11837-11346 S 0� 3-1Ar 4 11:86-11986 S 03�i88 31A' 4 11414-11454 8 O As MW 6 11488 -11606 0 041MA14 3.1A' 4 11828-11532 8 0 34Mr 6 11632-11542 0 10/2N86 34W 1 11676-11608 0 03►dr180 34W 4 11621-11636 O 07fl6N0 I ,1807' I 11lw ,. , .. 7,11 09-19 M ON BL WELL OHWi A SSSVr ON OL 11048' j -j51/2' BOT SEAL ASSY 110b1' 9-5✓ ' X 5-1 & BAKER M-1 PKR NIP, ID -7-4-45-W-1 Ili - SMEAROLff SLIH � G TAIL 11166' RM TFLOGGED Q41D4lSS FFZ XHX BAY UNR WELL: 09-19 PEFUWr No: 774)40 AR Not 50402D,'9XMM-00 Sec. 1, TDR RIW,1368.04 FEL. 4351.61 RNL BP F 11'm ENn IAIMty Wallace, Chris D (DOA From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Tuesday, April 15, 2014 3:17 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Wallace, Chris D (DOA); AK, OPS FF Well Ops Comp Rep Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA); AK, D&C Well Integrity Coordinator Subject: OPERABLE: Injector 09-19 (PTD #1770400) OA pressure stable post AOGCC witnessed MIT -IA All, Injector 09-19 (PTD #1770400) has shown no signs of outer annulus repressurization after monitoring the well for a week after an AOGCC witnessed MIT -IA on April 07, 2014. At this time the well has been reclassified as Operable, and may remain online as needed. Please call with any questions. Thank you, Laurie Climer SaNNEQ BP Alaska - Well Integrity Coordinator GWGt/►j G;0W1VVoP11s W Drganizavoll WIC Office: 907.659.5102 WIC Email: AKDCWeIIlntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sot: Friday, March 21, 2014 4:52 PM To: A OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operation am Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, iebere; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; 'chris.wallace ska.gov' Cc: AK, D&C DHD Well Integre ineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; 'jim.regg@alaska.gov' Subject: UNDER EVALUATION: Injector 09- PTD #1770400) Possible Inner x Outer Annulus Communication During MIT -IA All, Injector 09-19 (PTD #1770400) exhibited signs of outer annulus pressurization ing an MIT -IA on 03/20/2013. A subsequent MIT -OA failed on the same day. The well is reclassified as Under Evalua added to the Monthly Injector Report, and placed on a 28 day clock to facilitate evaluation. AOGCC MITIA Forms for 03-36760600), 03-12 (1790580), 03-37 (20990), 04-10 (... Page 1 of I Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Thursday, July 01, 2010 5:06 PM To: AK, D&C Well Integrity Coordinator Cc: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); AK, D&C Well Integrity Coordinator Subject: AOGCC MITIA Forms for 03-36 (1760600), 03-12 (1790580), 03-37 (2091390), 04-10 (1760420), 04-43 (1940130),04-44 (1940100),09-16 (1770370),09-19 (1770400), 09-31C (1960640), 09-36C (1951140), 09-37 (1940280) Attachments: June 2010 MIT Forms GPB part 1.zip Jim, Tom and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: 03-06 (PTD #1760600) 03-12 (PTD #1790580) -enclosed are 2 tests; original test from 6/12 /2010 and retest on 6/29/2010. 03-37 (PTD #2091390) 04-10 (PTD #1760420) 04-43 (PTD #1940130) 04-44 (PTD #1940100) r ,~~~~, 09-16 PTD #1770370) ,, ., ~~~ ~'~}; 9-19_ (PTD #1770400) ~~°`~"` 09-31 C (PTD #1960640) 09-36C (PTD #1951140) 09-37 (PTD #1940280) «June 2010 MIT Forms GPB part 1.zip» Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 7/2/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay /PBU / DS-09 DATE: 06/12/10 OPERATOR REP: Jerry Murphy AOGCC REP: John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. --' Well 09-19 Type Inj. W TVD 8,689' Tubing 1,480 1,480 1,480 1,480 Interval 4 P.T.D. 1770400 Type test P Test psi 2172.25 Casin 540 2,280 2,230 2,230 P/F P Notes: MIT-IA to 2300 for 4 year UIC OA 40 90 180 240 Pumped 7.2 bbls MEOH to achieve test psi Well 09-31C Type Inj. W TVD 8,487' Tubing 800 800 800 800 Interval 4 P.T.D. 1960640 Type test P Test psi 2121.75 Casing 440 2,320 2,300 2,300 P/F P Notes: MIT-IA to 2300 psi for 4 year UIC OA 30 30 30 30 Pumped 3.9 bbls of MEOH to achieve test psi Well 09-36C Type Inj. W TVD 8,588' Tubing 1,000 1,000 1,000 1,000 Interval 4 P.T.D. 1951140 Type test P Test psi 2147 Casing 610 2,300 2,260 2,250 P/F P Notes: MIT-IA to 2300 psi for 4 year UIC OA 130 300 300 310 Pumped 7 bbls of MEOH to achieve test psi Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tu P.T.D. Type test Test psi Ca Notes: TYPE INJ Codes TYPE TEST Codes D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test 1=Industrial Wastewater R =Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differential Temperature Test Interval P/F ~~? INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU 09-19 09-31 09-36 06-12-10.x1s MEMORANDUM ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 15, 2010 To: JimRegg '~ .~I~~1~ P.I. Supervisor ~~~ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-19 FROM: John Crisp PRUDHOE BAY UNIT 09-19 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed B P.I. Suprv J~- Comm Well Name: PRUDHOE BAY UNIT 09-19 API Well Number: 50-029-20260-00-00 Inspector Name: John Crisp Insp Num: mitJCr100614101126 Permit Number: 177-040-0 Inspection Date: 6/]212010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 09-19 ' ~ 8689 ~ IA Well ~ype Inj. w TVD P.T.D i7~oaoo TypeTest SPT Test psi i 2172 - OA 540 ao 2280 _ 9o 2230 2230 ~ Iso 2ao Interval a~TST p/ji P Tubing laso I 1480 _ Iaao laso Notes: 7.2 bbls meth pumped for test. Tuesday, June I5, 2010 Page 1 of 1 STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMM~ION REPORT OF SUNDRY WELL OPERATIONS If~.EC~ _3~0~ 6 MAY ~ ~ 2009 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated °" ~. ' ~ ° ~~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension 1" :' Change Approved Program ~ Operat. Shutdown ~ Perforate ~ ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 177-0400 . 3. Address: P.O. Box 196612 Stratigraphic ~~ Service ' - 6. API Number: Anchorage, AK 99519-6612 50-029-20260-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 54 KB PBU 09-19 , 8. Property Designation: 10. Field/Pool(s): ADLO-028327 ' Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 11934 ~ feet Plugs (measured) 11807 PBTD true vertical 9274.99 , feet Junk (measured) None Effective Depth measured 11807 feet true vertical 9189 feet Casing Length Size MD TVD Burst Collapse Conductor 72 20" Surface - 100 Surface - 100 Surface 2686 13-3/8" 72# N-80 Surface - 2714 Surface - 2714 5380 2670 Production 11877 9-5/8" 47# MN-80 Surface - 11905 Surface - 9255 6870 4760 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# N-80 SURFACE - 11166' 0 0 - Packers and SSSV (type and measured depth) 9-5/8"X5-1/2" BAKER FB-1 PKR 11051' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: -ntervals treated (measured): ~~;,~ , (~~~.i ~~ ~fl~. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 13258 420 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~ Service ~- Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas WAG - GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 5/28/2009 Form 10-404 R ised 04/20~~?'?'°~~~ ~ ~ ; ~_ Submit Original Only ~..JUN~~7DQ~Il ~~°i~ rS ~~~~ t~ i~ 09-19 177-040 PFRF oTTO[:HMFNT C~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 09-19 2/20/78 PER 11,337. 11,346. 8,873.28 8,879.23 09-19 2/20/78 PER 11,414. 11,454. 8,924.33 8,950.93 09-19 2/20/78 PER 11,465. 11,505. 8,958.25 8,984.96 09-19 2/20/78 PER 11,528. 11,542. 9,000.37 9,009.77 09-19 2/20/78 PER 11,576. 11,606. 9,032.64 9,052.85 09-19 2/20/78 PER 11,621. 11,638. 9,062.97 9,074.45 09-19 5/11/84 APF 11,366. 11,386. 8,892.48 8,905.74 09-19 2/5/88 SQZ 11,337. 11,638. 8,873.28 9,074.45 09-19 3/25/90 RPF 11,576. 11,606. 9,032.64 9,052.85 09-19 7/18/90 RPF 11,621. 11,638. 9,062.97 9,074.45 09-19 4/1/94 RPF 11,465. 11,485. 8,958.25 8,971.59 09-19 ~ 4/1/94 RPF 11,485. 11,505. 8,971.59 8,984.96 09-19 10/22/96 RPF 11,532. 11,542. 9,003.06 9,009.77 09-19 5/25/09 APF 11,334. 11,350. 8,871.3 8,881.88 ~~ AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 09-19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 5/25/2009 '"*'`WELL FLOWING ON ARRIVAL**" (PERFORATE) INITIAL T/I/O = 475/350/25. RIG UP ELINE. WELL SHUT IN PRIOR TO RIH. ,PERFORATED FROM 11335'-11351' WITH 3-3/8" POWER JET 3406 HMX, 6 SHOT PER FOOT, 60 DEGREE PHASING. TIED INTO GR/CCL DATED 28-DEC-1977 .(TIE-IN LOG) . -1' CORRECTION TO BRCS LOG DATED 21-DEC-1977 (REFERENCE LOG). ON DEPARTURE: SSV=O, MV=O,SV=C, WV=O, WELL READY TO BE PUT ON INJECTION. FINAL T/I/O =VAC/300/50, DSO NOTIFIED OF VALVE SETTING "`**JOB COMPLETE*** FLUIDS PUMPED BBLS 1 METH 1 diesel 2 Total R~~Ci v L.Ù AUG 0 8 2006 Schlumberger ~ Oif & Gas Cons. Com~ NO. 3883 Anchorage Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ... l rY¡WD 'Yo (..."., Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 GIG 1"7-7- - OLj 0 '·C J\N¡"'~Ef) !\UG .- ,":'},.h" ' Field: Prudhoe Bay WI( J b# C CD L D D B e 0 og escrlptlon ate L olor NK-43 11211388 PROD PROFILE W/DEFT 04/02/06 1 NK-22A 10568415 PROD PROFILE; W/DE;FT 02/26/03 1 L4-12 N/A WFULDL 05/09/06 1 L2-21 A 10670034 MEM PROD PROFILE 09/20/04 1 13-06A 11217266 INJECTION PROFILE 07/12/06 1 01-17B 11209602 MEM PROD PROFILE 04/27/06 1 09-08 11296705 INJECTION PROFILE 07/21/06 1 09-19 11296704 INJECTION PROFILE 07/20/06 1 09-25 11296703 INJECTION PROFILE 07/19/06 1 04-09 11211398 INJECTION PROFILE 04/28/06 1 04-10 11211380 INJECTION PROFILE 03/23/06 1 17-21 11223104 PROD PROFILE W/DEFT 03/22/06 1 18-03B 11057071 SBHP 12/02/05 1 X-15A 11212877 USIT 07/18/06 1 J-01 B 11511430 USIT 07/24/06 1 15-12A 11221595 US IT 07/25/06 1 Z·14B 11217268 US IT 07/29/06 1 S-400 10987564 CH EDIT PDC-GR OF USIT 01/26/06 1 D-03A 11217269 US IT 07/31/06 1 05-28A 11217267 US IT 07/28/06 1 Petrotechnical Data Center LR2-1 900 E, Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 08/01/06 . . MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg Q!.!Ii..< 1{Z;-¡OG P.I. Supervisor \ ·~t{ DATE: Monday, July 17, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-19 PRUDHOE BAY UNIT 09-19 \11-04-0 FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .'H"'Z- Comm NON-CONFIDENTIAL Well Name: PRUDHOE SAY UNIT 09-19 API Well Number 50-029-20260-00-00 Inspector Name: John Crisp Insp Num: mitJCr060705065324 Permit Number: 177 -040-0 Inspection Date: 6/29/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ¡ 09-19 ¡Type Inj. I w I TVD I 8689 ; IA 180 2250 I 2220 ¡ 2210 I P.T. i 1770400 ITypeTest i SPT I Test psi J 2172.25 i OA 180 380 ! 380 I 380 Tubing 1180 1180 I 1180 I 1180 Interval 4YRTST P/F P I ! Notes 6.6 bbl's pumped for test. ~(~ .;.;.¡",¡.:-.f;'; {; ",;' L..,'.' ."',.. :..:~ < ~wJIt.¡J \J ...~..,..... ..:.. ...-1 "'''' Monday, July 17,2006 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor Chair THRU' Tom Maunder ~~ P.I. Supervisor FROM: John Crisp Petroleum Inspector DATE: June 22, 2002 SUBJECT: Mechanical Integrity Tests BPX DS 04,09 & 16 04-08,43,44 09-19 16-16 Prudhoe Bay Field Prudhoe Bay Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. we,,I 04-08 I Type,nj.I S I T.V.D. 18454 I Tubing I 1600 l~600 1~600 l~600 I'nterva'l 4 P.T.D.I 1760100 ITypetestl P ITestpsiI 2114 1CasingI 150 I 2420 I 2400 I 2400 I P/F I --P Notes: 4 BBL. diesel pumped to achieve test pressure. We,I 04-43 I Type,nj.I S I T.V.D. 15880 I Tubing 12250 12250 12250 12250 I'nterva'l 4 P.T.D.I 1940130 ITypetestl P ITestpsil 1500 1CasingI 0 I 1980 I 1930 I 1920 I P/F I P Notes: 1 BBL. diesel pumped to achieve test pressure. WellI 04-44 I Typelnj.I S I T.V.D. I 7995 I Tubing I 1950 I 1950 I 1950 I 1950 I lntervall 4 P.T.D.I 1940100 ITypetestl P I Testpsil 1662 1CasingI 220 I 2060 I 20401 20301 P/F Notes: 1 BBL. diesel pumped to achieve test pressure. we,,I o~-~ I T ,e,nj.I ~ I T.V.D. 1~9 I Tubing 11700 11700 11700 11700 I'nterva'l 4 P.T.D.I 1770400 ITypetestl P ITestpsil 2172 I Casingl 190 I 23201 22201 22001 P/F I P Notes: 10 BBL. diesel pumped to achieve test pressure. we,,I ~-~6 I Type,nj.I S I T.V.D. 18438 I Tubingl 740 1740 1740 1740 P.T.D.I 1801270 ITypetestl P ITestpsil 2110 I CasingI 0 I 24101 23701 23601 P/F I --P Notes: 7 BBL. diesel pumped to achieve test presure. Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BP's PBU to witness 4 year MIT's on 5 wells. No failures witnessed. M.I.T.'s performed: _5 Attachments: Number of Failures: 0 Total Time during tests: 6 hrs. cc: MIT report form 5/12/00 L.G. MIT PBU DS 04,09 & 16 06-22-02jc.xls 7/8/2002 STATE OF ALASKA '~'- ALASKA C,,_ AND GAS CONSERVATION COM,~,ISSION REPORT OF SUNDRY WELL OPERATIONS 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 525' FSL, 250' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1316' FSL, 1567' FEL, Sec. 12, T10N, R15E, UM At effective depth 974' FSL, 1378' FEL, Sec. 12, T10N, R15E, UM At total depth 930' FSL, 1353' FWL, Sec. 12, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 54' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-19i 9. Permit number/approval number 77-40 10. APl number 50 - 029-20260 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 72' Surface 2686' Production 11877' 11934 feet 9275 feet Plugs(measured) PBTD Tagged @ 11605' MD (10/22/96) 11605 feet 9052 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 258 Sx AS II 100' 100' 13-3/8" 5300 Sx AS 2714' 2714' 9-5/8" 1000 Sx Cl G & 300 Sx AS 11905' 9255' Perforation depth: measured 11465 - 11505'; 11532 - 11542'; 11576- 11606'; 11621 - 11638' true vertical 8958 - 8985'; 9003 - 9010'; 9033 - 9053'; 9063 - 9074' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, LTC Tbg @ 11166' MD. Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 11051' MD; 5-1/2", Camco BaI-O SSSV @ 2215' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure .... 21910 -- 22757 Tubing Pressure 1960 1848 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations x 16. Status of well classification as: Oil Gas Suspended Service Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~ "~. ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 c.e: .IWP Date /~ ~ - ~ SUBMIT IN DUPLICA~FF~ 9-19i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED I 0/22/96' MIRU & PT equipment. RIH w/perforating gun & tagged PBTD at 11605' MD, then PU & shot 10' of reperforations as follows: Reperforated: 11532 - 11542' MD (Z2) Ref. Log: BHCS 12/21/77. Used a 3-3/8" carrier & shot 6 spf at 60 degree phasing at balanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to produced water injection & obtained a valid injection rate. .... -. STATE OF ALASKA _~_ ALASI' _AND GAS CONSERVATION CC IlSSION REPOR'I OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well , -- Perforate X · Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 525' FSL, 250' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1316' FSL, 1567' FEL, Sec. 12, T10N, R15E, UM At effective depth 974' FSL, 1378' FEL, Sec. 12, T10N, R15E, UM At total depth 930' FSL, 1353' FEL, Sec. 12, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 54' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-19i 9. 'Permit number/approval number 77-40 10. APl number 50 - 029-20260 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11934 feet 9275 feet Effective depth: measured 11752 feet true vertical 9151 feet Casing Length Size Conductor 72' 20" Sudace 2686' 13-3/8" Production 11877' 9-5/8" Plugs(measured) PBTD Tagged @ 11752' MD (3/31/94) Junk(measured) Cemented Measured depth True vertical depth 258 sx AS II 100' 100' 5300 sx AS cmt 2714' 2714' 1000 sx CIG & 300 sx AS cmt 11905' 9255° Perforation depth: measured 11465-11505'; 11576-11606'; 11621-11638' true vertical 8958-8985'; 9033-9053'; 9063-9074' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, LTC Tbg @ 11166' MD RECEIVED A U G ;5 0 'tqci Oil & 6as Cons. (;¢rnmission Packers and SSSV (type and measured depth) FB-1 Packer @ 11051' MD and BaI-O SSSV @2215' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure SHUT-IN 19170 Tubing Pressure 1607 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sig ned ~ ,.~¢.,~- ~"~ Form 10-404~ Rev 06/15/88 I t 7Q/t 9 t,r,- 1~'7 _ I~A/P Title Engineering Supervisor Date SUBMIT IN DUPLICAT/~ 9-19i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 3/31/94: RIH & tagged PBTD at 11752' MD. 4/1/94: MIRU & PT equipment. Reperforated: RIH w/perforating guns & shot 40' of reperfs as follows: 11465 - 11505' MD (Z2) Ref. Log: BHCS 12/21/77. Used 3-3/8" carriers, & shot 6 spf, at 60 degree phasing. Shot perforations while well was overbalanced w/full header pressure on tubing. POOH w/perf guns. Noted all but five shots fired. Rigged down. Returned the well to produced water injection & obtained a valid injection rate. RECEIVED ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360, E~horage, AK May 10, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263o4310 Transmittal #: 94037 99510,~ ~, RECEIVED Oil-& 6as Cons. Co,~ission Distribution //5 Well ILog Datei Tool Type I Run, Contractor: Number (M-D-Y) Scale OWDW- l 04-30-94 Pump-in Temp 1, 5" Sch -- ----------- ~' NVV OWDW- f 04-30-94 Pump-in Temp 1, 5" Sch _ .~ ,Si= -------P- 1-2 I 04-19-94 f CNL 1, 5" Sch ~ 1-4 ! 04-20-94 I f TDT-P I 1, 5" Sch 1-17 I 04-07-94 I f TDT-Pi 1, 5" Sch -------~ 1-24A i 04-08-941 J Perf Record 1, 5" Sch -~: ~ 2-18 l 04-16-94 1 f Perf Record 1, 5" Sch 04-17-94 if Prod' Profile 1, 5" Sch ...... 2-19 ,- 2-25 I 04-18-94 If Bridge Plug 1, 5" Sch ~- 2-34 i 04-19-94...-- Prod Log 1, 1"&5" Sch -- ~ 2-35 ! 04-12-94 i~' Prod Profile ~ 1, 5" Sch 3-17 I 04-27-94 l~lnjection Profile I 1, 5" Sch x t 3-17 i 04-19-94 if Perf Record f 1, 5" Sch --'-~ 3-21 i 04-20-94 i ,~ Perf Record! 1, 5" Sch _~~ 3-29 ii 04-14-94 ti"' Leak Detect I 1"&2"&5"f 1, Sch --~-~ 4-29 I 04-29-94 i-'Injection Profile ! 1, 5" Sch ----- -,r 4-33 i 04-12-94 ! ~ USlT i 1, 5" Sch *' i 4-44 ! 04-14-94 i ~ TDT-P~ 1, 5" Sch ! t 1 5" Sch k i 4-44 ~ 04-14-94i ~ CNTG [ , / i 4-45 I 04-24-94 ! .~ CNTG i 1, 5" Sch ~ i 4-45 04-24-94 ~' TDT-P 1, 5 Sch ..-------~- 4-46I 04-22-94 ~'- Perf Record 1, 5" Sch -------~ 5-10 f 04-13-94 ~- Leak Detect 1, 2"&5" Sch / 5-15A i 04-25-94 i~CTU Prod Log i 1, 5" Sch \ 5'15A i 04-26'94 ~ TDT'PI { 1,5" Sch -------~- 5-35 04-16-94 ! -~, Leak Detect 1, 5" Sch -~ 6-6 04-17-94 /" Completion 1, 5" Sch -~/~ 6-14~ 04-08-94 ~ TDT-P 1, 5" Sch I-~ '~ 6-14A 04-19-94 ~-- Completion 1, 5" Sch \*-~ 6-22A'I 04-27-94 f~Perf Record 1, 5" Sch ~ [ 07-23 04-13-94 -~Patch Record I 5" Sch ~ I 07-23 I 04-16-94 ! ~Leak Detect 1, 2"&5" Sch ! 7'24 I 12-09-931 ~--TDT. P 1, 5" Sch ..... ~ f 7-24 I 04-18-94 I ~ InjProfile I 1, 5" Sch ~ ~ 9-1 i 04-12-94t~ Patchf 1,5" Sch '' -~-~ 9-9 f 04-23-94i ~PatchRecord I 1, 5" Sch ~ 9-19i 04-20-94 i ~-Inject Profile I 1, 5" Sch 00- p_~q ~ ARCO Alaska, Inc. Is a Subsidiary of At~anflcRIchfleldCompany ARCO Alaska, Inc. P.O. Box 100360, ~)chorage, AK 04-27-94 --"-!- 9-20 ; 9-29 ....... ..L 9-33 11-6 · 11- 9?5- u© 02-19-94 04-11-94 04-20-94 04-15-94 /-"Inject Profile i 1, 5" /' Vertilog i 1, 5" ~"Perf Record i 1 i , JPerf Record i I 5" /Leak Detect i 1, 2"&5" i Sch Sch Sch Sch Sch 04-26-94 /'Perf Record ! I 5" Sch i Sch I 5" I 5" I 5" 1 5" 1 5" I 5" I 5" 04-19-94 /'"Completion 05-01-94 i/Injection Profile 04-23-94 I / Patch 04-21-94 l J Production 04-11-94t / TDT-P 04-10-94 -~CTU Conveyed 05-01-94 I / PDC & Static Sch Sch Sch Sch Sch Sch 04-18-94 1~' PatCh ~i 1' 5" Sch 04-22-94 ~/CTU Production I 1,2" 5" Sch · 04-23-94 CTU Production i 1, 5" Sch DS#6-22A the correct depths are Btm. 10473/-I'op 10465 DS#9-19, the correct APl# is 50-029-20260-00 DS#18-28ST1 the correct APl# is 50-029-22329-00 Number of Records: 53 Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon State of Alaska Mobil Please acknowledge receipt by signing and returning a copy of transmittal. By: /7 ~~ _z~ Date: ARCO Alaska, Inc. Is a Subsidiary of AtlantJcRIchfleldCompany ARCO Alaska, Inc. Date: Apr 14, 1994 P.O. Box 100360, , .;horage, AK Transmittal #: 94034 99510,j~ ~k, Subject: ARCO Cased Hole Finals From/Location: Telephone: To/Location: John- E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well ~ Number 01-11 t~. 01-33 03-01 7~-~q 03-02 03-19 03-29 · ~ 03-29 Log Date i Tool Type (M-D-Y)I 1/04-43 lqq.-'lS!~ 04-43 ! %,04-43 ~0! 04-44 04-02-94 t,," Perf Record 03-25-94 ! TDT-P 03-28-94 !,,,- TDT-P 03-27-94 i¢ Perf Record 03-22-94 !~ Leak Detection 03-22-94 t¢ Bridge Plucj 03-18-94 i,/Leak Detection 0~3-27-94 ~LI,-~?..i 03-31 03-27-94 03-29-94 04-45 05-08 o6-19 07-08 07-23 09-01 09-02 03-29-94 Bridge Plu~ Brid~e Plu9 TDT-P CNTG 7(~--5~ 09-03 '/"/-q.o! 09-19 ~%-2..~ 09-27 ;lb- ~Oi 11-04 ~lo~JCt f 11-17 5-.2.O~. 11-24A IZ.-5~ 12-06A ~2.- O~ 13-20 "~ ~5~. [ 14-03 ~ ?..-~;"'( ! 14-23 i//14'28 ~Z-~ 5~i 16-04A 1~5-7_q~J ~6-18 ~Z.- LoZ. i 16-28 ~--/t, 18-08 03-10-94 i ¢' USIT 03-13-94 ~v' USIT 03-29-94 {¢, USIT Cement 03-14-94 iv Prod Profile 03-18-94 i,/ Perf Record 04-03-94 i-' Perf Record 03-21-94 i,/ Brid(:je Plug 03-30-94 i,,' Prod Profile 03-17-94 i~ Prod Profile 03-29-94 !/ Prod Locj 04-01-94 i¢' Perf Record 03-16-94 i / Prod Log 03-22-94 i ~ Perf Record 03-16-94 ! ." Patch settin~ Perf Record Run, Scale 1 5" 1 5" 1 5" 1 2" 1 5" ! 5II 1,5" 1 5" Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch 1 5" 1 1 1 1 1 1 5" Sch 5" Sch 5" Sch 5" Sch 5" Sch 5" Sch ! 5II 1, 1"&5" Sch Sch Sch Sch . Sch Sch Sch Sch 1~ 5II 1~ 5II ! 5II 1, 5" 03-29-94 i./ 1, 5" Sch ~ 03-18-94 i- Prod Profile 1, 1"&5" Sch : Sch 03-15-94 j," Leak Detection 03-28-94 i" CNL 1~ 5II 03-19-94 ! ¢- Prod Profile 1, 1"&5" 03-15-94 ! ¢- Leak Detection 1, 5" Sch Sch .. Sch Sch Sch ! 5II 03-28-94 i,'"' Patch Settincj 03-21-94 i/' Bridge Plu9 CNL 1~ 5II , 03-17-94 iv- 1, 5" Sch 03-15-94 i,,.- Perf Record 1, 5" Sch 1, 2"&5" Sch 03-14-94 i¢-' Leak Detection 03-14-94 !,/ Perf Record Sch Sch 03-20-94 i'" TDT-P 1~ 5II t 511 Number of Records: 38 ARCO Alasl(a, Inc. Is a Subsidiary of AUant~cRIchfleidCompany ARCO Alaska, Inc. P.O~x 1OO360 Anchorage, 99510 DATE: 12-1-93 REFERENCE: ARCO CASED HOLE FINALS ~:_~__2-17 10-16-93 22 10-22-93 25 10-15-93 q 5..~.~.,r.,o.~ 10-25'93 ~ 10-26-93 q ~ ~l'b~/ ~/4-23A 10-9-93 ~~4-23A 10-18-93 ~5'6 10-21-93 ~-0 ~ ~0~6' 13 10-19-93 c~~6-19 10-19-93 '~~20 10-21-93 ~29 10-17-93 2-6A 10-14-93 '~12-10A 10-18-93 ~ ', 12-16A 10-18-93 10-12-93 D~ B~t T~P ~ ~ ~ USIT [¢~a~ ~~ Color ~P ~t iz~o - t~qo7 USIT (~vo~i&) Color Peff R~ ItLoO-1~57 Collar (~ ~ Completion ~i0o -~o 1, 5" q55o--.q, qq~' Sch 1, 5" Sch 1, 5''c/ta~q-l°'~-/5 Sch 1, 5" Sch 1, 5"qOS~--fiwz(~ Sch 1, 2"&5" 5- II0o0 Sch 1, 5"1o~0o-~ o535 Sch 1,1"&5"0- 5i~o Sch 1, 5" Atlas 1, 5" ~zoo - q-/~'o Sch 1, 2" iS~o-0zoo Sch 1, 5" Sch 1, 5" Sch 1, 5"0-d[500-~$0 Sch 1, ~' Sch 1, 5" Sch 1, 1"&5" o-~/o5~ Sch 1, 5" Sch 1, 5" Sch 1,5" ~lt$o ~lV/'52 Sch 1,5" ~3~0~1o~o Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5"/52'5~--~.5~/o Atlas 1, 5" Atlas 1, 1"&~'~0-1o7vo Sch 1, 5" Sch 1, 5" Sch 1, r' .~-2~-/~ Sch RECEIVED BY Have A Nice Day! Sonya Wallace AT0-1529 # CENTRAL FILES #CHEVRON #BFX # STATE OF ALASKA recetpt of data. /_)<<,f~C~//k AP P ROVED ~_,'~. ~ ~ ' ~,~_.'O¢~ ~ ~S' 931~-~ -' 'q~pe~: %, ~~N ~ MO~ * The correct APl# for 9-7 is 50-029-20223-00. ARCO Alaska, Inc. P.O,Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOT~- FINALS 12-1-92 Prod Profile R~_m 1, 5" 12-4-92 Prod Profile Run 1, 2"&5" 12-5-92 InJ Profile R~_m 1, 5" 11-12-92 Temperature R~_m 1, 5" 11-23-92 Jewelry Run 1, 5" 12-7-92 Lesk Detect Run 1, 5" 12-4-92 GR/Collar Run 1, 5" 11-21-92 InJ Profile Run 1, 5" 11-27-92 Prod Profile R~_~n 1, 2"&5" 12-7-92 Prod Profile R~_m 1, 5" 11-29-92 Prod Profile Run 1, 5" 11-20-92 Prod Profile R~_m 1, 5" 12-11-92 InJ Profile Run 1, 5" 12-1-92 Prod Profile Run. 1, 5" Please sign and return the attached copy as receipt of data. RECEIVED BY___~.~j~_j~ Have A Nice Day! Sonya Wallace ATO-1529 APP R OV E D___~ ~~ Trans# 93039 Cslnco Camco Camco Camco Camco Camco Caxnco Camco Camco Camco Camco Camco Camco Camco # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO ' * The correct well name for this log is 3-34A. STATE OF ALASKA ALASK/"-' L AND GAS CONSERVATION C~ MISSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 525' FSL, 250' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1316' FSL, 1567' FEL, Sec. 12, T10N, R15E, UM At effective depth 974' FSL, 1378' FEL, Sec. 12, T10N, R15E, UM At total depth 930' FSL, 13535' FEL, Sec. 12, T10N, R15E, UM Plugging Perforate X Repair well Other 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) RKB 54 feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-19 9. Permit number/approval number 77-40/90-111 10. APl number 50 - 029-20260 12. Present well condition summary Total depth: measured 11,934 feet Plugs(measured) true vertical 9275 feet Effective depth: measured 11,862 feet true vertical 9226 feet Junk(measured) Casing Length Size Cemented Structural 72' 20" 258 sx AS II Conductor 2686' 13-3/8" 5300 sx AS cmt Production 11,877' 9-5/8" 1000 sx CIG & 300 sx AS cmt 11. Field/Pool Prudhoe Bay Oil Pool Perforation depth: measured 11576-11606'; 11621-11638' true vertical 9033-9053'; 9063-9074' Tubing (size, grade, and measured depth) 5-1/2", L-80 tubing w/tail @ 11,166' Measured depth True vertical depth 100' 100' 2714' 2714' 11,905' 9255' JtJL - 2 Alaska 0it & Gas 00ns. 'Anchorage Packers and SSSV (type and measured depth) FB-1 Packer @ 11,051' & BAL-O SSSV @ 2215' 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation Representative Daily Average ~or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 25000 25000 Tubing Pressure 1900 1900 14. 16. Status of well classification as: Oil Gas Suspended Service 1 ~/~~ X ~r'~ 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Date ~/Z~,:/~ ~ SUBMIT IN DUPLICATE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ',~(_~f~f~,~ ~. ,~y~.~ ..... Title Operations EngineeringManager Form 10-404 Rev 06/15/88 DS 9-19i PERFORATING SUMMARY OF OPERATIONS ARCO Alaska, Inc. reperforated DS 9-19i in the Ivishak Sand of the Prudhoe Bay Unit on 3/25/90 (11576-11606' MD, ref. log BHCS 12/21/77) and on 7/18/90 (11621-11638' MD). Produced water was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/lubricator tested to 1.2 times the maximum expected surface pressure. A summary of the work is below: Rig up perforating unit on 3/25/90 and pressure tested equipment to 3000 psi. Backflow gas onto wellbore to depress liquid level (WHP 1600 psi) Bleed off WHP to drain system for drawdown. SI well. Shot 11576-11606' MD, 1 spf. Secured well. RD. Returned well back to production. Underream wellbore down to 11743' MD on 7/14/90. Rig up perforating unit on 7/18/90 and pressure tested equipment to 3000 psi. Backflow gas onto wellbore to depress liquid level. Bleed off WHP to drain system for drawdown. SI well. Shot 11621-11638' MD, 4 spf. Secured well. RD. Returned well back to production. A i'q C t.-i 0 R. A G E A I_ A £' K A 995~ D A 7' E ' '7 - S ~.~: '- 9 0 F:~EFEt:;:E:NCE AF;.:CO r"A~'E'-O HOLE F' :[ ;.,i ,'- , e F::t. JN i : RUN i: t:;.'. U i"..! i , F<' U Ni , F;.: LJ N 'i , F;,' U i"-! i , !:;.'.t.J i"4 i , F;.: U N !, F;..' U N t , F,'UN i, I:4 U Ni , t:;,'iJ F! i, F ;.'. t ..t i"! i , F<UN i , F;..' Lt N i, F' !.. ii.". A $ Er S ]: (} N i:" c' f" r.:' 'r.:. .' ....... L..Z V E D,.. '";: AND F<ETUt;.:N T!--ii= A"i"f'ACHiED COPY AZ.".' RECEIPT OF' DA'¥A., !--!AVE A NZC.:!i: DAY! ;ii; A I... L. Y H [) F:' F E':.3 K E F;.'. ATO-- i 5- 2 S=.-' D I S T R :[ B U"f' ]: 0 N · ~: C FZ N T R A L 1= l 1.. E $ :I,~. I'" FI :[ t_ I_ :[ F:' Y · "' F:HFVRON F'B WFI_L F']:I..E,".';-: 11' . ...... ' D & iq ~:;' * 'C' , ..Lt': . .". '::' Y' . ' -. B P X .,,. ..... FENSiON EXPLOR~':',T I ON. ",," :~. EXXON .':: STATE UF' ALA,'SK;:~; H A R A T It O N. T E X A C (ii ~ i,iOBIL ARC() ALA.'?KA, INC. F'.O. BOX t0036(-) ANCHORAGE, ALA~'KA 995t0 DATE · 4-4-90 REFERENCE' ARCO CASED HOLE FINAL.S' -4 O 3-3t -90 COLLAR/PERF RUN -26 3-2:3-90 COLLAR/PERF RUN t, 5 · -34 3-23-90 CNL.-GR RUN t , 5 .~ ~ m ~-~8 ~-2~-~ COLLAR/F'ERF RUN 2-29A 3-27-9~ F'ROD. F'KR RUN 3-~ :S 3-3()-9e COLI_AR/F'ERF RUN 3-~5~ 3--~-9~ COLLAR/F'ERF RUN ~, 5" 25 S-Se-ge COLLAR/FERF RUN 9-~9 3-25-9~ COLLAR/PERF RUN t, 5" 4-26 ~ 3-29-9e COLLAR/PERF RUN ~, 5' 5-4 3-22-9~) CNL-GR RLJN t, 5" 6-t~ '~ ~-28.-9e " COLLAR/PERF RUN t , 5' PLEASE ~IGN AND RETURN THE ATTACHED COPY A~ RECEIPT OF DATA. RECEIVED BY ~ HAVE A NICE DAY! SALLY HOFF'ECKER ATO-t 529 APR - 6 1990 OJ| & G~S OOTlS. 00111~%$¢~;"--' ~ T F,' A N $.~ A F'F'ROVEDg(~ '~'"~ 't 3 i Anchorage A "!' LA ~ A ]"I_A ;~' A'f'I...A S' ATI_A£ A'f'LA:? .,. · . .,~ ~ R ! I._ ~, ..~ ATLAS' A"I"I_ A ;; A"f'L.A~,~ A'T'I..A~' ATLAS' A'T'I_A~, DISTRIBUTION ~ CENTRAL FILES -.-'"' CHEVRON D & M · .. EXTEN..., l ON EXPLORATION ' EXXON MARATHON ~ MOBIL ?' PHILLIPS PB WELL FILES R & D BF' X STATE OF ALA~'KA TEXACO ARCO ALASKA, INC. P.O. BOX ~00360 ANCHORAGE, ALASKA 995 J O DATE' 3-9-90 REFERENCE' ARCO PRESSURE DATA 3-4 t-6-90 BHF'--$TATIC GRADIENT CAMCO 3-J8 t-6-90 BHF ....STATIC GRADIENT CAMCO 9-,t~ t-t5-90 BHP--$TATIC GRADIENT CAMCO 9-i9 t-t5-90 BHF ....ETATIC GRADIENT CAMCO ~-t ~-5-90 BHP--$TATIC HR£ ~.-~6 ~-5-90 BHF'--$TATIC HR$ J2.-2~ t-7-9~ BHF'--STATIC HR$ ~2-29 ~-~3-90 BHF'--$TATIC GRADIENT CAMCO t 3-32 J -7-90 BHP--STATIC HR$ ~4-2J ~-3-90 BHP--FLOWING GRADIENT CAMCO J4-36 ~-3-90 BHP--FLOWING GRADIENT CAMCO J6-J J ~-~3-90 BHP--STATIC GRADIENT CAMCO ~8-3 J~-29-89 BHP--STATIC GRADIENT CAMCO ~8-9 ~.-29-89 BHP--~TATIC GRADIENT CAMCO ~8-~6 t~-29-89 BHP--£TATIC GRADIENT CAMCO ~8-2~ ~J.-.29-89 BHP--$TATIC GRADIENT CAMCO PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA~ RECEIVED BY HAVE A NICE DAY! RE-C-F..fV-E O MAR ! 4 !990 APF, ROVED/'/'~ Oil & G~s Cons. Com~SS't~l I'RAN$~ 9~- Anchorage SALLY HOFFECKER ATO-~ 529 DISTRIBUTION CENTRAL FILES ~ ~'HILLIF'$ CHEVRON PB WELL. F:'ILE,S' D & M -,-'"R & D EXTENSION EXF'LORATION ~ BF'X EXXON ~ ~ STATE OF ALASKA MARATHON ~ ~ TEXACO MOBIL ARCO Alaska, Im Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager February 16~ 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 9-19 Permit No. 77-40 Dear Mr. Chatterton: Attached, in triplicate, is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/GSS/sbm , Attachment cc' J. Gruber- ATO 1478 PI(DS 9-19)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3E~--(~132-C APPLICATION FOR SUNDRY APPROVA 1. Type of' Request: Abandon Suspend 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 525' FSL, 250' FWL, Sect. 1, T10N, R15E, UM At top of productive interval 1316' FSL, 1567' FEL, Sect. 12, T10N, R15E, UM At effective depth 974' FSL, 1378' FEL, Sect. 12, T10N, R15E. UM At total depth 930' FSL, 1353' FEL, Sect. 12, T10N, R15E, UM Operation shutdown Plugging Pull tubing Variance 5. Type of Well Development Exploratory Stratigraphic Service X Re-enter suspended well Time extension Stimulate Perforate X Other 6. Datum of elevation(DF or KB) RKB 54 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-19 9. Permit number 77-40 10. APl number 50 - 029-20260 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 72' Surface 2686' Production 11,877' 11,934 feet 9275 feet Plugs(measured) None 11,862 feet 9226 feet Junk(measured) Size Cemented 20" 258 sx AS II 13 3/8" 5300 sx AS cmt 9 5/8" tooo sx Class G & 300 sx AS crnt None Measured depth 100' 2714' 11,9O5' True vertical depth 100' 2714' 9255' Perforation depth: measured All perforations squeezed true vertical All perforations squeezed Tubing (size, grade, and measured depth) 5 1/2", L-80 tbg w/tail @ 11,166' Packers and SSSV (type and measured depth) FB-1 Packer @ 11,051' & BAL-O SSSV @ ~a, J E 13. Attachments Description summary of proposal 14. Estimated date for commencing operation 2-20-90 16. If proposal was verbally approved Name of approver Date approved X Detailed operations program BOP sketch X 15. Status of well classification as: Oil Gas Suspended Service WAG Injector 17. I hereby~ertify that the foregoing is true and correct to the best of my knowledge. Signed 2~d2~ Title Operations Engineering Manager Date FOR COMMISSION LI~I::: 13NLY Conditions of approval: Notify Commission so representative may witness I Approval No.~¥) Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- /7~-~ LF Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C, Commissioner Date ~ ----"2-- J - Cji'Q) Form 10-403 Rev 06/15/88 Approved Copy i~eturne, d SUBMIT IN TRIPLICATE DS 9-19i PROPOSED ADD PERFORATIONS APl # 50-029-20260 PERMIT # 77-40 ARCO Alaska, Inc. proposes to reperforate previously cement squeezed intervals in DS 9- 19 within the Sadlerochit Sand from the Prudhoe Bay Unit. The proposed perforation intervals are as follows: Ref. BHCS Footage Flow (12/12/77) CMD) SPF Unit 11576-11606 30 1 Tango 11621-11638 17 4 Tango Well 9-19 is a WAG injector that is currently injecting SWI. The wellbore fluid present when the perforations will be shot is water. The expected bottom hole pressure is 3700 psi. All wireline work will be done through a 5000 psi WP BOP/lubricator, tested to 1.2 times the maximum expected surface pressure (diagram attached). 1. '5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF H I REL I NE BOP EC)U I PMENT · IIII II III IIIII I I ARCO ALASKA, INC. F'~O. BOX t00560 ANCHORAGE, ALASKA 995i 0 ~ ~') DATE' ' 8-...-89 REFERENCE' ARCO CASED HOLE FINALS i-i A 8-i 2-89 t -t A 8--i 2.--89 i -i 9 8-i S-89 4-6 8- t 0-89 4-6 8-t0-89 .5-i t 8-i ,1-89 .5-t i 8--i 4-89 -.5-t 8 8-i 0-89 9- i.,.:" 8-2-8? 9-t 8 8-3-89 9-t 9 8--4-89 9-25 8-4-89 --i i-27 7-2-89 i 6-1 8-7-89 i7-.5 8-9-89 t 8-~ G 8-.5-89 CET-THICKNESS CORR. PROTECTION EVAL. COLLAR/PERF COI_LAR BRIDGE PLUG DIFF~ TEMF' [;NL_--GAMMA CET INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION F'ROFILE DUAL SPACED NEUTRON INJECTION PROFILE COLLAR/F'ERF I'EMP/WHU'I' SURVEY PLEASE SIGN AND REI'URN THE ATTACHED COF'Y AS RECEIF'T RUN ', ~ R_IN RUN RUN RUN RUN RLJN RUN RUN RUN RUN RUN RUN RUN RUN RUN OF:' DATA 2CH $CH Al'LAS AI'I_AS ATLAS ATI_A£ ATLAS $CH CAMCO CAMCO CAMCO CAMCO HL$ CAMCO ATLAS CAMCO RECEIVED BY HAVE A NICE DAY! ~P~i~P'~ , , , Alaska Oil & Gas Ccn DISTRIBUTION CENTRAL FILES ~- F'HII_LIF'S CHEVRON PB WELL FILES D & M R & D EXTENSION EXPLORATION ~ ~ BF'X EXXON ~'~ STATE OF ALASKA MARATHON ~ .- TEXACO MOBIL THE ' " ..... - _ ~. CORRECIE'.D AF'I~ FOR 5-it IS 50 029-':-?-0':)5.'). THE CORRECTED AF'I~ FOR ?-i~? IS 50-027--n0') ARCO AI...A..~K A , F'.,O, BOX i ANCHOR. A ,.,,E AI...A..~'K A 9 9..'5 t (-) DATE' 4-2~-R8 RFEr,."E. iRENCE' ARC~ CA..~'[:]D HNI.F' F'T. NAI. IN.J[[CTIlF)N F'F?FIFIlI.F!~/TFMF' .?I!t:('VFY RI.IN t . I,JHI./T I:'OF~' ,~'AMF'I.t.:' VFF-?Tr,rTFiATI'FIN RI. IN t. ..~"f'A-F :[ C TF:HI:'r-.!:F;.'ATI.IF~'F". I:~'I.tN t., %" F't...E'A,gF ,~("I'~N AND r-;.'l.:.-Tl'llRN TI-IF. R E [.-. t!:: ]: W' Ii:' I) [-:~ Y 1--IAVIF A i'JTCIF' DAY~ F' E [; [..~ Y F-.; E N N [-.-. T "F A '1" O- 1 5 ? ~ At':FItT'D A%; r-~.. TPT F1F DA'FA T F;.'. A N,.? ~88248 _~ A F:' F' F;.' 0 V I-:: i) .................................................................... l) .T. STF4' ]7 l:~[.J T T F:AMCF] ['iAM~F! CAMCO F.,'E:NTRAt... FII...:F.S P. H F' ~,/R' .Fi N :,",: EYTE'..NYTON E,V,F'I.. ('/r('ATION -.'"' EX×'ON MAR'A'THON .,.'"'M 0 F~ I 1... ""' F'H'[t..I T "'~" · ~? , .. r" .;~ F' F~ IJ F I I I-T 'r t I::' X' ,:(' A I:' F: .? T AT E'. F. IF' TFYAP. n :'-- STATE OF ALASKA '-" 0 R I 6 ! N A ~ ALASKA'~.,,~- AND GAS CONSERVATION CC -~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE ~ WATER INJECTOR 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 77-40 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20260 4. Location of well at surface 9. Unit or Lease Name 525' FSL, 250' FWL, Sec. 1, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1316' FSL, 1567' FEL, Sec.12, T10N, R15E, UM 9-19 At Total Depth L11. Field and Pool 930' FSL, 1353' FEL, Sec.12, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 54' I ADL 28327 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 12/02/77 12/23/77 12/28/77' I N/A feetMSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. DirectionalSurvey I 20. Depth where SSSV set I21.Thickness°fPermafr°st 11934'MD, 9275'TVD 1t862'MD, 9226'TVD YES ~ NO [] 2215' feet MD 1900' (approx) 22. Type Electric or Other Logs Run DIL/BHCS/GR/CCL, FDC/Cal/GR, GR/CCL/CNL, FDC, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE :TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surf 100' 30" 258 sx AS II cmt 13-3/8" 72# N-80 Surf 2714' 17-1/2" 5300 sx AS cmt 9-5/8" 47# MN-80/ Surf 11905' 12-1/4" 1000 sx Class G & 300 s:< AS cmt Soo-95 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None open to production 5-1/2" 11166' 11051' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Acidized perfs f/113½7'-11638' 1400 gal of 12% HC1 Squeezed perfs f/113~7'-11638' 685 sx Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A I njecti ng Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED ~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE 28. CORE DATA None · ~,!-,; ,., ~ " .... ~aska 0il & Gas Cons. C0mm-s-0r; Anc!]orage · Note: Perforated wel] 2/20/78. Add perforations 5/11/84. Workover performed, well acidized & all perforations squeezed 2/11/88. Submit in duplicate Form 10-407 CONTINUED ON REVERSE SIDE Rev. 7-1-80 STATE OF ALASKA ..... ALAL , OIL AND GAS CONSERVATION COIV~ ..;SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging ~ Perforate [] Pull tubing Alter Casing [] Other E~ WORKOVER 2. Name of Operator ARCO Alaska~ Inc, 3. Address P.Oo Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 525' FSL, 250' FWL, Sec. 1, TION, R15E, UM At top of productive interval 1316' FSL, 1567' FEL, $ec.12, TION, R15E, UH At effective depth 974' FSL, 1378' FEL, Sec.12, TION, R15E, UM At total depth 930' FSL~ 1353' FEL~ Sec.12~ TION~ R15E~ UM 11. Present well condition summary Total depth: measured 11934'MD true vertical 9275 'TVD Effective depth: measured 11862 'MD true vertical 9226 'TVD feet feet feet feet 5. Datum elevation (DF or KB) RKB 54' 6. Unit or Property name Prudhoe Bay Unit 7. Well number 9-19 8. Approval number 7-1001 9. APl number 50-- 029 -20260 10. Pool Prudhoe Bay Oil Pool Plugs (measured) None Junk(measured) None Casing Length Size Conductor 72' 20" Surface 2686' 13-3/8" Production 11877' 9-5/8" Cemented Measured depth 258 sx AS II 100'MD 5300 sx AS cmt 2714'MD 1000 sx Class G & 11905'MD 300 sx AS cmt True Vertical depth IO0'TVD 2714 'TVD 9255 ' TVD Perforation depth: measured None open to production true vertical None open to production Tubing (size, grade and measured depth) 5-1/2", L-80, tbg w/tail ~ 11166' Packers and SSSV (type and measured depth) FB-1 pkr ~ 11051' & Bal-O SSSV ~ 2215' 12. Stimulation or cement squeeze summary 13. Intervals treated (measured) Acidized perfs f/11337'-11843', squeezed all perfs f/11337'-11638' Treatment description including volumes used and final pressure 1400 cjal of 12% HCI~ 685 sx Class G N/A Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Workover Wel 1 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. 12-1-85 Title Associate Engineer Date (Dani) SW03/53 Submit in Duplicate Feet ARCO Oil and Gas Company,~, '~ Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field PRUDHOE BAY UNIT Auth, or W.O, no, AFE: AS1932 Operator ~ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 01/26/88 ( TD:11934 PB:ll005 SUPV:RO 01/27/88 ( TD:11934 PB:ll005 SUPV:RO Ol/28/88 ( 3 TD:11934 PB:11862 SUPV:CD- 01/29/88 ( 4 TD:11934 PB:11862 SUPV:CD ICounty, parish or borough NORTH SLOPE BOROUGH Lease or Unit APL: 28327 Title WORKOVER 01/30/88 ( TD:11934 PB:11862 SUPV:CD 01/31/88 ( TD:11934 PB:11862 SUPV:CD 02/01/88 ( 7 TD:11934 PB:11862 SUPV:CD The above is correct Signature For form preparatio~(/and distribution, -- see Procedures MJj(2flal, Section 10, Drilling, Pages 86 ~l'nd 87, DS 9-19 lWell no. API: 50-029-20260 IDate Complete record for each day reported POOL 102 01125/88 JHour 0600 JARCO W.I. 22,0000 Prior status if a w.o. .LD TUBING MW: 8.5 SEAWATER ACCEPT RIG @ 0600 HRS 1/25/88. KILL WELL. ND TREE. NU BOPE. PULL BPV AND SET TEST PLUG. TEST BOP'S. PULL TEST PLUG. PU SPEAR. SPEAR INTO 5-1/2" TUBING. LAY DOWN HANGER. MIX AND PUMP HEC PILL DOWN TUBING. DAILY:S63,450 CUM:$63,450 ETD:$63,450 EFC:$196,020 TIH WITH OVERSHOT MW: 8.5 SEAWATER POOH LAYING DOWN 5-1/2" TUBING. RD CASING TOOLS. CHANGE OUT RAMS TO 3-1/2". TEST TO 5000 PSI. STRAP BHA AND DP. TIH WITH DRILLPIPE AND OVERSHOT. DAILY:S31,994 CUM:$95,444 ETD:$95,444 EFC:$196,020 FISHING MW: 8.5 SEAWATER PU DP. TAG FISH @ 10997'. MILL OVER AND ATTEMPT TO LATCH. NO SUCCESS. CIRC. PUMP HEC HI VIS PILL. POOH. NO FISH. TIH WITH FISHING TOOLS. DAILY:S28,368 CUM:$123,812 ETD:$123,812 EFC:$196,020 MILL PACKER MW: 8.5 SEAWATER MILL OVER AND LATCH FISH @ 10997'. POOH. PUMP 50 BBL HEC HI VIS pILL. POOH. LD FISHING TOOLS AND FISH. 1 1/2 JTS TBG, PBR, K-ANCHOR. MU PACKER.MILLING SHOE WITH PRT 4-3/4" GRAPPLE. TIH. MILL ON PACKER @ 11089'. DAILY:S31,622 CUM:$155,434 ETD:$155,434 EFC:$196,020 POH WITH PACKER MW: 8.5 SEAWATER ATTEMPTED TO RELEASED PRT GRAPPLE. PACKER CAME FREE-POOH. PUMPED 60 BBLS HEC PILL. CONTINUED POOH WITH PACKER. ~¢"~0~ DAILY:S25,788 CUM:$181,222 ETD:$181,222 EFC:8196,020~ ~'?' LD 9-5/8" BRIDGE PLUG MW: 8.5 SEAWATE~.s¥~u LD FISH. MU BRIDGE PLUG. TIH TO 2600'. TESTED CASING TO 1000 PSI. TIH TO 11192'. SET BRIDGE PLUG & TESTED CASING TO 1000 PSI. PU RTTS & sTORM VALVE. SET @ 35'. CHANGED 9-5/9" PACKOF~ & TESTED TO 3000 PSI-OK. LD RTTS. TESTED 9-5/8" CASING TO 2500 PSI. RELEASED BRIDGE PLUG. PUMPED HEC PILL. POOH & LD BRIDGE PLUG. DAILY:S37,140 CUM:$218,362 ETD:S218,362 EFC:$196,020 CIRC. WOC MW: 8.5 SEAWATER INSTALLED WEAR BUSHING.. PU 925' 2-7/8" TUBING. TIH. TAGGED BOTTOM @ 11862'. PU TO 11843' BREAK CIRC. RUB. J. HUGHES. SPOTTED 1400 GAL ACID - LET SET 10 MINUTES. BULLHEADED INTO FORMATION. SPOTTED BALANCED CMT PLUG (360 SX CLASS G). POOH. SQUEEZED 26 BBLS. FINAL PSI 750 @ 1/2 ~. Ci~ ~ 1730 .... 1/31/CC~ ..... PU ........ Date J Title ASSOCIATE ENGINEER I ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially., Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO Alaska, Inc. ICounty or Parish NORTH SLOPE BOUROUGH Lease or Unit DS 9-19 IState PRUDHOE BAY UNIT Date and deptt~ as of 8:00 a.m. 02/02/88 ( TD:11934 PB:11862 SUPV:CD 02/03/88 ( TD:11934 PB:11862 SUPV:CD 02/04/88 (1)) TD:11934 PB:11862 SUPV:CD 02/05/88 ( 1.) TD:11934 PB:11862 SUPV:RWO 02/06/88 ( 1 ~) TD:11934 PB:11862 SUPV:RWO 02/07/88 ( 11 ) TD:11934 PB:11862 SUPV:RWO 02/08/88 (1,i) TD:11934 PB:11862 SUPV:RWO The above is correct Complete record for each day while drilling or workover in progress POOL 102 CIRCULATE. W.O.C. DAILY:S88,606 CUM:$306,968 ETD:S306,968 EFC:$196,020 MILLING ON JUNK/CMT MW: 8.5 SEAWATER CIRC. WOC. TIH & TAGGED CMT @ 11385'. DRILLED CMT AND JUNK F/11385'-11485'. POOH. PU MILL & JUNK BASKET. TIH. TAGGED JUNK @ 11485'. MILLED ON CMT & JUNK @ 11485'. DAILY:S25,477 CUM:$332,445 ETD:S332,445 EFC:$196,020 POH FOR BIT MW: 8.5 SEAWATER MILLED ON JUNK & CMT FROM 11485' TO 11503'. POOH. PU 8-1/2" FLAT BOTTOM MILL. TIH. MILLED ON JUNK & CMT TO 11509'. WORKED ON ROTARY GEAR. POOH FOR BIT & ROTARY REPAIR. DAILY:S29,442 CUM:$361,887 ETD:S361,887 EFC:$196,020 DRILLING CEMENT MW: 8.5 SEAWATER POOH. BREAK OUT MILL & JUNK BASKET. WORKED ON ROTARY INPUT GEAR. TIH. SLIP & CUT DRILL LINE. TIH TO 11509'. DRILLED CMT F/11509'-11700'. DAILY:S26,709 CUM:$388,596 ETD:S388,596 EFC:$196,020 WORKING ON BREAK DRUM MW: 8.5 SEAWATER DRILLED CEMENT TO 11710'. CIRCULATED HI-VIS SWEEP. TESTED PERFORATIONS. BROKE DOWN @ 1000 PSI. CIRC. POOH. STRAP & PICKED UP TUBING. TIH. SLIP DRILL LINE. TIH. REPAIRED GLYCOL LINES ON BRAKE DRUM. REPLACE BRAKE BLOCKS. DAILY:S34,592 CUM:$423,188 ETD:S423,188 EFC:$196,020 TIH MW: 8.5 SEAWATER WORKED ON BRAKE DRUM. CUT DRILL LINE. TIH. MIXED & PUMPED 325 SX CLASS G CMT. SQUEEZED APPROX. 1BBL CMT INTO PERFORATIONS. RD BJ. PRESSURED UP WITH RIG. RE-SQUEEZED. FINAL SIP 1275 PSI. BLED OFF PRESSURE. POOH. MU BHA & TIH. DAILY:S58,167 CUM:$481,355 ETD:S481,355 EFC:$196,020 I~or form preparation ,~nd distribution see Procedures Man~'jll Section 10, Drilling, Pages 86 an~ 87 Well no. FINISHED TIH. TAGGED CMT @ 10813'. DRILLED FIRM TO HARD CEMENT F/10813'- 11700'. CIRC. HEC HI-VIS PILL. TESTED SQUEEZE ON PERFS TO 1400 PSI. WOULD NOT HOLD. AFTER 5 MIN. BLED BACK TO 600 PSI. INJECTION RATE APPROX. 1/4 BP. , DAILY:~26,359 CUM:$507,714 ETD:S507,714 EFC:$196,020 , .i:~sk~ (iii & gas Cons, Commis~io:~ LD RTTS MW: 8.5 SEAWATER POOH. TIH. DRILLED CMT F/l1700'-lL807' CIRC. HI-VIS HEC PILL. POH. PU RTTS & RIH TO 2600'. SLIP DRILL LINE. TIH TO 2600'. SET RTTS. TESTED FO'S & ANN. TO 2500 PSI-OK. U~h:$536,961· --=-: T,tle~£U $53~,'967 EPC:~z96,020 f-f3-~ ASSOCIATE ENGINEER ¸lO ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District iCounty or Parish I State ARCO Alaska, Inc. ~ NORTH SLOPE BOUROUGH I AK Field JLease or Unit PRUDHOE BAY UNIT ~ DS9-19 Complete record for each day while drilling or workover in progress POOL 102 Date and deptl~ as of 8:00 a.m. 02/09/88 ( 1 TD:11934 PB:11862 SUPV:RWO 02/10/88 ( 1 TD:11934 PB:11862 SUPV:RWO DROP BALL TO SET PKR MW: 8.5 SEAWATER FINISH LAY DOWN RTTS. PU BHA AND SCRAPER TIH. CIRC HI VIS HEC PILL W/ CLEAN SEAWATER W/ C 195. POOH. MU TAILPIPE AND BAKER FB-t PKR AND TIH W/ 3-1/2" DP. CUT DRILL LINE. TIH. DROP 1-7/16" BALL. SET PKR AT 11050' DPM. DAILY:S30,637 CUM:$567,604 ETD:S567,604 EFC:$196,020 RUN 5-1/2" TBG MW: 8.5 SEAWATER PRESSURE TEST PKR AND 9-5/8" CSG TO 2500 PSI FOR 30 MIN. BLEED OFF PSI. POOH LAY DOWN 3-1/2" DP. PULL WEAR BUSHING, CHANGE 3-1/2" RAMS TO 5-1/2" RAMS. TEST TO 3000 PSI. RU GBR AND RUN 5-1/2" TBG, SEAL ASSY. DAILY:S25,263 CUM:$592,867 ETD:S592,867 EFC:$196,020 IWell no. The above is correct For form prepar~on and distribution See Procedures~anual Section 10, Drilling, Pages 8'6 and 87 IDate ITitle ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO Alaska, Inc. Field PRUDHOE BAY UNIT Auth. or W.O. no. County or Parish NORTH SLOPE-PRUDHOE BAY ILease or Unit ADL: 28327 ITitle WORKOVER IAccounting cost center code State AK Well no. DS 9-1~ API: 50-029-20260 Operator ARCO Spudded or W.O. begun ACCEPT A.R.Co. W.I. 22,0000 Date I otal number of wells (active or inactive) on this DSt center prior to plugging and bandonment of this well our I Prior status if a W.O. I O600 01/25/88 Date and depth Complete record for each day reported as of 8:00 a.m. POOL 102 02/11/88 ( 1 TD:11934 PB:11862 SUPV:CD RIG RELEASED MW: 8.5 SEAWATER CeNT RIH W/COMP ASSY. MU SSSV. TEST CONTROL LINES TO 5000 PSI. CeNT RIH. STING IN. VERIFY W/ 00 PSI. SPACE OUT. MU FMC TBG HANGER. DISPLACE WELL W/150 BBLS DIESEL. ALLOW DIESEL TO U-TUBE TO BALANCE. LAND TBG. TEST ANNULUS TO 2500 PSI.. TEST TBG,_T~O~3009__~S~I. SET BPV. ND BOPE. NU FMC 5-1/2" GEN I TREE. TEST TREE TO 5000 PSI. SHEAR OUT BALL AT 3500 PSI. SET BPV. SECURE WELL. RIG RELEASED AT 0400 HRS, 2/11/88. (SSSV @ 2215', FB-1 PKR @ 11051', TAIL @ 11166') DAILY:S217,077 CUM:$809,944 ETD:S809,944 EFC:$196,020 Old TD J New TD I PB Depth Released rig IDate IKind of rig Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Producing method I Officia~ reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production (~il' on test Gas per day Pump size, SPM X length Choke size T.P, C,P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature J Date ITitle For form preparati/~ and-distribution, see Procedures M~hual, Section 10, Drilling, Pages 86 and 87. ASSOCIATE ENGINEER 20 AAC 25.O:30(8) 20 &AC 25.&12(c) 2O ,M~ ..~ ~/~.~~v-~ ..~ 2[, i,q -t~ . ~lt~ l c~ -~ PAl "" STATE ANNULUS TESTING DATABASE FOR PRUZMfOEtLISBURNE INJECTION IYE].LS 1988 AHNULAR TESTS TU~BII4G PACKER TEST LAST TEST WEU. __ ANNULIJtS FLUID _ SIZE MD'ITVD'_ ...... CASI~ ......... PRESS. _ DATE [ __L [ .... , [ [ -- _ L . · -; X[-~_ i -- Ill Jill i 1[ -- 4..6 ?r~.,di~+"lO.4,~ _ _5-!/2. 10487/7834 9-5~."', .... 47#, MN.-8.O .... 15o0 1./,8/88' , .,, -- .1,2-2. "' 0~---~ 7.'. 1167318464 ....... 9-5/8', 47#, L-80 ................. 306.4 2/28/88'. . ~.2..27"'./. ,,, lO~,'_hb~d;:~l+8.SNa~, , ...5'.1/2' 8,900~,,83,,9,4 9-5/8', 47#,...L-80 .............. 2505' I./1/8,8: , ,/ - * ~", 47#, .L'~. NSCC .lo 2200, N-80 1o 7TX~' 2493 3/30,./,B8 ,. 9-18 51 ~ d~[ + 9.5 .I~_CI ..... . .8705-8.482 ..... ~ 8.SNa~ 5 1/2' 11051/8668 9-.5/8.'~ 47#, sOO-95 to ;~20r, ,~,~50 Io ~_.~4~_6, 2565 2/1 1/88' o.~,.~ ,~ ~ ~ ~--~--~ +,, . , ,- ' ...... ............. " , !6.16'/,,,,,, 76 _k~d~_ diase$+ S-6, .,, , . INlaCA , ,,,, ,. ,,5'1t2', . , . _9826/.8.4,38 9-5/8,., 47~, .L-BO ............... 2~,2,,3 3/8185', , 1.2..10 '/ D~--~[ 2:.7~'6" .95.Gg./8.5_7.5. 9-5J8', .47.~, L-BO ............ 3t~4 3/.6/88 ... ~- L2.,24/, (~,n__~,, . _ , , ., ,,.. 2-.7./.a' 9~.40../_~.~p(;. 9-5~s', 47~, L-CO............. 2e~5. _ ~/' 7" .......... . ....... NGt-6 ' 51 ,':_-~-d-?--~ + 9..4. ~ . . .......... 806.617426 9-5/8", 47~, ldN-80 1950 2/8/6e' '"7' ~ 4153', 5-1/2' below Page 8 Revis~cl 4,/14Y88 STATE OF ALASKA ALA_ .,A OIL AND GAS CONSERVATION COt. ,ISSlON 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 C Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 5z~' feet 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510-0360 Prudhoe Bay Unit 4. Location of well at surface 525' FSL, 250' FWL, Sec. 1, T10N, R15E, UN At top of productive interval 1316' FSL, 1567' FEL, Sec.12, T10N, R15E, UN At effective depth 974' FSL, 1378' FEL, Sec.12, TION, R15E, UM At total depth 930' FSL, 1353' FEL, Sec.12, TION, R15E, UM 7. Well number 9-19 8. Permit number 77-40 9. APl number 50-- 029-20260 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 11934 ' MD feet 9275 ' TVD feet Effective depth: measured 11 862 'MD true vertical 9226'TVD Casing Length Size Conductor 72 ' 20" Surface 2686 ' 1 3-3/8" Producti on 11 877 ' 9-5/8" Plugs (measured) None feet feet Junk (measured) None Cemented Measured depth 258 sx Arcticset 100'MD 5300 sx Arcticset 2714'MD 1000 sx Class G 11905'MD Rue Verticaldepth 100'TVD 2714'TVD 9255'TVD Perforation depth: measured 11337'-11346', 11364'-11384', 11414'-11454', 11465'-11505', 11528'-11542' 11576'-11606', 11621 '-11638' true vertical 8873'-8879,, 8891 '-8904,, 8914'-8948,, 8956~'~..-8f~,65',~,' 9001 '-9010,, 9033,-9053,, 9062'-9074, Tubing (size, grade and measured depth) r'~:- ~'~: ?~....., .:-.. ~ ' 5-1/2", 17#, N-80 ~ 11091'MD; 4-1/2", 12.6#, N-80 ~ 11207' (tail) Packers and SSSV (type and measured depth) ~,.,,&~'~:'.L i~i~ (~: ~ :.:..~t~,~ ~ ~,~:, ,,,,~;';'¥'~: Baker SAB ~ 11079'MD, 5-1/2" Otis ROY SSSV qipple. (~ 2196' . . 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation January 10, 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~z, ~ ,~£/)~.Z,,,,' Title Associate Enqi neer ~ Commission Use Only ( DM L ) SA3/39 Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by i_~ ¢ ~ Form 10-403 Rev 12-1-85 Approved Copy Returned Approval No. ..~_..,,/,~/?~/~// , Commissioner by order of the commission Date Submit in triplicat~j/. APPLICATION FOR SUNDRY APPROVAL PBU DS 9-19 PRELIMINARY WORKOVER PROCEDURE OBJECTIVE' Remove leaky 5-1/2" tubing, mill up packer, cement squeeze perforations and clean out to PBTD. A 5-1/2" Class B completion string and 9-5/8" packer assembly will be run. 1) MIRU Pool 102. Kill well with seawater. 2) ND tree. NU and test BOP. 3) POOH and lay down 5-1/2" tubing. 4) Retrieve BOT PBR assembly. 5) RIH and mill SAB packer. CBU. POOH LD packer/tailpipe. 6) RIH with test packer and test 9-5/8" casing to 2500 psi. 7) RIH open ended and perform isolation squeeze across all perforations. 8) TIH w/bit and cleanout to original PBTD at 11862'. CBU. 9) Test squeeze to 1000 psi. 10) RIH with DP and set new packer. POOH LDDP. 11) RIH with 5-1/2" IPC tubing and SSSV. 12) Set BPV. ND BOP. NU tree and test. 13) Test tubing to 3500 psi and annulus to 2500 psi. 14) Release rig. Anticipated bottomhole pressure' 3800 psi Workover fluid: 8.5 ppg seawater SA3/39a 12/23/87 6 PIPE RAfI S BLIND RAILS 4 I'UelNe HEAD ~5 2 1 I$-$/8" CASIN~ HEA0 2. 9-5/8" CASING HEAD ~. 5000 PSI rUBIN6 HEAD 4. 15-5/B' - S000 PSI BLIND RArl$ 5. 1]-$/8' - 5000 PSI PIPE 6. 13-'5/8" - 5000 PSI ANNULAR ACC LATOla CAPACITY TEST I. ¢l, llCl~ ~ FILL ACCl,e'IAATell ~ TO ~ LEVEL ~'rl, i H~IC FLUIO. 2. ASSUlaI 'ri,tAT AC:~T01~ ~ I$ 3000 ~ ~1'~ 3. (18,~lg~ ~. THENCLOM 4LLWIT~ ~UL?JJEEOU~Y &ND I:~COAD T)E Title AND IWIE~ iitMleNe MITIA ALL WITIJ 4. I~COWI) OW TI, Il lAIN: {II~. ~ ACCEWI'MLE LOWEW LII'#1' I~S~JI~E. I~P STACK TEST 1. FILL BOP STACK ANO PIANIF~LD WITH AII~TIC DIESEL. 2. CHECK I'HAT ALL MOLD-00WN $C~ AI~ FULLY laETRACTED, ~REDETER~NE DEPTH THAT TEST PLtJ~ WILL SEAT AN0 SEAT IN WELLHEAD. laUN IN LOC~-D0WN SCREWS IN HEAD. ~5. CLOSE ANNULAR PREYENTEla AND CHOKES AND BYPASS VALVES ON THE I'~ANIFOLD. 4. TEST ALL C0rIPONENTS T0 250 PSI AN0 HOLD FOR 10 MINUTES. $. INCREASE PRESSURE T0 2500 PSI AND MOLD FOR 10 I~INUTES. BLEED T0 ~RO 6. OPEN ANNULAR PREVENTE~ AN0 CLOSE TOP SET OF PIPE RAftS. 7. INCREASE PRESSL.'IaE T0 5000 =$1 AND HOLD FOR l0 MINUTES, 0. CLOSE VALVES DHaECTL~, u~STlaEAr'l OF CHOKES. BLEED D0WNSTIaEA~-' PRESSURE TO ~RO PSi TO TE~T VALVES. I'EST ~EMAINING UNTESTE~ r'IANtFOLD VALVES, IF ANY. ~ITH $000 PSI UPSTREAr'I OF VALVE WITH ZERO PSI DOWNST~E,~r! BLEED SYSTEi"I TO ZERO PSI. 9. OPEN PIP~. .o, AI~S ~AC.~0FF ~UNN~NG JT ANO PULL OUT OF HOLE. CLOSE BL'.N0 ~,Ai'I.S A~O ~E~T T3 ~000 PSI F(~ ~0 MINUTES. 8LEF, D 10, OPEN ~,LIND ~API$ AN0 I~ECO',;ED TEST PLUG. HAKE SURE MANIFOLD LINES AI~E .:ULL OF AI~CT,C DIE3EL AND ALL VALVES APE SET IN THE DI~ILLIt'4G POSITION. J J. TESI'STANDPIPE VALVES TO 5000 t~$1. !2. TEST KELLY COCKS AND iNSIDE B0P T0 ~000 PSi WITH KOOrqEY !3 ~ECORD TEST INF01~I'IATION ON BLOWOUT PI~EVENTEIq TEST ANC) SEND T0 !4 PEI~FC~qr'I cor~PLET:, ~OPE TEST' ONCE A WEEK AND FUNCTIONALLY r~ .... · UG N0VEMBER. 21, I !::' ... ~;:o x t 0 (i:, 3:6 0 ~-.~ ~ ~ c. h (::~ Y' a ::;j e, A 1. a 5 k :.-'1 Fi.'. g. T'i . 'i, t::.' II ....' RECEIVED AUG- 5 1986 Alaska Oil & Gas Conm. Oommlmslon Anotmmge Max. Injection Rate During Well Last 3 Months {BWPD) J3-11 8000 INJECTION WELLS WITH ANNULAR COMMUNICATION EOA - PRUDHOE BAY FIELD Surface Pressure at Maximum Rate (psig) Tbg 9-5/8" Cs9 13-3/8" Cs9 1200 1200 0 3-12 33000 1100 1100 400 3-17 19000 9-12 16000 800 800 100 Probabi 1 i ty of Passing State Test Low Medium Medium 900 900 0 Low 9-14 36000 1300 1300 9-17 27000 1100 1100 9-19 28000 16-2 7000 ~/16-11 7000 200 None Low 1200 1200 0 High 800 1200 0 Medium 1100 1400 , ,' 200 '-~ ' Low Comments 9-5/8" pressure responds immediately to changes in tubing pressures Bled 9-5/8" pressure from 875 to 455 psig in 3 minutes', built up 80 psi in ~i I hour, built back up to 860 psi in 20 hours. Bled 3 Bbls oil and gas from 9-5/8" in 10 minutes, pressure decreased from 1050 to 200 p~i, built up 120 psi in I hour built back to 1000 psi in 18 hours. Bled 9-5/8" pressure from 795 to 350 psi, built up 200 psi in I hour, built back to 800 psi in 5-1/2 hours. Parted tubing at 13'. Bled 9-5/8" pressure from 625 to 250 psig, built back to 625 psi in I hour~.~ Bled 10 gals of H~O from 9-5/8" pressure decreaseU from 220 to ~ psig, built up 80 psig in 4 hours. Bled 40 gals diesel from 9-5/8", pres- sure decreased from 880 to 500 ps i g, built up 50 psi in I hour, built back to 850 psig in 10 hours. Has gas lift mandrels. 9-5/8" pressure responds immediately to changes in tubing pressure. Has gas lift mandrels. R.1N4/16 ~EL5: 9-~9 SPUD 2ATE: 12-2-77 SURFACE LOCATION: 525' N, & 250'E of SW CF. SEC. 1. T lON. R 15£. ~(~l'r~ HOLE LOCATION: 930' N ~ !353' w of SE CF. SEC. I2. TIO ~;. R !SE. UM .'i~':?i ORIGINAL RKB: )4' i ......RKB TO OCT HANGER "' TOP OF SADLEROCHIT: 11336' HD HOLE ANGLE THROUGH SADL~ROCHIT: 47o COMPLETION RUN: 12/27/77 API# 50-029-20260 ALL D~PTHS ARE RKB MD Depths are to TOP of equipment 26' 5½", 17#, N-80 NOT PLASTIC COATED Tubing 5½" x 9-5/8" Annulus Fluid: 10.6 CaCl2 & Diesel 2196' Otis RQ¥ ~2373' 9-5/8" FO . 2504' g-5/8" FO SSSV Nipple iD ~.562 2714' 13-3/8", 72#, N-80 w/ 5300 sx 10967 Otis XA ~liding Sleeve 11035 Otis XN Nipple 11042' BOT PBR Ass~nbly 11079 Baker SAB Packer 11150' Otis XN Nipple ID 3.813" 11206' Baker Shear Out Sub 11207' Bottom of 4½", 12.6#, MN-80 Tailpipe RECEIVED Alaska Oil & Gas Cons. CommJssio~ Anchorage 11337 11366 11414 11465 11528 11576 11621 - 11346 - 11386 - 11454 - 11505 - 11542 - 11606 - 11638 B~=E ZnNF E_T_ S9..E BHCS ~ 9 4 BHCS 3 20 4 BHCS 3,2 ~0 4 BHCS 2 40 4 BHCS 2 14 4 BHCS 2 30 4 BHCS 2 17 ~ C~MMFNT~ 2/20/78 5/11/84 2/20/78 2/20/78 2/20/78 2/20/78 2/19/78 11862' PBTD 11905' 9-5/8", 47~, MN-80 & S00-95 w/ 1000 sx 11934' TD 6/84 INJECTION WELLS WITH ANNULAR COMMUNICATION EOA - PRUDHOE BAY FIELD. Well Max. Injection Rate During Last 3 Months -/-~ (BWPD) ,./ 3-11 ,x/e~ p 8000 3-12 /d~ P 33000 3-17 pA~,'c 19000 9-12 ?/~v. 16000 9-14 me~-/") 36000 q-17 hd- P 27000 9'-19 /vofP 28000 16-2 ?/~ 7000 v 16-11 pl~,~v._ 7000 Surface Pressure at Maximum Rate (psig) Tbg 9-5/8" Csg 13-3/8" Cs0 1200 1200 0 1100 1100 400 800 800 100 900 900 0 1300 1300 200 1100 1100 0 1200 1200 0 8OO 1200 0 1100 1400 200 Probabi 1 i ty of Passing State Test ~/~tow ~4edium l~?Medium ¥':"None ~ High · ed~um Comments 9-5/8" pressure responds immediately to changes in tubing pressures Bled 9-5/8" pressure from 875 to 455 pstg in 3 minutes, built up 80 pst in 1 hour, built back up to 860 psi in 20 hours. Bled 3 Bbls otl and gas from 9-5/8" in 10 minutes, pressure decreased from 1050 to 200 pst, built up 120 psi in 1 hour built back to 1000 pst in 18 hours. Bled 9-5/8" pressure from 795 to 350 psi, built up 200 psi in 1 hour, built back to 800 psi in 5-1/2 hours. Parted tubing at 13'. Bled 9-5/8" pressure from 625 to 250 pstg, built back to 625 psi in 1 hour. Bled 10 gals of H~O from 9-5/8" pressure decreasetl from 220 to ~ psig, built up 80 psig in 4 hours. 9-5/8" pressure responds immediately to changes in tubing pressure. Has gas lift mandrels. Bled 40 gals diesel from 9-5/8", pres- sure decreased from 880 to 5.00 pstg, ~,,~ built up 50 psi in I hour, built back to 850 psig in 10 hours. Has gas lift mandrels. R,1N4/]6 ALL DEPTHS ARE RKB HD Depths ar~ to TOP of e~uipment ~1336'__ HO HOLE ANGLE THROUGH SADLERCC~[T: C01qPLETION RUN: I2/27/77 API t 50-029-20260 I. T !~N. R !SE. ~ HANGER 47o 5~", 17#, N-80 NOT PLASTIC COATED Tubing 5~" x 9-5/8" Annulus Fluid: ~0.6"CaC12 & Diesel 2196' Otis RQ¥ SSSV Nipple iD ~.562 . , 2373' 9-5/8' FO . 2504' 9-5/8" FO 2714' 13-3/8-° 72#, N-80 a/ 5300 sx 10967 Otis XA ~lidtng Sleeve 11035 Otis XN Nipple 11042' BOT PBR Assembly 11079 Bake~ SAB Packe~ 11150' Otis XN Nipple ID 3.813' 1:206' Baker Shear Out Sub 1~207' Botto~ of ~", 12.6w, HN-~O Tail~ioe 11337' - 11346' 8HCS 4 9 ~ 11366' - 11386' BHCS 3 20 4 11414' - 11454' BHCS 3,2 40. 4 11465' - 11505' BHCS 2 40 4 11528' - 11542' BHCS 2 14 4 11576' - 11606' BHCS 2 30 ~ 11621' - 11638' BHCS 2 17 ~ 2/20/78 5/11/84 2/20/78 2/20/78 2/20/78 2/20/78 2/I9/78 11862' PBTD 1~905' 9-5/8", 47#, MN-80 & S00-gS w/ 1000 sx 1193¢' TD 6184 ARCO Ataska, inc...~'--~. Post Office ~ 60 Anchorage, A~,,oCa 99510 Telephone 907 277 5637 December 13, 1985 Reference: ARCO PresSure Data DS 9-18 9-29-85 ~ DS 9-19 9-29-85 DS 9-25 9-19-85 .~DS 9-27 10-3-85 Surface Pressure Fall-off Surface Pressure Fall-off Surface Pressure Fall-off Bottom Hole Pressure Survey ARCO ARCO ARCO DA Please sign and return the attached copF as receipt of data. Kelly McFarland ATO-!429F Trans # 526 DISTRIBUTION Chevron ~D&M Exploration Services Phi 1 lips Prudh~ Bay Files R&D Extension Exploration "Sohio Marathon Mobil S=ate of Alaska Texaco · ARCO Alaska, inc. Post Office Box 100360 ~;i' Anchorage. Alaska 99510 Telephone 907 276 1215 DAte: August 21, 1985 REference: ARCO CH Finals '"-~1-8 j Spinner ~6-9 ~ Temp ~9-8-- Spinner X~D9-12/Spinner x~..j~ ~. / ~ ~pinner ~-J'"~-~13-6 Spinner ~15-20~Spinner "'"~ 5- 2 0 ~ollar ~x'-~16_10'Spinner 8-15-85 Run 1 5" Camco 7-31-85 1 5" GO 8-8-85 1 5" Otis 8-8-85 1 5" Otis 8-8-85 1 5" Otis 8-7-85 1 5" Otis 7-26-85 1 5" Otis 7-15-85 1 5" GO 7-25-85 1 5" GO Please sign as receipt of data. Received by F AUG 2 ? l~§ ~ Pam Lambert ATO 1429C OdS Cons. Commission Anchorage Trans 282 Chevron D&M Expl. Services Ext. Exptoracion Exxon Mara chon Mobil Phillips PB Well Files R & D Sohio rState-'of Alaska~- Texaco ARCO Alaska, Inc. Prudhoe Bay [ neering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 22, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-6 DS 3-7 DS 3-10 DS 3-18 DS 4-6 DS 4-8 DS 4-11 DS 4-14 DS 4-15 DS 9-8 DS 9-10 DS 9-12 DS 9-14 DS 9-15 DS 9-16 Permit # 76-60 Permit # 76-53 Permit # 79-21 Permit # 79-103 Permit # 76-42 Permit # 76-10 Permit # 78-6 Permit # 78-36 Permit # 78-37 Permit # 76-70 Permit # 76-82 Permit # 77-7 Permit # 77-25 Permit # 77-36 Permit # 77-37 DS 9-18 DS 9-17 DS 9-19 DS 9-20 DS 11-2 DS 16-1 DS 16-2 DS 16-3 DS 16-5 Permit # 77-39 Permit # 77-38 Permit # 77-40 Permit # 77-41 Permit # 81-128 Permit # 80-136 Permit # 80-150 Permit # 76-83 Permit # 81-37 DS 16-10 Permit # 80-04 DS 16-11 Permit # 80-118 DS 16-16 Permit # 80-127 DS 17-6 Permit # 80-132 DS 17-8 Permit # 81-74 DS 17-10 Permit # 81-97 Dear Hr. Chatterton: Attached are Subsequent Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. S cheve DFS/JEB/mjb RECEIVED Attachments J^ 5 g85 cc: Sohio Alaska Petroleum Company Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc, Is a Subsidiary of AtlantlcRlchfleldCompany STATE OF ALASKA ALASKA ,JIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLX3 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 77-40 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20260 OTHER [] 4; Location of Well 525'N & 250'E of ,.~,~ or Sec. 1, T10N, R15E, [~ 1316'N & !567'W of SE cr Sec. 12, T10N, R15E, 930'N & 1353'W of SE cr Sec. 12, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 54' RKB ADL 28327 9. Unit or Lease Name P~dhoe Bay Unit 10. Well Number DS 9-19 11. Field and Pool Prudhoe. Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO klaska, Inc. has converted DS 9-19 to water injection se~Tice. The well is ~ part of the Flow Station 2 waterfloodproject. The well began rece~ing water on June 14, 1984. Alaska Oi'i & G;.~.s (Joss, Cornmis, 14. I hereby ~':~y/F~/,~F'~,'~ ~/that the~fo,~ng i~ue ~~"//~///~/~ ~//'~)~t° the best of my~kn°wledge' Signed .. ~ '~; ~,,'~"¢,,~'- Title R.__ional En_ineerq The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARC[) ALaska: Inc F'-'.O, Box i Anchor'age: Al.a.z-.'ka DATr-'' l)ecem,h, er' 2~ , i'-.?S'~ D S' .3;--4 '-~"' f i--7-'8'" D,.S; ,.', - I':':'' / ..... -" .... '~ '~ .... ~ -- L::: 4 I),.S'.~ S-'i t-'"' t i--S-"84 .. ,.-~ D., ;' ., ....,'"-'-'~ .~ ! i --L..:;--b'-4 ..f)~ ,S' . 3 -.- t ~'"' i i -- .- ''') -- 84 D,.,?,. 3--i3 i i-.i-.84 D ":" -q .... i --" i i .... i 8--Fj:/, ~.:, D S ";-: '/'' '"' ' ., .~ ? 'i i ,...-'i 2 '" -' C.", I;' 2' ':::' -"':~ i i - 1 8-::'i: 4 ,~. .=. ..' ¢.'= .~.' . D, ,";.-.'., '::: .... '"' ~'"" ! i '- t 8-84 i) v, '4.'; .... ':";.:-"" i 2! -' 8 -" 84 . ,:.. ........ .'., i ! ! 9 ...."3,4 O t"' ~ " ' . ,.., ....... c:,' I 2 -' i '-'-' c> ,'~ 1".',, .,R., 9-"";:""" 'i 2-i ¢-84 D c, o 'o../ "3'-"84 ,.¢, ,--'] ,.' i:?: .... D,,S, f3-'24w~ i2-5--84 D '"' I S-" S 2 i "':'-"':": "':::' '"/' . D 5: i 4-'-":""" ., ., ,.:.: .-:' i L -' ,:':, -- ;:::; ':':' "":' .~ /:.... C:' A D,,~.r', t4-27 ..... 4,._. ,. .... -.,. D, S ,. i 4--S6- i 2.--6-8,q- ..... i--¢"' --4 .... 8 4 I;,.S, t ! '/"~.ea~e ~: i gn and 'r'e±u'r'r'~ · ' ~" ' "" ' t:;'. u.'n i C.F .',/.': I:., i 'nner ~' ~ ':." / t~ ) ' u,l ,-"-:',>'t I T~I](.¢I' ~',U.l'i i -.:' i) i f f Te mr.:, L ;';-.:, F',.'. ...... ~..:, i f f T e m p F.: u. 'n I 5" CI::'S,'/S::p i n'ne'r ...... l:;.'.~,r~ i =:," C F:' S/S.-.' p i n 'n C N / M S:.' / G R F;: u.'n S 5" -- 5'p inner -- -' ¢ I::' Il C N / M :';' / [; R R u. 'n 'I .;. C i'~ / i'i ;? / C;- R R ,S." F:: i 'n'n e '.,- L. o g R u 'n i 2" '" :: t S"'~ Cr;,, r',,S'/'[;R. Run i ...: ~:F., i 'r',r~erL_og ,":Tp i'nne'r L. ocj Ru.'n 'i 2 ~' F:' ' ' ' ... ,. 'n j r c:, f '"':" I:-'- i 'n n e ~" / T e m[:, / I I.., .. C.p i'n'ne'c/Temp/I'nJ F"co1"'i te t:;:.~'n i ~""" ~.:. .... ,. ]:ni F'rofi ,? p i 'n'n e'r' L. c, g F;..' u. '.,"~ i ::?." F:"rofi L ~.o: · ,_.Ff..:/Sp ~ n',.'~e'r F;:. u'n 'i 5" D i 'I" i"' ]"e m F' L o g P, u. 'n i ...:.~"" .4. j..te .a'4'4' __ : r:, (:la .a.~ ,. : : a c: J"., e cJ c o F:' Y a z-:: l' ,'::' r: e i ;::' 4. _ 4,.- -I' KeLLy McFar l.a~:.; A '¥' Fl.. --. 1 4 '2 '':~,. f:' Ch evF o'rl D & f"/ E'xpt. o'ra't:io'n Services [." x -t: e n ~ i o'n E x ~::, I. c:,'r a t' i o r, E x x o n Get '~ y ~'.I ;a 't' , ~ F' S h o iq Hol::,i i. E F'hi L i. ip':i: F:"r u cl h o e i:;~ & :'-?c,h i c, ,i....' ".r a i' e o f ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 26, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-1 DS 9-3 DS 9-8 DS 9-11 DS 9-13 Ds 9-19 Permit No. 75-76 Permit No. 76-35 Permit No. 76-70 Permit No. 76-84 Permit No. 77-8 Permit No. 77-40 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/kg Enclosures cc: SOHIO Alaska Petroleum Co. File Pi(DS 1)W4-3 File PI(DS 3)W4-3 File Pi(DS 8)W4-3 File Pi(DS 11)W4-3 File PI(DS 13)W4-3 File P1 (DS 19)W4-3 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 Classification of Service Well Water Injector 7. Permit Number 77-40 8. APl Number 50--029-:20260 4. Location of well at surface 525'N & 250'E of SW cr, Sec 1, TION, R15E, gM At Top Producing Interval 1316'N & 1567'W of SE cr, Sec 12, T10N, R15E, UM At Total Depth 930'N & 1353'W of SE cr~, Sec 12~ T10.N; R15E~ UM 5. Elevation in feet (indicate KB, DF, etc.) ~_ Lease Designation and Serial No. 54' RKB ADL 28327 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 11934'MD - 9275'TVD 11862'MD - 9226'TVD YES ~ NO [] 2203 feet MD 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 9-19 (34-3._2_-10-15) 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool -15. Water Depth, if offshore 116' No. of Completions N/A feet MS L .... 21. Thickness of Permafrost 22. Type Electric or Other Logs Run DIL/BHCS/GR/CCL, FDC/CAL/GR~ GR/CCL/CNL~ FDC 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE 20" 9Mkweld H40 13-3/8" 72#Butt N80 TOP Surf. S~lr f. Surf. BOTTOM lO0' 2714' 11905' 47~Butt ~'480 & S0095 9-5/8" HOLE SIZE 30" 17~" 12~" 25. SIZE 5~" 26. DEPTH INTERVAL (MD) N/A PRODUCTION TEST 24. Perforations open to Production (MD+TVD of Top and Bottom and and number) *New perfs w/4spf 8875 - 9074' TVD 27. interval, size 11337 - 11346' MD (9') *11366 - 11386' MD (20') 11~14 - 11454' MD (40') 11465 - 11505' MD (40') 11528 - 11542' MD (15') 11576 - 11606' MD (30') 11621 - 11638' MD (17') 1900~± CEMENTING RECORD 258 sx Arcticset II cmt 5300 sx Arctic cmt 1000 sx Class G cmt AMOUNT PULLED TUBING RECORD ACID, FRACTURE CEMENT SQUEEZE, ETC. iAMOUNT& KIND OF MATERIAL USED Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A ,I Injecting _-BBL G---~S--MCF wATER-BBL f CHOKE SIZE [GAS-O L-BBL ~AS-~CF WA'~ER-B'BL OIL GRAVITY-APl (cDr )IL RATIO - , DateofTest HourS Tested ipRO6ucTION FOR OIL-BBL TEST PERIOD ~1~ Flow Tubing Casing Pressure CALCULATED 01L-B~[ Press. 24-HOUR RATE I~ _ , 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED JUN2 8 t9t]4 Alaska Oil & Sas Cons, Commlssio. Anchorage Form 10-407 Rev. 7-1 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Sadlerochit O/W Contact Base Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH 9150' 9497' MD TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all ~'lu,ds ,ecovere(1 and gravity. GOR,and time of each phase. 9524' MD 8755' TVD N/A 9090 ' TVD 9116' TVD 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _~~..~. ~~ / Title Regional Engineer Date__ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this we should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, Inc. Prudhoe Bay ~..,gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 22, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 9-1 DS 9-3 DS 9-8 DS 9-11 DS 9-13 DS 9-19 Permit No. 75-76 Permit No. 76-35 Permit No. 76-70 Permit No. 76-84 Permit No. 77-8 Permit No. 77-40 Attached are "Subsequent Report" Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/lmh Attachments cc: Sohio Petroleum File Pi(DS 9-1)W1-3 File PI(DS 9-3)W1-3 File Pi(DS 9-8)W1-3 File Pi(DS 9-11)W1-3 File Pi(DS 9-13)W1-3 File Pi(DS 9-19)W1-3 ARCO Alaska, Inc. 18 a Subsidiary of AflantlcRIchfleldCompany ..... STATE OF ALASKA ALASKA ~_ AND GAS CONSERVATION CL ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELLX~ OTHER 7. Permit No. 77-40 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (Surface) 525'N & 250'E of SW cr Sec. 1, T10N, R15E, UM (Producing Interval) 1316'N & 1567'W of SE cr Sec. 12, T10N, R15E, UM (Total Depth) 930'N & 1353'W of SE cr. Sec. 12, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 54' RKB I 6. Lease Designation and Serial No. ADL 28327 8. APl Number 50- 029-20260 9. Unit or Lease Name Prudhoe' Bay Unit 10. Well Number DS 9-19 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations 1~ Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 5/11/84. RU perforating unit, pressure tested equipment. RIH with gun #1, shot interval 11366 -11386' MD (4spf), flowed well to clean up. Shut-in well, POOH, all shots fired. Ran SSSV, secured well, RD. Ref: BHCS 12/21/77 ECEIVED JUN2 8 Lq84 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Title Regional Engineer Conditions of Approval, if any: Approved by. Form 10-403 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc, Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 13, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9 Water Injectors Permit Nos: 76-70, 76-82, 77-7, 77-25, 77-36, 77-37, 77-38, 77-39, 77-40, 77-41 Enclosed are the Sundry Notices for Change of Well Status for the proposed Drill Site 9 Water Injectors. Very truly yours, D. F. Scheve DFS:SDC:kg Enclosures cc: SOHIO Alaska Petroleum Co. RECEIVED J U N 1 4 1984 Alaska 0il & Gas Cons, Commission Anchorage a[il~l'~ Al.aba in~ le · ~l,h~l~llor. nd Ailnnll,~RlchflelttC. amnllnv STATE OF ALASKA ALASKA~ . AND GAS CONSERVATION CC 41SSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL[] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 77-40 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20260 4. Location of Well 525'N & 250'E of SW cr Sec. 1, T10N, R15E, UM 9. Unit or Lease Name Prudhoe Bay Unit 1316'N & 1567'W of SE cr Sec. 12, T10N, R15E, UM 930'N & 1353'W of SE cr. Sec. 12, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etcl) 54' RKB 6. Lease Designation and Serial No. ADL 28327 10. Well Number DS 9-19 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: · , (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other E~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to change Well 9-19 status from oil producer to water injector. It will be Operated as part of the Prudhoe Bay Waterflood Project. RECEIVED Subsequent ~Vork Re~orte~ Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,,ned T,t,e eg±onal .ng±neer The space be,;; for Co m,ss ;n use Conditions of APproval, if any: ORIGINAL SIGNED BY' t ONqlE C. SMITH Approved Copy .R~turrm~ By Order of Approved by__ COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 June 1, 1984 Reference: ARCO Cased Hole Finals 1-1o 4-20-84 '~ D. S 4-1 4-_r_L1- 84 _ ~ D2S] 6 TDT CH CNL TDT CN/MSN/GR CET Log TDT > TDT ~.-~. '~-18 __ 4-28-84 TDT ~ Run 1 ~ ~--D.S. 7-21~/~-8~ ~--~ Run 1 / D S 7-26~v~,/4-27-84 PLS Run 1 / ~'=' a 19va'f~ 5-11-84 Collar/Perf Log Run 1 D.S. 11-5~ 3r29-R4 S~er/Basket Flw Mtr.. Run 2 ~~,~ "'D S. 12-17~ 5-20-84 Spinner Run 1 ~ ~-~~D.S. 12-21~5-2-84 ACBL/VDL/Signature/GR Run 1 ~ D.S. 13-16~4-12-84 Spinner Run 1 ~ D.S. 14-2/~ 5-3-84 CN/MSN/GR Run 3 D S 1 - ' 5-3-8~' C~T~~ Run 1 ~ ~~~~E Run 1 4-30-84 TD~ 16_3 ~ Run 1 D.S. 16-8~', 5-10-84 CET Run 1 D.S. 16-9/J 5-13-84 Collar/Perf NGI ~11 ~ 4-17-84 CET ~' 4-19-84 EPL 5" Sch Run 5 5" GO Run 2 5" Sch Run 2 5" DA Run 1 5" Sch Run 3 5" Sch Run 1 5" Sch 5" Sch 5" DA 5" DA 5" GO 5" Camco 5" Sch 5" Otis 5" Sch 5" DA 5" Camco 5" DA 5" GO 5" Sch 5" Sch 5" Sch Run 1 5" GO Run 1 5" Sch Run 1 2" Sch Please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. #221 DISTRIBUTION ~hevron DaM Dr i 11 ing Exp. Services Ext. Exploration Exxon Getty Marathon Have A Nice Day! Mob · l 'Chorage m~/,~$lorI Mobil E & P Phillips Prudhoe Bay Well Files R & D Carolyn Smith Sohio $~ate of Alaska ARCO Alaska, Inc Prudhoe Bay d. ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regionsl Operations Engineer March 19, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 9-1 Permit No. 75-76 DS 9-12 DS 9-2 Permit No. 76-16 DS 9-13 DS 9-3 Permit No. 76-35 DS 9-14 DS 9-4 Permit No. 76-40 DS 9-15 DS 9-5 Permit No. 76-47 DS 9-16 DS 9-6 Permit No. 76-48 DS 9-17 DS 9-7 Permit No. 76-58 DS 9-18 DS 9-8 Permit No~ 76-70 DS 9-19 DS 9-11 Permit No. 76-84 DS 9-20 Permit No. 77-7 Permit No. 77-8 Permit No. 77-25 Permit No. 77-36 Permit No. 77-37 Permit No. 77-38 Permit No. 77-39 Permit No. 77-40 Permit No. 77-41 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/lmh Attachments cc: Sohio Petroleum File PI(DS as above)W1-3 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfteldCompany STATE OF ALASKA -- ALASKa-. 3IL AND GAS CONSERVATION C .~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 'l 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 77-40 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20260 4. Location of Well 525"N & 250'E of SW cr Sec. 1, T10N, R15E, gM 1316'N & 1567'W of SE cr Sec. 12, T10N, R15E, UM 930'N & 1353'W of SE cr. Sec. 12, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 54' RKB I ADL 28327 9. Unit or Lease Name Prudhoe Bay Unit 12. 10. Well Number DS 9-19 11. FieldandPool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Trip!icate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate · [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state alt pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS 9-19 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 11366-11386' MD Ref: BHCS 12/21/77 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _~ ~.._~~. ,,~~4~ Title Regional Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate March 26, 1980 Reference' ARCO Cased Hole Logs D.S. 5-7 6/18/78 Continuous Flow Su]~'ey Run 1 5" D.S. 5-13 6/12/78 " " " ]~n 1 5" D.S. 9-9 10/28/78 " " " P, un 1 5" ~..S~,,.~A,~L~ 9/25/78 " " " Run ] 5" ~~8/5/78 " " " Run ]. 5" Please sign and return the attached copy as receipt of_' data. K. J. Sahlstrom North Engineering TRANSMITTAL # 229 DISTRI BLrFION North Geology Drilling Eng. ?,k~nag e r Geology State of Alaska Mobil Getty Phillips Sohio blarathon CJ~eYTon Reference' ~E~CO Hagnetic ]'al'ms D.S. 2-5 1/27/77 Tape //60221 ~?.S, 4 6 il/12/78 r,,.~ ~:6023~ T~ _ ~ ~,~)~ ~; .... D~-6 1/28/80 Tape //60240 1/27/80 T~pe ]~60247 ~P~ease s~n and retu~ the attached copy as receipt of d~t~. K. J. Sahlstrom North Engineering TR.L\'SHI ITAL /,~162 DISTRIB[FFION North Geolog7 Drillim~ En~ HanaRer D & }I Geology State o[ ~aska }bbil Getty Phillips Sohio >!arathon ARCO Oil and G~-w'"~ompany · '.-.~ ., ,r.[ :,'.;! .'..-,:" " · ,, .... ';')" 9 ;'7 ": · .' February 26, 1980 Reference' Enclosed are Cased Hole Logs for the following ARCO wells' D.S. 9-5 2/4/80 CNL Run 2 5" D.S. 9-6 1/28/80 " RUn 1 D.S. 9-7 1/25/80 " Run 1 5" D.S. 9-9.~ 1/26/80 " Run 3 ('~'~i~1~?'~-i~3% 1/27/80 CNL Run 2 5" .... 'Please sign and return the attached cop), as receipt o~ data. K. J. Sahlstrom North Fmgineering TK&YSMITTAL #122 DISTRfBUTION North Geology R&D Drilling Eng. Manager State of Alaska ~xxon Hobil Getty Phillips Sohio ~larathon O~evron C - North Alaska D..Lstri~St Post Office )" ,90 Anchorage,,~ .... ska 99510 Telephone 907 277 5837 ~rch 16, 1979 ,, Reference' , Enclosed are the following cased hole logs'. DS 4-2'-'/ Diff. Temp. 9/~5/78 DS 4-12 ~'"'× CCL 12/01/78 DS~9-20 - Spinner 12/ 3/78 DS 9-13-- Cont. Flow - 6/ 3/78 DS 14-3 ~" CNL 11/28/78 DS 7-6 "'~ CBL/VDL 11/20/78 DS 9-9~' Diff. Temp. 9/18/78 D~.~__~-,,/ Cont. Flow 6/ 2/78 '~~ Cont. Flow 10/24/78 DS 3-7c/ Cont., Flow 8/29/78 Please sign and return the copy as receipt of data. Sincerely, V.G.: Reimers North Engineering TR~qSMtTFAL #99 DISTRIBUI~ION North Geology Drilling, Eng. Manager. Geology '~?iState.ofiAlaska} Sohio Mobil Marathon Phillips Chew:on Getty F!o,'ih /'.!ask:- '"',,!rict Pos~ OMce ' 380 Ancho:age, ;!(~'Sks 9C, 510 Ye,;.~,.on~ 907 277 5537 November 16, 1978 Reference: Enclosed are the following logs: D.S. #5-9 Fluid Density . 9/20/78 D.S. #4-2 Diff. Temp. 10/5/78 D..S. #7-5 CNL 10/10/78 D.S. #4-2 ' Flow Meter 10/5/78 D.S. #7-2 CBL/VDL/GR 10/2/78 D.S. #4-2 Fluid Density 10/5/78 D.S. #5-1 Neutron 10/12/78 D._,._S-~-¢-2=.%~. CBL/VDL/GR 10/9178 ~D.S. #9-1~1> Fluid Density 10/24/78 '~1~'}~'~ Flow Meter 10/12/78 D.S. #7-4 CBL/VDL/GR 9/15/78 D.S. #9-17 Dual Spaced Neutron 10/26/78 D.S. #7-4 Noise Log 9/30/78 D.S. #9-9 Neutron 10/28/78 Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL ~J566 Nodh Ame~'"""' P¢oducino Division Alask~ Re.§, Post ChOice B~ 360 Ar~chorage, A~aska 99510 Yelephone 907 277 5637 September 20, 1978 Reference: Enclosed is Transient Pressure Survey for D.S. 9-19, dated 8-3-78. Please sign and return attanhed copy of transmittal as receipt of data. ~/¢~ Very truly yours, R. A. Logue North Operation Engineering Transmittal #474 AtlanticRichfieldCompany North American Producing Division North Alasl~-";strict Post Office x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 14, 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 9-13 Permit No. 77-8 DS 9-14 Permit No. 77-25 DS 9-15 Permit No. 77-36 DS 9-16 Permit No. 77-37 DS 9-17 Permit No. 77-38 Permit No. 77-39 Permit No. 77-40 DS 9-20 Permit No. 77-41 Dear Sir: Enclosed please find a Completion Report for the above-mentioned wells. Very truly yours, o ,¢, ' Frank M. Broom D±str±ct Drill±rig Eng-ineer FMB: lr Attachments SUBMIT IN D. ~ .ATE* STATE OF ALASKA (Se,,oth~r m- st l'Tlct lobs on reverse side; OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* W ELI, W ELL DR DEEP- ~ PLUG ~ DIFF. EN BACK RES'eR. la. TYPE OF WELL: b. TYPE OF COMPLETION: .~,w ~ wonK ~ ~VELL OVER Other 5. API NUiVIF. glCAL CODE 50-029-20260 2. NAME OF OPERATOR Atlantic Richfield Company ^,~ss OF O~.a~TO~ o~Pv~. P~Ox '~CI Anohn-r,qcrp A]~ltm OQql(I 4. ~,OC^Tm,w ~ 'ELL (Rel~ort location clearly and~n efccorda~ce-~c-~th any ~faTe--r~quirements)* At surface 525'N & 250'E of SW cr Sec. 1, T10N, R15E, UM At top prod. ~nterval reported below At total dep~316~N & 1567'W of SE cr Sec. 12, T10N, R15E, UM 6. LEASE DW-~SiGNATION A.ND SERIAL NO. _ ADL 28327. 7. IF INDIA-N, ALLOTTEE OR TRIBE NAJ~IE 8. UNIT,FAll2Vi OR LF~kSE NAME Pr~j~ha~ B~y liner g. WELL NO. n.q 9-~ 9 (34-1 2-10-]5) ~0. m~-~N~-vo6~, ca w~p~oe Prudhoe Bay Field-Oil Pool u. s~c., T.. ~., M., (~OT~O~ O~ E~'IV E ) Sec. 12,_ T10N, R15E~ U1 12. P~q~dVIIT NO. 9301';N~&13535W Of SE cr Sec. 12, T10N, R15E, UM 77-40 12-2-77 J 12-23-77 !12-28.-77 2-20-78) ! 54' RKB ., 18, T©TAL DEl=VI?H, ~LD & TVD~9, PLUG, BACK MD & TVD~0, I~ MULTIPLE CO1VI~PL.. [ 21. INTERVALS DRILLED BY I ! HOW1VIANY* I[ ROTARY TOOL,% - CABI,E T001,8 11,934'MD, 9275'TVD J!l,862'MD, 9226'TV~ Single [ All ?2. PRODUCING INTERVAL(S), OF THIS CO.IVIPLETION--TO~P, BOTTOM, NAME (MD AND SUI:.VEY MADE Top Sadlerochit 11,336'MD 8872' TVD Base Sadlerochit ll,806'MD 9188'TVD I Yes 24. TYPE ELECTF, IC AND OTHER LOGS RUN D.IL/BHC/OR/.CCL, _ F, DC/CAL/GR, , CR/CCL/CNL, FDL 25. CASING RECORD (Report all strings set in well) 23. ~VAS DIRECTIONAL A.R{OUNT PULLED cm~ 30. DATE FIRST PI~ODUCTION 'GRADE SET ( 1VID ) CA~SLNG SIZE \VEIGEIT, LB,:FT. I DEP~ , no'. !3-318" 79# 9-5/8" 47# Butt [ ~-~ 1 1: qO5_' .... I ,,. 20. LIN~ 28. P~gFO~AT~ONS OP~ TO PRODUC~ON (ingerval, size anO number) 11,621 '-11,638 ' 11,414 ' -11,454' 11,576 ' -11,606 ' 11,337 ' -11,346 ' 11,528'-11,542' w/4 shots per ft. 11,465 '-11,505 ' P~ODUCTION . 3-14-78 3-22-78 ! _.6.2 I 62/34 P-C6'~v. TUmNO leAsinG PRESSURE ICALCIJLATED OIL---BBL. ~]. OlSPOSIT'~ON O; GAS (~old, used Io~' tue[, vented, etc.) HOLE SIZE 30" 1 7--1 /9" i ,[ . 5300 _oy. _~_P. ctic Cmt ..~ 1 27. TU BI~'G RES O'~J) 5-1/2". 11,207' ACID, Si!CT, N/A ~~ ~'~' ~''" · "~ _ ~' ,i ~ ~ f,, .~ , ~ ,. .~ ,.,:-,~ .,.,:'"" ~ :.. :.}k.,.~ ,,, [%X~ELL STATUS ~Produciag or Producing OI~BBL. GAS--i~CF. ~V/dI'ER--BBL. [ GAS-OIL [L~TIO 13943.7 12466.8 [ 0 [ 62~ GAS--r~CF. WA~--BBL. ] OIL GRAVITY-~I (COgg.) 9549 ITEMT WITNESSED ~Y Production Operations Reiniected PACiiER SET (A~D) ,., 11,085' ~2.LIST OF ATTACHMENTS PRODUCTION ML'I[-IOD (Fiowii~g, gas lif~, pdmping size and type of pump~ Flowing -- all-available records ,~g. lslgN~~~,¢~>~~hereb' ,-Ycert. If y that th* foregoing and attached m form at ton 1, complete and e or re et as determiued fromTITL~ DiS trier Dr ill in~_Engr_ DATE __--/~4~~ _ *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS C, eneral: This form is designed for submitting a complete and correct wef[ completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in other spaces on this form and in any attachr.'nents. Items 90, and 22:: If this well is completed for separate prcduction from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prcducin9 int6rvat, or intervals, top(s), bottom(s) and name (si (if any) for only the interval reported in item 30. Submit a separate report (pa0e) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the ackiitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~::i. (See instruction for items 20 and 22 above). , , , 34. SUMMAIt¥ OF F'OI~MATION TES'I'S IN('I.UI)IN(; INTEItVAL TE.qTEr), PItES-qURE DATA ~'~COVEltI~ OF OIL. GAS, 35. G~GIC MAHK~ WAT~I AND MUD NAME I . 3a. CORE DATA. A'I'I'ACli tlalE~ D~CR[~I~NS O~~ LITHO~OGY, POR.OgI~Y. FRA:C~R~:. AppeNd: m'~ ..... AN'D, DE'EEC~'ED SILO'S OF t/IL. ~&S OR- WAT~I,. , , ,;!uadc;~ichiigldCompany North Ameri '~roducing Division North Alaska strict Post Office Box 380 .,-.> ~"7~ ~' Anchora;o, Aiaska 99510 '.;~',,:~',~,' "'" ~e 29, ~978 Enclosed are prints of the following Ope~oe Logs' D.S. #1-13 DIL 2" BCS 2" D.S. #2-11 DIL 2" D.S. #4-12 DIL 2" BCS 2" D.S. #5-7 DIL 5" D.S. #5-12 DIL 2" D.S. #5-13 DI'L 2" BCS 2" D.S- #9-20 DIL 2" Please sign and return attaChed copy of transmittal as receipt of data. Very truly yours, R.^. Logue North O?erations Engineering Transmittal lf833 North AlaSta DistrJ. ct t!n[~:ln~ ~no T RAN Si'.l I TTA L Froill ' J. A. Rochon/R. A. Lqgue __ Well Nane' i'ra.us:'n.i t ted herewith are the following for the subject well' Run No. Scale Xerox Sepia · BL Line -. A~id or Fracture Treatment Log. - B[-IP Buildup & Flm~' Profile Survey :' ' Borehole Geometry Log '-~ Carbon Ox)~en Log ~ ~ Collar Log Cement Bond Log : Compensated Neutron Log - Cased Hole Core Analysis - Interval Core No. : Core Description (SMC)- Inte~wal : 'Core Description (Cony.) - Cpre No. Directional Survey- Gyro - Single Shot - Multishot · Engineering Production' Log · -- Fluid Analysis- . ~ '__. Fluid. Dens ity Gamma Ray Location Plat Monthly l~'ell Test Data Mud Log Perforating Record - State Reservoir Pressure Report · _ _ Surveillance Reports ' Temperature Log · Transient Pressure Surveys - ~YI) Logs - IXml Induction Laterolog - Compensated Formation Density Log - Compensated Neutron-Formation Density Log - Borehole Compensated Sonic Log - Porosity Log Receipt Ackmowledged By: ~.':~>,-:-}/ ~, ,~.~'" Date' ~ . ~'l. ease Return Receipt To: Ms. R. A. Logue Atlantic Richfield Company P. O. Box 360 ' ~chorage, Alaska S'9~t0 7'; ~ ?- North Alaska District Engineering TRANSMI TTAL To' From: J. A. Rochon/D. R. Jackson Date' _ M~rch !4_>'lqTa' Well Name' D,s. 9-19 Transmitted heravith are the follmving for the subject well' Run No. Scale BHC sonic/Caliper Log ._ 1 BHC Sonic/Caliper - Gamma Ray Log .... 5,,~ 'BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/¥~L 1_ Compensated Formation Density Log .... 2"/5" Compensated Neutron-Formation Density Compensated Neutron 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 Formation Density Log/Ganm~aRay GammaRay/CCL Laterolog Location Plat bficrolaterolog ~crolog' ~dlog - Interval Sample Log (A.R. Co.') - Inte~va~ Synergetic Log TVD-DIL TVD-Porosity Log 1 Xerox Sepia BL Line ea. / ! ea. w ,, ,I. ,.e,.a. ea. ~ ea.. Receipt Ackmowledged For' Date' Please return receipt to' Attn' ~'k. Donovan Jac!:son Atlantic Richfield Company North Alaska Engineeri~g P. O. Box 360 Anchora~oe. Alaska 99510 .,Atlantic, RichfieldCompany North American Producing Division North Ala;'-'~')istrict Post Offic ,3x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 28, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, A1 aska 99501 Subject- D.S. 1-5 (23-9-10-15) Permit No. 70-40 D.S. 2-2 (23-30-11-15) Permit No. 70-35 D.S. 9-17 (43-1-10-15) Permit No. 77-38 43-2-10-15) Permit No. 77-39 34-12-10-15) Permit No 77 40 D.S. 9-20 (21-12-10-15) Permit No. 77-41 Dear Sir' Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned wells. Very truly yours, :":' / Frank M. Brown District Drilling Engineer /am Enclosure Form 10-403 REV. 1-10-73 Submit 'qntentions" 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 50-029-20260 6. LEASE DESIGNATION AND SERIAL NO. ADL 28327 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay Unit 3, ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360; Anchorage, AK 99510 DS 9-19 (34-12-10-15) 4. LOCATION OF WELL At su trace 525'N & 250'E of SCl cr Sec. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 54' RKB 1, TiON, R15E, UM 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 12, TION, R15E, UN 12. PERMIT NO. 77-40 )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 FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) Perforate REPAIRING WELL ALTERING CASING ABANDONMENT* (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form,) Pool 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Began perf operations @ 1300 hrs 2/18/78. Tstd tree, csg & wireline BOP's. Pulled dummy valve. Perf'd intervals 11,621'-11,638' 11 586'-11 606' 11,576'-11,586'-11,606' , , , , , 11,576'-11,586', 11,528'-11,542', 11,4'65'-11,505~', 11,414'-11,454', 11,337'-11,346' w/4 shots per ft. All perf'd depths referenced to open hole BHCS log of 12/'21/77. Ran Amerada press bombs & FDL. Flowed well. Ran & set ball valve. Tstd balance & control lines to 5000 psi' OK. Bled press above ball valve to 0 psi, held OK. Installed & tstd tree cap to 5000 psi OK. Released well to Production Dept @' 1130 hrs 2/20/78. 16. I hereby certify that the foregoing is true and correct SIGNED] .2/ ~ ~- .,.~ TITLE District Drilling EngineeroATE' 2/28/78 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side DiviJ of Oil and Gas ~ticm O:DirectorK. Gilbreth, Jr~~~' ':_ February 28, 1978 Ben I~N~rman ~ Surface Safety Valve (F~V) and Petroleum inspector Subsurface F~nfety Valve (SSSV) Tests Arco' s DS 9-19 ~~--~az'~' 8:00 ~M-~roj~ de~ via Wien flight %1 f~r Deadhorse ?~ ~~ ~~~ ~ 8:10 ~ ~ ~i~ ~ ~~~ at 10:30 ~. ~ ~.~f~ p~ ~~~ ~ ~1~, ~k ~ ~ ~~~s ~ f~lly ~ ~ ~~ at 1:~ ~. I ~s ~t at ~ ~{~ by ~~~ ~~ ~ ~~ F~ ~10, 45 ~les ~t of ~ ~, ~i~g at 2:30 ~L Aroo's drilling fore,mn was Minos Hebert and contract drilling rig was Br~f 959 whose toolpushar was Jerry Johnson. Nippling up was in progress and tests w~uld not begin until the foll~ day. ~rature -23° Ff clear skiesw light wind. ~~19, 1978 - BOPE tests initiated ~n Areo's West Sak B-10. 20,_197__8- BOPE tests ~ concluded at 4:15 ~M and later proceeded to DS 9-19 for SSV and SSSV tests with Y~n Jcnes, Tests began at 10:45 AM with shut in tubing pressure of 1200 psig. SSV t~as then closed and pressure downstream bled %o 720 psig and ~mnitored for ten m~s. The SS~f was then closed, the MSV opem~ and pressure above the SSSV b~ to 700 psig and monitored for ten minutes. Both SSV and SSSV tested bubble tight and tests ~ concl~ at 11:15 AM. A field //%specticm re~ w~s prepared with a copy gix~n to Ken Jc~es, a copy mailed to Bob Hines and the orig/na3_ attached to this report. I Tue ~February 21, !9~8- Stand~ by c~ DS 1-16o SSV and ~SV on DS 1-3. I d~~ Deadhorse via Wien flight #110 at 6:25 PM, arriving in Anchorage at 8:10 I~4 and at my hc~e at"8:40 PM. In ~: I witnessed su~essful SSV and SSSV tests cn Arco's DS 9-19. Drlg. Permit No._ ..... Opera tot /~¢~ A1'~''~Z'' Oil at]d Gas Conservation Commi:i ~ Field Inspection Report Wel 1 / P~=J~Em Sec T Represented by~j-~/L~ Name & Number ~,~S~ ~~ Satisfactory Type Inspection Yes No Item ( ) Location,General () () () () () () () () (~() (~() () () () () () () () () () () 1. Well Sign 2. General Housekeepin.a t. Reserve Pit-( )open( )filled 4. Rig (l~/~Safety Valve Tests 5. Surface-No. Well 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , , 9. BS&W , , , lO. Gro Bbls~- .... ( ) Final Abandonment ll. P&A Marker Satisfactory Type Inspection Yes No Item ( ) BOPE Tests ( ) ( ) 15 ( ) ( ) 16 ( ) ( ) 17 ( ) ( ) 18 ( ) ( ) 19 ( ) ( ) 20 ( ) ( ) 21 ( ) ( ) 22 ( ) ( ) 23 ( ) ( ) 24 () () 25 ( ) ( ) 26 ( ) ( ) 27 () () 28 "Casinq set Fa TesL fluid-( )wtr. ( )mud ( ) oil Master Hyd. Control Sys.- psig ~'!2 btls. , , , psiQ Remote Controls Drilling spool- "outlets Kill Line-( ) Check valve Choke Flowline ( ) HCR valve Choke Manifold No. valvs flas Chokes.-( )Remote( )P. os.(-~dj. Test Pluo-( )Wellhd( )csm( )none Annular Preventer ,~__~ps i m Blind Rams, psi.m Pipe Rams psiq ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 29 Kelly & Kelly-cock psig ( ) ( ) 13. Clean-up ( ) ( ) 30 Lower Kelly valve psi~ ( ) ( ) lZ$. Pad leveled ( ) ( ) 31 Safety Floor valves--~- -)-BV ( )Dart Total inspection observation time~ hrs/d~j~ Total number leaks and/or equiP, failures ~ Remarks -~-c~~~Noti fy in days or when ready Inspected by~-~;~o~ ...... ~r~=Date~--~ ~_-.~__~-. AtianticRichfieidCompany North American Producing uivislon North Ala,~'"'~")ist rict Post Officc < 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 25, 1978 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: D.S. 9-17 (43-1-10-15) Permit No. 77-38 D.S. 9-18 (43-2-10-15) Permit No. 77-39 D.S. 9-20 (xx-12-10-15) Permit No. 77-41 Dear Sir' Enclosed please find our Sundry Notice outlining our plans on the above-mentioned wells. Very truly yours, Frank M. Brown District Drill ing Engineer /am Enclosures 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 u~e this form for proposals todrlll or to deepen Use "APPLICATION FOR PERMIT-'-" for such proposals.) ~' o,= F~t ~AS E~ WELL~ WELL OTHER NAME OF OPERATOR Atlantic Richfield Company ADDRESS OF OPERATOR P.O. Box 360; Anchorage, Alaska 99510 4. LocATION OF WELL At surface 525'N & 250'E of SW cr Sec. 1, T10N, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 54' RKB 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE .50-029-20260 !6. LEASE DESIGNATION AND SERIAL NO. ADL 28327 7. IF INDIAN, ALLOI i'EE OR TRIBE NAME UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. Drill Site 9-19 (34-12-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE oBjEcTIvE) Sec. 12, T10N, R15E, UM 12'.' PERMIT NO. 77-40 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDtZE ABANDON* REPAIR WELL CHANGE PLANS (O ther) Perfo rate SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTEt Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state att pertinent detatls, and 9lye pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate 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 al~ wireline work. All perforations will be made with hollow carrier type guns at 4 shots per foot. Vlell will be flowed to a surge tank to recover load fluids and any produced well · fluids. All recovered liquids will be retained in the surge tank, then trucked to the oily waste disposal facilities for disposal. Any produced gas will be vented to the atmosphere during perforating operations. 'The downhole safety valve will be installed and tested upon conclusion of job. Estimated Start Date' 2-11-78 16. I hereby certify that t. he foregoing ts true and correct TITLE District Drill in9 Engineer DATE 1-25-78 (This space for State office u~e) CONDITIONS OF APPROVAL, ~F AN¥'~ Petroleum EnRineer See Instructions On Reverse Side DAT~anuarM 31, 1978, North Alaska District Engineering T RAN S ~Xl I T TA L ' To- .. · .- From: -' .. :".' ...'zT.-" .._' ,. .- - : .- .- . . . . . Transmitted herewith are the following for the subject well' ~IL)~Z ~l~ · . J. A. Rochon/ R. A. I,op:3.Le_ . . : . . . .. . Run No. Scale Xerox Sepia BL Line BHC Sonic/Caliper Log BHC Sonic/Caliper - Gama~na Ray Log BItC Sonic/Gamma Ray Log Caliper/CCL Cement Bond LOg/VDL - . Compensated FOrmation Density Log Compensated Neutron-Formation Density" _. / _ Compensated Neutron Log Core Analysis - Interval Core' No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro -- Single Shot l~'~altishot DrilI Stem Test - Test No. · baal Induction Laterolog Fomation Density Log -Formation Density Log/Gamma Ray . Ga~mna Rax/CCL Laterolog Location Plat ~2crolaterolog 3~icrolog ~udtog- Interval Sample Log (A.R. Co.-) - Interval Synergetic Log TVD-DI L . ~ R~D-Porosity Log Rec6J.pt Ackmojfledged For: Date: Please return receipt to' /k~t~: ~lr. Donovan Jackson ~tlj~ntic Richfield Company Nort*'~' 'h Alaska Engh~eering " P. O. Box 360. / // / Anchorage, Alaska 99510 / North Alaska District Engineering T RAN S ~X! I T. TA L ' To- .. .. From: -. .. · - ' -- . ..'--~.- ;~;' · '.. ~ .... r'.'&..~' ,' .'' · ~ -~-~. _ .. ~ .... . ~ ..-;. -... ,.; .. ~- . . .. ..~. :'.'-' -- . . ;.- .. . -.-- , .. Transmitted herewith are the f61lowing for the subject.we!l: · . Run No.. .' '~. ' . . BHC Sonic/Caliper Log ' · BHC Sonic/Caliper - Gamma.' Ray Log . -BHC Sonic/Gamma Ray Log -. Caliper/CCL . Cement Bond Leg/VDL' " CompensateR Formation Density Log Compensated Neutron-Formation DensitY." ....... Compensated NeutrOn Log Core Analysis - Inter~al . · -. ' Core' No. .- Core Description (SiVC) - Interval Core Desqrip. tion (Cony.) - Core No. - . , Directional Survey..- Gyro' . Single Shot' _ . '- . ~ltishot Drill Stem Test - Test No. . 'Dual Induction Laterolog. Formation Density Log Formation Density Log/Gamma Ray- .' Well Name'i .. - Interval · o Scale. Gan~aRay ~ Laterolog Location Plat Microlaterolog Microlog Mudlog - Interval San~le Log (A.R.c~'.') Synergetic Log' TVD-DIL . TVD-Porosity Log-' Recdipt Actmojflcdged For: Date: Please return receipt to' ~f/~r¥. _Mr. Donovan Jack~on i{l~ntic Richfield Company NoCth ~aska Engineering P. O. Box 360 Anchoraffe, ~aska 99510 J. A. Rochon/ R. A. I,o~ue s'. ':- '.. . .' f :'i' : ::.:" ! :':" !. : - . Xerox Sepia · BL Line. . -. -. By' A~a~ieRichfie~dCompa~y North Am~ Producing Post Office ~ox Telephone 907 277 5~37 January 5, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subj ec t: DS 9-19 (34-12-10-15) Permit No. 77-40 Dear Sir: Enclosed please find a Completion Report along with the Drillidg History and Multi-Shot Directional Survey for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosures i ', }"t~r !~ P 7 SUBMIT IN DL_~ICATE* STATE OF ALASKA ',S~,,oth~r m- st ructions on OIL AND GAS CONSERVATION COMMITTEE I II I II I I WELk COMPLETION OR RECOMPLETION REPORT AND LOG* WELL WELL ~ DRY b. TYPE OF COMPLE~ON: W EI,I, OVER EN ~ BACK gESVR. Other ~ 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360; Anchorage, Alaska 99510 4. LOC;/rION 0r WELL (Report location clearly and in accordance with any State requirements) At surface 525'N & 250'E of SW cr Sec. 1, T10N, R15E, UM At top prod. interval reported below 1316'N & 1567'W of SE cr Sec 12, T10N, R15E, U~ At total depth 930'N & 1353'W of SE er Sec. 12, T10N, R15E, UM 5. AP1 NUM2~{ICAL CODE 50-029-20260 6. LEASE DKS1GNATiON A~ND SERIAL NO. ADL 28327 7. IF INDIA.N, ALLOTTEE OR TklIBE NAI~iE 8. UNIT,FAILIVI OR Li~iSE NAME Prudhoe Bay [Init 9. WELL NO; .... ~S 9-19 ~34-12-10-15) 10: ~D"'~D ~6'~, OR ~ruanoe Day Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM I-IOLE OLM F. CTIVE) Sec. 12, T10N, R15E, UM 12. PEItlVIiT NO. 77-40 12/2/77 ] 12/23/77 ] 12/28/77 [ ( 54' RKB)., ,~ 18. TOTAL DEl>TH, ~LD & TVD[19. PLUG, B_~CK MD & "I%rD~), IF 1VIULTEPLE COi!q, PL., 1--21. INTER'VAI,S DRILl,ED Iii' 11,934'~D 9275'TVDIll,862'MD 9226'TVD[! ~°wTf'Sin e 1' ~o~^,, AllT°°L'~ I (:^,,.E TOO,., PRODUCING !NT~iRVAL(S), OF THIS CO.IVIPLETION--TO,P, BOTTOM, N'AME (MD AND 'iW-D)* 2~.WAS DIRECTIONAL ) SURVEY IV1ADE Top Sadlerochit 11,336'MD 8872' TVD ! Yes Base Sadlerochit ll,:806'MD 9188'TVD ,I 24. TYPE EI_,ECTiqIC AND OTHER LOGS RUN DIL/BHC/GR/CCL,, FDC/CAL/GR, GR/CCL/CNL CASING RECORD (Report 311 strings set in well) C7~SI~4C{ S1Z]~ 20" 13-3/8" [\¥EIGHT, LB,"FT. ~ "GI~*D~ I DEPTH SET (1VH~) 94# Welded] H:"~0] . 100'+ 72# Butt ~ N-80[ 27141-- [47# Butt ]~-80&]11.,9.05~ poo-951 9-5/8'.' 26. LINE~ tREC O~rLD ~8. PEiR.FORA'{'iONS OPEAW TO PRODUCTION (interval, size and nurnber) N/A 3o" l Circ to surf aPprox 300s~ 17-1/2'' 15300sx Ar'c. ticset cmt ' L2-1/4" ]1000mx Clos~ G cmt " I 5-1/'~"' I 11,207' [ 11,085' 29, ACID, Si!OW, Fi~A_C~[ GRE, C~,iKNT SQUZ.!~Z~, ETC. DEPI~i 1NTFS~V.~L (MD) £).M~bUNi' 2, ND I'2!ND OF M/k'IE:.'.IAL USED i *(:See Instructions and Spaces I:or Additional Data on Reverse Side) 30, Pt~ODUCTION ! and t>pe of pump) ,Iv'ELL- 'f~TATUS (Producing or ' -- ~', ': ~ } ]CASI2qG PRESSURE [CALC~T~ 3~. ~,S~OS,T,OX or c~s (d;ta, used ~or Iud, vented, ~tc.)' -' tTES'F WITNESSED BY 32. LIST 0F ATTACHMENTS Drilling History, :Hul¢ishot Directional Survey '" ~3. I hereb~~ certify that ~he foregoing and attached information la complete and'correct as determined from all-available recurds ~~- ~ District Drilling Engineer DATi,: SIGNED ~. r~ _ TITLE 1/S / 78 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in arty attachments. Items 20, ancl 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state ~n item 20, and in item 22 show the p~cducing 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, adequately identified, for each additior~al interval to be seperately produce,J, show- ing the acktitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and 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). SUMM'AI{'Y OF' FORMATION TF. STS INCLUI)IN(; INTERVAL TESTED. PI{ESSURE DATA AN1) RECOVERIES OF OIL, GAS.- 34. 35. G~GIC MARK~ WAT~ AND MUD 2~', ,. ~fi. CO~E DATA. A~'I'ACII llRIEF D~I~ONS O~ LITIIOLOGY. POROSITY. FHAC~R~, A~~ DIPS ' AND I)EI'EC~'EI) SHOWS O~ OlD, GAS OR DRILLING HISTORY DS 9-19 (34-12-10-15) API 50-029-20260, ADL 28327, Permit No. 77-40 Spudded well @ 1045 hrs 12/2/77. Drld 17-1/2" hole to 2750'. RU & ran 68 its 13-3/8" 72# N-80 Butt csg w/shoe @ 2714'. Cmtd w/5300 sx Arcticset cmt, 15.0 ppg w/3# per sx Kolite & 0.7% Di3R. Drld 10' new form. Tstd form. Drld 12-1/4" hole to 11,885'. Dropped multishot. Ran DIL/BHC/GR/CCL, FDC/CAL/ GR. Drld to 11,934'. RU & ran 9-5/8" csg w/shoe @ 11,905'. Cmtd w/1000sx Class G cmt w/add, 15.8 ppg. Opened, circ thru, closed & tstd upper FO. Opened & circ thru lower FO. Sqz 300sx cmt thru lower FO. Closed & tstd lower FO. Opened upper FO, did Arctic Pack job. Closed & tstd upper FO. Displ mud w/wtr & wtr w/10.6 ppg CaC1o. Ran gauge ring & junk bskt. Ran GR/CCL/CNL. RU & ran 5-1/2" tbg w/shea~ sub @ 11,207', Baker SAB pkr @ 11,085', sliding sleeve @ 10,972', & RQY nipple @ 2203'. Displ tbg w/diesel. Set pkr. Tstd csg & tbg OK. Installed & tstd xmas tree, OK. Pulled dummy valve. Ran dummy gun/CCL. Reran dummy valve. Tstd balance & control lines, OK. RU for long term tbg tst. Released rig @ 0800 hrs 12/28/77. Eastman/ 1 Whipstock l A PETROLANE COMPANY ~I~ REPORT of SUB-SURFACE D IREC TI ONA L SURVEY ATLANTIC RICHFIELD COMPANY #9-]9 WELL NAME PRUDHOE BAY LOCATION JOB NUMBER A1277 S0177 TYPE OF SURVEY MULTI-SHOT DATE 1-4~78 SURVEY BY JEREMY BEATTIE OFFICE ALASKA · COMPLETION REPORT ATLANTIC RICHFIELD COMPANY W EL..L DS MAGNETIC MULTISHOT SURVEY DECLINATION RADIUS Of CURVATURE METHOD OF COMPUTATION K B ELEV 54 FT DE GR E E_,.S.. _EA~ T ............ COMPUTED_ FOR E&_S. XMA__N W_U_.I._P_S_TP.C.~ ..... BY F M L IND_$E_Y_A_B.D._A_S.$_O.~_[.A_T_E$ ............................................ MEA$, DR!FT VERTICAL. .......... _SUB ........... DEP TH ANGL. E____D_E.~_T_H_ ........... .S_._.E_._A__ .......... DlJt._E__C D_I 5_T.ANCE .............. _A..131.GLF._ ........... DEGZiO. OF_T DI 5_T ANC O M DE.~: O ..... 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D !..S_T_.AN CE .................. A..NGLE ........... D_E.GZ1QOEI .......... DISTAN£ ' " DEG, D , 24o. 9. 5_ ....... ~.!.e_a....,.95 ......... s~.~..,.O.O_E .......... .~.83.~ ,.~.... S ...... ~o_~_~, o~ .._E. ~.a.~.~..,...~..? ....S ...~.~_.Z.7 ~..7_ ....... E ......... 0., ~z.~ .............. 4'~ 9Z"~'-~-~ 298. %8_ .... S.?..~ ,9..8 ....... 53 ~.._,.._O.O.E .......... ,_2~._._S ....... 3.0.~.~., ~_O .... E ....... _~.~_.6..7.,.60 .... 5_.3.8 z3 .~_8 E ..... 0., Z66 ................ ~+.~66.,.~ 35._6_,..5_6_ ...... _.e_._S.. 0~..,5 ~ ..... S_~.~.:_O.O..E_. ........ 3._9.5...3_ ,_7 %._S ......... S !.2 ~,. 2.~...._E. ......... 5._0...~__0. ,.~.Z ..... S 3.8 ~ ~_ .... 5~ .... E ........... 0_, O00 ..... 50 S ~., ZC ~ 15 ,_..6_ ~_ ...... ~__~_6_~_.,_a ~ ...... SS..~,_.o_._0_~__~.~..5,.~%__~ ..... _%!..~.?_,..~ ~.._~: ..... .% ~. _17 ,. 5 _e ..... S s.s .... 16 ....... ~.2 .... E ............ _o., ~.26 ......... ~ 113 ,_4_~ 47 3.5~ 8 4 ~.9..:..5. ~ ....... 39.~_,..0..o...~ .... .~.o.7..~_.,.Z!.__s_.__.s_..z_.O_.~_.._5...~ .... 10895 51 15 8590,00 10989 50 45 8649.15 11083 50 45 8708,63 11177 50 0 8768,57 11270 49 0 8828,97 11363'48 ~0 8890,29 11458 48 15 8953 11551 47 45 9015 11645 47 30' 9078 11778 1188~ 11934 BOTTOM 847'7,94 533,005 4137 ,._22._~ ........ 52~_9._..__!__8 ..... _E_ ..... .5.2_6Q,_5__9_$_.3_..8 .... 8__~_O__g .... 0_,3~_~ ........5_259.,6] 8~95 ~ 1.~ ....... .S~.2_:_._0.._0._E..__...4259,76 S S~28 ~ QO__E __ _~5..~_0._.5._,.~_7.._S_2__7__~_~_~_~ o_,..83~ __8654,6 ~_ ..... $3_.1. ,..9_O_E ..... _~_.~ 2_1__,_B._3__$ ~._~.6_6_,_04 L_5 ~_?_B_,..O_Q .... S__3_I_.EA___~I_E 0 ,..82-~ .......... 5~ 73_.,...~..~ 871 ~. 57_ ....... S31 ,.0....0 E ........ ~_38_3 ~..8..~_...$ ...... 3..~0~._,_. 3_~ E_ .... _5___5.~. 9_ ,_ 8.8 S._ ... 3! _ __4 9_ .__2_3 .... E. O...!9_e .............. 5.5~..9.,..~_c __8774,97 52.9.,_QQ_E 4~45,1._3 ..... s_ 3_4.3_8_,_.68 E__56!_9_,_.~__$__3]_~.~__._3._0_~ 1,.6_~_0 ..... ~.619_,52 __8836, Z 9__S_2~._,_.QQE .... _~ 5__0~_,._Z_8__.$ ..... 3_~__72 ~_.5_8_E. .... _5_689....,.0_6 ...... $___~1_ 3! ._~ ....... [ Q, ~3.8 ........... 56_8~_, 8.] ,40 8899,.~0 ..... SZ~_.,__O..P5 ..... ~ 5_6 8_,. 3 _% $ ..... 3._5.Q7.,_0_~ .... E ........ _.5..7_.5~_,Z~ _.~.._..}7 .... 30_.__~_4._._E ..... O,Z6~ ............ · 62 ..... _8..9.._6_._1..,62 .... SZ 9.,..P_O.E_ .... ~.6_2 8.:.~.~_S___~_5~_O_.,_5_Z_E 58 Z . 7_ ., 6._4.. __S . ._3 7_ Z~+_..._~_2_~.~__0_,.5.38 ......... 5..8£~,~_~ ,g8 9024,9_8_ ..... ~S_29,00E 4689e57 S 357~,18 E 5896,35'S 3.!._18_ 4.6 E 0.,_266 ............. 47 30 9141,81 9087.81 $29,00E ~_!59__,5~_.S___}.6.0..7_,__4.2 E ..... 5_9_6~.:.20.__'&.__3.7.__ 13 .... _~_._E__Q,O_O0 ........ 596~,..11 47 15 9165,51 9111__.,._.5..~ ...... S2_9_,D OE ~772.,.07_S___3.~_1._9 ,_9_.1___~ ....... 5..9..8_9_., 6_9___5._..3..7_. 1.0_ 5_7._.~ .... O..,.ll~._' ........ 5.989..~61 47 15 92~0,86 91_8_._6__,_8_6 ........ $.29__,_0._0E__~_8...43.,~6 ..... S ..... 36.59.,_.~3 E ....... 6_0_7_0.,38__S _.37 ........ 4_ 2.3 E ................. _0._,00..0 ......... 6070,31 7 1_5 __?_2.7~._ :_B_O_ ..... 9_.2.2_0__:8. Q _5_2.9_,.0._.0_5_ 4_8 ~_.5_.., ~_.7_. ..... s .... ~. 6.._7__7,23_. E_ ...... 6.1_06,74 __$ .3 7_ :1 __ 28 .... ~ ......... 0.,_00.0 ........610 6 ,_7~ HOLE CLOSURE 6106,74 FEET AT 5 37 1 28._E ........;"-i~ · ARCO__DS-9~_I_9- MAGNET-LC-.MUL-T-LSHOT SURV-E-Y ....................................................... DE-(~-,30 9- -tc) 77 MEASURED DEPTH AND OTHER DATA FOR EVER_..Y_.._E.V_E,N. .... 1,Q.Q .... F...[_E_T__0F___SUB_..SEA._DEPTH, ..................................................................................... TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH 154 254 554 654 754 854 95/.+ 1054 1154 1254 1354 1454 1554 165~ 1754 1854 1954 2o54 2154 DEPTH SEA DIFFERENCE CO~.~..E~Z. LO_B ....... !.C_TAL ..... CO.O.RD_I_NA_TES ..... 154, 100 0 0 ..................... ¢,._00_$ ....... _O.,_Q0...~ .................................................... 254, 200 0 .Q O,.0.0.._.$ .............. O.,.00_W 554, 500 0 Q ....... P..,0~ S ...0JOQ_~ 654, 600 0 q .................................. Q_,.~_0___5 ............... O_,..O0_,W 754, 700 0 854, 800 0 0 0,00 S. Q~O_~ 954, 900 0 _ ........ ~,OD__.5 .......~ ..... ~,_OQ_..~ 1054, __!._0_~.0 0 0 ~.,OQ_5 .................... ~,O..O__W. 1154, 1100 0 0 O,QQ. 5 ................. 0..,.0.0._~ 1.2.5.~ .......... 12~0 ............... ~ ...................................... 0 .................................................. ~_,oo..$ ...................... 0..,_0.0 ..... w ................ 1354, 1300 0 0 0,0.0_.5 ............ o_.,OO._~ .......................... 1454, 1~00 0 0 0,.PQ.__~ ........ ,__Q, 0_~._W !5._5_~, ........ 1.5.O.0 .............. Q .................................... 0 ......................................... 0,00._.5 ..................... 0,O0__.W 0 .......... 0, O_.__W ................... 1654. ...... ~..6.gO ................. 0 o.,.oo__$ o ............................. ' 1754, 1700 0 O 0,Q~..5 O,O~_W.. 1854, 1800 0 '0 0,~Q__..5.._.~ ..... _.0...~0.0 W 1954, 1~.0_Q .............. 0 ......................... O ............................... O,O.Q..S ............... 0,00_ W 2o5~, 2ooo o 0 Q.,.O0....~ .............. 0~0_0_.~ 2154, 2100 0 ...... ~ ...................... 0~.Q0.~ ............. 0_,.O.0._W ..... 0 O,..OO S.] .............. 0,00 _W ~__ 0 o,.0.0...~ O.,O.O .... W 0 0,.0¢__~ ......... O_,.O0_W 235~+ 2354, 2300 0 2454 2~+54, 2400 0 255~ 2554, 2500 0 0 0,00 S ............ 2654 2654. 2600 0 0 0,00 5 2754 2754, 2700 0 0 OiO1 N 2854 2854, 2800 0 0 0,21 N .2954 .2954 , 29_0_0 ......... _0 0 .____Z..,.8_0_..S 3055 3054, 3000 1 1 1!_:_~.6._ .5 3157 3154, 3100 2 1 24,72 S 3259 325~., 3200 5 3 41,51 S 3362 3354, 3300 7 2 61,31 5 3466 3454, 3400 11 4 3571 3554, 3500 16 5__ 0_: .0_0..__ W O,OO W .. O, 3_6__ E 2,75 E 8.8.1 E ...... 1_8_, 7_6._E 3_O~,_.3..Z__E .~.3.,_2~_E ...... ..5_7_.,_7__/~_E · A R ¢ 0 I~tEASURED DEPTH AND MEASURED DEPTH TRUE V E R T ! ¢ A L_S.U_EL ........ :~D.~_T_Y D V E9 T_ !CA_L .................................. ~. DEPTH SEA DIFFERENCE__ C~.R_R.E._.C__T_I_OjN_ ................. !.O.T..A_L ....... COORDINATES 3676 3654, 3600 22 6 3783 3754, 3700 29 7 169,86 5 3891 3854, 3800 36 7 204,43 5 411.3 .............................. .~.o.EA.~ ............... ~0oo ............... 5.8 12 ..................................... ,2~!, 5.~_ S 198, ? 7 E ~ 3..A6 ........ ~_2..5_~ .... ~_2.0P ............. ~1 .................................... 18 39.5.~ !l._._S ........ 251,8.6 E 4728 ~003 5141 5286 5432 5579 4~54, 4~00 ..... iA! ............................... 27 4554. 45~.0___11~ 23 4754, 4854, 5054, 5154, 611,69 S .........3~6,53 ...... E _ZOL.~.I $ ......... 383.7_3_~E 4700 2~..S .......................... 3~ 78.~,.6~_5 ........... 4900 33.~ ....................... , 44 95.!.,~%..$ ........ 528,03 ..... E 50OQ ...... 378 .................................. _~2 ..................... $.028.,~9_.$ ....... 602,6.6 ...... g 5100 425 47 1103,25__$ .................. ~8.0,1_8 ....... E __5200 ...... ~.7~ .................. ~9 _~1_1~%,.~..Z...S ......... 15~..,5.7 .... 5300 ........ 52.~ ........ 50 1~8.,_~_~ .......... 8.3~,.26 g __540~ .......... 577 53 1340.86 5 ......; .... 5!2_8. 5 2 5 ~ ' 5878 5354, 6031 5454, 6!83 555~, 6336 5654, 5600 682 53 6~+91 5754, 6649 5854e 5700 137 __5 _5. __5800 ,:._7. 94 57 59_0_0 ___. 8_ 5_ 3 59 __6_0_00__ .... 3!0 57 6!0.0 ...... 9.6.5 __55 62.0_0_ ......1020 55____ 6300 1073 53 68_07 69_64 6054, 7274 6254. 7a27 6354, lk2.3.,_Q_8_5 ........... 1000._,_2.5 .... E 15~ !,_29_$ ....... ! O~ 0_.,_1_7.._ E__ 1593_,_9.8__5_~ .... 1.160,_3_8 .... E 1 e 84,7 6 $ '._12 ~.2_,..12_E_ _~Z_76_~ 5.! ..... $ ..... 1~_~3~3.5 E 1_8_67 ,_~.~ $ ....... 1A03_ ~_33__ E __!9.5_6_,_.~.9__S ....LAS~_ ,_3.5_. E 2133,35 $ 1635,18 E 75_8_O 773_1_ 7883 6 kS_A., 6~_ .0.__0._ !_L26. 655~* 6500 1.177 6654, 6600 1229 51 52 6754, 6700 12.80 8187 8342 68_54, 6_fiO 0 1_3_33. 6954, 6900 1388 51 __5_3 55 8499 7054, 7000 1445 57 2305,44 5 1_78_6_._0.O__ E 2390,1 1 S 2474_3_8 $ _],_9_3_8.:_11_E 26 z+ 8,56 S 2_0_9__4..,._9.~,_E_ 27.3. 8,60 5 2_LZ6..~D_i_E _~AJ~CO_.~S.._ 9~_],9 ...................................................... MAGNEY_LC HUCTi3HOT_SU~VEY HEASURED DEPTH AND OTHER TRUE ........ ~EASURED VERTICAL SUB MD-TVD VERTICAL ...................... DEPTH DEPTH SEA DIFFERENCE CORRECTION. TOTAL CO0.R~_!~T.ES 8656 715~, 8812 725~, 8967 7354, 9121 7/+54, 9274 7554, 9/~2 ~+ 7654, 9572 775/+, __7200 1558 ' · 5'6__ 29 !_8__, 2_2._5_ ..... g 3_3~~5__,_50._ 730Q ..... _!.6_13 55 7~0~ ..... !_667 750.0_ .... ~.720 760__Q ....... 1_'t_70_ ..................... 7700 1818 9721 7854. 7800 1867 49 9874 795~, 7900 1920 53 10031 80~__.~o0.~ ....... ~..9.7:7 ............................. 57__ 825~. 8209 ......~!O~Q 63 10192 1035~ 34~7,80._~ .......... 2!66,66 ....... E_ 36~.8~.2___5. 2907.96 .E ....... ~7~Q,~..O..S ..... 2980.89..E 10516 8354a 10676 8~5~. 8~0.Q.__.22_2.~ ....................... 60 10 83 7 8 5 54, 8.~..Qq .... 2.2__~k ......................... 6 ~ 10996 865~, 8600 2342 59 11154 8754, 8700 2400 58 11308 885~, 8800 2a54 54 11459 8954, 8900 11608 905~, 9000 11756 915~, 9100 11903 9254, 9200 8300 ...... 2._1.6_2 ............................ 62 ........................... ._3~..5!._o].0 .._$ 312 Z+ , ~ 2 _.E ARCO DS M AG N_ E_T__ !_¢ _._MU_L_T_I_..S_~.O_T___S.U R_v_E_Y .............................................. D E C. _3 0., .... 19.7 ~ NTERPOLATED VALUE5 FOR EVEN 1000 FEE-T"'~F MEASURED BEPTH. TRUE M E:~.$U _R_.E D VER ]'_I_C__A_L ......... SUB ................ b E PT__H ....................... D_E_ ...P._T__H_ ........... _,SE:__A_ ........ _T_O_TA L .... _C O¢)_R D I.b.! .A___T_ E_S 1000 1000, 946. 2000 2000, 1946, 3000 2999, 2945, 4000 3953, 3899, 5000 ~751. 4697. 6000 - 5433, 5379, 7000 6076, 6022, 8000 6731, 6677, 9000 7375, 7321, 10000 8034, 7980. 11000 8656, 8602, o ,.._0__0 _S o ,_Q O___w_ 0.00 S 0,00 W 5.75 5 12.97 E 2~3.10 S 17~+.23 E 782 . 84 S ~+19 · 64 E 132~+,05 S ~ ....... . . 36~8.56 $ ~ 2893.82 E~ ~'- 800 1600- . _ _ ...... 2400-- '' I ! .... VERTICAL*' SECTION , .: . SCALE I" I 00" : -- ATLANTIC-RICHFIELD i CO. . . RADiUS!OF cuRVATURE --; ..... MAGNETIC MULTI-SHOT [ i , _. ...................... i ' .................................. ~_ ._: ....... i_ ._L: ..... 4800 ' ' -~ .- .......... ~ ......~-.-: ..... % , _! ...... ....... L .... : '_ ..... ; ...... :.. I ....... { , .. } ..... 5600 ~ ~ ........ ; .......... i .............. i ........... , ....-- ...., ........ ' ' , ......... i ........ ~[ ....... 1-~-~ --i ......... . ......... t ........ q~--r':' "--i .' ...... ~ ' ~ V .' i i T !- ' .-'-~: '--:---i.- ...., .... t ' ----'-: .... r ...... t- : ...... ~ ...... 1 ..... . -~ .... 6400 ._: _ I . I I ,. t i ..... i-'¥ .......... ?' ' : * ~ ............. [ i ..... i-~~, .... :i: ...... : ............ ' I .......T ..........~ ......... ~ ' d--~-d"-i ' i' : t ' j- - TV D.:i=: 927.5,~' 1 1 ? ' HORIZONTAL-~-VI EW ........ ! I '- i SCALE I" = IODO' ATLANTIC RIC'HFIELD CO. ' ........ ~ ........ 1}RiLU 'SITE-, .... 'g'-~-l'g-, ..... '- ..... . ............. , . ...... T ._~ ._~ ................. : ,MAGNETIC MULTI-SHOT-- ,' ' ................ ......................... ~ -~-~- 6000 640(~ ,, 7200 7600_: I Division of Oil and Gas C~nservation O. K. Gilbreth, Jr Dec~mg~_r 20, 1977 D~ Hoyle Blcw~nxt Preventer Equi~t ~~y,.~:~_ ~,~_~1977.- I de~ my ha~e at 7:00 AM for a 7:30 AM ~~ ~-~8:~0 AM~ via Arco char~_r to Prudhoe Bay. Our delayed d~ure flight arrived at Arco's strip at 10:35 /~4 wbmre I caught the bust to Arco base. Ben Davis picked me up and we arrived at drill site $9 at 11:15 AM.. Initial purpose of this trip was a BOPE test c~ Aroo's DS 9-19 whose drilling foreman was geith Bullard. Contract drilling rig was Rcwan $34 ~ toolgusher was O~in Graff. ~'ppling up was in progress. Tests began at 8:30 PM with shoe ~ 13 3/8" at 2714'. TWo stage Ko,ney pump and diesel ~ utilized in pressuring. The annular preven~ tested to 3000 psig. The outs~ wing val~e on the k~ll line leaked and while ~s were be/rig made, I ~ N2 backup bottles which tested 1900, 1950, 1950 and 1800 psig. Aucumulat~r pressure was 3000 psig. Upper pipe rams, outside valve on the kill line and outside ~alve ~ the choke I/ne tested to 5000 psig. Inside ~lves on the kill line and choke line and lower kelly valve tested to 5000 psig. Leaks in the kill line ~ valve, flanges on the choke ~ and choke manifold valve reserve pit ~ built, rig in good repair and well sign was up. Both dart and ball type~ floor valves w~re Ln place. ~ '26 flanges ~n--~'-~e manifold tested to 5000 psig. ~ pipe rams, blind rams and kelly cock tested to 5000 psig after. The nmnual adjustable choke was free mov~ and Swaoo superchok~ actuated fully c~ and fully closed o Tests w~re ~uded at 3:15 ~ and a field inspection report pre~ with the origJamal given to Keith Bull~, a copy mailed to Bob Hines and a copy attached to this report. ~December 7, 1977- I arrived ~at drill site #1 to await BOPE tests on DS 1-13. 9-19 -2- Dec~a~_r 20, 1977 ~ at 1:05 P~{, arriving in An~~ at 2:30 ~4 ~ at my ~ at 3:10 PM. In ~: I witnessed ~ooess~ BOPE tests c~ Arco's 5S 9-19. At~t "'-' ,.,"~" , :' ~.~. . ~~¥.~ ' - '~X ~ ~ = . ' = .- . :' ~ · v' s-".'., ' , ' ' ' ' · .' - ', ~ ' ~ : . .":':~.' '--:~t;' . .- ~_' ~ · . . · ' . ' '-. ( '. ' '' ..'-" -AI~ ~ Oil 'and Gas Conservation Co~i~ ~ - ' '~L ~ur ~ /' "''~]:'' ''/' .... ~-"' Field InSpeC~ion,'Report· :," g'..-.Permi.2No;~¢ , ~~ . Well/P~~ Se~,T/¢~RL~, ~ M Op6rator ~~ ~ ~.' Represented by~~.~ :_ Name & Number D~ Satisfactory lYpe Inspection Satisfactory lype Inspection Yes ~o Item (~kocat~on,~eneral Yes ~o Item {~'BOP[ lests (~,~'~ ( ) 1. Well Si~n (~ ( ) 15. ,~;~;Cas~n~ set 0~/~('~ ]6 1~ fluSd-( )~t~)mud () () () () () () () () 2. General Housekeeping (~)~ ( ) 3.. 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.lobser , , 9. BS&W~. , , , 10. Gr. Bbls. , , , ~ ( ) Final Aba~donm~n-t -- ( ) ( ) ( ) ( )- 11. P&A. Marker (~.) .... ( ) ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 13. Clean-up (~"* ( ) ( ) ( ) 14. Pad leveled ..... ~:,,, (~) ..... ( ) Total inspection Qbservation time~.};~?fhrs/da~s Total number leaks and/or equip, failures Remarks 17. Master Hyd. Control Sys.--,C;mmgpsig 18. N2 btl s ~,~'~,~,.~.~ t,<,".'~PS i g 19. Remote Controls' 20. Drilling spool- ,~? "outlets 21. Kill Li.ne-(~,)"Check valve 22. Choke Flowline ( ) HCR valve 23. Choke Manifold No. valvs,;~..-"" fl.as~ 24 Chokes-(~emote( )P~s. 25. Test P1Q'~-(¢,.,)~ellhd( )csg( )none 26. Annular Preventer¢~psia 27. B1 ind Rams¢;;u;~,,,,,,~,psia 28. P~pe Rams ~,~,,~,,,,~:ps~q ~; ~,,~ 29 Kelly & K~l~-Eock~~sig 30. Lower Kelly valve 31 Safety Floor valves-(¢-~BV (~-)"dart days or when ready~ Prudhoe Bay DS 9-19(xx-t2~10-15) Atlantic miCh~ield Per,it ~. 77-40 District Drilling Em~~ Atlantic Richfield ~ P. O. Box 360 ~ncb~rage, ~Alaska 99510 F~u~y ri-4~rs in. ~laska ~ ~~ drainage systems have bee~ classified as ~ for ~ spa~n~ or mtgrati~ of an~r=~us fish. Oparaticns in these ~ ~ sub~t to ~ 16.50.870 and ~he regulati~ prcz~tlgated there~ (Title 5, ~l.aska ~stra~ve Cod~). Prior to ~ing operations ~ ~ be con~ ~ ~ M~abitat Coc~dina~'s office, Depart- -m~nt-of Fish ~ ~. Pollution of any waters of ~ State is prohibited ~y AS 46, Chapter 03, Arti~e 7 ~ ~ .re~ttcns pr~~ thereunder (Title 18, Alaska Adm~~a~ ~, ~ 70) ar~ ~ the Federal Water Pollution Cc~l Act, as ~. Prior to ~ing operations you may be contacted by a representative- of ~he Department of En~tal Cx~sex~ation. Pur~ant ~ ~ 38.40, ~ ~re ~x~r State ~s, the Alaska Department f' .~ ~ is. ~ ~ !ied of ~ issuance of this .permit to drill. ~ ~ ~ in ~~~ field work, w~ ~ appreciate your notifyir~, this office wi~ 48 huurs after ~ well ~ ~. We %Duld also like to be notified so that a rep~ese~~ of '~ Division may be present to ?~tness tes~ ~ blowou~ preventer equ/~ b~_fcre surfac~ cas~ shoe is drilled. F. M. Brown -2- P. B. ~ 9-L9 June 15, 1977 In ~ event of suspensic~ ~r abandonment please give this ~f. fice adequate ~ ~ficatic~ so t~mt w~ may have a witness present. ~~ of Fish ~ ~, Habitat ~ w/o encl. D~partme~t of Erf~_rc~m~l Coru~rvat~ w/o encl. D~~t of ~, ~pe~isor, ~ Law ~liar~e Divisic~ w/o encl. Form 10-401 REV. 1-1-?1 STATE OF ALASKA SUBMIT IN IR' 'ATE OIL AND GAS CONSERVATION COMMITTEE la. TYPE OF WORK DRILL ~-1 b. TYPE OF WELL OIL GAS r--I S~LL [~. W~LL L] OTttER 2. NAME OF OPERATOR Atlantic Richfield CompanY 3. ADDRESS OF O~ERATOR P. O. Box 360 Anchoraqe, Alaska PERMIT TO DRILL OR DEEPE~.~ ;. DEEPEN [~] 4. LOCATION OF WELL At sur£ace 525'N & 250'E of SW cr Sec. 99510 SING LE .MULTIPLE ZONE ~ ZONE [--] 1, TI ON, R15E, UM 12, TION, R15E, UM , At proposed prod, zone 1400'N & 1570'W of SE cr Sec. 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approximately 6½ miles northeast of Deadhorse, Alaska API No. 50-029-20260 6. LEASE DESIGNA'I:,.)N AND SFRIALNO. '~'~:~L- 28327 7. IF INDIAN, ALLO'FTEE OR IPdBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. Drill Site 9-19 (xx-12'lO-l! 10. ~IELD~),ND POO~. OR W!L:>C' eruanoe uav Field Prudhoe .Oil Pool 11. SEC. T. R.. M., HOLE OBJECTIVE, Sec. 12, TION, RI5E 12. 14. BOND INFORMATION: . #8011- ~EStatewide Sure.~nCorNo. Federal Insurance Co 38-40 ~mo,n, $100,000. O0 ' 15.' DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, ff any) 1400 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 21. ELEVATIONS (Show whether DF, R¥, CR, etc.) 2650 21' Pad Elevation (Gravel) 23. 16. No. OF ACRES IN LEASE 2560 19.PROPOSED DEPTH 12188'MD 9361 'TVD 17. NO.ACRES ASSIGNED TO Tills WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK ';~ILL START Jan. 25~ 1978 PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FoOT GRADE ' sETTING DEFTH Quantity of cement ....... :91~" ....... ' .................. "' ............. ,94# H-40 . . 100'+ Circ to surf auDrox 500 s×,. . !7-1/2" ...... 13-3/8" .... 7,2# N-80 .... 2700'+ Circ ..to surf., approx 5500 .ax.. , 12'1/4'" 9,.-5/8"~ ,47# . N..-...80 .!lggq'T PtiO0'+ cmt,col~mn nn. ltl ~tao~..lC ........ , . & 500-95 . ..qOfl~+ cml nn ?nd qfan~ 19~+. cv . )0 sx Atlantic R~chfield Company proposes to dJrectSonally dril'l ~h~s ~ell to 12,188'+ HD, 9361 '+TV[ to produce the Sadlerochit zone. Logs will be run across selected intervals. - - A 13-5/8" 5000 psi Hydril and 13-5/8" 5000 psi pipe and blind rams will be used on the 13-3/8" casing. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of S½" 17# N-80 tubing, packer and necessary provisions for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. A non-freezing.fluid will be left in all uncemented annuli within the permafrost interval. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAbt: If proposal is to deepen give data on present productive zone and proposed new productive zone. It' proposal is to drill or deepen direcfionally. ~ve Fertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program, (This space for State office '.-:se) DATE: CONDITIONS OF A??R©','AL, IF ANY: District D.rj.!l i.ng. Engr. SAMPLES AND CORE CtIIPS REQUIRED [ MUD LOG [] YES [~ NO [ [] YES 50-029-20260 OILIER REQL'iREMENIS: ! DIRECTIONAL SURVEY REQUIRED A.P.I. NL'.'4ERiCAL CODE [~YES [] NO PERMIT NO. 77-40 ~ APPROVAL DATE June 15, 1977 APPOVEDBY ~-~ , _ TITLE' chai-riBc312 DATE: June 15_, 1977 --" '~See InstruCtion On Reverse Side £50' Well 19 2.74' Well 20 SEC. I SEC. ii SEC. 12 EXISTING WELL OR CONDUCTOR PIF:~E. A5 I~UILI WELL LUL,~i IL.Jr, l;:) WELL No. I;3 LAT. 70° 14' LONG. 148° I WELL No. 13 LAT. 70°14.' LONG. 148°14.' WELL No. 14. LAT. 70°I 4.' LONG. 148°14' WELL No. 15 L AT. 70 o LONG. 148° WELL No. 16 LAT. 70° LONG. i 4.8° WELL No. 17 LAT. 70° LONG. 148° WELL No. 18 LAT. '70° LONG. 148° WELL No. 19 LAT. LONG. WELL LAT. LONG. 4.6.838"Y 5 9~2 815.87 06.527"X 719, 456.54. 45.684' Y 5 942 699.'50 05,80¢" X 718 484.81 4.4..53Z"Y 5 94.2 582:.98 05.073"X 71 8 51:5.52 14' 4~5.377~Y 5 94-2 466.30 14'04..$52 X 718 54-1.52 ' 4.2 " 14. .221.Y 5 9~.2 349.60 14.' 03.613 X 718 570.52 14.,4'' 4.1.065",, Y 5 94'2 232..79 i 02.89:5 X 71 8 598.50 14' 39.910" Y 5 9,,-1.2 ! i 6.14 14'02.176" X 718 626,56 70°14; $8.7601,~,Y 5 94.2, 000.01 i 4,8 o I'$ 01.4.~2 X 718 655.18 No. 70° 14' 37.606~ Y 5 941 883.4.2 148 14'00.721' X 718 68.3..57 CERTIFICATE OF SURVEYOR I HERE BY CERTIFY THAT I AM PROPERLY REGISTERED AND L~CENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY IV1E OFt UNDEFt MY SUPERVISION AND ALL DIMENSIONS AN/~ OTHER DETAILS ARE CORRECT. , J / S~rvoyor / ARCO No. HVLNo 39-DS9-77 ATLANTIC RICHFIELD CO. AS BUILT DRILL SITE No. 9. WELLS No. 12,13 8~ 14 LOCATED IN PROTRACTED SECTION 1,T. ION.,R.15E,U.M. PREPARED BY HEWITT V. LOUN.SBUR¥ & ASSOC. 723 W. 6th AVENUE ANCHORA($E ,ALASKA DATE FEB. 1977 SCALE I" =200' CHKD BY PC FIELD BK. CHECK LIST FOR NEW WELL PERMITS 1. Is the permit fee attached ........ Yes No ' Remarks .... 2. Is well to be located in a defined pool 3. Is a registered survey plat attached ................ ~)~i- 4. Is well located proper distance from property line ......... ~p~ 5. Is well located proper distance from other Wells .......... 6. Is sufficient undedicated acreage available in this pool ...... /~/~22' 7. Is well to be deviated ...................... ~x? 8. Is operator the only affected party ............... ~]~: .9. Can permit be approved before ten-day wait ............. =%~,i:,. 10. Does operator have a bond in force ................. ll. Is a conservation order needed ................... 12. Is administrative approval needed ................ 13. Is conductOr string p~ovided .................. 14. Is enough cement used to circulate on conductor and surface .... 15. Will cement tie in surface and intermediate or production strings 16. Will cement cover all known productive horizons .......... ~.~ 17. Will surface casing protect fres'h water zones ....... /_ 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have Sufficient pressure rating - Test to -~s~,$ psig 20. Has DMEM approved Plan of Operation ................ Additional Requirements' Approval Recomm, ended · Geology: Engineering' HHH HWK ~,),~ '" LCS~,7~-RAD _~ Revised 11/17/76 Well Histo~ File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ No 'special 'effort has been made to chronologically organize this category of information. ,o 11 0OOO00 7?17777777 00OOOO 7777777777 11 0OO000 7777777777 000000 '777'7777777 Illi O0 O0 77 OO O0 '1'7 1111 O0 O0 77 O0 O0 77 11 O0 0000 77 OO 0000 77 11 O0 0000 't7 0'0 0000 77 11 O0 O0 O0 7'7 O0 O0 O0 11 00 O0 O0 77 O0 O0 OO 7'7 11 0000 OO 77 0000 OO 77 11 0000 O0 77 0000 OO 7:? 11 O0 O0 77 OO OO 77 11 O0 O0 77 O0 OO 77 111111 000000 77 000000 77 111111 000000 77 000000 77 066666 00OO00 222222 44 44 ??'?'?177777 666666 000000 222222 44 44 7777771777 66 O0 O0 22 22 44 44 77 66 O0 O0 22 22 44 44 77 66 O0 0000 22 44 44 77 66 O0 0000 22 44 44 77 66606606 O0 O0 O0 22 4444444444 '17 66666666 O0 O0 O0 22 444~444444 77 66 66 0000 O0 22 44 77 6~ 0~ 0000 O0 22 44 77 66 06 O0 O0 22 44 77 66 66 O0 OO 22 44 77 060606 000000 2222222222 44 77 ~06000 000000 2222222222 44 71 ,$TAF~T, USER PCAL [10707,O0247J JUB SlliP SE(J. ] DATE 05-MAi~-80 15:02:.~12 M(.)NiTL~R 5WS KLlOE34 dub-79. *START* USEF~, PCAL [1070'1,60247] JOb SHIP SE[a. 3 DATE 05-NAP,-80 15102:]2 MONITttR ~S KLlOL34 JUL-79' *START* I ii, II I iiii1:i II I I II Ii I I II Ii Ii t1111I i! IIii TTTT TTTT ,START* USER PCA6 [10707,60247] dUB Ship SgO. ~ DATE OS-MAR-80 MONITOR Sws KLIOE34 JUL-Y9. ,START* FILE: DSg. H:SHl/~AT.U<255>[10707 60247] CREATKD: 05-MAR-80 14141:42 PRINTr~u: 05-gAR-80 1~:02:55 QUEUE SVolTCHES: /~'ILE:FORT /COPIES:I /SPACiNG:I /6IMI. T:107 /FU~NS:NORM.AL 15:02:32 SH I P TO : Si~iPP ING iNSTRUCTIONS ISSUED 5-~IA,R-80 1 .~: 40 BY Glib PCCC VENTURA~, CALIFt]~NiA 9]003 PCCC IIIIII llIIiI 1I ii II II II ii II II Ii I1 IIllII IIIIII FF FI~' Y¥ YY YY 000000 000000 5555555555 000000 000000 5555555555 O0 O0 O0 O0 55 O0 O0 O0 O0 55 O0 0000 O0 0000 555555 O0 0000 O0 0000 555555 O0 O0 O0 O0 O0 O0 55 O0 O0 O0 O0 O0 O0 55 0000 O0 0000 O0 55 0000 O0 0000 O0 55 O0 O0 O0 O0 55 55 O0 O0 O0 O0 55 55 000000 000000 555555 000000 000000 555555 *START* !j&ER PCAL [10707,b0247] dub ~HiP 8gU. ~ONI:~UR Sw~ KLIOE34 JUL'19. *START* FILE: DSKH:VER1FY'O0~<OS!>['IO707pAiNTED: 05- -~AR 8015:0~:0560247] CREATED: QUEUE SWilCHES: /FILE:FORT /CCJPIES:I /8PACiNG:I /LIMiT:lO7 /POR~S:NOHMAL DATE 05-NAH-80 05-HAA-80 15:01:14 15:02:32 SCHLUt*!BERGER COMPUTING Ck;NTEt~ 10707,60247 REEL ~!E.ADE~ [~ENGI~!: 132 BYTES REEL NAME: P.C.A.L. SERVICE NAb~E: EDIT REEL CONTINUATION Nt..iI~BER: 01 PREVIOUS ~EEL .NAME: C(]SMENTS: L!S ~'URSAT COSTUMER TAPE DAI~L: 80/ 31 5 ~A'PE HE,ADEt~. LENGTH: 132 ~$YTES TAPE NAME: 60247 SERV ICE NAF~E: EDiT TAPE C{JN'I?INUA'I~ION NU~ER: Ol PREVIOiJ& TAPE NA~E: CSG:9.62501 1905/BTSZ:12,25 DATE: 80/ 31 5 PILE HEADER LENGTM: 62 BY'I~ES fILE NAME: EDIT .001 MAXIMUM PHYSICAh RECUR[) LENGTH: 1024 BYTES PREY iLJ[3S [~ 1LE NAME: ~'ILL C~MMENTS THE ~IgSI FIVE ~{]RDS ARE FROM ~ CASED HOLE CNL RUN UN 27-~AN-80. 2~E LAS~F 'IWO ~ORDS A~E ~RUM A CASED HOLE CaE RUN ON 26-DEC-77 AND DIGITIZED. ~ELI~ SI~'E 1Ni~UkblATIOt,i RECFjiRD bENGTH: C(3MP~N~: ~ Li.,L: ~'IELD: RANGE: T 0 ~ N: SEC TI {.~N: C {'1 Ij N T ~': 190 BYTE8 AT1, ANIlC RiCHFIeLD CO. DR1LLSIT~ 9'19 PRUDH.OE BA~ 10~ NORTh 8LuPE SPECIFICATION f~bOCKS; SVORD# UNIT,S AP,I[ API,, APl APl[ F,ILE~ 6IZ~; EXP PROC SAM REP DEPT SHIP'T F;'!r o o o o o 4 o o 1 08 o o GAP1 ~2 31 3~ 0 0 4 0 0 1 88 0 0 PU ~2 b8 0 0 4 0 0 1 68 0 0 C/C 42 42 I 0 0 4 0 0 1 ~8 0 0 CPS ~2 ]~ 92 0 0 4 0 0 I b8 0 0 CPS 42 4 93 0 0 4 0 0 1 ~8 0 0 GAP! 42 31 32 0 0 4 0 0 I 68 0 0 PO ~2 68 13 0 0 4 0 0 1 68 0 0 DEPTH 11~70o000 11 @00. 000 11700.000 11600.000 11500,000 11400.000 11.]00.000 11200.000 I 1. 100.000 1. 1000. 000 10900,000 10800. 000 10700. 000 10600.000 t050.4.000 VALUE MNFJMONiC VALUE O. 000 NPHI 0 ~ 000 17.160 GR 62,781 54. 100 NPHI 35. 660 42,900 GR 52, ]75 26,300 NPH I t. 5,180 49,764 GR 29,594 ~0,400 NPHIL 30,860 93.522 GR 18,797 15. 100 NPItI 27,500 103.$1 ~ bi{ 16.797 18."/00 NPHi 24,660 120. 978 GR 18. 391 68. 500 NPi-tI 30,700 63.063 GI~- 63.969 12~. 000 NP[i I 4,7,800 51. 480 GB 119.56:] 94. 700 NPHI 17.620 118.83.~ giq 10 ].563 '999.250 NPHi '999;25.000 -999.250 GR 89.563 -999.250 NPItl '99925.000 -999. 250 GR 70 .-175 -999.250 NPH1 -99925.000 -999,250 GR 72.750 '999,250 NPHI '99925.000 -999.250 GR 98.~75 -999.250 NPHI -999;25,000 '999,250 Gk 10<t,750 '999,250 NPHI -999~5,000 -999.250 GR -999.250 iC VAbUE 0,01~ 32,250 3.t38 31.~13 2.118 19.188 3.016 32. 500 2,80~ 33.219 2.~68 28.4~8 2.9~6 30.828 ~.826 52.906 2.250 ~7.031 -999.250 45.219 -999.250 42.]44 -999.250 -999.250 41.500 -999.250 40.188 -999.250 -999.250 ~qN t~.; MO N lC NC Nb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb VAbUE 9,438 120,549 t58.730 202,977 28'1.430 300.729 226,5i2 191.763 290.43~ -999,250 -999,250 -999.250 -999.250 -999.250 -999,250 i.,ENGTH: 1.~2 BYTES TAPE NANE: 60247 SERVICE NAME: EDIT TAPE CONTINUATION NUPIBEIq: O1 NEXT TAPE NAME: COMMENTS: 1,024 BITES DATE: 80/ ,~,1 5