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Home My WebLink About185-098CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:AOGCC Permitting (CED sponsored) To:Brooks, James S (OGC); Loepp, Victoria T (OGC); Davies, Stephen F (OGC); Dewhurst, Andrew D (OGC); Roby, David S (OGC) Cc:Carlisle, Samantha J (OGC) Subject:FW: KRU 1R-12 RWO 10-403 Date:Thursday, September 28, 2023 1:00:04 PM Attachments:KRU 1R-12 RWO 10-403 .pdf Hi James, Victoria, Steve, Andy, and Dave: FYI: Please see Jenna’s email. I noted this as cancelled in the 10-403 Excel log. Do I need to do anything else? Thank you, Grace Christianson Executive Assistant AOGCC (907) 793-1230 From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Sent: Thursday, September 28, 2023 11:25 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Ohlinger, James J <James.J.Ohlinger@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: FW: KRU 1R-12 RWO 10-403 Hello – We would like to retract this Sundry from submission. ConocoPhillips has decided to move this well to the RWO Sidetrack program that will take place later in 2024. The original submission doesn’t encompass our current plans for this well. Thank you, Jenna From: Taylor, Jenna Sent: Wednesday, July 12, 2023 8:30 AM To: aogcc.permitting@alaska.gov Cc: Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Subject: KRU 1R-12 RWO 10-403 Hello – See attached 10-403 for 1R-12 RWO. Please let me know if you need additional information. Thank you, Jenna 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8320'7672' Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY James Ohlinger james.j.ohlinger@conocophillips.com (907) 265-1102 CTD Engineer Tubing Grade:Tubing MD (ft): Packer: 7707'MD/6314'TVD Packer: 7908'MD/6456'TVD SSSV: 1807'MD/1807'TVD Perforation Depth TVD (ft):Tubing Size: J-55 7937' 9/3/2023 Packer: Camco HRP-1-SP Packer: Baker DB Permanent SSSV: Camco TRDP-1A-SSA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025635 185-098 P.O. Box 100360, Anchorage, AK 99510 50-029-21353-00-00 ConocoPhillips Alaska, Inc. KRU 1R-12 Kuparuk Oil PoolKuparuk Oil PoolKuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6750'7672'5489'1468 7732' MD 115' 3825' 115' 3953' 6737'8302' 16" 9-5/8" 78' 3916' Perforation Depth MD (ft): 7822-8111' 8267' 6395-6601' 2-7/8" 7" P s 66 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:40 am, Jul 12, 2023 323-389 Digitally signed by James J. Ohlinger DN: C=US, OU=ConocoPhillips, O=Wells - Coiled Tubing Drlling, CN=James J. Ohlinger, E=James.J.Ohlinger@ cop.com Reason: I am the author of this document Location: Date: 2023.07.11 15:35:47-08'00' Foxit PDF Editor Version: 12.1.2 James J. Ohlinger BOP test to 2500 psig Annular preventer to 2500 psig DSR-7/12/23 10-404 X X MDG 7/17/2023 VTL 7/17/23JLC 7/17/2023 07/18/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.18 00:09:08 -05'00' RBDMS JSB 071823 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 11, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: James J Ohlinger Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 1R-12 (PTD# 185-098). Well 1R-12 was drilled and completed in July of 1985 as a producer into the C, B & A-sands. In October of 2019 an RBP was set ~ 7732' MD, and became stuck. A CTU milling BHA was then deployed to mill out the plug, and became stuck also in May of 2020. If you have any questions or require any further information, please contact me at +1-907-229-3338. The selective will be pulled and replaced. 1R-12 RWO Procedure Kuparuk Producer CTD Setup PTD #185-098 Page 1 of 2 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests. 2. Dummy all but lowest GLM in upper completion. 3. CMIT-IA to 2500 psig. 4. Cut the tubing nominally at ~7665’ RKB, 10’ below the lowest GLM 5. Install BPV and prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nordic 3 on 1R-12. Pull BPV if need to circulate. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. Retrieve Tubing, Packers, and Blast Ring Tubing Section 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 2-7/8” tubing down to cut (~7665’ RKB), and retrieve 2-7/8” tubing stub 6. Pull first packer with 2-7/8” tubing down to on-rig cut at ~7725’ RKB. 7. Washover tubing section and mechanically cut the tubing ~7745’ RKB. 8. Overshot tubing and pull blast ring section down to on-rig cut at ~7903’ RKB, then pull to surface. Cleanout Run 9. Perform a Cleanout run if necessary, based on tubing condition and dress off 2-7/8” tubing stub if necessary. Install in 2-7/8” Tubing with selective 10. MU 2-7/8” tubing with selective completion, RIH and correlate completion so Kick Off Joints are at correct depth. 11. Once on depth, set packer and space out as needed. 12. Pressure test tubing to 3000 psi for 5 minutes. 13. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 14. Confirm pressure tests, then shear out SOV with pressure differential. 15. Install BPV. 16. ND BOPE. NU tree. 17. Pull BPV, freeze protect well, and set BPV if necessary. 18. RDMO. Post-Rig Work 19. Pull BPV 1R-12 RWO Procedure Kuparuk Producer CTD Setup PTD #185-098 Page 2 of 2 General Well info: Wellhead type/pressure rating: FMC Gen III Production Engineer: Jennifer McLeod Reservoir Development Engineer: Joe Versteeg Estimated Start Date: 9/3/2023 Workover Engineer: James Ohlinger (229-3338, James.J.Ohlinger@cop.com Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 2-7/8” completion down through selective, install a new 2-7/8” completion with selective across the C-sand and stacked packer. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed 8/12/2019 CMIT-TxIA Passed 10/23/2019 MIT-OA Passed 3/17/2020 IC POT &PPPOT PASSED – 8/10/2019 TBG POT &PPPOT PASSED – 8/10/2019 MPSP: 1468 psi using 0.1 psi/ft gradient Static BHP: 2051 psi / 5833’ TVD measured on 11/7/2015 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: CTMD (Top of fish) 7,672.0 5/26/2020 1R-12 rogerba Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: CTU BHA left in hole. RBP has been partially milled 5/26/2020 1R-12 rogerba Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 37.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 65.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,952.8 Set Depth (TVD) … 3,824.7 Wt/Len (l… 36.00 Grade K-55 Top Thread BUTT Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 8,302.0 Set Depth (TVD) … 6,737.0 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 34.5 Set Depth (ft… 7,936.5 Set Depth (TVD) (… 6,476.3 Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE 8RD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 34.5 34.5 0.08 HANGER FMC TUBING HANGER 3.500 1,807.2 1,807.1 0.93 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE (Locked Out 4/9/94) 2.313 7,689.5 6,301.2 45.07 SBR CAMCO OEJ SBR 2.297 7,707.0 6,313.6 44.99 PACKER CAMCO HRP-1-SP PACKER 2.344 7,821.3 6,394.6 44.85 BLAST RING BLAST RING OD 3.5" 2.441 7,906.5 6,455.0 44.77 LOCATOR BAKER LOCATOR SUB 2.406 7,907.5 6,455.7 44.77 PACKER BAKER DB PERMANENT PACKER 3.250 7,911.2 6,458.3 44.76 SBE BAKER SEAL BORE EXTENSION 3.250 7,928.2 6,470.4 44.73 NIPPLE CAMCO D NIPPLE 2.250 7,935.8 6,475.8 44.72 SOS CAMCO SHEAR OUT SUB 2.438 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,672.0 6,288.9 45.17 FISH CTU BHA stuck in the hole during milling operations 05/26/2020 (1.56" Catch G Fishneck, OAL = 15.85') Detailed BHA schematic of fish in Working well file 5/26/2020 0.000 7,732.0 6,331.3 44.96 Plug 2.225" PIIP RBP (CPP287018SC) w/ Equalizing valve (CPEQ28701SC). OAL 9' Max OD 2.225" (****RBP was partially milled by CTU 05-23-2020****) 10/23/2019 0.000 8,000.0 6,521.5 44.60 FISH DROPPED 1.5" GLV w/RK LATCH 10/27/2005 10/27/2005 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,822.0 7,834.0 6,395.0 6,403.5 C-1, UNIT B, 1R -12 8/9/1985 12.0 IPERF 120 deg. phasing; 5 1/2" Scalloped HJ 7,842.0 7,850.0 6,409.2 6,414.9 UNIT B, 1R-12 8/9/1985 12.0 IPERF 120 deg. phasing; 5 1/2" Scalloped HJ 7,859.0 7,871.0 6,421.3 6,429.8 UNIT B, 1R-12 8/9/1985 12.0 IPERF 120 deg. phasing; 5 1/2" Scalloped HJ 7,975.0 8,030.0 6,503.7 6,542.8 A-4, A-3, 1R-12 8/9/1985 4.0 IPERF 90 deg phase;4" Carrier HJ II Gun 8,051.0 8,083.0 6,557.8 6,580.6 A-2, 1R-12 8/9/1985 4.0 IPERF 90 deg phase;4" Carrier HJ II Gun 8,104.0 8,111.0 6,595.6 6,600.6 A-2, 1R-12 8/9/1985 4.0 IPERF 90 deg phase;4" Carrier HJ II Gun Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 1,846.7 1,846.6 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,265.0 8/29/2006 2 3,102.4 3,087.3 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,290.0 8/29/2006 3 4,012.9 3,875.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/1/1998 4 4,551.0 4,293.0 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,285.0 8/12/2019 5 5,056.4 4,616.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/25/1992 6 5,591.4 4,939.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/27/2005 7 6,129.8 5,272.1 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,275.0 8/29/2006 8 6,634.0 5,591.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/25/1998 9 7,108.9 5,905.0 CAMCO KBMG 1 GAS LIFT OV BK 0.188 0.0 3/21/2020 1 0 7,644.9 6,269.8 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/16/2006 1 1 7,746.2 6,341.4 CAMCO KBMG 1 PROD DMY BEK 0.000 0.0 2/24/1991 Close d 1 2 7,814.8 6,390.0 CAMCO KBMG 1 PROD DMY BTM 0.000 0.0 10/11/2010 1 3 7,893.9 6,446.1 CAMCO KBMG 1 PROD DMY BTM 0.000 0.0 10/12/2010 Notes: General & Safety End Date Annotation 3/11/2020 NOTE: Surface casing leak at ~40' repaired with SealTite pill 8/10/2019 NOTE: BH Welded Passed Gas and Fluid MITOA 10/15/2010 NOTE: View Schematic w/ Alaska Schematic9.0 (2 PAGES) 1R-12, 5/27/2020 11:55:18 AM Vertical schematic (actual) PRODUCTION; 35.0-8,302.0 IPERF; 8,104.0-8,111.0 IPERF; 8,051.0-8,083.0 IPERF; 7,975.0-8,030.0 FISH; 8,000.0 SOS; 7,935.8 NIPPLE; 7,928.2 SBE; 7,911.2 PACKER; 7,907.5 LOCATOR; 7,906.5 PRODUCTION; 7,893.9 IPERF; 7,859.0-7,871.0 IPERF; 7,842.0-7,850.0 IPERF; 7,822.0-7,834.0 PRODUCTION; 7,814.8 PRODUCTION; 7,746.2 Plug; 7,732.0 PACKER; 7,707.0 SBR; 7,689.5 FISH; 7,672.0 GAS LIFT; 7,644.9 GAS LIFT; 7,108.9 GAS LIFT; 6,634.0 GAS LIFT; 6,129.8 GAS LIFT; 5,591.4 GAS LIFT; 5,056.4 GAS LIFT; 4,551.0 GAS LIFT; 4,012.9 SURFACE; 37.0-3,952.8 GAS LIFT; 3,102.4 GAS LIFT; 1,846.7 SAFETY VLV; 1,807.2 CONDUCTOR; 37.0-115.0 HANGER; 34.5 KUP PROD KB-Grd (ft) 37.10 Rig Release Date 7/21/1985 1R-12 ... TD Act Btm (ftKB) 8,320.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292135300 Wellbore Status PROD Max Angle & MD Incl (°) 53.53 MD (ftKB) 5,300.00 WELLNAME WELLBORE1R-12 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT 1R-12 Current Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft) Conductor 115 115 16 15.06 65 Surface 3953 3825 9-5/8 8.92 36 Production 8302 6737 7 6.28 26 Tubing 7937 6476 2-7/8 2.44 6.5 COMPLETION Camco TRDP-1A-SSA Safety valve ~ 1807' RKB (Locked out 4/9/94) 2-7/8" 6.5# J-55 EUE 8rd Tubing to surface Camco KBMG gas lift mandrels Camco OEJ SBR 7690' RKB (2.297" ID) Camco HRP-1-SP Packer @ 7707' RKB (2.344" ID) 2-7/8" w/ Blast Rings (22') @ 7821'-7853' RKB 3-1/2" Blast Jts. @ 7853'-7890 Baker DB Permanent Packer @ 7908' RKB (3.25" ID) Baker SBE @ 7911' RKB (3.25" ID) Camco D-nipple at 7928' RKB (2.25" min ID) Surface Casing Production Casing Conductor A-sand perfs 7975' - 8111' RKB C&B-sand perfs 7822' - 7871' RKB 2.225 PIIP RBP ~9' OAL partially milled ~3' - 5/23/20 @ 7732' RKB 31.45' jt between Packer&GLM CTU Milling BHA ~16' OAL @ 7672' RKB Merla TGPD @ 7645' RKB Camco KBMG @ 7746' RKB 201' Eline cut ~ 7665' RKB Eline cut ~ 7725' RKB ELine cut ~ 7903' RKB OS Tubing cut ~ 7745' RKB 1R-12 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Conductor 115 115 16 15.06 65 H-40 Surface 3953 3825 9-5/8 8.92 36 K-55 Production 8302 6737 7 6.28 26 J-55 Tubing 7937 6476 2-7/8 2.44 6.5 J-55 COMPLETION Nipple profile 2-7/8" 6.5# L-80 EUE 8rd Tubing to surface KBMG gas lift mandrels 2-7/8" x 7" packer KBMG Production mandrels 2-7/8" x 7" packer Nipple profile Poor Boy Overshot Baker DB Permanent Packer @ 7908' RKB (3.25" ID) Baker SBE @ 7911' RKB (3.25" ID) Camco D-nipple at 7928' RKB (2.25" min ID) Surface Casing Production Casing Conductor A-sand perfs 7975' - 8111' RKB C&B-sand perfs 7822' - 7871' RKB 7908' RKB 37' ELine cut ~ 7903' RKB ~ 7781' RKB DSR-3/24/2020 x Surface casing SFD 3/26/2020 -00 VTL 4/8/20 RBDMS HEW Carlisle, Samantha J (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophiIIips.com> Sent: Thursday, March 19, 2020 9:00 AM To: Carlisle, Samantha 1 (CED) Cc: Well Integrity Compliance Specialist CPF1 & 2 Subject: KRU (PTD 185-098) 10-404 for SealTite Repair Hi Samantha, A 10-404 Report of Sundry Well Operations packet has been delivered to the mail room for KRU producer 111-12 (PTD 185-098) for a surface casing repair with SealTite. We are notifying you because we are unsure if there will be a delay in the mail delivery due to the cancellations of North/South bound flights from the slope. If you have any questions or would like an electronic copy of the packet, please feel free to contact us. Regards, Paul Duffy for Jan Byrne/Dusty Freeborn Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 41W'ELLS TEAM conacdfidrlps THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Jan Byrne Well Integrity Compliance Specialist ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 1R-12 Permit to Drill Number: 185-098 Sundry Number: 320-072 Dear Mr. Byrne: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alciska.gov Enclosed is the approved application for the 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, VJSPrice DATED this` J day of February, 2020. RBDMS l "FEB 14 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED FEB 11 2020 OV -5 2,f 13I 2.0 1. Type of Request: Abandon LJ Plug Perforations ❑ Fracture Stimulate LJ Repair Well U pera Ions shutdown LJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Appro{vved((pprogram ElPlug for Redrill ❑ Perforate New Pool ElRe-enterSusp Well El Alter Casing El Other: $eslTite repair❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhllll s Alaska Inc. Exploratory ❑ Development D Stratigraphic El Service ❑ 185-098 3. Address:6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50029213530000 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require a spacing exception? Yes ❑ No ❑Q , KRU 1R-12 9. Property Designation (Lease Number): 10. Field/Pool(s): , ADL0025635 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD). 8,320' 6,750' 7,732' 6,331' 7,732' Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 115' Surface 3,916' 9-5/8" 3,953' Intermediate Production 8,267' 7" 8,302' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7,822'-8,111' 6,395'-6,601' 2.875" J-55 7,936' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - CAMCO HRP -1 -SP PACKER MD= 7707 TVD= 6314 PACKER - BAKER DB PERMANENT PACKER MD= 7908 TVD= 6456 SAFETY VLV - CAMCO TRDP-IA-SSA SAFETY VALVE (Locked Out 4/9/94) MD= 1807 TVD= 1807 12. Attachments: Proposal Summary ❑' Wellbore schematic ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development M Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/17/2020 OIL ❑� WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jan Byrne Contact Name: Jan Byrne Authorized Title: Well Integrity Compliance Specialist Contact Email: N1617@conocophiilips.com Contact Phone: 907-659-7224 Authorized Signature: G„ Date: 2!7/2020 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS� FEB 14 2020 Post Initial Injection MIT Req'd? YesNo ❑ Spacing Exception Required? as No Subsequent Form Required: /D " -40 APPROVED BYlJ ,1 to Approved by: COMMISSIONER THE COMMISSION Date: (/I( 3 e�L//�� vrc z�ij�zo /'1 ��111 ///111 1 ♦. !!��/ t it Form and rorab3 0.eGised a ov Approved appl�a9o� �11d,��lydl►s t�m the date of approves? 7 // tach ena�sv'�n Duplicate v v H �lII7?A 1R-12 DESCRIPTION SUMMARY OF PROPOSAL In August 2019 1R-12 had a Bradenhead repair weld performed which was reported to the AOGCC by 10-404. A few days after passing diagnostic tests post Bradenhead repair weld the conductor was observed to have fluid exiting it. Diagnostics tests were performed and indicated that the leak was at approximately 20'. A plan for excavation and surface casing sleeve installation was implemented per sundry # 319-423. After excavating down 20' and removing the conductor and cement around the surface casing the OA was pressure tested. No leaks were observed on the visible surface casing, but the conductor at the base of the excavation had bubbling fluid. An additional Surface Casing Leak Detect was performed and determined there to be a leak in the surface casing at approximately 38.5'. This was corroborated by string line which showed the fluid level to be at approximately 40'. As 40' is too deep for excavation an alternate plan was made and CPAI now intends to pump a pill of SealTite Gel -Seal down the OA to the leak depth and then use N2 to squeeze the Gel -Seal out the leak to repair said leak. An N2 gas cap will be left on the OA so that the annulus pressure remains monitorable. Pertinent work steps are listed below. 1. Depress OA -FL to leak depth with N2. 2. Pump 40 gallons of 6.2 ppg Gel -Seal into the OA. This gives 32' of coverage. 3. Pressure up OA with N2 in 500 psi steps until the pressure begins to fall off indicating that the Gel -Seal is entering the leak point. Continue pressuring the OA until the OA holds test pressure for 30 minutes. Once the OA has shown to hold test pressure the OA pressure will be left for 24 hours to allow the Gel -Seal to cure. 4. Perform MIT -OA. 5. Bring well online and confirm Seal-Tite repair holds. 6. Submit 10-404. KUP PROD Legal Weliname 1R-12 Common Wellname1R-12 Well Attributes Angles MD TD Conoco Nhillips `- dale Name we„ re Apw welds mwa Maxax MD1& Aa1Btm,nKB) Alaska, Inc. KUPARUK RIVER UNIT 500292135300 PRODe$ 5353 530000 RSJ00 - I SSSV: LOCKED OUT Last Tag AK All WellboresSchem AnnaM„an K9) Endmre LesIMa4By weEba„ Last Tag. 51-ed79WD 11/1/2015 pp,1R-12 Last Rev Reason9nc.. Bllz ¢nits zz ems laoWaD PnnoUllon End Dale Iesl Mod By Wellbore -- Rev Reason'. Set RBP. Set catcher Pull OV. 11N23/2019 lama] Notes: General & Safety End Dare I annades- weuDore coxpuc7oR;a7a 1150 sAFSTv e4v, vem.z GAS LIFT: f,&8.> BAs uFT: 3,102.4 SDR.E.aT.Dass2e- G>5 LIR:4.012p GAS Ul 4.651.0 Bet LIFT; 5.06e.4 GAS UFT: e.1I Safi LlFI.RODe Ges.F;6.i GAs uFr, ).fats GRS LIFT; 76N,9 SOR.76995 DACKeR ZIDio caol,r:7.7m.D PW,7,r32o - PRODUCTION; 7746.a PROWmIgx'. 70148 - Iv¢RF;[tao7exB- IPSRF7Q0,7SD.0- INERF:78DR&T& PROOUCIION; 769]9 LOGTOR; ].90i.5 PACKEA;7,9075 seE: Lenn RIPPLE 2B1a3 toy:79X., Flaw a.DDD.D IPERF ].91568,N0,0- IPERF'.&Gfloe,aR.o- IP al es.00.",i,- FROWCTION:ffiP tal0 L 8 /1 012 01 9 NOTE: BH Weltletl Passed Gas antl Fluitl MITOA 1R-12 .Casing Strings Set➢epm FID, wut¢n cap oee ones) Werin Tov(nxe) safoepa@Ica) IRKID el. rad. Tep ru- vat'll CONDUCTOR 16 'ate. 370 1150 115.0 fi5.00 Hi0 WELDED 1ft-12 SURFACE 9518 892 370 3,952.8 3. 47 36D0 K-55 Bt1TT 1R-12 PRODUCTION > 6.28 350 0,3020 6]3]0 2600 J-55 BTC 1R-12 Tubing Strings Dea g Mar xommal DD gn) IO,In) amapm Top (RMa 6(2X8) Sem.pa,rvo, 12X8) vD avd, Glada TopTmad WNIWre TUBING 21/8 2A4 34.5 ]9365 64]6.3 6.50 J-55 EUE BRD 1R-12 Completion Details Top Ov. Topinal Neal TO, ,RKB, 1°) ,Iem Des Com ID (in) W,anne 34.5 34.5 008 HANGER FMC TUBING HANGER 3.500 1R-12 IADT2 1,807.1 0.93 SAFETY VLV CARCO TROP -IA -SSA SAFETY VALVE (LGcked Out 4SY94) 2,313 1R-12 ],6895 6,3012 450) SBR CARCO OEJ SBR 2.297 1R-12 ],70).0 6,3136 44.99 PACKER CAMCO HRP -1 -SP PACKER 2.344 1R-12 7,821.3 6,394.6 44.85 BLAST RING BLAST RING OD 3.S 2.441 1R-12 7,906.5 6,455.0 44.W LOCATOR BAKER LOCATOR SUB 2AO6 1R-12 2907.5 64557 44D PACKER BAKER DB PERMANENT PACKER 3.250 1R-12 ),911.2 6,458.3 44.76 SBE BAKER SEAL BORE EXTENSION 3250 1R-12 1,9282 6 4704 44.73 NIPPLE CASCO O NIPPLE 22! iR-12 7,935.8 6,4]5.8 M.72 SOS CARCO SHEAR OUT SUB 2.438 1242 Other In Hole (IAlireline retrievable plugs, valves, pumps, fish, etc.) Top ITVDI %PIRKBI IRKB, Topled l°) Des Com Run 0s. ID IIn) evalbort ),]28.0 6,320.5 4496 Catcher 2.24"x48.5°Catcher 10/23/2019 0.000 IR -12 ),]320 6,331.3 44.96 Plug 2.225 PI IF HER CPP2870185C)wl 10/23/2019 SON) UP -12 Equalain9 valve (CPE028]O15C). 01 MaxOD2225- 8.01100 6,521.5 4460 FISH DROPPED IF GLV veRK LATCH IM27120D5 IR -12 10127120D5 I As Liner Details TopfNIn van o as D' Twesse) Oz Topi ll°) IMM Des tom Im) Wens, 370 370 0.00 CONDUCTOR 15.062 iR-12 3].0 310 0.08 HANGER 8921 iR-12 Perforations & Slots Tppfton B[mIKB) Xde) efmm (KBD R United 2snse Date S„m Da:Td@ (sMl TyPo Com Wellbor¢ 1,822.0 1,834.0 6.3950 64035 G1, UNIT B,1R- 12 BI91985 12.0 (PERF 120de0.DNasing:512' Srall0petl HJ 1R-12 ),842.0 1,850.0 6,4092 6,4149 UNIT B,1R12 81911905 12.0 IF F 120 SeallopatHJ tleg. phasing: 512° 1R-12 7.9590 7,871.0 6,421.3 6,4298 UNIT B, IR -12 81911985 12.1 (PERF 120 Scalloped tleg phasing; 512° HJ 1R-12 7975.0 0,030.0 6,5037 --6-5-42T 774. A -31R-12 0511985 4.0 IPERF 90 II deg pbase:4-Carrier Hl Gun 1R-12 8,051.0 8,083.0 6,557.0 6580.6A -2,1R-12 819/1985 4.0 IPERF 90 deg Sund4"Carrier HJ Gun 1R-12 8,104.0 8,111.0 6,595.6 6,600.6 A-2, 1R-12 819/1985 4.0 IPERF 90 II deg phase 4"Carrier HJ Gun 1R-12 Mandrel Inserts at all Pan an No Ta(LNLa D) biles, MM1 tinRO e TRun Top IRKB) (RKB) Make easedeased00 (In) IType Type I(psi) Rap Com Wellbort 84 1 1,61 1,846.6 CARCO KBMG 1 GAS LIFT GLV BK 0.1.1 56 1,265.0 O129/200fi 1R-12 06 2 3.1024 3,087.3 CARCO KBMG 1 GASLIFT GLV BK DAN 1,2900 8129/2006 m-12 3 4.012.9 3.815.1 CARCO KBMG 1 GqS LIFT 0.MY B 000 K 0. 00 7/1/1998 1R-12 4 4,551.0 4,293.0 CARCO KBMG 1 G45 LIFT GLV BK 5.180 1,2850 BlIV2019 1R-12 5 5,056.4 4,616A CARCO KBMG 1 GAS LIFT MY BK 0.000 00 102511992 1R-12 6 5,5916 4,939°9 CNes1W KBMG 1 GAS LIFT My BK 0.000 0.0 102712005 1842 7 6,1298 5272.1 CASCO KBMG 1 GAS LIFT GLV BK 0.188 7275.0 012912006 1R-12 8 8,634.0 5.5914 CARCO KBMG 1 GASLIFT DMY BK DOW 00 612511998 1R-12 9 7.1009 5.905.0 CAMCO KBMG 1 GASUFT OPEN BK 0.0 10 Snoi9 I 1R-12 1 1,644.9 6,2698 MERLA TGPD 112 GAS LIFT MY RK 0°000 0.0 811612005 I 1R-12 0 1 ],74fi.2 6,3410 CARCO KBMG 1 PROD DMY BEK 0.000 0.0 V24/1991 Close 1R-12 1 d 1 7,8148 6.3900 CPMCO WOW -1 PRO D MY BTM 0.000 0.0 10/1112910 113-12 2 1 1,893.9 6,446.1 CARCO KBMG 1 PROD My BTM 0udu 0.01N1212010 1R-12 3 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 07 February 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 1R-12 (PTD 185-098) to use SealTite to repair a surface casing leak (OAxAtmosphere). Please contact Dusty Freeborn or me at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Loepp, Victoria T (CED) From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Wednesday, February 12, 2020 1:35 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 1 R-12(PTD 185-098, Sundry 320-072) Repair SC w/ SealTite Attachments: 111-112 180 day TO trend 2.12.20.pdf, MIT KRU 1 R-12 diagnostic CMIT-TxIA 10-23-19.xlsx Follow Up Flag: Follow up M 5 5 Flag Status: Flagged /n IT- -r a5 y Exna z Victoria, G fid e 1R-12 09/09/2019 Well was shut in. 10/23/2019 Well was secured with an RBP at 7732'. The well was circulated out and Passed a CMIT-TxIA to 2500 psi. After the —32' of SealTite is pumped into the OA, N2 pressure will be used to inject the SealTite out the leak until holding pressure, after which the sheared SealTite will be allowed to cure and repaired the leak. The exact amount of SealTite that will be injected through the leak is unknown, but based off the calculated 0.1247 GPM leak rate that was acquired during diagnostics the belief is that not much will be needed. The liquid SealTite pill that is left in the OA will remain a liquid and a pressured N2 gas cap will remain above the SealTite pill. Dependent upon the repair process we could end up with different numbers, but for example there could be 25' of liquid SealTite above the leak and a 15' N2 gas cap. Please let me know if you need any additional information. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, February 12, 2020 10:30 AM To: Byrne, Jan <Jan.Byrne@conocophillips.com> Subject: [EXTERNAL]KRU 1R-12(PTD 185-098, Sundry 320-072) Repair SC w/ SealTite Jan, Could you please provide additional information on this well such as: T/I/O plots Status of well Latest MIT results Will there be a column of Seal Tite left in the OA? The N2 cap would be ^39' in the OA? 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.Loeoo(a).alaska oov 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 Loeoo@alaska aov Annular Communication Surveillance Well Name: 1R-12 Start Date: 16 -Aug -2019 Days: 180 End Date: 12 -Feb -2020 Pressure Summary 1600 170 1400 1200 150 LL N 1000 130 v d w N 800 110 v n 600 n 90 E 400 ~ 200 70 0 50 mmmmmmmmmmmmmmmmmmo+o+o+mmmmmo+mmmmmmmmmmmmmmmmmmm000000000000000 MrlM Mrl'4'i Mei rl rlMeifi'i Nei rl rl rlri e4 rl rl rlMMMMei Mrl'i rl ei e -Ir -I ri ri rl rl ei'i eiMMNNNNNNNNNNNNNNN mnom mmmanann¢¢nnn��+-�Y�Y, o000000000vvvvvvvvvv T',»»»»»WWwvuuuoWccccctccccww » 3» >vavvvvvavv rovvnvmmmmmmvvvv aaaaaa��0000000000zzzzzzzzzz0000000000,,,��,,, „LL LLLLLL �O01N �(1 W ei Mlp OlN V10]M V hOM1lO41N V1M r•IahONN W ei OI�OMIp OINK W r•1 V I�OM4b Ol`~�NOMlp 01N V1 W e -1M lD 01N M MNNNM MMMNNNM MMMNNNM MMM NNNN MMMNNNN ri ei eiMNNNM M —WHP —IAP —OAP —WHT Annular Communication Surveillance Bleed History WELL—ID 1R-12 111-12 111-12 111-12 111-12 1R-12 1R-12 111-12 TIME 9/6/19 9/5/19 9/3/19 9/1/19 8/29/19 8/27/19 8/18/19 8/18/19 STR-PRES 266 335 6 40 60 120 280 60 END-PRES 0 260 300 1 0 1 1 1 DIF-PRES 266 75 -294 39 60 119 279 59 CASING OUTER OUTER OUTER OUTER OUTER OUTER OUTER OUTER SERVICE GLO GLO GLO GLO GLO GLO GLO GLO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: lim.reg00alaska.gov- AOGCC.Insoectorstaalaskaaov: Dhoebe.brooks(Walaska.aov OPERATOR: ConomPhillips Alaska Inc FIELD / UNIT / PAD: Kuparuk / KRU / 1R Pad DATE: 10/23/19 OPERATOR REP: Daniel Shows AOGCC REP: PTD chris.mIIaceaalaska aov Well IR -12 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 185098 Type Inj N Tubing 0 2525 2500 2500 Type Test P Packer TVD 6314 BBLPump 2.5 IA 75 2525 2500 2500 Interval O Test psi 1579 BBL Return 3.2 OA 120 130 130 130 Result P Notes: Diagnostic CMR-T%IA for secure Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Nom: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBI -Pump IA Interval Test psi BBL Return OA Result Nog: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBI -Pump IA Interval Test psi BBL Return OA Result Nems: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Imerval Test psi BBL Return OA Result Notes: TYPE INJ Cade, W = Water G = Gas S = slurry 1= Industrial Wastewater N = Not Injecting TYPE TEST COW, INTERVAL Codes Result Cotler P=Pressure Test I: Initlal Test P=Pam O= OMW(describe in Notes) 4=Four Year Cycle F=Fail V= Reputed by Variants 1=lnccnGus. 0 = Other(mocribe in notes) Form 10-426 (Revised 01/2017) MITKRU IR -12 diagnsstc CMIT-TxIA 10-23-19(003) WELL LOG TRANSMITTAL #905856099 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: IR -12 Run Date: 10/23/2019 31600 November 21, 2019 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 FRS_ANC@halliburton.com 1R-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21353-00 RECEIVED DEC 0 9 2019 AOGCC 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 FRS_ANC@halliburton.com Date: 1" 2b Signed: s THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Roger Mouser Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1R-12 Permit to Drill Number: 185-098 Sundry Number: 319-423 Dear Mr. Mouser: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www, aogc c. a lasko. gov Enclosed is the approved application for the 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, r1es,ieChmielowski Commissioner DATED this A day of September, 2019. FIBDMS�p 191019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 SEP 1 f 2'�i9 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well ' Operations shutdownLJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑v Other. Surface Casinel 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development 2 Stratigraphic El Service ❑ 185-098 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50029213530000 7. If perforating: N/A 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ KRU 1R-12 9. Property Designation (Lease Number): 10. Field/Pool(s): .,401. 0Z -5-(,-s5- , y7 Kuparuk River Field 1 Kuparuk River Oil Pool it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,320' 6,750' Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 115' Surface 3,916' 12" 3,953' Intermediate Production 8,267' 7" 8,302' Liner Perforation Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7822'-8111 MD' 2.875" J-55 7,936' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - CAMCO HRP -I -SP PACKER MD= 7707 TVD= 6314 PACKER - BAKER DB PERMANENT PACKER MD= 7908 TVD=6456 SAFETY VLV - CAMCO TRDP-IA-SSA SAFETY VALVE (Locked Out 4/9/94) MD= 1807 TVD= 1807 12. Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ / Exploratory F-1Stratigraphic El Development R Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL ❑� WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authodzed Name: Roger Mouser Contact Name: Roger Mouser/Roger Winter Authorized Title: Well I tegrity Field Supervisor Contact Email: N1927@conocophillips.com Contact Phone: 907-659-7506 Authorized Signature: %,. r Date: 9/13/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,r I L4 1 -5 %✓` Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: / 1 PhO%b dOC6,k"C.,h1 ,, //a I O G(z[va1ciyL GT-YId rfparI rc9VryCP J (• Post Initial Injection MIT Req'd? Yes ❑ No I� Spacing Exception Required? Yes ❑ No Subsequent Form Required: �O — -f p!f RBDMS1WSFP 19 2019 \_/� APPROVED BY Approved by: I, COMMISSIONER THE COMMISSION Date: !� iX J U TS Submit Form and Form 1e-903 Revised 4/2017 ApprovedR li o isp�,� oCAt s the date of approval. gctachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 13, 2019 Commissioner Jesse Chielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 1R-12 (PTD 195-186) repair surface casing leak at —20'. Please contact Roger Winter or myself at 659-7506 if you have any questions. Sincerely, Roger Mouser Well Integrity Field Supervisor Conocohi}lips Alaska, Inc. Attachments: 10-403 application for 1R-12 Surface casing repair. IR -12 Well bore schematic Proposal summary ConocoPhillips Alaska, Inc. 1R-12 Surface Casing Repair Procedure Obiective Repair the 9 5/8", 36 ppf, K-55 surface casing. The casing was determined to be leaking at a depth estimated 20' below the OA valve nipple. The conductor casing will require partial removal to expose the damaged surface casing. Excavation is required. Major Steps 1. Obtain 10-403 sundry approval from AOGCC to excavate and repair the surface casing. 2. Secure well for repair operations. 3. Complete wellhead loading calculations. 4. Excavate as needed for access. 5. Tap conductor and drain fluids. Several taps will be made to ensure adequate purge gas flow inside the conductor annulus. Install nitrogen purge fittings on conductor & OA if needed. 6. Cut windows for inspection. 7. Inspection of surface casing for damage and penetrations by Kakivik. 8. Remove complete conductor for surface casing inspection, final U/T & M/T inspection and patch length determination. 9. Prepare welding repair plan as per Mechanical Engineer's direction (seal weld / sleeve / patch or other). 10. Repair casing, QA/QC. 11. Perform tests to confirm no fluid to surface. Cover with corrosion protection materials. 12. Install new conductor casing and back -fill void area with cement and top with corrosion inhibiting waterproof sealer. 13. Replace excavated gravel and cellar box as needed. Install well house and floor kit. 14. Normal well up and return well to service General 1. Network number: 10419362, Activity code: ZX12, PMO 22916474, Sub PMO 22916473 2. The production casing to be repaired 9 5/8", 68 ppf, K-55 casing. The conductor to be removed is 20" 94# H-40. 3. The well is a producer. The well will be isolated from the facility by closed or disconnected wing and lateral valves. Standard energy isolation lockout & tag -out procedures apply as well as any additional energy isolation that may be required. 4. The well house, floor kit and cellar box may require removal for the excavation and repair. Scaffolding will be installed as required for access to the wellhead. 5. N2 purged on OA if needed. There will be periodic monitoring of 02 and LEL levels throughout the cut. 6. AOGCC Inspector will be notified for the opportunity to inspect the casing after conductor removal. 7. Any on-site personnel have the authority to stop or suspend the job should any safe -out or procedural conditions become suspect. Safety is everyone's responsibility. Repair Preparation: 1. Prepare In -Service package for welding patch. 2. Secure well by installing a plug above packer, verify tubing and production casing integrity by performing an MITT and MITIA. If needed. 3. Excavate around —20' (remove old cellar box and floor plate) and install shoring and scaffolding. 4. Bleed T, IA, and OA to zero psi. Verify flow is zero; inability to maintain zero psi prior or during job may cancel the welding operation. The OA is cemented to surface. 5. Prep 9 5/8" surface casing head. If equipped, pull VR plug and install opposing valve on casing head for N2 purge. 6. Verify OA fluid level is at least 24" below welding point; remove fluid via hose as needed. 7. Verify AOGCC 10-403 Sundry approval has been granted. Notify Inspector of upcoming witness opportunity if required by the AOGCC. 8. Drill and tap a hole in the conductor pipe near ground level for N2 purge of conductor during cutting and removal operation if needed. Drain any fluids that may be trapped in conductor. Install one or more additional purge points as determined on-site with Safety & Engineering representatives. 9. Station several hand-held extinguishers around wellhead. 10. Install purge lines from N2 bottle rack to conductor and OA if needed. The purge discharge to the bleed trailer will be monitored for LEL and 02 levels and must be accessible. Position bleed trailer downwind and as far from wellhead as practical. 11. Inspect and remove any combustibles in accordance with Hot Work standard — even if cold cutting. 12. Install welding blankets to cover purge hoses around wellhead if needed. 13. Hold pre -job safety meeting and ensure all permitting is in order. Job Procedure 1. The safety department will check entire well area before hot work or cold cut commences. Survey entire piping layout around wellhead to check for any potential flammable material sources. 2. Purge the conductor and OA only if needed with nitrogen, venting to slop trailer. Purged gas is to be monitored periodically throughout job for LEL and 02 levels. Target 02 level is < 5%. The heating / cutting operation may commence after target 02 level is reached. 3. Establish fire watch and begin hot work/cold cut. Fire watch shall have no other duties. 4. Cut windows in conductor. 5. Inspect surface casing for damage and penetrations. Have Kakivik U/T and M/T surface casing in the maximum amount of surface area exposed at both mandrel hanger connection and lower most conductor before the conductor is removed entirely. 6. Pending U/T and M/T results, remove complete conductor for surface casing inspection, final U/T inspection and patch length determination. 7. Stop N2 purge when hot work to exposed damaged area is complete. 8. Inspect casing damage and acquire data to formulate a welding and/or patch plan. 9. Invite AOGCC inspector to witness damage per sundry approval. 10. Pickup all trash and debris for disposal. Please leave a clean location! Repair Plan Procedure 1. Prepare welding/repair plan as per Mechanical Engineer recommendations, seal weld / sleeve / patch or other, 9 5/8" 36 ppf, K-55 casing internal yield is 3520 psi. The repair should result in at least 1600 psi design pressure rating and 2000 test pressure rating. 2. Ensure OA FL is below all welding points. 3. Repeat Job Procedure steps for purging and energy isolation as described above. 4. Begin patch welding preparation using the appropriate hot work permit standards. Repair surface casing as per Mechanical Engineer plans of a seal weld, a collar sleeve or other. Note: Replacement of the conductor will be performed after the repair is done and QA/QC is complete. Post Welding Plan 1. QA/QC repair. 2. Remove N2 purge valves and fittings, return wellhead to normal. 3. Pressure up with diesel or N2 and visually check for any external leaks in wellhead repair. Note: SC cemented to surface. 4. Install corrosion protection materials on surface casing as required by Mechanical Engineer repair plan. 5. Replace conductor casing with similarly sized casing, weld should be adequate to hold liquid cement material. 6. Remove scaffolding and shoring. 7. Fill conductor by surface casing void with cement and top with corrosion inhibiting waterproof sealant. 8. Replace excavated gravel and cellar box as needed. 9. Normal well up and return to service. 10. Monitor OA annular pressure and conductor area until well is stabilized. 11. Submit 10-404 report of SC repair to AOGCC. WELL LOG TRANSMITTAL 9905856099 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 1R-12 Run Date: 7/26/2019 3120® September 9, 2019 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 FRS_ANC@halliburton.com 1R-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21353-00 llecelvpn SEP 2 gals 4.0 AOGCC 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 FRS_ANC@halliibburton.com Date: G /C��% Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 7Performed: tions Abandon ❑ Plug Perforations Fracture Stimulate ❑❑ Pull Tubing Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Plug for Reddll ❑ erforate New Pool ❑ Repair Well Q Re-enter Susp Well ❑ 2. Operator 4. Well Class Before Work: Name: ConocoPhillips Alaska, Inc. 5. Parr Development ElExploratory El3. Address: P. O. Box 100360, Anchofage, Alaska Stratigraphic ❑ Service 6. API 99510 7. Property Designation (Lease Number): �. -___-- 8. Well Name and Number. pAUG 1 r14 ,{¢2019 A�[V4..'�CC Operations shutdown Change Approved Program Other: Braden Head repair I Number KRU IR -12 �ao alw suurnn electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Kuparuk River Field /Kuparuk River Total Depth measured 8,320 feet Plugs 9 measured None feet true vertical 6,750 feet Junk measured None feet Effective Depth measured 8,000 feet Packer true vertical6,522 feet measured, 7707, 7908, 79 feet true vertical , 6314, 6456, 64 feet 3asing Length Size MD TVD CONDUCTOR 78 feet 16 115' MID 115' Burst SURFACE 3,916 feet 9 5/8 " 3,953' MD 3325' PRODUCTION 8,267 feet 7 8,302' MD 6737' JEWELRY TYPE Measured depth feet Tubing (size, grade, measured and true vertical depth) 2.9 J-55 7,936' MD Packers and SSSV (type, measured and true vertical depth) HANGER - FMC TUBING HANGER 35' MD PACKER -CAMCO HRP -I -SP PACKER 7 7rrn nnn ilauon or cement squeeze summary: treated (measured): t descriptions including volumes used and final pressure: Prior to well operation: N/A Subsequent m operation N/A t )aily Report of Well Operations Q :opies of Logs and Surveys Run ❑ Tinted and Electronic Fracture Stimulation Data ❑ TI hereby certify that the foregoing is true and correct Mouser Title: Form 10-404 Revised 4/2017 1/7-4 L7 arage Production or Gas-Mcf Data P/ 7,908' MD 7 Pressure Collapse 6,476' TVD 35' TVD 6,314' TVD 6,456' TVD 6,470' TVD Pressure Exploratory ❑ Development ❑ Service Q Stratigraphic ❑ -------------------- SII Status after work: Oil Q Gas ❑ WDSPL ❑ t ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ of my knowledge. SundryNumber or N/A if C.O. Exempt: N/A Contact Name: Roger Mouser/Roger Winter Contact Email: N1927@conocophillips.com Contact Phone: 907-659-7506 9 8/1 15 2019 Submit Original Only Conoc Po hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West Vh Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocOPhillips Alaska, Inc. for the Braden head repair weld. KRU 1R-12 (PTD 185-098). Please contact Roger Winter or me at 659-7506 if you have any questions. Sincerely, Roger Mouser Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. 1R-12 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/09/19 (SC -REPAIR) WELD BRADEN HEAD (COMPLETE) KAKIVIK UT MT (IN -PROGRESS) 08/1011 9 (SC -REPAIR) KAKIVIK UT -MT (PASSED)GAS MIT -OA (PASSED TO 1400 PSI) MIT -OA (PASSED TO 1800 PSI (PASSED) (COMPLETE) L'-i4l _A I~J Cono P ' ' co hillips Alaska F.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ SEP a ~ 2oos AI~~k~ ~il ~ f~~ ~~na..Co 'ssion ~M4G~1Qi~ r ~' " . Jtt ~ . .. ..., ... ._,a '-. _ " _ 5~ ~ ~$ ~ ~ r~ ~~ ~ ~v Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRt~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 15~' and 23id 2009, and the corrosion inhibitor/sealant was pumped August 27th, 28;t' and 29~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~ ~~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ~ ,. I ~%1. f ~~_ .~ ~ ~~ ~,~r° '~`,y - / rE +~ ~ ~ ~ v~,i t, !~? ~t~.>.r F e _, ~ ~. ,._ .~, .... t . ~ ConocoPhillips Alaska inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/29/09 1 R PAD Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbis ft al 1 R-01 B 50029214040200 . 2001560 13'7" 2.0 26" 8/15/2009 5.1 8/27/2009 1 R-02 50029214050000 1851760 80' 13.30 23" 8/23/2009 4.7 8/28f2009 1 R-03A 50029214060100 2000210 15' 3.00 27" 8/15/2009 5.3 8/28/2009 1 R-04 50029214070000 1851780 15'2" 3.00 26" 8/15/2009 5.1 8/28/2009 1 R-05 50029213300000 1850700 20'9" 2.20 23" 8/15/2009 3.8 8/28/2009 1 R-06 50029213310000 1850710 14' 2.00 23" 8/15l2009 3.8 6/28/2009 1 R-07 50029213320000 1850720 44' S.00 24" 8/15/2009 4 8/28l2009 1R-OS 50029213330000 1850730 8' 1.00 21" 8/15/2009 13.7 8/28/2009 1 R-09 50029213500000 1850950 9' 1.20 25" 8/15/2009 4.3 8/28/2009 1 R-10 50029213510000 1850960 32' 5.40 22" 8/15/2009 3.4 8/28/2009 1 R-11 50029213520000 1850970 47' 6.00 38" 8l15/2009 13.9 8/28/2009 1 R-12 50029213530000 1850980 38' 6.00 24" 8/15/2009 4 8/28/2009 1 R-13 50029213850000 1851500 10' 0.50 25" 8/15/2009 4.3 8/29/2009 1 R-15 50029213870000 1851520 21'4" 4.00 35" 8/15/2009 12 8/29/2009 1R-16 50029213880000 1851530 12'6" 9.00 21" 8/23/2009 3.8 8/29/2009 1 R-17 50029222120000 1911140 20" N/A 20" N/A 4.4 8/28/2009 1R-18 50029221880000 1910870 9'4" 1.20 21" 8/15/2009 3.7 8/28/2009 1 R-19A 50029221850100 1910850 18" N/A 18" N/A 10.2 8/29/2009 1 R-20 50029222070000 1911080 8'A" 2.00 19" 8/15/2009 11.3 8/29/2009 1R-22A 50029222060100 1990490 16" N/A 16" N/A 9 8/29/2009 1 R-23 50029222000000 1911010 18'8" 2.30 39" 8/15/2009 13.9 8/29/2009 1 R-25 50029221530000 1910470 7'4" 1.50 26" 8/15/2009 5.1 8/27/2009 1 R-26 50029221930000 1910920 7' 3.50 38" 8/23/2009 13.9 8/28/2009 1 R-27 50029222010000 1911020 18" N/A 18" N/A 5.1 8/28/2009 1R-29 50029221950000 1910940 18" N/A 18" N/A 4.1 8/28/2009 1R-35 50029230500000 2012100 18" N/A 18" N/A 5.3 S/29/2009 1R-36 50029230570000 2012270 19" N/A 19" N/A 5.3 8/29/2009 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk \f'l 5 -" oq ~ \) t'V \~ Color CD Scblumbel'gel' NO. 3792 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth .., '. ,\1..\ T\t t:\ ' . )\;.; J " ..¡.,.." <\ ',~' '~,:i Field: Well Job# Log Description Date BL 1 Y -29 11213739 PRODUCTION PROFILE W/DEFT ~ "ir~ - ("!'ì. I 04/28/06 1 3M-25A N/A SHUT IN BHP I C\ L. - aGe., 04/23/06 1 2N-303 N/A LDL Ç) Cl' - I ¿.,C; 04/21/06 1 1 R-21 11213737 PRODUCTION PROFILE W/DEFT l~I-t\3 04/25/06 1 3F-07 N/A INJECTION PROFILE / ~-\" - d4~ 04/23/06 1 18-16 11235353 PRODUCTION PROFILE W/DEFT JC I...I-("<.~ 04/04/06 1 38-15 11213741 INJECTION PROFILE hc.ç - (' ;) ~- 04/30/06 1 1 G-07 N/A PRODUCTION LOG W/DEFT ¡ ~ ~ - ;::¡(', \ 04/19/06 1 1A-20 11235356 PRODUCTION LOG W/DEFT I"O-II~;:¡ 04/26/06 1 1 H-18 N/A INJECTION PROFILE 1'1'3 -b:lb 04/24/06 1 1R-12 11213738 PRODUCTION LOG W/DEFT l~~ -O'J?i 04/27/06 1 1 Y -13 11213740 INJECTION PROFILE 1"'6~ - C' ,-Ç 04/29/06 1 2N-318 11213742 LDL é)DO -!öD 05/01/06 1 1 Q-08A 11213743 INJECTION PROFILE ì ~ ''1 -i'C, ':¡, 05/02106 1 1 G-01 11213744 INJECTION PROFILE ìÝd-- l;i;'t> 05/03/06 1 3J-17 11258704 PRODUCTION LOG W/DEFT íC,(,- - (i..r~ 05/04/06 1 1 R-26 11258705 INJECTION PROFILE 'j C1 I - ('\~ ';::). 05/05/06 1 2A-04 11249902 INJECTION PROFILE ¡ ~L.I- {,<~ 05/06/06 1 1 G-06 11249903 INJECTION PROFILE I 1f d - ;);+t--, 05/07/06 1 1 E-18 11216193 MEMORY PRODUCTION PROFILE f~2,- -liLl 05/07/06 1 1G-14 11249904 INJECTION PROFILE I.<;(~·- '';'/1 05/08/06 1 05/09/06 e e Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1R-12 (185-098) Report ofTxIA comm added to weekly SCP report e e . .... . . Subject:1R-12 (185-'098) Report()fTxIA comm added to weel<ly SCP report From: NSK Problem w~n Supv <n1617@conocophillips.com:>" ' Date: Wed, 190ct 200511 :33 :22 -0800 ,", T'q,: tOl11L mauridbr@admin.~~te;ak. us;[Îilles Regg ':g im _ regg@adî'1Jfi.".state.~:1lJs> Tim & Jim, '. 1 R-12 has been added to the weekly producer SCP report due to TxlA communication. The well was SI on 10/16/05 and the operator observed a high IA pressure on 10/17/05. As of 10/18/05, the T &IA were equalized with the following pressures T/I/O = 2000/1980/620: The GL Vs are 1998 vintage and are the suspected leak point. Slickline will troubleshoot the leak and attempt to repair by fixing any leaky GLVs. The IA will be bled down and a TIFL will be performed to verify integrity. Attached is a schematic. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 «1 R-12.pdf» '~~-::k\H~h~~¡c.[ , 4.,;;1.....;J~ \j¡; \Jt;¡',L,....-' ( Content-Description: 1R-12.pdf Content-Type: application/octet-stream Content-Encoding: base64 :;¡;p.. ðÞ>. 1 of 1 :f{, (pSI) 1'1 ceo ~~p (pi.) 4l-7<ôO 3s-zo t~p ..- -~/>¡(ß~ 17;6% b1.o .-, 5 ð k per ('~ 4-~ t.., 4s'~oM:utp '\<1,1 (zfz:¡ I o~ 12/22/2005 4:29 PM SSSV 1807-1~:)~ OO:2J!ic; ~B~ (7689-76H). 00:2.!;{~: P:<R (7707-7708, 00:6.156) PKR (7908-7909, 00:6.156) NIP (7928-7929, 00:2.875) TUBING (0-7937, 00:2.875, 10:2.441) Perf (7975-8030) Perf (8051-8083) Perf (8104-8111) I - ... ,~!! '::>~¡'ll Camco'TRDP-1A-SSA' Camco 'OEJ' Camco 'HRP-1-SP' Baker 'DB' CAMCO D N!QQ!e Camco ID 2.313 2.297 2.344 3.250 2.250 2.438 2.438 ~:::¡::.. KBMG KBMG KBMG MMH-HF MMH-HF MMH-HF Description {Locked Out 4/9/941 DMY DPHFCV DPHFCV 1 :¡ 1 .0 :0 .0 BEK BEK BEK 0.000 0.000 0.000 o Q o Date Run 2/24/1991 J 1/7í2004 11/7/2004 -~ ~¥. ! 1.~;"Ao.1 :~.-. I Ji B. Jlê, :. ]W;,.} :1' 'Gäs un MandrclsNalves St : MD TVD' Man' : MäiïType Mfr ' 1 1 ".1i . ¡;~ 7 Camco KBMG 2 :; ;;j;; :i!Jiii Cam~o KBMG 3 ,~¡; : :; :.IX ï; Carnco KBMG 4 '1:::, i '11.:)3 Camco KBMG 5 ;:h" ,J:; I:, Camco: KBMG 6 ,;:;'j I 4';·~¡; Camco KBMG 7 (,1:<0 :-:i'Ï? Camco KBMG 8 ¡,ry :,:,r¡¡ Camco KBMG () I:;") ',;,:ò:; Camco· KBMG 10: ¡!..1, ';;IC Mer'açI",·,,!GPD 10!i!Jclion Mandrel.s¡Y~I;$S}Wi¡ . St MD TVD Man I Man Type Mfr 1 11 ¡hit, ..'·11 Camco -. -- -- - - 12 J1.'1~, Ù.J:1Ü C¡¡mco 13 . 7894 6446 Cameo ~thiÚ (plugs, equip:: etcl -º-epth TVD. Type _ 1807 1807 SSSV 7689 6301 SBR - 7707 6314 PKR 7908 6,156 PKR 7928 6470 NIP 7936 6476 SOS 793/ ü477 TTL !ilèneral Notes Date Note 5/181'1998' CV @ 78'15'" 7894' C SANDS OPEN 6/3/2000 V~RY HE^VY P/U WEIGHT, RECOMMEND .125 WIRE. UNABLE TO PULL CVs - "scale, cross flow. ,ossible buckled tubino". 1200# P/U wt., no spanos, lost CAT in cross flow 7786' WLM. unable to pull. V Mfr V Type GLV GLV DMY GLV DMY GLV OV DMY DMY LDMY VOD 1.0 1.0 1.0 1.0 1.0 1.0 1.0 10 0.0 1.5 Latch BK BK BK BK BK BK BK BK BK RK Port TRO 0.156 1260 0.188 1306 0.000 0 0.250 1425 0.000 0 0.250 1423 0.250 0 0.000 0 0.000 0 0.000 0 Date Run 7/1ï1998 7/1/1998 7/1/1998 7/1/1998 10/25/1992 '7I1i1998 6/25/1998 6/25/1998 4/25/1998 6/25/1.!:I98 Vlv Cmnt Closed Vlv Cmnt_ 784? ¡~, ß409-6415 785() fi~¡ :;421 - 6430 797f:> !,;f!¡; G504 - 6543 8051 ~O?\: !i558 - 6581 810<: ¡¡ 'ì596 - 6601 A-2 V Mfr V Type 32 55 7 2 VOD 12 8/9/1985 IPERF 12 ; 8/9/1985 IPERF 4 8/9/1985 IPERF 4 8/9/1985 IPERF : 8/9/19851IPERF 4 Latch Comment 120 deg. phasing: 5 112" Scalloped HJ 120 deg. phasing: 5 1/2" Scalloped HJ 120 deg. ph¡¡sing; 5 1/2" Sc¡¡lIoped HJ 90 dey. phasing;4" Carrier HJ II Gun 90 dog. phasing; 4" HJ II Gun 190 deg. phasing; 4" HJ II Gun Carrier Carrier I 1". ~--::J"" I '~,-""....'" r-;.:;~.::.". ]t~ :~'-f,:-. I Nmular Fluid: Reference Log: Last Tag' 8016 Last Tag D¡¡le: 8/6i2004 Casing String" ALL STRINGS Description CONDUCTOR SUR. C^SING PROD. C^SING Tubing String" TUBING. . Size Top 2.875 0 Peñoralions Summary Intervnl TVD 782;> ¡,nl ';395 - 6404 PROD 7i2111985 - 8320 ftKß 54 deg @ 5300 Bottom ~"""'TVD 115 115 3953 3825 8302.. ,,::¡F37 ""t' . 6.50 ¡¡¡¡Ii. Date 8/9/1985 8 Ft 12 TVD 6477 Size Top 16.000 0 9.625 0 7.000 0 Bottom 7937 . . .. Zone - -Status C-1,UNIT B UNITB UNIT B A-4.A-3 ^-2 -SPF 12 Type IPERF Grade J-55 Wt 65.00 36.00 :;>~.OO Thrëact' EUE 8RP Grade H-40 J-~5 J-55 -------we¡¡l'ypC; : Orig Complellon: L<lstW/O: Ref Log Datu: TO' Max Hole ^ngle: Thread ""'i'R=12 --APi·' 5ÕÕ292135306 sssv Typu: LOCKED OUT Rev Reason: Tag fill, GLV design Lns' Update: 12/6/2004 --- l\nyïU' (({TS: 45 dag @ "li74 ^ngle:g) TD: 44 deg @ 8320 III e ConocoPhillips Alaska. inC. e KRU 1R-12 STATE OF ALASKA "~ !~'"~" ~'~ AI_A,M(A OIL AND GAS CONSERVATION COMMIS~i~q REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate ..~ Plugging Perforate _ Repair well Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ~. Exploratory _ Stratigraphic Service 4. Location of well at surface 578' FSL, 215' FEL, Sec. 18, T12N, R10E, UM At top of productive interval 1565' FNL, 1394' FEL, Sec. 18, T12N, R10E, UM At effective depth 1298' FNL, 1519' FEL, Sec. 18, T12N, R10E, UM At total depth 1223' FNL~ 1570' FEL, Sec. 18, T12N, R10E~ UM 12. Present well condition summary Total Depth: measured 8 3 2 0' feet true vertical 6 74 9' feet Effective depth: measured 8 21 1 ' feet true vertical 6 6 71 ' feet Casing Length Size Structural Conductor I 1 5' 1 6" Surface 3953' 9 5/8" Intermediate Production 83 0 2' 7" Liner Plugs (measured) Junk (measured) Cemented 6. Datum elevation (DF or KB) 63' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1R-12 9. Permit number/Approval Number 85-98 / 90-410 10. APl number 50-029-21353-00 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool RI C IV .D depth 230 Sx CS II 1 1 5' 115' 1160 Sx PF"E" III & 3953' 3825' 350 Sx PF"C" 320 Sx Class G & 8 3 02' 6 73 5' 250 Sx PF"C" Perforation depth: measured 7822'-7834', 7842'-7850', 7859'-7871', true vertical 6395'-6404', 6409'-6415', 6421'-6430', Tubing (size, grade, and measured depth 2 7/8" J-55 6.5 #/FT @ 7923' MD-RKB Packers and SSSV (type and measured depth) 7975'-8030' 6504'-6543', 8051'-8083', 8104'-8111' MD-RKB 6558'-6581', 6596'-6601' TVDRKB Camco 'HRP'-I-SP @ 7693', Baker 'DB' @ 7894', Camco TRDP-1A-SSA SSSV @ 1793 13. Stimulation or cement squeeze summary HCl acid stimulation Intervals treated (measured) Cl Sand Treatment description including volumes used and final pressure 1000 gallons 12% HCI with 139 bls diesel flush / 2600 psi 14. Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 675 320 225 1 I 00 1 65 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 700 375 225 1 1 00 170 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~/ned ,' Title .~1~' J~ Form 10-404 Rev 09/12/90 Dato 7- D SUBMIT IN DUPLICATE AlaSKa, Inc. Subsidiary of Atlantic Richfield Company ..-----~. ° WELL .,,T ,"..r'-.~N, TRACTO R, (-'~ .-. ~ c:::>-~,,~ / REMARKS FIELD- DISTRICT. STATE OPERATION AT REPORT TIME WELL SERVICE REPORT CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK I Slgne~.~ REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL ,= CAMCO OTiS S 0 ~ SCHLUMBERGER .- DRESSER-ATLAS ,-- DOWELL ,G,,c.~ ct_ (.o oj_~ \ HALLIBURTON ., ARCTIC COIL TUBING FRACMASTER °t ~ ~ ~ -B. J. HUGHES N .~_ ~ '~ t O Roustabouts Diesel ~'~ Methanol Supe~ision Pre-Job Safety Meeting - AFL ,, TOTAL FIELD ESTIMATE . ~ ,~ ¢ [ ARCO Alaska, In Post Office aox 100360 Anchorage, Alaska 99510-0350 Telephone 907 276 12i5 May 23, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 1 R-12 Stimulate May, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J. R. Brandstetter ATe 1120 L. Perini ATe 1130 KeEl .4-9 w/o attachments P ECEIVE .Oil.& Gas Cons. -Cornrnissiort '"' ~chora~' ARCO Alaska, Inc. is a Subsidiary of Atlar~ticRichfieldCom, pai'&' STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska,, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ~ Exploratory _ Stratigraphic _ Service 4. Location of well at surface 578' FSL, 215' FEL, Sec. 18, T12N, R10E, UM 6. Datum elevation (DF or KB) RKB 83 7. Unit or Property name Kuparuk River Unit 8. Well number 1R-12 feet At top of productive interval 1565' FNL, 1394' FEL, Sec. 18, T1 At effective depth 1298' FNL, 1519' FEL, Sec. 18, T1 At total depth 1223' FNL, 1570' FEL, Sec. 18, T1 2N, R10E, UM 2N, R10E, UM 2N, R10E, UM 9. Permit number 85-98 10. APl number 5o-02cj-21 353-00 11. Field/Pool Kuparuk River Field I Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 8 3 2 0' true vertical 6 74 9' Effective depth: measured 821 1 ' true vertical 6 6 71 ' Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 3953' 9 5/8" Intermediate Production 8 3 0 2' 7" Liner feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth 230 Sx CS II 1 15' 1160 Sx PF"E" III & 3953' 350 Sx PF"C" 320 Sx Class G & 8 3 0 2' 250 Sx PF"C" R ECEIVE " . MAY 2 5 ,'~!aska Oil & {]as Cons, True vertical 115' 3825' 6735' Perforation depth: measured 7822'-7834', 7842'-7850', 7859'-7871', 7975'-8030', 8051 '-8083', true vertical 6395'-6404', 6409'-6415', 6421 '-6430', 6504'-6543', 6558'-6581', Tubing (size, grade, and measured depth 2 7/8" J-55 6.5 #/FT @ 7923' MD-RKB Packers and SSSV (type and measured depth) Camco 'HRP'-I-SP @ 7693', Baker 'DB' @ 7894', Camco TRDP-1A-SSA SSSV @ 1793 8104'-8111' MD-RKB 6596'-6601' TVD-RKB 13. Attachments Description summary of proposal Acid Stimulation Procedure Detailed operation program BOP sketch 14. EStimated date for commencing operation June 1, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas m Service _Oil Producer Suspended Si~ned t,~t~e foregoinglA~ ~is true and correctTitle to the best Ofsr.mYEngineerknOwledge. FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require 10- ~'c~' ~' IApprovalI No ?~) ORIGINAL 81~iNI~D !~. LONNIE C. SMITH Approved by the order of the Commission Approved Copy Returned --~/~~ C ummissioner Well 1R-12 Application for Sundry Approval May 23, 1989 It is proposed to acid stimulate the C1 Sand in Well 1R-12. The well will be stimulated with 12% HC1, and no workover fluid will be used. BOP's will be used on the coiled tubing unit. The expected bottom hole pressure of the C sand is 2500 psi. L, Bailey/G. Jones April 20,1990 Page 3 Pressu re Well 1 R-1 2 Survey/Acid Stimulation CC 230DS10RL Materials: MSR 100 ACID (mixed by Dowell offsite): 12% HCL A250 INHIBITOR F75N SURFACTANT L41 CHELATING AGENT L58 REDUCING AGENT W35 SLUDGE PREV. 1000 GALS 4 GALS 5GALS 100 LBS 20 LBS As per test results Nn'ROGEN 45 MSCF DIESEL Procedure: Pre-Acid Acid Slickline/Pressure Data: 1. Obtain produced crude sample and send to Dowell for sludge test. 2. MIRU slickline. 3. RIH with gauge ring for scale check. Most recent run was a 2.2" centralizer on 7/30/89 to TT (light scale was detected). Tag D nipple and record WLM depth for reference to be used if fill is tagged above blanking plug after acid job. (Fill was last tagged at 8005' WLM-RKB on 7/30/89.) 4. RIH with blanking plug and Panex pressure gauge with Amerada bomb for backup. Set in D nipple at 7914' WLM-RKB. 5. RD slickline. 6. Leave well shut-in well for 36 hours. 7. Notify NSK Operations Engineering to obtain WHP/FL. 8. Based analysis of reservoir pressure, a joint decision will be made whether to pump acid stimulation. Stimulation: 1. MIRU CTU, pump trucks, and transports. Pressure test lines. 2. Operations Engineering will titrate acid. Acid should be at least 12% HCI. L. B ailey/G. Jones Page 4 April 20,1990 3. RIH with CTU to 7700' CTU-MD (just above top GLM @ 7732' WLM- RKB), Pump diesel into well and monitor returns to insure CTU X tubing annulus is fluid packed, Minimum volume will be calculated from WHP/FL. . Pump Dowell MSR 100 system with nitrified 12% HCI (300 SCF/STB) as described above. Pump at the maximum rate possible, but do not exceed 2500 psi at the surface. Note: Pressure on the tubing/CTU annulus should not exceed 2000 psi. 4. Open well to production through production lines and pump nitrogen at 750 SCF/MIN. Lift well with nitrogen for a minimum of 45 minutes. 5. POOH and RD equipment. Post-Acid Slickline: 1. MIRU slickline. 2. Perform static BHP survey with 15 minute stops at the following depths with Amerada or Panex: Lubricator 7825' MD-RKB 7325' MD-RKB Lubricator Note: Do not run static if post-acid slickline is performed on same day as acid stimulation. 3. Pull blanking plug and Pannex/Amerada bombs. 4. RD slickline. 5. Return well to production @ 1,0 MMSCFPD gas lift as soon as possible. 6 5 4 3 2 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI ,4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. ,5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX I 1 ,'] I'1'1 TIIRJNi~ UNIT BOP EI~UIPMENT 1. ~000 PS1 ?" W[LLHCAD CONNCCTOR FLANGE 2. 5000 PS1 WIR[LIN£ RAMS (VARIABLE: SIZE) 3. 5000 PS~ 4 1/6" LUBRICATOR 4. ~000 PS~ 4 ~/~" fLOW TUBE PACK-Orr H]R£L]NE BOP. Ei3U]PHENT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown m Stimulate X PlUgging Perforate Pull tubing Alter casing Repair well Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 578' FSL, 215' FEL, Sec. 18, T12N, R10E, UM At top of productive interval 1565' FNL, 1394' FEL, Sec. 18, T12N, R10E, UM At effective depth 1298' FNL, 1519' FEL, Sec. 18, T12N, R10E, UM At total depth 1223' FNL, 1570' FEL, Sec. 18, T12N, R10E, UM 12. Present well condition summary Total Depth: measured 8320' true vertical 6749' Effective depth: measured 8 21 1 ' true vertical 6671 ' Casing Length Size Structural Conductor I 1 5' I 6" Surface 3953' 9 5/8" Intermediate Production 8 3 0 2' 7" Liner Other 6. Datum elevation (DF or KB) RKB 83 7. Unit or Property name Kuparuk River Unit 8. Well number 1 R- 12/~=4,5'4 9. Permit number/approval number 85-98 / 10. APl number $0-029-21353-00 11. Field/Pool Kuparuk River Oil Pool feet Plugs (measured) feet ~ feet Junk (measured) feet Cemented Measured depth feet 230 Sx CS II I 15' 1160 Sx PF"E" III & 3953' 350 Sx PF"C" 320 Sx Class G & 83 02' 250 Sx PF"C" True vertical depth 115' 3825' 6735' Perforation depth: measure 7822'-7834', 7842'-7850', 7859'-7871', 7975'-8030', 8051'-8083', true vertical 6395'-6404', 6409'-6415', 6421'-6430', 6504'-6543', 6558'-6581', Tubing (size, grade, and measured depth) 2 7/8" J-55 6.5 #/FT @ 7923' MD-RKB Packers and SSSV (type and measured depth) Camco 'HRP'-I-SP @ 7693', Baker 'DB' @ 7894', Camco TRDP;1A-SSA SSSV 13. Stimulation or cement squeeze summary Gelled deisel fracture with 20/40 Carbolite was pumped into the A Sand. Intervals treated (measured) 14. 81 04'-8111' MD-RKB 6596'-6601' TVD-RKB FEB 1 5 ]9,90 7975'-8030', 8051'-8083', 8104'-8111' AiaskaOii&GasCons. Commis= Treatment description including volumes used and final pressure Pumped 41,700 lbs of 20/40 Carbolite into the A Sand. Maximum treating pressure was/~l~r~. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1070 558 24 952 163 1979 1121 33 134 149 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,//~~ ~/~/~,~~"~f~/~~ Title Sr. Operations Engineer Signed ' 06 Form '~ ~--404 FI~ i 16. Status of well classification as: Suspended Service [0_I~ ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company REMARKS WELL SERVICE REPORT I PBDT I FIELD ...... - DISTRICT- STATE /~ ~ I DAYSz DAT ~~ C] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS l) 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate ~ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 578' FSL, 215' FEL, Sec. 18, T12N, R10E, UM At top of productive interval 1565' FNL, 1394' FEL, Sec. 18, T12N, R10E, UM At effective depth 1298' FNL, 1519' FEL, Sec. 18, T12N, R10E, UM At total depth 1_2_23' FNL, 1570' FEL~ Sec. 18r T12N1 R10E, UM 12. Present well condition summary Total Depth: measured 8320' feet true vertical 6749' feet Plugs (measured) Effective depth: measured 8211 ' feet Junk (measured) true vertical 6671 ' feet None Casing Length Size Cemented Structural Conductor I I 5' I 6" 230 Sx CS II Surface 3953' 9 5/8" 1160 Sx PF"E" III & Intermediate 350 Sx PF"C" Production 8302' 7" 320 Sx Class G & Liner 250 Sx PF"C" RKB 83 7. unit or Property name Kuparuk River Unit feet 8. Well number 1R-12 9. Permit number 85-98 10. APl number 50-0 29- 21 353-00 11. Field/Pool Kuparuk River Field ~t~kll~il~ 131il Pool I K[L.E! ¥ I MAY 2 6 1989 Oil & Gas cons. comrn lo,q Anchorage Measured depth True vertical depth 115' 115' 3953' 3825' 8302' 6735' 13. Perforation depth: measured 7822'-7834', 7842'-7850', 7859'-7871', 7975'-8030', 8051'-8083', true vertical 6395'-6404', 6409'-6415', 6421'-6430', 6504'-6543', 6558'-6581', Tubing (size, grade, and measured depth 2 7/8" J-55 6.5 #/FT @ 7923' MD-RKB Packers and SSSV (type and measured depth) Camco 'HRP'-I-SP @ 7693', Baker 'DB' @ 7894', Camco TRDP-1A-SSA SSSV @ 1793 Attachments Description summary of proposal_ Refracture Pump Schedule Detailed operation program 8104'-8111' 6596'-6601' BOP sketch MD-RKB TVD-RKB 14. Estimated date for commencing operation June 5, 1989 ~16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service .Oil Producer Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,/'~/~ ,'Y~') ~,t_~A~-.~ Title 2('~.~' ~5)Fe,~j.~-~'c.-! ' ' FOR COMMISSIO~I USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance m Mechanical Integrity Test M Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAl. ,SIGNED BY I f lNNI.F C, SMITH IApproval No. ~,pproved Copy Return¢_d Commissioner Date SUBMIT IN TRIPLICATE Well 1R-12 Application for Sundry Approval May 23, 1989 It is proposed to refracture Well 1R-12's A Sand. The well will be refractured with gelled diesel and 20/40 Carbolite pumped at 20 BPM, and no workover fluid will be used. No BOP is required. A surface manifold with tanks will be present and used to produce the well for the first few days. The expected bottom hole pressure of the A sand is 2500 psi. RECEIVED MAY 2 6 1989 Naska 0ii & Gas Cons. Commission N~chorage KUPARUK WELL 1R-12 'A° SAND REFRACTURE PUMP SCHEDULE 5115/89 STAGE_ FLUID CLE/kN VOLUME PUMP RATE PROP. COI~. PROPPN~ PROPPANT WT 'DIRTY VOLUME HIT PERFS DESCRIPTION BBLS BPM PPG DESCRIPTION LBS STG/CUM BBLS I GD PRE-PAD 150.0 20 0 NOPF:K3PPANT 0 1 501 150 47 ............................................... SHUT DOWN FOR ISIP ...................................................... 2 GDP/IO 285.0 20 0 NOPROPPANT 0 285~ 435 197 3 GD w/2 PPG 23.0 20 2 20~40 M CARBO-LITE 1930 2 5/ 460 482 4 GD w/4 PPG 29.8 20 4 20140 M CARBO-LITE 4999 3 5/495 507 5 GD w/6 PPG 31.6 20 6 20140 M CARBO-LITE 7972 401 535 542 6 GD w/8 PPG 29.6 20 8 20140 M CARBO-LITE 9937 40/ 575 582 7 GD wi10 PPG 34.7 20 1 0 20140 M CARBO-LITE 14576 501 625 622 9 GDFLUSH 46.0 +SV 20 ., 0 NO,PROPPANT 0 46~, ,671 672 TOTAL GELLED DIESEL = 629.6 BBLS +SV 20/40 M CARBO-LITE = 39413 LBS NOTES: Stages I and 9 are Gelled Diesel. Stage 2 is Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for a 8 hour break. Stages 3 through 7 are Gelled Diesel with 6 hour breaker and without silica flour. Stage 9 should include a volume adjustment for surface equipment between the wellhead and densttometer. This job is intentionally underfiushed by I bbl. The blender tub should be bypassed at flush. All fluids should be maintained at 70 to 90 F on the surface. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 31, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 1R-12 Dear Mr. Chatterton' Enclosed is a copy of the 1R-12 Well History (completion details) to incl, ude width the Well Completion Report, dated 10/14/85. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L54 Enclosure cc' 1R-12 Well File RECEIVED · ·., ;, , ,:..,~:, ,,;, .~ ~',{:L:, ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 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 repr~sentative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code State Alaska IWell no. 1R-12 District ~County or Parish Alaska I North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25635 Auth. or W.O. no. ~Title AFE 604263 I Completion Nordic 1 API 50-029-21353 Operator J A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun ~ Date Complete I 8/8/85 Date and depth as of 8:00 a.m. 8/09/85 8/lO/85 thru 8112185 Complete record for each day reported I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well I our I Prlor status if a W.O, I 0815 hrs. 7" @ 8302' 8182' PBTD, Perforating Accept Rig @ 0815 hrs, 8-8-85. ND tree, NU & tst BOPE. & scrpr to 8182'. POOH, RU SOS Perf f/8104'-8111' & 8073'-8083', w/4" csg guns, 4 S~F, 90° phasing. Rn bit 7" @ 8302' 8182' PBTD, RR Perf "A" sand f/8051'-8073' & 7975'-8030' w/4" gun, 4 SPF, 90° phasing. Perf "B" sand f/7859'-7871'. & 7842'-7850' & perf "C" sand f/7822'-7834' w/5" guns, 12 SPF, 120° phasing. Run GR & JB to 8163'. Rn Baker 'DB' perm pkr & set @ 7894' WLM. Rn 262 jts 2-7/8", 6,5#, EUE 8rd, J-55, IPC compl string. Perm pkr @ 7907.51', SSSV @ 1807'. Stab in, space out, land tbg, drop ball, set pkr. Shear SBR, reland tbg. Packer @ 7908', "D" nipple @ 7928', TT @ 7937', SSSV @ 1807'. Tst SSSV; OK. ND BOPE, NU & tst tree. Displ well to crude/diesel. Tst orifice vlv; OK. Set BPV. Release Rig @ 1430 hfs, 8-10-85. Old TD Released rig 1430 hrs, Classifications (oil, gasO~q~ Producing method Flowxng INew TD Date 8/10/85 PB Depth 8182' PBTD Kind of rig Rotary Type comp~t'letg~lr~le, dual, etc.) Official res~d;~D&~E~J~.) Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity - Ajl~w~le;~_~ . Effective date corrected i'~,C L,t / '~/[:D" The above is correc,t, ,1 t\ ' ~-' ~ ~ ~ :" ~ ~-' ~'~-~-~: 10/10/85 Drilling~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 .. ..-- -. ~CO~S CL~ AT~lll5B P.O. BOX 100360 ANCHO~GE, AK 99510 DATE: 10-31-85 TRANSMITTAL NO: 5421 TRANSMITTED HEREWITH AR~ THE FOLLOWING ITEMS. RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINALS/ SCHL/ CEMENT <ONE * OF EACH> -~lA-3 / CEMENT. EVALUATION TOOL -lB-4-~ .CEMENT ~:VALUATION TOOL "~lR-9 / CET LOG 1R-10~' ~.SET LOG -'iR- 11/ CET/CEL '-iR-12" CET LOG ~2A-13 -' CBL/VDL \2A-13-/ CET/CEL u2U-3~ CEMENT EVALUATION TOOL ',~2U-10/ CEMENT EVALUATION TOOL '-'2 Z- 13/ CET LOG 2Z-14-~ CET LOG "'2' Z-15~ CET LOG "~2Z-16-. CET LOG ~'3B-4'~. CEMENT EVALUATION TOOL ~'3B-12'"' CET LOG ,,3B-12/ CEMENT EVALUATION LOG W/ AC '"3B-16 /'" CEMENT EVALUATION TOOL --3C-9 '" CET LOG "~3C-10~' CET LOG PLEASE ACKNOWLEDGE 05-04-85 RUN #1 7468-8287 05-28-85 RUN #1 7200-7995 07-17-85 RUN #1 5990-8084 07-16-85 RUN Sl 7500-8632 07-25-85 RUN #1 5744-7129 07-26-85 RUN #1 4992-8144 07-13-85 RUN #1 6388-7554 07-24-85 RUN #1 6382-8032 03-26-85 RUN #2 6100-6600 05-19-85 RUN #1 5450-6950 07-09-85 RUN #1 6000-8411 07-09-85 RUN #1 5500-8173 07-01-85 RUN #1 2700-6617 07-01-85 RUN #1 6100-801! 05-31-85 RUN #'1 6000-7743 07-14-85 RUN #2 6139-8089 07-06-85 RUN #1 5500-8096 05-09-85 RUN #1 6186-7762 07-14-85 kUN $1 7485-8210 07-14-85 RUN #1 8190-8805 RECEIPT ACKNOWLEDGED: DISTRIBUTION: BPAE DRILLING*BL W. PASHEi{ B. CURRIEK L. JU~NSTON .. ~XXON CHEVRON MOBIL PHILLIPS OIL D & M NSK CLEkK*BL J. RAT~{MELL -DATE':'~s~a ~;~ ,, . - '---' ~ , ~n~. Co ; . UNION VAULT/~0' FILHS ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 4, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 1R-12 Dear Mr. Chatterton- Enclosed is a copy of the 1R-12 Well History to include with the Well Completion Report, dated 9/12/85. If you have any questions, please call me at 263-4944. Sincerely, ~J. Gruber Associate Engineer JG/lt GRU12/L09 Enclosure cc' 1R-12 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Company Well History - Initial Report- Daily · i~slmctioh~ Prepare and submit the "Initial Reporr' on the first Wednesday after a well is spudded or workover operations are started. Dally work prier to spudding should be summarized on the form giving inclusive dates only. District Alaska Field KuParuk River Auth. or W.O. no. AFB 604623 D° on 9 iCounty, parish or borough North Slope Borough Lease or Unit ADL 25635 Title Drill " IState Alaska IWell no. 1R-12 AP1 50-029-21353 O~or ARCO' Alaska, Inc. Spudd~ or w.O. b~un .~ Spudded 7/15/85 IH°ur Date· and depth aa of; 8:00 : : 7/18/85 7/19/85 Complete record for each day reported IARCO W.I. Prior statue if a W.O. 56.24:% 1200 hrs. 16" @ 115' 2960', (2845'), Drlg Wt. 9.7, PV 20, YP 25, PH 8, ~TL 16, So1 10 Accept ri~ @ 0700 hfs, 7/15/85. NU dtverter. hfs, 7/15/85. Dr1 surf hole to 2960'. Spud well @ 1200 16" @ 115' 3965', (1005'), Prep to cmt 9-5/8" Wt. 9.4., PV 18, YP 17, PH 9, W-L 12, Sol 8 Navi-Drl & surv 12¼" hole to 3965', short trip, CBU, TOH. RU & rn 90 its, 9-5/8", 36#, J-55 BTC csg w/FS @ 3953', FC @ 3864'. C&C f/emi. 3014', 19.0°, N3W, 3003 TVD, 74 VS, 82N, 5E 3426', 29.1°, N16Wi 3392 TV-D, 231V$, 236N, 28W 3915', 33.3°, N21W, 3792 TVD, 496 VS, 491N, 104W 9-5/8" @ 3953' 4428', (463'), Drlg Wt. 8.6, PV 6, YP 3, PH 9.5, W-L 14.6, Sol 2 Cmt 9-5/8" csg @ 3953', cmt w/l160 sx PF "E" & 350 sx PF "¢", bump plug. CIP @ 0940 hfs, 7/17/85. ND diverter. NU & tst BOPE. PU BNA, DO float equip. Test formation to 12.1 ppg EN~4. Trip f/motor, drl 3965'-4428'. 4188', 36.8°, Nll.7W, 4016.2 TVD, 652.7 VS, 641.6N, 148.3W 9-5/8" @ 3953' 6928', (2500')t'-Drlg= Wt. 9.6,-PV 15, YP-7, PH 9.5, W-L 5.8, Sol 8 Drl & surv 8½" hole to 6928'. 4373', 40.9°, N17.8W, 4180 TVD, 769 VS, 753.8N, 177.8W 4657', 48.1°, N15.8W, 4362 TVD, 966 VS, 945.5N, 232.0W 4909', 52.3°, N15.SW, 4522 TVD, 1160 VS, 1133.1N, 283.2W The above is ~trect Title Drilling Superintendent For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided_ The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting District ICounty or Parish I Slate Alaska . North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25635 Auth. or W.O. no. ~Title AFE 604623 I Drill Doyon 9 API 50-029-21353 Operator W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun I A.R.Co. Date Spudded 7 / 15/85 7/20/85 thru 7/22/85 Date and depth as of 8:00 a.m. cost center code Alaska no. 1R-12 Complete record for each day reported I otal number of wells (active or inactive) on this est center prior to plugging and I bandonment of this well our ~Prlor status if a W.O, 1200 hrs. 7" @ 8302' 8211' PBTD, (1392'), RI{ 10.4 ppg Brine Drl & surv 8½" hole to 8260', short trip f/logs, C&C, POOH. RU Schl, log DIL/SFL/SP/GR/CAL/FDC/CNL f/8250'-3953', FDC/CNL f/8250'-7500' & 4100'-3950'. Drl 8½" hole to 8320', circ, POOH, LD DP. RU & rn 190 jts, 7", 26#, HF-ERW, K-55 BTC csg w/FC @ 8212', FS @ 8302'. Cmt w/65 bbls, 320 sx Class G, 15.8 ppg cmt. 7/21/85. 7'/21/85. Displ w/10.4 ppg brine, bump plug. CIP @ 1045 hrs, ND BOPE, NU & tst tree to 3000 psi. RR @ 1400 hrs, Old TO Released rig 1400 hrs. Classifications (oil, gas, etc.) Oil New TO Date 8320' (7/20/85) JPBDepth 7/21/85 JKindofrig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 8211' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time ProdlJction Oil q~n te~t. ~ , Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable ' ~ ';~ Ef~Jl~e'.date corrected ' ' ~',,.: ;, ~ ,. ~- ,~ ~ - ,,..,~ The above is cok'~ct '~ ~j -; -; ., JDate ~ I JTitle ~, ~ P~OQ-DNOO '~'~A ~ ~[ ~_ [ ~ I Drilling Superintendent For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 15, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1R-12 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey 1R-12. I have not yet received the Well History (Completion Details). When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Si ncerely, · Gruber Associate Engineer JG/lt GRU12/L15 Enclosures RECEIVED OCT 2 Alaska Oil & Gas Cons. Commission Anch0ra,3e for ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~. ALASKA C._ AND GAS CONSERVATION CO. ,~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A1 aska, Inc. 85-98 3. Address 8. APl Number P. 0. BOX 100360, Anchorage, AK 99510 50- 029-21353 4. Location of well at surface ~ ..... ~-~-r, ' ~,~ i 9. Unit or Lease Name lC, .... ~ON,~, 578' FSL, '215' FEL, Sec.18, T12N, R10E, UN . \'Ei;,'iFi~.D ~ Kuparuk River Unit At Top Producing Interval i , _~~j~ 10. Well Number 1565' FNL, 1394' FEL, Sec. 18, T12N, R10E, UN[~u. ~I~ [.,i~Urr'---~;-" 1R-12 At Total Depth ~ 11. Field and Pool 1223' FNL, 1570' FEL, Sec. 1.8, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 83' RKBI ADL 25635 ALK 2568 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 07/15/85 07/20/85 - 07/21/85'J N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey J 20. Depth where SSSV set 21. Thickness of Permafrost 8320'ND, 6749'TVD 8211'MD, 6671'TVD YES~[~ NO[]I 1807 feetMD 1650' (approx) 22. Type Electric or Other Logs Run DI L/SFL/SP/GR/Cal, FDC/CNL,GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP .BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 230 sx CS II 9-5/8" 36.0# J-55 Surf 3953' 12-1/4" 1160 sx PF "E" & 350 s~ PF "C" 7" 26.0# K-55 Surf 8302' 8-1/2" 320 sx Class G & 250 s~ PF "C" 24. Perforations open to Production (_MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8111' - 8104' 2-7/8" 7937' 7707' & 7908' 8083' - 8051' w/4 spf, 90° phasing 8030' - 7975' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7871' - 7859' , N/A 7850' - 7842' w/12 spf, 120~ phasing 7834' - 7822' 27. N/A PRODUCTION TEST Date First Production I Method of Opera~ion (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief doscripti°n °f lith°l°gY'p°r°sity' fractures' apparent dips and presence °f °il' gas °r water' Submit c°rec~PL~None CIE VE D ~ Anchora§o Form 10-407 * NOTE: Tubing was run and the wel 1 perforated 8/10/85 DRH/INC21 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE' "' :-' ;" ' "" :": (~EoLo~'ic:MAR'Ki~RS '~ - ' " " ' ' " '' ' FORMATic~N'TESTs' ' . ...... · NAME ..- Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . Top Upper 5and 7772' 6359' N/A Base Upper Sand 7833~ 6z~02~ Top Lower Sand 7954' - 6488' Base Lower Sand 8112' 6600' , · 31. LIST OF ATTACHMENTS Gvroscoo~c Survey ¢2 copies) 32. I hereby certify that the foregoing is true and correct to the' best of my knowledge Signed ~ ~ ~_ Title AssocJa~;e Erlgineer 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 (G L) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Alaska, Inc. Post Office Bo. ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 19, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1R-12 Dear Mr. Chatterton' Enclosed is the Well Completion Report for the subject well. I have not yet received the Well History (completion details). When I do, I will forward a copy to you. Also, the bottomhole location, TVDs, and geologic markers will be submitted when the gyroscopic survey is received. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU11/L80 Encl osures RECEIVED Alaska Oil a Gas Cons. Con, mission Anchoraoe ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -~-'- STATE OF ALASKA .~-- ALASKA (, . AND GAS CONSERVATION CO .ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .- 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-98 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21353 4. Location of well at surface 9. Unit or Lease Name 578' FSL, 215' FEL, Sec.18, T12N, RIOE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is received. 1R-12 At Total Depth 11. Field and Pool To be submitted when gyro is received. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 84' RKB ADL 25635 ALK 2568 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 07/15/85 07/20/85 07/21/85* N/A feet MS L 1 17. Total Depth (MD+TVD) 8320' MD 18. Plug Back Depth (MD+TVD)8211 'MD YES19' Directional Survey[~x NO [] ] 20. Depth where SSSV set1807 feet MD I21' Thickness °f Permafr°st1650' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/Cal , FDC/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 230 sx CS II 9-5/8" 36.0# J-55 Surf 3953' 12-1/4" 1160 sx PF "E" & 350 s; PF "C" 7" 26.0# K-55 Surf 8302' 8-1/2" 320 sx Class G & 250 s~ PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8111' - 8104' 2-7/8" 7937' 7707' & 7908' 8083' - 8051' w/4 spf, 90° phasing 8030' - 7975' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7871' - 7859' N/A 7850' - 7842' w/12 spf, 120° phasing 7834' - 7822' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD 1~ I , Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None /[laska 0il & Gas Cons. C0mmi~sJ0n A. nr::h0ra~,e Form 10-407 * NOTE: Tubing was run and the well perforated 8/10/85. DPJ-i/WC21 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE '- ..... ' GEOLOG'IC MARKERs - ' .......... '" ~ ...... ~'":'~FoRMATIoN TEST~; · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH. GOR, and time of each phase. To be submitted wk'.~n gyro is recei fed. N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~ ~~ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the produbing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Alaska, Inc. Post Ottice Box ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 19, 1985 Hr. C. V. Chatterton Commissioner state of AlaSka Alaska Oil & Gas Conservation commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1R-12 Dear Mr. Chatterton' Enclosed is a copY of the 1R-12 Well HistorY to include with the Well Completion Report, dated 09/10/85. Ii= you have any questions, please call me at 263-4944. S i nce rel y, . Gruber Associate Engineer JG/tW GRUll/L86 Enclosure RECEIVED SEP 2 a ]985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, inc. is a Subsidiary o4 AtlanticRichfieldC°mpany AtlanticRichfiek,~;ompany '~' Daily Well History-Initial Report Inll~3clionl: Prepare and submit the "Initial Rsl~Orl" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska County or Parish North Slope Borough Lease or Unit ADL 25635 Title Drill IState Alaska Kuparuk River IWell no, 1R-12 Auth. or W.O. no. ArE 604623 Doyon 9 APl 50-029-21353 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 7/16/85 7/17/85 7/18/85 7/19/85 IDate I Hour 7/15/85 Complete record for each day reported 1200 hrs. A,R.Co's W.I. 56.24% Prior status If a W.O. 16" @ 115' 2960', (2845'), Drlg Wt. 9.7, PV 20, YP 25, PH 8, WL 16, Sol 10 Accept rig @ 0700 hfs, 7/15/85. NU diverter. hrs, 7/15/85. Drl surf hole to 2960'. Spud well @ 1200 16" @ 115' 3965', (1005'), Prep to cmt 9-5/8" Wt. 9.4, PV 18, YP 17, PH 9, WL 12, Sol 8 Navi-Drl & surv 12¼" hole to 3965', short trip, CBU, TOH. RU & rn 90 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 3953', FC @3864'. C&C f/cmt. ~ ~/ /l~ ~ ~F"£"~ ~ ~ ~ ~ .... '~ 3014', 19.0°, N3W, 3003 TVD, 74 VS, 82N, 5E 3426', 29.1°, N16W, 3392 TVD, 231VS, 236N, 28W 3915', 33.3°, N21W, 3792 TVD, 496 VS, 491N, 104W 9-5/8" @ 3953' 4428', (463'), Drlg Wt. 8.6, PV 6, YP 3, PH 9.5, WL 14.6, Sol 2 Cut 9-5/8" csg @ 3953', bump plug. CIP @ 0940 hfs, 7/17/85. ND diverter. NU & tst BOPE. PU BHA, DO flt equip. Conduct formation to 12.1 ppg EMW. Trip f/motor, drl 3965'-4428'. 4188', 36.8°, Nll.7W, 4016.2 TVD, 652.7 VS, 641.6N, 148.3W 9-5/8" @ 3953' 6928', (2500'), Drlg --~~ PV 15, YP 7, PH 9.5, WL 5.8, Sol 8 Drl & s~rv 8½" hole to 6928'. 4373', 40.9°, N17.SW, 4180 TVD, 769 VS, 753.8N, 177.8W 4657', 48.1°, NI5.SW, 4362 TVD, 966 VS, 945.5N, 232.0W 4909', 52.3°, N15.SW, 4522 TVD, 1160 VS, 1133.1N, 283.2W The above is correct Signature For o pep *on a d distribution see Procedures Manua, SectiCn 10, Drilling, Pages 86 and 87, JDate 7/30/85 JTitle Drilling Superintendent AR3B-459-1-B INumber all daily well history forms conseculively as they are prepared for each well. no. ARCO Oil and Gas Company Daily Well History-Final Report InslrUclions: Prepare and submit the "Final Reporl" 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 o1' time. On workovers when an officiaJ lesi is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporling the entire operation if space is availabJe. District ICounty or Parish Alaska I North $1oBe Borough Field [Lease or Unit Kuparuk River I ADL 25635 Auth. or W.O. no. ~Title AFE 604623 I Drill IAccounting cost center code State Alaska Well no, 1R-12 Operator Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. Doyon 9 A.R.Co. W.I. ARCO Alaska, Inc. Date 56.24% 7/15/85 Complete record for each day reposed 7/20/85 7" @ 8302' thru 8211' PBTD, (1392'), RR 7/22/85 10.4 ppg Brine Drl & surv 8½" hole to 8260', short trip f/logs, C&C, POOH. RU Schl, log DIL/SFL/SP/GR/CAL/FDC/CNL f/8250'-3953', FDC/CNL f/8250'-7500' & 4100'-3950'. Drl 8½" hole to 8320', circ, f POOH, LD DP. RU & rn 190 its, 7", 26#, HF-ERW, K-55 BTC csg ~]~ w/F~~, FS @ 8302'. Cmt w/65 bbls 15.8 ppg cmt~ Displ w/10.4 ppg b~ine, bump plug. CIP @ 1045 hrs, 7/21/85. ND BOPE, NU & tst tree to 3000 psi. RR @. 1400 hfs, 7/21/85. New TO 50-029-21353 I otal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well I our I Prior status if a W.O. I 1200 hrs. Date Old TD Released rig 1400 hrs. Classifications (oil. gas, etc.) Oil Producing method Flowing Potential test data I PI~ Depth 8320' (7/20/85) 8211' PBTD I Kind of rig 7/21/85 Rotary IType completion (single, dual, etc.) Sinsle Official reservoir name(s) Kuparuk Sands Well no, Date Reservoir Producing Interval Oil or gasTest lime rPro~uction OiJ 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 IOate/ I ~r'~tl~ ~., .~_~uperint end en~ For form preparer , see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459~3-C Alaska 0il & Gas Anchoring. Number all daily well"~i~tory forms consecutively ~_Page no. as they are prepared for each well. Division of AllanllcRIchfleldCompa,'l¥ ARCO Alaska, Ir''~ Post Offic,, ..~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-17-85 TRANSMITTAL NO:5357 . RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO-1 llSB . P.O. BOX 100360 ANCHORAGE, AK 99510 ENGINEERING TRANSMITTED HEREWITH ARE YHE FOLL~4ING IT~iS. PLEASE ACKNOWLEDGE RECEIPT AND ~L~TUKN ONE SIGNED COPY OF T~IS TRANSMITTAL. OPEN HOLE FINALS/ MCHL (ONE * OF EACH) 1R-13 ~,5"---'-DIL/SFL-GR 2"-""' DIL/SFL-GR 5' ."~'/ DEN/NEU PORO ~ '~2"'"' DEN/NEU PORO ~ ~-- 5'''/ DEN/NEU haw '~.2"---"DEN/NEU RAW ~4CYBERLOOK 07-27-85 RUN #1 3944-~550 07-27-85 RUN #1 3944-8550 07-27-85 RUN #1 6900-8524 07-27-85 RUN #1 6900-8524 07-27-85 ~UN #1 6900-8524 07-27-85 RUN #1 690'0-8524 07-27-85 ~UN ~1 6900-~501 [ -10 / UIL/SFL-GR ~"-2 DIL/SFL-(=R ~ ~"~5" / DEN/N~.'U .m ~2"/ DEN/NEU ~ ~'- 5"/' DEN/Ni-.'U ~'~2 ".'~"_ DE N / N ~: U ~YBERLOOK PORO PO RO RAW PO t<O PORO RAw RAW PORO oRU RAW I<AW RECK'IPT ACKNOWL~:DGED: BPAE B. CURRIER CHEVRON D & M*BL 07-20-85 RUN ~1 3950-8242 07-20-b 5 RUN ~1 3950-8242 07-20-85 RUN #1 3950-8219 07-20-85 RUN ~1 3950-8219 07-20-85 RUN #1 3950-8219 07-20-~ b RUN ~1 3950-8219 07-20-85 RUN ~1 7600-8220 07-06-85 RUN ~l 4633-8702 07-06-85 RUN ~l 4633-8702 07-0 b-85 RUN ~1 6500-8671 07-06-85 RUN #1 6500-8671 07-0 6-~5 i{UN ~1 6500-8671 07-06-85 ~UN #1 6500-8671 07-06-85 ~UN #1 8000-8700 06-28-85 RUN 06-28-85 RUN 06-28-85 RUN 06-28-85 RUN 06-28-85 RUN 06-25-~5 RUN 06-28-85 RUN DISTRIBUTION: DRI LL1N(~*BL W. PA~HER L. JOHNSTON EXXON MOBIL PHZL~.IPS OiL N~K CLEi~K*~L J. KATHMi.'LL*~L #1 4032-8114 #1 4032-8114 #l 4032-8088 4032-8088 #l 4032-8088 #1 4032-808~ #1 4032-~8114 !<'- " '' '.-'~ ~..,;-;~l~ '~. ~; .... ~hlO ........ ~ /SS UNION K . TULIN / VAULT* FILM ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, inc. Post Office b,.,^ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-11-85 TRANSMITTAL NO:5346 Pd~TURN TO: - ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECOKDS CLERK ATO-1115B P.O. BOX 100360 ANCHOP. AGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE KECEIPT AND KETURN ONE SIGNED COPY OF THIb TRANS~.IITTAL. lQ-12 2z-2 3B-14 WSW-5 iR-ii 1R-12 1H-07 SEQUENCE OF EVENTS SBHP 9/3-4/85 SEQUENCE OF EVENTS FRACTURE STIMULATION 9/2/~5 SEQUENCE OF EVENTS PBU 'A' SAND 9/2/85 SEQUENCE.OF EVENTS TEMPEkATURE LOG 8/15/85 STATIC BOTTOMHOLE PRESSURE REPORT 8/19/85 STATIC BOTTOMHOLE PRESSURE REPORT 8/19/85 STATIC BOTTOMHOLE PRESSURE REPORT 8/20/85 RECEIPT ACKNOWLEDGED: BPAE* B. CUKRIER CHEVRON* D & M* DKILLING L. JOHNbTON MOBIL* NSK CLERK DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL* J. RATHMELL* S T ~AL-A S.K A" ' UNION * K.TULIN/VAULT ARCO Alaska. Inc. is a SuDsJdiarv of A!ienticRichfJeldComDany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 11, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1R-12 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for 1R-12. I have not yet received copies of the Well Histories. When I do, I will forward them to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L54 Enclosures kECE VED SE? 1 '? i B5 Alaska Oil & Gas Coils. Com~nission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany - ' ~--", STATE OF ALASKA ALASKA L ~ AND GAS CONSERVATION CO ISSION WELL COMI LETION OR RECOMPLETION REI ORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I'~. ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-98 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21353 4. Location of well at surface 9. Unit or Lease Name 578' FSL, 215' FEL, Sec.18, T12N, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is received. 1R-12 At Total Depth 11. Field and Pool To be submitted when gyro is received. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 84' RKBI ADL 25635 ALK 2568 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 07/15/85 07/20/85 07/21/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8320'MD 8211 'MD YES I-~X NO []I 1807 feet MD 1650' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR/Cal, FDC/CNL, CET, GCT (Gyro) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD iAMOUNTPULLED 16" 62.5# H-40 Surf 115' 24" 230 sx CS II 9-5/8" 36.0# J-55 Surf 3953' 12-1/4" 1160 sx PF "E" & 350 s~ PF "C" 7" 26.0# K-55 Surf 8302' 8-1/2" 320 sx Class G & 250 s~ PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8111 '-8104' 7871 '-7859' 2-7/8" 7937' 7707' & 7908' 8083'-8073' w/4 spf, 7850'-7842' w/12 spf 8073'-8051 ' 90° phasing 7834'-7822' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. ._ 8030' -7975' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~' . I Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None i'(ECEiV l) Alaska 0il & Gas Form 10-407 * NOTE: Tubing was run and the well perforated 8/10/85. DRH/WC19 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE - -. GEoLO~ic_~Ai~i~ERS ': ,..~;i,~' ' :" : ~': ..... "':'. ' ,'FORMATiON TESTS' · ' '' · · . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted wt,~n gyro_is recei fed. . . . 31. LIST OF ATTACHMENTS None ., 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS -General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection., water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". $UB-SURFACE DIRECTIONAL ~URVEY ~UIDANCE JC--]ONTINUOUS L.T..~ oOL Company ~co ALA. SY~ INCO ,P~O,Pd~TED , . Well Name 1R-12 (578' FSL, 215' FEL~ S18. T]2N. R]OF. IT~% Field/Location ~,~, ~9~:~ S~,O~E. ALARKA -- Job ,Reference No. 70818 HALFACRg R EC E IV ED 18-September-85 r~,c.? 2 5 Computed Alaska 0it & Gas Cons. Oor;~rnis~, .... BOLAM GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. IR-12 KUPARUK NORTH £NGINEER! V,, HAL~ACRE METHODS OF COMPUTATION TOOL bOCATIONI TANGENTIAL- averaqed deViation and azimuth )NTERPOLATION~ LINEAR VERTICAL SECTIONS HORIZ. OIST, PROJECTED ONTO A TARGET AZIMUTH OF NORTH 20 DEG 41MZN WEBT COHPUTATION DATEI 1R-REP-85 ARCO AbkSKA, TNC, IR-t2 KUPARUK NORTH SLOPE,ALASKA ENGINEERI V,. HAbFACRE ZNTERPOLATED VALU£$ FOR EVEN lO0 FEET OF MEASURED DEPTH TRU~ SUB-SEA COUR$~ VERTZCAb DOGb GE RECTANGUbAR COORDINATE6 MEASURED VERTX,CAL VERTX~AL DEV~ATXON AZXMUTH SECTXON SEVgRXTY NORTH/SOUTH EAST/NEAT DEPTH DEPTH DEPTH DEG MXN DEG MTN FEET DEG/.tO0 FEET FEET PAGE DATE OF SURVEY! 26 JUL. 8S KELbY 61JSHtNG EbEVATXONI 83,00 r'Z o. Oo o oo -8 o g ~ ~o o ~o.,~2°'°° o.2o°'°° o.oo I o.oo ,oo.oo ,oooo .o. , ~:~ ~i!; ,oo.oo ~oo oD ~ ~ o.~ ~:t;o..?~ ,oo.oo ~oo oo ~ ~ o.,, *, ,.,o o.,, ,.,, o.,. ,.,, 900~00 899 99 8t6 g9 2,92 l~oo.oo ll~...~~9~'9? =l~.~?tls.~ ~ ~ o,o~ o,.o~ ] 1500,00 o ,, .,.,o o.,, ,.,, o.,, 1600,00 1599.95 516.95 ~ 4? lO 20 ~ -3.6? O.6S 3e.73 3,76 ,,oo.oo ,,,,.,, """ o ",' "'~""' 42 O.l? 4~85 ~ 0~3 1800.00 1799,95 716,93 0 56 45 t2 -5.13 0.13 5,97 S 1,29 1900.00 ~899.92 ,26.92 59 $46 55 W ~5.79 0,12 ?~1~ $ 2,50 ~ooo.oo ,~.~o ,~,~.~o ~ ~ ,~ ,,~ .~.~o o.,~ ~.~,.~ tO,3~ it, 61 -?°82 ,oo.oo iI"" .,.,,o.,, ,.,, 2400,00 2399.88 2316.88 0 2? 5.1111:60 S 2! -8.i3 1.52 10.63 2500,00 2499,84 2416,84 21E -6,{~ 3,60 8,44 4,t9 9 42 2600,00 2599.52 2516,52 5 43 1~ 1.~9 oegO ~,S? , 4 2700.00 2698.77 2615.77 I! 29 N~ 2i~ ~ 1.13 · 7,i! 29 64 2~00.00 2797.17 27141~7 55 29.4~ 2900.00 2894.3' 2811.31 3? N 34 E 51.08 4.29 S2.40 5.82 52 ,ooo oo ,,.,.,, ~,o,.,, ,, ,,,,,, ,..o, ~'",,,"""; '" ,,,"",, ~,oo oo ~o04.,, ~oo~.,, ,~ ~~~ ,o,.,x 2.,, ,, 3700 O0 36i4.45 353i,45 35 14 383.48 38t,75 4 56 388 96 3800 o0 3696,09 36t3,09 34 t3 441,04 ': ~ 4~?,24 90 Ss 446 52 3900 O0 377~.97 3696.97 32 49 ~ z, ~495,41 4e0,02 ~07 31 SO0 66 DEPARTURE AZIMUTH DEG, P4IN CONPUTATZON DATEI ~8-SEP-85 IR-J2 KELL~ BUSHTNG :' N KUPARUK NORTH ST.,OPE,At,,AAKA ENGINEERI V.. HALF'ACRE ZNTL.PRPOL, ATED VA~UE:$ FOR EVEN 100 K'I~ET OLr' REASURED DEPTH TRUE SUB.,Si~A COUR5~ VERT:[CAL DOGLEG RECTANGUbAR COORDZN, ATES MEASUR£D V£RTICAt~ VERTZ,C;IIL D~VIATION AZ[RUTH Sr, CTION $£VER[TY NORTH/SOUTH EAST/NEST DEPTH DEPTH DEPT,'s...:. DEG. NXN DE:G RXN FEET DEG/IO0 FRET FEET ,; ,ooo oo ,.,,.., ,,.o.., ! ~i ,,,,.! , ooo 49 ~ 107T,t9 0,'80 5i00 O0 4641, 4558~ 52 49 ~ li t7 1~ ~ 1234e',t2 1.~0 1203~34 306 74 5300 4762. 4699. 53 32 ~ 19 59 ~ 1473.06 1.89 1430e95 80 5400 4821,~6 4738. 53 29 20 57 5500 O0 4882,35 4;99. 5 5~ ~9 ~ 2~ 47 ~ Z55~.69 ~,50 2506,42 4O8 ,,oo oo ,oo,. 492,. ~ ~ ~ ~ 2, 1789~65 1.43 1725.9~ ~ 466 24 5,00 O0 5129.4, 5046. ~ 5, ~ 24 28 24 53 ~ ~868.63 1,7~ ~7~8e75 1947.20 0.2~ 1870.24 ~ ~9 05 6{00 O0 ~252. 5t69,34 5~ 3 2~04.55 2~58 2013~44 ~ 59 6600 O0 5568.,19 5485. 49 '5 6700 oo s633,5~ 5550. 48 53 ~ 26 ~ 2490.41 lei9 2361.57 795 6800 oo 5699.40 5616.40 48 43 25 7400 &098 63 6015.83 47 1~ 3012.99 e~ ~ 7500 6167 ?i 6084.7~ 46 ~ 26 ~ 3086 52 2899,82 1057 27 X5 ~58 60 2964,55 ~ ]090 X58 72 ,,o~o,,,,,, ,,,,.,, ,,,~~,, ,,,,,~oo ,o,..,, 7900 O0 6449 6366.28 44 4T ~ 27 3440 84 32]7.~4 ~ 40 DK;PARTURE: DtI:G. KiN COMPU?ATIOH ARCO ALASKA, ~NC. , DATE_OF SURVEY1 26 dub 85 IR-12 KEbbY BUSHING EbEVATIONI KUPARUK NORTH 3:NTERPOLATED VA[,UE$ FOR EVEN 100 FEET Or HEASURBD DEPTH , ,, TRU~ SUB-SEA C~URSg VERTICA~ DOGbEG RECTANGULAR COORDINATES NEASUR£D V~RT3:CA~ VERTZCAb' DEVIAT3:ON AZZHUTH $EC?ZON SEVER. ZT¥ NORTH/SOUTH EAST/NEAT DEPTH DEPTH DEP~H":,:'DEG N~N DEG 46 86 13,00 lr'T DEPARTURE DEG # 3:N ARCO ALASKA. ]:NC. IR-1,2 KUPARUK NORTH .St, OPE.ALA,SKA COMPUTATION DATEI 18-8EP-85 ENG~NEERI V.': HA. brACRIg. ,, !XNTERPOLATED VALUgS FOR EVEN 1000 FEET or MEASURED DE;PT SUB-SEA, TRU~ 8EVERZTyDOGbEG REC~ANGUbRR'NORTH/&OU~H ERST/N~a~'COORDZNA~E&~;N'~a~f i~.'.~'~ OgPAR~UR~ NEASURED VERTICA5 VERTICAb DEVIATION AZIMUTH SECTION AZZNU~H DEPTH D~PTH DEPTH~ DEG M~N D~G HZN FEET DEG/IO0 FEET fEET o.oo .,,.oo. .oo .oo o.oo . ~ 50 .46 8.3683, N 2000 O0 1999.90 191&'90 3~ .,47 ~ooo'°°° oo ~,,oo ~,~o ~,o?.,? ~! ''~ ~.~? '~ ..o? o~:~ ~:, " 44980234~ ~ 1954 ~34' t2 . ~.30 203. 3074 7000 O0 5831.86 5748.86 32 ~ ~.~ 77 . .~ ~, . ,2? .8~ . ,?~o. ~.. ' 27 N 333. 0.00 t7g.34 N ARCO ALASKA, :]:NC. 1R-12 KUPARUK NORTH si,OpE,ALASKA COMPUTATION DA?~ 18-$EP-85 ENGINEERt V, HAbr&CRE INTKRPObATED VAbUES FOR EVEN 100 rE:ET Or SUB-SEA DEPTH, · . . :1 :: .L TRUE SUB-SEA" COURSE VERTXCAb DOGbEG, RECTANGUbAR MEASURED VERTICAb VERTICAb, DrEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EA~3-/w~-l- ~iS~:":,:~,"~ AZIMUTH DEPTH DEPTH DEPTH' :DEG MTN DEG HTN FEET DEG/IO0 FEET FEET F~, DEG.HZN 0 O0 83 O0 383 O0 483 O0 ol 283 383 483 663 106 oo .,,'oo ~ ~ ~ o.oo oo I '~ g '" ~ g.,, ~ 0.22 76 O0 200.00 15 39 3548 E 0'44 26_ O0 400,00 ~ 33 ,20 ~ 0.50 oo,oo.oo ,00 600,00 17 56 _o45 23 0~ : : 6e oo~oo oo o 2o . ~ ~ ~ 46 2083 2163 2283 2383 2463 2583 2684 2765 2888 000 O0 t 8 O0 oo ½i~ oo 04 1383 O0 04 1463 O0 ~I~0 O0 05 1563 O0 150~'°0 .oo 08 1881 O0 1800.00 1963.10 1963 O0 1900,00 I ~o,~ 2000.00 163 2100.00 ~ ~ g~ ~oo oo 2383 300 O0 4 2483 O0 2400 O0 40 2583 O0 2500 O0 06 2693 O0 2600 O0 53 2763 ,27 2883 0 59 0 53 0 16 0 5 0 22 2 23 5 24 7 59 ~ ~700 O0 1! 26 600 O0 15 7 ~.~ ~..~ oo2~ .oo ~o~,.oo ~o,~ oo ~o°° 00.~0 16 54 3204,72 O0 ,00 22 9 3426.24 li~ O0 330~,00 28585 3542,38 O0 340 o00 31 3661,69 3583 O0 3500,00 34 23 3784,08 3683 .00 3600,00 34 40 3903,60 3783 O0 3700,00 32 51 4022,94 3883 O0 3800,00 33 ! $ 40 34 vi S 6934 vi N 73 6 W S 50 45 ~ N t2 14 E N 15 15 W N 4 19 vi N 2 14 E N 3 31 r~ N 10 30 W N 15 5 W N 14 46 N N 19 27 W N 19 44 W ! ,77 -0 0 ,,! 4 -1, 62 -2 34 -3 46 -4 34 -5 01 -5 67 O, '6,35 "7.39 -7,63 -7,67 -8,04 -7,10 48 4 t9 49 28 N 6 49 64 N 657 107 49 2,80 1! ?,05 112.45 ,,, 0, 3,,, ,,}:ll ~ ""' ~2.o,' "9'" 296 91 2,~6 ~.97 ~ 36.22 ~ 243,6! 361 70 2,43 ~66 68,76 437,49 4~ a4 2.09 .85 0,.95 ~ 502.58 COHPU?ATION DATEI 18-$EP,,85 ARcO AbASKA, TNC. 1R-12 KUPARUK NORTH 6LOPE,AbASKA ENGINEERI V,~ HAbrACRE INTERPObATED VA~UKS FOR EVEN 200 FEET OF SUBmSEA DEPTH '.' TRU£ SUB-SEA '*= COURSE VERTICA~ DOGbEG.. RECTANGUbAR COORD'INATE8 NEASUR~D V~RTICAL VERT!CAL,.,DEVIATION AZIHUTH SECTION SEVERITY NORTH/SOUTH EAST/NEST I DEPARTURE A~II4UTH ::~:, DEG NIN 4,44.~ 3983 O0 ~900'00,8'69 N.152~ ~ 70604 , 17 79 ~ 118{i 14 25 H 17 63060 2.2] 6~6.68 4083 O0 26 3,26 689,07 . ;0 4000,00 ~ 883 19 1.57 4400. 4183 O0 4]00,00 ~ ~ 19 89 22 08 - 420 ,,oo.oo ,, 5268. 4683.00 4600.00 45 28 1367,82 0.36 1331,3; ~ 346:~6'~ 533S, 4783.00 4700.00 46 20 32 0.93 1457,47 390..15 1508,~8 5501. 4883.00 4800.00 38 ~ ~ 1501.34 6307 O0 5300.00 ~ 26 ~ 2265.46 0.31 ?158.79 695,93 2268,19 6467 OO 5400.00 49 26 2 2~88.89 1,77 2270,2! ,?SO 27 w 2290,98 6622 oo 55oo,oo 26 2~ 6775i~ 5683 oo 5600.00 48 4~ N 25 50 w 853 80 2623,19 6926 5783 O0 5700.00 48 ~ _ ~ 25 58~ 2734.96 0,2? 58 e34 903 32 2735,78 7077 5883 O0 5800.00 48 25 57 . 952 76 2847,98 7227 49 5983 00 5900,00 48' 25 5~ 2784,83 7376616083006000.00472;~ ~ 26N ~ 2959.21~ 3375.30 0'28 t00189w 2959,57 3069.~7 0 92 2884.35 ~ 10.0 18 ~ ~069,58 7522 06 6183 O0 6100.00 46 N 27 16 3{74.40 0 35 2978,69 ?097 67 ~ 3174,50 27 14 ~ 3069.74 ~ 1144 58 {276.:~8 ?e06 48 6 e3 oo 6 00.00 44 U 36 0 20 794~ 46 6483 oo 64o0 0o 44~ 27 1~ - ~354.65 1280 84 3572.17 8~28 06 6683 00 6600.00 44 26 27 ~ 3669.58 8320 O0 6748 .64 6665.64 44 26 N 272 N 3733.57 0.00 3479,34 N 1354 ~! N 3733,77 N 16 ARCO AbAEKA, IN~, 1R-12 KUPARUK NOR?H ~LOPE,Ar, ASKA HARKBR TOP UPPBR SAND BASE UPPER SAND TOP LOWER SAND BASE bOWER SAND PB?D COMPU?ATXON DATEI 18-$EP-85 INTERPOLA?ED VAbU£S FOR CHOSEN HORI'ZON$ MEASURED DEPTH BEbOW KB 77?2,OO ?833.00 8 12.00 1,00 8 20,00 PAG~ DA?~ or su.vE~, 2~ ~p KEbb¥ BUSHING EbEVATION85 b~ 83,00 PI ENGtNEERI Vo HAbFACRE: ORIGTN~ 578', rSbe TVD FROM KB 8UBmSEA 64 ,1,4 82 64 6358..56 6275 640i,79 63.18 6487.64 6404 6600,14 6 1748,6~ 6665 SURFACE, .bgC.a~ZON REC?AgGUbAR'~:IRD~NAT~8 NORTH/SOUTH,~?!:~AAT/WEST :64 ,34 ARCO ALASKA, TNC. KUPARUK NORTH SLOPE~ALASKA MARKER TOP UPPER SAND BA$~ UPPER SAND LOWER SAND PBTD TD COMPU'rA'IK'ZON DAT£1 18-$EP-85 **~$****$*** STRATTGRAPH~C N£ABURED DEPTH BEbOW KB ??~2.00 7833~00 7954.00 81~2.00 R211~00 8320..00 ENGXNEERI V,, HALFACR~, SUMMARY ******~***** ORIGINm., 578~ rSbp TVD FROM KB SUB-AEA 6358.56 640! 79 6487 64 6600 ,14 2'75 66318 6404 56 ?9 64 14 82 64 FINAL WEI.,b bOC.ATZON AT TDI TRU£ SUB-SEA MEASURED VER?ICAL VERTICAb DEPTH DEPTH DEPTH 8320,00 6748.64 6665.64 HORIZONTAL DAE~ARTURE DISTANC£ IMUTH FEET DEG MXN 3733.77 N 21 16 W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC NELL 1 R- 12 FIELD KUPARUK COUNTRY USA RUN ONE DRTE LOOOEO 26 JUL 85 REFERENCE 0000708]8 SURFACE LOCATION: 578' FSL, 215' FEL, SlS, T12N, R10E, UM VERTICAL PROJECTION -~000 - ! 000 0 0 !000 ~000 :3000 4000 ,~000 6000 ............... ; ...................................................,..~.-.~..~4...1.-.~..,~...: ........ ;- .............. 1...~.4 ............ ~....:....: ....... :...L..: ............. ~...~...~..~...~....t ........ ~ ...... ~. ~s9 .... ~..~.-.~.,+..l-.-~.--~-.~,.~.....+.~+~--~+.?.~.., ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ..... :...: ....... ...:., :..: ...... _..:..:. _. : ,.~ ..... :., :...:. .............................. : - · . 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', "7'"F '; _ T' ~ ........... ~ ................ ~ ............. + "7' T"T'"~'T' ~' ~'" ~ ....... · ........... ; ...... %'" "~ ....... :'" ~.:; .:.': '7';'";'"::':':. i.': .......... :' ~'~:':.:' - .......... . . , ............ ',;L.;.'.'7~: ;; .7 '; "t" ; ;.E; .; ; ';:. " ;;' ; t" , . _ . .................. : ......................... ~ ............. ~ ................................................................................................... " ~ .......... T"%'~ ............... I ........... ' ........................ F'~'"~ ............ '" :"~ ":'~ . '~ ...... ~ ........... · ~ ~.-; ' i ' . ~ ..... ._. ~...~ ...... ~ ...... ~.-? ..... . ~ · ~ .......... : , [..,-.~ ......... ~..:..., ....... :..-~ ................... ~ '; ':' r." ..... :'~'"_ . ........................ · . .... ...... ~ .... O, ; . ' . -1'. O~ ............. ~ ........... t ............... + ........ ~ ......... t ................ ~ ................... : ........ ~'-~ ............... , : . ~ / '. ~.. ' ' ~ ~ ....... ~:~'. ~ .' ~ ~ ..........~_;~ ~.~ ;E ..... .~;'.~:.~..~.~..; ......... ~ ................................... ~ ...................................... ~ ................. ~ ..................... ~ .................. :'":: ..... ?_:_ ' ....... '~i~.~ '- PROJECTION ON VERTICAL PLANE 339. - ISg. SCALEO IN vERTICAL OEPTH$ HORIZ SCRLE = 1/1000 IN/FT WELL NAME: iR- 12 -SURFACE LOCATION: 578' FSL, 215' FEL, S18, T12N, R10E, I/M HORIZONTAL PROJECTION I~oo0 REF' 0000'70811] SCALE = 1/1000 IN/FT ...t...t ....... ~..-l.:,f..~..-~..`~.--] '"~'"~'"~'~'"~:"f"~"~"t"']": '~"'~ ....... ~"~'-?~"~'~--t''tll?~''t--'~ll~''%T''l'--f''t--i''~':'t'''~'''': ....... ~l'l[--l't'll~ ....... t...t...t--~Y~.}...~..~..~t`..t~.t..~."t...?"t...t~.~-t...?-t...~-j~*~.t..t-.t...~ ~w"?i ~ ~:-?' : i : : ~ ~ , F-~--w~T; I : : ~ ~ : ' I~-T~~7-*~VT-F~ ~ ; ~ : I: : ~ ~'~'~ ...~. ..... ~.--~--.~..':''.~''~''~'"~--''''~''=:"l'~'--~''l~''~--=:'''*lll~''l=~m~'+'~ ..... +----~4''':--''~''l:ll~''': .............. ~''': gO00 : : : , ~ ~ : : ~ - . - ~ ~ : ~ : : : - : · I : ~ ( ~ : ] ~ [ [ '. [ : : '. ~ : : ' I :: ' : : ~ : i I : ~: : ~ : : ] ~ ~] : ~ I ~ ~ : I : : ...;...z..:..~. 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L.; ....... "~':"~ ' ~ ..... ; ........ =: ...... ~ ........ :": ....... ~:"~'~"~': ~ "-"'~'~':"':- - ~ ~ . ~ ........~ . - ~' ~.~ ~ ~ : ' ~. .~ ! ]ooo . ._ : , ,. .; - ',.k ~ -. ~ .. : .'~ ~ '. :. I ~ ~ ~.[ ................... j .. .' .. ; ~ .................. ~ .......... ~---~ ........ ~ ........................... ~ ........................... ~-~ ......... ~ ................ f---~---H-~---T .......... T ...... ~--------y--1 : . ~ ...... ~:"~=~'~,. .... ~._ _._: ...... ~ . ..~.~ ........... ~ ........... ~..~. ~. ........... ~......~ ................ L..L./..~..L._L.~ .... ..................... ~ .......... ~ ........... :-..:.4 ........... =-~-'-~-"?-r-H~'"~"H~ ........ ~--=--.= : ..... ; ........ . r---~---L-: ..... ~ ........ :----: -7-~ ~ --; ............ r .............. =--'i ......... S'"ZSSZ"~ '~"i .... -1000 -~ ~ .....~ ..... . . ~ .'. .. .. -~ooo -~ooo -2ooo -~ooo o :ooo zooo aooo qooo WEST E~T Suggested form to .be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WELL ~AbIE AND NUMBER Reports and Materials to be received by: Date Required Date Received Remarks Completion Report '-~ z ~L/~--_-- ~ ~-.h ! Core Chips ,~~__ '~h~" ' ....... "~, xld Core Description ~/~ . ~/~ /'~-- ,, Registered Survey Plat ~ Inclination Survey ~- Directional Sur~~ 7~.S .... ~/ /~- ~. ~ ~< ~~ Drill Stem Test Reports Production Test Reports ~*-~.r ~,-~*-' _., .... . Digitized Data ~~ ARCO Alaska, In~.. Post Offi( 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 /t DATS: 09-05-85 TRANSMITTAL NO: 5332 RATURN TO: TRANSMITTED 'RECEIPT AND SEQUENCE OF ARCO ALASKA, INC. KUPARUK_OPERATIONS ENGINEERING RECORDS CLERK ATO-1115S P.O. BOX 100360 ANCi~OKAGE, AK 99510 HERL54ITtt ARE THE FOLLONING ITEMS. 11/-3 -" PBU 2A- I--- ' C ' 2B-13-' 'C' 2C-U 'A' 2V-2 - 'A' 2V-5 ~ 'A' RETURN ONL SIGNED C~PY EVENTS PKESSURE DATA OF THIS 03-07-85 SAND PBU 08-03-85 SAND PBU 08-01-85 SAND PBU 08-16-85 SAND PBU 07-27-85 SAND PBU 06-25-85 PLEASE ACKNOWLEDGE TRANSMITTAL . SEi-:UENCE OF EVENTS FROM WELL SERVICE lA-8~'' bBHP & MISC. 0 lA-5 PBU & MISC. 0 IA- 3/ PBU 0 lA-3-~ PBU 0 lB-2-- 'C' SaND Pt~U 0 1B-2~ 'C' SAND PBU 0 lB-5 / STATIC TEMP.LOG iE-21~ RUN BHP & MISC. 1F-5 PBU 'A' & 'C' bAND {ISLT-D) 1F-5 / PBU 1G-15-/ 'C' SAND PBU 1G-15~- 'A' 5AND PBU 1G-15/ 'C' SAND PBU 1R-10,--~ BHP & MISC. 1R-9/' Blip & MIbC. 1R-12 ~ BHP & MISC. 2A-1/ "C' SAND PBU 2A-1'/ 'A' SAND BHP 2A-1~' 'C' SAND PBU 2A-13,- BliP & MISC. 2B-13-~ 'A' SAND BHP 2B-13-~ 'C' SAND PBU 2B-13-~ DATA FROM BHP 2]~-13-~ 'C' ~AND PbU 2C-8/ PBU 2G-16" PBU 2G-16/ PBU RLCEIPT ACKNOWLEDGED: BPAE B. CURRIER CHEVRON D & M & blISC. SURVEY REPORTS/PRESSURE 8-22-85 8-14-85 8-12-85 8-11-85 8-05-85 8-06-85 0-~-15-~5 08-03-~5 08-18-~5 08-17-85 08-10-85 08-06-85 08-09-85 08-15-~5 08-15-85 08-19-85 08-04-85 08-04-85 08-03-85 08-25-85 08-02-85 08-02-85 08-03-85 08-01-85 08-17-85 08-17-85 08-1~-85 DISTIiIBUTION: DIxILLING W. PASHER L. JOHN~3TON EXXON ['l~BIL P~ILLIP$ OIL NbK CLERK J. kAk'HI, IELL DATA *PLEASE NOTE--DISTRIB- SLATE Z. ,. ' ~"~':/~ ~' ~,I,.~,: .... ARCO Alaska, Inc. is a Subsidiary of AtlanticR~chfieldcompany ARCO Alaska, Inc. ~ ' Post Office E .~}0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 10, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: Well Action Date Performed 1Q-2 Fracture 9/1/85 1Q-3 Fracture 9/1/85 1R-5 Ac idi ze 8/23/85 1R-6 Acidi ze 8/24/85 1R-9 Fracture 8 / 27/85 1R-1 0 Fracture 8/26/85 1R-11 Fracture 8/26/85 1R-12 Fracture 8 / 27 / 85 2C-9 Perforate 8 / 26/85 2Z-1 Fracture 8 ! 19 / 85 2Z-2 Perforate 8/25 / 85 2Z-2 Fracture 9/2/85 2Z-3 Fracture 8 / 19 / 85 on the If you have any questions, please KuM. Drumm paruk Operations Coordinator TMD/kmc Attachment (Duplicate) call me at 263-4212. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~v~MISSION suNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 578~ FSL, 215' FEL, SEC. 18 T12N, R10E, UM OTHER [] 5. Elevation in feet (indicate KB, DF, etc.) 84' 12. 7. Permit No. 85-98 8. APl Number 50- 029-21 353 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1R-12 I 6. Lease Designation and Serial No. (RKB) ADL 25635, ALK 2568 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 [] Altering Casing Stimulate [] Abandon [] Stimulation ~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL (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). On August 27, 1985, the "A" sands of Kuparuk well 1R-12 were hydraulically fractured and propped to improve production. The treatment consisted of 213 BBLS of gelled diesel as pad and carrying fluid and 750 LBS of 100 mesh and 9,240 LBS of 20/40 sand as proppant. 45 BBLS of gelled diesel was used as a flush. Prior to pumping, equipment and lines were tested to 7000 psi. RECEIVED SEP 1 1985 Alaska OiJ & Gas Cons. Commissior Anchorage 14. I hereby certify that the foregoing is true and correct to the best of The space below for Commission use Conditions of Approval, if any: 9/~0/86 Date Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-08-85 TI{ANSHITTAL NO: 5285 KETURN TO: ARCO ALASKA, INC. KUPAt~UK OPERATIONS ENGINEEIcING t~E CO~J3~ CLEkK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 !'KANSMITTED HERE~4ITH ARE qECEIPT AND RETURN ONE S iN BOX 1 OF 2: JPEN H~OLE LIS TAPES PL 3C-11 06-23.-85 RUN 3C-10" 07-02-85 RUN 3C-9~' 07-10-85 RUN ~C-7" 07-31-85 RUN 3B-14 -- 03-20-85 RUN 3B-12-- 07-03-85 RUN 3B-11~' 06-26-85 RUN 3B-10 ~ U6-17-85 RUN 3 B- 9-"- 06-10-85 RUN 2Z-15" 06-19-85 RUN 2Z-14/ 06-28-85 RUN !Z-13~ 07-05-85 RUN 2Z-12~ 07-20-85 RUN IZ-11,~ 07-27-85 RUN THE FOLLOWING ITemS. IGNED ~ ACKNO~¢LEDGE COPY OF THIS TKANSMITT~L. US LIS%'INGS (ONE COPY OF EACH) #1 4427.5-8881.5 REF #70597 $1 1785.0-8987.5 ~EF #70620 #1 3920.0-8332.5 REF #70642 ~1 4617.5-8747.5 ~EF #70706 #2 3280.0-6~03.5 RI-:F #70229 ~1 4021.5-8261.5 REF #70641 #1 2190.5-9257.0 REF #70598 #1 3273.0-7270.5 REF #70555 #1 2092.0-8415.0 REF ~70634 ~1 2658.0-6620.0 REF '#70562 #1 3876.0-8334.0 REF #70600 #1 4180.0-8538.5 REF #70639 #1 4409.0-9412.5 REF #70661 #1 3531.5-7534.0 I{EF #70704 _N SOX 2 OF 2: .~PI~HOLE LIS TAPES PLUS LISTI 'W-16~/ 01-28-85 RUN #1 31 2V-14"/ 05-16-85 RUN #1 30 ~V-12~/ 04-22-85 RUN #1 39 U-10~ 04-11-85 RUN ~1 29 U-7~/ 03-'1-9-85 RUN #1 35 ~A-13/~ 07-16-85 RUN ~1 76 ~R-13'/ 07-27-85 kUN #1 ~R-12 ~ 07-20-85 RUN #1 .R-11'~-' 07-13-85 RUN #1 _R-10~''~ 07-06-~5 }<UN #1 .R-9''/ 06-28-85 RUN #1 t{-7// 06-04-~b RUN #l&3 NGS (ONE 16.0-7038. 47.0-7086. 60.0-9265. 72.0-7063. 94.b-8179. 49.5-8160. 3940.0-8578. 3935.0-8277. 3810.0-7213. 2991.0-8738. 3991.5-8131. 0045.5-7103. COPY OF EACH) REF ~ 70436---REVISED REF ~ 7U614---REVIS~.'D REF #70613---REVISED KEF # 70612---REVISED REF # 70505---~{EVISED --' # 70645 REF ~ ~70702 ELF #70660 REF #70643 REF # 70640 REF #70601 kEF ~ 70509 ECEIPT ACKNO~LEDGED: ?AR · CURRIER ~EVRON & M D~IbLING L. JOHNSTUN HOBIL NSK CLERK DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL J. RATHMELL DATE: ~l~--~. _ . n~__ $ ~-;~ .... Cons. Commission STAT~ OF ALASKA*- ~ SOHIO UNION K.TULIN/VAULT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: Oil an~ Cas Consen'atlo~ Commission 3uol ~orcuDipe Drive Anchor;~e, Alaska on~ RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY DESCRIPTION RECEIVED: DATED: Copy sent YES ,, to sender NO .... STATE OF ALASKA ALASKA oIL AND GAS CONSERVATION COr,,'*iSSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: State of Maska Alas~ 022 and Gas Conservation Commission 8001 Porcupine Drive .~2chorage, Alaska 99501 RE: Receipt of the following material which was transmitted via ,///.,? f,/ is hereby acknowledged: ~QUANT iTY DE S CRI PT ION ~ / RECEIVED: DATED: Copy sent to sender YES NO Y-- ARCO Alaska, Inc. ~-'-"- Post Office B, ~0360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 14, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton. Enclosed are the July monthly reports for the following wells' 2A-13 3C-10 2Z-11 WSP-20 11-11 2A-14 1R-10 2Z-12 9-31 12-3 (workover) 3B-12 1R-11 2Z-13 9-32 12-5 (workover) 3C-8 1R-12 2Z-WS#1 9-33 14-3 (workover) 3C-9 1R-13 WSP-9 (2) 11-10 14-5 (workover) L1-14 L2-20 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L120 Enclosures RECEIVED AUG 1 ]985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany .... STATE OF ALASKA ALASKA C._ AND GAS CONSERVATION CO,...~llsSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling welk~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P, 0. Box 100360, Anchorage, AK 14. Location of Well at surface 99510 7. Permit No. 85-98 578' FSL, 215' FEL, Sec.18, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 84' RKB 8. APl Number 50-- 029-21353 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1R-12 6. Lease Designation and Serial No. ADL 25635 ALK 2568 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of July ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1200 hfs, 7/15/85. Drld 12-1/4" ho]e to 3965'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 8260'. Ran logs. Continued drilling 8-1/2" hole to 8320'TD (7/20/85). Ran, cmtd, & tstd 7" csg. PBTD = 8211'. Secured well & RR ~ 1400 hfs, 07/21/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 115'. Cmtd w/230 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 3953'. Cmtd w/1160 sx PF "E" & 350 sx PF "C". 7", 26.0#/ft, K-55, BTC csg w/shoe ~ 8302'. Cmtd w/320 sx Class G & 250 sx PF "C". 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR/Cal f/8250' - 3953' FDC/CNL f/8250' - 7500' & 4100' - 3950' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report~n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. ...... TEMP/MR90 .q,,hmit in rlnnlie.~t~. C. Commissioner MEMORANOUM State of Alaska ALASKA OIL AND GAS CONSERYATION COMR~ISSION ~ --~.~~er~ DATE: July 23, 1985 TO: C.V. orJ. Chai~~v F~LENO: D.EWS.53 TELEPHONE NO: FROM: Edgar W. Sipple, Petroleum Inspector SUBJECT: BOPE Test Arco' s Kuparuk 1R-12 Permit No. 85-98, Kuparuk River Field Wednesday, July 17, 1985: I traveled this date from Alyeska Pump #1 (subject of another report) to Arco's Kuparuk 1R-12 Doyon Rig 9, to witness a BOPE test. The drilling contractor was in the Process of cementing the casing. The BOPE test commenced at 2:15 PM and was concluded at 3:15 PM. There were no failures. I filled out the AOGCC BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on Arco's Kuparuk ~R-12, Doyon Rig 9 . ' Attachment C~2-NRIA(Rmv 10/79~ o~0 ~5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Location: Sec /~ Drillin~ Contractor Date ~7_//~- Well / £~/~_ ~e~re.ent~t~v. Permit ~! ~-fF ~; Casing Set @, Representative Location, General ~ ~ Well Sign~k_ General Housekeeping ~ ~..Rig O ~ Reserve Pit 0/'~ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors Test Pressure BOPE Stack Ann~ r Preventer Pip e ~Rams 0/~ Blind-~'" Rams ~ ChoT Line Valves H.C.R. Valve Kill Line Valves check Valve ,.~ ooo ~000 3 600 ACCUMULATOR SYSTEM Full Charge Pressure ~ Pressure After Closure /7o0 psig Pump incr. clos. pres. 200 psig . Full ~rge Pressure Attained: N2 /~7 ~1o~~/~lg~ &~o~O psig Controls: Master_. ~//~ Remote ~ ~ Blinds switch coverX/~.Y · Kelly and Floor Safety Valves Upper Kelly ~ ~est Pressure Lower Kell~</Test Pressure Ball Type ~-'~ ~ Test Pressure Inside BOP ~'~0~ Test Pressure Choke Manifold No. Valves /~ No. flanges ~ psig ~ ~O m~F ~e~. min2-~ sec. · Test Results: Failures ~'--- Repair or Replacement of failed equipment to-be made within Commission office notified. , ~OOo Test Pressure ~..~000 Adjustable Chokes ~~ Hydrauically operated choke --t-- ~ Test Time / hrs. GO ~~; ~/~ days and Inspector/ Remarks: DistribUtion orig. - AO&GCC cc - Operator cc - Supervisor Inspector ARCO Alaska, Inc Post Office ,.,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 20, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 1R Pad Wel 1 s 1-16 _ Dear Elaine: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L115 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany f~" WELL I Y= 5,991,050.09 Let. = 70°23'ii.$70'' x = 539,829.76 Long.= 149o40'33.808" ~ SEC. 20 -- 154'FNL, 139'FWL N 0 R T H I. WELL 2 Y= 5,990,990.16 L~I. = 70°23'10.781" I x = 539,829.82 Long. = 149°40'$3.816" I ~ SEC. 20-- 214'FNL, 138'FWL i WELL 3 Y= 5,990,930.24 Let. = 70°23'10.192'' I i ! x = 539,829.78 Long. = 149°40'33.826'' [ I SEC. 20 -- 274'FNL, 13e'FWL ~ i,~..~ i WELL 4 ~:5,990,870.26 Let. : 70023'09.602" o~ ~--12 x: ~'~.'~ ~ [ ] ~4"~1~',.~/ SEC. 20-- 334' FNL, 137' FWL I ,o ~, WELL 5 Y= 5,990,070.21 Lot. = 70025'09.620" i 9, ' ~6-~: x= 539,469.75 Long.= 149°40'44.377' I SEC. 19-- 332'FNL,223'FEL i WELL 6 ~= 5,990,930. z~ Lot. = 70°23'~0.Z~0'' ~i ~ X= 539,469.74 Long. = 149°40'44.$68'' I I L r ; SEC. 19 -- 272' FNL, 222'FEL i WELL 7 ¥: 5,990,990.23 Lot..: 70°23'10.800'' i X = 539,469.76 Long. = 149°40'44.358" SEC. 19 -- 212' FNL~ 222'FEL '.-- WELL8 Y= 5,991,050.20 Lot. = 70°23'11.390" ~S~O X = 539,469.73 Long. = 149°40'44.350 ,, .~, SEC. 19 -- 152' FNL, 221' FEL ~.~. 8 ,~ WELL 9 ~= 5,991,600.16 Lot. = 70°23'16.e00'' 7 ~ i 2-~,~, x= 559,469.91 Long.= 149°40'44.259'' WELL I0 y= 5,991,660.11 Lot. = 70°23'17.389 X = 539,469.82 Long. = 149o40'44.253" i SEC. 18 -- 458' FSL, 216'FEL .___...--~ , WELL Ii Y= 5,991,720.17 Let. = 70°23'17.980" , i X = 539,469.81 Long.= 149040'44.244" j ] ~~; SEC. 18 -- 518' FSL, 215'FEL : WELL 12 ~= 5,991,780.16 Lat. = 70°25°18.570" - X = 539,469.78 Long. = 149°40'44.235" SEC. 18 -- 578' FSL, 215'FEL DRILL SITE R ,"= 300' WELL 13 ~= 5,991,780.16 Lot. = 70°23'18.551" , X = 539,829.75 Long. = 149°40'33.695" AS-BUILT CONDUCTOR LOCATIONS s~c.~7 -- 576'FSL, 145'FWL ~ITi'IIN SECTIONS 17,18,19 ~ 20, TI2N,RIOE, LI.M. WELL 14 ~= 5,991,720.13 Let. = 70°23'17.961" X= 539,829.71 Long.= 149o40'$3.705". NOTE: SEC.17 -- 516' FSL, 145'FWL COORDINATES ARE ALASKA STATE PLANE, ZONE 4. WELL 15 Y = 5,991,660.19 Lot. = 70023'17.371" SECTION LiNE DISTANCES ARE TRUE. X= 539,829.71 Long.= 149°40'33.715'' HORIZONTAL 6 VERTICAL POSITIONS PER L.H.D. SURVEYORS, SEC. 17 -- 456'FSL, 144'FWL DOCUMENT N0.129:NI9+69 NI7+25 ~ELL 16 ~=5,99~,600.20 Lot. = 70°23'16.781'' E 9+56 8 E 15+25 X = 539,829.77 Long.= 149°40'$3.722'' EL.50.39 EL.38.75 SEC. 17-- 396'FSL, 144'FWL CERTIFICATE OF SURVEYOR: I HEREBY CERTIFY THAT I AM PROPERLY . still '~_..~ SURVEYED FOR: AI~UU AIOSKQ] IBC I~il ~ ? o~-~ MAY9,19851 :"- ~--~- F ROSERT SELL ~,~ JUil -:. o.~w. aoAvls I~.~,~o.: ALASKA OILFIELD ':~ ' : :-'V,~'.._ '.o. 3~=~ ..'~"~, == 8SSDI], A.O.S. o,-851 CHECKED d HERMAN ,-.,. ' ' "., · $$10NAt. · ' ' ilUOa .o. 85029 ! ' May 17, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 A~nchorage, Alaska 99510-0360 Re: Kuparuk River Unit 1R-12 ARCO Alaska, Inc. Permit No. 85-98 Sur. Loc. 578'FSL, 2!5'FEL, Sec. 18, T12N, R10E, UM. Btmhole Loc. 1238'F~]L, i523'FEL, Sec. 18, T!2N, R10E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their-drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited bv AS 46, Chapter 3, Article 7 and the regulations promulgated'thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal ~Tater Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. K~win Kuparuk River Unit IR-12 -2- May 17, 1985 To aid us in scheduling field work, please notJofy this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I~rhere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF ?~!~E COM2~ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. ~ Post Office, · 100360- Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 9, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1R-12 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 1R-12, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment We estimate spudding this well on June 17, 1985. If you have any questions, please call me at 263-4970. Sincerely, Area Drilling Engineer JBK/HRE/tw PD/L86 Attachments RECEIVED MAY 1 0 1985 AlasKa Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany " ?-~' STATE OF ALASKA ~ ALASKA t,,L AND GAS CONSERVATION CO,v;MlSSlON PERMIT TO DRILL 20 AAC 25.005 ~ SERV,CE [~} %~TRAT' G RAI~"~ 1 a. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~[X DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 9. Unit or lease name Kuparuk River Unit 4. Location of well at surface 578' FSL, 215' FEL, Sec.18, T12N, R10E, UN At top of proposed producing interval 1629' FNL, 1375' FEL, Sec.18, T12N, R10E, UM At total depth 1238' FNL, 1523' FEL, Sec.18, T12N, R10E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 84', PAD 47' ADL 25635 ALK 2568 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 1238' ~ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8247' MD, 6747' TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2414 feet. MAXIMUM HOLE ANGLE 46 oI (see 20 AAC 25.035 (c) (2) 10. Well number 1R-12 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 t15. Distance to nearest drilling or completed R-11 well 607 @ surface feet 18. Approximate spud date 06/17/85 2824 psig@ 80°F Surface 3242 psig@ Gc~O0 ft. TD (TVD) 21 SIZE Hole Casing [24" 16" ~12-1/4" 9-5/8" 8-1/2" 7" Weight 62.5# 36.0# 26.0# Proposed Casing, Liner and Cementing Program CASING AND LINER Grade Coupling H-40 Wel J-55 BTC HF-ERW J-55 BTC SETTING DEPTH Length M D 80' 35' I 35' I 3930' 35' 35' 8213' 34' I I TOP TVD I I 34' MD BOTTOM TVD 115' II 115' 3965' 13800' I 8247' I 6747' I I QUANTITY OF CEMENT (include stage data) ± 200 cf Poleset 1160 sx Permafrost "E" 350 sx Permafrost "C" 270 sx Class G neat HF-ERW 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8247'MD (6747'TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 3965'MD (3800'TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (3000 psi for annular). Expected maximum surface pressure is 2824 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed, using the workover rig, with 2-7/8", 6/5#, J-55, EUE 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby c.ertify that the foregoing is true and correct to the best of my knowledge The spac~ belo~ for Co~mission use - - V- ~ CONDITIONS OF APPROVAL Samples required I Directional Survey required I APl number []YES ~.~0 L ~--Y--ES [-]NO 1 Permit number -- APPROVED BY. ~~~~(~ Form 10-401 (HRE) PD/PD86 Mud log required DYES SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission May 17, 1985 , Submit in triplicate PERMIT TO DRILL 1R-12 instal]ed and tested upon completion of the job. 1R-12 will be the eighth well drilled on the pad. It is +60' away from 1R-11 ~ surface. There are no other close we]lbores anywhere downhole. Top of cement for the production string will be placed at 6600'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process~', After the completion rig has moved off location, the well wiT1 be fracture stimulated. RECEIVED Alask~ Oil & Gas Cons, Con~rnissior, Anchorage HOR I Z 0 I"~'~AL SCALE 1 IN. PROJECTION = 1000 FEET KI, IPARt~ FIELD. NORTH SLOPE, ALASKA EASTBAN I~,IIpSTocK. laC. 4000 . 1000 _ .m 1000 _ WEST-EAST 3000 2000 '1000 0 1000 I I I I m 31/'o 14IT IIIIF N 20 3388' TD TARGET LOCAT1011,, 153~s FilL, . . . sL,'c. _t!~.. t~_~p, .m · AC~ LOC~TT~II~. 571' FIL. KC. II, Tlgll, DEG 4t I'1[N V RECEIVED (: T O T ARGE T) iVlAY .t 0 !98§ Alaska Oit & Gas Cons. Commissiori Anchorage AR~O ALASKA, INC. PAD IR. gELL NO~ 12 PROPOSED KUPARUK FIELD, NORTH SLOPE. ALASKA EASTtIAil ~NIPSTOCK. INC. 0 Sl,~rACE BA~E PERI'tAFRO,~T TYD-1634 . ~ KOP TVD-241· TH0-2414 DEP-O 3 9 TOP UGNU ~ TYD-2684 TI'ID-26S$ DEP-19 3000 , ~ tm ~. 6000 _ 21 ag, TOP la S-Jg ~ TVD-33~6 TND-3403 DEP-2$O ~ K-12 TVlI~3~W4 TND-:3~:)3 DEP-4S3 +s EOC (CSG PT} TVD-3~)O TI'ID-39~$ DEP,-$96 AVERAGE 46 DEG 30 I"'I]:N K-$ TVD-$634 TND-6630 DEP-2529 %,, TM~ET CNTR TVD'644.9 TI'ID'?81.4., DEP'33Bl "~ TOP LOYR SleDS TVD 6495 TND 7'~B! DEP"343~ '~ BASE ICUP SleDS TVD'6609 TIID'B04? DEP'3S$? 7000 I ! I 0 1000 2000 3000 VERTICAL SECTION TD (LOG PT) TVD-ET4? TIII)-6247 DEP-3?02 I 4000 Alaska Oil & Gas ConS. comm~ss~or~ JO ~0 ~0 3O 3O O0 O0 900 800 ZOo 600 SO0 OR,T H ~o, ........................ , 300 ~To 33?8 ,.3223 ARCO ALASKA, INC. : PAD IR. g~l.L NOt 9-10-11-12' PROPOSED KUPM~UK FIELD. NORTH SLOPE. ALASKA 3141 EASTI'Mff Id'IIPSTOCK. INC- NOTEI I,iELL PATHS: EXTNED BE OND tHiS. ~ ZE. ZNO viNP 'i..ii .., ........... . 2'00 100 LJ.J o · S.urface Diverter System ].. [6" - 2000 psi Tankco starting head. Z. Tankco quick connect assy. 3. 16" x ZO" 2000 psi double studded adapter. 4. 20' 2000 psi drilling, spool w/lO" side outlets. · 5. 10" ball valves, hydraulically actuated, w/lO' lines to reserve pit. Valves to open automal~ically upon closure of annular preventer. 6. ZO' 2000 psi annular'preventer. · 7. ZO' bell nipple. · h . Maintenance & O~eratton Upon initial inslallation close annular preventer and verify that ball valves have opened properly. Close annular preventer and blow air through diverter lines 'every 12 hours. Close-'annular preventer in the event, that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to u~wind dtverter line. Oo not. shut in well under any circu.mstances.. ' · 16" Conductor RECEIVED MAY 0 Alask~ OJl &. Gas Corl$. OommJssion Anchorage. 7 6 5 2 Anchore4e BI A61~ #1 PSI RS~RA BOP STACK A(~ATOR CAPACITY TEST I. Q-ECX ~ FILL ACO, MJ_ATOR R~rOIR TO PRCI~R LEVEL WITH HYDRAL&_IC FLUID, 2. ASSUR~ THAT ACO, M.LATCI~ ~'.I'S 3000 I~ ~Z ~~ ~ T~ ~~T~. 3. ~~ TI~ T~ ~ ~ ~TS 4. ~~ ~ ~ ~T, T~ A~~ L~ LI~T I$ 45 ~E(::;13q~ C~:ISI~ TIM~ A~D 1200 I:~I RIS,4AIN:IN~ · 13-5/8" ~ STACK T[ST I. FILL ~ 5'TAQ( N~) ~ MN~FCLD W];TH DIESEl_ 2. O-ECX THAT ALL LCZ:K EOw~ SI:::RE~ 1N IAELLI-E_N:) ARE FULLY I~'TEACTEI:X SEAT TEST PLUG IN W~TH I:a.N~I~ JT Aha:) ~ IN L~ 3. CLOSE ~ PI~'VENTI~ N~D ~ KILL N~D O-EKE LIhE VALVES ADJ~ TO BCP STN:X. ALL OTI-ER 4. I4:ESSLRE L~ TO 250 PSI AhD HOLD FOR lO MIN. IN-- (::REA~ PRES~___m:~ TO 3000 PSI AhD i-ELD FOR ~0 ~N. Bt. EED~ TOOPSI. LlhE VALVES. CLOSE TCP PIPE RAIVB AhD MCR VALVl~ Chi KILL AhD O.K:XE LIhES, NOT A FLLL CLO':3Ih,G I:~]TIV~ SEAL O'K:~.Toqj. Y 8. (:PEN TCI:> PIPE R~ AhO CL_?~__ BO'~OM PIPE CLOSI"' ~..IhD ~ AhD TEST TO 250 PSI AhD PSI. I~,t,~F'~].D AhD LIhF-S ~ FLL.L CF hCN-FR~R'TIh~ FI~UID. SEg' ALL VALVl~ IN D~ILLIN~ POSITIC~. I~. TEST E'r~IPE VALV~ K'F'~Iy, ~..LLY COCX~ ~ILL PIPE SAFETY VALVE, AhD IhBIDE EN:P TO 250 PSI AhD 3000 PSI. 13. RECO~ TEET IhFC321~TIC~I ON BLOK:Z,rT PREVENTER TEST FORM, SION, AND ~ TO I~ILLING SLI~RVISOR. ~[K].Y TI-E3~~ F~ICNALLY OPERAT[ BOP[ I~RILY. 510O84OO I ~v I CHECK LIST FOR NEW WELL PERMITS Company IT EM APPROVE DATE (1) Fee ...... (2) Lo.c' i, (2 thru 8) (8), '~ ' (~' thru 1'~)i 10. · '~ .~J. _~ ,,?,;,,,~' ,,, .:.,~5. 11. .,~i~/~,' ,~' ,.,., ~ ..r ~, _- (10 and 12)' 12. (13 thru/21) (5) BOPE ..... ~; ,::~,. , (22 thru' 26) (6) Add: 13. 14. 15. 16. 17. 18. 19. 20. 21. YES NO REMARKS 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ................... 3 Is well located proper distance from property line · · · 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in_ this pool 6. Is well to be deviated and is wellbore plat included ' .... 7. Is operator the only affected party ......... ' ...... '.'. 8. Can permit be approved before ten-day wait .......................... 22. 23. 24. 25. 26. 27. Does operator have a bond in force .................................. (d~,,,t. ..... , Is a conservation order needed ...................................... Is administrative approval needed .................................... Is the lease number appropriate ..................................... ~,, Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will cement cover all known productive, horizons ..................... Will surface casing protect fresh water zones ......................... Will all casing give adequate safety in collapse, tension and burst.. ?~7~77 Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... ':,'~' Are necessary diagrams of diverter and BOP equipment attached ........ q:i:~T~ Does BOPE have sufficient pressure rating - Test to 7~3~'77~ psig .. ~:i; Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. 0 GeologMj. Engineering: Lcs JAL~ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~VP 010,HO} VEPIFICATIRH I,,TSTING PA~E 1 )A?E I~5/07/24 1R~G{N l ~E~b NRM~ l ~ONT~NUA~ON # 101 ~R~V'~OU$ R~EL I TAPE HEADFR ~ERVICE NAME :FD~T 3ATE R5/OT/g4 3RIGI~ ~OMT~NtlATION # PR~V{O{I$ TAP~ rlt, g N,AM~ {~DTT ,OOl MAXIMUP LENGTH : 1024 FXLE TYP~ l PREVIOI}8 r~b~ : UN{T ?YPE ~A?E 8,X~E ~ODE VERIFICATION I~ISTING PAGE 2 "I~LD : IqlTP &RI, IK .'.OUNTY : NORTH StOPE ~I3RnUGH 7OR NU~B.F..R AT ~CC: 70660 ~UN #ONE, hATE LOGC, ED: 20-JUL-~5 ~DP: = ~ = 5" TO 8263,0' ~ASING 9 69,5" 36.00' - nit SIZE 8, tYPE F[,UTD = L~ND - X~. POLY )EN$TTY = I0,4 LB/G ~M = ~ 690 N 73,0 DF ;I~COSITY = 4],0 S ~F ~ 4:490 ~ 7~,0 DF ~H = q,O R~C : 2,920 ~ 7~ 0 DF ~bUID LOSS = 5,6 C3 RM AT ~HT = 2,021 ~ 13~,0 D~ ~* THIS D~T~ HAS NOT BEFN DFPTfl SHIFTED - OVERI.,~YS FIELD PRINTS ~~ ~C~LUM~E~GER [,~IGS TNC~!,ID~D N~TH TH~S M~,C;NETIC TAPE: ,VP O10.WO~ VEPIFiCATInN LI$?ING PAGE 3 * DUAL INDUCTIDN 8PHERIC~b£,Y FncusED * FOPM~TION ~EMSTTY COMPENSATED . COMPeNSaTED NEUTRON LO~ (FmN~ , , · , * , , · · , , , , ~ , ~ * DATA FORMAT RECORD ~N?RY TYPE SIZE ~EPR CODE ENTRY 2 1 66 0 4 ! 6~ 1 8 4 ?~ 6O 9 4 65 16 1 66 1 0 1 66 0 ID O~O~R # bOG TYPE Cb~$$ ~OD NO. ~FLO ~Ib £L~ *R rDN ~HOB FD~ 3RHO rOW ~RAT ~PH! rDN FT O0 000 O0 0 0 OH~ O0 220 01 0 0 ~HM~ O0 120 46 0 0 OHM~i O0 120 44 0 0 ~V O0 010 01 0 0 GAPI O0 3 0 0 0 0 GAPI O0 310 Ol 0 0 ~N O0 ~80 0~ 0 0 G/C3 O0 ~ 50 OZ 0 0 ~/C3 O0 356 01 0 0 O0 42O 01 0 0 O0 000 O0 0 0 PU O0 ~gO O0 0 0 CPS O0 330 31 0 0 ~P8 O0 330 30 0 0 BEPT ~PHI 8277,500 32768.0000 DR~O 35,.3516 ~CNL 3,0254 16417,500 0000 AT ?68 R 4~o oooo 0000 SFt, U 2,7930 ~b~ 9~.4375 OR SiZE SPb REPR PROCESS , ~, ooooooo oooo , ~0 oooooooooooooo ~ ~ oooooooooooooo ~ ~ oooooooooooooo ~ ~ oooooooooooooo ~ ~ oooooooooooooo ~ ~o oooooooooooooo ~ ~ oooooooooooooo ~ ~ oooooooooooooo ~ ~ oooooooooooooo ~ ~ oooooooooooooo ~ ~o oooooooooooooo ~ ~ oooooooooooooo ~ ~ oooooooo,o~oooo ~ ~ oooooooooooooo 664,1 lbl~ .4375 CALl 5VP Oln. HO? VEnIFICA~ION hISSING PAGE: 4 ~HOB )EPT ~P ~HOB ~PHI SP qPH! )EPT ~EPT ~P ~PHI SP RHOB DEPT SP ~P~I NPHI OEPT RHOB NDHI DEPT SP ~HOB NPHI 8!00. 33. 8~00 2, 31, 7000 0* 7~00, , 7~00, ?400. -999. 999, =999. 7~00. ]b9! !9~4 NCNb 0000 4063 4102 4492 NCNb OOO0 ~FLU 5625 2324 DRHO 5430 NCNb 000O SFLU ~875 3730 76]7 NCNb 0000 SFI, U 6602 NCNb 4375 ORHO 6953 NCNb 0000 8FLU 6875 29]0 ~RHO 7031 NCNb 0000 ~906 ~R 37'~0 OE~O 3828 NCNb 0000 8FLU 6250 OR ~500 ~R,O 2500 ~CNb ~500 DRHO ~500 NCNG '~0075 ~R~FI'U ~500 DRHO ~500 0000 SFt,U 0 0239 1020[00o0 5.7734 80.4375 0.0195 2396.0000 45.5313 46.6250 0.0215 2598.0000 7 1250 2330~ 0386 O000 5.0352 3.$1~5 80.0117 2840.0000 2.:2246 12~,0000 .0220 2118.0000 1,5938 114,3125 0,~142 1687, 000 ~,1.348 . 0~9 l~Tt,O000 3 4609 -990 500 -099 ~500 4,~477 '999, 0 '999,~500 1.46: 0 "~99 '2500 999' - .2500 ~IR~T rCNL ~R NRAT FCNL ~R NR~T FCNb MR~T rCNb NR~T rCNb ~R NRAT rCNb ~R ~RR.T ~R NR~T rCNb NEAT rCNb 3.7930 538.5000 ~.2305 89.4375 3.0879 799.0000 27.8125 46.6290 2.8477 Ol3,O000 6.3516 74,1250 2.9805 815. 5000 3.4727 83.8125 2,5742 1155.0000 ~ 664 ! ~~0000 121] 2969 662 0000 4. 1 ,5 '113,69 2 484.2500 3 9 121.! 530,0000 -9~J,~" 5'00 -999:,2500 3.75293 288. 500 -999 ,2500 46, 0 ~39.. 0 , 50 :999. 500 2.5234 CAb! ~NRA CALI RNRA CAt, I RNRA CAL! RNRA CALl IbM CALl EN~A LM RNRR CAb! 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