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Home My WebLink About185-237MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 15, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3A-10 KUPARUK RIV UNIT 3A-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2025 3A-10 50-029-21457-00-00 185-237-0 W SPT 5908 1852370 1500 2790 2790 2790 2790 200 360 360 360 4YRTST P Austin McLeod 8/4/2025 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3A-10 Inspection Date: Tubing OA Packer Depth 510 1990 1950 1935IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250804190400 BBL Pumped:1.2 BBL Returned:1 Monday, September 15, 2025 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 999 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.09.15 12:28:40 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3A-10 (PTD 185-237) Update and plan forward Date:Tuesday, May 16, 2023 1:44:02 PM Attachments:AnnComm Surveillance TIO for 3A-10.pdf RE EXTERNAL RE 2D-02 (AIO 2B.052 PTD 184-152) and 2E-10 (PTD 184-230) update 07-02-17.msg MIT KRU 3A-10 03-01-23.xlsx From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Tuesday, May 16, 2023 1:37 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3A-10 (PTD 185-237) Update and plan forward Chris KRU 3A-10 (PTD 185-237) was previously troubled by slow TxIA communication while on seawater injection and had been shut in since 6/28/2018. On 12/13/22 a plan was communicated to the AOGCC which would determine if this was a temperature sensitive issue by bringing the well online, on produced water injection for a 90 day monitor period. The monitor period is nearing completion and the well has appeared normal with no observed communication while on produced water injection. Additionally the well passed a SW MITIA after stabilization. There was some slight IA pressure increase, but it appeared to follow normal thermal and tubing pressure increase. As the well appears to be normal with no integrity issues while on produced water injection the plan is to establish internal controls to limit the well to produced water injection only. The same approach was used on 2E-10 (PTD 184-230) back in 2017. I’ve attached the TIO trend, MIT form, and 2E-10 email for reference. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 265-6471 Cell phone: (808) 345-6886 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1852370 Type Inj W Tubing 2075 2075 2075 2075 Type Test P Packer TVD 5908 BBL Pump 2.0 IA 720 2900 2840 2830 Interval 4 Test psi 1500 BBL Return 2.0 OA 640 860 860 860 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: 3A-10 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 3A Pad Austin McLeod Hembree / Hills 03/01/23 Form 10-426 (Revised 01/2017)MIT KRU 3A-10 03-01-23 3A-10 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 3A-10 2023-02-18 400.0 160 -240.0 OA 3A-10 2023-02-19 850.0 640 -210.0 IA 3A-10 2023-03-21 900.0 500 -400.0 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,667.0 3A-10 11/10/2010 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set DV & Pulled Catcher/Plug 3A-10 12/11/2022 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 6/28/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 31.0 107.0 107.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 30.7 3,212.5 3,142.7 36.00 J-55 BTC PRODUCTION 7 6.28 30.0 6,980.9 6,380.2 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.0 Set Depth … 6,523.6 Set Depth … 5,972.1 String Ma… 2 7/8 Tubing Description TUBING Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE 8RD ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 24.0 24.0 0.01 HANGER 6.000 FMC GEN III HANGER W/ 3 1/2 PUP FMC GEN III 3.500 1,821.4 1,821.4 0.75 SAFETY VLV 3.000 BAKER FVL NON-EQUALIZING SSSV BAKER FVL 2.313 2,249.0 2,248.9 3.19 GAS LIFT 4.750 MERLA TMPD 2.375 4,065.7 3,846.6 33.27 GAS LIFT 4.750 MERLA TMPD 2.375 5,315.6 4,915.2 29.07 GAS LIFT 4.750 MERLA TMPD 2.375 6,040.4 5,547.0 29.30 GAS LIFT 4.750 MERLA TMPD 2.375 6,391.0 5,854.4 28.08 GAS LIFT 5.460 MERLA TGPD 2.375 6,431.5 5,890.2 27.69 PBR 4.750 BROWN PBR TYPE-CB W/ PUP BROWN CB 2.312 6,452.1 5,908.4 27.46 PACKER 6.140 BROWN HB PACKER BROWN HB 2.313 6,490.3 5,942.5 27.01 NIPPLE 3.668 CAMCO D NIPPLE NO GO CAMCO D 2.250 6,522.7 5,971.3 26.90 SOS 3.750 BROWN SHEAR-OUT-SUB BROWN 2.441 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,249.0 2,248.9 3.19 1 GAS LIFT DMY BK 1 0.0 1/7/1986 0.000 4,065.7 3,846.6 33.27 2 GAS LIFT DMY BK 1 0.0 1/7/1986 0.000 5,315.6 4,915.2 29.07 3 GAS LIFT DMY BK 1 0.0 1/7/1986 0.000 6,040.4 5,547.0 29.30 4 GAS LIFT DMY BK 1 0.0 1/7/1986 0.000 6,391.0 5,854.4 28.08 5 GAS LIFT DMY RK 1 1/2 0.0 12/11/2022 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,598.0 6,600.0 6,038.5 6,040.3 A-4, 3A-10 11/26/1993 12.0 RPERF 2 1/8" Dyna Jet; 189 deg. phase 6,600.0 6,620.0 6,040.3 6,058.1 A-3, 3A-10 11/26/1993 20.0 RPERF 2 1/8" Dyna Jet; 60 deg. phasing 6,628.0 6,658.0 6,065.2 6,092.0 A-2, 3A-10 11/26/1993 8.0 RPERF 2 1/8" Enerjet; 180 deg. ph 3A-10, 12/11/2022 5:21:30 PM Vertical schematic (actual) PRODUCTION; 30.0-6,980.9 RPERF; 6,628.0-6,658.0 RPERF; 6,600.0-6,620.0 RPERF; 6,598.0-6,600.0 SOS; 6,522.7 NIPPLE; 6,490.3 PACKER; 6,452.0 PBR; 6,431.5 GAS LIFT; 6,391.0 GAS LIFT; 6,040.4 GAS LIFT; 5,315.6 GAS LIFT; 4,065.7 SURFACE; 30.7-3,212.5 GAS LIFT; 2,249.0 SAFETY VLV; 1,821.4 CONDUCTOR; 31.0-107.0 HANGER; 24.0 KUP INJ KB-Grd (ft) 35.71 RR Date 11/10/198 5 Other Elev… 3A-10 ... TD Act Btm (ftKB) 7,000.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292145700 Wellbore Status INJ Max Angle & MD Incl (°) 34.81 MD (ftKB) 3,600.00 WELLNAME WELLBORE3A-10 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP From:Well Integrity Specialist CPF1 & CPF3 To:Wallace, Chris D (OGC) Subject:RE: [EXTERNAL] RE: 2D-02 (AIO 2B.052, PTD 184-152) and 2E-10 (PTD 184-230) update 07-02-17 Attachments:image001.png Chris, That sounds like a fantastic idea! We will operate 2E-10 under an internal waiver only which will limit the well to only produced water injection. To make it official, CPAI would like to rescind the Administrative Approval application that Brent submitted on July 2. With this in mind, I plan to also send in AA cancellation requests for the two 2D wells (2D-02 and 2D- 04) which are already waivered for TxIA communication, but which appear to demonstrate the same temperature-dependent leak type as 2E-10. They were initially AA’ed without understanding fully the underlying failure mechanism. Going forward, these wells will also be operated under an internal waiver to limit them to produced water only injection. Let me know if you see a problem with this. Kelly Lyons / Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Monday, July 10, 2017 3:34 PM To: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Subject: RE: [EXTERNAL] RE: 2D-02 (AIO 2B.052, PTD 184-152) and 2E-10 (PTD 184-230) update 07- 02-17 Brent, Kelly, Looking this over I am struck with the thought that AOGCC shouldn’t get that restrictive for a water well with temperature sensitivity. I mean, we do not have a way of recording a pressure test with seawater vs. differentiate from a produced water test. What about CPAI doing an internal requirement to restrict to produced water and then you could continue (without additional AOGCC restriction and without the 2 yr MIT)? If the packer leaks on produced water you would see the pressures and CPAI would need to act at that point. Maybe that is the better approach here. Regards, Chris From: NSK Well Integrity Supv CPF1 and 2 [mailto:n1617@conocophillips.com] Sent: Thursday, July 6, 2017 7:30 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] RE: 2D-02 (AIO 2B.052, PTD 184-152) and 2E-10 (PTD 184-230) update 07- 02-17 Sorry, I just noticed I had the wrong well in the body of the form. -Kelly From: NSK Well Integrity Supv CPF1 and 2 Sent: Thursday, July 06, 2017 3:16 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] RE: 2D-02 (AIO 2B.052, PTD 184-152) and 2E-10 (PTD 184-230) update 07- 02-17 Here you go. Thanks Kelly Lyons / Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Thursday, July 06, 2017 9:45 AM To: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: [EXTERNAL] RE: 2D-02 (AIO 2B.052, PTD 184-152) and 2E-10 (PTD 184-230) update 07-02- 17 Brent/Kelly, The application for 2E-10 references a May 30, 2017 MITIA but doesn’t include a 10-426 MIT form. AOGCC has no electronic record and so this is not in our database. Please send the excel 10-426 to the distribution list so we can import this one in and process the application. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: NSK Well Integrity Supv CPF1 and 2 [mailto:n1617@conocophillips.com] Sent: Sunday, July 2, 2017 6:28 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Subject: RE: 2D-02 (AIO 2B.052, PTD 184-152) and 2E-10 (PTD 184-230) update 07-02-17 Chris, The 30 day injection test on produced water for 2D-02 and 2E-10 has ended. 2D-02 did not display any signs of TxIA communication while on produced water. There were a couple of IA pressure rises but one can be attributed to a thermal response and the other was due to an increase in rate and wellhead pressure. This well will remain online and continue to follow the provisions under AIO 2B.052 at this time. Attached for reference is a 1 month TIO plot to cover the test period. 2E-10 did not display signs of TxIA communication while on produced water injection as well. The plan is to apply for an AA for produced water injection only allowed. I have attached a copy of the AA application for reference and the paper copy is in the mail. The well will remain on injection while the AA is being processed. Please let me know if you disagree with these plans. Brent Rogers / Kelly Lyons NSK Well Integrity Supervisor CPF 1 & 2 ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 394-0402 From: NSK Well Integrity Supv CPF1 and 2 Sent: Saturday, March 18, 2017 9:26 PM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: 2D-02 (AIO 2B.052, PTD 184-152), 2D-04 (AIO 2B.037, PTD 184-151) and 2E-10 (PTD 184- 230) update 3-18-17 Chris, 2D-02 (AIO 2B.052, PTD 184-152), 2D-04 (AIO 2B.037, PTD 184-151) and 2E-10 (PTD 184-230) were all identified with TxIA communication earlier this winter after their pads were swapped to colder seawater injection for the first time in years. (Please see the attached latest email communication regarding each well.) We believe that the wells only display communication when on cold fluid injection due to shrinkage of the metal, causing the tubing to pull out of the PBR. Two of the wells (2D-04 and 2E-10) had this theory corroborated when LDL’s were run while on seawater and discovered that the PBR’s were in fact the leak sources. 2D-04’s acoustic LDL was run on 02/07/17 and 2E-10’s acoustic LDL was run on 02/15/17. 2D and 2E pads will be swapped back to the warmer produced water injection (PWI) later this spring, currently anticipated to occur mid-April. To confirm that the leaks are indeed only present when on cold water, when the pads resume PWI, CPAI intends to return the 3 wells to produced water injection and be put on a 30 day diagnostic monitor. 2D-02 and 2D-04 are already AA’ed for TxIA communication and they will resume management under their respective AA’s. 2E-10 however is currently classified as a normal well and governed under Kuparuk’s AIO. Once we establish 2E-10’s reaction on warm produced water injection, we will make a determination of whether or not we will be applying for an Administrative Approval. A follow-up email will be provided at the conclusion of the monitor period. Please let us know if you disagree with the plan forward. Kelly Lyons / Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 5, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3A-10 KUPARUK RIV UNIT 3A-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/05/2023 3A-10 50-029-21457-00-00 185-237-0 W SPT 5908 1852370 1500 2075 2075 2075 2075 640 860 860 860 4YRTST P Austin McLeod 3/1/2023 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3A-10 Inspection Date: Tubing OA Packer Depth 720 2900 2840 2830IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230302112715 BBL Pumped:2 BBL Returned:2 Wednesday, April 5, 2023 Page 1 of 1         Well shut in since June 2018; last MIT 8/9/2013 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1852370 Type Inj N Tubing 1250 1250 1250 1250 Type Test P Packer TVD 5908 BBL Pump 0.5 IA 1175 2500 2475 2475 Interval O Test psi 1500 BBL Return 0.4 OA 20 40 40 40 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Diagnostic MITIA Notes: 3A-10 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 3A Pad Gomez 12/10/22 Form 10-426 (Revised 01/2017)MIT KRU 3A-10 diagnostic MITIA 12-10-22 (002).xlsx 3A-10 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,667.0 3A-10 11/10/2010 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set DV & Pulled Catcher/Plug 3A-10 12/11/2022 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 6/28/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 31.0 107.0 107.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 30.7 3,212.5 3,142.7 36.00 J-55 BTC PRODUCTION 7 6.28 30.0 6,980.9 6,380.2 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 24.0 Set Depth … 6,523.6 Set Depth … 5,972.1 String Ma… 2 7/8 Tubing Description TUBING Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE 8RD ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 24.0 24.0 0.01 HANGER 6.000 FMC GEN III HANGER W/ 3 1/2 PUP FMC GEN III 3.500 1,821.4 1,821.4 0.75 SAFETY VLV 3.000 BAKER FVL NON-EQUALIZING SSSV BAKER FVL 2.313 2,249.0 2,248.9 3.19 GAS LIFT 4.750 MERLA TMPD 2.375 4,065.7 3,846.6 33.27 GAS LIFT 4.750 MERLA TMPD 2.375 5,315.6 4,915.2 29.07 GAS LIFT 4.750 MERLA TMPD 2.375 6,040.4 5,547.0 29.30 GAS LIFT 4.750 MERLA TMPD 2.375 6,391.0 5,854.4 28.08 GAS LIFT 5.460 MERLA TGPD 2.375 6,431.5 5,890.2 27.69 PBR 4.750 BROWN PBR TYPE-CB W/ PUP BROWN CB 2.312 6,452.1 5,908.4 27.46 PACKER 6.140 BROWN HB PACKER BROWN HB 2.313 6,490.3 5,942.5 27.01 NIPPLE 3.668 CAMCO D NIPPLE NO GO CAMCO D 2.250 6,522.7 5,971.3 26.90 SOS 3.750 BROWN SHEAR-OUT-SUB BROWN 2.441 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,249.0 2,248.9 3.19 1 GAS LIFT DMY BK 1 0.0 1/7/1986 0.000 4,065.7 3,846.6 33.27 2 GAS LIFT DMY BK 1 0.0 1/7/1986 0.000 5,315.6 4,915.2 29.07 3 GAS LIFT DMY BK 1 0.0 1/7/1986 0.000 6,040.4 5,547.0 29.30 4 GAS LIFT DMY BK 1 0.0 1/7/1986 0.000 6,391.0 5,854.4 28.08 5 GAS LIFT DMY RK 1 1/2 0.0 12/11/2022 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,598.0 6,600.0 6,038.5 6,040.3 A-4, 3A-10 11/26/1993 12.0 RPERF 2 1/8" Dyna Jet; 189 deg. phase 6,600.0 6,620.0 6,040.3 6,058.1 A-3, 3A-10 11/26/1993 20.0 RPERF 2 1/8" Dyna Jet; 60 deg. phasing 6,628.0 6,658.0 6,065.2 6,092.0 A-2, 3A-10 11/26/1993 8.0 RPERF 2 1/8" Enerjet; 180 deg. ph 3A-10, 12/11/2022 5:21:30 PM Vertical schematic (actual) PRODUCTION; 30.0-6,980.9 RPERF; 6,628.0-6,658.0 RPERF; 6,600.0-6,620.0 RPERF; 6,598.0-6,600.0 SOS; 6,522.7 NIPPLE; 6,490.3 PACKER; 6,452.0 PBR; 6,431.5 GAS LIFT; 6,391.0 GAS LIFT; 6,040.4 GAS LIFT; 5,315.6 GAS LIFT; 4,065.7 SURFACE; 30.7-3,212.5 GAS LIFT; 2,249.0 SAFETY VLV; 1,821.4 CONDUCTOR; 31.0-107.0 HANGER; 24.0 KUP INJ KB-Grd (ft) 35.71 RR Date 11/10/198 5 Other Elev… 3A-10 ... TD Act Btm (ftKB) 7,000.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292145700 Wellbore Status INJ Max Angle & MD Incl (°) 34.81 MD (ftKB) 3,600.00 WELLNAME WELLBORE3A-10 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3A-10 (PTD 185-237) Intent to BOI Date:Tuesday, December 20, 2022 9:34:49 AM Attachments:AnnComm Surveillance TIO for 3A-10.pdf MIT KRU 3A-10 diagnostic MITIA 12-10-22.xlsx From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, December 13, 2022 6:07 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3A-10 (PTD 185-237) Intent to BOI Chris, KRU 3A-10 (PTD 185-237) has been shut in since 6/28/2018 due to slow TxIA communication while on Seawater Injection. To determine if this is a temperature sensitive issue CPAI intends to bring the well online, on Produced Water Injection for a 90 day monitor period. Once the well has stabilized a State Witnessed MITIA will be performed (the last MITIA passed on 12/10/2022, 10-426 attached). The well will then be monitored for TxIA communication for the remainder of the monitor period and if it is proven to have integrity on Produced Water Injection the proper paper work will be submitted for continued injection. A wellbore schematic is attached. Please let me know if you disagree or have any questions with the plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Wednesday, May 30, 2018 4:54 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: KRU 3A-10 (PTD# 185-237) update Chris, I wanted to update you on our diagnostic work on KRU injector 3A-10(PTD#185-237). The well was brought on water injection for monitoring and the IA pressure did indeed rise. In addition to the daily Operators wellwalks, DHD techs have been doing regular checks of the IA buildup rate to establish if there is enough pressure communication to attempt a log. At this point,the pressure buildup seems to be very inconsistent and at times almost nonexistent. We intend to continue the frequent monitors and attempt to establish a pressure build up trend that warrants a logging attempt. If we don't believe we can successfully log the well by June 30, 2018,we will shut the well in and inform you at that tim Please let me know if you have any questions or disagree with this plan. Travis From: NSK Well Integrity Supv CPF3 and WNS Sent:Wednesday, May 2, 2018 1:24 PM To:Wallace, Chris D(DOA)<chris.wallace@alaska.gov> SCANNED JUN 0 1 2018 :Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subj t: KRU 3A-10(PTD#185-237) update Chris, Recently we attempte• •'.gnostics on KRU injector 3A-10(PTD#185-237) in support of the work below. However, D D was unable to establish any '•d of leak rate between the tubing and IA. Our current suspicion is that there is a ; perature effect of having the well on seawater injection that contributes to the IA pressurization. CPAI proposes return! : the well to injection and monitoring for another instance of IA pressurization. If this occurs as expected,we wil •tify you of the high IA pressure, and we intend to propose at that time to leave the well on injection long enough to pe • • a leak detect log while on seawater injection. Please let me know if you have any questions or disagree with thi •Ian. Travis From: NSK Well Integrity Supv CPF3 and WNS Sent: Monday,July 31, 2017 4:22 PM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tvler.Senden@conocophillips.com> Subject: KRU 3A-10(PTD#185-237) update Chris, 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Wednesday, May 2, 2018 1:24 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 3A-10 (PTD# 185-237) update Chris, Recently we attempted diagnostics on KRU injector 3A-10(PTD#185-237) in support of the work below. However, DHD was unable to establish any kind of leak rate between the tubing and IA. Our current suspicion is that there is a temperature effect of having the well on seawater injection that contributes to the IA pressurization. CPAI proposes returning the well to injection and monitoring for another instance of IA pressurization. If this occurs as expected, we will notify you of the high IA pressure, and we intend to propose at that time to leave the well on injection long enough to perform a leak detect log while on seawater injection. Please let me know if you have any questions or disagree with this plan. Travis From: NSK Well Integrity Supv CPF3 and WNS Sent: Monday,July 31,2017 4:22 PM SCANNED To:Wallace, Chris D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: KRU 3A-10(PTD#185-237) update Chris, This is an update for 3A-10(PTD#185-237), an injector previously reported for suspect IA pressurization after an IA bleed in July 2016. Diagnostics were conducted after the observation including a passing MITIA and packoff tests, however,the IA DDT failed during a monitor. The well was shut-in in August 2016 and secured for further diagnostics. Eventually,the tubing and IA pressure were bled down for a long-term monitor. Based on the diagnostic results, CPAI suspects a packer leak and plans to pursue a remedial repair. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 I�5 -a3 7 Carlisle, Samantha J (DOA) From: Loepp,Victoria T (DOA) Sent: Wednesday, October 04, 2017 3:01 PM To: Carlisle, Samantha J (DOA) Subject: FW:WITHDRAW SUNDRY#317-295 Follow Up Flag: Follow up Flag Status: Completed Please handle. From: Haggerty-Sherrod,Ann (Northland Staffing Services) [mailto:Ann.Haggerty- Sherrod@contractor.conocophillips.com] Sent:Wednesday,September 13, 2017 8:32 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc: Brown, H Marshall<H.Marshall.Brown@conocophillips.com>; Kanady, Randall B <Randall.B.Kanady@conocophillips.com> Subject:WITHDRAW SUNDRY#317-295 Good Morning, This email is to officially request withdrawal of the following approved Sundry: 3A-10 (Resin Packer Repair) approved Sundry#317-295 We are withdrawing this application due to significant changes in the original job and subsequent approved new application. Thanks, Ann Haggerty-Sherrod 907/263-4612 rcc i - 1iui7 • C4 0 w ! I— IP (4N moo a Y o 4-, N N z On ? 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OD U C) Q f6 N 7 d qj E z a) op 21 Q NO O ao a-- N N a- M M 44 E G) to m Z 1 co L a % Fi Vi 2. n > > X ca U 6 QE _ — a Q O N N N N N M N N y1 Z Y c 'ai C ^ co C to )o 00 N 'y v 0 O a LD Q - g a` a Q • SOF 1.4, (00",\\I//7. ,v THE STATE Alaska Oil and Gas ofLAsKA Conservation Commission - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS"' Fax: 907.276.7542 www.aogcc.alaska.gov H. Marshall Brown Wells Engineer ConocoPhillips Alaska, Inc. N EP Q P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3A-10 Permit to Drill Number: 185-237 Sundry Number: 317-412 Dear Mr. Brown: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /°)*Gvti--"- Cath P. Foerster Commissioner DATED this day of September, 2017. RBDMS ,v SEP - 7 2017 • • • RE -f, • r..r V 1�les; STATE OF ALASKA AUG 2 5 017, 1 ALASKA OIL AND GAS CONSERVATION COMMISSION 7 APPLICATION FOR SUNDRY APPROVALS G l 20 AAC 25.280 7. 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: Resin Packer Repair El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 0 185-237 ' 3.Address: Stratigraphic ❑ Service E. 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-21457-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ' KRU 3A-10 Will planned perforations require a spacing exception? Yes 1=1No El 1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25631 • 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 ND: MPSP(psi): Plugs(MD): Junk(MD): 7,000' • 6,397' ' 6885 . . 6294 3878 NONE NONE Casing Length Size MD ND Burst Collapse Structural Conductor 76' 16" 107' 107' Surface 3,182' 12" 3,213' 3,143' Production 6,951' 7" 6,981' 6,380' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6598-6600,6600-6620, 6038-6040,6040-6058, 2.875" J-55 6,524' 6628-6658 ' 6065-6092 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-BROWN HB PACKER . MD=6452 TVD=5908 SAFETY VLV-BAKER FVL NON-EQUALIZING SSSV ' MD=1821 TVD=1821 12.Attachments: Proposal Summary 2 Wellbore schematic (] 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service El' 14.Estimated Date for 9/6/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 ' GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown '❑ Abandoned ❑ 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: H.Marshall Brown Contact Name: H.Marshall Brown Authorized Title: W Is Engineer Contact Email: H.Marshall.Brown@cop.com Q� '77�iy Contact Phone: 907 265-6218 Authorized Signature: 1 '�C Date: S 1' - ( ) COMMISSION fJSE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ( 7- I-7//Z_ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test lfr" Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes M No 0 / -- 1 Spacing Exception Required? Yes ❑ No V Subsequent Form Required: 0 ` n RBDMS V- SEP - 7 2017 APPROVED BY Approved by: , , COMMISSIONER THE COMMISSION Date:q"G . l 7 -Psi t/p i V77- gill/ 11-7- 7.01 O R4I4I Submit Form and For 10-40 Rd 4/2017 Niitl�N`o is valid for 12 months from the date of approval. Attachments in Duplicate • • Background: 3A-10 was converted to injection in January 1987. In July of 2016; 3A-10 reported for a high IA pressure. The production tubing packoffs were tested as well as an MIT-IA was performed in which both tests passed. However, a draw down IA tests was preformed and a slow buildup of pressure was reported indicating a one-way packer leak. Job Objective: Pump 4.5 bbl. of 14.1 PPG. Halliburton LockCem down 2-7/8" production tubing through the side pocket mandrel at 6,391 ft. and seal leaking packer and seal assembly 61 ft. below. / Procedure: E-Line/DSL: (Cement Bod Log, Perf) 1) Hold pre job safety meeting and identify hazards. 2) MIRU E-Line/DSL and support equipment 3) RIH with CBL and log from top of Liner @ 6,700 ft. to 5,000 ft. (above GL station 3) 4) RIH w/2.113" O.D. Baker QUIK Drill composite bridge plug and set @ 6,470 ft. 5) RIH w/ tubing punch and punch holes from 6,428 ft.- 6,426 ft. @ 4SPF. @ 0-degree phasing 6) POOH w/fired guns and establish circulation via T to IA a. Ensure well is freeze protected 7) RIH w/ Black Hawk 2 7/8" cement retainer and set @ 6,410 ft. 8) RDMO E-line Coiled Tubing: (14.1 PPG LockCem, Milling) 1) Hold pre job safety meeting and identify hazards 2) MIRU coiled tubing and support equipment 3) Prepare to take returns from tubing annulus (7" production casing) a. Rig up choke manifold on tubing annulus in order to hold 1,500 psi on tubing annulus during pumping operations. 4) RIH and sting into retainer @ 6,410 ft. a. Pressure test coiled tubing annulus to ensure properly stung into retainer • • 5) Establish injection thru tubing punches and circulate 100 bbl. of diesel into IA. a. Attempting to wash any possible debris from squeeze area 6) Pump LockCem as follows while holding 1,500psi back pressure on IA: a. 10 bbl corrosion inhibited seawater b. 7 bbl. 14.1# LockCem c. 18 bbl. corrosion inhibited seawater(Coiled tubing volume) i. Once LockCem volume is pumped past cement retainer, shut down and pull out of retainer while continuing to hold back pressure d. Open CT x T annuls e. 28 bbl. of MMCR/Musol (Cement/Resin Retardant) i. Lay in tubing while POOH ii. Want to leave Retardant from top of retainer to 1,500ft. f. 9 bbl. diesel freeze protect 7) RDMO Coiled tubing and support equipment a. Let LockCem set for 7 days before returning to mill out. b. Leave IA shut in with 1,500 psi on it ***7 DAYS LATER*** 8) Hold pre job safety meeting and identify hazards 9) MIRU coiled tubing and support equipment 10)PU 2.25" mill w/ motor and RIH to top of Cement Retainer @ 6,410 ft. 11)Mill thru cement retainer, 60 ft. of LockCem & composite bridge plug. 12)Once the bridge plug has been milled out, RIH to Nipple and tag 13)POOH and PU 2.00"jet nozzle 14) RIH to below tubing tail @ 6,523 ft. 15)Perform FCO to surface. 16)RDMO Coiled Tubing and support equipment E-Line/RELAY: (MIT- IA, CBL) 1) Hold pre job safety meeting and identify hazards 2) MIRU RELAY and pressure test as required 3) RIH and set plug in 2.25" D Nipple No GO @ 6,490 ft. 4) Preform MITIA& DDT for good LockCem seal on packer and perforations. • • 5) RIH and retrieve plug @ 6,490 ft. 6) RIH w/ CBL and log from 6,480 ft. to 5,900 ft. (above GL station 4) a. Looking for LockCem on backside of tubing. 7) Hand well over to operations for injection and state witnessed PT after stabilized injection. KUP 3A-10 ConocoPhillips Well Attributes Max Angle&MD TD Wellbore API/UWI Field Name Well Status Prod/Inj Type Incl(°) MD(ftKB) Act Btm(ftKB) A€a.K v.Ir1C. 500292145700 KUPARUK RIVER UNIT INJECTING 34.81 3,600 6,975 �onocN�tlitl�fc . """' Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well Conga-3A-10,31512009 i:O8t39.PM SSSV:TRDP 0 1/1/2009 35.71 11/10/1985 Schernosc-Acloal ;>>Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,662 3/4/2009 Rev Reason:TAG RATHOLE triplwj 3/5/2009 Casing Strings __ i - ___.. String OD String ID Set Depth Set Depth(TVD) String Wt String Casing Description (in) (in) Top(ftKB) (ftKB) (ftKB) (lbs/ft) Grade String Top Thrd CONDUCTOR 16 15.062 36 107 107.0 62.50 11-40 SURFACE 9 5/8 8.765 0 3,212 3,142.5 36.00 J-55 PRODUCTION 7 6.151 0 6,975 6,374.9 26.00 J-55 Tubing Strings String OD String ID Set Depth Set Depth(TVD) String Wt String Tubing Description (In) (in) Top(ftKB) (ftKB) (ftKB) (lbs/ft) Grade String Top Thrd CONDUCTOR, I TUBING 3 1/2 2.992 0 28 28 9.30 N-80 EUE 8RD 107 TUBING 2 7/8 2.441 28 6,524 5,972 6.50 J-55 8R Other In Hole All Jewelry:Tubing Run&Retrievable,Fish,etc.) Top Depth SAFETY VLV, - (TVD) Top Incl 1,321 i,.. Top(ftKB) (ftKB) (°) Description Comment Run Date ID(In) 1,821 1,821.0 -0.05 SAFETY VLV Baker'FVL' 1/7/1986 2.312 2,249 2,248.8 3.17 GAS LIFT MERLPJTMPD/1/DMY/BK///Comment: 1/7/1986 2.375 4,066 3,846.8 33.20 GAS LIFT MERLA/TMPD/1/DMY/BK///Comment 1/7/1986 2.375 GAS LIFT, 5,316 4,915.4 28.88 GAS LIFT MERLA/TMPD/1/DMY/BW//Comment: 1/7/1986 2.375 2,249 6,040 5,546.7 29.43 GAS LIFT MERLA/TMPD/1/DMY/BK///Comment: 1/7/1986 2.375 I 6,391 5,854.4 28.08 GAS LIFT MERLAJTGPD/1.5/DMY/RK///Comment:W/WI PKG 10/24/1997 2.375 6,431 5,889.5 26.90 PBR Brown'HB' 1/7/1988 3.000 SURFACE, 3,212 6,452 5,908.3 26.90 PACKERBrown'NB' _- 1/7/1986 3.000 6,490 5,942.1 26.90 NIPPLE Camco'D'Nipple NO GO •1/7/1986 2.250 6,523 5,971.6 26.90 SOS Brown 1/7/1986 2.441 GAS LIFT, 6,524 5,972.5 26.90 TTL 1/7/1986 2.441 4,066 Perforations&Slots Shot Top(TVD) Btm(TVD) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) lone Date (sh... Type Comment GAS LIFT, 6,598 6,600 6,038.5 6,040.8 A-4,3A-10 11/26/1993 12.0 RPERF 2 1/8"Dyna Jet;189 deg.phase 5,316 6,600 6,620 6,040.3 6,058.4 A-3,3A-10 11/26/1993 20.0 RPERF 2 1/8"Dyna Jet;60 deg.phasing 6,628 6,658 6,065.5 6,092.0 A-2,3A-10 11/26/1993 8.0 RPERF 2 1/8"Enerjet;180 deg.ph Notes:General&Safety End Date Annotation GAS LIFT 1/7/1986 NOTE: FMC GEN III HNGR w/31/2"pup-XO-3 1/2"X 2 7/8"X 4(4.15+.5) 6,040 GASLIFT, 6,391 "rt. PBR,6,431III PACKER,6,452 NIPPLE,6,490 1. • I II I SOS,6,523 TTL,6,524 RPERF, 6,596-6,600 _ RPERF, I T 6,6008,620 RPERF, 6,626-6,656 8 1 M PRODUCTION, TO,:,:g N • .. Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Monday,July 31, 2017 4:22 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 3A-10 (PTD# 185-237) update Chris, This is an update for 3A-10(PTD#185-237), an injector previously reported for suspect IA pressurization after an IA bleed in July 2016. Diagnostics were conducted after the observation including a passing MITIA and packoff tests, however,the IA DDT failed during a monitor. The well was shut-in in August 2016 and secured for further diagnostics. Eventually,the tubing and IA pressure were bled down for a long-term monitor. Based on the diagnostic results, CPAI suspects a packer leak and plans to pursue a remedial repair. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 or TA., 11/7 THE STATE Alaska Oil and Gas hfLASJ() �t1 /� Conservation Commission o A fl{= i� 333 West Seventh Avenue r Anchorage,Alaska 99501-3572 GOVERNOR BILL WALKER g Main:907.279.1433 ALAg*1.' Fax:907.276.7542 www.aogcc.alaska.gov H.Marshall Brown Wells Engineer ConocoPhillips Alaska,Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool,KRU 3A-10 Permit to Drill Number: 185-237 Sundry Number: 317-295 Dear Mr.Brown: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, • Hollis S. French Chair DATED this 6 day of July,2017. • • • • • RECEIVED STATE OF ALASKA JUN 2 3 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1 1.Type of Request: Abandon 0 Plug Perforations LI Fracture Stimulate El Repair Well u v•rL • Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other: Resin Packer Repair El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 0 •185-237 3.Address: Stratigraphic ❑ Service EI 6.API Number P.O.Box 100360,Anchorage,Alaska 99510 50-029-21457-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3A-10 Will planned perforations require a spacing exception? - Yes ❑ No❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25631 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 ND: MPSP(psi): Plugs(MD): Junk(MD): 7,000' 6,397' 6885 6294 3878 NONE •NONE Casing Length Size MD ND • Burst Collapse Structural Conductor 76' 16" 107' 107' Surface 3,182' 12" 3,213' 3,143' Production 6,951' 7" 6,981' 6,380' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: • Tubing MD(ft): 6598-6600,6600-6620, 6038-6040,6040-6(158, 2.875" J-55 6,524' 6628-6658 6065-6092 Packers and SSSV Type:- Packers and SSSV MD(ft)and ND(ft): PACKER-BROWN HB PACKER Mix 6452 TVD=5908 SAFETY VLV-BAKER FVL NON-EQUALIZING SSSV MD=1821 TVD=1821 12.Attachments: Proposal Summary 0 Wellbore schematic El 13.Well Class after proposed work: , Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 Stratigraphic 0 Development❑ Service l] 14.Estimated Date for 7/24/2017 15.Well Status atter proposed work: Commencing Operations: OIL 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 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: H.Marshall Brown Contact Name: K.Marshall Brown Authorized Title: Wells Engineer Contact Email: H.Marshall.Brown@cop.com f4:11,64 -7-- J / t Contact Phone: (907)265-6218 Authorized Signature: GDate: (� 4A2 [ COMMI ON USE ILLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Si-7-2/6 Plug Integrity 0 BOP Test El Mechanical Integrity Test Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes L•J No 0 Spacing Exception Required? Yes ❑ Nor/ Subsequent Form Required /D 4-0 APPROVED BY 91- 1 c It, Approved by: C../:12c4---\____ COMMISSIONER THE COMMISSION Date: J D U I I Submit Form and Form 10-403 Revised 4/2017 ror v ppAtiT iElld for 12 months from the date of approval. Attachments in ouplcate • • Background: 3A-10 was converted to injection in January 1987. In July of 2016; 3A-10 reported for a high IA pressure. The production tubing packoffs were tested as well as an MIT-IA was performed in which both tests passed. However, a draw down IA tests was preformed and a slow buildup of pressure was reported indicating a one-way packer leak. Job Objective: Pump 4.5 bbl. of 14.1 PPG. Halliburton LockCem down 2-7/8" production tubing through the side pocket mandrel at 6,391 ft. and seal leaking packer 61 ft. below. Pump& Slickline: (14.1 PPG LockCem,Valve Change Out,Retrieve Catcher& Packer) 1) Rig up pump and supporting equipment. 2) Prepare to take returns from tubing annulus (7" production casing) a. Rig up choke manifold on tubing annulus in order to hold 1,000 psi on tubing annulus during pumping operations. b. Rig up pump and lines to allow for reverse circulation 3) Open tubing annulus 4) Pump as follows: 1-2 BPM a. 80 bbl. of heated diesel (80°F - 100°F) b. 30 bbl. heated corrosion inhibited water(80°F - 100°F) 2 -3 BPM (want LockCem past permafrost zone as quickly as possible) c. 4.5 bbl. of 14.1 PPG. LockCem (80°F- 100°F) d. 5 bbl. corrosion inhibited water (80°-100°) e. 5 bbl. MMCR/Musol (Resin Inhibitor- DO NOT HEAT) 1-2 BPM f. 19 bbl. MMCR/Musol (Cement Retardant) (80°-100°) g. 10 bbl_ of heated diesel (80°F - 100°F) — Resin will be pumped away thru check valve at end of volume h. SHUT DOWN—Hold 1,000 psi on 3-1/2"X 7"Annuls for 5 minutes 1 BPM 6 bbl. of heated diesel (80°F- 100°F) j. Shut Down NOTE: LockCem HAS 6 HOURS BEFORE IT SETS AND BECOMES UNWORKABLE III 40 KUP 3A-10 ConocoPhillips e*T Well Attfr•b.U.}aatss '. Max Angle&MD ID Wellborn APPUWI F7eld Name Well status Incl Alaska,int.. 1 I'f IAD NIKE) Am Dim ROW) car caenllflpl _ 500292145700 IKUPARUK RIVER UNIT INJ 34.81 3,600.00 7,000.0 Comment NM(ppm) Dale Annotation End Data lW.G1d(fl) Mg Reisman Dale vrenwnr..:•3MID.ienswuT:15s2nle SSSV:TRDP Last WO: 35.71 1100/1985 srhrtuAnnaalon Depth(BKB) End Dale Annotation Last Mod... nd Data Lest Tag:SLM 6,6670 11710/2010 Rev Reesore DRILL DATES/PROD CSG RKB oshort 10/152012 Cas1U,q:Stnngs ' Casing Description Bring 0... String IO Top{MMB) BM Depth(1..Set Depth(ND)...Siring Wt..,String...String Top Thrd NA80ER2 '.i CONDUCTOR 16 15.062 31.0 107.0 107.0 62.50 H40 WELDED Casing Description String 0... String ID._Top(1KB) Sol Depth(L.Set Depth[IND)...String WL..String Siring lop Tbrd SURFACE 95/8 8.921 30.7 3,212.5 3,1429 36.00 J-55 BTC Casing Description String 0... &d.8 ID...Top(ItOBI Set Depth(L-Sol Deplh(IVD)...String Wt_String...Swag Top Thd PRODUCTION 7 6.276 30.0 6,980.9 6,390.2 26.00 J-55 BTC Tubij3g Strints - Tubin50000rtpllon String O... swine lD... op(BKti) Sat Oapli(I.Bet Depth(iVU)._ gM...awing...swing lop Thad TUBING I 2718 I 2,041 240 I BS23.6 5,972.1 450 I J-55 EUE BRD Comnitt(on Dat011t . •. Top Depth (TVD) Topinci NoM..- 1-op pBK6) (6KB) (1 Bern Deendpgan Comment ID(In) 2411 24.0 -0.06 HANGER FMC GEN II11-ANGER W/3 12 PUP 3,500 CONDUCTOR. 31.107 1,821.4 1,821.4 -0.04 SAFETY VLV 'BAKER FVL NON-EQUALIZING 55SV 2.000 it 6,431.5 5,890.0 26.90 PBR BROWN PIR TYPE-CB WJ PUP •2.312 Well'VLV, 6,452,1 5,908.3 26.90 PACKER BROWN HB PACKER 2.313 1.021 6.490.3 5,9425 26.90 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,522.7 5,971.3 26.90 SOS BROWN SHEAR-OUT-SUB 2.441 . GAS UFT.__-__-- '. PerfOrations&Slots . - - - Z249 Shot . Top(TVD) Sha(TVD) Dena Top MKS)Btn1MKS) (BKS) (586) Zola Ode PM- Type Comment 6,59811 6,600.0 6,038.5 6,040.8 A-4,3A-10 1112671993 12.0 RPERF 2 1/8"Dyna Jet;189 deg,phase 6,600.0 6,620.0 6,040.3 6,058.4 A3,3A-10 11/26/1993 20.0 RPERF 21/8'Dyne Jet;90 deg.phasing 6,6280 6,658.0 6,065.5 6,892.0 42.3A-10 11726/1993 8.0 RPERF 21/8'Enerjel;180 deg.ph • End Dale I ...Annotation 5/28/2010 NOTE:View 9chgmgge wd Nask,Sehema0c911 SURFACE. A L. 31-9213 GAS UFT, �, . 4.056 I ' GASLIFT, 5316 I. GAS LIFT, 6,040 GAS OFT, 4 . 6,371 P80,6,431 [ 1 PACKER,6,452 e It- NIPPLE,6,490 A . 505 5523 RPERF, RPERF, r 1a11Mr�1'a/SWrW . B.Ee0G.640 iTop .. T p D pth Top r Pa( • (ND) Incl CID Vohre Latch Sloe TRO Run Stn Top ISMS) (hKBI I') MoIre Model (in) Sae Type Type (tn) (w9 Run Date Coad. t4PhR9. 1 2,249.0 2,248.8 3.17 MERLA TMPD MV 1 GAS UFT DBK 0.000 0.0 1/7/1988 6.03-6.668- ---� 2 4,065.7 3,846.633.20 MERLA TMPD 1 GAS UFT DMY BK 0.000 0.01)7/1986 3 5,315.6 4,915.1 28.88 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/7/1986 4 6,040.4 5,547.0 29.43 MERLA TMPD '1 GAS L FT MAY BK 0.000 0.0 1/7/1986 5 6,391.0 5,854.4 28.08 MERLA TGPD 1 1/2 GAS LIFE DMY RK 0.000 0.0 10124/1997 PRODUCTION, 366,981 ' T0,7,000 • ®F T�, THE STATE Alaska Oil and Gas • o f e T \ S}( ^ Conservation Commission 333 West Seventh Avenue 2=== I Anchorage, Alaska 99501-3572 *011)T7 ,, GOVERNOR BILL WALKER Main: 907.279.1433 OF n',,410* Fax: 907.276.7542 www.aogcc.alaska.gov H. Marshall Brown SCANNED ►� ? 2 7 20 17, Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3A-10 Permit to Drill Number: 185-237 Sundry Number: 317-295 Dear Mr. Brown: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this 6 day of July, 2017. RBDMS " 1 1 2017 • • RECEIVED STATE OF ALASKA JUN 2 3 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Repair Well Erc n'' Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other: Resin Packer Repair 0•' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory 0 Development 0 185-237 ' _ 3.Address. Stratigraphic 0 Service 0. 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-21457-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A • Will planned perforations require a spacing exception? Yes 0 No 0 J KRU 3A-10 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25631 ' 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): 7,000' - 6,397' . 6885 _ - 6294 3878 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 16" 107' 107' Surface 3,182' 12" 3,213' 3,143' Production 6,951' 7" 6,981' 6,380' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: • Tubing MD(ft): 6598-6600,6600-6620, 6038-6040,6040-6058, 2.875" J-55 6,524' 6628-6658 • 6065-6092 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BROWN HB PACKER • MD=6452 TVD=5908 SAFETY VLV-BAKER FVL NON-EQUALIZING SSSV r MD=1821 TVD=1821 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for 7/24/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 ' GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 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: H.Marshall Brown Contact Name: H.Marshall Brown Authorized Title: fi 4Wells Engineer Contact Email: H.Marshall.Brown@cop.com�� ,�/ 67.221000— COMMIS ` Contact Phone: (907)265-6218 Authorized Signature: ,/ Date: (� l l COMMIS ION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317- 2/5 _ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes �No 0 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /0 -40 L}- RBDMS L(-- .L. 1 1 2017 APPROVED BY _4 I ` i t Approved by: � COMMISSIONER THE COMMISSION Date: 7 illi 9'. 0441)- ►1` -7-13`17- Ca- ?_�- Submit Form and Forrlelec b, tJ R "GIN p tills is valid for 12 months from the date of approval. Attachments in Duplicate • • Background: 3A-10 was converted to injection in January 1987. In July of 2016; 3A-10 reported for a high IA pressure. The production tubing packoffs were tested as well as an MIT-IA was performed in which both tests passed. However, a draw down IA tests was preformed and a slow buildup of pressure was reported indicating a one-way packer leak. Job Objective: Pump 4.5 bbl. of 14.1 PPG. Halliburton LockCem down 2-7/8" production tubing through the side pocket mandrel at 6,391 ft. and seal leaking packer 61 ft. below. Pump & Slickline: (14.1 PPG LockCem, Valve Change Out, Retrieve Catcher& Packer) 1) Rig up pump and supporting equipment. 2) Prepare to take returns from tubing annulus (7" production casing) a. Rig up choke manifold on tubing annulus in order to hold 1,000 psi on tubing annulus during pumping operations. b. Rig up pump and lines to allow for reverse circulation 3) Open tubing annulus 4) Pump as follows: 1- 2 BPM a. 80 bbl. of heated diesel (80°F - 100°F) b. 30 bbl. heated corrosion inhibited water (80°F - 100°F) 2 - 3 BPM ant LockCem past permafrost zone as quickly as possible) c. 4.5 bbl. of 14.1 PPG. LockCem (80°F - 100°F) d. 5 bbl. corrosion inhibited water (80°-100°) e. 5 bbl. MMCR/Musol (Resin Inhibitor- DO NOT HEAT) 1- 2 BPM f. 19 bbl. MMCR/Musol (Cement Retardant) (80°-100°) g. 10 bbl. of heated diesel (80°F - 100°F) — Resin will be pumped away thru check valve at end of volume h. SHUT DOWN — Hold 1,000 psi on 3-1/2" X 7" Annuls for 5 minutes 1 BPM i. 6 bbl. of heated diesel (80°F - 100°F) j. Shut Down NOTE: LockCem HAS 6 HOURS BEFORE IT SETS AND BECOMES UNWORKABLE KUP • 3A-10 ConacoPhi11ips Well Attributes Max Angle&MD TD Al 1 Wellbore API/UWI Field Name Well Status Incl(°) MD(ORB) Act Btm(ftKB) C vxxaawktn 500292145700 KUPARUK RIVER UNIT INJ 34.81 3,600.00 7,000.0 "" Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••• Well Conlp'-3A-10,10/15/20127:15:52 AM SSSV:TRDP Last WO: 35.71 11/10/1985 Schemattc-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 6,667.0 11/10/2010 Rev Reason:DRILL DATES/PROD CSG RKB osborl 10/15/2012 Casing Strings e' `pro, Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd HANGER,24 CONDUCTOR 16 15.062 31.0 107.0 107.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.921 30.7 3,212.5 3,142.9 36.00 J-55 BTC Casing Description String 0... String ID...Top(ORB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 30.0 6,980.9 6,380.2 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String... String Top Thrd pi ri TUBING2 7/8 2.441 24.0 6,523.6 5,972.1 6.50 J-55 EUE 8RD Completion Details Top Depth (ND)D) Nomi... Top IRKS) (ftKB) (°) Item Description Comment ID(in) 24.0 24.0 -0.06 HANGER FMC GEN III HANGER W/3 1/2 PUP 3.500 CONDUCTOR, 31-107 1,821.4 1,821.4 -0.04 SAFETY VLV BAKER FVL NON-EQUALIZING SSSV 2.000 I 6,431.5 5,890.0 26.90 PBR BROWN PBR TYPE-CB W/PUP 2.312 SAFETY VLV, 6,452.1 5,908.3 26.90 PACKER BROWN HB PACKER 2.313 1,821 6,490.3 5,942.5 26.90 NIPPLE CAMCO D NIPPLE NO GO 2250 6,522.7 5,971.3 26.90 SOS BROWN SHEAR-OUT-SUB 2.441 GAS LIFT, Perforations&Slots 2,249 Shot .'•• Top(TVD) Btm(TVD) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (dh.- Type Comment 6,598.0 6,600.0 6,038.5 6,040.8 A-4,3A-10 11/26/1993 12.0 RPERF 2 1/8"Dyna Jet;189 deg.phase 6,600.0 6,620.0 6,040.3 6,058.4 A-3,3A-10 11/26/1993 20.0 RPERF 2 1/8"Dyna Jet;90 deg.phasing 6,628.0 6,658.0 6,065.5 6,092.0 A-2,3A-10 11/26/1993 8.0 RPERF 2 1/8"Enerjet;180 deg.ph Notes:General&Safety J End Date Annotation 6/28/2010 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE, I 31-3,213 GAS LIFT, 4,066 GAS LIFT, 5,316 GAS LIFT, 6,010 GAS LIFT, 6,391 1 FOR,6,431 L-_ t PACKER,6,452 NIPPLE,6,490 SOS,6,523 f ! 6,598-6, { RPERF, 600 - 6. RPERF, Mandrel Details Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (RKB) (") Make Model (in) Sery Type Type (in) (psi) Run Date Corn... 1 2,249.0 2,248.8 3.17 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/7/1986 6,628-6,658 2 4,065.7 3,846.6 33.20 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/7/1986 3 5,315.6 4,915.1 28.88 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0'1/7/1986 4 6,040.4 5,547.0 29.43 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/7/1986 5 6,391.0 5,854.4 28.08 MERLA TGPD 1 1/2-GAS LIFT DMY RK 0.000 0.0 10/24/1997 PRODUCTION, , 306,9814 TD,7,000 • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday, July 16, 2016 9:12 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: Kuparuk Injector 3A-10 (PTD # 185-237) unexplained IA pressure increase Attachments: 3A-10.pdf; 3A-10 90 Day TIO plot.JPG Chris- Kuparuk injector 3A-10 (PTD# 185-237) has shown an unexplained increase in IA pressure after an IA bleed. The IA was bled initially towards the end of June and again on the 14th of July. Initially the increase was suspected to be a thermal response to the slight increase in the flowing tubing temperature but the repeatable increase in pressure makes it suspect. The well will be left on water injection during the initial diagnostics. If the initial diagnostic testing passes the IA will be bled down and monitored for 30 days. If the diagnostic testing fails the well will be shut in and secured for further investigation. Please let me know if you have any questions or disagree with the plans. Attached is a well bore schematic and a 90 TIO plot. Dusty Freeborn /Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 `yWELLS TEAM ConocoPhillips SCANNED DEC 0 12016 w • • . ..;,, .z..W H v„ vi i CC CL 0- w w a 0 vi o 0 w -7 u', K -1 L' Ct. L" G O v, O O w �i 47 N OC t-, M a *G o ¢) y ... m N O O w O c rn O C.- CV • a N LO (.0 G O Lu N N 1 'vt N ~ I- ID O JI O O J w <YQ ,-,-, Cr, o0 ( Bap �I o 0 m c.0 r-- LG Lc, n r i N 0 U 1 1 1 1 1 I 1 1 T 61 1 1 m I 4o a) 1 U C R = i t 1 G 1 ...c 0 .),_ , u 4 o c 3 c 0 U I to = 1 z c a 1J1 2 \I f , M ` lagi I 1 1111 I E 01 a, , 1 o $ a $ $ § $ H °d •• m to tu cno` ISd KU P . 3A-10 ConocoPhillips " 'fie Well Attributes llborn Max Angle&MD T Field Marne w. Status Ind tB) D (ftKB)Alaska'Ir1c. W500292145700 KUPARUK RIVER UNIT INJ 34.81 3500.00 7,000.0 lonocoPhlll,to Comment HIS(ppm) Date Annotation End Data KB-Ord(ft) Rig Release Date • Well Conk:-3A-10,10/15/2012 7:15:52 AM SSSV:TRDP Last WO: - 35.71 11/10/1985 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 6,667.0 11/10/2010 Rev Reason:DRILL DATES/PROD CSG RKB osborl 10/15/2012 Casing Strings Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd - HANGER,24 CONDUCTOR 16 15.062 31.0 107.0 107.0 62.50 _ H-00 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String•••String Top Thrd SURFACE 95/8 8.921 30.7 3,212.5 3,142.9 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd PRODUCTION 7 6.276 30.0 6,980.9 6,380.2 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top MB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd TUBING 27/8 2.441 24.0 6,523.6 5,972.1 6.50 J-55 EUE 8RD II ri Completion Details Top Depth (TVD) Top Incl Hotel... ftKB To (ftKB) ( ) Item Description ID in p 1°IComment 1 1 24.0 24.0 -0.06 HANGER FMC GEN III HANGER W/3 1/2 PUP 3.500 CONDUCTOR, 31-107 1,821.4 1,821.4 -0.04 SAFETY VLV BAKER FVL NON-EQUALIZING SSSV 2.000 6,431.5 5,890.0 26.90 PBR BROWN PBR TYPE-CB W/PUP 2.312 SAFETY VLV, O 6,452.1 5,908.3 26.90 PACKER BROWN HB PACKER 2.313 1,e21 6,490.3 5,942.5 26.90 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,522.7 5,971.3 26.90 SOS BROWN SHEAR-OUT-SUB 2.441 GAS LIFT, Perforations&Slots 2,249 Shot Top(ND) Btm(TVD) Dens Top(ftKB) Bun(RKB) (ftKB) (kKB) Zone Date . Type Comment 6,598.0 6,600.0 6,038.5 6,040.8 A-4,3A-10 11/26/1993+12.0 RPERF 2 1/8"Dyna Jet;189 deg.phase 6,600.0 6,620.0 6,040.3 6,058.4 A-3,3A-10 1126/1993.20.0 RPERF 2 1/8"Dyna Jet;60 deg.phasing 1 6,628.0 6,658.0 6,065.5 6,092.0 A-2,3A-10 11/26/1993' 8.0 RPERF 2 1/8"Enerlet;180 deg.ph Notes:General&Safety End Date Annotation 6282010 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE, ' 31-3,213 i GAS LIFT, t 14 4.066 GAS LIFT, 5,3701,1-4' r GAS LIFT,,040 Oo4o 11.1 GAS LIFT, 6,391 fil PBR,0,431 l J PACKER,0,152 NIPPLE.6.490 SOS,6,523 RPERF, _ 6,598fi,650 - - , 6.600RPE.0,62RF0 Mandrel Details Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) C) Make Model (in) Sere Type Type (in) (psi) Run Date Corn... 1 2,249.0 2,248.8 3.17 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/7/1986 RPERF, 6,626-8,658 _ 2 4,065.7 3,846.6 33.20 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/7/1986 3 5,315.6 4,915.1 28.88 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/7/1986 4 6,040.4 5,547.0 29.43 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/7/1986 5 6,391.0 5,854.4 28.08 MERLA TGPD 1 12 GAS LIFT DMY RK 0.000 0.0 10/24/1997 PRODUCTION, 30-0,901 A ' TD,7,000 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. /g~P'~- ~,~_~_,~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: rn Diskettes. No. [] Maps: [3 Grayscale items: D Other, No/Type [3 Other items scannable by large scanner [] Poor Quality Originals: ~ Other:/~.~-*~,F~~ OVERSIZED (Non-Scannable) [3 Logs' of various kinds ~r~ mOther TOTAL PAGES: NOTES: ORGANIZED BY: BEVERLY E~REN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI Scanned (done) III lllllllllll II Ill PAGES:~ ? (at the time of scanning) SCANNED BY.' BEVERLY BREN VINCEN~ARIA RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file:/'~/~ .,-~"-/O PAGES: i~ ? Quality Checked (done) Rev1 NOTS,~anned,wpcl WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 3A-10 Run Date: 4/28/2010 May 7, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3A-10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21457-00 ~ ~~; PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax:907-273-3535 rafael.barreto @halliburton. com ~.~ ~: CJZ~ l ~5 _~3~ Date: l 9 (,5~ Signed: ~ ®- °~ ~~~. C ~ . _ . ~_ C~ ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 ~,, „, Anchorage, AK 99501 ,y ~ ~,~~ :.~.:- '`~ ~~ ~ ~'' ~''~'` Dear Mr. Maunder: • ~r _ 016 ~~ ~~r~. ~+eei:i. :^~~t OG~IOt~"~~~ APR F ~n:,~a ~f ~ r "~ / ~.~ " f ~ `~~~ ,rt , 1 ~/ L ~ ~` Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). 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 March 27th and 30th, 2009. The corrosion inhibitor/sealant was pumped April 6th and 15th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Peny~in ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off -~ Report of Sundry Operations (10-404) Kuparuk Field Date 4/17/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-01 185-186 28" NA 28" NA 3.50 4/15/2009 3A-036 207-131 11' 1.50 25" 3/27/2009 4.80 4/15/2009 3A-05 185-221 30' 4.10 26" 3/27/2009 7.70 4/15/2009 3A-06 185-222 12' 2.00 19" 3/27/2009 2.60 4/15/2009 3A-08 185-224 22" NA 22" NA 3.10 4/15/2009 3A-09 181-194 SF NA 13" NA 2.55 4/6/2009 3A-10 ~ 185-237 16' 2.50 25" 3/27/2009 5.95 4/6/2009 3A-11 185-238 SF NA 20" NA 2.55 4/6/2009 3A-12 185-239 SF NA 13" NA 1.00 4/6/2009 3A-13 185-281 18'8" 1.00 32" 3/30/2009 7.70 4/6/2009 3A-14 185-282 13' 3.00 20" 3/30/2009 9.35 4/6/2009 3A-15 185-283 NA NA 2.60 4/15/2009 3A-17 196-132 3'6" NA 3'6" NA 12.75 4/6/2009 3A-18 196-133 11'10" 2.00 9" 3/30/2009 2.55 4/6/2009 ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg \Voó,r,;· c¡1[~æ; P.I. Supervisor ~ t { 1 DATE: Monday, September 12,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC 3A-1O KUPARUK RIV UNIT 3A-1O \ q¡S' ')-"?:>7 FROM: J eff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .jßt!- Comm NON-CONFIDENTIAL Well Name: KUPARUK RlV UNIT 3A-1O Insp Num: mitJJ050909121334 Rei Insp Num API Well Number 50-029-21457-00-00 Permit Number: 185-237-0 Inspector Name: Jeff Jones Inspection Date: 8/30/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We.!lJ. 3A-1O ¡Type 1Ri.1 w I TVD _~._5908--.J IA 1175 ___---'~ i 3270 3250 P.T. I ¡852:~"-JTYleTest, SPT i Test psi ¡ 1477 .l?~ 550 825 _~__'!25 825 _-1___ _ I~t~rval 4YRTST J)/F.:_____. P Tubing 2700___.J 2680 I 2680 2680 i Notes 2.3 BBLS diesel pumped. 1 well house inspected; no exceptions noted. on\·,r, cµ ;:\,i; !...I..I '-' '-" , IC~' (, t? t.~ "- (',' ,,', - Ce.", '" ~. I~\l¥,"'\ t...J.,';/':) ~ ~~'¡)"\\I~"i,:, "'" Monday, September 12,2005 Page 1 of 1 MEMORANDUM TO: Julie Heusser ~-v,~'~ DATE: July 21, 2001 Commissioner SUBJECT: Mechanical Integrity Tests THRU: Phillips Alaska Tom Maunder P' I' S uperv is°r~-d'~'~ °JJ'""'":3 ' 3APed FROM: John Crisp 3A-02,04,06,07,10 GKA Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission Packer Depth Pretest Inil~al 15 Min. 30 Min. · we~,I 3A-02' I fYpelnj.,I...s, I ~.v.D. ! 5~30,1 Tu~"r~l ~"~ !' 2"00i 2~,i :~Ob',.l'=~l .4. i ' ".',f.O.I 1852050,1TYPetesti P, IT=Ps,.I ~'~ I c,,~n,I 2?00. I ~ I :~ ! .3300. I ,./F !_--" ! Notes: "w~q"~-o/ :l~.e~i-I" S i~-9-D-I ~ I~u~l 2'x'° I 2~ I'v~,,l'~',l~~l,"a P.T.D:I 1'852070 IType.,~l. P, I'restpsiI '~4b-'9 .I Casingl ~280..I ~01 !s501 ~°1 P/F 'w~I 3^~ IT~..~ni.i ~. I T-¥~D- I' SSO1 I Tut~.gl ,26751 ~'c~o I"~ '1 Notes: wa, P~,T.D. we#l P.T.D. Notes: 3A-07 I.Typ~nj.I S I T.V 'i'YPet~l p ITes~ i I.*u=n.'i . 0oo i ! ! 4. p~l 1,4so lca~i"gl !,0,75 I ~8401 ~820 1,~820! ,P/F ! P 3A-~0 IT~pe'nj.l' S IT:v-D- I 59°8 ITuU"~! ~ i ~ I ~o, i 3000 I,r~a'i'! 4 1852370 ITy~testl ,P ,IT~,psil ~477 IC~i.g,! ~5ool 2~ I ~ ,i 2o~o I, ,"~: I _" Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N -- NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Intelval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in n~tes) Test's Details These wells passed the Standard Annulus Pressure tests. 2 annulus pressures were high considering they were bled down the previous day. 5 MIT's no failues witnessed. M.I.T.'s performed: _S Attachments: Number of Failures: 0 Total Time during tests: 3 HRS: cc.._;-. MIT report form 5/12/00 L.G. MIT KRU 3Aa 7-21-01jc.xls 7/23/01 ARCO Alaska. Inc. ,;os'[ Cffice Rc-..,~,.~360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 17, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~'~,--- ~-~U 2D-08 ~ ..%-~q 3A-10 Stimulate Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering ! ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ALASKA OIL AND GAS ~VAT1ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate ~ Plugging Perforate Pull tubing Alter casing Repair well et h e r 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development __ ARCO Alaska. Inc. Exploratory __ RKB 72' feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 service ~ Kuparuk River Unit 4. Location of well at surface 8. Well number 744' FSL, 806' FEL, SEC.7, T12N, R9E, UM 3A-10 INJECTOR At top of productive interval 9. Permit number/Approval Number 1384' FSL, 1141' FWL, SEC.8, T12N, R9E, U 85-237 At effective depthU 10. APl number :1431' FSL, 1266' FWL, SEC.8, T12N, R9E, 50-029-21457-00 At total depth 11. Field/Pool Kuparuk River Field 1446' FSL~ 1316' FWL~ SEC.8~ T12Nf R9Ef UM -.~, Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 7000' feet Plugs (measured) true vertical 6 3 9 7' feet None Effective depth: measured 6885' feet Junk (measured) true vertical 62 9 4' feet None casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 07' 1 6" 195 Sx AS II 1 07' 1 07' surface 321 2' 9 5/8" 1200 Sx AS III & 3 21 2' 31 42' Intermediate 300 Sx Class G Production 6975' 7" 475 Sx Class G & 6975' 6375' Liner 175 Sx AS I Perforation depth: measured 6598'-6620'; 6628'-6658' true vertical 6038'-6058'; 6065'-6092' Tubing (size, grade, and measured depth) .~ EC~IV~) 2 7/8" J-55, 6.4 Ib/ft, Tail @ 6524' Packers and SSSV (type and measured depth) J~,,~. '~ ~ ~99~ Brown HB ~ 6452'; Baker FVL @ 1821' 13, Stimulation or cement squeeze summary .~_~.~S[4~ Oii & Gas Cons. C0mmissior; REFRACTURE A SAND. .Anch0rag~ Intervals treated (measured) 6598'-6620'; 6628'-6658' Treatment description including volumes used and final pressure SEE A'I-I'ACHED WELL SERVICE REPORT SUMMARY. 14. Representative Daily Averane Production or Injection Data _ OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 6 3 0 1 5 2 5 2 7 3 0 Subsequent to operation 0 0 1 7 5 0 2 0 0 2 6 5 0 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run 'Daily Report of Well Operations ~ Oil Gas Suspended Service X 17. I hereb)~,certify that the foregoing is true and correct to the best of my knowledge. Signed · Title Sr. Petroleum Engineer Date J - / '~- ~/74 Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT WELL -SA-to DATE DAY I TIME DESCRIPTION OF WORK CONTRACTOR/KEY PERSON OPERATION AT REPORT TIME [] INCOMPLETE [] COMPLETE 15~3- ~555 KUPARUK PETROLEUM ENGINEERING C/CC FIELD EST: ACCUMULATED COST LOG ENTRY PAGE 1 OF , , '' -- Z-O -lO0 -~550 - ,, ~' -- 7_.0 -- %tO -- (%66-- ,, " -- 7.0 - %[O - .tO~0 - - t 540 - ,, - (.,,ooo- ~45o [ 54~ - ,. - GC~ 80- 5z~o I--1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather J Temp. I Chill Factor Visibility Report °F °F miles AR3B-7031 Gas Cons. Commission JWind Vel. 298-3486 REMARKS CONTINUED: SERVICE COMPANY SCA # DALLY ACCUM. TOTAL C.. e-- 5 '~ ~... O "/ ,, -.- TOTAL FIELD ESTIMATE I'&J z~:80-~ MORNING REPORT SUMMARY 12/19/93 TO 12/19/93 CpF-3 DS-3A 3A-10 12/19/93 A SAND REFRAC W/ DS & YF14D: PUMPED 150 BBL BREAKDOWN W/ SLICK WATER @ 31 BPM, FWHTP = 6570, FG = 0.86. PUMPED 600 BBL PAD FOLLOWED BY 790 BBL SLURRY, 16/20 2 PPA, 12/18 4-14 PPA @ 20 BPM. ADDED 20 BBL TO 14 PPA STAGE, MAX PRES DURING SLURRY = 6760 PSI, FLUSHED TO COMPLETION. TOT PROP PUMPED = 185 MLBS, TOT DSG = 178 MLBS. IN FORM; 8.3 MLBS 16/20, 176.6 MLBS 12/18. TOT FLUIDS; SEAWATER = 1205 BBL, DSL = 53 BBL, ADD = 84 BBL. (MCINNIS/GOLDEN) REC[IVED AJ~,'_ska Oil & Gas Cons. Commission ARCO Alaska, Inc. Post Office Bo.._...;0360 Anchorage, Alaska 99510-0360 Telephone 907 27'6 1215 December 17, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION '-"~"-'~'t 1F-02 Perforate ,~- 1L-01 Perforate 9~/---F~'~ 2X-1 3 Perforate ~-~-~ 2X-1 5 Perforate /3A-03 Stimulate 99-~ %3A-03 Pedorate ~_~5~ 3A-10 Pedorate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering DEC P- 1 199) A~ch0rage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~.~.,_..jKA OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPER' TIONS 1. Operations Performed: Operation Shutdown . Pull tubing , Alter casing Stimulate Plugging. Perforate X 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 744' FSL, 806' FEL, SEC.7, T12N, R9E, UM At top of productive interval 1384' FSL, 1141' FWL, SEC.8, T12N, R9E, UM At effective depth 1431' FSL, 1266' FWL, SEC.8, T12N, R9E, UM At total depth 1446' FSL 1316' FWL 12. Present well condition summary Total Depth: measured 13. 6. Datum elevation (DF or KB) RKB 72' 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-10 INJECTOR O. Permit number/Approval Number 85-237 10. APl number 50-029-21457-00 14. Effective depth: Ca~ng Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical 107' 3212' 6975' measured 6598'-6620'; true vertical 6038'-6058'; Tubing (size, grade, and measured depth) IM foot 7000' 6397' 6885' 6294' Size 16" 9 5/8" foot feet feet feet Plugs (measured) Junk (measured) 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool True vertical depth # Measured depth 6628'-6658' 6065'-6092' 195 Sx AS II 107' o 107' 1200 Sx AS III & 3212' 31-42' 300 Sx Class G 475 Sx Class G & 6975' 6375' 175 Sx AS I 2 7/8" J-55, 6.4 lb/fi, Tail @ 6524' Packers and SSSV (type and measured depth) Brown HB 6452'; Baker FVL ~ 1821' Stimulation or cement squeeze summary REPERFOF~TE A SAND. Intervals treated (measured) 6598'-6620'; 6628'-6658' Treatment description including volumes used and final pressure HOLE" CHARGES. PERFED RECEIVED DEC 2 1 1995 Alaska (.iii & Gas Cons. Commission Anchorage. PERFED WITH SCHLUMBERGER 2-1/8" ENERJET "BIG 180° PHASING, ORIENTED 90° CCW FROM LOW SIDE OF HOLE. Tubing Pressure Reoresentafive Daily Averaqe Production or Ip!ectjon Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subse( 15. Attachments ~ 16. Status of well classification as: I Copies of Logs and Surveys run m Daily Report of Well Operations X Oil __ Gas Suspended 17. I hereby c~,'tify that the foregoing is true and correct to the best of my knowledge. ned '~J~(~'/} ~~ Title Sr. Petroleum E n~ineor Form 10-404 Rev 09/12/90 Service SUBMIT IN DUPLICATE ARCOAlaska, Inr ) Sul~ldlary of Atlantl= Richfield Comp~l~_~ WELL SERVICE REPORT WELL 3A-10 JPBDT CONTRACTOR £¢kl~.~l~r~¢r' REMARKS FIELD-DISTRICT-STATE OPERATION A'r REPORT TIME J OA~S I DATE I "/~'/'u /iFc: clqgl3o f.v/-. Co.,,'{': ~t 'lqSo. CP' I1~'15 1o i\ I. ' -- DEC 2_ 1 I993 [ii~ & Gas Oons. COmmission Anchorage CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK REMARKS CONTINUED: DESCRIPTION DALLY ACCUM. TOTAL CAMCO OTIS SCH LU M BERG ER $77,~O. DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel 200. Methanol Supervision Pre-Job Safety Meeting AFE TOTAL FIELD ESTIMATE I Signed c.w. WELL SERVICE REPORT ARCO Alaska, Inc Sul~idlary of Atlantic Rlcl~fleld JPBDT 3A-lO I WELL CONTRACTOR REMARKS TP: 2~ ff;~; CP: ITSO p~i ~ 344t IDAYS I DATE I FIELD - DISTRICT. STATE OPERATION AT REPORT TIME 5cR: gO2Z5 C~ Co=f: ~2Z,2oo 05oo oIoo 0q3o 1005 Ills I~.1o t4ZO 15oo · Gas ..~.-.. Cons. Commission 4 SPF / o, N,'N: I. Ivaro, I;,: .,,.I k,s s/o,., le,,g. Blo.k~J ~.d-,.I I:.. ;. ® +~.. a kdJ, F.~,,,. o~. I--} CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. · TOTAL CAMCO ,, OTIS SCHLUMBERGER DRESSER-ATLAS ,. DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER .,. a. J. HUGI'[ES Roustabouts . -Diesel ~ 200 ~oo. Methanol Supervision Pre-Job Safety Meeting , ., AFE .= TOTAL FIELD ESTIMATE I Signed )IL AND GAS CONSERVATION COMMI '~SL,.~ ALAS~ REPORT'OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well _ Change approved program _ Pull tubing _ 99510 2. Name of Operator 5. Type of Well: Development Exploratory Stratigraphic Service Operation Shutdown _ Re-enter suspended well _ Plugging _ Time extension _ Stimulate __ Variance_ Perforate ~x Other m 6. Datum elevation (DF or KB) ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK feet RKB 72 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-10 9. Permit number¢ A,opr~,,,~t 85-237 10. APl number 5o-02(J-214[i7 11. Field/Pool Kuparuk River Oil Pool 4. Location of well at surface 744' FSL, 806' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1384' FSL, 1141' FWL, Sec. 8, T12N, R9E, UM At effective depth 1431' FSL, 1266' FWL, Sec.8, T12N, R9E, UM At total depth 1446' FNL, 1316' FWL~ Sec. 8, T12N, R9E, UM 12. Present well condition summary Total Depth: measured 7000' MD feet Plugs (measured) true vertical 6397' MD feet Effective depth: measured 6885' MD feet Junk (measured) true vertical 6294' MD feet Measured depth True vertical depth 107' MD 107' TVD 3212' 3142' 6975' MD 6375' TVD RECEIVED qi~$k.~ Oii & 8as Coas~ O0m.rr~issioi~. Casing Length Size Cemented Structural Conductor 1 07' I 6" 195 Sx AS II Surface 321 2' 9 5/8" 1200 Sx AS III & Intermediate 300 Sx Class G Production 6 9 7 5' 7" 475 Sx Class G Liner 175 Sx AS I Perforation depth: measured 6658'-6628' MD 6620'-6600' true vertical 6092'-6065' TVD 60 5 8'- 6 04 0' Tubing (size, grade, and measured depth 2 7/8" J-55, 6.4 Ib/ft, TT @ 6524' MD Packers and SSSV (type and measured depth) Brown HB ~ 6452'; Baker FVL SSSV~ 1821' 13. Stimulation or cement squeeze summary Intervals treated (measured) 6600-6620 Treatment description including volumes used and final pressure See attached perforation summary Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 55O 1 230 0 0 9OO 1 230 Tubing Pressure 2485 2495 Prior to well operation Subsequent to operation 16. Status of well classification as: Oil Gas Suspended Service Water Injection 14. 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUBMIT IN DUPLICATE Signed ///-~ ,,~ ~r~ ~y~ =orrn 10-404 ~e[/ 06/15/88 Title Sr. Operations Engineer ' ARCO Alaska, Inc,._~ Subsidiary of Atlantic Richfield Company WELL ~ , JIFIELD- - WELL SERVICE REPORT 0~oo I O~.~ ... lc) /200 [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots Signed ARCO Alaska, In Posl Office ,~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 8, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 'Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well ~ Anticipated Stad Pate 2 X- 1 2 Scale Sqz. J u ne, 2 A- 1 5 Scale Sqz. J u n e, 2 A- 09 Scale Sqz. J u l y, 3 H- 03 Acidize June 3 H- 1 4 Acidize June 2 U- 1.2 Scale Sqz. June. 2 W- 0 7 Scale Sqz. J u n e 3J-06 Fracture June 3J-02 Fracture June. 3 A - 1 0 Perforate June 1 E- 0 6 Acidize June. 1 E-1 1 Acidize June. 1 E- 1 5 Acidize June. 1989 1989 1989 1989 1989 1989 1989 1989 1989 1989 1989 1989 1989 If you have any questions, please call me at 265-6840. Sincerely, G. B. ~'mallwood Senior Operations Engineer ~laska 0ii & ¢~as ,Cons, Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany STATE OF ALASKA _._t- ALASKA OIL AND 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 744' FSL, 806' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1384' FSL, 1141' FWL, Sec. 8, T12N, R9E, UM At effective depth 1431' FSL, 1266' FWL, Sec.8, T12N, R9E, UM At total depth 1446' FSL, 1316' FWL~ Sec. 8, T12N, R9E, UM Present well condition summary Total Depth: measured true vertical 7000' M D feet 6397' M D feet 12. 6. Datum elevation (DF or KB) RKB 72 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-10 9. Permit number 85-237 10. APl number 5o-029-21 457 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) NC~E Effective depth: measured 6885' MD true vertical 6294' MD feet Junk (measured) feet NC~E Casing Length Structural Conductor 1 0 7' Surface 3 21 2' Intermediate Production 6 9 7 5' Liner Perforation depth: measured 6658'-6628' true vertical 6092'-6065' Size 16" 9 5/8" 7" MD TVD Tubing (size, grade, and measured depth 2 7/8" J-55, 6.4 lb/fi, Tail @ 6524' MD Packers and SSSV (type and measured depth) Brown HB @ 6452'; Baker FVL @ 1821' 13, Attachments Description summary of proposal_ _ Add Perforations to the A-3 Sand Lobe. 14. Estimated date for commencing operation June 5. 1989 16. If proposal was verbally approved Name of approver Date approved Cemented Measured depth 195SxASII 107' MD 1200Sx AS III & 3212' 300 Sx Class G 475 Sx Class G 6975' MD 175 Sx AS I RECEIVED True vertical depth 107' TVD 3142' 6375' TVD 3UN ! 19 9 _Alaska_ 0il & Gas Cons. Commission '.~ ~nch0rage Detailed operation program ~ BOP sketch 15. Status of well classification as: Oil __ Gas m Suspended Service Water Injector 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /'~,,,'~.J ,/~ ,~~~--M,~- Title Sr. Operations Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Plug integrity __ BOP Test Mechanical Integrity Test m Notify Commission so representative may witness Location clearance Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE C. SMITH SUBMIT IN TRIPLICATE Attachment to Application for Sundry Approval Kuparuk River Unit Well 3A-10 Additional Perforations Well 3A-10 is currently perforated in the A-2 Sand Lobe, as listed on the Application for Sundry Approval. This Application for Sundry Approval is to add 20' of perforations in the A-3 Sand Lobe in this water injection well. A Wireline BOPE will be used during the perforating procedure. Static Bottom-Hole Pressure is expected to be 3700 psi in this well. No workover fluid will be used during the perforating procedure. RECEIVED l z 1989 ~aska Oil & Gas Cons. Commission Anchorage 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANOE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF RECEIVED Alaska Oil & Gas Cons. Commission Anchorage N I REL I NE BOP EOU I PHENT · i I I ~l~fl6~R RFV. ATTACHMENT 1 PAGE 2 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 4 - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl DATE OF DATE OF DATA TYPE REASON FOR NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ 50-029 INJECTION SURVEY SURVEY SURVEY .,, WELL COMPLETION ZONES TAKING WATER 2B-11 21089 11/19/85 2H-O1 20033 03/15/86 2H-04 20027 03/15/86 06/16/87 06/05/87 06/07/87 50-103 2T-04 20074 , 03/30/87 2T-09 20071 03/30/87 2T-11 20075 03/30/87 2T-15 20062 03/30/87 2T-16 20063 03/30/87 SPINNER FOLLOWUP A&C S SPINNER FOLLOWUP A&C S SPINNER FOLLOWUP A&C S 21433 50-029 3A-02 21431 01/21/87 3A-04 01/21/87 3A-10 21457 01/21/87 06/13/87 SPINNER INITIAL A&C SS 06/16/87 SURVEY INITIAL A S 06/21/87 SPINNER INITIAL A&C SS 06/16/87 SURVEY INITIAL A&C SS 06/16/87 SURVEY INITIAL A&C SS ~ ,~J~I~"~"l~ 1458 01/21/87 05/27/87 3A-14 21/.I, 90 04/14/87 05/87 05/25/87 05/87 05/87 SPINNER INITIAL A&C SS SURVEY INITIAL A&C SS SURVEY INITIAL A S I~~ INITIAL A&C SS SURVEY INITIAL A S 3"' .."'" ~.. A&C A&C A&C A&C AA&C A A A&C A A A&C A .. -/%.72 ,/,,.,' I NJ ECT I ON BWPD 3485 1833 590 2500 1200 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 1650 .RECEIVED Alaska Oil & Gas Cons. 6omm[ssion . Anchorage c,// STATE OF ALASKA ALASK"~"OIL AND GAS CONSERVATION COMN,._.,¢SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed' Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other ~ Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 744' FSL, 806' FEL, Sec. 7, T12N, RgE, UN 5. Datum elevation (DF or KB) RKB 72' 6. Unit or Property name Kimar~k River ! 7. Well number 3A-10 Feel At top of productive interval 1384' FSL, 1141' FWL, Sec. 8, At effective depth 1431' FSL, 1-266' FWL, Sec. 8, ~t4~l~arl debt h FSI.., 1_316' FWL, Sec. 8, T12N, R9E, UM T12N, R9E, UM T12N, R9E, UM 8. Approval number #85-237 9. APl number 50-- 029-21-457 10. Pool Kuparuk River 0il Pool 11 · Present well condition summary_znnn, MD Total depth: measured "-"-'"' true vertical6397' TVD feet feet Effective depth: measured 6885' MD true vertical6294' TVD feet feet Casing Structural Conductor Surface X X X :JCxt~ ~rRc~l(iRt e Production xxx~JS~xxxx Perforation depth: Length Size 107' 16" 3212' 9-5/8" 6975' 7" measured 6658'-6628' MD true vertical6092'-6075' TVD Plugs (measured)None Junk (measured) None Cemented Measured depth True Vertical depth 195 SX ASII 107' MD 1200SX ASII 3212' MD & 300SX Class G 475SX Class G 6975' MD & 175SX ASI 107' TVD 3142' TVD 6375' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, 6.4 ]b/ft, Tail @ 6524' MD Packers and SSSV (type and measured depth) Brown HB @ 6452'; Baker FVL @ 1821 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 419 (Injection started on 1/21-/87. Subsequent to operation 554 0 600 150 Rates shown are 1/31/87) 1180 250 1475 14. Attachments Daily Report of Well Operations I~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ X4t,~t,~r Form 10-404 Rev. 12-~¢~5 ' - Title Sr. Operations Engineer Date¢ Submit plicate ,, , WELL Z PRODUCTION WELL STATUS GAS LIFT STATUS NO. TA O T N U E FTP TEMPCHOKE 7"CSG 10"CSG GAS INJ METER WELL S PSI F BEAN PSI.,. PSI TEMP HCF TOTAL SI/HR REMARK 3 . P ~ ~so ~ Jo~ ~o ~o .- , t) ~ )~o 2~ lloO 3~o /ff ~ I~~ q~ ~ /3~ ~ ~ il 3 ~o TOTAL ~ ~ ~ ,. MAXIMUM WELL I Z ALLOWABLE INJECTION WELLSTATUS NO. N O/ , J N ~ ~u CHART TOTAL TOTAL E TEMP CHOKE 7"CSG 10"CSG METER CALC INJ INJ WELL ro..~ ~ . F BEAN PSI PSI TOTAL MMSCF BBLS MMSCF SI/HR DRILL SITE PROD TEST PROD TEST BATH BLANKET RUN TIME HEATER TEMP TEMP PSI PSI TEMP GAS PSI CHEMICALS TYP"E GAL.'DAY COMMENTS: OPERATORS SIGNATURE; TS Z PRODUCTION WELL STATUS GAS LIFT STATUS WELL NO. A O T N U E FTP TEMP CHOKE 7"CSG IO"CSG GAS INJ METER WELL S PSI F BEAN PSI PSI TEMP HCF TOTAL SI/HR REMARK i ~ T b ~zo 17 / loss q~ ¢ 1.33 TOTAL MAXIMUM WELL I ~ ALLOWABLE~ INJECTION WELLSTATUS NO. N J N IoN~ ....~u~ CHART TOTAL TOTAL E TEMPCHOKE 7"CSG 10"CsG METER CALC INJ INJ WELL F BEAN PSI PSI TOTAL MMSCF BBLS MMSCF SI/HR .2q~ ~ ~~ - _~so ~ o ~ ~ oo~ -~ GAS CORR FACTOR = ¢0~ HEADER PRESS = TOTAL FOR O.S. DRILL SITE PROD TEST PROD TEST BATH BLANKET RUN TIME HEATER TEMP TEMP PSI PSI TEMP GAS PSI COMMENTS: CHEMICALS TYPE GAL/DAY ~, 02-01-87 I~__.5 T-6597737 NSK ARCO Alaska, Inc. I:)RILL$1TE STATUS REPORT OATE: I-~ t-~.,~ _TIME: FTP TEMP CHOKE 7"CSG 10"CSG GAS INJ METER ~iiFHL~ PSI F BEAN PSI ,PSI TEMP HCF TOTAL REMARK ,, . . . . - ..... , .......... . . . , ....... ...... ~ . , _ --.- , ,., TOTAL. WELL I Z MAXIMUM INJECTION WELL STATUS "O. N O ALLOWABLE J ~ ~ 1 C,AR, TO~i'L' TOTAL TEMPICHOKE ?" CSG :10" CSG METER CALC INJ INJ WELL F BEAN PSI PSi TOTAL MMSCF BBLS MMSCF SI/HR ...... , ~ ........ ~ '' ~,~S,C?RR FACTOR = ,,.. Il · ~.E HEADER PRESS = ~ ~ TOTAL FOR D.S. -. , . . DRI~'I~Sl;i;E .... 15ROD TEST PR6C) TEST : BATH BL,~h~KET RUN TIME HEATER TEMP TEMP PS1 PS1 TEMP GAS PSi ..~ ~ 3~ Jb~ .!qo Z~ zo .,zq ,.o~ ~o I~0 ~0 .1~o .. CHEMICALS TYPE GAL/DAY OPERATORS SIGNATURE: COM M ENTS: i STATE OF ALASKA ALASK¥~-OIL AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other . Name of Operator ARCO Alaska, ]:nc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 744' FSL, 806' FEL, Sec. 7, T12N, RgE, UM At top of proiJuctive interval 1384' FSL, 1141' FWL, Sec. 8, T12N, RgE, UM At_effective depth 1431' FSL, 1266' FWL, Sec. 8, T]2N, RgE, UM At total depth 1446' FSL, 1316' FWL, Sec. 8, T12N: RgE: UM 11. Present well condition summary Total depth: measured 7000' ND feet true vertical 6397' MD feet 5. Datum elevation (DF or KB) RKB 72 6. Unit or Property name Kuparuk River Unit 7, Well number 3A-10 8. Permit number Permit #85-237 9, APl number 5o-- 029-21457 10. Pool KuparlJk Riw~- flil Pool Plugs (measured)None feet Effective depth: measured 6885' MD feet true vertical 6294' MD feet Casing Length Size Structural 107' 16" Conductor Surface 3212' 9-5/8" x x x ;t~xt~l~'l~lt e Production xxxk-krxeXxxxx Perforation depth: 6975' 7" Junk (measured) None Cemented 195 SX ASII 1200 SX ASII & 300.SX Class G 475 SX Class G & 175 SX AS 1 measured 6658'-6628' MD true vertica16092'-6065' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, 6.4 lb/ft, Tail @ 6524' MD Packers and SSSV (type and measured depth) Brown HB Ca 6452'; Baker FVI fa 12.Attachments Description summary of proposal Measured depth ~ue Vertical depth 107' HD 107' TVD 3212' HD 3142' TVD 6975' MD 6375' TVD Detailed operations program [] BOP sketch [] Convert well from oil producer to water injectnr 13. Estimated date for commencing operation January 10, 1987 14. If proposal was verbally approved Name of approver /('//1,. ~/. A',z,,~F'/4/ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /'f.,~ o.,t .~_.2 ~,..~..~//~..tx.~.¢.-~ Title Sr. 0perations Engineer Commission Use Only Da~2/23/86 Conditions of approval Notify commission so representative may witness I Approval No. ,,~ [] Plug integrity [] BOP Test [] Location clearance t ,,._ / ~¢ ;2._.:,, byordero¢ Commissioner the commission Date Approved by L~.f_...~"~l[ ¢,gc"i ,,.'...,,??.; ,-' .: .~? Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Alaska, inc. Post Office Bo~ ~0360 Anchorage, AI~.~...~ 99510-0360 Telephone 907 276 1215 October 31, 1986 RETURN TO' ARCO ALASKA, INC. ATTN' Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5805 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. £ 8~. Final Prints- '-.3 ~1A-8 CET/CEL 1-03-86 ..~~1H-4 CET/CEL 12-21-85 ~-1R-2 CET/CEL 10-22-85 "~ ',.vlR-3 CET/CEL 10-09-85 ~ ...~-3A- 10 CET/CEL 12-15-85 ~ --~C- 14 CET/CEL 10-30-85 "-.. -'-~. 3F-2 CET/CEL 10-17-85 ~ ~.~ .- 3J'~2 CET/CEL 12-17-85 '"~-.5 --~_3J-3 CET/CEL 10-05-85 -~ ~ _3J-7 CET/CEL 10-19-85 ~ - 6300 Run =1 5600' ~ - 7521 Run =1 4800' .Run #3 8490' - 8830 ~ - 7406 Run =2 6800' Run #1 5496' - 6870 Run #1 5350' - 8342 Run #1 5925' - 7726 Run #2 8595' - 9110 Run #1 6624' - 8367 Run #1 5350' - 7527 Receipt Acknowledged' Distribution' '~tate .of Alas~ BPAE Chevron Mobi 1 NSK Drilling Vault(1 film) SAPC Union ·. ARCO Aiaskt, inc. is a Subsidiary ot AtlanticRichlieiclCompany STATE OF ALASKA ALASKA-O-i'L AND GAS CONSERVATION ~M'MISSION -. WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL []XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-237 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 5o- 029-21457 4. Location of well at surface 9. Unit or Lease Name 744' FSL, 806' FEL, Sec.7, T12N, R9E, UPI Kuparuk River Unit At Top Producing Interval 10. Well Number 1384' FSL, 1141' FWL, Sec.8, T12N, R9E, UM 3A-10 At Total Depth 11. Field and Pool 1446' FSL, 1316' FWL, Sec.8, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 72' RKB ADL 25631 ALK 2564 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 11/01/85 1 1/09/85 11/10/85* N/A feet MS L 1 17. Total Depth (MD+TVD) 18. PIugBackDepth(MD+l-VD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 7000 'MD ,6397 'TVD 6885 'MD ,6294 'TVD YESI~ NO [] 1821 feetMDI 1550' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/CNL/Cal, FDC, CET, GCT · 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 107' 24" 195 sx AS II 9-5/8" 36.0# J-55 Surf 3212' 12-1/¥ 1200 sx AS Ill & 300 ,,x Class G 7" 26.0# J-55 Surf 6975' 8-1/2" 475 sx Class G & 175 ,,x AS I 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) 6658' - 6628' w/4 spf, 90° phasing 2-7/8" 6524' 6452' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Add~;ndum, dated 2/27/86. 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 GAS-OIL RATIO TEST PERIOD II~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE ~P' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED APR0 1986 ~ 0il & Gas Cons. ~mmission Anchorage J Form 10-407 * NOTE: Tubing was run and the well perforated 1/7/86. GRU1/WC08 Submit induplicate ~ Rev. 7-1-80 CONTINUED ON REVERSE SIDE I! 29. NAME Top Kuparuk ¢ Base Kuparuk ¢ Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH --- __ 6029' 6143' 30. GOR, and time of each Not present Not present 6588' 6716' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravitv, 3hase. N/A 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed__~~/~)~--- ~~ Title Associate Engineer Da,e 3-~1-~ 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: tf this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" Form 10-407 ADDENDUM WELL: 11/18/85 2/01/86 3A-10 Arctic Pak w/175 sx AS I. Begin frac @ 1830 hrs, 2/1/86. AFE AK0324 Frac Kuparuk "A" Sand perfs 6628'-6658' in 7 stages per 1/30/86 procedure using gelled diesel, 5% Musol, 100 mesh & 20/40 mesh sand. Press'd ann to 2500 psi w/diesel. Tst ins to 7800 psi. Stage 1: Pmp'd 45 bbls 5% Musol/diesel spear @ 3.5/5.6 BPM w/final pressure of 2710 psi. Stage 2: 50 bbls gelled diesel pre-pad @ 17 BPM w/final pressure of 6190 psi. Stage 3: 19 bbls gelled diesel w/1 ppg 100 mesh @ 20 BPM w/final pressure of 4330 psi. Stage 4: 55 bbls gelled diesel pad @ 20 BPM w/final pressure of 4170 psi. Stage 5: 23 bbls gelled diesel w/3 ppg 20/40 mesh @ 20 BPM w/final pressure of 4190 psi. Stage 6: 38 bbls gelled diesel w/8 ppg 20/40 mesh @ 20 BPM w/final pressure of 4830 psi. Stage 7: 40 bbls gelled diesel @ 20 BPM w/final pressure of 5250 psi. Job underflushed by 2 bbls. Pmp'd 756# 100 mesh, 13,120# 20/40 mesh in formation leaving ±490# 20/40 mesh prop below tbg tail. Load to recover 264 bbls of diesel. Job complete @ 2115 hrs, 2/1/86. Drilling S~perintendent z Dat~e ARCO Alaska, Inc. = Post Office B6'~'-i00360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 6, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are intent notices on the following Kuparuk River Field' Well Action Anticipated Start Date 3A-10 Perforate March 15, 1986 3A-11 Perforate March 16, 1986 3A-12 Perforate March 17, 1986 If you have any questions, please call me at 265-6840. Sincerely, wells G. B.VSmallwood Senior Operations Engineer GBS'pg'O014 Attachments cc' File KOE1.4-9 ARCO A aska. Inc. is a Subsidiary of AtlanticRichfieldCompany .._. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C0~;)[MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL []X OTHER [] 2. Name of Operator ARCO Alaska, Inc 3. Address P. 0. Box 100360, gnchorage, Alaska 99510 4. Location of Well SURFACE LOCATION: 744' FSL, 807' FEL, SEC. 7, T12N, R9E, LN 5. Elevation in feet (indicate KB, DF, etc.) 72' (RKB) 12. 7. Permit No. 85-237 8. APl Number 50- 029-21457 9. Unit or Lease Name KUPARUK RTVER IIN_TT 10. Well Number 3A-J0 11. Field and Pool KUPARUK RIVER FIELD I 6. Lease Designation and Serial No. KUPARUK RIVER OIL POOL /tr~_ ?~31_~ ALK 25~ 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 [] (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). It is proposed that the "A" Sand be perforated for production. Procedures call for the well to be perforated through tubing with 4 SPF. Proposed Interval (1~)' 6600 - 6618 ANTICIPATED START DATE: March 15, 1986 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ f_/~..~"~ TitleKuparuk Th. ,p~.e b~,ow ~'Commi,,io..~. S~. ~rations Eng,. Conditions of Approval, if any: Approved by Approved Copy Returrted Fly Order of COMMISSIONfiR the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 ARCO Alaska, Inc. Pos! OffiCe 6,... 100360 Anchorage, Alaska' 99510-0360 Telephone 907 276 1215 February 19, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are the Well Completion Reports and gyroscopic surveys for the following wells' : 3A-10 3A-11 3C-14 3C-15 3C-16 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L150 Enclosures STATE OF ALASKA ALASK~'t~L AND GAS CONSERVATION ~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. 85-237 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21457 4. Location of well at surface 9. Unit or Lease Name 744' FSL, 806' FEL, $ec.7, T12N, R9E, UM ~~ Kuparuk River Unit At Top Producing Interval VERIFIEn 10. Well Number 1384' FSL, 1141' FWL, Sec.8, T12N, RgE, UM '~- . 3A-10 , Surf. At Total Depth /~[ 11. Field and Pool 1446' FSL, 1316' FWL, Sec.8, T12N, R9E, UN B.H..4~ _ Kuparuk River Field _ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 72' RKB ADL 25631 ALK 2564 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 11/01/85 11/09/85 11/10/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 7000 'MD ,6397 'TVD 6885 'MD ,6294 'TVD YES ~( NO []I 1821 feetMD 1.550' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/CNL/Cal, FDC, CET, GCT 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 107' 24" 195 sx AS II 9-5/8" 36.0# J-55 Surf 3212' 12-1/4" 1200 sx AS Ill & 300 ,~ix Class G I 7" 26.0# J-55 Surf 6975' 8-1/2" 475 sx Class G & 175 ¢~x AS I 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) 6658' - 6628' w/4 spf, 90° phasing 2-7/8" 6524' 6452' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 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.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~l~ Flow Tubing Casing Pressure CALCULATED.1~ 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 Form 10-407 * NOTE: Tubing was run and the well perforated 1/7/86. DAM/WC37 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS TRUE VERT. DEPTH MEAS. DEPTH Not present Not present 6588' 6716' 6029' 6143' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase_ N/A 31. LIST OF ATTACH'MENTS Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge __ __~L/~ Associate Engineer Signed__ ~ Title Date 2 -/~:~ -~:~ L~ 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 iniection, 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 suf)plemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 ARCO Alaska, Inc. Post Office Bb~.-i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3A-10 Dear Mr. Chatterton' Enclosed is a copy of the 3A-10 Well History to include with the Well Completion Report, dated 1/31/86. If you have any questions, please call me at 263-4944. Si ncerely, Gruber Associate Engineer JG/tw GRU13/L100 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ~ ~un~. parish or borough IState Alaska I North Slope Borough Alaska Kuparuk River ADL 25631 3A-lO Auth. or W,O. no. ~Title AFE AK0324 I Drill Parker 141 API 50-029-21457 Operator ARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begUnspudded I°at° 11/1/85 IH°ur 1800 hrs. IPr°rstatusifaw'O' Date and depth Complete record for each day reposed as ol 8:~ a.m. 1[/o2/85 thru 11/04/85 [1/05/85 [[/o6/85 11/07/85 11/o8/85 16" @ 107' 2770', (2663'), Rig repair Wt. 9.1, PV 12, YP 13, PH 9.0, WL 19.2, Sol 6 ~ccept rig @ 1200 hrs, 11/1/85. NU diverter sys. S~ud well @ 1800 hfs, 11/1/85. Drl 12¼" hole to 2039', DD to 2770'. Rig repair, circ slowly 15' off btm. 2100', Assumed vertical 2287', 4.2*, N78.5E, 2286.87 TVD, 6.85 VS, 1.58N, 6.67E 2721', 20.4°, NS1.3E, 2709.77 TVD, 96.60 VS, 7.75N, 97.97E 16" @ 107' 2770', (0'), Rig repair Wt. 9.1, PV 13, YP 19, PH 9.0, WL 17.2, Sol 5.8 Rig dn f/repairs. 16" @ 107' 3137', (367'), Drlg 12¼" hole Wt. 9.1, PV 13, YP 18, PH 8.5, WL 17.6, Sol 5.8 Fin rig repairs. DD, drl & surv to 3137'. 2814', 23.6°, NS0.4E, 2796 TVD, 131.25 VS, 13.29N, 132.37E 9-5/8" @ 3212' 3232', (95'), Drlg FC Wt. 8.4, PV 2, YP 1, PH 8.0, WL NC, Sol 1 Drl to 3232', 10 std short trip, C&C, POOH. RU & rn 81 its, 9-5/8", 36#, J-55 HF/ERW BTC csg w/FS @ 3212', FC @ 3130'. Cmt w/1200 sx AS III, followed by 300 sx C1 "G". Displ using rig pmps, bump plug. Good cmt rtns. ND diverter sys. NU & tst BOPE. TIH fo FC, tst csg to 1500 psi. Drl on FC @ 3130'. 9-5/8" @ 3212' 6103', (2871'), Turbine drl Wt. 9.7+, PV 12, YP 8, PH 10, WL 8.8, Sol 10.7 DO FC, cmt, FS + 10' new hole to 3242'. Chg over to Polymer mud. Conduct formation tst to 12.5 ppg EMW. TIH w/turbine, drl to 6103'. 3487', 34.8°, N79E, 3369.37 TVD, 480.40 vS, 79.99N, 476.03E 4494', 32.2°, N72.5E, 4207.04 TVD, 1038.72 VS, 210.47N, 1019.13E 5460', 29.3°, N68.3E, 5038.80 TVD, 1528.41VS, 373.18N, 1482.40E 5835', 29.7°, N63.3E, 5365.18 TVD, 1710.77 VS, 448.88N, 1650.83E The above is correct For form preparation and-dis~rl~tion~' ' -- see Procedures Manual, Sectioff 10, Drilling, Pages 86 and 87. JDate JTitle Drilling Superintendent 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 it space is available. Spudded or W.O. begun Spudded 11 / 1/85 Accounting cost center code District County or Parish State Alaska Alaska North Slope Borough Field Lease or Unit ~Well no. Kuparuk River ADL 25631 I 3A-10 Auth. or W.O. no. T t e AFE AK0324 Drill Parker 141 API 50-029-21457 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Date 11/09/85 thru 11/11/85 Date and depth as of 8:00 a.m, Old TD 2200 hrs. Released rig Classifications (oil, gas, elc.) 0il Producing method Flowing Potential test data 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 l Prior status if a W.O. 1800 hrs. I 7" @ 6975' 7000' TD, 6885' PBTD, (897'), RR -- 10.0 ppg brine wtr in 7" csg to FC @ 6885' Turbine drl to 7000', 20 std short trip, circ hi-vis sweep, TOH. RU Schl, log DIL/SFL/SP/FDC/CNL/CAL f/6994" WLM to 3212', logged to 6300' w/FDC, w/DIL logged to 9-5/8" shoe. RD Schl. TIH, wsh & rm 50' to btm, 20 std short trip, circ hi-vis sweep, TOH. RU & rn 161 its, 7", 26# csg w/FS @ 6975', FC @ 6885'. Cmt w/100 sx C1 "G" w/50/50 flyash/Class G cmt. Tail in w/375 sx C1 "G". Bump plug w/3000 psi. ND BOPE. Displ f/7" csg. Set pack-off & wellhead. Tst pack-off to 3000 psi. RR @ 2200 hrs, 11/10/85. 6368',28.3°, N59.5E, 5831.35 TVD, 1962.09 VS,572.58N,1877.70E 6965',27.5°, N84.3E, 6360.48 TVD, 2235.58 VS,670.80N,2134.44E New TO PB Depth 7000' TD 6885' PBTD Oate 11/10/85 Kind of r g Rotan7 Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature ~ For form preparation and distribution, see Procedures Manual, Section 10, Dritling, Pages 86 and 87. IDate ITitle Drilling Superintendent ARCO Alaska, Inc. Post Office B;~x-q00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 5, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3A-10 Dear Mr. Chatterton: Enclosed is a copy of the 3A-10 Well History (completion details) to include with the Well Completion Report, dated 1/31/86. If you have any questions, please call me at 263-4944. Sincerely, J~. Gruber Associate Engineer JG/tw GRU13/L67 Enclosure 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 Reporl" should be submilled also when operations are suspended for an indefinite or appreciable length of time, On workovers when an official test is not required upon completion, report completion and representative test data. in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District Alaska Field ICounty or Parish Lease or Unit Title North Slope Borough State Kuparuk River Alaska I Well no. ADL 25631 3A-10 Auth. or W.O. no. AFE AK0324 Completion Nordic Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete Date and depth as of 8:00 a.m. AP1 50-029-21457 Old TO Released rig 1/06/86 1/07/86 thru 1108186 2400 hrs. IA.R.Co. W.I. 56.24% Date 1/7/86 Complete record for each day reported Classifications (oil, gas, etc.) 0tl Producing method Flowing Potential tesl data Iotal number of wells (active or inactive) on this, DSt center prior to plugging and I bandonment of this well our I Prior status if a W.O. I O3 15 Moving rig. 7" @ 6975' 6880' WLM PBTD, RR Diesel Accept rig @ 0315 hrs, 1/7/86. ND lower tree, NU & tst BOPE to 3000 psi. RU Schl. Perf w/4" guns, 4 SPF, 90° phasing f/6628'-6658',.RD Schl. RU & rn 2-7/8" tbg w/SSSV @ 1821', SBR @ 6431', HB Pkr @ 6452', "D" Nipple @ 6490'. Press tbg &.ann to 2500 psi. Displ well to diesel. PR @ 2400 hrs, 1/7/86. New TD Date IPB Oepth Kind of rig 6880' (WLM) PBTD 1/7/86 Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature Date Drilling Superintendent For form preparation and ~stribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, RCO Oil and Gas Company Daily Weli'~istory-Final Report Inatructiona: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Filial Rel~orl" should be submitfed 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 si)ace ~s available. Accounting cost center code District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0324 County or Parish Lease or Unil Title North Slope Borough ADL 25631 Completion State Alaska IWell no. 3A-10 Nordic 1 Operator I A.R.Co. W.I. ARCO Alaska, Inc. { 56.24% Spudded or W.O. begun ~Date Complete I 1/7/86 Date and depth Complete record for each day reported as of 8:00 a.m. Old TD 1/06/86 1/07/86 thru 1108186 Released rig 2400 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data AP1 50-029-21457 I otal number of wells (active or inactive) on thisI DSt center prior to plugging and bandonment of this well our I Prior status if a ~W.O. 0315 I Moving rig. 7" @ 6975' 6880' WLM PBTD, RR Diesel Accept ri~ @ 0315 hfs, 1/7/86. ND lower tree, Nil & tst BOPE to 3000 psi. RU Schl. Perf w/4" guns, 4 SPF, 90° phasing f/6628'-6658',,RD Schl. RU & rn 2-7/8" tbg w/SSSV @ 1821', SBR @ 6431', HB Pkr @ 6452', "D" Nipple @ 6490'. Press tbg &-ann to 2500 psi. Displ well to diesel. RR @ 2400 hrs, 1/7/86. RECEIVED New TO Date 1/7/86 PB Depth Kind of rig 6880' (WLM) PBTD Rotary Type completion (single, dual, etc.) Single lOfficial reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature _ Date ITitle 7.~ ~...__....~_~_~_~ t/.,,~../,~"~ I Drilling Superintendent For form preparation and c~tribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc. Post Office BOwel00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3A-10 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 3A-10. The bottomhole location, TVDs, and geologic markers will be submitted when the gyroscopic survey is run. Also, 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. Sincerely, Gruber Associate Engineer JG/tw GRU13/L27 Enclosure RECEIVED FEB 0 4 Oil & Gas Cons. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK~..._~ AND GAS CONSERVATION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-237 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21457 4. Location of well at surface 9. Unit or Lease Name 744' FSL, 807' FEL, Sec.7, T12N, R9E, UN,.-' Kuparuk River Unit // At Top Producing Interval// 10. Well Number To be submitted when gyro is run. /// 3A-10 At Total Depth 11. Field and Pool To be submitted when gyro is run. l/ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 72' RKB ADL 25631 ALK 2564 '1'2. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore. 116. No. of Completions 11/01/85 11/09/85 11/10/85* N/A feet MSLI 1 17. Total Depth (MD+TVD) 7000 'MD 18. Plug Back Depth (MD+TVD) 6885 'MD YES19' Directional Survey[] NO [Z~X I20' Depth where sssv set1821 feet MD I21' Thickness °f Permafr°st1550' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/SP/CNL/Cal, FDC ~3. 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 107' 24" 195 sx AS II 9-5/8" 36.0# J-55 Surf 5212' 12-1/4" 1200 sx AS III & 300 s~ Class G 7" 26.0# J-55 Surf 6975' 8-1/2" 475 sx Class G & 175 s~ AS I 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) 6658' - 6628' w/4 spf, 90° phasing 2-7/8" 6524' 6452' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "Ir 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE F E B 0 4 ]~S~ Alas,ka 0il & Oas Cons, u,J,,-~missi0n Anchorage Form 10-407 * NOTE: Tubing was run and the well perforated 1/7/86. TEMP3/WC63 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ' " ' ' FORMATIONTES-IzS- ':' .... ' :' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A N/A 31. LIST OF ATTACHMENTS Addendum (dated 12/1'1/85) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~)~]]_~ Title Associate Engineer Date /'3/-~ # - INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion rePort and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas 'injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 3A-10 Arctic Pak w/175 sx AS I. RECEIVED FEB 0 4 :¢ Oil & Gas Cons. Commission Drillin~ Superintendent SUB-$URFACE DIRECTIONAL ~URVEY r'~UIDANCE [~ONTINUOUS {-~'] OOL Company Well Name , 'ARCO ALASKA INCORPORATED i i WELL 3A-10 (744' FSL, 806' FEL, S7, T12N, R9E) ii i Field/Location ~UPA~, NORT~ SLOPE, ALASKA II Job Reference No. 71178 Loa{3ed By_:. WEST Date 26-JAN-1986 Computed By: HALSTEAD $CT O!~ECTi]N~L SU~V=Y 'UST3~ER LISTING ~RC] ~LaSK~, lq'. 3A-lO KUP~q'JK METHg]$ O= COqPUT~TIO~ TOOL LOC~TI]N: T~NSENTI~L- INTERPOLATI]N: LINEAR VERTICAL SSCTI3N: tgRIZ. 2IST. N2RT~ SLJP~,~L~SK~ SURVZY 3~TE: 12-16-~5 EN,SINEEq: W=ST ~VE~&3=_] DEYZ'aTI2N ~N:3 ~R3J.'_-CTED ,'"'JXlTg ~ T~RC,::T ~Z!M'JTH a Z I '.I U T :] F 74 51 "11!q =~ST 33~UT~,TI3N D~I'E: Z6-J~N-3$ ~...;=' I &R~D ~LASKA, I~C 3&-10 KJ~fiRJK NORTH SLOPE,fiL~S<~ =T INT:ROOL~T:3 VALUES :OR EVE~ 100 TRUE SJB-S:A 4EASURE3 VERTICAL V:RTiCAL DEPTH DEPTH DEPTH 0.00 0.00 -72.00 1DO.OD 100.00 23.00 '200.03 200.00 128.00 300.03 300.00 2Z8.00 400.03 400.D0 32~.00 500.00 500.00 42~.00 500.00 5~9.~9 527.99 700.09 599.99 527.99 800.00 799.99 727.9'9 900.00 899.99 1000.30 999.98 927.98 1~00.00 1099.98 1027.9~ 1~00.00 1199.~8 1127.98 1300,00 1299.9~ ~227.98 1400.00 1399.~8 1327.98 1~00.0~ 1499.98 1427.9a 1600.03 1599.97 1527.97 1700.00 1699.97 1627.97 1~00.00 1799.97 1727.97 l~DO.O0 1899.~5 1827.95 2000.00 1999.94 1927.94 2100.00 2099.B7 2027.87 2200.00 2199.86 2127.85 2300.00 2239.58 2227.55 2400.0~ 2399~1 2327.01 2~00.00 2~97.39 2425.39 2500.00 2594.27 2522.27 2700.00 2689,,4 2617.4~ 2,00.00 Z78:2..~ 2713.37 2~00.00 Z8~3, 2801.28 3000.00 2889.89 3100.00 2975.27 3200.00 i:2~O~ 3050.0~ 3300.00 321~ :35 31~2.35 3~00.00 3296,56 3224.56 3500.00 3378.77 3305.77 3500.00 3~60.90 338B.90 3790.00 35~3.33 3471.03 3900.00 3625.43 3553.43 3~0.30 3708.15 3535,15 CDJ~SE DEVI~TIO~ AZIMUT~ ];G ~IN DES MI~ 0 N 3 3 3 N 225 13 S 57 13 S 19 1'7 S 12 42 16 S 11 ~1 25 S 12 ~3 31 S ~ 42 S 23 17 S 19 37 0 30 S 15 48 0 Z4 S 9 4 0 15 S 17 1Z 0 i0 S 45 40 0 7 S 62 43 0 8 N 25 41 0 1~ N 50 15 0 21 N 3 23 0 44 M 11 41 0 ~7 N 2~ 27 VEqTIC&L SECTION _~_ 0.00 -0.25 -3.51 -0.75 -0.7~ - O · 95 -1.26 -1.23 -1.30 -1.72 -2.01 -2.11 -2.44 -2.49 -2.37 -2.57 -2.77 -2.53 -2.60 -4.13 -7.09 -7.17 -1.41 9.35 21.1! 5! · 17 91.53 11,9.29 ! 59. ,35 205.18 255.52 311.03 357.'71 538.25 5.95.21 551.77 707.~5 335L=3 SEVERITY DES/IOO 3.00 0.2"3 3.23 3.15 0.1~ 3.15 .}.33 .3.0) 0.13 0.15 0.35 0 · Z 2 0.15 O.2D 0.28 3.12 0.73 3.37 0.83 2.57 ~ iF_ 3.55 3.95 3.71 3.27 3.1~+ 2.75 1.5~ O. OZ 0.1~ 0 · 19 3.17 0.35 0.43 0.72 5. 5. 5. 6. 5. 5. 5. 4. 3. Z . 1. 1. O. O. O. 1. 5. 12. 21. 32. 67. 9 0 · 101. 112. 135. ] 3:PTW 3'JL A.} T C 33R ,3 FEET 16 ~,,~ 5~ 51 ~? 79 34' ,9'? ~7 39 17 74 u5 3.57 0.53 .-., u.59 O.3~ 3.~Z 0.72 I. 0 0 1,25 1.33 1.75 ~5 77 51 70 a9 ,5. ~5 7. :33 1.2~ 10.09 27.92 52.55 82.37 119.19 (*3 97 ~2 :,37 11 37 77 29 "33 204,70 253.71 307.0B 362.70 418.47 ~74.28 530.22 5~$.11 541.61 5~.57 ,iq'u' d 3:3 4. 51,3 ,5 ~ 7 5.33 5.52 5 · Z5 4.9 3 3.~7 4.41 7.0:~ 7. 18 i.4.7 2~.92 52. 53 161.23 A~CO ~LAS,(~, I~C. 3~-10 KJPARJ~ ND~TM SLJPE,fiL~SK4 C24PUT~TIDN O&TE: 25-J~N-~5 INTErPOLaTED V4LJES :OR :VEN 100 =E~T TRUE SJB-S:& MEASURED VERTICAL V:RTZ'4L ]EPT4 DEDTH DEPTH 4000.00 3791.24 3719.24 4100.3D 3874.7~ 3502.78 4200.00 395B.?~ 3885.74 4300.00 4042.94 3973.94 4400.03 ~127.38 ~055.38 4500.00 4212.}7 ~14~,07 4500.03 4295.98 ~22~.98 4700.00 ~382.05 Q310.OB 4BOO.OD 4457.53 ~395.53 4900.00 ~553.51 ~481.51 5000.00 ~539.88 ~567.B8 5100,00 4726.74 ~554.7~ 5200.00 ~813,B$ ~741.8B 5300.00 ~901.~9 ~82~.09 5400.00 ~988,58 4915.58 5500.00 5075.~ 5600.00 5153,11 5091,11 5700.00 5250.~4 5178.04 5800.00 533T.02 5265.02 5900.00 542~,11 5352,11 6000.00 5511.27 5439.27 6100.33 5598.50 5525.50 6200.00 5685,86 5613.86 6300,00 5773,70 5701,70 6%00,00 5861,82 5789.82 6500.00 5950,44 6500.00 6039,77 5957.77 6700.00 6128,83 5055.83 6800.00 ~218,~6 5145.06 6900.00 $30:7~,35 5235,35 7000,00 COJRS: ~ ._ ~ V:RTI AL 3EVI&TI]N AZIMJTq SECTION SEVaqITY ]EG qlN DEG MIq ~EET 953/100 33 37 N 75 9 E 763.46 1.23 33 4 N 74 25 ,_~ B1~.4£ 0.71 ~ ~7~.73 32 ~4 N 73 35 : ., 32 33 N 73 ~ = 925.65 0.3~ 32 14 N ?Z 41 5 9B9.20 31 39 N 72 9 E 1033.33 3.33 31 ~7 N 71 42 E 1085.3~ 3,40 31 2B N 71 5 = 113~,50 31 5 N 70 45 : 1190,33 ],73 30 22 N 70 25 £ 124!,24 30 7 N 70 13 E 1291.50 0.55 29 2~ N 59 49 E 1340.~6 3.3~ 2'9 22 N 5) ? E 13~9,71 D.3'3 29 3 N 68 24 E 143~.37 3,75 29 2 N 5~ 18 £ 1486.47 29 15 N 67 32 E 153~,89 29 27 N 65 25 ~ 1583,33 0,87 29 ]9 N 55 1 ~ 1532,15 3,72 29 27 N 63 50 E 16~0,68 0,55 29 1.1 N 5! 2~ E 1728,~0 29 20 N 51 8 : 1775,55 0.45 29 14 N 50 7 E 1A23.94 3.37 28 53 N 60 15 E 1,371,01 0.13 28 15 N 59 2~ : 1917,21 3.55 25 3 N 59 13 :.. 1952.74 ~.71 26 54 N $1 25 2007.43 3.05 26 54 N 65 25 = 2'~3!,56 27 5 N 57 13 : ~095.51 t.45 26 33 N 72 2~ ~ 2141,42 3.52 26 ~B N 73 53 ~ 2.186,44 5324,60 2,5 ~8 N 73 53 E 2231.54 D.OJ :ES 14~ .32 152.35 177. ~0 !'92..~3 23~ ,3~ 22~.33 _~ 40. ~ '~ 257.7,~ 27~.75 Z 31,7 ] 305.5~ 325.56 342.75 3~3.5! B7B.42 396.70 ~15.73 ~36,04 &57.36 ~79. &8 502.57 5!5.71 550. ~0 57'~.92 52 Z. 3 9 5~2 I~ 56 O. 51 575. ~8 5 .~ 9,07 701,5~ ~JL~R 3JTq ='AST/N 'ST FEET F::" 1254.42 E 1ZSi. ~4 1301.00 E 13~.1.ii 1345..~5 E 13~'g.~]7 13~2.55 E 1~32,45 1437, 53 E 1~85. 51 1~82,75 E 153~, 20 1527,7~ E 15~3.33 1572,B5 5 1632.18 1617,35 5 1580,7{ 1661,23 ~ 1729,04 1704.41 ~ 1773.9~ N 73 '3':,. ~.. 1747.JD E 1{24..57 ~.~ }'3 13 : 17~9.2£ E 1.372.11 'J T2 ~3,3 '- 1833.5'3 E I '-~i ~.7 ~ ~ 72 3~ 1871.22 :' I ~3,~. 7.~ '..~z2 !4/ 1951.57 ; 2554.4~ W T1 ~7 ~ 1993.16 'm 22~9.F5 q 7l 39 ii 2035,37 E 214~,~4' q 71 35 ~ 2078,59 ~ 2139,3B ~ 7l 39 Z N 2121.93 E 223~.~1 N 7 1 '4 Z E CD~PUTaTI3~ Dal'5: 26-J~N-35 o:~:: '3 3~-10 KJPARJK NDRTH SLDOE,AL~$K~ TRUE ~E~SURED VERTICAL DEPTH OEPTH 0.00 0.00 1000.00 999.98 2000.00 1999.94 3000.00 Z961.~9 4000.00 ~Tgl. Z4 5D)O.OO ~639.~ 6000.09 5511.Z7 7000.00 5396.50 ~NT=RPOL~TEO VALJES =OR =VEN lOOD FE':T 3= $J~-SEA CDURSE VERTICAL 29G' EG VERTI'AL ~EVI~TI3~ AZIMUTfl SECTION SEVERITY DEPTH ];G 4IN DEG MIN FEET 0E$/103 -71.00 1997.~4 2889.89 3?lg.g4 %567.88 543~.27 $32~.60 0 0 N 0 0 E 0.00 O.OO 0 30 S 15 ~ W -1.72 0.15 1 50 N 30 lB W -~.13 D.D3 28 53 N ?6 ~ 5 205.18 2.73 33 37 N 76 ~ '~ 753.46 1.23 30 ? N ?0 13 = 1291.50 3.55 Z9 20 N 61 8 E 1776.55 0.45 26 ~8 N 7'3 53 E 2231.5~ 3.00 R--TAN ND~TH/ <"LLY 5U'S-liq3 --2 -}::PT 3~JL&R SDUT~ T CQ]ROIqAT:S ~]RIZ. :~ST/W:S/ '~ST F~T ='EET 0.30 ~.45 S 3.57 W ~.5'3 2.58 S 3.53 W 4.4i -.:.~0 143.32 N 750.7~ ~ 765.30 30B.5~ N 125~.41 : i!91.~,~ 502.57 '~ 1704.~1 f 1775. g9 701.59 "~ 2121.93 ': 2234.~1 ~Z~qUTH '~ 3 0 -_' '~m'-}3 52 : ',~ 75 1 '2~, ~ 73 :3,4 .:_ CgMPUTATID~ DATE: 26-JAN-B5 p~3{ ~ ARCO ALASKA, I~C. 3~-10 KJP~Rj< NDRTH SLDPE,~L~SK6 INT=RPOL~TED VALUES FOR =VEN lOS :EET 0= TRUE SJB-S;& ME~SURE3 V:RTIC~L VERTI'AL DEPTH DEPTt DEPTH 0.00 0.20 -72.00 72.02 72.00 0.00 172.03 172.00 100.00 272.D0 272.D0 Z03.0D 3?2.3.3 372.00 300.00 ~72.33 472.00 ~03.00 572.01 572.00 503.00 572.31 672.00 503.00 772.01 772.00 703.00 872.31 872.00 803.00 ~72.02 972.a0 900.00 1012.02 1072.00 lOOD.O0 1172.02 1172.00 1100.00 1272.02 1272.00 1209.00 1372.32 1372.00 1303.00 1~72.02 1472.00 1403.00 1572.03 1572.90 1500.00 1572.03 1672.00 150.3.00 1772.03 1772.00 1700.00 1~72.0~ 1872.00 180~.00 1972.05 1972.00 1902.00 2372.11 2072.00 2000.00 2172.13 2172.00 2100.00 2272.24 2272.00 220~.00 2372.73 2~72.00 2300.00 2~74.37 2472.00 2400.00 2576.83 2572-00 2500.00 2581.54 2672-00 2500.00 27B8.70 ~'~,00 2709.00 3372.00 3472.00 3572.00 3572.00 3772.00 3872.00 3011.55 3128.02 3248.49 3370.12 3491.76 3513.53 3735.1i~ 3856.3~ 3976.89 4096.63 CDJRSE VERTICAL DOGLEG 2~VI~TI]N AZIMUTH S:CTIDN SEVERIT~ ]EG ~Iq 053 MIq FEET ~EG/103 0 0 N 0 0 E 9.00 0.00 0 5 N 29 52 E -0.10 2.19 0 10 N 72 g W -0.17 3.27 0 13 S 35 41 W -0.53 0 17 S 3 5~+ E -0.73 .3.17 0 18 S 15 49 £ -0.73 3.11 0 !2 S 12 1~ ~ -0.'35 0.27 0 31 S 3 4~+ ,~ -1.1~ 3.22 0 25 S 23 42 5 -1.25 0.23 0 17 S 9 56 W -1.23 3.2~ 0 29 S lB 15 'a -1.59 ;3.21 0 29 S 1 23 =. -1.97 0 16 S ~ 25 W -2.05 0.32 0 14 S 3~. 33 W -2.35 3.27 0 8 S 32 15 E -2.52 9.33 0 5 N 11 47 E -2.37 3.42 0 13 q 61 15 W -2.49 O.I~ 0 16 N 32 4~ W -2.76 0.50 0 ~+3 N 2. 17 W -2.58 2.25 0 ~,8 N ZO 53 '~ -2.55 ,3.35 1 1 0 4 7 11 15 19 22 26 30 N 75 5 W -3.38 1.65 57 N 75 23 '~ -5.32 0.57 34 q 55 5:) E -7.,5~ 3.73 7 q 33 52 5 -3.5~. 1.9,3 18 N ~5 O : ) S ~9 55 : 22.03 %.I~ 14 N 'B5 23 E 44.90 '3.91 5 N ,~0 50 ~ 75.54 3.9~ i2 N 79 2~ E 113.~3 3.25 6 N 7~ 53 E 159.25 3.1~ 2203.00 3000.00 3100.00 3200.00 3300.00 3403.00 3500.00 3600.00 3700.00 3800.00 29 32 34 34 34 34 34 34 33 33 12 N 75 17 E 211.75 2.:31 28 N 77 35 E 271.40 3.0~ 37 N 78 23 : 339.45 0.3~ %2 N 78 25 ~ 407,57 ].25 ~4 N 78 37 : ~76.55 O. 23 %9 N 78 31_~ 545.99 0.17 33 N 78 22 ~ 615.16 3.23 ~ N 7~ ~ 5 583,42 0.50 = 750.65 1.03 42 N. 75 37 : 5 N 7~ 27 ~ 915.51 9.70 3a, T" ] = SJF<V :Y: 1.1-!5-'!5 q:LLY 5,JSHi'~3 'L"~T'~'.~' q:~TAqSULAq CD]q]I'4~T-S H]RiZ. - ~IST N]qT'H/S~UTq E&.5T/,~:ST ~. . FEET FEET~ ='::T 0.30 ~ O.OO E O.O0 3.02 ~ 3.11 ~ 0.11 0.15 ~ O.Z2 W 0.26 ,3.3~ '~ 3.55 W 3.55 0.43 S 0.55 0.91 S 3.51 W !.05 I.~1 S 0.5'3 w 1.50 1.21 5 3.0~ w !.30 3.37 S 0.47 W 3.11 3.55 S 0.Z~ W 3.55 ~.22 3 3.50 W ~.,'~5 5.12 S 0.65 ~ 5.16 5.75 S 3.57 W 5.77 5.17 S 0.77 W 5.22 5.~2 S C.~37 W 5.~4 S 0.?1 ~ 5.48 6.22 S 0.90 W 6.29 .5.9,~ S 1.25 '~ 5.11 5.10 S 1.33 ',~ 5.!5 3.~1 S 1.~1 W 4.14 2.74 S 2.75 W 3.39 2.35 S 5.03 W 5.'3~ 1.55 S 7.53 ~J 7. 5 ~ !.01 S 3.:~3 W :5. 5:~ 0.1'.~ 't 6.37 L 5. ~7 !.1~ q ~6.20 :. 45.21 ~,.~'9 ~q 75.93 = 77.0'~ 11 55 q 11~.80 g 11~ ,~ 2!.39 q 159.19 ! 150.52 34.24 q 210.11 E 212.,~3 47.72 ~ 268.25 E 272.4.~ ,51.51 N 333.98 ~. 33'~.50 75.'43 ,3:').1;3 M 469,67 5 q7,,3.~5 1'32,90 ~ 537.79 E 547.5; 115.19 ~ 605.89 ~ 515.q4 13J.55 ~'~ 572.65 E 535.22 145.~3 ~ 738.3~ E 752.30 161.95 O:O~RTUq: & Zi ~"JTq ARCO &L~SK~, ZNC. 3~-10 KJP~RJq ND]TH SLgmE,~L&Sq~ T ME&SUREO VER DEPTq D 4215.75 39 4334.45 40 4452.73 41 4570.50 4Z 4588.1B 43 4805.23 44 4921.42 45 5D37.11 46 5151.93 47 5255.58 48 5381.0~ 49 5¢95.54 50 5510.20 51 5725,28 52 5840.18 53 5954.94 54 6059.$~ 55 6~84.~$ 55 62~8.~? 57 5~11.5~ 58 6524.11 6536.15 67~8.44 6950.39 7000.00 rNT~.:~POL~.TE3 Va. LJSS mgR :VE~ 103 :~:T 3: RUE SJB-SEA TIC~L VSRTi-AL rgJRS'-,~ V~TICAL_ 00,3' :G ]EVi&Ti,]~ &Z!MUTH 5=CTION SEVE~IT~ DEG qlN DES MI~ FEST J:31109 72.00 3903.00 72.00 4000.00 72.00 ~103.00 72.30 4200.00 72.00 4309.00 72.00 4400.00 72.00 4500.00 72.20 72.00 72.00 32 %1 N 73 31 5 ~81.25 9.4~ 32 27 N 72 59 -_ 945.15 0.33 32 7 N 72 25 : 100B.25 0.50 31 50 N 71 53 : 1070.50 0.2~ 31 31 N 71 7 = 1132.35 D.73 31 3 N 70 45 E 1193.03 O.7~ 30 18 N 70 ?~ E 1252.02 0.20 29 ~7 N 70 ~ 5 1310.03 1.22 29 ~12 N 6~ 2~ 5 1355.23 S.~3 29 15 N 6~ 35 ~ 1422.22 ~.67 72.00 ~909.00 72.00 5000.00 72.00 5100.00 72.00 5200.00 72.00 5303.00 72.00 540~.00 72.00 5500.00 72.00 5600.00 72.00 5700.00 72.00 5800.00 28 5'9 N 68 lB 5 1477.33 0.27 29 15 N 57 5~ : 1532.72 0.59 29 51 N 66 15 E 158B.30 0.93 29 37 N 54 4? : 1.5~,48 3.7~ 29 16 N 53 22 ~ 1700.05 0.61 29 ?1 N 61 ~3 5 1755.05 0.73 29 15 N 60 I~ E 1809.50 0.55 28 58 N 50 15 '~ 1853.$0 28 15 N 59 29 ~ 1915.33 0.59 27 57 N 59 1~ E 1957.95 5972.00 5900.00 $072.00 5000.00 5172.00 510D.OD 6272.00 5200.00 6372.00 5300.00 $396.~0 532~.50 26 ~3 N 52 42 E 2017.98 2.73 27 0 N 65 57 E 2067.74 3.55 26 50 N 69 12 r- 211~.34 26 4~ N 73 53 =' ~_168.'57 0.00 26 ~8 N 73 53 ~ ~21~.11 O.Og - ~3~ .54 0.03 "i:aT ' 2: SJ;'V '¥: S~JTH =2$T/~-ST DIST. T F£~T =::r 179. 19,5. !35. 255. ZTS. 514. ~0 ~ g54.30 - 532.{1 23 q F25.52 E 745.31 15 W 1045.21 ~2 127!.55 7~ ~ 1103. 35 ~: 1133.11 5~ N 1161.36 ~ I193.52 99 N 1271.39 5 131~.31 ~1 q 1324.33 ~ 1365.43 55 N 1377.44 5 1~2£.34 ?75. 395. 117. 441, ~gZ. 519, 347, 574, }Z k) 14Z~,93 E 1~77,37 35 :,t 1480.73 5 1532,73 /'5, "4 153Z,3S 5 1533.30 3~ kl 138~,I,B ~ 1344,52 14 q 1635,~6 ~ 1790,21 0'~ q 1583.0Z E 1755.40 33 N 173~.I~ 5 1~10.24 13 N 1732,57 5 1~.54.54 35 ~ 1829,32 E 1~17,~4 73 N 1.~75.8~ ~ 1970.D4 527. 548. 568. 70! . ~+0 N 1920.77 5 2023.54 .~7 N 1955,51 7! ,N 2013.55 E 21£1.69 11 N 2061,43 14 N 2109,99 f 2222.a5 59 q 2121.93 71.'3) :T ": :&RTU~': AZ ' ~ 71 '54 'q 71 37 '~:~ '~ 71 ~RCO ~L~SK~, INC. 3~-10 KJ~RJ.~ N]RTH SLSPEg~L~S~,6 TOP BaSE TOP BASE PBTD TO MARKER KU=~RUK C KUP~RUK .~ KUm~RUK ~ C3~PUT~TI]~ iNTER~JL&TED V~LUES $OR ~E~SJRED DE~TH N3T PRES~qT 5588.00 6715.00 D&TE: 'HOS£N q]RIZ3NS :ROM KB 5029.07 5143.08 5293.96 5395.60 ]RIGiN: TV'3 7~4' :SL, ~05' Sj3-S=a 5957.37 5!21.95 532.~.$0 SJRF~'z _9':AT 13,1 ~T ~_L, $:' T, T1Z'~, q:~'TINSULAq.~ ":]]q=£",lAT:q~.. NJ~TH/S2JTq 5S3.2~ ~ 1~9~. ~) 5~7.I~ :'~ 2}72.3~ -... 7,31.I:~ '.1 2121. ~ ': ARCO ALAS(~, I~C. 3~-10 KJP~RJK N~TH SLgD~,~L6~ MARKER TOP KUm~RUK ' BAS= K~PARUK C TDP KUm~RUK ~ B~SE KUP~RUK ~ PBTO TD ~E~SgRE3 DE~TH ~'SLON <B NIT PRES~XT NiT PRES:~T ~5~8.00 6T16.00 5385.00 T~O0.O0 SJ ,I'4 '~ .q f 5029.07 51~3.08 5293.96 FSL, 5957.~7 5]TI.OB 5221.~6 5324.60 SJq=iTM _2C~Tl';q ~T ;3_, i -C Z, Ti'""4, =T mlN~L MEASJRE] OEPTH 7000.30 WELL LOS&TI2N TRUE VERTICAL DEPTH $~96o50 ~T TD: SJB-SE~ VERTICAL DEPTH 5324.50 H]R!Z]XT~L DIST&~CE F!ET 2234.91 3EP6RTURE &ZIqUTq SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3A- 10 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOGGED.. . .. REFERENCE 00007 ] ! 78 WELL 3A-10 (744' FSL, 806'FEL, S7, T12N, R9E ) HORZONTAL PROJECTION 8C¢11.E = ]/,~ !N/FT · '. ~ : -' --i..4-4-~ Zkd-l-~ ! ! ~ '. .... ~ · · · ~~ : : i ..' ~ J_L.~ ~ ~ : : : ~ -;-".*.4--4- ~ - · ' ' ' '· · ' : : ....... ~4- ' ' '~ .,4--... 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': '- : : : ! : : : : : : : : ! : : : : j : : : : ~ : : : i : ~ : i...L.-:...~-..~.-~ .... ~..4...~..-~-J.-~ ..... :---~ ...... ;---: ...... ~.-.~-.-~--.~'-;'-; ; ...... ~--~'-t"-+' ~' :'" --.;--~'--~--4--'i-~'-:'--~--': ...... .~-'"~"-.:'"j-'--+. ....... :"'?'"e '~'":"?"~"~'"?'-~"~'"?"1-'.-'"'.---?.'"?".'"?'"?"~"'! ...... :"".'"f": / ! : : : : : ~: . : : : : : ' ....i..i...:...:...:..i .... :.-.:-.'-'.:-'4":": ..... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ....... !--.H--.:---I---H.-H ....... :--H'-':---:,:--:--':'-:--? ...... :::::::::::::::::::::::::::::'-:' :::::::::::::::::::::::::::::: ,---i-'-:'--i--!---,+--~-'-Ff'-i '-?:-:"':--:'"? :'--:---?--~ ~lgl~r]J3?'?-?'f ...... ?.?-:.:--.?j-..:.-T--~..-: ...... :'":":'-: I'":'":"T": ..... :-":'-:"':'"F':'":'":'": ..... :": '::~' :: ': :. i'. . 3OOO '74. PROJECTION ON VERTICAL PLANE 74. - 2S4. SCI:LEO IN VERTICAl_ OEPTHS HORIZ SCALE = I/S00 IN/FT EXACT RAO!US OF CURVATURE METHO0 TIE-IN LOCATION MEASURED DEPTH TRUE YERTICAL DEPTH DISTANCE NORTH DISTANCE EAST BOTTOM HOLE COURSE LENOTH COURSE AZIMUTH MEASURED DEPTH TRUE VERTICAL DEPTH DISTANCE NORTH DISTANCE EAST LOCAT I ON 0.0 FT 0.0 FT 0.0 FT 0.0 FT 2234,7 FT 71.7 BED 7000.0 FT 6396.7 FT 701.4 FT 2121.8 FT REF 000071178 Suggested form to be inserted in each "Active" yell folder to check for timely compliance with our regulations. ' · , Reports and Haterials to be received by: /c>~ /~ .... C>~ ~ate R~quired ' Da~:e Received '" ~emarks · ~. . _. .... ~' ~. ~-- . . . . , . , . /1~/..,, ~- .. . ..... . ,, . ........... ~, ~ , , Inellnatlon Survey ~.,~..-~........--~: --pl. , ....... , , . .......... .d:?_' ~-'~ '. ...... . ...... ............ ~ > ,/~.~o~ ~.~ / ARCO Alaska, Inc. Post Office Bo.. ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. OPen Hole Finals/ Schl/ One * of each 5" DIL/SFL 11-09-85 Run#1 -2" DIL/SFL 11-09-85 Run#1 -5" Den/Neu (poro) 11-09-85 Run#1 .... '2" Den/Neu (poro) 11-09-85 RUn#l ~5" Den/Neu (raw) 11-09-85 ,Run# 1 ~2" Den/Neu (raw) 11-09-85 run#l ,- ~Cyberlook 11-09-85 Run# 1 3A-8 ,,'" 5" DIL/SFL-gr 10-30-85 Run#1 '2" DIL/SFL-gr 10-30-85 Run#l 5" Den/Neu-gr (poro) 10-30-85 Run#l 2" Den/Neu-gr (poro) 10-30-85 Run#-] .. 5" Den/Neu-gr (raw) 10-30-85 Run#[ 2" Den/Neu-gr (raw) 10-30-85 Run#l · -. Cyberlook 10-30-85 Run#l 3A-7 5" DIL/SFL-gr 10-24-85 Run#l 2" DIL/SFL-gr 10-24-85 Run#l 5" Den/Neu (poro) 10-24-85 Run#l 2" Den/Neu (poro) 10-24-85 Run#l ..~ 5" Den/Neu (raw) 10-24-85 Run#l ~ ' 2" Den/Neu (raw) 10-24-85 Run#l · . v Cyberlook 10-24-85 Run#1 DATE 12-19-85 TRANSMITTAL # 5481 B Please acknowledge receipt and 3211-6988 3211-6988 6180-6962 6180-6962 6180-6962 6180-6962 6400-6800 3161-7080 · 3161-7080 6390-7055 6390-7055 6390-7055 6390-7055 6490-7030 1950-7238 1950-7238 4750-7212 4750-7212 4750-7212 4750-7212 6650-7189 Receipt Acknowledged: STATE OF AK*BL&SE RATHMELL*BL NSK CLERK*BL DRILLING*BL VAULT*FILMS DEGLOYER & MACNAUGHTON*BL Date: ARCO Alaska. Inc. is a Subs,diary of AllanticRtchlieldCompany ARCO Alaska, inc. Post Office B[~--~0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE12-19-85. TRANSMITTAL # 5473 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Tape plus listing/ schl/ One copy of each lQ-4/z G3-18-85 Run #1 4570.0-9471.0 ref#' 70997--;~d~/?&c~e~ t / ~2H-9/~ 12-02-85 Run #1 1800.0-8113.0 ref# 71048 ~2H-10w 11-23-85 Run #1 2856.0-7960.0 ref# 71002 '~2H-12 J, 11-07-85 Run #1 2743.0-6829.0 ref# 70947 ~2U-7z/ 03-19-85 Run #1 3594.5-8179.5 ref# 7095~~/~~q ~'~2V-16/! 06-03-85 Run #1 2973.0-7168.0 ref# 70952-f~-C~p~T~ ~3A-10]! 11-09-85 Run #1 3179.0-7014.0 ref9 70960 ~'~3A-11~, 11-16-85 Run #1 3208.0-7330.0 ref9 70989 3A-12;/ 11-23-85 Run #1 3797.0-8006.0 ref# 71003 '~3A-13;/ 12-01-85 ~un #1 1800.0-7597.0 ref9 71047 ~3A-14'/ 12-09-85 Run #1 0144 5-7818.0 ref9 71073 ~'30-9~ 07-10-85 Run #1 3920.0-8332.5 ref#__70996--r~4n4~,p ~~ 3F-8~! 11-09-85 Run #1&2 0115.0-7040.0 ref% ?0994 ~3F-9/~ 11-17-85 Run #1 3410.0-7770.0 ref# 70990 "~3F-10~ 11-27-85 Run #1 1800.0-6631.0 ref# 71037 3F-11~ 12-05-85 Run 91 0148.0-8618.5 ref9 71061 3J-9.x/ 11-24-85 Run 91&2 0~91.0-6789.0 ref# 71034 3J-10'~ 12-08-85 Run 91 0096.5-7348.5 ref# 71074 - Date Receipt Acknowledged: 'STATE OF A~S~* ARCO Alaska. Inc. ~$ a $ubs~d~ar~ ol AllanticR~ch/~el~Com~an~ ARCO Alaska, Inc. Post Office Bo~ .}360 Anchorage, Alas~a 99510-0360 Telephone 907 276 1215 December'13, 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 November monthly reports for the following wells: 2H-9 3A-11 3F-8 4-22 16-19 2H-10 3A-12 3F-9 4-29 L2-3 2H-11 3A-13 3F-10 16-7 L2-21 2H-12 3C-6 3J-9 16-15 L3-15 3A-10 3F-7 3J-10 16-18 WSP-12 WSP-20 If you have any questions, please call me at 263-4944. Si ncerely, Gruber Associate Engineer JG/tw GRU12/L129 Enclosures RECEIVED ~i & Gas Cons. Commis~ion Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany. .- STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION COb~MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wetlY~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-237 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21457 4. Location of Well atsurface 744' FSL, 807' FEL, Sec.7, T12N, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) 72' RKB 6. Lease Designation and Serial No. ADL 25631 ALK 2564 For the Month of November , 19 85 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3A-10 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1800 hfs, 11/1/85. Drld 12-1/4" hole to 3232'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 7000'TD (11/9/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 6885'. Secured well & RR ~ 2200 hrs, 11/10/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40 weld conductor set, ~ 107'. Cmtd w/195 sx AS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 3212'. Cmtd w/1200 sx AS ill & 300 sx Class 7", 26.0#/ft, J-55, BTC csg w/shoe @ 6975'. Cmtd w/475 sx Class "6" & 175 sx AS I. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/CNL/Cal f/6994' - 3212' FDC f/6300' - 3212' CEIVED 6. DST data, perforating data, shows of H2S, miscellaneous data None Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED /~~~ TITLE Associate Engi neet DATE /2./~-,9~ NOTE--Report(/Sn 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. Form 10-404 TEMP2/MR65 Submit in duplicate MEMORANOUM TO: THRU: FROM: Stateof Alaska ALASKA OIL AI~D GAS CONSERVATION CObR~ISSION C. ~'"~'t ter ton Cha~z~n~' // Lonnie C. Smith .--',," Commiss loner Bobby D. Fosteri~- ~ Petroleum Inspector DATE: November 12, 1985 FILE NO: D. BDF. 115 TELEPHONE NO: SUBJECT: BOPE Test ARCO - K.R.U. - 3A-10 Permit ~85-237 Kuparuk River Field Wednesday. a. nd Thursday,_November 6 & 7, 1985: The BOPE test began at 10:30 PM and ~As concluded at 1:00 PM. As the attached BOPE test report shows, there was one failure which was repaired and tested before I departed the location. In summary, I witnessed the BOPE test on ARCO's 3A-10. Attachment 02-O01A(Rev. 10/79) O&G it4 5/84 ._ '. . ~'~ STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Location: Sec ~ _~~R~__M. O , , Drilling Contractor ~~ Rig f/~/~'/ Representative Location. General ~~ Well Sign~' ACC~ATOR SYST~ General HousekeepingO~ Rig ~~ -- Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve / Test Pressure Test Results: Failures / Full Charge Pressure Pressure After Closure Pump incr. cloG. pres. 200 psig Full Charge Pressure Attained: Controls: Master psig. psig. rain A--sec. ~ min~gsec. psig~ Remote~ ~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly / Test Pressure Lower Kelly / Test Pressure Ball Type / Test Pressure Inside BOP / Test Pressure Choke Manifold ?~ Test Pressure No. Valves., ~ No. flanges ~q Adjustable Chokes / Hvdrauically operated choke Test Time ~ ~'~ hrs. Repair or Replacement of failed equipment co be made within days and Inspector/ Commission office notified. Distribution orig. - AG&GCC cc - Operator cc - Supervisor October 10, 1985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3A-10 ARCO Alaska, Inc. Permit No. 85-237 Sur. Loc. 744'FSL, 807'FEL, Sec. 7, TI2N, R9E, UM. Btmhole Loc. 1358'FSL, 1462'FWL, Sec. 8, T12N, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation'so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION 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 B0"~"'i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 1, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3A-10 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 3A-10, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore ° A proximity plot A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on October 20, 1985. If you have any questions, please call me at 263-4970. ,erely, Regional Drilling Engineer JBK/JFB/tw PD/L179 Enclosures OCT 0 Choraoe' Cornmjs~/on ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA OTC AND GAS CONSERVATION COmmISSION PERMIT TO DRILL 20 AAC 25.0O5 lb. Type of well EXPLORATORY [] SERVICE [] ~ _STR~GRAI~H I~[] DEVELOPMENT OIL ~X SINGLE ZONE ~ 9. Unit or lease name Kuparuk River Unit la. Type of work. DRILL I-~X REDRILL [] DEEPEN [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 7/+4' FSL, 807' FEL, Sec.7, T12N, RgE, UN At top of proposed producing interval 1309' FSL, 1283' FWL, Sec.8, T12N, RgE, UN At total depth 1358' FSL, 1462' FWL, Sec.8, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease des/~ation and serial no. RKB 72', PAD 42' 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Storewide Surety and/or number #8088-26-27 10. Well number 3A-10 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 807' ~ surface feet 3A-9 Well 22' ~ 650'TVD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7033' MD, 6375' TVD fe~.t 2560 10/20/85 '120.Anticipated pressures 2660 psig@ 80°F Surface 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 2143 feet. MAXIMUM HOLE ANGLE 33 oI (see 20 AAC 25.035 (c) (2) 3058 psig@ 6000 ft. TD (TVD) 21 I Proposed Casing, Liner and Cementing Program i SIZE SETTING DEPTH QUANTITY OF CEMENT Hole 24" 12-1/4" 8-1/2" Casing Weight 16" 62.5# 9-5/8" 36.0# 7" 26.0~ CASING AND LINER Grade I Coupling H-40 [ Weld -55/HF-EIW BTC -55/HF-EIW BTC 22. Describe proposed program: Length 80' 32' 32' 3198' 32' 32' I 7002' MD TOP TVD I 31' I 31' MD BOTTOM TVD 1121 112' 3230~ 3172' 7033'1 6375' I I (include stage data) ± 200 cf 720 sx AS III & 300 sx Class G 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7033' MD (6375' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2660 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at.surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3A'10 will be 22' away from 3A-9 at 650'TVD. There' are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby c~t~fy that the foregoing is true and correct to the best of my knowiedge SIGNED TITLE Regional Drilling Engr. The space,~w~fo//CoUmy~iss.on d~v -- CONDITIONS OF APPROVAL Samples required []YES [~.NO Permit number Form 10-401 ~J~ P~D/PD179 7-1-80 Mud log required I-lYES [~10 Approval date ," Directional Survey required I APl number [~ES []NO 50--O'~- Z-i ¥-~7 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE I'~r,~-r~,,~- ~ I~ 1985 bV order of the Commission Submit in triplicate PERMIT TO DRILL 3A-10 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED Aiaska OiJ & Gas Cons. C0mmJss[0~ :-:.E~THAH WH[PS. TO~~. INC.';-- -~ --.~ _ - . ......... [. . . f . . ...... , · . . _J ...................... - .................... ; . ._ ~ .................................. . .. ~ .... ' ...... ~ ..... : .... L ........... _ ................ ~. ........... ... .... .''- ........... ~ - ; ....... __- ...................... ,- - : . - . _ _ :. : . _ · .......................... ............... ~ .......... ~'_ .............. - ............................................ ............................. · ......................... . ' ...... . ....... ~ ............ - ............................. ..... ~ .... . ; ................ : ............. _ .............. -~ __ . - .- ........ ....... ~ ........ ~ ....... : ........ . ........- ...... . _ _ . ~ ................ - .............. ................ ...... . ............... ................. ...... _ . . : . _ .......... ............... BASE-PERHAFROST ...... T-VVD=t 552--- ' ......................... , _- ........................ . _ . .. ........................................... - L_2000... .. __ _ KOP TVD=2143 TMD=2143'DEP=O _ -'- .-'- ...... . - . _ _-_ -.- _--._-' .:'.-_'_--_.. _ ..... : 3 -- - BUI[LD :3 DEi~ _ .... 9 ..... PER 1 OD FT - ': ............. : ..... : -'-' ...... ;..-.2 ~: :_. :' .---' ,':S---'i:~P-' ','2, ' S~-~-- ..:' ~;N D s -" .'T ~D-~:~-~ 2- ~-!~-=26 ~'~.: ....... '-D E P =-78- :.:::-:{-_T-:-~ :~__:.--3000<. ~_'.': 27 K-12 -TVD=2972 Tt'ID=3001'DEP=189 : -' -' ~ _-- ...- . '-~-' -' .... -Eoc" -(~' .sx~- C~ -~> --' ........... ---::."-'-- ...... - ........ ::-'--:- ~. .'~': 'TVD :3172 Tt'ID 3230-DEP=301 '- - : ..... '~'- '-' ' xX'~ ' - AVERAGE ANGLE ~.____,4ooo ~:.......'.: .-~.- ..-~ ....... : ...... 3.2 .... .DES 37-MI:N-: ..... ........... --- : ...... ............. '--------:-. ..... :-:--------::: .... ~ . =-- ..... V ..... -'-- .---:----"-. ........ ,..- ..... -Sooo_ . '-'_-_::--i:' :-.-:'-" ........ ..~ ' T.TZONEiD -'TVD=5982 THD=6566 DEP=2099 :- -:-:- ~-::-::~/'-::'.:" _'._:.__6000.= ..--~ .... --T-/ZONE :-C: TVD=6000- THD=6557- 'DEP=21'l'O .......... --?-- ..... : ...... - :'. '-. ~ \ ':._T/ZONE_A--__:-~T-V-D=608$ THD=6685 DEP=2165 -'::-:':: .... - - -' -,~-'i-' TARgET--CNTR -TVD=614.6 TMD=6760 .DEP=2204 ._- .............. : · ':; .... BASE-KUP--SNDS.' TvD'=6207 TMD-'-6833-DEP=2243 ........ '---.! .... .:--:-'-::':'-"TD-(LO(} PT) TVD=6375 THD=?0:3;3 DEP"-23'50 ......... ............. ~ ........ , ..... ~-- . ...... : ..... : -.-: ............... ..... ~. : · i -- : : - - -' .......... - ..... ' ........ T ....... , . i :_:. ,.: -i~:-F_-C-F-:i:V-F_:n ~ - ............. ' ; .... ; =,.,,~ ,,.~ ~., , ~.~,'-- . ' -- - ..... ~--T'--- .... :-': ...... · ~ ~ .... ' 0 '- ......... -- ............... '-"': .... _'- '-_.---_'.- -_'_ .0 - ': --'."' .- ~ 000. :..: .... 2000:-! :-- :-.300 : -? :_-- -- _ -. - -_.. ....... ~-- - ........... : -'-' ..... : ' '-'~ ! ....'"- !':-"- ....... ' ~ T :7- - - - ' -: ........... -_ ..... "~ . ........ .............. :,-- VERTICAL----SEC'TI:ON: ':': ' '-~-~,-0-~"-~'- ' ' · : - ..................... , ..... ! ................ ' -A_F~i~a- Oii- &- B'aS.-C~: 'Commissior~-!-::'-: .... -" -:-----:--'-:-- :---'- , . ........ , _, .__. ::. ___.. ::. -_:.::__-_- _:-_ A~!Or~__ : ............... - ' : .: ...... ~ ., . : _ -' . : ~ _ . :L-. I,l' i; ~ · ~"~ ....... ' "' '["': : ...... ..... ~: ~ ARCO ALASKA, INC, ~ i.: PAD 3A, WELL NOt 10 I REVISED:PROF ~ KUPARUK FIELD, NORTH~SLOPE,'.ALASKA ': , '~''EAsTHAN PSTOOK iI~C ," .~..~...,..~...' .: ~..., .......... ~- : ...... ~..~ i ..... ~..4-~-.~-~.. ~ i--~..] .... , '...20o0 I · ,i"i!~;, I' ' ~ ' ' ...i.3} ...... , t , [ , { ' ' i,,i I ! i : DEP=2; tRTH ]LOC, oE'~ .,32o.i rs~. ,32o.. 1200 1000 900' 1100 1000 I ALASKA, INC. 9O0 I PAD 3~.: WEEL NO,: 10-11-12 PROPOSED KUPARUK FIELD. NORTH_SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. - ~ .... TO0 I 600 I 500 f~OO. i~ FO0 .... 500 '_ , i .WELL PATHS EXTEND BEYOND THIS; VIEWING WINDOW 800 : 000~ 90O w, KUPARUK RIVER UNIT 20" -DI VF_J TER SCHEMAT I C DE S CR I P T I ON i. 16 · C~CTOR. 2. TADa(O STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LO~R OUICK-C~CT ASSY. 5. TAI,a<O UPPER QO I CK-C~CT ASSY. 6. 20' 2000 PS]: DRILLING SPCX:!L_ Vi/I0" OOTLETS. 7. I0" NCR BALL VALVES W/I O' ,.// D]:VERTER LZl',,ES.. VALVES OPEN AUTOMATICALLY UPON CLOSURE (::IF A~AR PREVEt,,FT'ER. B. 20' 20CMD PSI AD, t,,ULAR PREVE~ER. 7 6 7 5 2 MAt NTENANCE & OPERAT.} ON I. UP-ON INITIAL INSTALLATION. CLOSE 'PREVENTER AND VERIFY THAT VALVES -- HAVE OPENED PROPERLY. 2. CLOSE AhZ~LAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE . F. LUIDS OR GAS IS DETECTED. IF NECESSARY, MANUALLY OVERRIDE AND CLOSE APPROPR I ATE VALVE TO ACHIEVE DONNWlND DIVERSION. DO NOT SHUT IN V~LL UNDER ANY CIRCUMSTANCES- 7 6 5 > > DIAGRAM #1 1~-5/8"-~5(;X~ PS~ RSRRA ~P STACK I. 16' - 2000 PSI TAtS<CO STARTING ~F_AD 2. II · - 5000 PSI CASING ~F. AD ~. 11' - 5000 PSI x I~-Ev'8' - 5000 PSI SPACER SPOOL 4. 1~5/8' - 5000 PSI PIPE RANIS 5. 15-5/8' - 5000 PSI DRILLING SPOCL ~'C~ A~D KILL LI~S 6. 15-5/8' - 5000 PSI C~ RAM' W/PIPE ;b~ CIN TOP, ?. 15-5/8' - 5000 PSI ~ ACCIJvtJLATOR CAPACITY TEST 1. C~CK AbE) FILL ACC~TOR RF_~OIR TO F~ LEVEl. WITH ~~IC ~UID.' 2. ~ ~T A~T~ ~~ IS ~ ~I WI~ I~ ~I ~T~ ~ ~'~~T~. ~. ~ TI~, ~ ~ ~ ~ITS SIXThlY 4. ~~ ~ ~ ~T, ~ A~T~E L~ LI~IT IS 45 ~~ ~I~ TI~ ~ l~ ~I ~INI~ 13-5/8" BOP STACK TEST 4 3 2 . 1. FILL BOP STACK A~ CHCI<E MANIFCLD WITH ARCTIC DIESEL. 2. OEO< THAT ALL LO0< DO~ SC~ IN Y~EI_LJf_AD ARE F1JLLY E~'TRACTED. SEAT TEST PLUG IN 14Ei_L]f_AD WITH RUNNING JT AhD RUN IN LO(~ SCR~. 3. CLOSE ANXU_AR PREV~ Ah~ N~IJAL KILL AhD 0-~ LIhE VALVES ADJACENT TO BOP STACK, ALL OTHER 4. PRESSURE UP TO 250 PSI Ah~ HOLD FOR I0 MIN. IN-- CREASE PRE~ TO 3000 PSI AhD HOLD FOR I0 MIN. BLFFr~ PF~SSLIRE TO 0 PSI. 5. OmEN Ah~tJLAR PREVENTER AhD MANJAL KILL AN) LIhE VALVES. CLOSE TOP PIPE RAMS AhD NCR VALVES C~ KILL AND O-O<E LIhES. G. TEST TO 250 PSI AhD 3000 PSI AS IN STEP 4. 7. ODNTIhIJE TESTING ALL VALVES, LI~F_.S, AN~ O-EX'ES WITH A 2.50 PSI LO~ AhD 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY ~ THAT NOT A FULL O..OSING POSITIVE SEAL O-O<E. ON_Y FL~XL'TION TEST CHO<ES THAT DO NOT FULLY CLOSE. OPEN TOP PIPE RA/v~ AN~ CLOSE BOTTO~ PIPE RAMS. TEST BOTTO~ PIPE RA/v~ TO 2.50 PSI AhD 3000 PSI. OPEN BOTTO~ PIPE ~o BACK OUT ~ING JT AhD CLOSE BLIhD RAMS AhD TEST TO 250 PSI AhD PSI. · O=SN ~I~D RA~S A~D RE'mitrE TEST RUG. ~E SURE '~[F~ A~ L[~ES AR~ FU_L CF ~:~--FRF_EZING FLUID. SET ALL VALVES IN DRILLING POSITIO~L 12. TEST STAhDPIPE VALVES, KELLY, KEI_ LY COCKS, DRILL PIPE SAFETY VALVE, AhO INSICE BOP TO 2.50 PSI AhO $000 PSI. 15. RECC:RD TEST IN=OG~TICN ON BLO~ P~ TEST FOR~, SIGN, AhD SEhD TO DRILLING SUPERVISDR. Y TNEREAFTER ~ICI~LLY ~TE BC:F~ DA21_Y. OCT 0 Alaska Oil & ~as Oo~s. Commission ARCO Alaska, Inc. r~ Post Office BOX 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plats - 3A Pad Wells 1-16 Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU11/L22 Enclosure If RECEIVED AUG o 1985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfleldCompany ? 8 18 17' NOTES :. GJCRDINAT~S ~RE A.S.P.,ZONE 4 2. SECTION ;.,NE DISTANCES ARE TRUE. 5. HOR!ZONTAL POSITIONS BASED CN THE D,S.-OA WEST & 3AMID PER LHD 8~ ASSOC. ~.VERTICAL POSITION BASED CN SA EAST I~ 3A MID PER LHD I~ ASSOC. $.0.G. ELEVATIONS iNTERPOLATED FROM S/C DWG, CED- RIXX- 302_0 rev. ~ HEREBY CERTIFY THAT I A M PROPERLY REGISTERED L SCENSED TO PRACTICE LAND SURVEYING IN THE: STATE: OF ALASKA, THAT TH~S PLAT REPRESENTS A SURVEY MADE ~JNDER MY DIRECT SUPERVISION 'AND THAT ALL DETAILS ARE CORRECT AS OF AUGUST 14, 1985 LOCATED IN PROTRA. CTED SEC.7,1:. "' A~s ~a 0il & \ I I 13 18 17 AS BUILT'~' CONDUCTORS I- 16 1- Y:5,996,860.05 LAT= 70024'09.520''` x= 507.712.01 LONG= 169°56' I~,020" . 478' FSL, 736' FEL, 36.8 OLi, ~.0.8 PAD 2- Y:5,§96,884.17 LAT= ?0o74'09.758'' X: 507,705.57 LONG= 149o56' !4.207 503' FSL, 743' FE[, 35.8 Off, :,0.9 3- Y=5,ggG,g08.32 LAT= 70o24'09.-:)95'' x= 507,699.06 LONG= 149056, 1L+.j~7 527' mSL, 749'~EL, 36.7 OG, 40.8 PAD 4- Y=5,996,932.72 LAT= 70°24' 10.235'' X= 507,692.55 LONG= 149°56' 14.587'' 551' FSL, 756~ FEL, 36.7 OG ~0.8 Pa~ 5- ¥=5,996,g56.61 LA~= /O°2q i0.~70" ~= S07,686.2[ LONG= 1~9°56'14.773'' 575 FSL, 762'CEL, 35.50G, ~O.g PAD 6- ¥=5,996,980.84 LA~: 70°2~ 10.709" X= 507,679.66 LONG= 169°56'14.963" 599 FSL, 768' FEL, 36.50G 40.8 PAD 7- Y=5,ggT,004.90 LAI= 70°2~ 10.9~5" X= 507,673.26 LONG= 149°56' 15.t5['' 623 FSL, 77~'FEL, 36.5 Off, 51.1 PA9 8- ¥=5,g97,029.03 X= 507,666.81 647 FSL, 781' 9- Y=5,§97,101.24 X= 507,647.70 720 FSL, 800' lO- Y=5,997,125.66 X= 5d ,640.89 LA[= 70°Z, ~1. [93" LONG: 149°56' 15.33:~'' FEL, 36.40G 40.9 ~AO LAT= 70o24 11.893" LONG: 149o56~ 15.896" FEL, 36.3 OG ~1.7 PAP LAT= 70024 i2.134" LONG: 149°56'16.095'' /44 Il- Y=5,gg?,149.84 X= 507,634.44 768 FSL, 12- ¥:5,997,173.97 X= 507,627.96 792 FSL, 819' 13- Y=5,997,198.08 ×= 507,621.48 817 FSL, 825' 14- ¥=5,997,222.29 X= 507,615.01 C;L, 806! FEL, 36.3 OG A1.6 PAD LAT= 70024 12.371" LONG= 149°56' 16.283'' FEL, 36.2 OG 4~ PAD LAT= 70°24 12.509" LONG= 149°56' 16.,,7{'' FEL, 36.10G, ~1.3 LAI: 70°2a' !2.8~6'' LONG= l~g°SG'tS.5~ FEL, 36.0 0G, 41.0 L~T= 70°24' !3.gSa'' LONG= 149°55'16.861" 841 FSL, 832' FEL, 35.8 :3G. 41.0 PaC 15- Y--5,997,2~6.44 LAf= 70°24' 13.322" 'EIVED ~. .x= 507,608.55 LONG= 149°56' 17.03-~" 865 FSL, 838' FEL, 35.6 OG, ~,1.3 o']O :~= 5n?,b02.10 LONG= Ia9°55' 17. :'" · ~ ' ' 9~4';EL, ]5 5 OG ~,[ t - ' - Sas Cons. Commlss~ ; ....... ~nchorage Kuporuk Pro~ect CONDUCTOR AS- B UI LT LOCATIONS --~BSSH~ o~,.aUe, lG. lSe, Sc.,.: '"=3,-'.. Drofted by:~ ,,--,,, .... ., ,~.:- . O~g. nO.: NSK 85-16 i i i - CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (2) Loc ..... ~...."; ~,~. ' .... ,>~ ~(2 thru 8) (8) .., " ':~ ~:'~ .... 9 (3) Admin ....... - ..... (9 th.ru 12) 10. (10 and 12) 12. (13 thru 21) (22 thru 26) 13. 14. 15. 16. 17. 18. 19. 20. 21. YES 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. NO REMARKS Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons .......... Will surface casing protect fresh water zones ..~ ....... iiii111..i~ Will all casing give adequate safety in collapse' tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ,~O~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: Geology: Engija~ering: WVA ~.~.~3f,?. ' MTM ~ HJH JAL .,,:.,.,' '~'~ .,,,, :,~ rev: 03/13/85 6.011 IN ITIAL 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 APPENDIXl ,. No special'effort has been made to chronologically organize this category of information. LVP OlO,H02 VEPIFI~ATION [,TSTING PAGE SERVYCF NAME. ;EDYT DATE I~5/ll,/18 ORYGYN ~ RE~L N~M~ . :1492,19 CONTYNI,~A?ION # ~01 PR~VTOUS R~EL { ~O~MENTS {LIBRARY TAPE ** TAPE H'EID~R SERVICE NAME DATE :~5/11/18 TAPE NAM~ .... i CONTINUATION,# PReViOUS TAPE' Alaska Oil & Gas Cons. Commission Anchorage ** FIL~ HEADER SE~VTCF MAME VERSION # DATE I ~AX~MUM LENGTH I. 1024 mILE TYPE ** INF~RMAT'I~N RECORDS WiiI Ii'IIIilI CN i ARCO AbABKA WN ~ ~A-IO mN { KUPARUK ~ANG~ gE TOWN{ 12N MNFM CONT~NT~ ** CoMmEnTS ** YNC, UNIT TYPE 000 000 000 000 000 000 000 000 TYPE 000 CATE 000 000 000 000 000 000 000 000 CATE 000 016 006 OOB 002 004 002 012 006 SIZE 001 cODE IIIi 065 065 065 065 065 065 065 065 CODE O65 ~-"I'""~ m""J ITl mil ~1:4 LVP OIO.HO~ VERIFICATION LTS?ING PACE, * SCH[,UMB~R~EW CO.PAHY = ARCO ALASKA COUNTY = NORTH Si, OPE BOROUGH ~TAT~ = ALASKA JOB ,UMB~R ~T ACC:I 70960 'bUnD = POLY = 9:,.5 FLUID LOSS = 6,5 C] B~T S~ZE = 8.5" TO ?000.0° RM R~C RM AT BHT ~TRY BkOCKS TYPE SZZE REPR COD, E.TRY 2 ! 66 0 4 1 66 1 8 4 7] 60 9 4 65 16 1 66 1 0 I 66 0 OATUM SPgCIFIC~TIOM MNEM S~RVICE S~RVICE UNiT ID OR'D~R # AP! AP! APl APl FILE SIZE SPL REPR LOG TYPE CLISS MOD NO. CODE PR C~SS LVP 010.~02 VERIFICA?ION LTS~ING PAGE 4 FLU ~R RHOB ~R~O NRA? D II, FT O0 OH~M O0 OHMM O0 OH~ O0 ~¥ O0 ~API O0 GAP! O0 ~N O0 ~/C3 O0 ~/~3 O0 O0 O0 PU O0 CPS O0 000 22n 12 0 0 O0 0 0 4 Ol 0 0 4 4,6 0 0 0 0 44 O! 0 0 4 O1 0 0 4 O1 0 0 Ol 0 0 4 02 0 0 01 0 0 4 O~ 0 0 4 O0 0 0 4 O0 0 0 4 31 0 0 ~0 0 0 4 00000000000000 6S 60000000000000 00000000000000 00000000000000 00000000000000 00000000000000 O0000:O00000.O00 O0000OOOO00OO0 i~ 00000000000000 00000000000000 :6800000000000000 68 000o0000000000 68 00000000000000 oooooooooooooo ooooooooooo:ooo DATA OEPT St:' RHOB ~IpHI SP. RHOB 7 0000 ~3 547 Zooo.oooo ,~967 45,4590 6900 0000 38 08~9 -55. 3 41'422 6~00.0000 60,9883 38.9648 SFLU DRHO DRHO $FLU GR ORHO SFLU SFLU OReO 1729 . 8:95 r:C~L 0 FCNL 1964.,0161 NRAT ,68'75 FCNL 2 ~I~02 ILO I09'~ 23 GR ' 283 NRAT l?~ :g8~5 rC.L 4 ~R~T 2022.6975 MCNL 6500 0000 '9883 45.3613 l' 130,40375 GR .- 2'73 175:~:68'75 2.3518 528~8225 o 406 5.7078 8q.96¢8 ].2600 ~36,8125 IbM 2,6389 ~NRA CALl RNRA 3:,8167 2,5432 8,~973 ~N~A 3.7151 IbM 2.0549 CALX 8,6582 RNRA 3,.6467 TLM $,2546 CALl 6,4004 RNRA 3,7698 CALX 2~17 RNRA 645 125 131,4 455,1406 7,2664 8,3066 1,7647 ,2676 .6518 DEPT 6400.0000 SFLU -60,~883 DEPT 6100~0000 ~FLU ~P '4~,g883 WHOB ,3538 DRHO 62:00. 0 '0 -9 ~0 , RHOB R'HOB ~HOB -6 590~ 0000 iO0 · ~EP? 5gO0.O000 SP. '69.9727 WH'OB -999,2500 MpH! -999,~500 DEPT 5700,0000 RHOB -999 0 ~P~I -999'2500 , ~EPT 5600.0000 RHOB '999,2500 qPH! -999,2500 ~EPT 5500,0000 SP. -73,4727 ;HOB -999.2500 MP~I -999,~500 oo' ooo -81, 7~7 RHOB -~99,2500 qPH! -999,~500 DRHO ~R DRHO N'CNb 2.8049 4 0 4., 65 ~R OR:. GR t"C:NL ~,3536 ThO -999~2500 rCNL 120 {398 -99'9 2500 NRAT -999,2500 PCNL 4.5945 -999, NRAT '999'~$00 ~CNL 3,3206 1..10,9023 -999o~500 -999,2500 1,6797 ~0 131,0625 '999,2500 NRAT 'P99,~500 3 5995 109.3398 OR -999,2500 BRAT 6406 '3 47'? ' .3906 "'999 -999,..2500 2500 -9~'{'2500 , -999.{~00 -999. O0 -999,2500 =999o2500 -999,2500 2,1077 -999,2500 -999,2500 ].4124 -999.2500 -999o2500 -999.2500 CA£,! mNRA ~:.t. bl RNRA. RNRA RNRA RNRA ~ALX RNRA 0 ,,,99 999, '999.2500 -99~, 0 '999, 0 3,3518 -99~,2500 '999,2500 2.1135 -999,2500 -999.2500 ~.30tO -999,2500 -999,2500 LVP OIO,HO) VERIFICA?ION blS?lNG PA~E 6 OEPT 5300,0000 8FI. U SP,. -71, :2227 C,R RNHOB -q99,~500 ORgO P~I -999.~500 NCNb 0000 SP RHO8 NPHI OEPT RHOB NPHi ~HOB NPHI OEPT ~PHI OEPT SP -999 3500 '99, 999. "999, ~00 49~ '99.19 0000 3389 ?00.,0000 999. 4600.~000 -999. 500 . 38.8008 .999.~500 999.2500 4400.0000 -40.0~95 -999.25O0 4)00.0000 8FLU 8FbU ~R ORHO .~LU DR'HO NCnb NCNb NCNb SrLU OR DRHO NCNb SFI,U 8FLU DRHO NCNb SFt, U DR DRMO ~FT, U ~R DRMO '2, '502 '999' gq.e, ioo NRRT GR NRA? 13 ., 5 CR -9~ ,2500 NRR~ -9 ~,2500 rCNb -999,2500 2 9065 -999,~500 NR~T -999,2500 2,3655 8e,5273 Ge -999,2500 NRA? -999.2'500 48 -999.;'~0 NRAT -999. 0 ~CNb ~.0100 81,~523 ~R '999. 500 ~R~T ~99. CALX .999. ~NRA 9:99. ].2444 IbM -9! {500 5:':0 RNRA 0'2 ~5oo -999.,2500 R'NR,A -9.99,2500 250~ ~999, O0 999. 50 RNRA -999°2500 2,9290 '99q,2500 . 2°4456 .999,2500 CAb! 999,2500 -999;25'00 ~ 6o~8 .~99:25oo CALX 2.)987 IbM '999,2500 CALI -qgq.9500 RNRA .2 -999,2500 23:66 3~2500 :,soo -999. ~,,0549 ,2500 2500 2'2 0 -999, -999,2500 -999'.2500 500 -999,2500 . 2,3538 999, O0 LVP OlO.gO~ ~E~IFICATInN L~STING PAGE ? NP~I -999,.~500 NCNB DEPT ~00 0000 SFl.,U SP. -4~ 0508 ~R RH~B -999 250'0 ~RHO NPNI -~99 :~500 NCNL OE~T 4100,0000 SFLU ~R qHoO -99~ ,~500 DRHO '~PH! -999'2500 NCNb 0000 :0508 ,~00 P,. 'Si DR H, OB '~50i0 DRHO ~HOB . ,~50u NPHI 999.~500 NCNb 0£~? 3:6.00.0000 SrbU SP~ -58,0820 RHOB #999,~500 DRHO ~PHI -999. 500 NCNb DEDT 3500.0000 Srt, U SP "60.8320 nHOB -999.2500 DRHO NPH! -999.2500 NCNB ,oo oooo RHOB -999.250 DRHO ~PHI -990.2500 NCnb OEuT 3200.0000 ~Ft.U ~HOB -9 . OReO NP,I -~99.2500 NCNb OEPT 3~.0000 SFt, U 8P .~399 ~R nHOB NPHI DEPT RHOB NPH1 SFLU ~R ORH'O NCNb 8Ft, U -999.2500 9~.5.I39 .6523 -999 500 2 760 FCNb MRAT rCNb PC'Nb N:R:~ T NR'RT R GR NRAT rCNb GR NRAT FCNL NRAT ~R NRAT Ibr). -g99.2500 2 5862 -999:2500 -999,25"00 -.999.~500 2,.B9807 ..999. "999.~500 2.9944 -999'~2500 "999,2500 "9'99". 25 O0 .99{ .7463 ,2500 · ,999 ' 25':00 '999.2500 4.2859 :, 5oo ,-99 . { -9 . 500 ','999.2500 9.~.4070 ..9 .~2500 -999.2500 -999.2500 4.6257 -999,~500 -999.~500 -999,2500 3,3674 '999.2500 '999.2500 -999.2500 3 3225 -999, 500 '999.2500 9,8848 -999.~500 RNRA ~A,bI RNRA NRA CA hi RNRA CAbl RNRA RNRA Ib~ CAbI RNRA T. bM CAI, I RNRA IbM RN~A 999,.2:500 2.'8479 ..'999 -999,2500 2,9456 '997,2'500 -999,25O0 999[ 2500 2500 4,.1882 .2500 5,2546 -999.2500 -999,2500 . 4,4460 .999,2500 999.2500 3.1995 -999,2500 -999,2500 1702 %91' 2500 -999~2500 tVP OlO,~O~ VERIFICATION LTS?ING PAGE RNOB ,,~99,2500 NPHI -g99,~500 NCqb ~:999,.~500 NRAT DEPT 3179,0000 SP' -30':6670 ~HOB -999,2500 ~PHi -999'~500 NCN~ 55,.~6~7 ~R -99~,2500 ~RAT . O01 : 1024 2500 9~5098 -999.:~500 -999,~500 -999,~500 RNRA CAK,! RNRA "999,2500 2000.6875 -99~, 2500 -999,2500 ~E~VYCE NA.~E tEDY? DATE :85/'11/18 ORIGi'N ::FS1. A TAPE NAM~ CONMENTS i{,]BRARY TAPE OR~GYN : ~E~L NAM~ :149219 COnTinUATION # NEXT R~ET., NAME CO~ZN?6 :T.,I~RARY TAPE