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Home My WebLink About199-043MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 2, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-27 KUPARUK RIV UNIT 1C-27 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/02/2024 1C-27 50-029-22943-00-00 199-043-0 W SPT 6375 1990430 3000 2336 2325 2328 2334 218 490 480 475 REQVAR P Kam StJohn 5/21/2024 MIT-IA to MAIP per AIO 2C.086 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 1C-27 Inspection Date: Tubing OA Packer Depth 890 3300 3260 3250IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240522124238 BBL Pumped:2.7 BBL Returned:2.7 Tuesday, July 2, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 AIO 2C.086 James B. Regg Digitally signed by James B. Regg Date: 2024.07.02 13:09:38 -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 1C-27 (PTD 199-043) Update and plan forward Date:Wednesday, November 9, 2022 2:26:10 PM Attachments:MIT KRU 1C-27 diagnostic MITIA 10-28-22.xlsx From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, November 9, 2022 1:30 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1C-27 (PTD 199-043) Update and plan forward Chris, KRU 1C-27 (PTD 199-043) Following the last report the well passed an MITIA and the IA was degassed for the monitor period. Unfortunately the IA pressure has continued to increase during the monitor period while on gas injection. The plan is for the well to be WAG’d to water ASAP and then a new 30 day monitor period will begin to prove integrity while on water injection. Subsequent the monitor period any required paperwork will be submitted for continued injection or corrective action. A 90 day TIO trend and wellbore schematic are 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 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1990430 Type Inj W Tubing 3812 3792 3792 3792 Type Test P Packer TVD 6374 BBL Pump 5.1 IA 169 3010 2995 2995 Interval O Test psi 1594 BBL Return OA 50 93 96 97 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 ConocoPhillips Alaska Inc, Kuparuk / KRU / 1C Pad Miller 10/28/22 Notes:Diagnostic MITIA Notes: 1C-27 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)MIT KRU 1C-27 diagnostic MITIA 10-28-22 (002) 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 1C-27 (199-043) Report of suspect TxIA communication Date:Tuesday, October 25, 2022 1:27:19 PM Attachments:AnnComm Surveillance TIO for 1C-27.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, October 25, 2022 9:52 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1C-27 (199-043) Report of suspect TxIA communication Chris, KRU 1C-27 (PTD 199-043) is exhibiting suspect TxIA communication. The IA pressure has been bled multiple times, but pressure has continued to slowly increase. The plan is to have DHD conduct initial diagnostics including an MITIA, pack off tests, and degassing the IA for a DDT. Afterwhich the well will be place on a 30 day monitor period. Subsequent the monitor period any required paperwork will be submitted for continued injection or corrective action. A 90 day TIO trend and wellbore schematic are 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 1C-27 90-Day Bleed HistoryWELL DATE STR-PRES END-PRES DIF-PRES CASING1C-27 2022-09-18 2020 1020 -1000 IA1C-27 2022-10-24 2317 894 -1423 IA Last Tag Annotation Depth (ftKB) End Date Last Mod By WellboreLast Tag: CTM 13,221.0 2/25/2009 ninam 1C-27Last Rev Reason Annotation End Date Last Mod By WellboreRev Reason: Set Patch 7/5/2021 famaj 1C-27Casing StringsCsg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB)Set Depth (TVD) (ftKB)Wt/Len (lb/ft) Grade Top Thread WellboreCONDUCTOR 16 15.06 34.0 115.0 115.0 62.58 H-40 WELDED 1C-27SURFACE 9 5/8 8.83 33.4 6,916.0 4,546.6 40.00 L-80 BTC-MOD 1C-27PRODUCTION 7 6.28 30.9 10,787.4 6,403.1 26.00 L-80 BTC-MOD 1C-27LINER 4 1/2 3.96 10,528.7 13,907.0 6,411.8 12.60 L-80 ABT-MOD 1C-27Tubing Strings Des String Max Nominal OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt (lb/ft) Grade Top Thread Wellbore TUBING 4 1/2 3.96 28.6 10,535.3 6,376.5 12.60 L-80 ABT-MOD 1C-27 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 28.6 28.6 0.13 HANGER FMC GEN IV 5M HANGER 4.500 1C-27 492.6 492.2 5.60 NIPPLE CAMCO DB NIPPLE 3.812 1C-27 10,034.6 6,222.8 64.94 NIPPLE HES X NIPPLE 3.813 1C-27 10,518.9 6,373.6 79.41 LOCATOR BAKER LOCATOR 3.850 1C-27 10,520.0 6,373.8 79.45 SEAL ASSY BAKER 80-47 SEAL ASSEMBLY 4.000 1C-27 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) Wellbore 8,027.0 5,151.5 57.54 PACKER - PATCH - UPR 3.76" P2P w/ Spacer Pipe and Anchor Latch. ME@8030'. OAL 28'. 7/5/2021 2.000 1C-27 8,032.0 5,154.2 57.61 Spacer Pipe 21' of 2 3/8" Spacer Pipe. 7/5/2021 1.920 1C-27 8,040.0 5,158.5 57.71 TUBING LEAK TUBING LEAK AT 8040' 5/22/2020 3.960 1C-27 8,053.0 5,165.4 57.83 PACKER - PATCH - LWR 3.76" P2P ME@8056. OAL 5' 7/4/2021 2.000 1C-27 9,935.0 6,178.8 62.65 Packer - Patch UPR 3.76" P2P w/ Spacer Pipe and Anchor Latch. OAL 19' 8/26/2020 2.000 1C-27 9,940.0 6,181.1 62.76 Spacer Pipe 2 3/8" Spacer Pipe and Anchor Latch 8/26/2020 1.995 1C-27 9,945.0 6,183.4 62.87 TUBING LEAK TUBING LEAK AT 9945' 5/11/2020 3.960 1C-27 9,953.0 6,187.0 63.05 Packer - Patch LWR 3.76" P2P. OAL 5' 8/25/2020 2.000 1C-27 10,000.0 6,207.9 64.10 FISH GLV @ 7781' RKB, LOST SAME, DID NOT FALL INTO CATCHER Lost below this depth 3/6/2007 0.000 1C-27 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 30.9 30.9 0.15 HANGER 6.276 1C-27 33.4 33.4 0.16 HANGER 8.835 1C-27 34.0 34.0 0.16 CONDUCTOR 15.062 1C-27 989.8 981.2 15.06 PORT COLLAR 8.835 1C-27 10,528.7 6,375.4 79.80 PACKER 1 BAKER 'FAB' PACKER w/X-NIPPLE 3.813" ID 4.000 1C-27 10,533.9 6,376.3 80.01 PACKER 2 BAKER SLZXP LT PACKER w/12' TIE BACK SLEEVE - 'PACKER LEAKED' 4.000 1C-27 10,555.8 6,379.9 80.88 HANGER BAKER 5" HMC HANGER 3.958 1C-27 13,863.5 6,411.5 89.63 BUSHING PACK OFF BUSHING 3.958 1C-27 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com Wellbore 10,568.0 11,689.0 6,381.8 6,444.2 UNIT D, C-4, 1C- 27 6/30/1999 99.0 SLOTS Slotted liner 1C-27 12,165.0 13,863.0 6,432.8 6,411.5 C-4, 1C-27 6/30/1999 99.0 SLOTS Slotted Liner 1C-27 Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com Wellbore 1 1,934.0 1,799.9 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 3/8/2007 1C-27 2 3,351.2 2,607.5 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 11/19/2007 1C-27 3 5,914.7 4,005.5 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 11/19/2007 1C-27 4 7,780.9 5,017.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 11/19/2007 1C-27 5 9,074.6 5,717.2 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 7/3/2021 1C-27 6 10,018.7 6,216.1 CAMCO KBG-2 1 GAS LIFT DMY BTM 0.000 8/22/2020 1C-27 CommentSSSV: NIPPLE 1C-27, 7/6/2021 5:41:35 AMVertical schematic (actual) LINER; 10,528.7- 13,907.0 SLOTS; 12,165.0- 13,863.0 SLOTS; 10,568.0- 11,689.0 PRODUCTION; 30.9- 10,787.4 SEAL ASSY; 10,520.0 LOCATOR; 10,519.0 NIPPLE; 10,034.6 GAS LIFT; 10,018.8 FISH; 10,000.0 Packer - Patch LWR; 9,953.0 Spacer Pipe; 9,940.0 TUBING LEAK; 9,945.0 Packer - Patch UPR; 9,935.0 GAS LIFT; 9,074.6 PACKER - PATCH - LWR; 8,053.0 Spacer Pipe; 8,032.0 TUBING LEAK; 8,040.0 PACKER - PATCH - UPR; 8,027.0 GAS LIFT; 7,780.9 SURFACE; 33.4-6,916.0 GAS LIFT; 5,914.7 GAS LIFT; 3,351.2 GAS LIFT; 1,934.0 NIPPLE; 492.6 CONDUCTOR; 34.0-115.0HANGER; 28.6KUP INJ KB-Grd (ft)40.11 Rig Release Date6/30/1999AnnotationLast WO:End DateH2S (ppm) Date...TDAct Btm (ftKB)13,910.0Well AttributesField NameKUPARUK RIVER UNIT Wellbore API/UWI500292294300 Wellbore StatusINJ Max Angle & MDIncl (°)94.47 MD (ftKB)12,413.35Legal Wellname 1C-27 Common Wellname1C-27AK All Wellbores SchemK MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-27 KUPARUK RIV UNIT 1C-27 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1C-27 50-029-22943-00-00 199-043-0 G SPT 6375 1990430 1594 3843 3844 3843 3843 34 43 43 43 4YRTST P Austin McLeod 5/15/2022 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 1C-27 Inspection Date: Tubing OA Packer Depth 410 1815 1780 1775IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220515190742 BBL Pumped:1.5 BBL Returned:1.5 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 09:40:46 -08'00' Originated: Delivered to:3-Aug-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1C-27 50-029-22943-00 n/a Kuparuk River Packer Setting Record Field- Final 4-Jul-21 0 12 1D-135 50-029-22816-00 907261026 Kuparuk River Packer Setting Record Field- Final 11-Jul-21 0 13 1D-135 50-029-22816-00 907276312 Kuparuk River Packer Setting Record Field- Final 19-Jul-21 0 14 1E-34 50-029-22805-00 907273379 Kuparuk River Patch Setting Record Field- Final 17-Jul-21 0 15 1E-34 50-029-22805-00 907240278 Kuparuk River Multi Finger Caliper Field & Processed 29-Jun-21 0 16 1R-101 50-029-21404-03 907268285 Kuparuk River Leak Detect Log Field- Final 16-Jul-21 0 17 1R-101 50-029-21404-03 907269600 Kuparuk River Multi Finger Caliper Field & Processed 16-Jul-21 0 18 2K-04 50-103-20099-00 907266787 Kuparuk River Plug Setting Record Field- Final 14-Jul-21 0 19 2N-333 50-103-20525-00 906845070 Kuparuk River Cement Retainer Record Field- Final 2-Jul-21 0 110 2V-03 50-029-21040-00 907240668 Kuparuk River Plug Setting Record Field- Final 30-Jun-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:08/03/2021Wd͗ϭϵϵϬϰϯϬͲ^Ğƚ͗ϯϱϰϳϲBy Abby Bell at 2:10 pm, Aug 03, 2021 MEMORANDUM TO: Jim Regg 7(Z`t ZtIZ. P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 28, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1C-27 KUPARUK RIV UNIT 1C-27 Src: Inspector Reviewed By: P.I. Suprvn`— Comm Well Name KUPARUK RIV UNIT 1C-27 API Well Number 50-029-22943-00-00 Inspector Name: Lou Laubenstein Permit Number: 199-043-0 Inspection Date: 7/24/2021 – Insp Num: mitLOL210724132722 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IC -27 Type Inj - -W TVD 6375 - Tubing 2290 _ 2290 - 2290 - 2290 PTD 1990430 Type Test SPT JTest psi! 1594 IA 1210 3100 - 3070 - 3060 _ BBL Pumped: 1.9 BBL Returned: 1.9 OA 320 562 554 549 ' Interval OTHER IP/F P Notes: MIT -IA post patch per Sundry #321-258 ✓ Wednesday, July 28, 2021 Page 1 of 1 ! 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ME@8030'. OAL 28'. 7/5/2021 2.000 CPP45026 8,032.0 5,154.2 57.61 Spacer Pipe 21' of 2 3/8" Spacer Pipe. 7/5/2021 1.920 CPAL45006 8,040.0 5,158.5 57.71 TUBING LEAK TUBING LEAK AT 8040' 5/22/2020 3.960 8,053.0 5,165.4 57.83 PACKER - PATCH - LWR 3.76" P2P ME@8056. OAL 5' 7/4/2021 2.000 CPP45024 9,935.0 6,178.8 62.65 Packer - Patch UPR 3.76" P2P w/ Spacer Pipe and Anchor Latch. OAL 19' 8/26/2020 2.000 CPP45015 9,940.0 6,181.1 62.76 Spacer Pipe 2 3/8" Spacer Pipe and Anchor Latch 8/26/2020 1.995 CPAL45004 9,945.0 6,183.4 62.87 TUBING LEAK TUBING LEAK AT 9945' 5/11/2020 3.960 9,953.0 6,187.0 63.05 Packer - Patch LWR 3.76" P2P. OAL 5' 8/25/2020 2.000 CPP45012 10,000. 0 6,207.9 64.10 FISH GLV @ 7781' RKB, LOST SAME, DID NOT FALL INTO CATCHER Lost below this depth 3/6/2007 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,568.0 11,689.0 6,381.8 6,444.2 UNIT D, C-4, 1C -27 6/30/1999 99.0 SLOTS Slotted liner 12,165.0 13,863.0 6,432.8 6,411.5 C-4, 1C-27 6/30/1999 99.0 SLOTS Slotted Liner Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 1,934.0 1,799.9 42.99 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 3/8/2007 2 3,351.2 2,607.5 55.99 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 11/19/2007 3 5,914.7 4,005.5 57.10 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 11/19/2007 4 7,780.9 5,017.3 57.12 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 11/19/2007 5 9,074.6 5,717.2 55.71 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 7/3/2021 6 10,018.7 6,216.1 64.53 CAMCO KBG-2 1 GAS LIFT DMY BTM 0.000 8/22/2020 1C-27, 7/7/2021 12:29:53 PM Vertical schematic (actual) LINER; 10,528.7-13,907.0 SLOTS; 12,165.0-13,863.0 SLOTS; 10,568.0-11,689.0 PRODUCTION; 30.9-10,787.4 GAS LIFT; 10,018.8 FISH; 10,000.0 Packer - Patch LWR; 9,953.0 Spacer Pipe; 9,940.0 TUBING LEAK; 9,945.0 Packer - Patch UPR; 9,935.0 GAS LIFT; 9,074.6 PACKER - PATCH - LWR; 8,053.0 Spacer Pipe; 8,032.0 TUBING LEAK; 8,040.0 PACKER - PATCH - UPR; 8,027.0 GAS LIFT; 7,780.9 SURFACE; 33.4-6,916.0 GAS LIFT; 5,914.7 GAS LIFT; 3,351.2 GAS LIFT; 1,934.0 NIPPLE; 492.6 CONDUCTOR; 34.0-115.0 KUP INJ KB-Grd (ft) 40.11 Rig Release Date 6/30/1999 1C-27 ... TD Act Btm (ftKB) 13,910.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292294300 Wellbore Status INJ Max Angle & MD Incl (°) 94.47 MD (ftKB) 12,413.35 WELLNAME WELLBORE1C-27 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 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: Tubing Patch 2.Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13907 N/A N/A Casing Collapse Conductor N/A Surface N/A Production N/A Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR: SSSV:SSSV: 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:5/26/2021 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 659-7224 Seal Assembly 10520 N/A Seal Assembly 6377 N/A Size Authorized Signature: 6/10/2021 4.5 Perforation Depth MD (ft): L-80 COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 6382 - 6444, 6433 - 6412 Perforation Depth TVD (ft):Tubing Size: 10568 - 11689, 12165 - 13863 Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025649 199-043 P.O. Box 100630, Anchorage, Alaska 99508 50029229430000' ConocoPhillips Alaska, Inc. Kuparuk River / Kuparuk River Oil KRU 1C-27 6412 13221 PRESENT WELL CONDITION SUMMARY 6401 N/A Length TVD Burst 10535 MD N/A N/A N/A 4547 6403 6916 10756 115 115 10787 81 16 9.625 7 6883 Well Integrity & Compliance Specialist Jan Byrne Jan.Byrne@conocophillips.com m n P 66 t Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:38 pm, May 26, 2021 321-258 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室宇室宷宨孽季孵孳孵孴孱孳學孱孵孹季孴孶孽孶孳孽孷孹孰孳孻孪孳孳孪安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孴孱孶 Jan Byrne DSR-5/26/21 X : ADL0028242 DLB DLB 05/27/2021 VTL 6/4/21 X X 10-404 dts 6/4/2021 JLC 6/4/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.04 11:29:35 -08'00' RBDMS HEW 6/4/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 26, 2021 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 1C-27 (PTD 199-043) to install a retrievable tubing patch over a known tubing leak. Please contact me at 659-7244 if you have any questions. Sincerely, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室宇室宷宨孽季孵孳孵孴孱孳學孱孵孹季孴孶孽孶孳孽孳孴孰孳孻孪孳孳孪安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孴孱孶 Jan Byrne Well Work Justification & Objectives (and date required if appropriate): 1C-27 was reported by Operations to be exhibiting suspect TxIA communication. A follow up MITIA failed and the well was shut in and freeze protected, and reported to the AOGCC. Slickline HF diagnostics indicated a leak between 7997' and 8095' and a TxIA LLR of 3.6 GPM at 3000 psi was established. A CMIT TxIA passed proving the patch, tubing below the patch, packer, and production casing integrity. An acoustic log was performed and confirmed a tubing leak at 8040'. The Well Work Request steps below outline the plan to patch the tubing leak. Risk/Job Concerns: • TxIA communication. During the acoustic LDL the LLR increased from 4 GPM to 17 GPM at 3000 psi. • Test tool set in P2P tubing patch with 1.995" ID set at 9935' • Need approved sundry from the AOGCC prior to starting work Steps: Relay 1. Pull test tool from patch at 9935'. 2. Set catcher and pull dummy valve at 9075'. 3. Pump down IA taking returns to formation with 128 bbls seawater w/ 54 gallons of CRW-132 followed by 41 bbls diesel for freeze protect. 4. Sit over GLM #5 with new dummy valve and install dummy valve at 9075' once complete pumping fluids down IA. 5. Pull catcher. 6. Brush and flush tubing. 7. RIH with smart holefinder to acquire combo PT TxIA at 8056' and PT tubing at 8030' (planned packer set depths). 8. If PTs pass RIH with lower P2P and set mid element at 8056'. Correlate with LDL 5.21.21. 9. RIH to sting into lower P2P with test tool and perform CMIT TxIA to 3000 psi. Record TIOs. Pull test tool. 10. RIH with upper patch assembly to sting into the lower P2P. The patch should be 26' element to element setting the upper the P2P mid element at 8030'. 11. Perform MITIA to 3000 psi. Record TIOs. 12. RDMO, turn well over to Operations. 13. DHD to perform SW MITIA once well has stabilized. SW MITIA once well has stabilized. 1C-27 was reported by Operations to be exhibiting suspect TxIA communication. s indicated a leak between 7997' and 8095' and a TxIA LLR of 3.6 GPM at 3000 psi w Last Tag Annotation Depth (ftKB) End Date Last Mod By Wellbore Last Tag: CTM 13,221.0 2/25/2009 ninam 1C-27 Last Rev Reason Annotation End Date Last Mod By Wellbore Rev Reason: Set Patch 8/26/2020 famaj 1C-27 Notes: General & Safety End Date 3/6/2007 Annotation NOTE: 1" GLV/BL LATCH LOST IN WELL Wellbore 1C-27 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Wellbore CONDUCTOR 16 15.06 34.0 115.0 115.0 62.58 H-40 WELDED 1C-27 SURFACE 9 5/8 8.83 33.4 6,916.0 4,546.6 40.00 L-80 BTC-MOD 1C-27 PRODUCTION 7 6.28 30.9 10,787.4 6,403.1 26.00 L-80 BTC-MOD 1C-27 LINER 4 1/2 3.96 10,528.7 13,907.0 6,411.8 12.60 L-80 ABT-MOD 1C-27 Tubing Strings Des String Max Nominal OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt (lb/ft) Grade Top Thread Wellbore TUBING 4 1/2 3.96 28.6 10,535.3 6,376.5 12.60 L-80 ABT-MOD 1C-27 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 28.6 28.6 0.13 HANGER FMC GEN IV 5M HANGER 4.500 1C-27 492.6 492.2 5.60 NIPPLE CAMCO DB NIPPLE 3.812 1C-27 10,034.6 6,222.8 64.94 NIPPLE HES X NIPPLE 3.813 1C-27 10,518.9 6,373.6 79.41 LOCATOR BAKER LOCATOR 3.850 1C-27 10,520.0 6,373.8 79.45 SEAL ASSY BAKER 80-47 SEAL ASSEMBLY 4.000 1C-27 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) Wellbore 9,935.0 6,178.8 62.65 Packer - Patch UPR 3.76" P2P w/ Spacer Pipe and Anchor Latch. OAL 19' 8/26/2020 2.000 1C-27 9,940.0 6,181.1 62.76 Spacer Pipe 2 3/8" Spacer Pipe and Anchor Latch 8/26/2020 1.995 1C-27 9,945.0 6,183.4 62.87 TUBING LEAK TUBING LEAK AT 9945' 5/11/2020 3.960 1C-27 9,953.0 6,187.0 63.05 Packer - Patch LWR 3.76" P2P. OAL 5' 8/25/2020 2.000 1C-27 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 30.9 30.9 0.15 HANGER 6.276 1C-27 33.4 33.4 0.16 HANGER 8.835 1C-27 34.0 34.0 0.16 CONDUCTOR 15.062 1C-27 989.8 981.2 15.06 PORT COLLAR 8.835 1C-27 10,528.7 6,375.4 79.80 PACKER 1 BAKER 'FAB' PACKER w/X-NIPPLE 3.813" ID 4.000 1C-27 10,533.9 6,376.3 80.01 PACKER 2 BAKER SLZXP LT PACKER w/12' TIE BACK SLEEVE - 'PACKER LEAKED' 4.000 1C-27 10,555.8 6,379.9 80.88 HANGER BAKER 5" HMC HANGER 3.958 1C-27 13,863.5 6,411.5 89.63 BUSHING PACK OFF BUSHING 3.958 1C-27 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com Wellbore 10,568.0 11,689.0 6,381.8 6,444.2 UNIT D, C-4, 1C- 27 6/30/1999 99.0 SLOTS Slotted liner 1C-27 12,165.0 13,863.0 6,432.8 6,411.5 C-4, 1C-27 6/30/1999 99.0 SLOTS Slotted Liner 1C-27 Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com Wellbore 1 1,934.0 1,799.9 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/8/2007 1C-27 2 3,351.2 2,607.5 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/19/2007 1C-27 3 5,914.7 4,005.5 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/19/2007 1C-27 4 7,780.9 5,017.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/19/2007 1C-27 5 9,074.6 5,717.2 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/19/2007 1C-27 6 10,018.7 6,216.1 CAMCO KBG-2 1 GAS LIFT DMY BTM 0.000 0.0 8/22/2020 1C-27 Comment SSSV: NIPPLE 1C-27, 8/27/2020 7:49:17 AM Vertical schematic (actual) LINER; 10,528.7- 13,907.0 SLOTS; 12,165.0- 13,863.0 SLOTS; 10,568.0- 11,689.0 PRODUCTION; 30.9- 10,787.4 GAS LIFT; 10,018.8 Packer - Patch LWR; 9,953.0 Spacer Pipe; 9,940.0 TUBING LEAK; 9,945.0 Packer - Patch UPR; 9,935.0 GAS LIFT; 9,074.6 GAS LIFT; 7,780.9 SURFACE; 33.4-6,916.0 GAS LIFT; 5,914.7 GAS LIFT; 3,351.2 GAS LIFT; 1,934.0 NIPPLE; 492.6 CONDUCTOR; 34.0- 115.0 KUP INJ KB-Grd (ft) 40.11 Rig Release Date 6/30/1999 Annotation Last WO: End DateH2S (ppm) Date... TD Act Btm (ftKB) 13,910.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292294300 Wellbore Status INJ Max Angle & MD Incl (°) 94.47 MD (ftKB) 12,413.35 Legal Wellname 1C-27 Common Wellname1C-27 AK All Wellbores Schem C:\Users\aebell\Desktop\May 2021 Data Drop\CPA Data Drop 06012021\2021-05-21_15780_KUP 1C-27_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15780 KUP 1C-27 50-029-22943-00 LeakPoint Survey 21-May-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM Abby Bell PTD: 1990430 E-Set: 35175 Wallace, Chris D (CED) From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, April 21, 2021 9:30 AM To: Wallace, Chris D (CED) Cc: Earhart, Will C Subject: KRU 1C-27 (PTD 199-043) Report of suspect IA pressurization Attachments: 1 C-27.pdf, 1 C-27 90 day TIO trend 4.21.21.pdf Chris, KRU 1C-27 (PTD 199-043) was reported by Operations this morning to be exhibiting suspect IA pressurization. The IA pressure was bled, but immediately began re -pressurizing. The well is being shut in and freeze protected ASAP. DHD will be begin initial diagnostics within the next few days. The proper paperwork for continued injection or corrective action will be submitted once a path forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 Originated:Delivered to:9-Nov-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 1A-24 50-029-22984-00 906642121 Kuparuk River Plug Setting Record Field- Final 5-Aug-20 0 1 2 1C-27 50-029-22943-00 n/a Kuparuk River Packer Setting Record Field- Final 25-Aug-20 0 1 3 1F-19 50-029-22660-00 906642776 Kuparuk River Packer Setting Record Field- Final 6-Aug-20 0 1 4 1Y-27 50-029-22379-00 n/a Kuparuk River Production Profile Field- Final 29-Aug-20 0 1 5 2B-02A 50-029-21154-01 906679203 Kuparuk River Multi Finger Caliper Field- Processed 29-Aug-20 0 1 6 2C-15 50-029-21219-00 n/a Kuparuk River Packer Setting Record Field- Final 30-Aug-20 0 1 7 2G-08 50-029-21125-00 906659316 Kuparuk River Packer Setting Record Field- Final 16-Aug-20 0 1 8 2L-301 50-103-20588-00 906671629 Kuparuk River Plug Setting Record Field- Final 24-Aug-20 9 2L-301 50-103-20588-00 906671629 Kuparuk River Tubing Punch Record Field- Final 25-Aug-20 10 2M-33 50-103-20240-00 906598622 Kuparuk River Leak Detect Log Field- Final 13-Aug-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 Received by the AOGCC 11/09/2020 11/09/2020 Abby Bell PTD: 1990430 E-Set: 34220 MEMORANDUM TO: Jim Regg P.I. Supervisor 2 tl(�(iiti FROM: Adam Earl Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, September 10, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1C-27 KUPARUKRIV UNIT IC -27 Src: Inspector Reviewed By: P.I. Suprv3j�LL- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IC -27 API Well Number 50-029-22943-00-00 Inspector Name: Adam Earl Permit Number: 199-043-0 Inspection Date: 9/6/2020 Insp Num: mitAGE200908095957 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IC -27 - jType Inj w ' TVD 6375 Tubing 1708 1711 1709 - 170& - -- PTD 1990430 iType Test•, SPT' Test psi 1594 IA 865 2620 ' 2565 2560 - BBL Pumped: 1.6 -BBL Returned: 1.4 OA 271 428 - 422 - 418 - Interval OTHER !P/F P Notes' MIT IA Post Patch Tested as per Sundry 320-331 Thursday, September 10, 2020 Page 1 of 1 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing Patch ConocoPhillips Alaska, Inc.Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13910 feet 10035'feet true vertical 6412 feet N/A feet Effective Depth measured 10035 feet 10520 feet true vertical 6223 feet 6374 feet Perforation depth Measured depth Slotted liner feet True Vertical depth Slotted liner feet Tubing (size, grade, measured and true vertical depth)4.5 L-80 10535 6377 Packers and SSSV (type, measured and true vertical depth)Baker 80-47 Seal Assem10520 MD 6374 TVD None None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: 9/6/2020 Contact Phone: 199-043 50029229430000' ADL0025649|ADL0028242 KRU 1C-27 P.O. Box 100630, Anchorage, Alaska 99508 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number: Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk River/ Kuparuk River Oil Plugs measured Junk measured Burst Collapse Conductor 81 16 115 115 N/A N/A N/A Production 10756 7 10787 6403 N/A N/A Surface 6883 9.625 6919 4547 N/A ----- N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 320-331 Authorized Name: Authorized Signature with date: Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Jan Byrne / Dusty Freeborn n1617@conocophillips.com 659-7224 Well Integrity & Compliance Specialist ----- t Fra O 6. A G L PG R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:28 am, Sep 08, 2020 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷宏宲宦室宷宬宲宱孽季安季宺宬宱宪孯季宎宒宆孯季宎宸害室宵宸宮宇室宷宨孽季孵孳孵孳孰孳孼孰孳孺季孳孺孽學孳孽孶學安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孳孱孳 Jan Byrne SFD 9/8/2020DSR-9/8/2020 RBDMS HEW 9/8/2020 VTL 10/01/20 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 6, 2020 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 for Sundry 320-331 well operations from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in well KRU 1C-27 (PTD 199-043). Please contact Dusty Freeborn or me at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. 宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷宏宲宦室宷宬宲宱孽季安季宺宬宱宪孯季宎宒宆孯季宎宸害室宵宸宮宇室宷宨孽季孵孳孵孳孰孳孼孰孳孺季孳孺孽學孳孽孵孷安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孳孱孳 Jan Byrne Date Event Summary Executive Summary 1C-27 was reported to the AOGCC on 5/3/20 for suspected TxIA communication, the well was shut in and secured. A diganostic LDL located a tubing leak at 9945'. A 4.5", 22' OAL, retrievable tubing patch utilizing Paragon 2 Packers was installed over the tubing leak. Subsequent testing passed. Pertinent well work is copied below. 05/08/20 SET 3.81" XX PLUG @ 10,035' RKB; CMIT TBG X IA TO 2500 PSI (PASSED) DRAW DOWN TBG X IA TO 1300 PSI. JOB COMPLETE AND READY FOR E-LINE LEAK DETECT. NOTE: JUMPER EQUIPMENT & MEOH PUP ON LOCATION FOR LDL. C-MIT. PRE=2675/2411/30 INITIAL=2850/2546/30 15MIN=2825/2546/30 30MIN=2825/2548/30 BLEED TBG PSI. 05/11/20 PERFORM LEAK DETECTION LOG. LLR ESTABISHED .35 BPM @ 2500 PSI. LEAK FOUND @ 9945'. 08/25/20 SET 3.76" LOWER P2P (SN:CPP45012) @ 9953' RKB (ME). IN PROGRESS 08/26/20 RAN 4.5" TTS TEST TOOL TO LOWER P2P @ 9953' RKB, OBTAINED PASSING CMIT- TXIA TO 2500 PSI, PULLED TTS TEST TOOL, RAN 3.76" UPPER P2P (SN:CPP45015) W/ SPACER & ANCHOR LATCH (SN:CPAL45004) @ 9935' RKB (ME), OBTAINED PASSING MIT-IA TO 2500 PSI. JOB COMPLETE CMIT TO 2500 PSI PRE = 1200/1025/30, INITIAL = 2600/2510/30 1.5BBLS PUMPED 15 MIN = 2575/2490/30, 30 MIN = 2575/2480/30 << PASS >> BLEED BACK EQ & PULL TEST TOOL, POOH MIT-IA PRE = 1250/1100/30, INITIAL = 1250/2500/30 1BBL TO PRESSURE UP 15 MIN = 1250/2450/30, 30 MIN = 1250/2450/30 << PASS >> BLEED BACK, 09/06/20 (SW) STATE WITNESSED (ADAM EARL) POST PATCH MIT-IA TO 2620 PSI (PASSED) Initial T/I//O = 1708/865/271. IA FL @ SF. Pressurize IA to 2620 psi w/ 1.6 bbls of diesel. Monitor 30 min. Starting T/I/O = 1711/2620/428. 15 min T/I/O = 1709/2565/422 (-55). 30 min T/I/O = 1708/2560/418 (-5). Bled IA to 865 psi (1.4 bbls back). Final T/I/O = 1708/865/270. Last Tag Annotation Depth (ftKB) End Date Last Mod By Wellbore Last Tag: CTM 13,221.0 2/25/2009 ninam 1C-27 Last Rev Reason Annotation End Date Last Mod By Wellbore Rev Reason: Set Patch 8/26/2020 famaj 1C-27 Notes: General & Safety End Date 3/6/2007 Annotation NOTE: 1" GLV/BL LATCH LOST IN WELL Wellbore 1C-27 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Wellbore CONDUCTOR 16 15.06 34.0 115.0 115.0 62.58 H-40 WELDED 1C-27 SURFACE 9 5/8 8.83 33.4 6,916.0 4,546.6 40.00 L-80 BTC-MOD 1C-27 PRODUCTION 7 6.28 30.9 10,787.4 6,403.1 26.00 L-80 BTC-MOD 1C-27 LINER 4 1/2 3.96 10,528.7 13,907.0 6,411.8 12.60 L-80 ABT-MOD 1C-27 Tubing Strings Des String Max Nominal OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt (lb/ft) Grade Top Thread Wellbore TUBING 4 1/2 3.96 28.6 10,535.3 6,376.5 12.60 L-80 ABT-MOD 1C-27 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 28.6 28.6 0.13 HANGER FMC GEN IV 5M HANGER 4.500 1C-27 492.6 492.2 5.60 NIPPLE CAMCO DB NIPPLE 3.812 1C-27 10,034.6 6,222.8 64.94 NIPPLE HES X NIPPLE 3.813 1C-27 10,518.9 6,373.6 79.41 LOCATOR BAKER LOCATOR 3.850 1C-27 10,520.0 6,373.8 79.45 SEAL ASSY BAKER 80-47 SEAL ASSEMBLY 4.000 1C-27 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) Wellbore 9,935.0 6,178.8 62.65 Packer - Patch UPR 3.76" P2P w/ Spacer Pipe and Anchor Latch. OAL 19' 8/26/2020 2.000 1C-27 9,940.0 6,181.1 62.76 Spacer Pipe 2 3/8" Spacer Pipe and Anchor Latch 8/26/2020 1.995 1C-27 9,945.0 6,183.4 62.87 TUBING LEAK TUBING LEAK AT 9945' 5/11/2020 3.9601C-27 9,953.0 6,187.0 63.05 Packer - Patch LWR 3.76" P2P. OAL 5' 8/25/2020 2.000 1C-27 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 30.9 30.9 0.15 HANGER 6.276 1C-27 33.4 33.4 0.16 HANGER 8.835 1C-27 34.0 34.0 0.16 CONDUCTOR 15.062 1C-27 989.8 981.2 15.06 PORT COLLAR 8.835 1C-27 10,528.7 6,375.4 79.80 PACKER 1 BAKER 'FAB' PACKER w/X-NIPPLE 3.813" ID 4.000 1C-27 10,533.9 6,376.3 80.01 PACKER 2 BAKER SLZXP LT PACKER w/12' TIE BACK SLEEVE - 'PACKER LEAKED' 4.000 1C-27 10,555.8 6,379.9 80.88 HANGER BAKER 5" HMC HANGER 3.958 1C-27 13,863.5 6,411.5 89.63 BUSHING PACK OFF BUSHING 3.958 1C-27 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com Wellbore 10,568.0 11,689.0 6,381.8 6,444.2 UNIT D, C-4, 1C- 27 6/30/1999 99.0 SLOTS Slotted liner 1C-27 12,165.0 13,863.0 6,432.8 6,411.5 C-4, 1C-27 6/30/1999 99.0 SLOTS Slotted Liner 1C-27 Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com Wellbore 1 1,934.0 1,799.9 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/8/2007 1C-27 2 3,351.2 2,607.5 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/19/2007 1C-27 3 5,914.7 4,005.5 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/19/2007 1C-27 4 7,780.9 5,017.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/19/2007 1C-27 5 9,074.6 5,717.2 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/19/2007 1C-27 6 10,018.7 6,216.1 CAMCO KBG-2 1 GAS LIFT DMY BTM 0.000 0.0 8/22/2020 1C-27 Comment SSSV: NIPPLE 1C-27, 8/27/2020 7:49:17 AM Vertical schematic (actual) LINER; 10,528.7- 13,907.0 SLOTS; 12,165.0- 13,863.0 SLOTS; 10,568.0- 11,689.0 PRODUCTION; 30.9- 10,787.4 GAS LIFT; 10,018.8 Packer - Patch LWR; 9,953.0 Spacer Pipe; 9,940.0 TUBING LEAK; 9,945.0 Packer - Patch UPR; 9,935.0 GAS LIFT; 9,074.6 GAS LIFT; 7,780.9 SURFACE; 33.4-6,916.0 GAS LIFT; 5,914.7 GAS LIFT; 3,351.2 GAS LIFT; 1,934.0 NIPPLE; 492.6 CONDUCTOR; 34.0- 115.0 KUP INJ KB-Grd (ft) 40.11 Rig Release Date 6/30/1999 Annotation Last WO: End DateH2S (ppm) Date... TD Act Btm (ftKB) 13,910.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292294300 Wellbore Status INJ Max Angle & MD Incl (°) 94.47 MD (ftKB) 12,413.35 Legal Wellname 1C-27 Common Wellname1C-27 AK All Wellbores Schem Submit to: OOPERATOR: FIELD /UNIT /PA D: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1990430 Type Inj W Tubing 1708 1711 1709 1708 Type Test P Packer TVD 6375 BBL Pump 1.6 IA 865 2620 2565 2560 Interval O Test psi 1594 BBL Return 1.4 OA 271 428 422 418 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 ConocoPhillips Alaska Inc, Kuparuk / KRU / 1C Pad Adam Earl Weimer / Beck 09/06/20 Notes:MITIA to prove integrity post patch per Sundry # 320-331 Notes: 1C-27 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c al Int egr i t y Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)MIT KRU 1C-27 09-06-20.xlsx 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: Tubing Patch 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13910 N/A Casing Collapse Conductor N/A Surface N/A Production N/A Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR: SSSV:SSSV: 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:8/10/2020 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 659-7224 Baker 80-47 Seal Assembly None 10520 MD 6374 TVD None Size Authorized Signature: 8/20/2020 4.5 Perforation Depth MD (ft): L-80 COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): Slotted liner Perforation Depth TVD (ft):Tubing Size: Slotted liner Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025649|ADL0028242 199-043 P.O. Box 100630, Anchorage, Alaska 99508 50029229430000' ConocoPhillips Alaska, Inc. Kuparuk River/ Kuparuk River Oil KRU 1C-27 6412 10035 PRESENT WELL CONDITION SUMMARY 6223 10035'N/A Length TVD Burst 10535 MD N/A N/A N/A 4547 6403 6919 10756 115 115 10787 81 16 9.625 7 6883 Well Integrity & Compliance Specialist Jan Byrne / Dusty Freeborn n1617@conocophillips.com m n P 66 t h Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:17 pm, Aug 10, 2020 320-331 Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-08-10 14:06:02 Foxit PhantomPDF Version: 10.0.0 jan.byrne@conoco phillips.com X NA DLB DLB 08/10/2020 DSR-8/10/2020 10-404 X X VTL 8/11/20 q C 8/11/2020 JLC 8/11/2020 RBDMS HEW 8/11/2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 10 August 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 1C-27 (PTD 199-043) to set a retrievable tubing patch over a known tubing leak. Please contact Dusty Freeborn or myself at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-08-10 14:05:43 Foxit PhantomPDF Version: 10.0.0 jan.byrne@co nocophillips.c om Proposal Summary KRU 1C-27 was reported to the AOGCC on 5/3/2020 for exhibiting TxIA communication. The well was secured with an XX plug at 10,035’ and a passing CMIT TxIA was acquired on 5/8/2020. An LDL identified a tubing leak at 9945’ on 5/11/2020. CPAI intends to set a 4.5”, Paragon 2 Packer, ~22’ OAL, retrievable patch over the tubing leak. Below is the planned work, the work may change slightly as wellbore conditions dictate. Well Work Justification & Objectives (and date required if appropriate): 1C-27 was reported for high IAP after which the well was SI and FP. An LDL located a tubing leak at 9945'. The well needs a tubing patch to regain tubing integrity and return the well to injection. In addition the well should be circ'd out, and a SBHP is added from a PE WWR. Risk/Job Concerns: TxIA communication LLR of 12.6 gpm at 2650 psi. CMIT TxIA passed on 5/8/20. Well has had surface subsidence issues in the past. Do not start work until 10-403 is approved by AOGCC. Steps: Slickline/LRS Need jumper line rigged from IA to production 1. RIH to set catcher and pull dummy valve from 10,019'. 2. Circ well out pumping down tubing taking returns up IA to production with 272 bbls (T-118, IA-154) corrosion inhibited seawater and 76 bbls (T-34, IA-42) diesel. U-tube TxIA until fluids have equalized. 3. RIH to set dummy valve at 10,019'. 4. RIH to pull catcher and XX plug at 10,035'. 5. Obtain C-sand SBHP with dual gauges: i. Perform 10 minute lubricator stop. ii. RIH to 10500’ RKB and obtain 30 minute static iii. Pull up to 10154’ RKB and complete 15 minute gradient stop. iv. Perform 10 minute lubricator stop. 6. RIH to brush and flush around patch set area 9900' to 10,000'. Relay 7. RIH with lower P2P to set mid element at 9953'. Correlate with 5/11/20 LDL. 8. RIH with test tool to sting into P2P. Perform CMIT TxIA to 2500 psi, Record TIOs, pull test tool. 9. RIH with upper patch assembly and sting into lower P2P. Patch should be 18' element to element setting the upper P2P at 9935'. 10. Perform MITIA to 2500 psi. Record TIOs. 11. RDMO, turn well over to Operations, will require SW MITIA once BOI and stabilized (notify DHD supervisor). Last Tag Annotation Depth (ftKB) End Date Last Mod By Wellbore Last Tag: CTM 13,221.0 2/25/2009 ninam 1C-27 Last Rev Reason Annotation End Date Last Mod By Wellbore Rev Reason: Identified Tbg Leak & Set Plug 5/8/2020 zembaej 1C-27 Notes: General & Safety End Date 3/6/2007 Annotation NOTE: 1" GLV/BL LATCH LOST IN WELL Wellbore 1C-27 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Wellbore CONDUCTOR 16 15.06 34.0 115.0 115.0 62.58 H-40 WELDED 1C-27 SURFACE 9 5/8 8.83 33.4 6,916.0 4,546.6 40.00 L-80 BTC-MOD 1C-27 PRODUCTION 7 6.28 30.9 10,787.4 6,403.1 26.00 L-80 BTC-MOD 1C-27 LINER 4 1/2 3.96 10,528.7 13,907.0 6,411.8 12.60 L-80 ABT-MOD 1C-27 Tubing Strings Des String Max Nominal OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt (lb/ft) Grade Top Thread Wellbore TUBING 4 1/2 3.96 28.6 10,535.3 6,376.5 12.60 L-80 ABT-MOD 1C-27 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 28.6 28.6 0.13 HANGER FMC GEN IV 5M HANGER 4.500 1C-27 492.6 492.2 5.60 NIPPLE CAMCO DB NIPPLE 3.812 1C-27 10,034.6 6,222.8 64.94 NIPPLE HES X NIPPLE 3.813 1C-27 10,518.9 6,373.6 79.41 LOCATOR BAKER LOCATOR 3.850 1C-27 10,520.0 6,373.8 79.45 SEAL ASSY BAKER 80-47 SEAL ASSEMBLY 4.000 1C-27 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) Wellbore 9,945.0 6,183.4 62.87 TUBING LEAK TUBING LEAK AT 9945' 5/11/2020 3.960 1C-27 10,035.0 6,223.0 64.95 3.813" XX Plug 3.813" XX Plug w/ Fill Extension (3' 7" OAL w/ four 3/16 eq ports & four 1/8 eq ports) 5/8/2020 0.000 1C-27 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 30.9 30.9 0.15 HANGER 6.276 1C-27 33.4 33.4 0.16 HANGER 8.835 1C-27 34.0 34.0 0.16 CONDUCTOR 15.062 1C-27 989.8 981.2 15.06 PORT COLLAR 8.835 1C-27 10,528.7 6,375.4 79.80 PACKER 1 BAKER 'FAB' PACKER w/X-NIPPLE 3.813" ID 4.000 1C-27 10,533.9 6,376.3 80.01 PACKER 2 BAKER SLZXP LT PACKER w/12' TIE BACK SLEEVE - 'PACKER LEAKED' 4.000 1C-27 10,555.8 6,379.9 80.88 HANGER BAKER 5" HMC HANGER 3.958 1C-27 13,863.5 6,411.5 89.63 BUSHING PACK OFF BUSHING 3.958 1C-27 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com Wellbore 10,568.0 11,689.0 6,381.8 6,444.2 UNIT D, C-4, 1C- 27 6/30/1999 99.0 SLOTS Slotted liner 1C-27 12,165.0 13,863.0 6,432.8 6,411.5 C-4, 1C-27 6/30/1999 99.0 SLOTS Slotted Liner 1C-27 Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com Wellbore 1 1,934.0 1,799.9 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 3/8/2007 1C-27 2 3,351.2 2,607.5 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/19/2007 1C-27 3 5,914.7 4,005.5 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/19/2007 1C-27 4 7,780.9 5,017.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/19/2007 1C-27 5 9,074.6 5,717.2 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/19/2007 1C-27 6 10,018.7 6,216.1 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 11/20/2007 1C-27 Comment SSSV: NIPPLE 1C-27, 5/11/2020 1:53:24 PM Vertical schematic (actual) LINER; 10,528.7- 13,907.0 SLOTS; 12,165.0- 13,863.0 SLOTS; 10,568.0- 11,689.0 PRODUCTION; 30.9- 10,787.4 SEAL ASSY; 10,520.0 LOCATOR; 10,519.0 3.813" XX Plug; 10,035.0 NIPPLE; 10,034.6 GAS LIFT; 10,018.8 TUBING LEAK; 9,945.0 GAS LIFT; 9,074.6 GAS LIFT; 7,780.9 SURFACE; 33.4-6,916.0 GAS LIFT; 5,914.7 GAS LIFT; 3,351.2 GAS LIFT; 1,934.0 NIPPLE; 492.6 CONDUCTOR; 34.0- 115.0 HANGER; 28.6 KUP INJ KB-Grd (ft) 40.11 Rig Release Date 6/30/1999 Annotation Last WO: End DateH2S (ppm) Date... TD Act Btm (ftKB) 13,910.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292294300 Wellbore Status INJ Max Angle & MD Incl (°) 94.47 MD (ftKB) 12,413.35 Legal Wellname 1C-27 Common Wellname1C-27 AK All Wellbores Schem WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED Sharefile CD's 1G-05 50-029-20908-00 1005117.1S10 KUPARUK RIVER WL LDL FINAL FIELD 9-May-20 1 1G-05 50-029-20908-00 1005117.1S10 KUPARUK RIVER WL Caliper FINAL FIELD 9-May-20 1 1C-27 50-029-22943-00 1005117.1S11 KUPARUK RIVER WL Caliper FINAL FIELD 10-May-20 1 1C-27 50-029-22943-00 1005117.1S12 KUPARUK RIVER WL LDL FINAL FIELD 11-May-20 1 4 Delivery Receipt ________________________________X____________________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. AlaskaPTSPrintCenter@slb.com SLB Auditor - A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private Received by the AOGCC 05/14/2020 PTD: 1990430 E-Set: 33086 Abby Bell Abby Bell 05/18/2020 WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED Sharefile CD's 1G-05 50-029-20908-00 1005117.1S10 KUPARUK RIVER WL LDL FINAL FIELD 9-May-20 1 1G-05 50-029-20908-00 1005117.1S10 KUPARUK RIVER WL Caliper FINAL FIELD 9-May-20 1 1C-27 50-029-22943-00 1005117.1S11 KUPARUK RIVER WL Caliper FINAL FIELD 10-May-20 1 1C-27 50-029-22943-00 1005117.1S12 KUPARUK RIVER WL LDL FINAL FIELD 11-May-20 1 4 Delivery Receipt ________________________________X____________________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. AlaskaPTSPrintCenter@slb.com SLB Auditor - A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private Received by the AOGCC 05/14/2020 PTD: 1990430 E-Set: 33085 Abby Bell Abby Bell 05/18/2020 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPH & 2 <n1617@conocophillips.com> Sent: Sunday, May 3, 2020 6:29 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1C-27 (PTD 199-043) Report of annular communication Attachments: 1 C-27.pdf, 1 C-27 90 day TIO trend 5.3.20.pdf Chris, KRU injection well 1C-27 (PTD 199-043) was shut in last night after exhibiting suspected TxIA communication. The current plan is to secure the well with a tubing plug and begin diagnostics to locate and repair the source of communication. The proper paperwork for continued injection or corrective action will be submitted once the path forward has been determined. A 90 day TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Cell phone: (808) 345-6886 Office phone: (907) 659-7224 WELLS TEAM CwipcoPF+iNips MEMORANDA!? State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,May 16,2018 P.I.Supervisor ' 14 �4 Z�( U SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1C-27 FROM: Austin McLeod KUPARUK RIV UNIT 1C-27 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-27 API Well Number 50-029-22943-00-00 Inspector Name: Austin McLeod Permit Number: 199-043-0 Inspection Date: 5/13/2018 Insp Num: mitSAM180514083436 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well lc-z7 Type Inj wTVD_ — 6375 Tubing2366 ' 2364 - 2362 '1 2365 " I ' j PTD -_---- -�---- --- _ 1990430 1Type Test SPT Test psi 1594 IA 815 1810 1780 1770 ' BBL Pumped: 1 1.5 BBL Returned: 1.3 OA 338 " 462 " 454 ' 449 Interval T 4YRTST P/F P ✓ Notes: MIT-IA S OW) JUN 0 1201$ Wednesday,May 16,2018 Page 1 of 1 Image( .'oject Well History' File Cover R, je XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J/_~_~- D_L~.~ Well History File Identifier Organizing 7CAN Color items: [] Grayscale items: Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL ~INDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds DATE: ~1~/~]03/S;t h ~rp Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~WINDY Scanning Preparation .~_"~ x 30 = ~ (~ BY: BEVERLY ROBIN VINCENT SHERYL ~INDY DATE: Is~ TOTAL PAGES 0 Production Scanning Stage I PAGE COUNT FROM, SCANNED FILE: BY: Stage 2 /O7 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES BY: IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO RESCANNEDB'Y: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: Is~ Quality Checked 12/10/02Rev3NOTScanned.wpd MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission 6 I ~~ I l Q DATE: Tuesday, May 25, 2010 TO: Jim Regg t P.I. Supervisor ~ ~ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-27 FROM: John Crisp KUPARUK RIV UNIT 1C-27 Petroleum Inspector Src: Inspector NnN-CnNFiDENTIAL Reviewed By: P.I. Suprv ~~~- Comm Well Name: KUPARUK RIV UNIT 1C-27 API Well Number: 50-029-22943-00-00 Inspector Name: John Crisp Insp Num: mitJCr100524065040 Permit Number: 199-043-0 Inspection Date: 5/21/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 1c-27 Type Inj. ' G ~ TVD 637s ~~ IA ss o --- z23o z19o zlao P.T.Di 1990430 "TypeTest ;'PT Test psi 1593 ~A 132 I -~- ~ 1 J 238 ; 236 228 - ---- . ----- --- InteYVa14YRTST p~F, P ~ Tubing' 3762 3771 376 3767 ~ Notes: 2.6 bbls pumped for test. ANS] 1500 flange installed on IA valve. With the high gas injection pressure & possible thermal expansion the IA could exceed rated working pressure of A SI 1500 flange. Not good industry practice on gas injectors. Operator Reps made aware of deficency. c~ ~I~CeS~'. re~,~~ r~ use r ST 15'Z.v -~~-cs -i~-~ `~ ~S ~ ~ S~F- ~ (2~ ~ to - cc~~ ~~ r ~, /~;t+ }~~ i, , ct Tuesday, May 25, 2010 Page 1 of 1 Page 1 of 1 Regg, James B (DOA) ~ • From: Regg, James B (DOA). _ _ _ ~~~~ ~~ZS`~ Sent: Friday, June 25, 2010 2:17 PM ~~c- 2~ To: 'NSK Well Integrity Proj'; 'NSK Problem Well Supv' ~ i~L~i- lxi3 Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: ANSI 1500 Flanges Inspectors have been finding ANSI 1500 flanges installed on the IA of some wells when out to witness MITs. The rated working pressure for these flanges is 3700psi. If I understand the situation correctly, the ANSI 1500 flange is installed on the IA and would either be directly exposed to test pressure approaching the rated working pressure, or could be exposed to excessive injection pressures in the case of TxIA communication (e.g., high injection pressures on gas injectors or via thermal expansion). During witnessed MITs in late May 2010, ANSI 1500 fllanges were found on West Sak gas injectors KRU 1 C-25 and 1C-27. In both occurances, CPAI was advised these are deficiencies. API defines the rated working pressure of equipment to be the maximum internal pressure that the equipment is designed to contain or control, and further notes that rated working pressure should not be confused with testing presssure (I read that to say it is inappropriate to justify operating equipment at pressure exceeding rated work pressure just because it was tested to the higher pressure). Exceeding the rated working pressure represents an inappropriate risk to field personnel attending to the wells. Inspectors have not been able to field verify if ANSI 1500 flanges have been hydrotested to proposed higher test pressure, and even if the flange was tested, we question how you would account for the history (exposure to extreme temps, harsh chemicals, corrosive fluids, etc.). We are interested in understanding CPAI's safe operating practices regarding ANSI 1500 flanges. We are also interested in reviewing any CPAI test policy that allows for the pressure rating of equipment to be exceeded. Other deficiencies noted during the KRU 1 C-pad inspections in late May: - Two instances of tree flange adapters made up to tubing spool without full engagement of the nuts on the studs (1 C-10, 1 C-15) - KRU 1 C-119 and 1 C-121 were noted to have mandrel hangers off seat from conductor casing; WAG injection lines were hanging from tree without support, placing the casings in a sideways bind. - KRU 1 C-174 was observed to have orifice meter wrapped in absorbent and an oily waste bag; use and condition of the orifice meter here needs to be explained. Please address these items. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 6/25/2010 ~~ ~~ rv~~_____ 06/10/08 ~i~Ul~)G~~~ NO. 4741 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~N~~~ ~UN ~ ~ 208 Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 (.~ Field: Kuparuk t i ~ .. © ~" ~ l ~-~~ Date BL Color CD 2W-13 11970689 GLS/PROD PROFILE - (0 05/27/08 1 1 3J-17 11970690 GLS/PROD PROFILE /~ - J 05/28/08 1 1 2M-08 11996642 PROD PROFILE/DEFT / _ / / ~ 06/03/08 1 1 1 B-10 11994672 PROD PROFILE/DEFT G 05/31/08 1 1 1A-20 11994673 PROD PROFILE/DEFT - 06/01/08 1 1 1G-13 11994674 PROD PROFILE/DEFT 3 ~ ~(o~l~~ 06/02/08 1 1 1A-03 11994673 PROD PROFILE/DEFT p (p y~y 06/04/08 1 1 2W-17 11996644 PROD PROFILE/DEFT .t ®( G( 06/05/08 1 1 iC-125 iC 127 11994677 ~ INJECTION PROFILE -~- ~~~~(~~ 06/05/08 1 1 - 11994675 INJECTION PROFILE _ c. 6~c,/~, 06/03/08 1 1 1F-09 11994671 PROD PROFILE/DEFT -/ ®~~(~ 05/30/08 1 1 iC-27 11994679 SBHP SURVEY ~ /(~C( 06/07/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ._ 1 9 I ,", pp ,y ~.~ r~ i !n ~ tl 1 f ~C~111~C1~~1'~~I' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1'11\R ~ ~ 20C1~3 gt~i`s~q,:dfi?i ~`,, ~, ~~~ MAR ~ `~ 200 C' , NO.4617 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk OZ/28/08 • Well Job # Log Description Date BL Color CD 1A-02 (REVISED) 11994615 INJECTION PROFILE /- 02111/08 1 1C-27 11970632 WFL V 02/21/08 1 3R-21 11970633 LDL j . (~ 02/22/08 1 2P-451 11996604 SBHP SURVEY ' d - p~ 02122/08 1 1C-11 11968846 LDL -- ( 02/20108 1 2P-438 11964581 SBHP SURVEY aU (- 02128108 1 2P-448A 11964582 SBHP SURVEY 02/27/08 1 C: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM To~ Jim Regg _; P.LSupervisor ~~o~r~ )~i~~~:~`~~ FROM: Lou Grimaldi Petroleum Inspector State of Alaska . Alaska Oil and Gas Conservation Commission DATE: Friday, January 04, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-27 KLPARUK RIV LNIT 1C-27 Src: Inspector NON-C(3NFIDENTIAL Reviewed By:_ P.LSuprv '~~"- Co mm Well Name: KUPARUK RN UNIT 1C-27 API Well Number: 50-029-22943-00-00 Inspector Name• Lou Grimaldi Insp Num: mitLG071224120626 Permit Number: 199-043-0 Inspection Date: 12/29/2007 Rel Insp Num: Packer Depth Pretest Initial 151VIin. 30 Nlin. 45 Vain. 60 Min. -- Well ~ Ic-z7 IType Ind w f TVD '~~ 637> IA soo ~ zzzs ~~ ~ - --- zzzz I 22zo X75 340 j P•T~ 1990430 i~T~'L)eTest SPT ~ Test pSl ~i, ?225 ; i A ~; 335 ~ 340 j ~~ Tubing i4as ~ I4os Interval wRKOVR P/F _ P - _ I4os ~ Iaos~~ _ NOteS: 2.6 bbl's pumped. [A pressure initially raised to 2120 psi w 10 degree fluid, well temp 135 degrees. IA seemed to be theanally pressuring up. Moved to next well and allowed this well to stabilize for I hour. Came back and observed these pressures. ~~!~+~%JAN ~ ~ 2000 Friday, January 04, 2008 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~85~8 III r- ~~ '~'''i?`~~ ~~ ~m+~i~sjott REPORT OF SUNDRY WELL OPERATIONS !' =' ` ~`~'' 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q oil to waG Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 199-043 ' 3. Address: Strati ra hic g p ^ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22943-00 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 95' 1 C-27 " 8. Property Designation: 10. Field/Pool(s): ALD 28242 ALK 2292 Kuparuk River Field /Kuparuk Oil Pool - 11. Present Well Condition Summary: Total Depth measured 13910' feet true vertical 6412' ~ feet Plugs (measured) Effective Depth measured 13863' feet Junk (measured) true vertical 6411' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115` SURFACE 6821' 9-5/8" 6916' 4547' PRODUCTION 10692' 7" 10787' 6403' LINER 1121' 4-1/2" 11689' 6444' LINER 476' 4-1/2" 12165' 6433' LINER 1698' 4-1/2" 13863' 6411' Perforation depth: Measured depth: 10568' - 11689'; 12165' - 13863' true vertical depth: 6287' - 6444'; 6433' - 6316' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10520' MD. Packers &SSSV (type & measured depth) PKR= Baker FAB packer w/ X-nipple & plug in tail pipe PKR = 10528' SSSV= NIP SSSV= 492' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 306 165 12 716 221 Subsequent to operation 2770 ~ 974 1487 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ " Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAGQ GINJ^ WIND ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exempt: 307-063 - Contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buchho~z Title Production Engineering Technici an Signature ~~~G~~~~~'" V _ ~~ - Phone 659-7535 / Date J z / 3t'~~~ Form 10-404 Revised 04/2004 ~1ZZ,oo ~~'~. ~if~IV ~ ~ (a~~ `+~'~ Submit Original Only • 1 C-27 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/16/07 Commenced Water Alternating Gas Injection • ConocoPhillips Alaska, Inc. NIP andr~ andr ands ana 3nc • KRU 1 C-27 1 C-27 API: 5002922.943_0_0 Well T e: PROD 1999 An le TS: 85 de 11044 Angle @ TD: 90 deg @ 13910 SSSV Type: Nipple Ori 6/30/ g (asz-as3, Com letion: Rev Reaso n: DMY TUBING )D:5.030) Annular Fluid: Last W/O: Last U date: 11/24/2007 Reference Lo Ref Lo Date: _ Last Ta :10681' _ TD: 13910 ftKB Last Ta Date: 11/21/2006 Max Hole An le: 94 de 12413 Gas Lift al/Dummy vales 1 C astn Strin -CASING Slze Top Bottom TVD Wt Grade Thread 934-1935, I D escri tion CONDUCTOR 115 115 16.000 0 62.58 H-40 WELDED 80 BTC-MOD L DD:5.984) SURFACE 9.625 0 6916 4547 6403 40.00 00 26 - L-80 BTC-MOD Gas Lift el/Dummy PRODUCTION 7.000 0 10787 500 10568 11689 6444 4 . 12.60 L-80 BTC-MOD Vales 2 LINER . 500 11689 12165 6433 4 12.60 L-80 BTC-MOD ~35t-3352, oD:s.ssa) I LINER LINER . 4.500 12165 13863 6411 12.60 L-80 BTC-MOD Gas Lift ~el/Dummy T ubin Strin -TUBING glZe _ _ _ To _ _ Bottom _ TVD Wl Grade 60 L-80 12 Thread BTC-MOD vales 3 4.500 0 . 10520 6373 1915-5916, OD:5.984) Perforations Summa Interval _ TVD Zone Status Ft SPF Date 1121 99 6/30/1999 Comment T e IPERF Slotted liner Gas Lift 10568 - 11689 6382 - 6444 UNIT relroummy C-4 D Vales 4 ne1-77az, I _ _ - 12165 - 13863 6433 - 6411 , - C-4 1698 99 6/30/1999 IPERF Slotted Liner OD:5.984) Gas Lift MandrelsNalves St MD ND Man Mfr - Man Type V Mir V Type V OD Latch Port TRO Date Run Cmnt Gas Lin IrellDummy vales 5 1 1934 1799 CAMCO KBG-2 CAMCO DMY 1.0 BK 0.000 0 3/8/2007 0 11/19/200 so75-so7s, OD:5.984) I 2 3351 2608 CAMCO KBG-2 CAMCO DMY 1.0 BK 0 BK 1 0.000 000 0 0 11/19/20 3 5915 4006 CAMCO . _KBG-2 CAMCO DMY 0 BK 1 . 000 0 0 11/19/200 Gas Lift 4 7781 5017 CAMC_ O --- - . _KBG-2 CAMCO DMY BK - . 000 0 0 11/19/200 lrel/Dummy valees - 5 9075 5717 CAMCO_ KBG-2 CAMCO DMY 1.0 0 BK 1 . 000 0 0 11/20/200 ~o1s-loozo, 6 10019 6216 CAMCO . KBG-2 CAMCO DMY . oDSS6a) Other lugs e w etc ~ JEWELRY . ~ ID TUBING ---~ Tyke De ih TVD - Descri tlon - 813 3 (alaszo, oD:a.soo, _ 492 492 NIP CAMCO DB . 3.813 ID:3.958) 10034 6222 NIP HES'X' NIPPLE 4.000 10520 6373 SEAL 10528 6375 PACKER Baker 80-47 BAKER 7" x 4.5" FEB acker with X-ni le & lu in tail i e 4.000 000 4 10534 6376 PACKER BAKER 7" x 4.5" SLZXP LT Packer & 12' tie back sleeve . 3.813 10540 6377 NIP ral Notes G HES X ene Deto Note SEAL - 3/6/20 07 1" GLV/BL LATCH LOST IN WELL o5zo-1os26, - OD:4.750) PACKER 0528-10534, OD:4.500) PACKER 10534-10540, OD:4.500) 'RODUCTION I I (0-10787, OD:7.000, W t:28.00) Perf I 10568-11689) I I LINER (10568-11689, I I OD:4.500, W t 12.60) LINER I (11689-12165, OD:4.500, Wt:12.60) I I Perf ;12165-13863) I I LINER I (12165-13863, OD:4.500, Wt:12.60) I I . . Conoc6Phillips Alaska RECEIVED AUG 2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 23, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 SCANNED SEP 0 6 2007 Anchorage, AK 99501 \q ~/ 043 Dear Mr. Maunder: . Enclosed please find a spreadsheet with a list of wells trom the Kuparuk field (KRU). Each of thesé wells was fôund to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water trom 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 corrosion inhibitor/sealant was pumped between August 19 & 21,2007. The attached spreadsheet presents the wen name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. ;~4~~· M.J.¿el~d ConocoPhiUips Well futegrity Projects Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/21/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date - ft bbls ft aal 1 0-28 204-237 18" N/A N/A N/A 10 8/19/2007 1 0-30 200-104 24" N/A N/A N/A 6.5 8/19/2007 10-34 200-143 14" N/A N/A N/A 4 8/19/2007 10-12 199-084 1" N/A N/A N/A 1.7 8/20/2007 10-14 199-089 2" N/A N/A N/A 3.4 8/20/2007 10-140 200-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007 10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007 '1C-11 199-172 - SF NA NA NA 0.5 8/21/2007 1C-12 196-177 SF NA NA NA 0.5 8/21/2007 1C-15 198-229 SF NA NA NA 0.5 8/21/2007 1C-16 198-246 22" NA NA NA 8 8/21/2007 1C-17 198-224 17" NA NA NA 1.7 8/21/2007 1C-18 199-005 SF NA NA NA 0.5 8/21/2007 1 C-24 201-248 20" NA NA NA 11 8/21/2007 1 C-26 199-051 3" NA NA NA 0.85 8/21/2007 1C-27 199-043 4" NA NA NA 1.7 8/21/2007 1 C-28 205-104 SF NA NA NA 0.5 8/21/2007 1C-117 201-121 26" NA NA NA 12.3 8/21/2007 . . SARAH PALIN, GOVERNOR AI/ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Christensen ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK99510 ... '-',".''''' '~¡f' Re: 'V., fY1,u1 ~qq' ~3 Kuparuk River Field, Kuparuk Oil Pool, 1 é)4'v 11 Sundry Number: 307-063 . ' ~FEB 262007 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Appt"oy§JJ r.~I9:ggg_!g th~,,_ ~ above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisÆ3day of February, 2007 Encl. . . Conoc6Phillips Robert Buchholz / Robert Christensen Production Engineering Tech. Greater Kuparuk Unit, NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 February 13, 2006 To: Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission th 33 W. 7 Ave. Ste. 100 Anchorage,AJ< 99501 \x/1J /~ \~\K. Subject: Sundry Applications for Proposed Change of Well Class ConocoPhillips Alaska, Inc. submits the attached sundry applications for proposed change of well class on Kuparuk well1C-27. If you have any questions regarding this matter, please contact myself or Robert Buchhloz at 659-7535. fJ:k,~~ Robert D. Christensen Attachments: 10-403 Forms STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 1 4 2007 APPLICATION FOR SUNDRY APPROV AlAlaska Oil & Gas Cons C " 20 MC 25.280 . ommlsslon o Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 o Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 o Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 P. O. Box 100360, Anchorage, Alaska 99510 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0 1C-27 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ALD 28242 ALK 2292 RKB 95' Kuparuk River Field I Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13910' 6412' 13863' 6411' Casing Length Size MD . . 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory 0 Service 0 RECEIVED Producer to Injector 5. Permit to Drill Number: 199-043 6. API Number: 50-029-22943-00 8. Well Name and Number: CONDUCTOR SURFACE PRODUCTION LINER LINER TVD 115' 115' 6821' 10692' 1121' 476' 16" 11,5' 6916' 10787' 11689' 12165' 9-5/8" 4547' 6403' 6444' 7" 4-1/2" 4-1/2" 6433' Perforation Depth MD (ft): 10568' - 11689'; 12165' -13863' Packers and SSSV Type: PKR = Baker FAB packer wI X-nipple & plug in tail pipe SSSV= NIP Perforation Depth TVD (ft): 6287' - 6444'; 6433' - 6316' Tubing Size: 4-1/2" Packers and SSSV MD (ft) PKR = 10528' SSSV= 492' 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for Commencing Operations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Robert D. C~ristense July 7, 2007 Date: 14. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Contact: Title: Signature Phone 659-7535 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ~ Location Clearance 0 Other: \.)\\\ ~~ \- e a ~ ~s"o..\\'~~' ... ~L~~ \).1/1\\c) à-~ RBDMS 8Ft 2 H APPROVED BY THE COMMISSION Approved by: Form 10-403 Revised 06/20 Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 10520' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Bob Christensen I Bob Buchholz Production Engineering Technician Sundry Number: Date: Submit in Duplicate . 1 C-27 DESCRIPTION SUMMARY OF PROPOSAL . ConocoPhillips Alaska Inc. requests approval to change the approved program for Kuparuk well 1 C-27 from Oil production to WAG EaR injection service. The conversion of well 1 C-27 will provide pressure support for the Kuparuk C sands. There is 1 well penetrating the Kuparuk River Oil Pool within one-quarter mile, which is 1 C-25/1 C-25L 1. The 9-5/8" Surface casing (6916'md 14547' tvd) was cemented with 822 sx AS III LW followed by 663 sx Class G, The 7" Production casing (10787'md 16403' tvd) was cemented with 173 sx Class G. A CBL was not initially performed (development well). A RWO to pull the 4-1/2" tubing would be required to obtain a CBL. Attached is a copy of the 1 C-27 cementing report, 7" casing detail, and an evaluation of the cement jobs for both 1 C-27 and 1 C-25. The injection tubing/casing annulus (1 C-27) is isolated via a Baker 7" x 4.5" SAB packer with X-nipple & plug in tail pipe. The top of the Kuparuk C sand was found at 11044' md 1 6415' tvd. A WFL is expected to be performed within 90 days after the conversion to verify injection zone integrity. . . . CólloooPhiUlþsAlaska, Inc. KRU 1 C-27 ..' '~'.~ , 1C'-'27 mil API: 500292294300 Well Tvce: PROD Anale @ TS: 85deQ @.11044 NIP (492-493, SSSV Tvce: Niccle Oria Comcletion: 6/30/1999 Anale @ TD: 90 deQ @. 13910 ·i::::::::::::::::::::::f·.·.· : OD:5.030) Annular Fluid: Last W/O: Rev Reason: TAG FILL Reference Loa: Ref Loa Date: Last Update: 11/24/2006 Last Taa: 10681 ' TD: 13910 ftKB Last Tag Date: 11/21/2006 Max Hole Anale: 94 deg-¡a, 12413 Cásihi;i String "CASING ... Descriction Size Toc Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.58 H-40 WELDED SURFACE 9.625 0 6916 4547 40.00 L-80 BTC-MOD GasUl! PRODUCTION 7.000 0 10787 6403 26.00 L-80 BTC-MOD MandreWalve LINER 4.500 10568 11689 6444 12.60 L-80 BTC-MOD 2 (3351-3352, LINER 4.500 11689 12165 6433 12.60 L-80 BTC-MOD OD:5.984) LINER 4.500 12165 13863 6411 12.60 L-80 BTC-MOD GasUl! MandreWalve Size Top I Bottom I TVD T Wt T Grade I Thread 3 (5915-5916, 4.500 0 I 10520 I 6373 I 12.60 T L-80 I BTC-MOD OD:5.984) Pëtforätioiis SummarY. .... GasUl! . Interval TVD Zone Status Ft SPF Date Tvne Comment MandreWalve 10568 -11689 6382 - 6444 UNIT 1121' 99 6/30/1999 IPERF Slotted liner 4 (7781-7782, D,C-4 OD:5.984) 12165 -13863 6433 - 6411 C-4 1698 99 6/30/1999 IPERF Slotted Liner Gas Lift MähdtëlsNälVes ...... GasUl! st MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv MandreWalve Mfr Cmnt 5 (9075-9076, 1 1934 1799 CAMCO KBG-2 CAMCO DMY 1.0 BK 0.000 0 1/13/2000 OD:5.984) 2 3351 2608 CAMCO KBG-2 CAMCO GLV 1.0 BK 0.125 1366 3/27/2003 3 5915 4006 CAMCO KBG-2 CAMCO GLV 1.0 BK 0.188 1381 3/27/2003 ...~ 4 7781 5017 CAMCO KBG-2 CAMCO GLV 1.0 BK 0.188 1362 3/26/2003 . . 5 9075 5717 CAMCO KBG-2 CAMCO GLV 1,0 BK 0.188 1362 3/26/2003 6 10019 6216 CAMCO KBG-2 CAMCO OV 1.0 BK 0.250 0 3/26/2003 TUBING othër 'plugs ·édiiiiï,; eta]. '-'JEWELRy....·· (0-10520, Decth TVD Tvpe Description ID OD:4.500, Ij¡!¡¡¡¡¡¡r¡¡¡iiil 492 492 NIP CAMCO DB 3.813 ID:3.958) 10034 6222 NIP HES ')Ç NIPPLE 3.813 10520 6373 SEAL Baker 80-47 4.000 ,. 10528 6375 PACKER BAKER 7" x 4.5" FEB packer with X-nipcle & plug in tail Dice 4.000 10534 6376 PACKER BAKER 7" x 4.5" SLZXP L T Packer & 12' tie back sleeve 4.000 10540 6377 NIP HESX 3.813 SEAL (10520-10528, OD:4.750) . PACKER I (10528-10534, OD:4.500) PACKER (10534-10540, OD:4.500) I¡¡¡::::::::¡~::::::::¡I: ................. PRODUCTION 11 .. ...... ... .. .. ...... ... ..,.. ....., ... (0-10787, 00:7.000, Wt:26.00) I Perf ..... (10568-11689) 1 .d' I LINER 1 r (10568-11689, OD:4.500, Wt:12.60) r< LINER (11689-12165, 1< 1 OD:4.500, Wt:12.60) Perf lHH f (12165-13863) ..--.....__...... HHIH . LINER ;::;: :'::.. (12165-13863, OD:4.500, I HI Wt:12.60) . . WelllC-27 Assessment of Cement and Wells Within One-Quarter Mile Application to Convert to Water Injection February 12, 2007 lC-27 Cement Evaluation WelllC-27 is a horizontal producer in the Kuparuk C sand. It is proposed to convert lC-27 to water injection in spring 2007. It is completed with 7" production casing cemented to a depth of 10,787' MD (6403' TVD) with 4~" slotted liner installed in the horizontal section. The only wells within one-quarter mile of the C sand of 1 C-27 are wells lC-25 and lC-25Ll to the west. The 7" casing in welllC-27 was cemented in place on June 3, 1999 using 37.5 bbl of 15.8 ppg cement. The job proceeded smoothly without any problems. The calculated top of cement is reported as 9987' MD (6202' TVD), but no cement evaluation log was run. Full returns were maintained during the cement job, and the casing was reciprocated until shortly before the plug was bumped. Gemoco bow-spring centralizers were installed on every joint for the bottom 25 joints. The 7" casing was pressure tested to 3500 psi prior to drilling out, but for some unknown reason no LOT or FIT was conducted after drilling out the shoe. 1 C-25 Cement Evaluation There is approximately 490' of separation to lC-25Ll at 6482' TVD in the C Sand, and approximately 1250' of separation to the originallC-25 well. WelllC-25 is a Kuparuk C sand producer that was only recently approved for injection service, but as of yet the well has not been placed on injection. lC-25 is equipped with 3W' tubing and production liner. The 3W' liner spans the entire C sand from 9416' -10,138' MD, 6213' - 6648' TVD. The Lllateral in welllC-25 was drilled in December 2006 and completed with 2%" slotted liner in the C Sand, while still leaving the original perforations open in the 1 C-25 wellbore. The 3 W' liner across the Kuparuk C sand in well 1 C- 25 was cemented in place on April 26, 1999. A total of33 bbl of 15.8 ppg cement were pumped, which compares to a gauge open hole volume of 13.9 bbl. The cement job proceeded smoothly without any problems. Full returns were maintained throughout the cementing operation, and the pipe was reciprocated until shortly before the plug was bumped. Gemoco "spirolator" centralizers were installed on every joint. After releasing from the liner hanger, 13 bbl of cement were circulated off the top of the liner. A SCMT log run on June 24,2006 shows excellent cement coverage over the entire 3~" liner. The lC-25Lllateral exits the 3W' liner at 9793' MD (6440' TVD), which leaves a 223' cemented interval across the 3W' liner up to the 7" shoe at 9570' MD. 1. Gary Eller ConocoPhillips Wells Engineer . . Page 1 of2 P AI Daily Drilling ~ ¢J ~ Q Conoc6Ã,iUips ConocoPhillips Alaska Daily Drilling Report Well Sidetrack Network 24 Hrs TMD TVD DFS REPT NO. DATE ProQ 1C-27 1C-27 AK0024 0' 10,797' 6,4p5' 13 6/3/1999 . FRED HERBERT / Supervisor RICK Proposed TMD 0' Pressure Test(s) OVERSTREET Rig Name Pool 6 Da ilv Cost $0 Type I Date I TMD TVD I MW Press I Tot. press I EMW Field KUPARUK RIVER Cumul·ative Cost Name UNIT $0 11'1'1 ppg psi I 0.00 psil 0.00 ppg Current PU BHA. Last Safety BOP Tst '3/29/1999 I Status Meeting (LastNext) Event ODR ~ncident 1st ~4 hrs? No Rig Accept: 5/22/19993:30:00 AM@ Code Rig Release: 6/30/1999 6:00:00 PM @ 24HR Forecast Last ., Survey TMD: INC": Azim: Last Casing Next Casing One rations. Summarv From To I". ..~. Time~. Start End Hours Phase ~ctlVlty ",ubcode CI I' rouble D 'th D th - . ass . ep ep . P 10 797' 10 797' Circulate & fondition mud. Held PJSM , , for cement job. . Pumped 5 bbls water to flush & fill lines. Press. test lines to 3500 psi. Pumped 20 bbls ARCO pre-flush, 40 10 797' 10 797' bbls ARCO spacer, dropped bottom , , plug, pumped 37.5 bbls cement, dropped top plug, displaced w/rig, bumped plug. Press. to 2000 psi for 10 min. Check float eQuip. 10,797' 10,797' RD casing equip; LID landing jt. 10 797' 10 797' Drain stack, install packoff, test to , , 000 psi, lO min. 10 797' 10 797' hang.e bottom rams & saver sub on , , op drive. 10 797' 10 797' Test choke manifold, witness by , , Chuck Shieve (AOGC). Set test plug, tried to test, no good. EQIP 10 797' 10 797' ry to energize test plug, no good. , , Pull te5t plug & inspect ( confirmed wrong plug). est top pipe rams, blind rams, 10,797' 10,797' Hydril, all BOP valves, floor' valves, koomv test. Botto·m DiDe rams failed. Change out bottom rams try to test (failed). Change out saver sub change 10 797' 10 797' ~aws and g~ide. Pull out wear plate & , , Inspect. Walt on parts. Put on new eals try to test (failed). Changed rams to 5" test to 250 /5000 OK. Operation 00:0003:00 3.00 PROD CIRC 03:0006:00 3.00 PROD CEMENT PUMP P 06:0007:00 1.00 PROD P ~ P 07:0008:30 1.50 PROD 08:3011:00 2.50 PROD WELCTL BOPE P 11:0012:00 1.00 PROD WELCTL BOPE p 12:0014:00 2.00 PROD Np 14:0016:30 2.50 PROD WELCTL BOPE P 16:3000:00 7.50 PROD WELCTL BOPE P 24 h~://partI1ers.conocophillipsa1aska.comJdri~ing/cgi-bin/reportsl daily. asp?:wellname= 1 C%2D27 &... 1/11/2007 ~ i í ì '. ! ¡ ¡ ¡ ì i i í I i ¡ . L I ¡ ¡- I_ I Ì ~.:~ i ¡ L ¡ j í I , i . . Page 1 of2 P AI Daily Drilling r- ¢ ~ Q -., V ConocoPhillips Alaska ConocóPhiUips Daily DrilIine: Report Well Sidetrack Network 24 Hrs TMD TVD DFS REPT NO. DATE Proa lC-27 lC-27 AK0024 0' ·10,817' 6,410' 15 6/5/1999 FRED HERBERT / Supervisol RICK Proposed TMD 0' Pressure Test(s) OVERSTREET Rig Name Pool 6 Inailv Cost $0 Type Date, I TMD I TVD I MW I Press I Tot. Dress I EMW Field KUPARUK RIVER Name UNIT Cumulative Cost $0 J 1'1'1 ppgl psl 0.00 psll 0.00 ppg Current TRIP BACK IN . Last Safety BOP Tst HOLE. SLIP & CUT 5/29/1999 I Status DRILL LINE. Meeting (LastNext) event ODR Incident 1st 24 hrs? Rig Accept: 5/22/19993:30:00 AM@ Code No Rig Release: 6/30/1999 6:00:00 PM @ 24HR Forecast ,. '.' , .. . Last , Survey TMD: INC: Azim: Last Casing Next Casing . Onerations SUmmary From To Hours Phase Activity Subcode Time Trouble Start End Operation Class Depth Depth 00:00 01:00 1.00 PROD TRIP ,P 10,797' 1.0,817 ' Rnished P/U 4" DP, run DP out of derrick and taaaed @ 10684'. 01:00 02:00 1.00 PROD CIRC P 10,817' 10,817' Circulated hole. RU.test equip. Ran C.LT. on 7" casing 02:00 03:00 1.00 PROD CASE DEQT P 10,817' 10,817' (30 min.). RD test equip.3500 psi for 30 mln.s 0 Dsi lost 03:00 03:30 0,50 PROD Np EQIP 10,817' 10,817' Lost power, traced oui: and reset. 03:30 [08:00 4,50 PROD DRILL DRLG P 10,817' 10,817' Drill out float èollar; cement, & float shoe f/10684' t/10797'. O~:OO 09:00 1.00 PROD DRILL DRLG P 10,817' 10,817' Drill 20' ofliew hole f/l0797' Ul0817'. ART - 0 hrs AST = 1 hr. PJSM on new mud (drilling fJuÎd). Clean possum belly, flow lines etc. 09:00 14:30 5.50 PROD CIRC P 10,817' 10,817' Displace hole with new 10.5 ppg Baradril-N. Circulating pressures 500 psi high than normal. Circulate BU while cleanina Dill Dit to mix drY lob. Monitor well (static). Pump dry job, 14:30 20:30 6.00 PROD TRIP P 10,817' 10,817' POOH to avoid swabbing and wet !DiDe. Work BHA take out sources, break off 20:30 22:00 1.50 PROD P 10,817' 10,817' þit. Clean out jet nozzles on bit and replace 2. 22:00 00:00 2.00 PROD PULD P 10,817' 10,817' lJnload data and reprogram MWD. Orient bit and work BHA. 24 Hr. [sum: http://partners.conocophillipsalaska.comJdrilling/cgi-binJreports/dai1y.asp?wellname=IC%2D27&...I/II/2007 " ¡--. ( ..... 'YARCO Alaska, Inc. W.II Name: 10-27 Ri Name: Pool 6 Casing Size 7" Hole Diameter: 8.5" Angle thru KRU: Report Date: 06103199 AFC No.: AK0024 Shoe Depth: 10,787' . ( Cementin Details Report Number: 2 Field: LC Depth: 10,698 % washout Stale type usad, intervalS coveted and spacing Run 1 bow spring centraliZer per jOlndor Joints 1·25 Additives: Class 'G' w/3% D53, 0.6% D65, Q.130"k D800, 0.80% S001, 0.2 gaVsk D47, 0.1 gaVsk D135, 2.0 gaVsIC D600 Rate(tail around shoe): 2bpm Reciprocation speed: 15fpm Actual Displacement: 461 bbls (see remarks) Bumped plug: yes Weight: 11.0 Gels before: 15/22 Caiculated top of cement: 9987' PV(prior oond): 26 Gels after: 6/8 Mix wtr te/T'P: Mix wtrtemp: 70 CPo Date:0G/03l99 Time:05:25 PV{aftercond): 27 Total Volume Circulated: 1254 bbls Volume: 20 Volume: 40 No. of Sacks: No. of Sacks: 173 YP(prior cond): 36 YP{afier cond): 20 Weight: 8.35 Wèight 12.0 Weight: Yield: Weight: 15.8 Yiefd: 1.21 , ¡ I ! Str. WI. Up: 300k SIt. WI. Down: 150k SIr. WI. In mud: t 1 ¡- L Roats held: yes Remarks;Caslng went bottom Be circulated with no problell1$. Pumped 20 bbls wash, 40 bbls Arco Spacer, 37.5 bbls 15.8 cement Be DlsþIaced with rIg pumps. At ",,'aulaled displacement (by strokes) it was detennined that the mud pumps were not operating at the expeCled output as the pressure build was not enough, casing on vacuum. The plugs were confirmed to have left the head. Continued pumping until bumping the plug 62 bbls over by the strokes. Reclp casing until within 100 strokes of bumping plugs (calculated). Cement Company: DS Rig Contractor: POOL Approved By: Fred Herbert I Rick Overstreet . ( . (-,. Casing Detail 7" 26# Casing WELL: lC-27 DATE: 06/01/99 1 OF 1 PAGES ARCO Alaska, Inc. Subsidiary of Atlanfic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RTto LOS = 30.93' TOPS 7" Landing Joint 30.93 , 7" FMC GEN V FLUTED MANDREL HANGER 1.88 30.93 jts 3-262 7", 26#, L-80 STC-MOD (260jts) 10665,59 32.81 Gemeco Float Collar 1.32 10698.40 jts 1-2 7", 26#, L-80 STC-MOD (2 jts) . 86.18 10699.72 Gemeco Float Shoe 1.47 10785.90 BTM OF SHOE @ 10787.37 T.D.r@ 10797' leavIng 10' of rathOle 10787.37 . 25 Gemeco Bow Spring CENTRALIZERS ¡Mæ!If!m¡ÆWMJle¡mºñ§.mp'~§.If.iIij~nlråªmÇfr.,*lfi4iØltf@;iWtmWIí¡¡ft¡ , , . Remárks: String Weights with Blocks: 300k Up, 150k Dn, 70k Blocks. Ran 262 joints of casing. Drifted casing with 6.151" plastic rabbit. Used Arctic Grade API MOdified No Lead thread compound on all connections. Casing Is non-coated. Pool 6 Drífling SupeNisor: FRED HERBERT / RICK OVERSTREET . . . COßocoPhilIÎp$Alaská, Ißc; KRU 1C-25 . ,", ;¡ Angle@T~ TUBING API: 500292294100 Well Type: PROD (0-9452, ~ SSSV Type: Nipple Orig 4/28/1999 Angle @ TD: 52 deg @ 10140 OD:3.500, Completion: ID:2,992) ::::::11111111111111 .' Annular Fluid: Last w/o: Rev Reason: Adjust Prod CSG depth ...............o:;.....:;'~....... .......... .... Reference Ref Log Date: Last Update: 1/19/2007 .~ Log: Last Tag: 9994 TD: 10140 ftKB Last Tag 10/12/2006 Max Hole 56 deg @ 4002 Date: Angle: .Çª$!ij9$ttiijgFAtPØ~$'Ng$)i.·.·.·.·.·.····················· .. Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62,58 H-40 WELDED SURFACE 9.625 0 6567 4554 40.00 L-80 BTC-MOD PRODUCTION 7.000 0 9570 6305 26.00 L-80 BTC-MOD PRODUCTION LINER 3.500 9416 10138 6648 9.30 L-80 EUE 8rd " C-SAND LINER TOP 2.375 9775 9796 6441 4.70 L-80 STL C-SAND WINDOW 3.000 9795 9796 644~ ~ I Size I Top I Bottom I TVD I Wt I Grade Thread Interval TVD Zone Status Ft SPF Date Type Comment 9788 - 9824 6437 - 6458 C-4 36 4 :I/27/199E IPERF 2.5 HC, DP, 180 deg. ph 9834 - 9844 6464 - 6470 C-4 10 10 :1/27/1999 IPERF 2.5 HC, DP, 180 deg. ph 9967 - 9987 6544 - 6556 C-1 20 6 5/16/2006 APERF 2" 2006 PJ Omega S.tÎmÛlâtîôriš&j'fèâtmerdš.: H ....c;harges... ~ ..................................................................... ~ Interval I Date Type I Comment 9788 - 9844 111/9/2002 FRAC St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv ... Mfr Run Cmnt " ~ 1 3230 2612 CAMCO KBMM CAMCO GLV 1.0 BK 0.156 1392 2/8/200 2 5166 3734 CAMCO KBMM CAMCO GLV 1.0 BK 0.188 1409 2/8/200 -- 3 6594 4570 CAMCO KBMM CAMCO GLV 1.0 BK 0.188 1390 2/8/200 4 7775 5262 CAMCO KBMM CAMCO OV 1.0 BK 0.250 0 /13/200 5 8616 5749 CAMCO KBMM CAMCO DMY 1.0 BK 0.000 0 1/9/200 6 9391 6198 CAMCO MMM CAMCO DMY 1.5 RK 0.000 0 1/11/200 Qm~t (þlijg$~iqijjþW~t¢a..gøQMPter'QN·.<)·····················.......'."'", .. II Depth TVD Tvpe Description ID 502 502 NIP CAMCO DS nipple 2.875 9410 6209 NIP CAMCO D nipple NO GO profile, ELMD @ 9413 ON SWS 2.750 ~ JEWELRY LOG 9/21/99 9416 6213 PACKER PRODUCTION LINER ZXP LINER TOP PACKER 1 C-25 4.000 9422 6216 SEAL BAKER 80-40 casing seal assemblv 3.000 9793 6440 BAKER GEN II MONOBORE FLOW-THRU WHIPSTOCK 0.000 2/5/2006 NOTE: MULTI-LATERAL WELL - 1 C-25 & 1 C-25L 1 (C-SANDS)-1 C-24L 1 ::: ::::-1 .¡ .................. . Whipstock ~:.. ~ (9793-9798, ~ OD:4,OOO) Perf (9788-9824) FRAC 1--7 (9788-9844) ts K Perf - ~ (9967-9987) - f----- - r-- - . . Con()~oPhmips Alaska.1 toe. KRU ~' TUBING (0-9452, 00:3.500, 10:2.992) Perf (9788-9793) Perf (9775-10454) Whipstock (9793-9798, 00:3.500) ~- s = ~ = F= ~ ~ = 1= = != =. 1= ='. F= ='.', '= t= = ' t==== =. F I'~ ï = Ili~ ~ = ...... 1== = 1== = 1== = 1== == 1== = 1== = 1== = F= = F= == 1== = F= = F= = 1== = F= = F= == 1== = F= = F= = F= = '== = = = = == == - - - 1 C-25L 1 API: 50 SSSV Type: NIPPLE Orig 12/5/2006 Angle @ TD: 82 deg @ 11804 Completion: Last W/O: Annular Fluid: Ref Log Date: Rev Reason: Adjust Prod CSG depth Last Update: 1/19/2007 Reference 30' RKB Lo~r Last Tag: TD: 11804 ftKB Last Tag Max Hole 94 deg @ 10295 Date: Angle: ºª$iijg$~titigMAM;$}(RINQ$))'···"'··' .. Description Size Top SURFACE 9.625 0 PRODUCTION 7.000 0 CONDUCTOR 16.000 0 PRODUCTION LINER 3.500 9416 TOP L 1 C-SAND LINER 2.675 9775 10487 6461 4.70 L-80 STL L 1 WINDOW I Size I Top. EUE~ Interval TVD Zone Status Ft SPF Date Type Comment 9775 - 9788 6429 - 6437 13 40 12/5/2006SLOTS Slotted Liner 9788 - 9793 6437 - 6440 5 44 12/5/2006SLOTS Slotted Liner 9793 - 6440 - 6462 661 40 12/5/2006SLOTS Slotted Liner 10454 St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Mfr 1 3230 2612 CAMCO KBMM GLV 1.0 2 5166 3734 CAMCO KBMM GLV 1.0 3 6594 4570 CAMCO KBMM GLV 1.0 4 7775 5262 CAMCO KBMM OV 1.0 5 8616 5749 CAMCO KBMM DMY 1.0 6 9391 6198 CAMCO MMM DMY 1.5 øJij~rfijIQg~it!qtdpWij.tç~)kØØMg¡;¡!$)Nø.Ni·'·""'" , Depth TVD Type " " '" Description 502 502 NIP CAMCO DS LANDING NIPPLE 9410 6209 NIP CAMCO D NIPPLE wINO GO PROFILE 9416 6213 PACKER PRODUCTION LINER ZXP LINER TOP PACKER 1C-25 9422 6216 SEAL BAKER 80-40 CASING SEAL ASSEMBLY 9793 6440 Whipstock BAKER GEN II MONOBORE FLOW-THRU WHIPSTOCK 10453 6462 L1 L1 O-RING SUB O-RI NG 10486 6461 L 1 SHOE UNIQUE SELF ORIENTING GUIDE SHOE ~ 215/200Ej NOTE: MULTI- LATERAL WELL: 1C-25 & 1C-25L 1 ARE IN THE C-SANDS 215/200Ej NOTE: 1 C-25L 1 LINER STUCK ~ -10,500' TO, LINER TOP CHEMICAL CUT ~ 9775' Bottom 6567 9570 115 9794 BK-5 BK-5 BK-5 BK-5 BK-5 RK TVD 4554 6305 115 6440 wt 40.00 26.00 62.58 9,30 0.156 0.188 0.188 0.250 0.000 0.000 Grade L-80 L-80 H-40 L-80 Thread BTC-MOD BTC-MOD WELD EUE8rd 1392 1409 1390 o o o Date Run 218/200 218/200 2181200 113/200 1/9/200 1/111200 VI v Cmnt ID 2.875 2.750 4.000 3.000 0.000 1.000 1.995 . . \<;.,,-04 ~ tŒCRÞ~ICAL INTEGRITY P~PORT " ~?UD 0.~_-=-':. OPER & fIELD c..PI\ r Ì<:;:U NUMEER \ c.. - d~ ?IG 2.s~::;._:::.::: TD: \~S\Û.MJ) ~ L..\ \) TVD i :?BTD : \?'S\o'~ HD (,~\ \ TVD Shoe: to'\ <6\ HI) G~O'> TVD i DV: Nt\. ill) \-Jt\. ' Iv!) Shoe: HI) '[V1 ; :CP: t·m ;:''¡T) -,..,sLL DATA Cë.S ir:g : ~ _ ::..:¡e::- : TVD í Set ë. t \ D S d Ù ':> \0 \Aiè..0 \-,N. ,- Per£3 to \ 1\1,'1 Q :-"JOi.:;g: ~ Q Pa.cker \ùç:) f:) ~ '6,ç :-:'ole Size ana $)"5<':' ~ ~ \~ S (¡ 's. :-SC?.ÞJEc;·.L INTEGRITY - ?.tŒT 11 ,. .~ ,.- 1J; 'd) \J\ <;I ~~~CHÞ~ICÞ~ INTEGRITY - PART 12 : ..i Ce!Ilent: Volume.s:· Þ..mt. Liner "-J '" ('/' .."., rr.:> ;> . J If. io' ./ [) .>I d ,1 o .-r L ~ J' I.. U 1/ ~ J l, Q ". ,r ~ j CBL ~va.luation, zone ë.DOVe perfs ( ¿ p 1 J; 2 zr '" 0 {J';' (;1 JI ,J , ("þ Annulus Press Test: 15 min i 30 min " (> M.<'-'- "",', ,,'-' \ '""'" "'<:, ~« ''', <-(,\-..)J -:-"";) Cow:r;:¡ents: t~~tQ, \-<" ';) T... \~ ~ '\0 \" ..\0 ~\() <.. \ \1'-- '- ~ç \ \ . ,-) \.......... ~<t\-..J\~« ,/' ~ )~:~~~\ (! \.:) \ Cs g \''7\")<) '( i DV ~ í\.. . U ~I' ____ \t d\ ~~\s <:.()~(~~ ,\Û ç' ~Q\ '''"~\lJ C~t 701 to cover <:: ~O'lo ~ ~ Der=3 'l'heoretical TOC c')atú~~ \oc.. ~ '\SOOI ~J Cement Bond Log (Yes or No) \-.JÙ i In AOGCC File.\.....) þ..., ~\\. Prociuc.tion Log: Type ¡Evaluation P'~-.:c\\'$~' \t--~,~\\'i:H' ':>,,'C:>~.~ c......""^"~\.v.-\';.~~ ~\i ~~"'~ a ç ,--\,5"'20 . _ .,. 'N u...\Q. \'-~~~c.. \-'\c:)\......~~'-> \)(.(..\"'-0... ,>"«c>-'D'i S\ ~(g:c.()~"'~\t.. \~2)\ ." C1 I c; ~ CONC:LUSIONS: .'- ~ ?art ;1: ? ax:: : z , M.1:: '\ ''-> \ ~ \"1" '- ~I\ ~ ~<C> ~h \0 '-GV\-fu:\_ c. ~ ç\..- h-~ "'N\. ,~,\-"= ''''- ~a ~'i"7~ c...~"~~\'>\Ù('. :>- ,- ;i' \:>'":\ . Ù 1 C-27 ( PTD # 199-043 ) Failed TIFL . . Tom, 1C-27, gas lift producer, PTD # 199-043 failed a TIFL 02/08/07. T/I/O = 300/780/300 psi prior to the test. The well has been placed on the Sustained Casing Pressure report and slickline will be dispatched to troubleshoot the T X IA communication. Let me know if there are any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophil/ips.com «1C-27.pdf» Content-Description: 1 C-27.pdf 1 C-27.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 2/23/2007 10:27 AM Review of Sundry Application 307-063 ConocoPhiUips Alaska, Inc. Wens Kuparuk River Unit lC-27 Kuparuk River Field, Kuparuk River Oil Pool Requested Action: ConocoPhillips Alaska, Inc. (CP AI) proposes to convert an existing development wellbore to WAG injection. Recommendation: I recommend approval of CP AI's proposed actions Discussion: CP AI proposes to convert weIll C-27 from development oil status to WAG injection service. The well bore is completed in the Kuparuk 'C sand' and the conversion is intended to provide production support to other 'C' sand development wells in the area. The original wellbore was completed in June 1999 and began production in September of that year. To date the subject wen has produced a total of 1.6 million barrels of oil and is still producing at approximately 300 barrels per day. PCJŒ>4D1Œ 01 Rie(Fq (tl:I!d):Ch1¡i6jm ~Rie(Fq(tl:I!d)D:npJ6im D'l1E The well is located in a portion of the pool that currently does not have much injector support. Converting this well to an injector should provide pressure support to the other producers in the area and increase ultimate recovery from this portion of the pool. Kuparuk 1C Pad Well Bottomhole locations 5980000 5978000 5976000 5974000 5972000 Q) ..... ro 5970000 !: :¡:¡ ... 0 0 5968000 u >- 5966000 5964000 5962000 5960000 5958000 550000 555000 560000 565000 570000 575000 580000 X Coordinate . Producers 1C-27 Conclusion: Converting this wen to WAG injection service should improve current operations in this portion of the pool. Therefore, it is prudent to authorize CP AI to perform their requested actions because of the future benefits that should be achieved. D.S. Roby Reservoir Engine r February 20,2007 . . We1l1C-25L1 Assessment of Cement and Wells Within One-Quarter Mile Application to Convert to Water Injection January 12, 2007 5(;ANNED JAN 1 9 2007 1 C-25 Cement Evaluation WelllC-25 is a Kuparuk C sand producer equipped with 3Yz" tubing and 3Yz" production liner. The 3Yz" liner spans the entire C sand from 9416' -10,138' MD, 6213' - 6648' TVD. The Lllateral in welllC-25 was recently drilled and completed with 2%" slotted liner in the C Sand, while still leaving the original perforations open in the 1 C-25 wellbore. It is proposed that welllC-25 and the lC-25Lllateral be converted to water injection. The only other well within one-quarter mile of the C sand of lC-25 or lC-25Ll is welllC-27 to the east. The 3 Yz" liner across the Kuparuk C sand in well 1 C-25 was cemented in place on April 26, 1999. A total of 33 bbl of 15.8 ppg cement were pumped, which compares to a gauge open hole volume of 13.9 bbl. The cement job proceeded smoothly without any problems. Full returns were maintained throughout the cementing operation, and the pipe was reciprocated until shortly before the plug was bumped. Gemoco "spirolator" centralizers were installed on every joint. After releasing from the liner hanger, 13 bbl of cement were circulated off the top of the liner. A SCMT log run on June 24,2006 shows excellent cement coverage over the entire 3 Yz" liner. The lC-25Lllateral exits the 3Yz" liner at 9793' MD (6440' TVD), which leaves a 223' cemented interval across the 3Yz" liner up to the 7" shoe at 9570' MD. ~ ~ 1 C-27 Cement Evaluation \ S <;. -CJ ~ '3> ~ Well 1 C-27 is a horizontal producer in the Kuparuk C sand, although there are plans to convert it to water injection in 2007. It is completed with 7" production casing cemented to a depth oflO,787' MD (6403' TVD) with 4Yz" slotted liner installed in the horizontal section. There is approximately 490' of separation from welllC-25Ll at 6482' TVD in the C Sand. The 7" casing in welllC-27 was cemented in place on June 3, 1999 using 37.5 bbl of 15.8 ppg cement. The job proceeded smoothly without any problems. The calculated top of cement is reported as 9987' MD (6202' TVD), but no cement evaluation log was run. Full returns were maintained during the cement job, and the casing was reciprocated until shortly before the plug was bumped. Gemoco bow-spring centralizers were installed on every joint for the bottom 25 joints. The 7" casing was pressure tested to 3500 psi prior to drilling out, but for some unknown reason no LOT or FIT was conducted after drilling out the shoe. 1. Gary Eller ConocoPhillips Wells Engineer P AI Daily Drilling . . Page 1 of2 "... Cono~Phillips ConocoPhillips Alaska Daily Drillin2 Report Well Sidetrack Network 24 Hrs TMD TVD DFS REPT NO. DATE Proa iC-27 1C-27 AK0024 0' 10,797' 6,405' 13 6/3/1999 FRED HERBERT I Supervisor RICK Proposed TMD O' Pressure Test(s) OVERSTREET Rig Name Pool 6 Dailv Cost $0 Type J Date I TMD I TVD I MW I Press I Tot. Dress I EMW . Field KUPARUK RIVER Cumulative Cost Name UNIT $0 11'1'1 ppgl psil 0.00 psil 0.00 ppg Current PU BHA. Last Safety BOP Tst '3/29/1999 I Status Meeting (LastINext) Event ODR ~ncident 1st 24 hrs? Rig Accept: 5/22/19993:30:00 AM@ Code No Rig Release: 6/30/19996:00:00 PM @ 24 HR Forecast Last TMD: INe: Azim: Last Casing Next Casing Survey ¢1 ~ Q ~ OnerationsSummarv From To Hours Phase !Activity SubcodE: Time Trouble Start End Class Depth Depth Operation 00:00 03:00 3.00 PROD CIRC P 10,797' 10/797' Circulate & condition mud. Held PJSM or cement iob. Pumped 5 bbls water to flush & fill lines. Press. test lines to 3500 psi. Pumped 20 bbls ARCO pre-flush, 40 03:00 06:00 3.00 PROD CEMENT PUMP P 10,797' 10,797' bbls ARCO spacer, dropped bottom plug, pumped 37.5 bbls cement, clropped top plug, displaced w/rig, bumped plug. Press. to 2000 psi for 10 min. Check float eauiD. 06:00 07:00 1.00 PROD P 10,797' 10,797' RD casing equip. LID landing Jt. I-- 07:00 08:30 1.50 PROD P 10,797' 10,797' Drain stack, install packoff, test to 5000 psi, 10 min. 08:30 11:00 2.50 PROD WELCTL BOPE P 10,797' 10,797' Change bottom rams & saver sub on OD drive. 11:00 12:00 1.00 PROD WELCTL BOPE P 10,797' 10,797' trest choke manifold, witness by Irhuck Shieve (AOGÒ. Set test plug, tried to test, no good. 12:00 14:00 2.00 PROD Np EQIP 10,797' 10,797' ry to energize test plug, no good. Pull test plug & inspect ( confirmed wrona olua). rest top pipe rams, blind rams, 14:00 16:30 2.50 PROD WELCTL BOPE P 10,797' 10,797' Hydrll, all BOP valves, floor valves, koomv test. Bottom oloe rams failed. Change out bottom rams try to test (failed). Change out saver sub change 16:30 00:00 7.50 PROD WELCTL BOPE P 10,797' 10,797' gaws and guide. Pull out wear plate & inspect. Wait on parts. Put on new seals try to test (failed). Changed ams to 5" test to 250 -/5000 OK. 24 http://partners.conocophillipsalaska.com/dril_ling/cgi-bin/reports/ daily. asp ?wellname=1 C%2D27 &... 1/11/2007 PAl Daily Drilling . . Page 1 of2 r- ¢1 ~ Q ,., ConocJPí"illips ConocoPhiUips Alaska Daily Drillin2 Report Well Sidetrack Network 24 Hrs TMD TVD DFS REPT NO. DATE Prog 1C-27 1C-27 AK0024 0' 10,817' 6,410' 15 6/5/1999 Supervisor FRED HERBERT / RICK Proposed TMD 0' Pressure Test(s) bVERSTREET Rig Name Pool 6 Dailv Cost $0 Type I Date I TMD I TVD I MW I Press I Tot. press I EMW Field KUPARUK RIVER Name UNIT Cumulative Cost $0 11'1'1 ppgl psil 0.00 psi 0.00 ppg Current TRIP BACK IN Last Safety BOP Tst HOLE. SUP & CUT 5/29/1999 I Status DRILL LINE. Meeting (Last I Next) Event ODR ncident 1st 24 hrs? Rig Accept: 5/22/19993:30:00 AM@ Code No Rig Release: 6/30/19996:00:00 PM @ 24 HR Forecast . .- , Last TMD: INC: Azim: Last Casing Next Casing Survey Onerations Summarv From To Hours Phase ~ctivity SubcodE Time trrouble Start End Operation Class Depth Depth 00:00 101:00 1.00 PROD TRIP P 10,797' 10,817' Finished P/U 4" DP, run DP out of lcIerrickand taClCled @ 10684', 01:00 102:00 1.00 PROD CIRC P 10,817' 10/817' Circulated· hole. RU test equip. Ran C.LT. on 7" casing' 02:00 03:00 1.00 PROD CASE DEQT P 10,817' 10,817' (30 min.). RD test equip.3500 psi for . GO min.s 0 psi lost 03:00 03:30 0.50 PROD Np EQIP 10,817' 10,817' ost power, traced out and reset. 03:30 08:00 4.50 PROD DRILL DRLG P 10/817' 10,817' Drill out float collar; cement, & float shoe f/10684' t/l0797'. 08:00 D9:00 1.00 PROD DRILL DRLG P 10,817' 10,817' Drill 20' of new hole f/10797' t/10817'. ART = 0 hrs AST = 1 hr. PJSM on new mud (drilling fluid). lean possum belly, flow lines etc. 09:00 14:30 5.50 PROD CIRC P 10,817' 10,817' Displace hole with new 10.5 ppg Baradril-N. Circulating pressures 500 psi high than normal. Circulate BU ~hile cleaning pill pit to mix dry job. Monitor well (static). Pump dry job, 14:30 20:30 6.00 PROD TRIP P 10,817' 10,817' POOH to avoid swabbing and wet bioe. Work BHA take out sources, break off 20:30 22:00 1.50 PROD P 10,817' 10,817' bit. Clean out jet nozzles on bit and reDlace 2. 22:00 00:00 2.00 PROD PULD P 10,817' 10,817' Unload data and reprogram MWD. Orient bit and work BHA. 24 Hr. Sum: http://partners.conocophillipsalaska.com/drilling/cgi-bin/reports/ daily . asp ?wellname= 1 C%2D27 &... 1/11/2007 . t ...'" '''ARCO Alaska, Inc. Hole Diameter: Angle fhru KRU: Report Dale: 06103/99 AFC No.: AK0024 Shoe Depth: 10.787' 8.5' . (- Cementin Details Report Number. 2 Fl&ld: lC Depth: 10,698 % washout: State type US6d, intervals covered and spacing Run 1 bow spring centralizer per joint for joints 1·25 Weight 11.0 Gels before: 1 !iI22 PV(prior cond): 26 Gels after. 618 Mix wtr temp: Mix wtr temp: 70 PV(after cond): 27 Total Volume Circulated: 1254 bblS Volume: 20 Volume: 40 No. of Sacks: No. of Sacks: 173 YP(prior cond): 36 yp(aI1er cone): 20 Weight 8.35 Weight 12.0 Weight: Yield: Weight 15.8 Yield: 1.21 Additives: Class 'G' w/3% D53, 0.6% D6S, 0.130% D8OO, 0.80% S001, 0.2 gallsk 047, 0.1 gallsk D135, 2.0 gallsk D600 Rate(before tail at shoe): Rate(tail around shoe): 6 bpm 2 bpm Reciprocation length: Reciprocation speed: 20. 15fpm Actual Displacement: 461 bbis (see remark.s) Sfr. Wt. Up: 300k Str. Wt. Down: 1501< Str. Wt. In mud: Aoets held: yes CP: Date:06lO3l99 Time:05:25 Remarks:Caslng went bouom & circulated with no problems. Pumped 20 bbls wash, 40 bbls Area Spacer, 37.5 bbls 15.8 cement & Displaced with rig pumps. At calculated displacement (by strokes) It was determined that tha mud pumps were not operating at the expected OU1put as tha pressu... build was not enough, casing on vacuum. The plugs were confirmed to have left the head. Continued pumpIng until bumping the plug 62 bbls over by the strokes. Reelp casing unW within 100 strokes of bumping plugs (calÇ\Jlated). Calculated top of cement: 9987' Cement Company: DS Rig Contractor. POOL Bumped plug: yes Approved By: Fred Herbert I Rick Overstreet . fr . (~. Casing Detail 7" 26# Casing WELL: lC-27 DATE: 06/01/99 1 OF 1 PAGES ARca Alaska, Inc. Subsidiary of Atlanflc Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RTto LOS = 30.93' TOPS 7" Landing Joint 30.93 7" FMC GEN V FLUTED MANDREL HANGER 1.88 30.93 jts 3-262 7", 26#, L-80 BTC-MOD (260 jts) 10665.59 32.81 Gemeco Float Collar 1.32 10698.40 its 1-2 7", 26#, L-BO BTC-MOD (2 jts) 86.18 10699.72 Gemeco Float Shoe 1.47 10785.90 BTM OF SHOE @ 10787.37 TD.r@ 10797' leavina 10' of rathole 10787.37 25 Gemeco Bow Spring CENTRAUZERS ¡¡ii.t:¡i.i¡¡:¡:rn:iiiitlti¡tRiñ¡¡ºm:~mp.il&r.$¡;tii¡¡}.J.Ki¡¡¡i.k¥,f$.¡iaiit¡i.MMi.i.i.MIm:i.iliti.¡¡¡ . . Remarks: String Weights with Blocks: 300k Up, 150k On, 70k Blocks. Ran 262 joints of casing. Drifted casing with 6.151" plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Casing is non-coated. Pool 6 Drílling Supervisor: FRED HERBERT / RICK 0 VERSTREET Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2926 Company: Alaska Oil & Gas Cons Comrn Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 07/31/03 Field: Kuparuk Well Job # Log Description Date BL Color CD 1B-10 i ~ )- I,'~,, ~'-3 SBHP 07/21/03 1 ! su.wY 1 D-140 ~ t ~ ~ SBHP 07122/03 1 1J-10 ~-~+ { SBHP 07/21/03 1 2B-01 ~ ~-~,..~ PRODUCTION PROFILE .07/19/03 1 2B-02 ~-~- ~,~ PRODUCTION PROFILE 07/20/03 1 2B-14 ~- ~ ~ ~ PRODUCTION PROFILE 07/23/03 1 2E-11 ~ ~.~_-~.~ PRODUCTION PROFILE 07/18/03 3F-13A ~ ~'-~'~ LDL 07/17/03 1 3K-08 ~-~ ~ LDL 07125/03 1 3M-03 ~~ ~ !~ LDL 07124/03 1 3S-19 ~.-~..~ PERFIJEWELRY/& INITIAL SBHPS 07/11/03 .... ., , ..... . .,,, DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Permitto Drill 1990430 MD 13910 '-~ TVD DATA SUBMITTAL COMPLIANCE REPORT 71212003 Well Name/No. KUPARUK RIV UNIT 1C-27 Operator CONOCOPHILLIPS ALASKA INC 6412 .--- Completion Dat 6/29/1999 -~ Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22943-00-00 UIC N REQUIRED INFORMATION Mud Log No Sample N.._Qo Directional Survey N.__Qo DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type ~ Fmt (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval Start Stop OH I Dataset CH Received Number Comments 9056 4-7 SRVY RPT 1 ~R/EWR4-MD FINAL C,I;)GPJCN P/SLD-MD FINAL ~SR/CNP/SLD-TVD FINAL ~PJEWR4-'FVD FINAL 680O 0 6925 6925 4551 4551 13867 13910 13910 13910 6411 6411 Open 11~/1999 /_.D9056 6800-13867 OH 11~/1999 ~9656 SPERRY MPT/GR/EWR4/CNP/SLD OH 7/29/1999 SPERRY 0-13910. OH 11~/1999 6925-13910 OH 11/4/1999 6925-13910 OH 11/4/1999 4551-6411 OH 11/4/1999 4551-6411 Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y/~) Chips Received9 Y / H Analysis Y / N .......... R~n~.iv~d? Daily History Received? Formation Tops y~~N N Comments: Compliance Reviewed By: Date: Annular Disposal during the second quarter of 2002: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-15 10176 100 0 10276 371 10446 21093 March April CD2-25, CD2-50 2002 2002 2P-420 9479 100 0 9579 150 0 9729 April May 2002 2P-427, Heavenly 2002 2P-415A 26238 100 0 26338 52 4943 31333 March April 2P-431, 2P-422A, 2P-427, 2002 2002 Heavenly, Grizzly, 2P-441 CD2-49 27474 100 0 27574 386 0 27960 April May 2002 CD2-46, CD2-22, CD2-50 2002 CD2-17 14962 100 0 15062 372 0 15434 May 2002 June2002 CD2-48, CD2-46 1D-11 32102 100 0 32202 235 0 32437 May 2002 June 2002 1D-103 CD2-32 18536 100 0 18636 379 0 19015 June 2002 June 2002 CD2-19, CD2-41 1C-18 4176 100 0 4276 379 0 4655 June 2002 June 2002 1C-104 Total Volumes into Annuli for which Dis 9osal Authorization Expired during the second 7uarter 2002: ~ Freeze P~otect To~al Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 1J-09 24202 100 0 330 24632 Open, Freeze Protected May 2001 May 2001 1J-10 1C-17 33139 100 0 160 33399 Open, Freeze Protected May 2001 June 2001 1C-133, 1C-121, 1C- 123, 1C-127 CD2-42 33507 100 0 385 33992 Open, Freeze Protected June 2001 October CD2-24, CD2-33, CD2- 2001 15 2P-417 30965 100 0 887 31952 Open, Freeze Protected October March 2P-422, Grizzly, 2P-451, 2001 2002 2P-441, 2P-448, 2P- 422A, 2P-420 1C-27 31766 100 0 153 32019 Open, Freeze Protected June 2001 July 2001 1C-127, lC-117, 1C- 111, 1C-123 Annular Dis ~osal durin the second quarter o~2001: /¢%1/5 h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date / 1C-17 33139 100 0 33239 0 33239 May01 Jun01 lC-133, lC-121, lC-123, lC-127 :~ 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar 01 May 01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2-24 i' 1C-27 3533 t00 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli for which Disposal Authorization Expired durin$ the second quarter 2001: · Total Voiume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus '~ 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 · 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- '~ 2000 35, CD1-32, CD1-24, CD 1-22A, CD 1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only - CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 annutar vtsposat aurtng tne tntra ~,uarter of h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-27 28133 100 0 28233 3633 31866 June 2001 July 2001 1C-127, 1C-117, lC-111, 1C-123 CD2-42 13465 100 0 13565 18134 31699 May2001 July2001 CD2-24, CD2-33 CD2-24 30443 100 0 30543 375 30918 June 2001 Sept 2001 CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec2000 July2001 2N-314, 2N-302, 2N-332' 31453 100 0 31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 1C-16 19579 100 0 19679 0 19679 Sept 2001 Sept 2001 1C-102, 1C-131 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept2001 1C-123, 1C-119, 1C-102 CD2-39 279 100 0 379 0 379 Sept 2001 Sept 2001 Freeze protect volume from CD2-39 7 CD2714 276 100 0 376 0 376 Sept 2001 Sept 2001 Freeze protect volume from CD2-14 Total Volumes into Annuli for which Disposal Authorization Expired durin~ the third quarter 2001: · Total Voiume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQ1, CD1-21 2N-332' 225 100 0 325 Open, Freeze Protected July 2000 July 2000 Freeze protect 2N-332 only 2N-347 31540 100 0 31640 Open, Freeze Protected Sept 2000 Sept 2001 2N-349, 2N-305 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2000 1D-30, 1D-40, 1D-141, 1D-36 1D-30 31622 100 0 31722 Open, Freeze Protected Sept 2000 Oct 2000 1D-36, 1D-34 2N-318 ' 17498 100 0 17598 Open, Freeze Protected Dec 2000 July 2001 2N-314, 2N-302 2N-316 240 100 0 340 Open, Freeze Protected Aug 2000 Aug 2000 Freeze protect 2N-316 '2N-332 was permitted for annular disposal the first time in July 2000 (300-187) and re-permitted (301-219).in August 2001. The volumes for the expired permit applies just to that permit. Annular log Original ;Subsequent AC)GCC In PTD or Sundry Sunclry I letter Final Well Final Total Sundry C,¢~n~ :Approval Approval LOT/CMT Approval Report Fl{e Report Votume Operator F~cl W~ Name Approval Permit # Date Date Dates Results (y/n) (.y/n) (~/n) Date Injected CornineSs .... BPX DIU : 1-O3/P-16 PTD 95-150 11~95 NIA N N __. ol Never u~l=e~ BPX PBU 11-38 SUN - 96-189 1119/97 N 0 Nevarutltized, noeundryflled 3PX DlU 1-19/I-18 PTD 95-093 8/17/95 N/A Y N 2/28/97 8960 A~omval fax from BEW; from BPXA 1995 & 1996 con'ected summaries BPX DIU 1-23/O-15 PTD 94-128 1/13/95 N/A N Y ___Y 2/26/97 32084 From BPXA Annular inJection Data Entry Screen; from1-53.K320, 2-40/S22,1-O3/P16 AAI PBU 12-35 PTD 95-130 10/27/95 N/A N Y Y 2/6/96 3723 From BPXA Annular Injection Data Entry Screen AAI PBU 12.38 PTD 95.158 11/21/95 ~I/A N Y .Y 2/28/97 4032 fromBPXAt995&1998cormc~:lsurnmariea BPX DIU 1-33/M-23 PTD 95-107 1~4/95 N/A N Y N 2/28/97 9879 Letter app~3val fax; sudace broach; volume from BPXA 1995 & 1996 contacted summaries ___ AAI PBU 13-36 PT[3 95-167 12/24/95 N/A N Y N 2/28/97 4137 from BPXA 1995 & 1996 corrected summa~es AAI PBU 14-44 PTD 95-103 9/15/95 ~IIA N Y 12/14/98 3974 Frorn BPXA Annula__r Injec~on Data Ent~j Screen AAI PBU 15-42 ---' PTD 95-185 ,1/17/98 N/A 'N N n/a 0 Nevarufiltzed AAI pBU 15.43----- PTD ~6..083 5/25/96 N/A N N n/a 0 Never utilized :~,1 PBU 15-45 PTD 96-069 5/4/96 NIA N Y Y 7/2/96 1882 Broach to surface - downsqueeze annulus 5/5/96 -- -- AAI PBU 15-46 PTD 98,061 6/20/96 N/A N N n/a 0 ~lever utilized ~AI PBU 15-47 PTD 95-174 12/8/95 N/A N Y N 2/28/97 3002 from BPXA 1995 & 1996 corrected summaries AAI PBU 15-48 P--~D 95-208 3/11/96 N/A ___ N Y Y .... 4/11/96 3385 From BPXA Annular Injection Data En_t_t_~ Screen AA__I__ PBU 15-49 PTD 96-034 4/7/96 NIA N_ Y Y 2/28/97 4869 from BPXA 1995 & 1996 corrected summaries BPX Diu 1-59/O-24 PTD 96-022 2/21/96 NIA N N n/e 0 Never utilized BPX 3J'U ' 1-61/Q-20 PTD ~4-142 12/16/94 NIA N Y 12/14/98 25228 From BPXA Annular Injection Data EntrX Screen; from 2-48/O13.,. 1-65/N25 BPm~- DI-U--- 1-65/N-25 --- PTD 95-1~8--- 1--/2~o/98 NIA N N n/a 0 Never utilized AAI PBU 18-30 PTD 95-091 7/26/95 :N/A -- - N __ Y _ 12/14/98 2266 From BPXA Annular InJe~on Data Entry Screen AAI PBU 18-31 PTD 95-109 9/9/95 ~llA N Y__ .... 12/14/98 6086 From BPXA Annular Injection Data Entry Screen AAI PBU 18-32 PTD 95-124 1015/95 NIA N Y Y _ __ 115/98 3311 From BPXA A_nnular Injection. Data Entr~ Screen; from 18-32 AAI PBU'-- 18-33 PTD --- 95-143 10/29/95 __ NIA ........... ........ N Y Y 1/16/96 5215 From BPXA Annular Injection Data Entry Screen AAI PBU 18-34 PTD 95-164 12/4/95 NtA N N n/a 0 Never utilized -- Unocal GPT ~8742 28RD2 PTD 95077 8/18/95 NIA ....... N N AAI -'- KRU 1C-11 SUN 96-172 1/14/97 11/8/96 '- Y 'Y Y 4/9/97 _ 34985 from AAI re[~ submitted 2/26/99 AA! -" K'--R-O-' lC-13 P'rD 98-Oll i2/13/98 NIA Y__ Y Y .___~/99 26900 from AAI report submitt~ 2/26/99 AAI '-- K-AU '¥C-14 PTD 98-017 3/17/98 NtA ,Y N__.. N contingent on date submittal, data not in well file, FIT to 16.0 . AAI KRU lC-15 SUN 198.229 12/30/98 1/8/~9 ............ 7/27/99 48990 permission granted 4/22/99 to exCeed 35~000 bbl limitation. _~Ai_L__._._KRU lC-16 SUN 98-24S 12/31/98 0.h_y_~_rat_.~e~p_..~._ms b_~_~_~.ch___~.g,, no 10.403 in well file. AAI .... KR___U. 1C-17 PTD 98-224 12/2/98____ 3_/_18/9~.___ 5__~_2~_17____ 14.9, 14..1___N___ .......................... co__n.t_/n enen~ 10__0_-4_0_~-403 ann____ular denied 12/23/9e,~3118/99 AAI KRU 1C-t8 's-uN 9-~-005 4/2/99 61tl/99 13.8 __ __ Approval# 39g-070 ... AA--i 'T<-~u IC-21 SU__~N, 98,013 .E~.tm(~O AAI KRU '1C-23 ...... SUN 98,034 5/21/99 5/28/99 34570 from AA110/5199 [e_p. off, telte, r_~r.._oval to exceed volume limit g.ranted 8/11199 AA--~ ' KRU._ 1C-25 SUN -- 99-031 5/27/9g 4/30/99 34936 from AA11015/99 report PA~ <.U ~C.=7 SUN -~0~' , .............. PAl .... KRU 1C-t23 SUN _20--1-064 ..................... ,,~reque~t later./_n~o not provided AAI K-RU 1D-09 --- .'~UN 98-065 6/3/98 .7/7/98 Y Y Y 10/5/99 32640 from AAI report submitted 2/26/99 ~,AI .... KRU 1D-10 ~ PTD 98-049 4/12/98 .N/A .......................... _Y__ ..... Y Y 7/27/99 35573 contln, i;[ent o~ clara submittal. In well file; from AN r__e~oort ~bmllled 2/26/99 AAI KRU 1D-11 S~N . . 9g-072 10/26~9 235 _w/~r~lueSt later, Info net AA-"~- KRU_ 1D-12 SUN 99-084 _ 9/2____.0/99_~_.9/2.__~___9_ .............. N N Y ._ 1._._~13/00 ...___~891 ~ 10113~OO0 ~o~ AAI KRU 1D.130 -- PTD 97-183 11/7/97 NIA .... Y N N D contingent on data submittal_LOT data l~n._.~_~l file; Never utilized ~A-'T- KRu 113-14 SUN 99.089 35504 notified commission of exceede__n~_~_.__~_P_PCO.._1...0/13/20_~___quarta__~_r_e~__ ......................... PA~ K.U 10'-'~40 __ _SUN_~___ .~-13~ ........... -~ PAl KRU~ 113-30 SUN 200-104 31722 fr__om PPCO l~rt_~ort PAl KRU 113-32 SUN 200-173 ......... 2_.3599 from PPCO 4/2_._4/0~ 1 quarte__~ m_~port, source wells: 1D-39 .... PAl KRU 1D.34 SUN 200-143 322_3~_ LOT to 13,1, 11,4 for annular. Sundry approval#300-280 PAl KRU 1D-3S .... SU_~N 2--00-!30 ........... 10/U_,.00_ N 302O4 ;~m PPCO 1/19/2001 ~__~ report_ ..... : .............. ___ ............................ PAl KRU 1D-37' SUN 280-204 ..................................... ' w/re_~ae-~'wflen well completed k3st rtrns during crrff'g, found TOC '740', top job. LOT ~shoe 14,9, deep test 13.5; total from PPCO PA! ..... KRU. 1D-3a SUN 2~0-077 ......... 7.__~/00__ 34007 10~~rt~ PAl KRU 1D-39 SUN 200-216 wl~__quest annular at later dato-not w/.[3td,. PAl KRU ,1D-40 SUN 200-119 ...... ~ .......... ~ p_~ ed~.k for s/t before annular in~ection >';~¥'-- k-~ 1~1o-4~i .... ,~--~"s-b-~" , ,, , '---~, .... , ......... --~----'--~.ueetanT.~=rat~=~=e~otw/~ ..... Page PAJ [KRU' 1~42 ~ ' ' I ~ L_~__ ~ Y , ~-~ IKRU 1E-31 97-138 8/2Q~7 IN/A i } , ~ ~2405 f/om PPCO 4/24/2~1 qua~ ~ source ~s:: 1D~37, 1D-39 .... Y [Y 12/15/97 3374~ contingent ~ ~ta a~lltal - In ~ell ~e: from AAI mp~t aubm#~ 2r26~9, ~ ~{,ikAI .... KRU 1E-32 p~ 97-132 [8/20/97 IN/A ----I I _ Y iY IY 1/30/~I 45305 cordon data subl~ttat, inffie; AOGCCverballyepproved 45,000, notiftedg/97 ofexceedence ~..IKRU 1 E-.'.'.'.'.'.'.'.'.%3 97-151 11/2/97 N/A _____ Y N 0 conl~ on data sul3miflat - In w~l lt~e; Never uaized ~1 KKRi~U 1E-34 97-168 10/9/97 NIA Y N I 0 cor~3gent on data-submittal, data n~ in well fie;, Ne~r u~ized ~A! 1F-17 PTD 96-047 7/1/96 N/A------~- i N '-- ~' I I 0 Neverufllized AA~ KRU 1F-20 .... .lU ~ 12r~3~ 14.S IN N i i ~as ~F-20A PAl iKRU 1J-03 __ SUN 201q324 1 1 --' 13120 from PPCO4/24/2001 quarterly report, source'a~s: 1J-09~ 1J-14. / 15.4. ~f~equast aplxoval at mn of dtllfing rations, w~! need to develop data sheet and ~3ok into PAl KRU 1J-09 SUN 201-044 2nd=13.8 ___ additional precaultona necessa,'y for gas-,chaq~ed sands? N/A to surface (ag shoe - deep sanda. w/request approval at completiort of drilling op~ra~,ts. Will need to develop data sheet and look into PAJ KRU 1J-10 SUN 201-071 __ additional precautions necessa~ ~ ga~ed sands? N/A to surface csg shoe - daep ~ands. PAl KRU 1J-14 (S~v_ert~p) SUN 200-200 w/reciuest ff production csg set 3Al 1L-28 ___ SUN 199-098 Y 4/24/01 9937 /mm PPCO 4/24/2001 quarterly ~ s~)urce wells: 1L-20A, 1L-26A AAI KRU 1Q-20 PTD 95-131 9/15/95 N/A N ;N 13 Never~!~,.;l AA__[I KRU 1Q-21 PTD 95-133 4/20/96 N/A N ,N 0 Neverutllized - AAI KRU 1Q-22 __ PTD 95-140 4/18/96 N/A N iN O Never util~ed AAI KRU 1Q-23 PTD 95-141 1113/96 NIA NN N 0 Never utilized AAI KRU 1Q-24 PTD-- 95-121 12/31/95 N/A '--' ___ - __ N N ._ 1/17/96 -~23258 fmmreportsubmlttad2/21N99,4/9/99 __AAI KRU 1Q-26 PTD__ 95-132 1/21/96 N/A N Y N 1117/98 26031 from AAt report submitted 2/26/99~ 4/9/99 BPX DIU 2-49/S-22 PTD _ 94.162 2/10/95 _.. NIA .__ N Y Y .... 2/26/97 31195 From BPXA Annular In,leetlon Data____Entry Screen; from 1-311M21,1-19/118,1.33/M23 AAI __ KRU 2A-18 PTD 95-059 10115/95 N/A .......... N__.. Y 5/1/95 16284 ifrom AAI report subm#ted 2/26/99 AAI _KRUg__ 2A-22 PTD 95-056 6/11/95 N/A N Y ~' .... 4/9/9-~ _ . 16849=from AAI mporl submitted 2/'26/99 AAI _. KRU 2A-25 PTD 196-062 4/24/96 N/A N N 0 Never utilized AAI KRU 2F-OSX PTD ..... 196-203 3/25/97 NJA ____ Y Y Y 7/7/97 13840 ~nt on data sui3mla~n - in well file; from AAt .m_port submitted 2/26/99 AAI KRU 2F-18 ........ SUN 96-178 2/12/97 .... 1/17/97 .......... Y Y Y 5/20/97 26368 from AAI repot1 submttta(t 2/26/99 AAI KRU 2F-19 PTD ~6-201 8~/97 N/A- N Y Y 3/1/97 20825 From Cam_pl.__~on Rel~3rt & A~A.I re_port submitted 2r,26/99 AAI '~RU 2H-17 SUN _. 2___~-019 '--' __ ..... _ AAI KRU 2L-305 SUN 98-240 12/6/98 ._AAI_L ..... KRU.. 2L-307 - SUN -- 98.256 5/3/99 2nd approval from AAi 7/25/2000 report. 2nd 403 request 11/20/00. Wastes to date: 3/99 8654 bbls fro, 2L.307, AAI KRU 2L-313 . SUN 98-219 11/21/98 12/2~t/98 11/1/2000 ............ 2___.~_90 4/99 3879 bbls fm. 2L.307, 5/2000 4740 bbls fm. 2L-317, msum.e_d~lling.2L-,317, AAI KRU 2L-315 SUN 98-218 12/15/98 :.A~_I ~ KRU 2L-317 SUN ................ Sidetracked as 2L-317A :AAI KRU_ .2L___~_17A.-_-__-~-~_-'--_'-_'. SUN ~ ~3~.-~-~3- ..................................... w/requ_ee_t._a.E~o__v~_~_L~_~_p_~_on_.~ drlllin_g__o~erations' :AAI KRU 2L-321 SUN __ 98-262 1/11/99 ;AAI KRU 2L-323 SUN 98.251 12/25/98 -- ~,~j KRU 2L-325 SUN 98-209 11/12/98 12/8/98 - ~ 20380 from AAI 1/24/2000 mDOrt ~,-~ KRU 2L-329A SUN 98-225 11/3/98 11/8/98 Y 34071 from AAI 1/24/2000 report ~1.---~.- KRU 2M..31 __ SUN 96.077 9/9/96 5/17/~ ................... ~' ...... ~" .... ~'-- ........... 1¥~-/9~ ....... '.5,~-contin~.entont0.403, datalnwellflleLfromA~../re~__rtsubmitte~l~6~9 AA! KRU 2M-33 PTD 96-072 7/25/96 N/A .... N Y Y ' 1~'{)-/~ 30201 from AAI re. lx~t submitted 2/26/99 AAI KRU 2M-34 . ._ SU__~N .... 96-079 1015/~6 .......... ~ ....... N 0 Never utilized ....... AAI KRU 2M-35 PTD 96~080 8/28/96 N/A N N 0 Never uttlize~ .PAl .... ._KR~U. 2N-302 SUN ............ 201-115 .......... _wl_re__q~e. sta ft.._~e_r ~llli__~;L_ ..... PAl KRU ;2N-305 SUN 200.135 380 LOT to 14.9, 2nd LOT for annular to 12,.9_, Su_nd_._~_ap_p_m__~val ~300-277 AAt _..~KRU. :2N-307 SUN 99-0t7 3/9/99 .................................................... No l0-403 in well fite as of g/20/00 AAI KRU '2N-308 SUN _9_9-01~0 .. _.~....~ ............. No 10-403 tn well file as of 9/20/00 ..A~,_I ..... ;.K_.RU.. 2N;30~ ............. SUN 99-021 4/3/9g No 10-403 in wetl file as of g/20/00 ' ' AA_JI .... K__.R_U 2N-313 . . SUN 98-091 8/2/98 8/28/98 .......... Y__ .......... Y Y ....... !_O/5_/~__9. 32858 from AAI rej3ort submitted 2/26/99 .... AAI (RU 2N-314 SUN 200-193 - ........ w/req~afte~__ AAI KRU 2N-3t5 SUN 98-190 9/30/~-' il/24/98 . _.Y ..... _N. ....... .¥_ ................ 254,26 contlng~_nt___on I0-403, I~n well flte,~l, Fr__om 1/24/2~30 re~ort ~AI _cffu 2N-316 SUN 200-09~-- .... 340 _br_~c._~hwhll____e_ed~.~l~ortosufface~ting~_. AAI KRU 2N-317 SUN 98-143 9/13/98~--' 9/25/98 .......... Y --- N N _c~_.n. tin_j~.n, ton___~0"40___~3~t.n_.wetlflle ~A'i-- KRU 2N-318 SUN - 2-'~-100 13995 __fr~m pPCO 4/24/2001 quarterly report, source well: 2N-314 ................. ~ KRU - 2N-319 $-~1"~---_ 98-197 '1-~'8~8 DENIED ...... Y ~-' N ~. .............. Perrnlssion DENIED via t0.403 re[uast, FIT did not confirm shoe adequately cemented AAI _K~RU 2N~320 SUN 99-001 2/11/99 ' - ..... No 10.403 in well file as of 9/20/00 ...... AAI KRU 2N-321 ....... SUN ..98__-14__8__.8/24.___~_.8_8sfr Y N N contingent on 10.403, p&a for s/t ' from AAI report dated 10/5/99, RA tracer indicates possible channeling ab(~e surface shoe, AAI ., Kff,U 2N~IA ,, sUN, 98-173~ ~,~ , ,9~25/98 .............. Y. Y Y 10/5/99 27607 researching ...................................... Page 2 Annular AAI KI~U i2N-323 ' iFi-D 98-O71 '4/24/98 ihlA i i {Y IY iY t 7~27/cJ~1 32798tleeeraptx~valtnto2N-~.2N-32~,2N-343;f~A~d~lX~Subm~te~ ~AT--- KRU 2N,325 _~UN 98-1~3 9/18/98 ]11~5/98 tY IN N I Icontlngentonl0-403 :AAI KRU 2N-329 tSUN ;98-0~7 ~ '{5114/98 -t Y Y N 7/27/99l 109 ffomAAImportsubmitted~ ;AAI KRU {2N-331 ISUN 98-117 9/11,~8 i9/25/98 } ~[Y LN_ N _[__ contir~e~onl0-403, inwalltila _~__~ -i-- !N---.~-___ ~-__ i {,0-407(#300-187)sut:~m~:ted7/17/2030w/LOT&cmt'ginfo AA!PAl KRuKRU {2N-33512N'332- SuNSUN 98-204~30`079 7117/0010/19/98 7/21/130 ~--- ---~-- ......... 25495 fram PPCO 10/13~2000 quarterly report AA, KRU {2N-337A SUN 98-122 6/19/98 717/98 t ~~---I~-' 1[~5/99 30839fmmAAIreport~ubrnilmc12/2~ kal IKRU 12N,339 SUN 98-100 5/30~8 .='7f17/98~ I ~ N~ conb~gent on10-403, not in well flle es of g/20/00 .__ _AAI __ ?RU _~2__N-341 SUN __98-103 7/6/98il __iyN 34150 fnl: PPCO 10/13/20(X3 quarterly report, drilling no~s indicate 2N-341 in communication with 2N-347 I letter approval into 2N,328, 2N,329, 2N,343, injecl~d volume w/compl, rpt ~ 7/27/99, fa~cl prod. AAI KRU 2N-343 SUN 98.092 5/18/98 15/14/98 7/27/99 31808 Csg cmt. AAI KRU 2N-345 ISUN 98-113 7/18/98 8/23/98 cont~'3genton 10-403, lnwatlffie, broact~ed conduclDrwhile riffling 2N-343 50 bl31s cmt to surface, no broaching; volume from PPCO 10/13/2000 quartody report, drillJ~ notes PAl CRU 2N-347 SUN 200-063 6/16~30 r/21/00 31640 indlcate2N-341 i~ cow~lunicatton with 2N.347 PAl KRU 2N-349 SUN 200-111 S/T w/request annular at later date. S/T as 349A, no 10-403 in wall file as of 9/20~03 PAl CRU 2N-349A SUN 200-139 __ LOT {~ st~oe to 11.86~ 2nd LOT for annular to 10.72, Sund~j approval #300-278 PAl KRU 2P-417 SUN ~'ef~uast approval alter well drilled. ........ PAl KRU 2P-429 SUN 201-102 .w/request approval after w~l drl~ed. PAl KRU 2P-438 SUN 201`082 w/request approval after well dri~ed. PAl KRU 2P-447 SUN 201-104 __. w/request approval after well ddtlad. AAI KRU 2T-21 PTD 95-013 6/4~95 NIA N Y 5/1/95 91369:fi om AAI refx~lsub~nitted 2/26/99 AAI KRU 2T-32 PTD 95-049 10/20/95 N/A N Y 8/1/95 111000 from AAI report submitted 2/26/99 ................... =AAI KRU 2T-36 PTD =95-102 10/20/95 N/A N N 0 Never utitized __ __ kal KRU 2T-37 PTD 95-101 9/26/95 NIA N N 0 Never utilized __ kal KRU 2T-38 PTD 95-112 9/27/95 NIA N N 0 Neverutllized AAI KRU 2V-17 PTD ]7-008 NIA .... Y N ~- - 0 contingent on data submission; cancallecl__permit AAI KRU 2X-;17 PTD 95-'171 - 4/16/98 __ NIA .__ N Y N 1/17/96 495 from AAI m_port submitted 2/26/99 AAI KRU 2X-18 PTD ~5-160 5/9/96 NIA _. N__ Y N 1117/91~ 25079 from AAI report submitted 2/26/99 _ AAI KRU 2X-19 PTD 95-'175 3/22/96 NIA N N 0 .Never utilized .... AAI (RU 2Z-22 PTD 94-147 4/3/95 N/A N Y _~ 211/95 10807 fTom AAI report submitted 2/26/99 AAI KRU 3A-17 ~UN 98-t32 10/29/98 8/30/96 Y Y Y 12/16~ 13320 co_ntl__~t on 10-403, ~ta' In well file; 'from AN_._m_ pe~t submlffed 2/26/99 AAI KRU 3A-18 PTD 96-133 10/31/96 ~N/A Y N N 0 contingent on 10-403, ~ job to 550' _ AAI KRU 3F-t9 SUN 96.102 8/7/96 6/25/96 Y Y Y 10/29/96 15394 contin.~.ent on 10.403, data in well file; from AAI relx~t submitted 3/26/99 AAI __ KRU 3F-20 SUN __ 199`079 PAl KRU 3F-21 SUN 200-203 ..... _w/Il re_q~_~st at ~~__drllllng-O--Pe--_ra.__tto_nns~_ .............................................. AAI KRU 3G`03 SUN 96.q 22 8/29/96 8/5/96 Y Y Y 11/8/98 6473 contingent on 10-403, (late In weti file; from. AAI rel~rt submitted 2/26/99 ............. AAI KRU 3G-25 ....... PTD 96-t18 8/8/98 NIA N N . ~ continger~on 10-403 w/CQL or LOT; took kick, .Susponded well. AAI __ KRU_ 3G.26_~ SUN 99075 6/19/99 .................. AAI KRU _3t~1_-24 PT__D_____ _96,O15 5__/9_~__.___.._ NIA ............. N__.~_ .Y Y 10/28/96 27t17 from AAI report submitted 2/26/99; also 30201 bbl~ into 2M-33 & 15428 bbla into 3M-27 . . AAI KRU 3H-28 PTD 96-018 2/15/96 ~"A'- ....... N ~1 0 ~o&a & s/t as 3H.28A ,AAI KRU 3H-28A PTD 96-037 '5/8/96 N/A .N N 0 Never utilized __ kal __ KRU 3J-17 PTD ~. 96-146 12/21/96 N/A Y N 0 contingent on 10-4_~~_43__~" wa____s~te_~s_to__l_.C.-_~11 ~kal KRU 3J-18 P'ID 96-147 12/14/96 NIA Y N 0 contingent on tO-403 w/CQL or LOT _ kal KRU 3J-19 SUN 96.148 11/2/96_ ....... 1_.0/~J_~/~/~6_ ...........................Y_ ..... .Y_ ......Y _~_ 1/14/9.7. 21235. from AAI ~rt submitted 2/26/99 PAl KRU 3K-19 SUN 2__01-10a :~!an t__o eventual m~_~eSt~l~..val for an..__n, ular dispcoal -info not submitted w./ptd application PAl KRU 3K-20 SUN .)01-088 plan to eventua~a~E~.~__~r an~osal - info not submitted wl.p_td__a_Eplication ~-[-- ' KRU 3K-23--~ PTD 97.097" 7~'15/9~ 12121/9~'- .............. ~--- ..... N .......~1 0 _S.u_nd_~l_ap_provel# 398.327, 12/21/98 AAI =KRU 3K-24 SUN 98.249 1/30/99 3118199 Sundr~_a_Eproval#399-040~_~_18/9.___9- ......... _A_A~___T"_--_.-__. (RU---'3K~25 S__UN ..... 98081 5/2__.~5/9.8_.~ '1~0/9---~- N N N 4302 _Sun__d~oval # 39 .9-~301,.!./20/99 total fm ~99801 .r.e~ dated 4/9/99 AAI KRU 3K-2~_ PTD ........... 97-077 7/22/97 NIA Y Y Y 4/9/99 34070 from AAI re_port submitted 2/26/99, 4/9/99 AAI ~_ _KRU .. 3K-27 i PTD 97-046 5/8/97 N/A Y Y Y 7/18/97 37273 contir~[ent on data submittal, cOntacted AOGCC wi exceeded: from m.port submitted 2/28199 AAI KRU 3K-30 ...... 'SUN ._ 97-113___ 7/27/97 ___Y__ ..... N N not req_uested as of 6/8/01 AAI (RU 31(-3t SUN 98082 6/8/98 ....... _Y ..... N __N ................... not requested as of 6/8101 AAI .... KRU 3K-32 P'-T-~- ..... 97`076 5/2---~'?.-_-~_' N/A_ ............... Y Y Y 8/7/97 33480 contingent on data submittal- In well file; from AAI report submitted 2/26/99 AAI KRU 3K-34 SUN __98_-O77 6/17/99 5/28~8 ....... Y N N ...... ..S_u_n_d.~l~datedS~.~8~98 .............................................. AAI KRU 3K-35 PTD 97-109 7/21/97 NIA ...... Y N __N .......... 0 n__ot?.~_q, uested as of 8/8/01 AA1 KRU 3M-27 PTD .._ 95-214_ 5/--12-~6-- NIA . __ -~ ..... ~-'----' Y 10/29/96 -~-- 15428 from AAI report submitted 2/26/99 AAI KRU 3M.29 PTD 96`005 5/3/96 NtA N N 0 Never utilized AAI .K._RU._~__ 30-20 PTD __ 97`045 4/12/97 .__ N/A Y Y Y 6/23/97 11905 ~fingent on da{a eubmtttal - in well file; from AA! report submitted 2126/99 . AAI KRU 30-22 ....... PTD 95.186 2/8/96 N/A ........ N__ .......... Y N 1/23/97 6345 from AAI reports submiffed 2/26/99, 4/9/99 AAI KRU 3R-26 - PTD 95-187 2/4/96 NIA ............. N N ......... 0 Never utilized iPAI EXPL Atlas #I SUN 201-004 requested w/ptd iBpX" PBU B-33 PTD 93.018 1115/93 NIA ~N ~Y 12/14/98 .3974 From BPXA Annular injection Data Ent~f Sa~e_n;.from B.36 :a.x P~u ,~ ...... P~D ,,, ~085~,i~-/~TT'i~7~X--71 .... 7-- ......... I,N "~ ......... ;--;'--- ...... ,,,, 0 ~,v.r.ti!,=ed ....................... Page 3 Annular log AAI ' ~E,~',~ Buffieheedl iPTD 12/16/95' [12/12/95 ' IN 'i~Y, 9/5/96 111~ar~~1~,~v~BEW ...... ~l~u CDI~I__~ISUN ~ ~1~ ~ ~Y, ' -- ~1 CRU CD1~2 /~ ~172 -}] ~1' -- ~1 CRU ~1~ SUN 1~1~ Y ~1t P~ ~1 q~ ~ ~ ~: CD1~5 PAl CRU CDI~ SUN ~71 ~ ~ PAl CRU CD1-10 SUN 2~.171 ~___ ~ ~. w~ ~ s~ ~m ~al ~1 CRU CD1-13 SUN 1~ ~ , -'l 189 ~m~ 1D~~ ~ 'cRuCRU CD1-16 SUN 1~ 10~ -~ Y ~, .... ~ ~ 1~1 ~ CRU ~1-19~ SUN ~3 ~ ~ ~ ~ CDI-~ P~ 97-2~ ~1~ ~A N N ~ ~nfi~ent ~ s~, a~ul~ ~ CRU CD~-~ SUN ~ ~ ~ __ L ~ ~ ~ ~ ~ ~ - CRU CD1-24 SUN ~1 CRU CD1-25 ~N ~ ~7 ~m ~11~1~ q~ ~R _ ~1 ~ ~RU CDI-~ SUN ~ 1014~ __ _ ~ CRU CD1~7 SUN 2~ _ Y ~1 ~814 ~1~1 q~y~ ~r~s: CDI~, CD1-19~CDl~. CDI~ ~1 CRU CD1-28 SUN ~-1~ PAl CRU CDI~ SUN ~1~ ~1 CRU CDI~0~ SUN 9~5 Wa none .... ~E ~, near PAl CRU CDI~I SUN ~118 71 ~ ;~nd~ ~val ~, ~. PAl ~4~1 ~d, sou~ ~lls: CD1-14 ~ C~ CD1~2 SUN ;1~1~ ..... ~13 '~m ~11119~1 qu~ PN CRU CDI~ SUN 2~212 ~est ~n ~ai~ ~mp~ ~1 ~U CDI~ SUN ~3 _ 378 ~m ~17~ ;~1 CRU CD1G5 SUN ~38 317~m~11~4~ m~R . .. ~ ~RU CDI~ SUN 1~-112 1G~ ~7~m~l 1/1g~1 ~! .... CRU C~7 SUN ~7 ~ ~7~9 Y 1011~ ...~2~7 ~m ~11011~ m~R; ~. e~ ~1 CRU CD1-38 ~ SUN ~ ...... Y ..... 4~4~t ~20 ~ ~O ~ qu~ m~ ~ ~lls: CDI~, CD141, CD1-19A ~ CRU CD1-39 SUN ~ 9~0 ~16~9 ~ Y~_ 1~13100 315~ ~ ~11~13~ ~; auth. ~d ~1 CRU CD140 'SUN ~ ~11~9 N ~877 ~m ~17~6~ ~1 CRU CD141 SUN ~17 ................................ ~1 CR~._ CDI~ ~UN 199-I19 1~ 31~ ~m ~11119~1 PAl - ~U CD143 '~ SUN -- 2~.i~ ..... 31~7 ~p. ~0-241, ~m ~O ~_~1 qua~~ so~ ~lls: CD1-NQ1, CDI~ ~1' ~'bRU CDI~ ...... SUN. 2~5 __ - ........ .~__~-'--~--~ ...... '~, _~]92~m~14~1 ~ CRU CD145 SUN 1~101 ............................................. 323~ ~ ~1111~t r~ ~1 ~RU CD2-23 SU~ 2~027 ~ ........... ~1 ~CRU CD2~ .... SUN ~28 ..~ ..... ~1 CRU CD242 ~ SUN 201~7 ~ ........ . ...... ~nti~ent ~ da~ subm~ - In ~fl file Fo.c ~.L c~c~.~ PTD .7-2~ S~ N/A ~---~ .... T Y V 4~ ;~ BPX .~_ p~u D-30 P~. ~. ~ ~A N Y Y ~0~ 5281 From BP~ Annular I~ Dam E~ S~en BPX _ PBU D~31 .......... PT~_ ~71 5/1~ ~A N 'Y N ~7 ~ 1~ ~m BP~ 1995 &.1~6 ~ summ~es BPX PBU D~3 PTD :~ ~ NIA __ ;N Y 'Y ~11~6 ~1 F~ BP~ Ann~ar I~ Da~ Ent~ S~en BPX .~BU E~.__~D ... ~202 1~7~ ~A N ~ ~_. Y __ 2~6~7 ~ ~ From ~ Annular l~e~n ~ En~ Scm~; ~m E~, E~ :BPX PBU E-~ ......... PTD 9~073 711~5 N/A .... ~ ....... ~_ ........... 1~14J~ ..... 9~7~. F~m BP~~nu!ar I~on.~ S~en aPX PBU E-37 ~TD '" ~ ~5_~ NIA ........ N . Y _y~ 2~1~7 ~5 From BP~ 19~ &~ ~ summus; from E-39 BPX PBU E-~ PTD g~105 911~5 N/A N N 0 ~ver uflHz~ ~_ PB~ E-39 P~ ~-12L~m .-~A N Y Y 2~-~ 2250'FmmBP~An~rln~t~~eq;~mE~9 BPX ~ ~B~ F~3 ...... PTD ~ ~1~ NIA _ N Y Y ~8~ 1~ ~m BP~ Annular lnJe~on Da~ En~ S~en ~X P~ F~ P~ 95~.~ ~ NIA ......... N Y N ~7 6~3 ~ BP~ 19~ & 1~ ~ed summaH~ ~X ~ P~',"]G~ ~TD 9~-1.~ {~4~ ~A .......... N Y ' '1~11~ 59~7~ From BP~ An,ular I~j~on Data En~ S~een BPX ;PBU G-21 PTD 9~1~ 1 t112~5 N/A ........ N Y Y ' 12114~8 _~ 114~ From BP~.~ular inje~on D~ E~ Semen; from G~21~ G~A ve~ approval ~m B~ 6118~8; LOT plots In ~11 fi~, Sund~ Approval for 2nd Inj~on peri~. UNO TBU G-~ SUN 7~16 7118E_~__~0 ................ ~_~.~.__Y _~010~..7310 Fm:G-15~R~G-26RD ........ BPX ._~p~H~5 S~H~__~Ij[_.IjI~5 ..................... ........ N Y Y ~6~7 ~ ~~ratorf~H~5&H-~ .. . BPX ~U H~.__ SUN ~155 11~5 ........... ~ .... Y Y ~7 1452 [~~~~.~H~S&H~6 .. UNO TBU K-19 SUN UNO Tau K~RO SUN ~02~ ~m~ ........... UNO __~BU. K-12RD SUN 7~7 UNO TSU K-~9 SUN 74:0~ ..... ~]_ .... UNO mU K-~S SUN UNO TaU K-~mO SUN _.~3 ......... ~ ............ ,'~'~- .... ............ MAR KU KDU 33~ SU~ 9~2~ .................................................. not ~um if an~l~p~jt MAR KU ~U 42-7 SUN ~5 not sum E ann~ar ~ ....... EXP~, LoneC~kei, ,, ,, , , SUN ~'-',, ,, 10112~8, .... 911~,,, ,,, ,,..... ,, , ,, , , Y,, ,, ~y, ,iY~ , , 1~1~ , 12057 o~ln~n~0n~,ln~,tller~n~volu, , , , ~ere~ffedondal,, , ~d~illn~re~. ,, , , ......... P~e4 Annular log kAl~Ai"' I'F_~PL Meltwater N~"13h #2 'tSUNExPL Me{twater Norlh #2A SUN 200-031199'130 ' ' i' i 1' 1i [I i I 1468[Fmm BPXAAnnutartnjectlon Data Ent~ ~creen: Outerannulu$1eftopea" -- MPU MPB-24 ~PTD 96-009 3/3,/96 N/A 1 IN N BPX ,PU MPC-~ PTD 96-016 6,{2/96 N/A '-- , .... 'N ..... y Y 2060, From C-23, C-26 (al~31905 bbl8 into C-25, 5228 bbls into C-26) BPX MPU MPC-25 PTD 96-001 '1/26/96 .N/A ~ Y N 2t28/97 1905 from EtPXA 1995 & 1996 con~cted summaries BPX MPU MPC-25A P'rD 96-021 5/4/96 -tN/AtN Y[ 19051From C-25. C-23 NIA N Y ___5~__~ t Y 11/2t~961 425 From C-28, BPX MPU MPC-28 PTD 95.,029 5/15/98 NIA N Y BPX MPU MPE-17 SUN 96-115 2/7/97 Y --- N - I 0 Neveruffiized, nosunck~ffied BPX MPU MPE-20 PTD 95-071 9/3/95 N/A / N ,Y 'N 2/28/97. 486~_ ~ BPXA 1995 & 1996 corrected BPX MPU MPE-22 PTD 9,5.081 8/4/95 N/A iN 'N , O Neve~'utittzed BPX MPU MPE-23 PTD 95-094 ~ ~I/A-~ IN N i__ 0 Never uffiized ..... BPX MPU MPF-01 PTD 9,5-045 10/25/96 N/A N N 0 Never utilized BPX MPU MPF-13 PTD 95-027 i10~1/95 N/A N Y 12/14/98 3234 From BPXA Annular Injectien Date Entry Screen BPX MPU MPF-14 PTD 95-212 3/26/96 N/^ N Y Y __8/29/96 18717 From BPXA Annula~ lnjec~on Data Entry Screen 'BPX MPU MPF-21 SUN 96-135 6/17/97 N N 0 Never utilized, ne sund~ flied __ __ __ ~.BPX MPU MPF-22 PTD 95-201 3/31/96 N/A N Y N 2rZ8/97 6536 BPX MPU MPF-25 PTD 9F~.018 11/6/95 NIA N Y N 2/28/971 9897 Yom BPXA 1995 & 199~ corrected summafles __ BPX MPU MPF-30 PTD 95-184 2/5/96 N/A N N 0 Neveruttlized BPX 'MPU MPF-37 PI"D 9.5-025 11/10/95 N/A N Y ~-- 2/28/97 7032 from BPXA 1955 & 1996 corrected summaries BPX MPU MPF-38 PTD 95-168 3/22/98 NI~- N 7' N 2/28~7 9232 lOO~ ~ into F-48 from F-38; volume from BPXA 1995 &la96 con-ected ~ummarles __ BPX ~IPU MPF-45 _ PTD 95-058 t119/96 NIA __ N Y__ 12/14/98 17562 From BPXA An~ular Injection Data Entry Screen. :~PX MPU ~IPF-,49t SUN 97-003 4115/97 - ~,1 N N 0 Never utilized, no surtd~J ~ BPX -- MPU MPF.53 -- PTD 95-108 2/16/96 .NIA __ N__~ ~2114/98 _ 6051 From BPXA Annular Injection Data Entry Screen BPX MPU MPF-61 PTD 95-117 ,5/28/96 N/A N Y 12/14/98 5732 From BPXA Annular Injection Data Entry Screen BP---X MPU MPF-62 PTD 95.161 1111 t/95 NIA ~. ' ' '-- N Y____ Y__ 9~3/98 .... 386 From BPXA Annular injection Data Entry Screen BP.___X MPU MPF.88 SUN 96-142 9/20/96 __ Y .... ~N .... 0 Never utilized, no Sund.~ filed BPX ~P___U MPF-~9 PTD 95-125 5/2~N96 __ N/A . __ N___ .... Y 12/~4/98 9740 From BPXA Annular Injectk~n Data Entry Screen BPX MPU MPF-70. PTD 95-153 3/4/96 NIA N Y Y 2./28/97 19775 from BPXA 1995 & 1996 corrected summaries BPX MPU MPF-?8__. PTD 95.144 7110/96 NIA =N .Y Y 2/26/97 8476 fr~m BPXA 1995 & 1996 corrected summaries BPX MPU MPH-65 PTD 96-098 8/24/95 NIA N Y ....... 12/14/9B 8283~FtOm BPXA Annular Injection D. ate Entr~ Scree~ BP~ MPU MPH.06 --- pTD i95-115 4/23/96 NIA N Y :N 2/28/97 8515 from BPXA 1995 & 1996 corrected summerles ............. ~X MPU MPH-07 SUN 95-142_ 1/30/97 N N ....... 0' Never ufllized ne s.__~d_r~ fled BPX MPU MPt~0~---~ PTD 95-15'1 't0/8/96 N/A_ .............. N Y Y 6/30/97 1680 From BPXA Annular I~lactt~. Da~__E.E_nI~/s¢~_en; from MPI.0?, MPI.-05i, ................. BPX MPU MPJ-I$ PTD .94-'126 2/19195 N/A N Y Y 2/25./9~7~ '1.4127 FromBPXAAnllularln~..io._n.~DateEnflTS~aen; from MPJ-13, MPJ-19, MPJ-16 §PX MPU MPJ-16 ~D 95-189 114/98 NIA N - ~' ___-N--- 2/28/97 __ 985 frorn.BPXA 1995 & 1996 corrected summaries BPX -- MPU MPJ-19 PTD 95-'159 10/27~97 . N._/A ........ .N. -- ~- 0 Never utilized BPX MP._U_'MPK-02 SUN 96.081 8/7/96 N N __ 0 _Never utll_l_ze__d~ fl..~/__~_ ..BP__X_ ..... _MPLI .. MPK-05 . SUN 96-068 8IlI~ ............................... _Y_ ....... N__ ................................ O _Never utilized, no sund_.s¥_n~l._ry_.flled ~PX MPU MPK;06 ...... SUN. 96-191 1114~7 N N 0 Never utilized, no sundry filed BPX' MPU MPK-09 ........... PTD. ~ I]6.(]67. __ ~IA ' .__~ was this well dlllled? BPX MPU MPK*10 PTD 95-048 N/A .Don'l~ know if .dr!!led ~.needed amendment to AIO #1 ~-~x ~Pu MpK-'1_7'_-'_.-_'T---__--__~?TD'~."_-~:0~L ~2/1.~'-- N/A ............ i;_--'~ ...... i_hZ. ....... ~_Z_~__Y_'"_-Z _ ~s/9._z7. . ~s. BPX MPU MPK-18 SUN ~7-004 2/17/97 N N N 0 Never utlllzed.~nosu.....~.~0.~' flied BPX -ffiPU MPK.21t SUN 98-176 10/21/97. Y N D Neverutilize~_._no_.sun_.q_d.~flled BPX MPU MPK-25 ......... SUN 96-032 3/24/96 N N ........... _._0._N. eve__._r._ut_ll_ized no st~rtdry-~d~`.~--~-~/-d-rat--e-~--e--m~-~a~1en-~s~u--s~-e-n--d~-e-d-`w~-~----- ............. BPX MP_.U__ M .PK..,.3~._ .... SUN 98-188 11/25/96 Y N ....... 0 Never utllized.,n~d~ob BPX .... .MPU.. MPK--33 SUN__ 96-202 211!/97 ...... N N ........... 0 Never utlllzed~ filed BPX MPU MPK-34 SUN 96-169 11/25/97 N N 0 :Never utilized, no sundry filed aP~' ' MPU MPK-3_7.~_., ..... SUN'.. :~... !~/2~,r~ .--______~--__~ ........... :.N__ ...... _N_ .................... _0'_Neveruti~zed~s__~_~_~ed ;BPX MPU MPK-38 SUN =96-030 8/2/9~_ ...................... N _. _N_ ............. _4../1._.1./9_7_ ..... 0_ N~e. ver u.____~J~_~su..~.~..~.~apE_roval B'-~X ~IPU MPK-54 SUN 95-192 =4/6/97 ....... Y N 0~ Ney~r. utili.zed, no sund_~flled _ BPX ~Pu" ' MPL-16 PTD 95-080 11/24/95 NIA . __ N ~1' ............... 0 Never utJlize~ BPX ---'MPu MPL.21-- PTD 95;191 5/16/96 NIA N 'N 0 Never utilized BPX MP.U__ MPL-2'~ - PTD 95-07.__~0__ 6_./4./95 N/A ................... ....... ~..i_~ ..... N .Y_ ........ 1__~__1.____~ ..... -~79---~ From BPXA Annular Injection Data Entry Screen BPX MPU MPL-25 PTD 95-180 5/25/96 N/A N N 0 Never utilized ............... __ AAI EXPL 'Nanuk ffi;~ SUN 200-030 ............. PPC NCIU NCtU B-1 PTD 97.115 10t17/97 Y Y Y 11110/98 134325 contingent on data submiltal_ some In file aP---~ .. MP__U i NMP #1 ....... ~UN - ~i6-0~5' ' ~/30/96 N N 0 .N.__e..v_er ~l__..~_~d _rio eund_~ ~ BPX MPU NMP#2 SUN 98-038 3/18/96_.~N/A .................... L____N_ .................. ~'^~---~U P~,~7..-7-'7;--,~'~-~---~p,~.00,s .......................... P~e5 Annular log BPX I_F-XPL ~n~D~ ~e-2~ ~ I { __t I I 0 N~u~z~ BPX IPBU S-29A/AL1 'PTD 96-11112 2/23/96 [NIA ' Bp~,BPX PBU S-41L1 _____~.DPTD 96-02596'0244/2/964r2/~ NVA LI .... -L-----~.--'-~[ IN ---JY-- 5/29/96 a/a5/29/961 8062 a/aFmm S.41 & S-42, also 7701 bbls into S-24 BPX PBU S-42 PTD 96-054 ,5/1:3~6 BPXPBUExPL ,~Jrd PTD 97-052 &r22/97I~.~_N/AI Y I I IN I Y 12/14/98] 5943 From BPXA Annular Injection Data Entry Screen ~,PC ~Lo~eCreek~#2- SUN 200-108 -_ , PAl CRU 0D1'17 SUN 200'145' N/A ~ I 'I[-- AAI KRU W. Goldhltl PTD 97-016 5/4/97 N N PPC KRU 2N-326 SUN 200-155 .... approval w~3e mClUeSted after ~ i~ drilled FORC WMR WMRU5 PTD 98-047 6~16/98 N/A Y N __! __ 0 conttnge~t~data~bml~taI, LOT data ln well file, ne~eruaedpe~RebStinson, 1/4~99 FORC RU Redoubt Unit #1 SUN _ __200-165 __. 'Y~ 4/18~1 5759 aurface broach while init, annular dl~lX:eal stot3ped. Injected 12/13-18/2000. FOREST RU Redoubt Unit #2 SUN _ FOREST RU Redoubt Unit #3 SUN 201-064 .... -- ......... Total 28~0257 ....... Page6 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 31, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED oi/ ,~ cos co ~ lJ O l Anchoro~' Com~issio~ Re: Kuparuk Area Annular Disposal, Second Quarter, 2001 - REVISED Dear Ms. Mahan: Please find attached the revised report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. We have revised the amount for CD2-42 because the original manifest incorrectly reported the CD2-24 annulus used for the disposal. Please call me at 263-4603 should you have any questions. Sincerely, : Paul Mazzolini Drilling Team Leader PM/skad CCi Marry Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake 't.,o J '~ol - Annular Dis :al durin the second ,uarter r2001. h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May01 Jun01 1c-133, 1c-121, IC-123, 1c-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N'302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 ] Jun01 Jun 01 1C-127 Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2001: Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume VOlume Volume Status of Annulus 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CDI-06, CDI-40, CDI- 2000 35, CD1-32, CD 1-24, CDI-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 2o0 -ol :/ PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 17, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Second Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files RECEIVED JUL 1 Alaska Oil & Gas Cons. Commission Anchorage Annular Disvosal durin the second ruarter ~2001: h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 1c-133, 1c-121, 1c-123, 1c-I'27 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 16902 100 0 17002 0 17002 . May 01 Jun 01 CD2-24 _~.~ 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli ~r which Dis vosal Authorization Expired during the second quarter 2001: Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 I00 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD1-32, CD1-24, CD1-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down~ CD1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CDI- 33, CD1-NQ1 [Fwd: 1 C-27 Annular Disposal Permit - RUSH] Subject: [Fwd: 1C-27 Annular Disposal Permit - RUSH] Date: Tue, 26 Jun 2001 11:30:32 -0800 From: Jane Williamson <Jane_Williamson~admin.state.ak.us> Organization: Alaska Oil & Gas Conservation Commission To: Jody J Colombie <jody_colombie~admin.state.ak.us> For the record Subject: 1C-27 Annular Disposal Permit- RUSH Date: Tue, 26 Jun 2001 10:41:28 -0800 From: "Mark A Chambers" <mchambe2~ppco.com> To: j ane_williamson~admin.state.ak.us Jane: Thank you for expediting the approval process for the above referenced well. As we discussed, the currently permitted 1C-17 well is approaching the upper limit of 35,000 bbls and without the 1C-27 well our only recourse would be to haul fluids and cuttings to another disposal site. I apologize for the short notice and any inconvenience it may have caused. Again thank you for your help. Sincerely, Mark Chambers Drilling Engineer 1 of 1 6/26/01 12:46 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X Annular Disposal 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1708' FNL, 3925' FEL, Sec. 12, T11 N, R10E, UM At top of productive interval 1973' FNL, 564' FEL, Sec. 7, T11 N, R11, UM At effective depth At total depth 2952' FNL, 3160' FEL, Sec. 8, T11 N, R11 E, UM 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service__ (asp's 562361, 5968530) (asp's 573335, 5967385) 6. Datum elevation (DF or KB feet) RKB 95 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 C-27 9. Permit number / approval number 199-043 10. APl number 50-029-22943 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 115' SURFACE 6821' PRODUCTION 10692' LINER Size 16" 9-5/8" 7" 4-1/2" 13910 6412 13863 6411 feet Plugs (measured) feet feet Junk (measured) feet Cemented 9 cu yds High Early 822 sx AS IIILW, 663 sx Class G 173 sx Class G slotted liner Measured Depth 115' 6916' 10787' 13863' 6404' True vertical Depth 115' 4546' 6411' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 10568'- 11689', 12165'- 13863' 6382'-6444', 6433'-6411' 4-1/2", 12.6#, L-80 Tbg @ 10520' MD. Baker 'FAB' pkr @ 10529' & Baker SLZXP LT pkr 10534' MD. CAMCO DB @ 492' MD. JUN 2, 2, Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal __X 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved Detailed operations program BOP sketch B 15. Status of well classification as: Oil __X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mark Chambers 265-1319 Signedja ~~ Title: Drilling Engineering Supervisor Date Prepared b~/ Sharon AI/su~-Drake 263-46 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ]' Approval Plug integrity __ BOP Test_ Location clearance_ Mechanical Integrity Test _ Subsequent torm required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 · OJ~I~IklAL ~!GHE,.r? ~¥' J, ~. Hsus~r' ORIGINAL Commissioner Date SUBMIT IN TRIPLICATE Annulus Disposal Transmittal Form Designation of the well or wells to receive drilling wastes: 1 C-27 The depth to the base of freshwater aquifers and permafrost, if present: No Aquifers / Base Permafrost = +/-1,795 TVD RKB A stratigraphic description of the interval exposed to the From the 9-5/8" shoe to the Cement top all that is open open annulus and other information sufficient to support is shale or minor non-hydrocarbon bearing sands. a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste: See attached map. 1C-25 is the only well which passes through a 1/4 mile radius, horizontal circle, centered at the 1C-27 surface casing shoe. Well 1C-25 was permitted for Annular Disposal on 4/27/99 and utilized for disposal from 5/99 thru 7/99. Total volume injected during that period was 34,936 bbls. The approved Annular Disposal Permit, and back-up documentation, for 1C-25 is attached for review. There are no potable water wells within one mile of 1C-27. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry: An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined: Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and ~ermafrost, if present, and cemented with sufficient :ement to provide zone isolation: Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: Any additional data required by the Commission to confirm containment of drilling wastes: Types of waste can be drilling mud, drilling cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. Maximum anticipated pressure at casing shoe during disposal operations is 1,855 psi. See attached: calculation page. See attached: cementing reports, LOT / FIT reports and casing reports. See attached: casing summary sheet and calculation pages. ARCO Alaska, Inc. NIP (492-493. OD:5.030) Gas Lift landrel/Dummy Valve 1 (1934-1935, 0D:5.984) Gas Lift MandrelNalve 2 (3351-3352, OD:5.984) Gas Lift MandrelNalve 3 (5915-5916, 0D:5.984) Gas Lift Mandrel/Valve 4 (7781-7782, 0D:5.984) GKA lC-27 1 C-27 APl:, 500292294300 .... ! ....... . _Well_Typ_e :_ :_P _R_O__ .D ......... ! .... ._A_ n g i e~T~S: j_8_5 _d_~eg_(~_ ~1._1_0_4~4 SSSV TYpe: ..................... ' O~r!g_Co~mp_l.e_t_ig~nX ~6_/3_0_!_9~ ..................... _A__n. gl_e_@_T_ ~.'_j_90~_d_e_g_@ .!_3 _9_1~ Annular Fluid:; Last W/O: Rev Reason:, GLM BY VG Reference Log: Ref Lgg Date:. Last ~date: 1/14100 !13863 TD: .' 13910 ffKB Date: j 9/3/99 ........... ; _._M__ax_ H.o!e_ _An g I~._' '~4_d_eg ~. !._24_ !_3~` _: ............ , - CASING Size Top_ Bottom ' TVD ' Wt ' Grade ~ Thread 16.000 0 ; 115 ; 115 i 62.58 ' H-40 ~ WELDED ; 9.625 0 , 6916 i 4547 40.00 7.000 ..... ~ ........ i .... {-0787 ..............., ~74~3 ....... ~l~.~b--- i [.:~ .... ~ .......... ~C2~b ............. 4.500 10568 ~ 11689 ~ 6444 ~';~j~0-_ ~-_~;~L~ b--' - 4.500 11689 ~ 12165 ~ 6433 ~ ~2.60i L-a0 ~ BTC-MOD 4.500 .... ~_2J~_ ..... ~ 13863 [ ....... [~_~ 12.6~__.L '-~L%8'~__.~.~..~_--'~--~;M~-b - TUBING Size I Top BoSom WD ~ Wt ~ G~de ~ Thread Perforations Summa~ 10568- 6382- 6444 / UNIT '-~- ~ 112~99~6/30/99/~*~'~%~~ ...... 12165- 6433-6411 .... ~ ........... 1698 99 ~ IP~ 13863 GaS:Lift Mandrels~alves Vlv Comment Gas Lift Mandrel/Valve 5 (9075-9076, OD:5.984) Gas Lift MandrelNalve 6 (10019-10020, OD:5.984) TUBING (0-10520, OD:4.500, ID:3.958) ,:JEWELRY : ;: Descri ID NIP CAMCO DB 3.813 NIP CAMCO X 3.813 SEAL Baker 80-47 4.000 PACKER BAKER 7" x 4.5" FEB p__a_c_k_e_r.?it~h_X_-~@l_e_~&@.lug_i_n_t.ai_l_pjp.~ ....... 4.000 PACKER BAKER 7" x 4.5" SLZXP LT Packer & 12' tie back sleeve 4.000 NIP HES X 3.813 p-.' :; r: ...;- .;,, OD:7.000, Wt:26.00) Per[ (10568-11689) Pelf (12165-13863) C~oted b~ finCh D~3te plotled: 7-Jun-2001 P~ot Referanc~ ~ PM~ <0-13910'>. Coord~nate~ ore ~n feet reference sk)t ~27. I True Vert~cot Deplhe~ce RKB (Poo~ 2000 1800 1600 1400 1200 1000 8OO I 600 400 200 " 0 (D 200 400 I 600 V 800 1000 1200 1400 1600 1800 2000 Phillips Alaska, Inc. Structure : Pod lC Well : 27 Field : Kuporuk River Unlf Location : North Slope, Alaska East (feet) -> 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 i i [ ~ ~ i i i i i i i i i i i i i [ ~ i i i i & s i i i i i 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 East (feet) -> 2OOO 1800 1600 1400 1200 1000 8OO A 600 I z o 400 200 0 '' o 2OO 400 ,-+. 600 I V 8OO 1000 1200 1400 1600 1800 2000 Phillips Alaska, Inc. Pad lC 27 slot #27 Kuparuk River Unit North Slope, Alaska HORIZONTAL PLANE CLEARANCE by Baker Hughes INTEQ REPORT Your ref : PMSS <0-13910'> Our ref : svy5975 License : Date printed : il-Apr-2001 Date created : 24-May-1999 Last revised : 1-Jan-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 28.354,w149 29 39.662 Slot Grid coordinates are N 5968529.338, E 562359.365 Slot local coordinates are 1710.00 S 1352.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 2000 feet Phillips Alaska, Inc. CLEARANCE LISTING Page 2 Pad 1C,27 Your ref : PMSS <0-13910'> Kuparuk River Unit,North Slope, Alaska Last revised : 1-Jan-1999 Reference wellpath Object wellpath : PMSS <0-10140'>,,25,Pad lC Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 6916.8 4547.0 31.2N 4697.7E 6555.9 4547.0 185.0N 4196.3E 287.1 524.5 339.7 Phillips Alaska, Inc. CLEARANCE LISTING Page 3 Pad 1C,27 Your ref : PMSS <0-13910'> Kuparuk River Unit,North Slope, Alaska Last revised : 1-Jan-1999 Reference wellpath Object wellpath : PMSS <0-9390'>,,15,Pad lC Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.Do Rect Coordinates Bearing Dist Dist 6916.8 4547.0 31.2N 4697.7E 6349.3 4547.0 1423.3N 3744.1E 325.6 1687.5 1655.8 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot %27 and TVD from RKB (Pool 6) (95.00 Ft above mean sea level). Vertical section is from N 0.00 E 0.00 on azimuth 109.34 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ( To; WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.- Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs November 04, 1999 1C-27, AK-MM-90124 1 LDWG formatted Disc with verification listing. API#: 50-029-22943-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTAC1TED COPY OF Tm~ TRANSM1TT~ LETTER TO TIlE ATTENTION OF: Sperry-Sun Drilling Service Atto: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED vQ,~V 0 4 1999 Date: ;'~tllltOll & Gas Cons. Comm{ss{o ~orage Signe 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 A Halliburton Company r'~RI L. LIN B C;ERL/I ~-- E c; WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November 04, 1999 RE: MWD Formation Evaluation Logs 1C-27, AK-MM-90124 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1C-27: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22943-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22943-00 2"x 5" MD Neutron & Density Logs: 50-029-22943-00 2" x 5" TVD Neutron & Density Logs: 50-029-22943-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia D 1999 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 20, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ORIGINAL Subject: 1C-27 (Permit No. 99-43) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on 1C-27. If there are any questions, please call 265-6830. Sincerely, R. Thomas Drilling Team Leader AAI Drilling RT/skad RECEIVED OCT 22 gg9 Oil& Cas Cons. Commissi Anchorage on STATE OF ALASKA '~, ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [] Gas F'"l Suspended D Abandoned r-~ Service D 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 99-43 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ;.....-r~.-...~.-~-~..,~ 50-029-22943 i ~";"'""'";" ,3~. ~' ; ~,' '"'. 9. Unit or Lease Name 4. Location of well at surface~'....,.-\~' -"c ~',- i ~~ 1710'FNL, 1352'FWL, Seo. 12, T11N, R10E, U~_.~.~¢-¢¢?i ,~ KuparukRiverUni, At Top Producing Interval ~ ';,'~'~- i; ~,.~.,. , 10. Well Number 1973' FNL, 564' FEL, Sec. 7, T11N, R11E, UM .~~ I --~i '~- lC-27 At Total Depth '~'~'-~"~'~"~?~'-"~'"- '"~ "~ .... "'"~-, 11. Field and Pool 2324' FSL, 2120' FWL, Sec. 8, T11N, R11E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparul~ River Pool RKB 95' feetI ADL 28242 ALK 2292 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions May 22, 1999 June 15, 1999 June 29, 1999I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 13910' MD / 6412' TVD 13863' MD / 6411' TVD YES [] No DI N/A feetMD 1933' 22. Type Electric or Other Logs Run GR/Res 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP BO'FFOM HOLE SIZE dEMENTING RECORDI AMOUNT PULLED 16" 62.5# R-3 Surface 102' 24" 9 cu yds High Early 9.625" 40# e L-80 Surface 6916' 12.25" 822 sx AS III LW, 663 sx Class G 7" 26# L-80 Surface 10787' 8.5" 17.3 sx Class G 4.5" 12.6# L-80 10529' 13907' 6.125" slotted liner 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) 4.5" 10512' 10529' & 10534' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. slotted liner DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) September 15, 1999 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 10/3/1999 4.0 Test Period > 1770 3033 86 176I 1714 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press. -- psi N/A 24-Hour Rate > 295 506 14 23.8° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A ORIGINAL Alasb Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ~9. [, 30. ~{ GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 11044' 6415' Base Kuparuk C 13910' 6412' Top Kuparuk A 13910' 6412' Base Kuparuk A 13910' 6412' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. ~'~'~"ned ~,.~~'- ~?. ~-~. Title Drilling Engineerinq Supervisor Date [~ ('~-.~ f.,~_~ ' Randy Thomas INSTRUCTIONS Prepared by Sharon AIIsup-Drake 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 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 08/20/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:lC-27 WELL_ID: AK0024 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:05/22/99 START COMP: RIG: POOL 6 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22943-00 05/22/99 (D1) TD/TVD: 295/295 SUPV:R.W. SPRINGER MW: 9.1 VISC: 211 PV/YP: 32/36 ( 295) DRILLING SURFACE APIWL: 7.4 PJSM. Accept rig ~ 0330 hrs. 5/22/99. NU diverter and test. Pre-spud meeting. Spud from 102-295' UPCOMING OPERATIONS:DRILL TO CASING POINT 05/23/99 (D2) MW: 10.2 VISC: 116 PV/YP: 28/32 APIWL: 6.8 TD/TVD: 2280/2021 (1985) DRILLING SURFACE 12-1/4" @ 3076' SUPV:R.W. SPRINGER Drilled from 295' to 1396'. Getting weak signal on MWD. P0H to check MWD. Drill from 1396' to 2280' UPCOMING OPERATIONS:DRILL TO CASING POINT 05/24/99 (D3) MW: 10.3 VISC: 106 PV/YP: 40/42 APIWL: 4.8 TD/TVD: 4808/3404 (2528) DRILLING 12-1/4" SURFACE @ 5387' SUPV:R.W. SPRINGER Drilled from 2280' to 4808' UPCOMING OPERATIONS:TRIP F/BIT & DRILL TO CSG POINT 05/25/99 (D4) MW: 10.2 VISC: 84 PV/YP: 28/32 APIWL: 5.2 TD/TVD: 5516/3793 (708) DRILLING SURFACE @ 5972' SUPV:R.W. SPRINGER/SCOTT REYNOLDS Drilled from 4808' to 5412'. RIH. Tight from 1950-2334', work thru tight spots. Ream from 5323' to 5412'. Drill from 5412' to 5516'. UPCOMING OPERATIONS:WIPER TRIP, POH TO RUN CASING. 05/26/99 (D5) MW: 10.3 VISC: 98 PV/YP: 35/46 TD/TVD: 6925/4551 (1409) CIRCULATING PRIOR TO POOH TO RUN CSG. SUPV:R.W. SPRINGER/SCOTT REYNOLDS Drill from 5516' to 6925'. UPCOMING OPERATIONS:POOH. RUN 9-5/8" CASING. APIWL: 5.0 05/27/99 (D6) MW: 10.3 VISC: 78 PV/YP: 27/32 APIWL: 5.2 TD/TVD: 6925/4551 ( 0) CIRCULATING & CONDITIONING MUD, PREPARING TO CEMENT CA SUPV:R.W. SPRINGER/SCOTT REYNOLDS POH f/wiper trip, tight hole ~ base of permafrost, pump and back ream from 1867'-1774' RIH, no tight spots, no fill. Run 9-5/8" casing. UPCOMING OPERATIONS:CEMENT SURFACE CASING, ND/DIVERTER. Date: 08/20/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 05/28/99 (D7) MW: 10.3 VISC: 57 PV/YP: 24/26 APIWL: 5.5 TD/TVD: 6925/4551 ( 0) TESTING BOPE SUPV:R.W. SPRINGER/SCOTT REYNOLDS Run 9-5/8" casing to 6916'. Pump cement. ND diverter. NU BOP's. UPCOMING OPERATIONS:DRILL OUT, SHOE TEST 05/29/99 (D8) MW: 8.4 VISC: 40 PV/YP: 9/10 APIWL: 14.5 TD/TVD: 6945/4562 ( 20) DRILLING AHEAD ~ 7566' SUPV:R.W. SPRINGER/SCOTT REYNOLDS Test Hydrill 250/3000 psi. Drill cement stringers float equipment and 20' new hole from 6925' to 6945'. Perform LOT, 14.0 ppg EMW. UPCOMING OPERATIONS:WIPER TRIP ~ 8940' 05/30/99 (D9) MW: 9.1 VISC: 45 PV/YP: 15/19 APIWL: 6.0 TD/TVD: 9049/5023 (2104) DRILLING AHEAD ~ 9330' SUPV:R.W. SPRINGER/SCOTT REYNOLDS Drill from 9645' to 9049' ,UPCOMING OPERATIONS:WIPER TRIP T/SHOE & OH LOT @ MID HRZ. 05/31/99 (D10) MW: 11.1 VISC: 48 PV/YP: 20/31 APIWL: 3.8 TD/TVD:10551/6379 (1502) CIRCULATING ~ 10797' CASING T.D. SUPV:R.W. SPRINGER/SCOTT REYNOLDS Drilled from 9049'-10100' Perform Leak off test to 12.5 ppg EMW. Drilled from 10100'-10551' UPCOMING OPERATIONS:WIPER TRIP, POH L/D DRILLPIPE, RUN 7" CASING 06/01/99 (Dll) MW: 11.1 VISC: 50 PV/YP: 22/27 APIWL: 4.0 TD/TVD:10551/6379 ( 0) POH, LAYING DOWN BHA. SUPV:R.W. SPRINGER/SCOTT REYNOLDS Drill from 10551' to 10797' UPCOMING OPERATIONS:RIG UP CASING EQUIP. AND RUN 7" CASING & CEMENT. 06/02/99 (D12) MW: 11.1 VISC: 53 PV/YP: 25/24 TD/TVD:10797/6405 (246) RIG DOWN CASING EQUIPMENT SUPV:FRED HERBERT / RICK OVERSTREET PJSM. Run 7" casing. UPCOMING OPERATIONS:TEST BOPE, P/U 4" DP APIWL: 4.2 06/03/99 (D13) MW: 11.1 VISC: 53 PV/YP: 25/26 APIWL: 4.2 TD/TVD:10797/6405 ( 0) PU BHA. SUPV:FRED HERBERT / RICK OVERSTREET PJSM. Pump cement. UPCOMING OPERATIONS:TRIP IN, CHANGE OVER MUD. DRILL TO TD. 06/04/99 (D14) MW: 10.5 VISC: 57 PV/YP: 19/32 APIWL: 3.7 TD/TVD:10797/6405 ( 0) DRILLING CEMENT. SUPV:FRED HERBERT / RICK OVERSTREET Install variable rams and test. Take out variable rams and Date: 08/20/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 install 4" rams. Test to 5000 psi, held OK. UPCOMING OPERATIONS:DRILL OUT SHOE, DISPLACE DRILLING FLUID, DRILL HORIZONAL SECTION. 06/05/99 (D15) MW: 10.5 VISC: 55 PV/YP: 18/31 APIWL: 4.2 TD/TVD:10817/6410 ( 20) TRIP BACK IN HOLE. SLIP & CUT DRILL LINE. SUPV:FRED HERBERT / RICK OVERSTREET Drill out float collar, cement, & float shoe from 10684' to 10797' Drill 20' of new hole from 10797' to 10817'. PJSM. Displace hole with new 10.5 ppg Baradril-N. UPCOMING OPERATIONS:DRILL HORIZONAL SECTION. 06/06/99 (D16) MW: 10.5 VISC: 49 PV/YP: 17/30 APIWL: 3.4 TD/TVD:10965/6403 (148) DRILLING AHEAD, DEPTH 11025' SUPV:FRED HERBERT / RICK OVERSTREET Drill from 10817' to 10965' UPCOMING OPERATIONS:CONTINUE DRILLING, SHORT TRIP 06/07/99 (D17) MW: 10.5 VISC: 50 PV/YP: 17/31 APIWL: 3.2 TD/TVD:l1410/6436 ( 445) MAKING SHORT TRIP F/l1501' T/SHOE ~ 10787' SUPV:FRED HERBERT / RICK OVERSTREET Drill from 10965'-11204'. CBU. Back on bottom @ 1104', returns showed trace amount of gas & oil. Drill from 11204'-11410' UPCOMING OPERATIONS:CONTINUE DRILLING AHEAD. 06/08/99 (D18) MW: 10.6 VISC: 51 PV/YP: 19/35 APIWL: 3.0 TD/TVD:l1717/6444 ( 307) DRILLING AHEAD ~ 11888' SUPV:FRED HERBERT / SCOTT REYNOLDS Drill f/l1410' to 11717'. Observed pit volume losses that coincide with crossing fault. Spot barafiber LCM pill. CBU. Circulate gas to surface. Gas cut mud until bottoms up then cleared up. Pump barafiber and baracarb. UPCOMING OPERATIONS:SHORT TRIP. 06/09/99 (D19) MW: 10.8 VISC: 48 PV/YP: 22/28 APIWL: 3.8 TD/TVD:l1912/6439 ( 195) DOWNLOADING MWD SUPV:FRED HERBERT / SCOTT REYNOLDS Drill from 11717' to 11912'. Start losing returns @ 11870' Spot LCM pill. Weight mud up to 10.8 ppg. UPCOMING OPERATIONS:TEST BOPE. PICK-UP PWD TOOL AND PBL SUB FOR NEW BHA ASSEMBLY. RIH TO TD. 06/10/99 (D20) MW: 10.6 VISC: 48 PV/YP: 20/29 APIWL: 4.0 TD/TVD:l1912/6439 ( 0) CBU AND EVALUATE LOSSES. LOSSES RANGING FROM 0-6 BPH. SUPV:FRED HERBERT / SCOTT REYNOLDS Test BOPE to 250/5000 pis. PJSM. RIH w/PBL circ sub. Drop ball and open PBL sub. Pump and spot baracarb and barafiber. UPCOMING OPERATIONS:RIH & DRILL AHEAD. Date: 08/20/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 06/11/99 (D21) MW: 10.6 VISC: 56 PV/YP: 21/34 APIWL: 3.4 TD/TVD:12044/6433 (132) DRILLING AHEAD @ 12245' SUPV:FRED HERBERT / SCOTT REYNOLDS Spot LCM pill. Squeeze LCM pill. CBU ~ shoe, losses minimal. Drill from 11912' to 11956'. Spot LCM pill. Squeeze LCM pill. CBU. Drill from 11956' to 12044' UPCOMING OPERATIONS:DRILL AHEAD. 06/12/99 (D22) MW: 10.6 VISC: 50 PV/YP: 20/28 APIWL: 4.0 TD/TVD:12662/6408 ( 618) 24 BPH LOSSES SUPV:FRED HERBERT / SCOTT REYNOLDS Drill from 12044 to 12374'. Spot LCM pill. Circulate at shoe and monitor losses. Drill from 12374' to 12662' UPCOMING OPERATIONS:SHORT TRIP. 06/13/99 (D23) MW: 10.6 VISC: 49 PV/YP: 18/27 APIWL: 3.0 TD/TVD:13230/6402 ( 568) LOSSES ~ 10 BPH. DRILLING AHEAD @ 13292' SUPV:FRED HERBERT / SCOTT REYNOLDS Drill from 12662' to 13141'. Circulate lo-vis sweep around. CBU at shoe. No gas. Drill from 13141' to 13230' UPCOMING OPERATIONS:SHORT TRIP-- POOH TO RUN LINER & COMPLETION. 06/14/99 (D24) MW: 10.6 VISC: 49 PV/YP: 18/28 APIWL: 2.5 TD/TVD:13561/6409 ( 331) 12 BPH LOSSES. DRILLING AHEAD AT 13,740' SUPV:FRED HERBERT / SCOTT REYNOLDS Drill from 13141' to 13561' UPCOMING OPERATIONS:DRILL TO TD. SHORT TRIP, MAD PASS. 06/15/99 (D25) MW: 10.6 VISC: 47 PV/YP: 16/25 APIWL: 3.0 TD/TVD:13910/6411 (349) 9 BPH LOSSES. MAKING M.A.D. PASS FROM TD - 13910' TO SUPV:RICK OVERSTREET / DENNIS CUNNI Drill from 13561' to 13910' TD. Circulate lo-vis sweep around. Shut down. Monitor well. Wiper trip, pump out to shoe ~ 10787' CBU ~ shoe. No gas. UPCOMING OPERATIONS:POH AND RUN 4-1/2" SLOTTED LINER. 06/16/99 (D26) MW: 10.8 VISC: 48 PV/YP: 20/20 APIWL: 2.8 TD/TVD:13910/6411 ( 0) POH W4" & BHA. SUPV:RICK OVERSTREET / DENNIS CUNNI MAD pass from 13910' to 11000' Pumping out to avoid swabbing. Pipe displacement not correct. Shut down. Circulate bottoms up. weight upt to 10.8 ppg. UPCOMING OPERATIONS:FINISH POH AND RUN 4-1/2" LINER. 06/17/99 (D27) MW: 10.8 VISC: 46 PV/YP: 19/23 APIWL: 3.0 TD/TVD:13910/6411 ( 0) STRIPPING IN HOLE. SUPV:RICK OVERSTREET / DENNIS CUNNI Weight up to 10.8 ppg. POH. Shut down, monitor well. Gained 5.4 bbls verified that well is slightly flowing. SHut well in. Attempt to strip in hole. Bleed press. Open BOPE, RIH. Strip in hole to 3013' Date: 08/20/99 RECEIVED ARCO ALASKA INC. WELL SUlVSW-ARY REPORT OCT ~ 2 999 Nas~ Oil & Gas Cons. Commissio~ Anchorage Page: 5 06/18/99 (D28) MW: 10.8 VISC: 49 PV/YP: 19/29 APIWL: 2.8 TD/TVD:13910/6411 ( 0) POH (PUMPING OUT). SUPV:RICK OVERSTREET / DENNIS CUNNI Strip in hole to shoe @ 10787'. Circulate thru choke ~ shoe. No signs of gas. Bring MW up to 10.8. Strip in hole from 10787' to 13910' Shut in press, built up to 220 psi. Leak in high press, unit in mud line. Replaced gasket. No signs of gas. Shut down. Monitor well. UPCOMING OPERATIONS:LD BHA. RUN 4-1/2" SLOTTED LINER. 06/19/99 (D29) MW: 10.8 VISC: 51 PV/YP: 20/18 APIWL: 3.2 TD/TVD:13910/6411 ( 0) RIH W/ 4-1/2" SLOTTED LINER. SUPV:RICK OVERSTREET / DENNIS CUNNI Circulate BU. Shut down, monitor well. 42 bbl loss while pumping, flowed back 28 bbls. Flow steadily decreased. POH. Monitor well. R/U tools for running liner and inner string. Monitor well in trip tank, 9.7 bbl gain, small flow steadily decreased. UPCOMING OPERATIONS:LINER TO TD. SPOT MUDZYME. SET LINER HANGER AND PACKER. POH W/ DRILL STRING, 2-7/8" INNER STRING & SETTING TOOLS. 06/20/99 (D30) MW: 10.8 VISC: 47 PV/YP: 18/26 APIWL: 3.0 TD/TVD:13910/6411 ( 0) POH W/DP, 2-7/8" INNER STRING & LINER-PACKER SETTING T SUPV:RICK OVERSTREET / DENNIS CUNNI PJSM. Run 4.5" slotted & blank liner to TD - 13910' Pump Mudzyme. Attempt to set packer, would not hold. Liner set w/bottom ~ 13907' UPCOMING OPERATIONS:RIH W/SEAL ASSY. AND TEST PACKER. 06/21/99 (D31) MW: 10.8 VISC: 45 PV/YP: 18/23 APIWL: 5.6 TD/TVD:13910/6411 ( 0) WELL SHUT IN. R/U COILED TUBING UNIT. SUPV:RICK OVERSTREET / DENNIS CI/N-NI POH to shoe ~ 10770'. Well static. Circulate BU ~ shoe. POH. Hole fill off, well breathing. Test BOPE to 250/5000 psi. RIH and installed TIW & dart valve screwed into top drive. Shut in well. Bullhead down annulus 10.8 ppg mud. UPCOMING OPERATIONS:KILL WELL WITH CTU FROM TD. 06/22/99 (D32) MW: 10.8 VISC: 44 PV/YP: 16/21 APIWL: 6.0 TD/TVD:13910/6411 ( 0) PRE JOB MEETING TO DISCUSS COIL WELL KILL OPERATIONS SUPV:RICK OVERSTREET / SCOTT REYNOL Monitor well. LD HWDP. UPCOMING OPERATIONS:DISPLACE GAS AND MUD IN ANNULUS AND CASING TO 10.8 PPG KWM. 06/23/99 (D33) MW: 10.8 VISC: 58 PV/YP: 19/33 APIWL: 7.2 TD/TVD:13910/6411 ( 0) KILLING WELL. CURRENT MW OUT=10.5 PPG HEAVY ON PRESSU SUPV:RICK OVERSTREET / SCOTT REYNOL PJSM on coil tubing well kill operations. RIH with coil. Date: 08/20/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 6 Circulate influx out on choke to flowline. Killed well. w/CTu to 11098', would not go to TD. No gas or oil. UPCOMING OPERATIONS:CONTINUE KILLING WELL BY DISPLACING WELL TO 10.8 PPG MUD. 06/24/99 (D34) MW: 10.8 VISC: 48 PV/YP: 15/31 APIWL: 9.8 TD/TVD:13910/6411 ( 0) CONTINUE WELL KILL OPERATIONS. DP=1380 PSI; CSG=90 PS SUPV:RICK OVERSTREET / SCOTT REYNOL Continue to circulate 10.8 ppg mud to kill well. Pump lost prime. Had to shut down to replace ruptured disc and clean out screen. Continue having problems problems with aired up mud. UPCOMING OPERATIONS:CONTINUE TO CIRCULATE UNTIL MW OUT=MW IN= 10.8 PPG. 06/25/99 (D35) MW: 10.9 VISC: 46 PV/YP: 13/31 APIWL: 9.8 TD/TVD:13910/6411 ( 0) MONITORING WELL SUPV:RICK OVERSTREET / SCOTT REYNOL Continue killing well. Monitor well. With 600 psi trapped coil pressure, well flowing. No flow ~ noon, well dead. CBU. Shut down and monitor well. Well static. UPCOMING OPERATIONS:RD DOWELL CTU. RU TO RIH W/4" DP TO WASH AROUND LINER TOP PACKER. 06/26/99 (D36) MW: 10.9 VISC: 45 PV/YP: 11/26 APIWL: 10.6 TD/TVD:13910/6411 ( 0) CIRCULATING HOLE CLEAN SUPV:RICK OVERSTREET / SCOTT REYNOL Monitor well @ 10534' ~ liner top, well static. Pump OOH to 8000' and monitor well, static. Pump OOH to 2400' & monitor well, static. PJSM. Pump gas & oil out of DP until good mud returns to surface. Monitor well, static. Pump coil out to surface, displace coil w/diesel. RIH slow w/4" DP. Displacement was acceptable. Tag packer ~ 10531'. Start circulating BU by staging up rates & monitoring losses. Large amount of gas to surface on BU. No oil shows. CBU, pump lo-vis/hi vis sweeps around while rotating. Still receiving large amount of barite, barocarb and barofiber. UPCOMING OPERATIONS:POOH TO RUN PACKER W/ X-NIPPLE & PLUG. Date: 08/20/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 7 06/27/99 (D37) MW: 11.1 VISC: 45 PV/YP: 14/29 APIWL: 10.6 TD/TVD:13910/6411 ( 0) POH W/OPEN ENDED DRILL PIPE FROM CLEAN OUT RUN. SUPV:RICK OVERSTREET / SCOTT REYNOL Circulate and clean out 7" casing from top of liner. Pumped lo/hi vis sweeps. Shut down pump, monitor well, static. Started pulling out of hole. Hole was not taking correct hole fill. Ran back in hole from 9400' to 10533' (TOL). CBU. Small amount of oil and very little gas. Weight up mud to 11.0 ppg. POH, pump out to 8150'. Monitor well. Ran back in hole to 10531' Circulate and condition mud weight to 11.0 ppg all around. POH pump out to 8438' UPCOMING OPERATIONS:RUN BAKER PACKER AND SET AT TOP OF LINER AND TEST. 06/28/99 (D38) MW: 11.1 VISC: 46 PV/YP: 13/27 APIWL: 10.8 TD/TVD:13910/6411 ( 0) POOH LAYING DOWN 4" DP. MWD & MUD MOTOR SUPV:FRED HERBERT / SCOTT REYNOLDS Pump OOH from 8438' to 5272' Well static. Continue pump OOH. RIH w/ FAB packer and 4.5" XX plug. Set packer. CBU, no gas, no oil. UPCOMING OPERATIONS:RUN 4-1/2" COMPLETION; SWAP OVER TO SEAWATER AND FREEZE PROTECT. 06/29/99 (D39) MW: 11.1 VISC: 48 PV/YP: 15/31 APIWL: 1.0 TD/TVD:13910/6411 ( 0) NIPPLE DOWN BOPE SUPV:FRED HERBERT Run 4.5" tubing. UPCOMING OPERATIONS:NIPPLE UP TREE, L/D 4" DP F/ DERRICK CLEAN PITS, RELEASE RIG, MOVE TO 1C-26. 06/30/99 (D40) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:13910/6411 ( 0) RIG RELEASED F/ 1C-27 @ 18:00 HRS SUPV:FRED HERBERT ND BOPE. NU tree and test to 5000 psi. Freeze protect well. UPCOMING OPERATIONS: CI !~ I I_1_ I I~J 13 28-Jul-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 qg. Re: Distribution of Survey Data for Well 10-27 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 13,910.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ,tlii. 2.9 1999 Alaska 01} & Gas Cons. CoBrni~sion 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Prudhoe Bay Unit Alaska state Plane Zone 4 Kuparuk 1C, Slot 1C-27 1C-27- 1C -27 Job No. AKMMg0124, Surveyed: 22 May, 1999 ORIGINAL SURVEY REPORT 28 July, 1999 Your Ref: API-500292294300 Surface Coordinates:. 5968529.34 N, 562359.37 E (70° 19' 28.3541" N, 149° 29' 39.6618" W) Kelly Bushing: 95. lOft above Mean Sea Level Slmel~r',Nf-sun o R I i I_ I N I; !i I;, I:l v, I I:: I~ ~ Survey Reft svy8666 Sperry-Sun Drilling Services Su.rvey Report for lC-27- lC -27 "Your Ref: AP!-$00292294300 Job No. AKMM90124, Surveyed: 22 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 0.00 0.000 0.000 -95.10 50.00 0.235 139.120 -45.10 100.00 0.471 139.120 4.90 150.00 0.706 139.120 54.90 200.00 0.941 139.120 104.89 250.00 1.076 119.815 154.88 300.00 1.384 95.317 204.87 350.00 2.198 71.348 254.85 400.00 3.317 61.319 304.79 450.00 4.629 56.684 354.67 500.00 5.752 55.457 404.46 550.00 6.788 55.135 454.16 600.00 7.753 55.442 503.76 650.00 8.437 57.741 553.26 700.00 9.205 60.347 602.67 750.00 10.110 63.449 651.96 800.00 11.015 68.040 701.11 850.00 11.986 72.903 750.11 900.00 12.907 78.561 798.93 950.00 13.963 83.276 847.57 1000.00 15,338 85.163 895.94 1050.00 17.049 86.123 943.99 1100.00 19.526 85.626 991.46 1150.00 21.416 85.977 1038.26 1200.00 22.783 86.927 1084.58 Vertical Depth (ft) 0.00 50.00 100.00 150.00 199.99 249.98 299.97 349.95 399.89 449.77 499.56 549.26 598.86 648.36 697.77 747.06 796.21 845.21 894.03 942.67 991.04 1039.09 1086.56 1133.36 1179.68 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5968529.34 N 562359.37 E 0.08 S 0.07 E 5968529.26 N 562359.44E 0.31 $ 0.27 E 5968529.03 N 562359.64 E 0.70 S 0.60 E 5968528.65 N 562359.98 E 1.24 $ 1.08 E 5968528.11N 562360.46 E 1.82 $ 1.74 E 5968527.54 N 562361.12 E 2.15 S 2.72 E 5968527.21N 562362.11E 1.90 $ 4.23 E 5968527.47 N 562363.61E 0.91S 6.38 E 5968528.48 N 562365.75 E 0.89 N 9.33E 5968530.31N 562368.69 E 3.45N 13.09 E 5968532.90 N 562372.44E 6.56 N 17.58 E 5968536.04 N 562376.90 E 10.20 N 22.79 E 5968539.72 N 562382.08 E 14.07 N 28.67 E 5968543.64N 562387.92 E 18.02 N 35.22 E 5968547.65 N 562394.44E 21.96 N 42.62 E 5968551.65 N 562401.80 E 25.76 N 50.96 E 5968555.52 N 562410.11E 29.07 N 60.35 E 5968558.91 N 562419.47E 31.72 N 70.79 E 5968561.65 N 562429.89 E 33.51N 82.24 E 5968563.53 N 562441.33E 34.77N 94.82 E 5968564.90 N 562453.90 E 35.76 N 108.63 E 5968566.00 N 562467.70 E 36.89 N 124.28 E 5968567.27 N 562483.34 E 38.24 N 141.83 E 5968568.76 N 562500.88 E 39.40 N 160.60 E 5968570.07 N 562519.64 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/lOOff) (ft) Comment o.oo o.471 0.08 o.471 0.30 o.471 0.68 o.471 1.21 0.727 1.93 1.2o5 2.94 2.18o 4.41 2.428 6.44 2.700 9.17 2.257 12.63 2.073 16.74 1.931 21.51 1.513 26.91 1.73o 32.98 2.087 39.89 2.471 47.75 2.742 56.71 3.055 66.79 3.041 77.97 2.910 90.33 3.465 103.94 4.963 119.36 3.789 136.65 2.825 155.18 Continued... 28 July, 1999- 10:42 -2- DrillQuest Sperry-Sun D-' g Services Survey Report for lC-27- lC -27 "Your Ref: AP1-$00292294300 Job No. AKMM90124, Surveyed: 22 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 125o.oo 23.750 88.o9o 113o.49 13oo.oo 24.467 89.379 1176.13 135o.oo 25,252 90.237 1221.49 1400 ,oo 26.058 90.944 1266.57 145o.oo 27.738 91.392 1311.16 150o.oo 29.484 91.727 1355.o6 155o.oo 31.487 91.178 1398.15 1600.00 33.300 90.753 1440.33 165o.oo 34.414 90.586 1481.85 17o0.oo 35.549 90.448 1522.82 1750.o0 36.725 90.356 1563.20 1800.00 38,148 90.506 1602.93 1850.oo 39,842 90.894 1641.79 19oo.oo 41.679 90.658 1679.68 195o,oo 43.611 90.064 1716.45 2000.00 45,762 88.990 1752.o2 2050,00 47.998 87.825 1786.19 21oo.0o 50.176 88.o13 1818.93 215o.o0 52.344 88.389 1850.22 2200,00 54.007 88,155 188o.19 2250.00 55.463 87.952 1908.99 2300.00 55.692 87.899 1937.26 2350.00 55,986 87.885 1965.35 2400.00 56.458 87.976 1993.15 2450,00 56.809 88.150 2020.62 Vertical Depth (ft) 1225.59 1271.23 1316.59 1361.67 1406.26 1450.16 1493.25 1535.43 1576.95 1617.92 1658.30 1698.03 1736.89 1774.78 1811.55 1847.12 1881.29 1914.03 1945.32 1975.29 2004.09 2032.36 2060.45 2088.25 2115.72 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (fi) (fi) 40.28 N 180.40 E 5968571,11 N 562539.42 E 40.72 N 200.81 E 5968571.73 N 562559,84 E 40.78 N 221.83 E 5968571.96 N 562580,85 E 40,55 N 243.47 E 5968571,91 N 562602.50 E 40.09 N 266,07 E 5968571,64 N 562625.10 E 39.42 N 290.00 E 5968571.17 N 562649,03 E 38.78 N 315,35 E 5968570.74 N 562674.39 E 38.35 N 342.19 E 5968570.53 N 562701.23 E 38.02 N 370,04 E 5968570,43 N 562729.08 E 37.77 N 398.70 E 5968570.42 N - 562757,74 E 37.56 N 428.19 E 5968570.46 N 562787.23 E 37.36 N 458.53 E 5968570.51 N 562817.58 E 36.98 N 489.99 E 5968570.39 N 562849.04 E 36.47 N 522.61 E 5968570.15 N 562881.66 E 36.26 N 556,48 E 5968570,22 N 562915.53 E 36,51 N 591,63 E 5968570.77 N 562950.67 E 37.53 N 628.10 E 5968572.09 N 562987,14 E 38.96 N 665.86 E 5968573.84 N 563024.89 E 40.19 N 704,84 E 5968575.38 N 563063,85 E 41.39 N 744.84 E 5968576.92 N 563103.85 E .. 42.79 N 785.69 E 5968578.66 N 563144.68 E 44.28 N 826.91 E 5968580.49 N 563185.88 E 45.81 N 868.24 E 5968582.37 N 563227.20 E 47.32 N 909.77 E 5968584.21 N 563268.72 E 48.75 N 951.52 E 5968585.99 N 563310.45 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100ft) (ft) Comment 2.142 174.75 1.779 194.99 1.727 215,86 1.724 237,40 3.386 259,90 3.506 283,75 4.045 309.02 3.654 335.74 2.235 363.45 2.275 391.96 2.355 421.28 2.852 451.46 3.423 482.77 3.687 515.24 -3.947 548.92 4.560 583.81 4.784 619.95 4.365 657.31 4.376 695.90 3.346 735.52 2.931 775.95 0.467 816.74 0.588 857.64 0.957 898.74 0.760 940.07 Continued,.. 28 July, 1999 - 10:42 - 3 - DrillQuest Sperry-Sun Drilling Services Su .rvey Report for lC-27 - lC -27 Your Ref: AP!-$00292294300 Job No. AKMM90124, Surveyed: 22 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2500.00 56.982 88.446 2047.93 2143.03 2550.00 56.918 88.629 2075.16 2170.26 2600.00 56.657 88.720 2102.55 2197.65 2650.00 56.465 88.388 2130.11 2225.21 2700,00 56,309 87.844 2157.79 2252,89 2750.00 56.191 88.146 2185.57 2280.67 2800.00 56.082 88.649 2213.43 ~ 2308.53 2850.00 56.500 88.810 2241.18 2336.28 2900.00 56.976 88.939 2268.62 2363.72 2950.00 57.732 88.934 2295.59 2390.69 3000.00 58.256 88.966 2322.02 2417.12 3050.00 57.828 89.150 2348.49 2443.59 3100.00 57.466 89.369 2375.26 2470.36 3150.00 57.253 89.663 2402.23 2497.33 3200.00 57.063 89.783 2429.35 2524.45 3250.00 56.899 89.704 2456.59 2551.69 3300.00 56.526 89.645 2484.00 2579.10 3350.00 56.002 89.603 2511.77 2606.87 3400.00 56.004 89.756 2539.79 2634.89 3450.00 56.221 89.989 2567.66 2662.76 3500.00 57.064 89.649 2595.19 2690.29 3550.00 58.004 89.230 2622.03 2717.13 3600.00 57.798 89.507 2648.57 2743.67 3650.00 57.526 89.777 2675.32 2770.42 3700.00 57.181 89.645 2702.29 2797.39 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (fi) (ft) (ft) 49.99 N 993.39 E 5968587.58 N 563352.31 E 51.04 N 1035.31 E 5968588.98 N 563394.22 E 52.01N 1077.13 E 5968590.30 N 563436.03 E 53.01N 1118.84 E 5968591.65 N 563477.73 E 54.38 N 1160.45 E 5968593.36 N 563519.33 E 55.89 N 1202.00 E 5968595.22 N 563560.86 E 57.05 N 1243.50 E 5968596.72 N 563602.35 E 57.97 N 1285.08 E '5968597.99 N 563643.92 E 58.79 N 1326.87E 5968599.15 N 563685.71E 59.57 N 1368.96 E 5968600.28 N 563727.79 E 60.36 N 1411.40 E 5968601.42 N 563770.22 E 61.05 N 1453.82 E 5968602.47 N 563812.63 E 61.61N 1496.04 E 5968603.38 N 563854.85 E 61.96 N 1538.14 E 5968604.08 N 563896.94 E 62.13 N 1580.15 E 5968604.60 N 563938.95 E 62.32 N 1622.07 E 5968605.14 N 563980.87 E 62.56 N 1663.89 E 5968605.73 N 564022.68 E 62.84 N 1705.47E 5968606.35 N 564064.26 E 63.09 N 1746.88 E 5968606.94 N 564105.67 E 63.18 N 1788.39 E 5968607.38 N 564147.17 E 63.28 N 1830.13 E 5968607.83 N 564188.91E 63.70 N 1872.31 E 5968608.59 N 564231.09 E 64.18 N 1914.68 E 5968609.43N 564273.45 E 64.43 N 1956.93 E 5968610.03 N 564315.69 E 64.64 N 1999.03 E 5968610.59 N 564357.79 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100fi) (ft) Comment 0.604 981.53 0.333 1023.07 0.543 1064.52 0.674 1105.85 0.958 1147.06 0.556 1188.17 0.863 1229.28 0.878 1270.50 0.975 1311.93 1.513 1353.67 1.048 1395.75 0.910 1437.82 0.814 1479.72 0.653 1521.52 0.430 1563.24 0.354 1604.88 0.752 1646.41 1.052 1687.69 0.255 1728.82 0.581 1770.05 1.779 1811.52 2.009 1853.39 0.625 1895.44 0.710 1937.39 0.726 1979.20 Continued... 28July, 1999-10:42 -4- DrillQuest Sperry-Sun Services Su.rvey Report for 1C-27 - 1¢ -27 'Your Reh AP1-500292294300 Job No. AKMM90124, Surveyed: 22 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. 3750.00 56.872 89.579 3800.00 56.695 89.761 3850.00 56.525 89.836 3900.00 56.364 89.708 3950.00 56.433 89.526 4000.00 56.756 89.288 4050.00 57.241 89.338 4100.00 57.839 89.587 4150.00 57.928 90.113 4200.00 57.848 90.733 4250.00 57.618 90.908 4300.00 57.370 91.030 4350.00 57.173 91.003 4400.00 56.960 91.024 4450.00 56.646 91.375 4500.00 56.380 91.548 4550.00 56.236 91.249 4600.00 56.031 91.222 4650.00 55.738 91.600 4700.00 55.826 91.840 4750.00 56.257 91.953 4800.00 56.610 91.953 4850.00 56.924 91.898 4900.00 56.787 91.890 4950.00 56.573 91.890 Sub-Sea Depth (ft) 2729.51 2756.90 2784.42 2812.06 2839.77 2867.30 2894.56 2921.39 2947.93 2974.51 3001.19 3028.06 3055.10 3082.27 3109.65 3137.25 3164.99 3192.84 3220.88 3249.06 3276.99 3304.63 3332.03 3359.34 3386.81 Vertical Depth (ft) 2824.61 2852.00 2879.52 2907.16 2934.87 2962.40 2989.66 3016.49 3043.03 3069.61 3096.29 3123.16 3150.20 3177.37 3204.75 3232.35 3260.09 3287.94 3315.98 3344.16 3372.09 3399.73 3427.13 3454.44 3481.91 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 64.94 N 2040.97 E 5968611.24 N 564399.73 E 65.18 N 2082.80 E 5968611.83 N 564441.55 E 65.31N 2124.54 E 5968612.30 N 564483.30 E 65.47 N 2166.21 E 5968612.81 N 564524.96 E 65.74 N 2207.82 E 5968613.42 N 564566.57 E 66.17 N 2249.56 E 5968614.20 N 564608.30 E 66.72 N 2291.48 E 5968615.10 N 564650.21E 67.11 N 2333.66 E 5968615.84 N 564692.39 E 67.25 N 2376.04 E 5968616.33 N 564734.77E 66.94 N 2418.39 E 5968616.37 N 564777.12 E 66.31N ' 2460.67 E 5968616.10 N 564819.40 E 65.60 N 2502.83 E 5968615.74 N 584861.57 E 64.85 N 2544.88 E 5968615.34 N 584903.63E 64.13 N 2586.84 E 5968614.96 N 584945.59 E 63.25 N 2628.67 E 5968614.43N 564987.43E 62.14 N 2670.35 E 5968613.67 N 565029.11E 61.13 N 2711.94 E 5968613.00 N 565070.71E 60.29 N 2753.46 E 5968612.51N 565112.23 E 59.27 N 2794.84E 5968611.83 N 565153.62 E 58.01N 2836.12 E 5968610.91N 565194.91E 56.63 N 2877.57 E 5968609.89 N 565236.37 E 55.20 N 2919.22 E 5968608.80 N 565278.03 E 53.80 N 2961.01 E 5968607.74N 565319.84E 52.41 N 3002.87 E 5968606.71N 565361.70 E 51.04 N 3044.63 E 5968605.68 N 565403.47E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.627 2020.84 0.466 2062.38 0.364 2103.85 0.386 2145.24 0.332 2186.56 0.759 2227.99 0.972 2269.58 1.268 2311.45 0.908 2353.55 1.063 2395.67 0.547 2437.75 0.537 2479.72 0.398 2521.60 0.426 2563.38 0.859 2605.04 0.606 2646.58 0.575 2688.02 0.411 2729.37 0.857 2770.61 0.434 2811.77 0.881 2853.11 0.706 2894.66 0.636 2936.35 0.275 2978.10 0.428 3019.75 Continued... 28 July, 1999 - 10:42 - $ - DrillQuest Sperry-Sun Services Su~rv.ey Report for-i c.27.10.27 Your Ref: AP1-$00292294300 Job No. AKMM90124, Surveyed: 22 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. 5000.0~ 56.373 91.607 5050.00 56.214 91.293 5100.00 56.561 91.051 5150.00 56.893 90.798 5200.00 57.149 90.490 5250.00 57.215 90.435 5300.00 56.601 91.287 5350.00 56.256 91.421 5400.00 56.207 90.746 5450.00 56.426 90.693 5500.00 56.797 90.993 5550.00 57.608 90.898 5600.00 58.545 90.693 5650.00 58.467 90.595 5700.00 58.190 90.530 5750.00 57.962 90.768 5800.00 57.727 90.999 5850.00 57.400 91.121 5900.00 57.124 91.106 5950.00 57.047 90.542 6000.00 56.892 90.083 6050.00 56.605 89.796 6100.00 56.369 89.789 6150.00 56.185 90.073 6200.00 56.084 90.267 Sub-Sea Depth (ft) 3414.42 3442.18 3469.86 3497.29 3524.51 3551.55 3578.85 3606.55 3634.34 3662.11 3689.62 3716.74 3743.18 3769.24 3795.49 3821.93 3848.54 3875.36 3902.41 3929.58 3956.82 3984.23 4011.85 4039.61 4067.48 VertiCal Depth (ft) 3509.52 3537.28 3564.96 3592.39 3619.61 3646.65 3673.95 3701.65 3729.44 3757.21 3784.72 3811.84 3838.28 3864.34 3890.59 3917.03 3943.64 3970.46 3997.51 4024.68 4051.92 4079.33 4106.95 4134.71 4162.58 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 49.75 N 3086.29 E 5968604.74 N 565445.14 E 48.70 N 3127.86 E 5968604.03 N 565486.72 E 47.85 N 3169.50 E 5968603.53 N 565528.36 E 47.17 N 3211.30 E 5968603.20 N 565570.16 E 46.70 N 3253.24 E 5968603.08 N 565612.11 E 46.44N 3295.29 E 5968603.16 N 565654.16 E 45.81 N 3337.18 E 5968602.88 N 565696.05 E 44.69 N 3378.79 E 5968602.10 N 565737.67 E 43.90 N 3420.34 E 5968601.66 N 565779.23 E 43.46 N 3461.92 E 5968601.57 N 565820.81 E 42.85 N 3503.67 E 5968601.30 N 565862.56 E 42.12 N 3545.67 E 5968600.92 N 565904.56 E 41.53 N 3588.10 E 5968600.69 N 565947.00 E 41.06 N 3630.77E 5968600.57 N 565989.67 E 40.64 N 3673.32 E 5968600.51N 566032.23 E 40.16 N 3715.75 E 5968600.38 N 566074.66 E 39.51N 3758.08 E 5968600.08 N 566116.99E 38.73 N 3800.27 E 5968599.65 N 566159.19 E 37.87 N 3842.31E 5968599.14 N 566201.24 E 37.27 N 3884.28 E 5968598.88 N 566243.21E 37.06 N 3926.21E 5968599.03 N 566285.14 E 37.11 N 3968.03 E 5968599.42 N 566326.95 E 37.31 N 4009.71E 5968599.97 N 566368.63 E 37.36 N 4051.29 E 5968600.36 N 566410.21E 37.22 N 4092.80 E 5968600.57 N 566451.72 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.618 3061.29 0.612 3102.72 0.804 3144.18 0.787 3185.80 0.728 3227.53 0.159 3269.35 1.882 3311.04 0.726 3352.51 1.127 3393.89 0.447 3435.26 0.896 3476.81 1.629 3518.63 1.906 3560.86 0.229 3603.31 0.565 3645.64 o.610 3687.87 0.611 3730.00 0.685 3772.01 0.553 3813.88 0.959 3855.66 0.830 3897.35 0.747 3938.89 0.472 3980.29 0.598 4021.61 0.380 4062.87 Continued... 28 July, 1999 - 10:42 - 6 - DriliQuest Sperry-Sun Drilling. Services Survey Report for lC-27- lC -27 Your Ref: API-500292294300 Job No. AKMM90124, Surveyed: 22 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) G250.00 56.941 90.398 4095.40 6300.00 57.064 90.394 .4123.05 6350.00 58.439 90.346 4149.73 6400.00 58.451 90.605 4175.83 6450.00 58.244 90.914 4202.06 6500.00 58.157 90.641 4228.41 6550.00 58.070 90.391 4254.82 6600.00 57.952 90.525 4281.31 6650.00 57.819 90.684 4307.89 6700.00 57.628 90.939 4334.59 6750.00 57.437 90.951 4361.43 6800.00 57.246 90.470 4388.41 6850.00 57.091 90.334 4415.53 6900.00 56.979 90.640 4442.73 6950.00 56.868 90.946 4470.02 7000.00 56.758 91.253 4497.39 7050.00 56.671 91.066 4524.83 7100.00 56.597 90.615 4552.33 7150.00 56.469 90.652 4579.90 7200.00 56.325 90.837 4607.57 7250.00 56.161 90,656 4635.35 7300.00 55.994 90.396 4663.26 7350.00 56.733 90.670 4690.96 7400.00 57.439 90.946 4718.11 7450.00 57.837 91.189 4744.88 VertiCal Depth (ft) 4190.50 4218.15 4244.83 4270.93 4297.16 4323.51 4349.92 4376.41 4402.99 4429.69 4456.53 4483.51 4510.63 4537.83 4565.12 4592.49 4619.93 4647.43 4675.00 4702.67 4730.45 4758.36 4786.06 4813.21 4839.98 Local Coordinates Global CoOrdinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 36.98 N 4134.29 E 5968600.68 N 566493.21 E 36.68 N 4175.94 E 5968600.72 N 566534.86 E 36.41 N 4218.22 E 5968600.80 N 566577.15 E 36.07 N 4260.87 E 5968600.82 N 566619.80 E 35.51N 4303.43 E 5968600.61N 566662.36 E 34.93 N 4345.92 E 5968600.38 N 566704.85 E 34.55 N 4388.38 E 5968600.36 N 566747.31E 34.22 N 4430.78 E 5968600.37 N 566789.71E 33.78 N 4473.13 E . 5968600.29 N 566832.07 E 33.18 N 4515.40 E 5968600.04 N 566874.34 E 32.42 N 4557.58 E 5968599.63 N 566916.52 E 31.90 N 4599.67 E 5968599.46 N 566958.62 E 31.68 N 4641.68 E 5968599.59 N 567000.63E 31.32 N 4683.63E 5968599.58 N 567042.58 E 30.74 N 4725.52 E 5968599.35 N 567084.47 E 29.94 N 4767.36 E 5968598.89 N 567126.31 E 29.03 N 4809.14 E 5968598.33 N 567168.11E 28.42 N 4850.90 E 5968598.07 N 567209.86 E 28.00 N 4892.61E 5968597.99 N 567251.58 E 27.45 N 4934.25 E 5968597.80 N 567293.22 E 26.89 N 4975.82 E 5968597.58 N 567334.79 E 26.51 N 5017.30 E 5968597.54 N 587376.28 E 26.13 N 5058.93 E 5968597.50 N 567417.90 E 25.53 N 5100.91E 5968597.26 N 567459.89 E 24.74 N 5143.13 E 5968596.82 N 567502.12 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.234 4104.12 2.047 4145.54 2.750 4187.59 0.441 4230.01 0.669 4272.36 0.495 4314.65 0.458 4356.88 0,326 4399.06 0.380 4441.19 0.576 4483.26 0.383 4525.26 0.896 4567.14 0,385 4608.91 0.559 4650.64 0.559 4692.33 0.559 4733.99 0,358 4775.62 0,769 4817.18 0.263 4858.67 0.422 4900.11 0.446 4941.48 0.547 4982.75 1,548 5024.15 1.486 5065.94 0.895 5107.99 Continued... 28 July, 1999 - 10:42 - 7- DrillQuest Sperry-Sun Drilling Services Su.rvey Report for lC-27 - lC -27 "Your Ref: API-500292294300 Job No. AKMM90124, Surveyed: 22 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 7500.00 58.069 91.20.~ 4771.36 7550.00 57.894 91.066 4797.87 7600.00 57.682 90,880 4824.52 7650.00 57.419 90,756 4851.34 7700.00 57.259 90,607 4878.35 7750.00 57.185 90.436 4905.41 7800.00 57.078 90.426 4932.55 7850.00 56.957 90.495 4959.77 7900.00 56.780 90.467 4987.09 7950.00 56.589 90.413 5014.55 8000.00 57.193 90.994 5041.88 8050.00 57.821 91.582 5068.73 8100.00 58.041 91.835 5095.28 8150.00 58.196 92,061 5121.67 8200.00 58.068 92.173 5148.06 8250.00 57.940 92,230 5174.56 8300.00 57.812 92.166 5201.14 8350.00 57.711 92,148 5227.82 8400.00 57.644 92.189 5254.56 8450.00 57.582 92,284 5281.34 8500.00 57.527 92.435 5308.16 8550.00 57.510 92.378 5335.02 8600.00 57.510 92.232 5361.88 8650.00 57.480 92.433 5388.74 8700.00 57.441 92.732 5415.64 Vertical Depth (ft) 4866.46 4892.97 4919.62 4946.44 4973.45 5000.51 5027.65 5054.87 5082.19 5109.65 5136.98 5163.83 5190.38 5216.77 5243.16 5269.66 5296.24 5322.92 5349.66 5376.44 5403.26 5430.12 5456.98 5483.84 5510.74 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 23.79 N 5185.53 E 5968596.22 N 567544.52 E 22.92 N 5227.91 E 5968595.70 N 567586.91 E 22.21 N 5270.22 E 5968595.34 N 567629.22 E 21.61 N 5312.41 E 5968595.09 N 567671,41 E 21.10 N 5354.49 E 5968594,94 N 567713,50 E 20.72 N 5396.52 E 5968594.90 N 567755.54 E 20,42 N 5438.52 E 5968594.95 N 567797.53 E 20.08 N 5480,46 E 5968594.97 N 567839.48 E 19.72 N 5522.33 E 5968594.95 N 567881.35 E 19.40 N 5564.12 E 5968594.98 N 567923,13 E 18.90 N 5605.98 E 5968594.83 N 567965.00 E 17.95 N 5648,15 E 5968594,22 N 568007.18 E 16.68 N 5690.50 E 5968593.31N 568049,54 E 15,23 N 5732.95 E 5968592,21 N 568091.99 E 13.66 N 5775.38 E 5968590.99 N 568134,44E 12.02 N 5817.75 E 5968589.70 N 568176.82 E 10.39 N 5860.07 E 5968588,43 N 568219,15 E 8.81 N 5902,33E 5968587.20 N 568261,42 E 7.21 N 5944,55 E 5968585.95 N 568303.65 E 5.58N 5986,74 E 5968584.67 N 568345.86 E 3.84N 6028.90 E 5968583.28 N 568388.03 E 2.05 N 6071.04 E 5968581.83 N 568430.18 E 0.35 N 6113.18 E 5968580.49 N 568472,33 E 1,34 S 6155.31E 5968579,15 N' 568514,48 E 3.24 S 6197.42 E 5968577.60 N 568556.60 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100ft) (ft) Comment o.498 515o.22 0.523 5192.44 0.527 5234.56 0.566 5276.55 0,407 5318,42 0.323 5360.23 0.213 5402.00 0.270 5443.71 0.355 5485.36 0.393 5526.92 1,552 5568,58 1,600 5610.59 0,615 5652,81 0,493 5695.15 o.319 5737,50 0.274 5779.79 0,277 5822.02 0.205 5864,19 0.151 5906.32 0.203 5948.43 0.278 5990.52 0.102 6032.59 0.245 6074.66 0.344 6116.71 0.511 6158.77 Continued... 28 July, 1999 - 10:42 - 8 - DrlllQuest Sperry-Sun Drilling Services Suwey Report for lC-27- lC -27 Your Ref: API-500292294300 Job No. AKMM90124, Surveyed: 22 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 8750.00 57.239 92.586 5442.62 5537.72 8800.00 57.029 92.404 5469.75 5564.85 8850.00 56.772 91.967 5497.06 5592.16 8900.00 56.503 91.393 5524.55 5619.65 8950.00 56.186 90.297 5552.26 5647.36 9000.00 55.930 89.569 5580.19 5675.29 9050.00 55.780 89.596 5608.25 . 5703.35 9100.00 55.599 89.466 5636.43 5731.53 9150.00 55.386 89.160 5664.76 5759.86 9200.00 55.670 89.043 5693.12 5788.22 9250.00 56.229 89.033 5721.12 5816.22 9300.00 56.310 89.053 5748.83 5843.93 9350.00 56.181 89.087 5776.61 5871.71 9400.00 56.161 89.114 5804.45 5899.55 9450.00 56.150 89.140 5832.30 5927.40 9500.00 56.017 88.764 5860.20 5955.30 9550.00 56.020 88.420 5888.19 5983.29 9600.00 56.980 88.339 5915.78 6010.88 9650.00 57.876 88.698 5942.68 6037.78 9700.00 58.600 90.287 5969.00 6064.10 9750.00 59.507 91.439 5994.75 6089.85 9800.00 60.660 91.969 6019.69 6114.79 9850.00 61.517 92.884 6043.80 6138.90 9900.00 62.083 94.188 6067.43 6162.53 9950.00 62.979 95.384 6090.54 6185.64 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5.20 S 6239.47 E 5968575.99 N 568598.67 E 7.03 S 6281.43 E 5968574.51N 568640.64 E 8.63 S 6323.28 E 5968573.26 N 568682.50 E 9.89 S 6365.02 E 5968572.34 N 568724.26 E 10.51 S 6406.64 E 5968572.07 N 568765.87 E 10.37 S 6448.11 E 5968572.55 N 568807.34 E 10.07 S 6489.49 E 5968573.20 N 568848.72 E 9.76 S 6530.79 E 5968573.85 N 568890.02 E 9.27 S 6571.99 E 5968574.69 N 568931.21E 8.59 S 6613.16 E 5968575.70 N 568972.37 E 7.90 S 6654.58 E 5968576.74 N 569013.79 E 7.20 S 6696.20 E 5968577.78 N 569055.39 E 6.53 S 6737.76 E 5968578.80 N 569096.95 E 5.87 $ 6779.29 E 5968579.80 N 569138.47 E 5.24 S 6820.81 E 5968580.78 N 569179.99 E 4.49 $ 6862,30 E 5968581.88 N 569221.47 E 3.46 S 6903.72 E 5968583.25 N 569262.88 E 2.28 S 6945.39 E 5968584.78 N 569304.54 E 1.07 S 6987.52 E 5968586.34N 569346.66 E 0.69 S 7030.03 E 5968587.07 N 569389.16 E 1.43S 7072.88 E 5968586.68 N 569432.02 E 2.72 S 7116.20 E 5968585.75 N 569475.35 E 4.50 S 7159.96 E 5968584.34 N 569519.12 E 7.22 S 7203.94 E 5968581.98 N 569563.12 E 10.93 S 7248.12 E 5968578.64 N 569607.33 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.473 6200.77 0.520 6242.67 0.894 6284.44 1.101 6326.07 1.931 6367.49 1.313 6408.68 0.304 6449.77 0.420 6490.77 0.661 6531.66 0.599 6572.50 1.119 6613.58 0.166 6654.85 0.265 6696.08 0.060 6737.27 0.048 6778.46 0.677 6819.60 0.572 6860.65 1.924 6901.93 1.890 6943.66 3.066 6985.86 2.682 7028.52 2.483 7071.71 2.346 7115.40 2.560 7159.41 2.778 7203.72 Continued... 28 July, 1999 - 10:42 - 9 - DrillQuest Sperry-Sun Drilling Services Su~. ey Report for lC-27- lC -27 'Your Ref: AP1-$00292294300 Job No. AKMM90124, Surveyed: 22 May, 1999 Prudhoe Bay Unit Measured Depth (ft) 10000.00 10050.00 10100.00 10150.00 10200.00 10250.00 10300.00 10350.00 10400.00 10450,00 10500.00 10550.00 10600,00 1065O.O0 10700.00 1 O75O.00 10800.0O 10850.00 10900.00 10950.00 11000.00 11050.0O 11100.00 11150.00 11200,00 64.094 65.338 66.641 68.093 69.544 70.912 72.311 73.862 75.413 76.941 78.656 80.646 82.201 83.415 84.924 86.725 88.772 90.210 87.622 85.595 84.709 84.918 85.002 85.156 86.962 Azim. 96.498 97.444 98.313 99.069 99.824 100.927 lO2.076 103.573 104.729 105.019 lO5.385 105.862 106.134 106.246 106.496 106.283 105.474 105.828 105.555 lO5.461 lO6.993 lO7.564 108.281 110.870 112.843 Sub-Sea Depth (ft) 6112.83 6134.19 6154.54 6173.78 6191.85 6208.76 6224.54 6239.09 6252.33 6264.28 6274.89 6283.88 6291.25 6297.51 6302.63 6306.31 6308.29 6308.35 6309.22 6312.13 6316.46 6321.08 6325.36 6329.82 6333.26 Vertical Depth (ft) 6207.93 6229.29 6249.64 6268.88 6286.95 6303.86 6319.64 6334.19 6347.43 6359.38 6369.99 6378,98 6386.35 6392.61 6397.73 64Ol.41 6403.39 6403.45 6404.32 6407,23 6411,56 6416.18 6420.46 6424.92 6428.36 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 15.57 S 7292.64 E 5968574.37 N 569651.89 E 21.07 S 7337.51 E 5968569.24 N 569696.80 E 27.34 S 7382.75 E 5968563.35 N 569742.09 E 34.31 S 7428.36 E 5968556.76 N 56.9787.76 E 41.96 S 7474.35 E 5968549.49 N 569833.81 E '50.44 S 7520.63 E 5968541.40 N 569880.16 E 59.87 S 7567.13 E 5968532.35 N 569926.73 E 70.49 S 7613.77 E 5968522.12 N 569973.46 E 82.38 S 7660.49 E 5968510.62 N 570020.28 E 94.84 $ 7707.42E 5968498.55 N 570067.31 E 107.63 S 7754.57 E 5968486.15 N 570114.57 E 120.88 $ 7801.94E 5968473.30 N 570162.04 E 134.55 $ 7849.46E 5968460.03 N 570209.68 E 148.38 $ 7897.10E 5968446.59 N 570257.43 E 162.38 S 7944.83 E 5968432.99 N 570305.27 E 176.57 $ 7992.63 E 5968419.19 N 570353.19 E 190.21 $ 8040.69 E 5968405.96 N 570401.36 E 204.03 $ 8088.74 E 5968392.54 N 570449.52 E 217.47 S 8136.88 E 5968379.49 N 570497.78 E 230.78 $ 8184.99 E 5968366.59 N 570545.99 E 244.70 S 8232.81 E 5968353.06 N 570593.93 E 259.43 S 8280.37 E 5968338.73 N 570641.61 E 274.60 $ 8327.82 E 5968323.95 N 570689.18 E 291.21 S 8374.76 E 5968307.73 N 570736.26 E 310.03 $ 8420.95 E 5968289.30 N 570782.61 E Alaska State Plane Zone 4 Kuparuk lC Dogleg Vertical Rate Section (°/100ft) (ft) Comment 2.992 7248.48 3.021 7293.68 3.052 7339.34 3.220 7385.45 3.226 7432.01 3.434 7478.94 3.548 7526.20 4.221 7573.74 3.821 7621.50 3.108 7669.52 3.504 7717.81 4.088 7766.37 3.156 7815.12 2.439 7864.01 3.058 7913.01 3.626 7962.09 4.402 8011.38 2.961 8060.67 5.205 8110.02 4.058 8159.32 3.531 8208.40 1.212 8257.31 1.438 8306.16 5.168 8354.67 5.343 8402.67 Continued... 28 July, 1999- 10:42 - 10- DrlllQuest Sperry-Sun Drilling Services Su ~rvey Report for lC-27- lC -27 'Your Ref: API-500292294300 Job No. AKMM90124, Surveyed: 22 May, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 11250.00 11300.00 11350.00 11400.00 11450.00 11500.00 11550.00 116OO.OO 11650.00 1170O.OO 11750.00 11800.00 11850.00 11900.00 11950.00 12000.00 12050.00 121O0.00 12150.00 12200.00 12250.00 12300.00 12350.00 12400.00 12450.00 88.157 87.937 87.357 88.132 88.228 88.684 88.726 88.300 88.394 88.576 90.443 91.582 92.196 91.700 92.093 93.668 91.540 89.854 91.532 92.780 92.650 92.337 92.724 94.018 94.218 Azim. 112.624 112.561 113.835 113.116 112.785 111.640 111.836 112.310 112.574 112.933 112.506 111.334 108.773 107.794 108.379 109.648 108.815 108.617 109.542 109.986 110.070 110.479 110.796 110.479 110.326 Sub-Sea Depth (ft) 6335.27 6336.94 6339.05 6341.11 6342.62 6344.12 6345.16 6346.47 6347.93 6349.37 6349.77 6348.88 6347.06 6345.42 .6343.96 6341.39 6338.96 6338.55 6338.25 6336.17 6333.77 6331.58 6329.50 6326.62 6322.85 Vertical Depth (ft) 6430.37 6432.04 6434.15 6436.21 6437.72 6439.22 · 6440.26 6441.57 6443.03 6444.47 6444.87 6443.98 6442.16 6440.52 6439.06 6436.49 6434.06 6433.65 6433.35 6431.27 6428.87 6426.68 6424.60 6421.72 6417.95 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 329.38 S 8467.01 E 5968270.33 N 570828.82 E 348.60 S 8513.14 E 5968251.50 N 570875.11 E 368.38 S 8559.01E 5968232.10 N 570921.15 E 388.20 S 8604.86 E 5968212.66 N 570967.16 E 407.66'S - 8650.90 E 5968193.58 N 571013.36 E 426.76 S 8697.08 E 5968174.87 N 571059.70 E 445.15 S 8743.56 E 5968156.87 N 571106.33 E '463.95 S 8789.88 E 5968138.45 N 571152.80 E 483.09 S 8836.04 E 5968119.70 N 571199.12 E 502.42 S 8882.14 E 5968100.75 N 571245.37 E 521.82 S 8928.21E 5968081.73 N 571291.61E 540.66 S 8974.52 E 5968063.28 N 571338.07 E 557.65 S 9021.50 E 5968046.68 N 571385.19 E 573.11 $ 9069.02 E 5968031.61N 571432.84 E 588.44S 9116.59 E 5968016.68 N 571480.54E 604.83 S 9163.76 E 5968000.68 N 571527.84 E 621.21 $ 9210.93 E 5967984.69 N 571575.14 E 637.18 $ 9258.31 E 5967969.12 N 571622.65 E 653.73 S 9305.49 E 5967952.96 N 571669.97E 670.58 S 9352.51E 5967936.50 N 571717.13 E 687.76 S 9399.41 E 5967919.71N 571764.17 E 705.02 $ 9446.28 E 5967902.84N 571811.19 E 722.68 S 9493.01 E 5967885.57 N 571858.06 E 740.30 S 9539.72 E 5967868.34N 571904.91 E 757.63 S 9586.46 E 5967851.39 N 571951.80 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100ft) (ft) Comment 2.428 8450.61 0.458 8498.60 2.798 8546.40 2.114 8594.19 0.688 8642.11 2.464 8690.14 0.401 8738.39 1.275 8786.52 0.560 8834.54 0.804 8882.51 3.830 8930.47 3.269 8978.59 5.264 9027.18 2.194 9076.14 1.409 9125.13 4.044 9173.83 4.570 9222.54 3.394 9271.41 3.830 9320.15 2.650 9368.76 0.309 9417.29 1.030 9465.80 1.001 9514.22 2.663 9562.60 0.504 9610.99 Continued... 28 July, 1999 - 10:42 - 11 - DrillQuest Sperry-Sun Drilling Services Su .rvey Report for lC-27- lC -27 'Your Ref: AP1-$00292294300 Job No. AKMM90124, Surveyed: 22 May, 1999 Prudhoe.Bay Unit Measured Depth (ft) 12500.00 12550.00 12600.00 12650.00 12700.00 12750.00 12800.00 12850.00 12900.00 12950.00 13000.00 13050.00 13100,00 13150,00 13200.00 13250.O0 133OO.O0 13350.00 13400.00 13450,00 13500.00 13550.00 13600,00 13650.00 13700.00 93.727 92.562 91.586 90.993 91.508 91.747 90.936 89.762 90.012 90,087 89,965 90,901 90.315 90.776 92.072 90.125 89.000 88.730 88,308 88.175 88.090 88.336 90.085 90.485 89.720 Azim. 110.586 111.089 110.369 110.712 110.694 110.009 109.518 108.983 107.811 107.604 107.408 106.144 106.162 106.893 107.114 106.886 107.617 107.783 106.898 106.337 107.164 109.020 110.798 112.710 111.082 Sub-Sea Depth (ft) 6319.40 6316.61 6314.72 6313.65 6312.74 6311.23 6309.99 6309.77 6309.97 6309.83 6309.88 6309.54 6309.01 6308.63 6307.12 6306.01 6306.38 6307.45 6308.68 6310.30 6311.81 6313.64 6314.25 6313.82 6313.72 Vertical Depth (ft) 6414.50 6411.71 6409,82 6408.75 64O7.84 6406.33 · 6405.09 6404.87 6405,07 6404.93 6404.98 6404.64' 6404.11 6403.73 6402,22 6401,11 6401.48 6402.55 6403.78 6405.40 6406.91 6408.74 6409,35 6408.92 6408,82 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 775.17 S 9633.16 E 5967834.25 N 571998.64 E 792.86 S 9679.84 E 5967816.94 N 572045.47 E 810.75 S 9726,49 E 5967799.44 N 572092.26 E 828.05 S 9773.39 E 5967782.53 N 572139.30 E 846.17 S 9819.98 E 5967764.81 N 572186.05 E 863.58 S 9866.83 E 5967747.78 N 572233.03 E 880.36 S 9913,91 E 5967731.39 N 572280.25 E 896.62 S 9961.19 E 5967715.53 N 572327.67 E 912.61 S 10008.56 E 5967699.93 N 572375.17 E 927.74 S 10056.22 E 5967685.20 N 572422.95 E 942.83 S 10103.89 E 5967670.51N 572470.74 E 957.40 S 10151,71E 5967656.33 N 572518.69 E 971,38 S 10199,72 E 5967642.76 N 572566,81 E 985.29 S 10247,74 E 5967629.24 N 572614.94 E 1000.06 S 10295.48 E 5967614,87 N 572662.81 E 1014.58 S 10343.31 E 5967600.74 N 572710.76 E 1029.45 S 10391,05 E 5967586.27 N 572758.61E 1044.77 S 10438.63 E 5967571.35 N 572806.32 E 1059.49 S 10486.40 E 5967557.02 N 572854.21E 1073.70 S 10534.31 E 5967543.22 N 572902.24 E 1088.08 S 10582,17 E 5967529.23 N 572950.22 E 1103,64 S 10629.65 E 5967514.07 N 572997.83 E 1120.61S 10676.67 E 5967497.49 N 573044.99 E 1139.29 S 10723.05 E 5967479.19 N 573091.52 E 1158,18 S 10769.34E 5967460.69 N 573137.96 E Alaska State Plane Zone 4 Kuparuk lC Dogleg Vertical Rate Section (°/100ft) (ft) Comment 1.111 9659.36 2.538 9707.73 2.425 9756.09 1.369 9804.63 1.031 9852.96 1.451 9901.46 1.896 9950,13 2.579 9998.93 2.397 10047.80 0.441 10096,85 0.461 10145.91 3,145 10195.07 1.174 10244.33 1.729 10293.61 2.630 10342,71 3,920 10391.86 2,684 10440.96 0,634 10489,96 1.961 10539.08 1.152 10588.28 1.661 10637,45 3.744 10686.38 4.988 10735.01 3.905 10783.18 3.597 10831.30 Continued... 28 July, 1999- 10:43 - 12- DrillQuest Sperry-Sun Drilling Services Survey Report for lC-27- lC -27 Your Ref: AP1-$00292294300 Job No. AKMM90124, Surveyed: 22 May, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (fi) (ft) (ft) (fl) 13750.00 88.927 110.408 6314.32 6409.42 1175.77 S 10816.14 E 5967443.49 N 573184.91 E 13800.00 88.529 111.244 6315.58 6410.68 1193.44 S 10862.90 E 5967426.21 N 573231.81 E 13850.00 89.587 113.202 ¢316.30 6411.40 1212.29 S 10909.20 E 5967407.75 N 573278.27 E 13900.00 89.630 113.360 6316.62 6411.72 1232.11S 10955.10 E 5967388.31 N 573324.33 E 13910.00 89.630 113.360 6316.69 6411.79 1236.07 S 10964.28 E 5967384.42 N 573333.54 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vedical depths are relative to Well. Northings and Eastings are relative to Well. Alaska State Plane Zone 4 Kuparuk 1C Dogleg Rate (°/lOOft) Vertical Section (ft) Comment 2.o80 1.850 4.450 0.328 0.00o 10879.77 10928.21 10976.34 11024.17 11033.74 PROJECTED SURVEY The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 96.432° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13910.00ft., The Bottom Hole Displacement is 11033.74ft., in the Direction of 96.432° (True). Continued... 28 July, 1999- 10:43 - 13- DrillQuest Sperry-Sun Drilling Services Sur~..ey Report for 1C-27- 1C -27 Your Ref: APi-$00292294300 Job No. AKMM90124, Surveyed: 22 May, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1C Comments Measured Depth (ft) 13910.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6411.79 1236.07 S 10964.28 E Comment PROJECTED SURVEY 28 July, 1999- 10:43 - 14. DriilQuest STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X Annular Injection 2. Name of Qperator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1710' FNU 1352' FWU Sec. 12, T11N, R10E, UM At top of productive interval 1905' FNL, 750' FEL, Sec. 7, T1 1 N, R11 E, UM At effective depth At total depth 2324' FSL, 2120' FWL, Sec. 8, T11 N, R11 E, UM 5. Type of Well: Development _X Exploratory __ Stratigraphic _ Service _ 6. Datum elevation (DF or KB feet) RKB 28.6' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 C-27 9. Permit number/approval number 99-43 10. APl number 50-029-22943 11. Field / Pool Kuparuk River Field / Kuparuk River Pool 12. Present well condition summar Total depth: measured 13910 true vertical 6412 Effective depth: measured true vertical Casing Length Size Conductor 73' 16" Surface 6887' 9.625" Production 10758' 7" Liner 3378' 4.5" Perforation depth: measured N/A true vertical N/A Fubing (size, grade, and measured depth Packers & SSSV (type & measured depth) feet Plugs (measured) feet feet Junk (measured) feet Cemented 9 cu yds. High Early 822 sx AS III LW, 663 sx Class G 173 sx Class G slotted liner Measured Depth 102' 6916' 10787' 13907' 4.5", 12.6#, L-80 @ 10512' Baker 'FAB' packer @ 10529', Baker SLZXP LT packer @ 10534' True vertical Depth 102' 4546' 6404' 6411' RECEIVED d'i,JL 14 1999 ~Jasl<a 0il & Gas Cons. Anchorage 13. Attachments Description summary of proposal __ 14. Estimated date for commencing operation July 15, 1999 16. If proposal was verbally approved Name of approver Date approved Detailed operations program 15. Status of well classification as: Oil __X Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Drilling Engineering Supervisor Randy ~" FOR COMMISSION USE ONLY BOP sketch __ Conditions of approval: Notify Commission so representative may witness Gas __ Suspended __ Questions? Call William Lloyd 265-653 Prepared b~/ Sharon Al/sup-Drake I AP P r° va' n ~1~"'""/,¢~ Plug integrity __ BOP Test_ Location clearance_ Mechanical Integrity Test_ Subsequent form required 10- .~ ¢.?OV-{- ~'~/¢!~vl~4~lr' ~,)c:~',~ ORIGINAL SIGNED. By the Commission RO~;~l"t N, (~hdSt___~_e~.~ Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Casing Detail 9.625" Surface Casing WELL: 1C-27 ARCO Alaska, Inc. DATE: 05/28/99 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LR = 34.60' TOPS Above RKB 9 5/8"' Landing Joint 33.35 FMC GEN V- Kuparuk 9 5/8"" Csg Hgr 1.34' up 1.62 33.35 jts156-180 9 5/8"", 40.0#, L-80 BTC-MOD (25 jts) 954.82 34.97 TAM 9 5/8" Port Collar 2.62 989.79 jts. 2+4-155 9 5/8", 40.0#, L-8C] BTC-MOD (153 jts~) 5840.45 992.41 Gemeco Float Collar 2.35 6832.86 jts 1 & 3 9 5/8", 40.0#, L-80 BTC-MOD (2 its) 78.25 6835.21 Gemeco Float Shoe 2.50 6913.46 Casing shoe @ 6915.96 ...... T.D. @6925' leaving ~9' of rathole 24 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1, 3 over stop collars and over casing collars on Jts. 2 & 4 thru 23 and over collar of jt. 179 Run 1 ROTCO Rigid Straight Blade Centralizer on joints 155 and 156 ... · , Remarks: String Weights with Blocks: 350k Up, 155k Dn, 68k Blocks. Ran 180 oints of casing: Drifted casing with 8.679" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Pool 6 Drilling Supervisor: R. W. SPRINGER ARCO Alaska, Inc. Cementing Details Well Name: 1C-27 Report Date: 05/28/99 Report Number. 1 Rig Name: Pool 6 AFC No.: AKO024 Field: KRU · . 9-5/8' 40# L-80 EUT-MOD 12-1/4" n/a 6916 MD Centralizers State type used, intervals covered and spacing Comments: Run centralizers In center of Jts. 1,3 over stop collars and over casing collars on Jts. 2 & 4 thru 23 and over collar of it. 179. 24 Gemeco Bow Spring CENTRALIZERS & 2 Straight Run I ROTCO Rigid Straight Blade Centralizer on Joints 155 and 156. Blade Centralizers. Mud Weight: PV(prior cond): Pr(after cond): YP(prior cond): YP(after cond): Comments: 10.3 42 24 56 26 Gels before: Gels after. Total Volume Circulated: 23/48 10/16 1215 bbls Wash 0 Type: Volume: Weight: Comments: ARCO B47 19 bbls 8.3 ppg Spacer 0 Type: Volume: Weight: Comments: . ARCO B45 60 10.7 ppg ~ . · Lead Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: . · .: AS III Lite 70 822I 10.7 ppg 4.43 .. i: Additives: : . 50% D124, 9.0% D44, 0.4% D46, 30% D53, 1.5% S1 & 1.5% D79 TallCement 0 =. Type: I Mixwtrtemp: No. ofSacks: I Weight: I Yield: COmments: G 70 663 15.8 ~. pg 1.17 = Additives: ' ' : .. i:.. 1% S1, 0.2% D46, & 0.3% D65. DisplaCement· :0 ' i': '=" Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: COmments: i ~ i 8 bpm 8 bpm 360k . ;' Reciprocation length: Reciprocation speed: Sir. Wt. Down: ! · : :. . = 10' 10ft/mln 175k · ' ;.. Theoretical Displacement: Actual Displacement: Str. Wt. in mud: . . = :: i 'i . . 5820stks 5924stks Calculated top of cement: CP: Bumped plug: Floats held: surface Date: 5/28/99 NO ¥ E S Time:13:30 Remarks:Reclproc,~ m casing until 1000 strks Into rig displacement then landed In hanger. Pulled up 1' to allow cmt flow ti~r~: Ilutes on hanger. Could not get casing to land back on hanger upon slack off. Overdisplaced by 3 bbls on top of plug and 3 bbls of shoe volume--did not see plug 'bump. Held 1200 psi on csg for two hours. Floats Held. . Cement Comp~:y: Rig Contractor: POOL IApproved By: Scott Reynolds / Ray Springer DS CASING TEST and FORMATION INTEGRITY TEST Well Name: 1 C-27 Date: 5/30/99 Supervisor: Scott Reynolds Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40# L-80 BTC Casing Setting Depth: 6,916' TMD 4,551' TVD '- Hole Depth: 10,097' TMD 6,250' TVD Mud Weight: 9.3 ppg Length of Open Hole Section: 3,181' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 1,050 psi + 9.3 ppg 0.052 x 6,250' EMW for open hole section = 12.5 ppg Pump output = 0.0846 bps Fluid Pumped = 6.4 bbl 1,400 psi I 1,300 p~ 1,2gO psi 900 ~si 700 psi 600 psi 5OO psi 4C]0 psi 3OO psi 200 psi 100 psi 0 psi STROKES LEAK-OFF DATA CASING TEST DATA MiNUTEs MINUTES FOR LOT STROKES PRESSURE F .............. i----~:;ii~;---i ..... i~-/:,-~'F .... ............... T---~-~ii~---'---~-¥b--~'~i-'-' ~ 4 ~tk~ 1715 ! i 8stk~ 190 ,si 16 stks 375 3si 25 stks 580 3si ............... i'--~-;ii~"i---~i-i~-'~'~]-"j 35 stks 810 3si ............................. .1_ ........ --.-.----! 40 stks 910 psi L. .............. J- .............. J- ................ 45 stks 1,000 psi 46 stks 1,005 psi .............. .j 47 stks 1,010 psi ! ..~ ................................. 48stks 1,030psi 49 stks 1,040 psi 1,050 psi FOR CSG TEST STROKES PRESSURE ................... -~-~ii~-'--" .... i~'i~'i- .... .............. · -~ .............. ~ ................ .............. · -~ .............. ~- ................ .a-- .j.. ..~ _1.. .r. .............. ..[. .............. .,t. ................ , 51stks 1,050 psi j ................................................. ............... ............... =-,=-~:-~,_---~. ~,--:-:~ .,i--~-~;ii~- .... ¥;6-b~'~;~'f'i ? ................................................ ............... 4- .............. -I ............. ~---, i SHUT SHUT IN PRESSURE ,.j_ 58 stks ,,.j_ 970 ps, [ r .......... IN TIME,. .................... r .......... T .... ; .............. i-'~-~[i~-'~--~[J~)--I~'~]'"! ~ 0.0 m~n , 0 ps ' .............. ',- .............. "- ............ ~--" '- . T T j 66 stks i 880 ps~ .___l.'_0___.m. Ln_.$ .............. $ ................ [ j -~ ~tks j 8~-I~ ~.~J 2.0 minj i ' SHUTIN TIME j SHUT IN PRESSURE 3.0 mln , I [ii_ i-ioiiZn_-iiiiiiiiiiiiiiiiiiiii. i _ iL !i] 1.0 minj 810 psi __3:_o___m!n__ .................... Z_6__o___p_sj .... , 4.0 min 740 psi ............... 70min j j 700 psi ~_____'_' ......... ,a_ .............. .a_ ................ · i i · ~ 8 0 mm J j 700 .... :.'_' ........................ .,- ................ 90min J ~ 700 psi '----:~ .........,-l- .............. ,'J- ................ ; 10.0 min 700 psi i_ ..............,d ...............J ................. 4.0 min -L'" i .__.%.9_..m_Ln__.', .............. ..L,' ................ . i i 6.0 m~n j j 7.0 min , ~ ............... · .i- .............. 'I' ................ 8.0 minj ' ' , ........... ,----1- .............. 1- ................ , 9.0 m~n ~ ~ ............ :--1- .............. I- ................ 10.0 m~n ~ ~ '~'?~,:'~-~ZT, .............. T ................ '~-~_'b-.'b"r~ZT .............. T ................ '~-~-.-6"rEB-? .............. i-,,, ................ ............... ~ .............. ? ................ 30.0 min ,, ,, NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1 C-27 Date: 5/30/99 Supervisor: Springer/Reynolds Reason(s) for test: [] Initial Casing Shoe Test [] FOrmation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud weight Casing Size and Description: 9-5/8" 40# L-80 BTC Casing Setting Depth: 6,916' TMD 4,551' TVD Hole Depth: 6,945' TMD 4,562' TVD Mud Weight: 8.4 ppg Length of Open Hole Section: 29' EMW -- Leak-off Press. + Mud Weight = 1,330 psi + 8.4 ppg 0.052 x TVD 0.052 x 4,562' EMW for open hole section = 14.0 ppg Pump output = 0.0846 bps Fluid Pumped = 2.6 bbl 1,qO0 psi I I I I I ~ ..... l. . i...1...1...~...1...1.., l~...l...l...l...l...!...l ....... I, ,/--~.-~-,-,~.,-,~._-,~.-_!_-'.L_'I"' -- : LEAK-OFF TEST I I I I~'i -- ~cASING TEST ---- ...... ~---.-- LOT SHUT IN T ME / ON~ Mi'NOTE~idKS : I -- --z-- CASING TEST SHUT IN TIME ~j I ---- , TIME LINE 3.200 psi 3.100 psi 3,00O psi 2.9OO psi 2,800 psi 2.700 psi 2.6OO psi 2,500 psi 2,400 psi 2.3O0 psi 2,20O psi 2.]00 psi 2,000 psi !.800 psi 1.700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,]00 psi 1.000 psi 700 psi 100 psi o psi STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ................................ : ........... , .... , ................ [----~-:~-~---: .... -6-~;[ .... :j,,' ! 0'stks 0 ps~ j ............................................... .............. ..j. ............... ~. ................ i 5 stks 200 psi j 5 stks 250 psi ! .............. T,' -'¥6"~i~"T-'~-~'i:~-r'- ~ : .................. -~-~-t'~-~--:,, ---~-6'~'i:~-F'i .............. T'i-~--~iii~--'r"-i~-~§'ii~T"i i ................. 'i§-~-t'f,-i ...... i~'~-~'i~i"'! ............... ~ ............... -,[ ................. '~'~'t-~"T, -"~-~'~'i:~'F'i : 20stks : 900ps, ,' 25 stks 1,120 ps,'l,; ............... ~'-'~§-~'t'~i ..... i:-l'~-6-'~iif-'i,' .............. T,: --:-a-:i::---F-~;:a'6-i::;F! i ............... "--~:-:'t'::-'~' -'::: ~'6-'~:F~'~: .............. T"§~-'~iE~- .... -~:§~-~-~;~-['l r .................. -~§'~'t'~-~ ..... .............. t ................................ :::::::::::::::::::::::::::::::::::::::::::::: ' ............... r ................ -r : ' 45 stks 2,075 psi .............. , .............. , ? .................. ~ .................. '~§'~-f~---"--~',i~i~-6-~[--, ....,~ ............... ,I- ............... ]- ................ 4, : ................................................. 60 stks 2,800 psi I ................ t ............... r ................ I: ................. -~:i-~-f~ ..... -~1~[:,-6-~[--, , .............. ! ............... , ................ ~ l~ ..............~'I ................................ ,' ~,' '~ ............................... ?i ................ -I ,- .............' ............... ? ................ 1 I ~ ~ ~' i' '~ , SHUT IN TIME SHUT IN PRESSURE i" .............. '~', ............... ,'~ .......................... i ~ 0.0 mint ................................... ~ 3,000 psi:"; ,I- .............. -~ ............... I- ................ 1 ~ ......................... '. .............. '_L ...... [ ........................ J ~ l'0mm ~ , 2,070 ps, , ~ ~ ' ! i 2.0mm [ ~ 2,055 ', i ' ~ S.UT~T~M~' S.UT~ PRESSURE i 3.0 rain 2,945 psi ~ ~' ............... " ............... ~ .............. ;'I [-'~y6"~[3'--r ............... F'~:-~§6-¢~T-] [ 4.0 m~n 2,94o p~, ............... .4-' ................................ I , - ......... r .... ~' ............... I' .............. ! 1.0min i 1,330,$i ~ ~ 5.0mm ~ ~ 2,940 [-'::~)--r~[~"T, ................. -~;§~l'~'-~;f'i ................................ 6.0 min -~ .............. 2,935 ps, i 4.0rain ! 1,320 :~i i ["~-'r~i~'"[ ............... -[,--~:~t-I~-'~'~ [___s_.__o___m_Ln___5 ............... L.~_:.a_j.o._ p_ ~:_.,, ~"5~"r~i3' .................. i 6.0rain i 1,305 ,si i ['-1'~--~[~ ................. -["~}~-~-~['" r .............. -'r ............... r ................ 'I r ............... ~' ............... "1- ................. : 7.0min i j 1,300 3si j ' ' ' ................................. ' ' = 15.0mm ~ i 2,925 ps, ~ .............. '- .............. -~ ................ ' "'-~)--r~[~'" 2,920 psi j 8.0min : I 1,300 ~sii ~ 9.0 min ~, i 1,300 psi ! 25.0 min, 2,920 psi ,.. ..... '.. .......................................... .~ ................ L .................................. NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION May 13. 1999 Randy Thomas Drilling Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3'192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re; Kuparuk River Unit 1C-27 ARCO Alaska. Inc. Permit No: 99-43 Sur Loc: 1710'FNL, 1352'FWL, Sec. 12, Ti IN, RIOE, UM Btmhole Loc. 2363'FSL, 2116'FWL, Sec. 8, T1 IN. RI IE, UM Dear Mr. Thomas: Enclosed is thc approved application for permit to drill thc above referenced well. Thc permit to drill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on the same drill site must comply with thc requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to usc that well for disposal purposes for a period longer than one year. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 arc met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed bv a valid Formation Integrity Test (FIT). Cementing records, FIT data. and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Blowout prevention equipment (BOPE) must bc tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlffEnclosures Department of Fish & Game, I Iabitat Section w/o cncl. Department of Enviromnental Conservation w/o encl. STATE OF ALASKA '! ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill [] Redrill [] lb. Type of well. Exploratory [] StratigraphicTest [] Development Oil[] Re-entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 95 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0361 ADL 28242 ALK 2292 Kuparuk River Pool 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 2O AAC 25.0251) 1710' FNL, 1352' FWL, Sec. 12, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1905' FNL, 750' FEL, Sec. 7, T11N, R11E, UM 1C-27 #U-630610 At total depth 9. Approximate spud date Amount 2363' FSL, 2116' FWL Sec. 8, T11N, R11E, UM May 15, 1999 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'I'VD) 750 @ Target feet 1C-01 13' @ 500' MD feet 2560 13905 ' MD/6466 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.03,5 (e)(2)) Kickoff depth: 300 MD Maximum hole angle 92° Maximum surface 2680 psig At total depth (TVD) 3180 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casin~ Wei~lht Grade Couplincj Le%lth MD TVD MD TVD (include sta~le data) 24" 16" 62.5# R-3 Weld 25' 95' 95' 120' 120' 9 cu yds. High Early 12.25" 9.625" 40# L-80 BTC-Mod 6824' 95' 95' 6919' 4543' 790 sx AS III L & 650 sx Class G 8.5" 7" 26# L-80 BTC 10766' 95' 95' 10861' 6408' 180 sx Class G 6.125" 4.5" 12.6# L-80 I BT-Mod 3305' 10600' 6379' 13905' 6466' NON E - slotted liner 19. To be completed for Redrill. Re-entry. and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production Liner } ECEIVED Per/oration depth: measured 0RIG IN A L true vertical Alaska 0i~ & Gas Cons. Anchorage '20. Attachments Filing fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call William Lloyd265-653 Signed ~,.._ ~r- '// Title: Date Commission Use Onl} Permit N~i~er,, ¢3 APl number I Approval date See cover letter 50- O,,~ ?"" 2., ~ ~)' ~ ,~ ,,~"" lo"~ ' /~ ~' for other requ rements Conditions of approval Samples required [] Yes ,~ No Mud log required [] Yes 1~ No Hydrogen sulfide measures [] Yes ,1~ No Directional survey required ]~ Yes [] No Required working pressure for aOPE [] 2M; [] 3M; [] (~) [] 1OM;[] [] Other: ORIGINAL SIGNED BY by order of --- Approyed__bY_ J;;~nh~rt kl ~1,,,.;,.,, ..... Commissioner the commission Date ~ "" j <~' '" ¢ ¢ Form 10-401 Rev. 12/1/85 · Submit in triplicate ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 1C-27 Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel API Filtrate pH % Solids Spud to surface casing point 9.3-10.2 ppg 16-26 25-35 100- 150' 10-20 15-40 7-15 9.S-10 ±10% Drill out to top Kuparuk 9.5- 11.5 ppg 6-20 5-20 35-50 2-6 4-8 6- 15 9.0-10 <11% Horizontal Interval to TD 10.5- 11.0 ppg 5- 18 5 - 20 36 - 45 2-5 3-8 <5 9.0 - 9.5 <8% Drilling Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Degasser *Spud mud should be adjusted to a FV between 100-150 sec/qt to drill gravel beds l:..l.,.~ ~ ''~ Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25AC}~a 0il & GasCons. Maximum Anticipated Su~ace Pressure: Anchorage Maximum anticipated surface pressure (HASP) while drilling the production hole is calculated using a su~ace casing leak-off of 13.5 ppg ENW (0.70 psi/E) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a su~ace pressure of 2,680 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after se~ing surface casing. HASP = (4,543 ~)(0.70- 0.11) = 2,680 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of 1C pad are expected to be ~3,350 psi (0.52 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6,408'. Target (Kuparuk C4) (3350+ 150 )/(0,052'6455)= 10.5, Well Proximity Risks: The nearest well 'to 1C-27 is lC-01. The wells are 13.4' from each other at a depth of 500' HD. Gyro surveys will be required to validate survey integrity. Drillinq Area Risks: Drilling risks in the :1C-27 area are surface interval hydrates, lost circulation and potential bore hole instability in and below the permafrost formation. Hydrate risks will be minimized by the use of sufficient ARCO Alaska, Inc. mud weights to allow for tripping of pipe, controlled drilling rates, and optimum rheological properties to safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM) Annular Pumpinq Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class ]i]i disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The ::[C-27 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. ]If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. Following drilling operations, a sundry notice requesting permission to annular inject into the :LC-27, per regulation 20 AAC 25.080, will be submitted. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300- 500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (4,543') + 1,500 psi Max Pressure = 4,334 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8' 40 L-80 3 BTC 3,090 psi NA 5,750 psi 4,888 psi 7" 26 L-80 3 LTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi 31/2''* 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,95:L psi 10,160 psi 8,636 psi * if needed Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). All Depths are RKB Pool Rig 6 1C-27 Dri. and set Casing FMC Prudhoe Gen V 9-5/8 x 7 9-5/8 Mandrel Hanger Base of permafrost at 1,933' MD / 1,795' TVD 12-1/4" Top of West Sak at 5,786' MD / 3,928' TVD Base of West Sak 6,551' MD / 4,343' TVD 9-5/8" 40 ppf L-80 BTC Surface Casing 6,919' MD / 4,543' TVD -,. 8-1/2" Hole Baker 4.5" x 7" ZXP LTP and tieback sleeve and HMC Liner Hanger w/PBR @ 10600' MD Weatherford Gemoco 7" Float Collar and Float Shoe Baker 4-1/2" Guide Shoe 16" Conductor '"'" Weatherford Gemoco '.-.,. · .-.'.9-5/8" PORT Collar '"'" Standard Grade, BTC ...... 1,001' MD / 1,000' TVD iiiiii Mud Weight in Surface :::::: hole: 10.0 ppg by 1100' TVD 10.2 ppg by 1900' TVD Weatherford Gemoco 9-5/8" Float Collar and Float Shoe Mud Weight in Production hole 10.5 to 11.0 ppg i:!:i:! 7" 26 L-80 BTC Mod Csg i:i:!:! 10,861' MD / 6,408' TVD %, %, ,., .., 4-1/2"12.6#/ft L-80 IBT-Mod Slotted Liner Completed 1C-27 FMC Prudhoe Gen V 9-5/8 x 51/2 x 31/2 Base of permafrost at 1,933' MD / 1,795' TVD 12-1/4" Hole Weatherford Gemoco ':':' 9-5/8" PORT Collar ~i... Standard Grade, BTC !::!::!::1 ::::::: 9-5/8" 40 ppf L-80 BTC-Mod Surf. Csg. 6,919' MD / 4,543' TVD 81/2" Hole 4Y2" 12.6 ppf L-80 8rd EUE tubing w/15' seal bore extension tied 7" 26 ppf L-80 BTC Intermediate· Csg. 10,861' MD / 6,408' TVD CAMCO DS lie for SCSSV +MD ) 4Y2" x 1" pocket GLM Camco 4Y=" x 1-1/2" side pocket GLM ICO 3.75" D nipple Baker 4.5" x 7" ZXP LTP and tieback sleeve and HMC Liner Hanger. TOL @ 10600' MD/6379' TVD 6-1/8" Hole ARCO Alaska, Inc. Drill and Case Plan for lC-23 Kuparuk Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 12 1/4" hole to the surface casing point at 6919' MD/4543' TVD. Run MWD logging tools in drill string as required for directional monitoring. 4. Condition hole for casing, trip out. 5. Run and cement 9 5/8" 40# L80 BTC casing string to surface. · Employ lightweight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. · TAH Port Collar will be placed in the casing string at 1000' IVlD to be used in the event that cement does not reach the surface in the primary one stage job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test 7. Hake up 8 1/2" bit and BHA and R[H to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 8. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 9. Drill 8 1/2" hole to Base HRZ at +10226' IVlD/6284' TVD · Perform a second LOT and determine an acceptable kick tolerance · If kick tolerance is acceptable, 8 1/2" hole will be drilled to top of Kuparuk C · If kick tolerance is unacceptable, 7" casing will be run to base of HRZ. 10. Run and cement 7" 26# L80 BTC-Mod 11. Make up 6 1/8" bit and BHA and R[H to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 12. Drill float equipment and approximately 20' of new hole 13. Drill 6 1/8" horizontal wellbore to TD at 13905' MD/6466' TVD · Condition hole and mud for casing 14. Run 41/2'' 12.6# L80 [BT-Mod slotted liner w/liner hanger and liner top packer 15. Run and land 4 1/2" tubing with seal bore extension and gas lift completion stung into LTP 16. Nipple down BOP's. Install production tree and pressure test same. 17. Secure well, release rig KOP 1.50 500 1 i Begk~ Tu,n to T~rgei 1000 15,82 21,75 BLS: 3.00 deg per 100 fi 27,71 1500 3.3 69 39.67 2000 57.14 DEG TANGENT ANGLE Field : Kuporuk Rver Unil Point ...... MD Inc D[r r¥D Norlh East V. SectBeg/100 KOP 300.00 0.00 0.00 30000 0.00 0.00 000 0 O0 Begin Turn io 'forget 600,00 4,50 55.00 599.69 6.75 9.65 9,49 1,50 Bose of Permafrost 1932.50 45,63 89.22 1795,00 44.53 8.33,58 532,39 3,00 EOC 2385,66 57,14 90.52 2082.00 45.59 880.32 87901 5.00 Top of West Sak 5785,91 57.14 90.,32 3928.00 29.72 3738.17 3756,45 0.00 Base of West Bok 6550.77 87.14 90.52 4343.00 26.18 4380.64 4378,84 0.00 Surtoce Cosin9 P! 6919 38 57.14 90.32 4543.00 24.43 4690.27 4688 42 0.00 iC80 7184,77 57,14 90.52 4687,00 23.19 4913.20 4911,32 0,00 C50 8677.64 57,14 90.52 5497.00 16.22 6167,19 6155,15 C40 9171.57 57.14 90.52 5765.00 15.92 6582,09 6579,97 0,00 BeGin Build/Turn to 9701,07 57.14 90.32 6052.50 11,45 7026.87 702468 0.00i C30 9849.96 60.84 95.23 6129.00 7.43 7154.,387182,25 C20 10148,90 68.44 98.51 625700 20.56 7422.73 7421 18 Bose of HRZ 10228,76 70.42 99.77 6284,00 -52,00 7493.77 7492,47 3 O0 iK-1 10428,17 ?'5,58 102.95 6343.00 70.20 7683.48 7683.03 3.00] 7 Coslrlg Pt 10494,83 77,41 103.96 6358.44 -B5.22 7746,26 7746.12 3.00] [Top Kuparuk D Shale10594.53 80.05 108.46 6378,00 110.12 7841,09 7841.52 5.00i ~op C4 10860,59 87.02 I09.55 6408.00 189,15 8093,14 8095,55 ~orget--Heel/Top C4/E 10860.61 8%02 109,34 6408.00 189.16 8093.15 809536 1.13i ~op C5 11418.64 87.02 109.34 6457.00 -375.67 8618,99 8625,37 0.00i [Torgei--Hrizn #1/Begi 11572.67 87.02 109.34 6445,00 424,60 8764.I4 8771,67 3.00 EOC 11748.O0 92.28 109.34 6446.06 482,63 8929,52 8958,36 3.00i Begin Angle Drop 11987.59 92,28 109.54 6435,52 - 561.90 9155,42 9166.04 0.00i q[Tar e-Fault 12063.71 90.00 109,33 6435.00 -587,09 9227.25 9238.45 3.00i EO¢, 87.17 6437.33 -618.29 9316.!4 932805 12157.98 109 ,$4 3.00' 12617.46 87.17 109.34 6460.00 770,24 9749,18 9754.51 3.00 7orget-Hdzn #2/Begi '%~ EOC 12721.45 90.29 I09,34 6462.30 804.66 9847.27 986338 3.00 ~, forget HBzn #3/Begi 12977.01 90.29 109,34 646!.00 -889.27 10088,4110106.43 3.00 EOC 12997.23 89.68 109.34 6461.00 -895.97 10107,4910125.56 3.00; % 91,34 AZIMUTH ~ ........ ~ 8095' (T0 TA2GET HEEL) ~ 9 5/8 Cosin9 Vertical Section (fee Azimuth 9t.34 wPth reference 0.00 N. 0.00 E from slot #27 ARCO Alaska, Inc. Sfruofure : Pad 1C Well : 27 Field : Kuporuk River Unii Location : Norfh Slope, O.DirOo ~¢D Nodh East V Secl Deg/lO0[ E~sf (fee0 -> 0 500 1000 1500 2000 2500 5000 5500 4000 45O0 5000 5500 6000 6500 7000 75oo 8000 8500 gO00 95OO 10000 I o5O0 ~ 1000 1 ! 5OO r TARGE~ NOR~ZON ~2: ] [ TARGET HORIZON ¢3: I I 2563' FSL ~116' FWL~ ARCO Alaska, Inc. Field : Kuparuk River Unit Location : Norfh Slope, Alosko Easf (feel) -> 7000 7200 7400 7600 7800 8000 8200 8400 8600 8800 9000 9200 9400 9600 9800 1 DODO 10200 10400 10600 10800 ! 1000 ! 1200 ~ 1400 4OO 8OO 1200 t9000 ARCO Alaska, Inc. S~ruc~ure : Pad 10 Well : 27 Fie~d : Kuporuk River UnH Lc~aation : North Siope, A]asko[ Easf (feel) -> 80 60 40 20 ~ 0 20 40 50 80 !00 120 140 ~60 1BO 200 220 240 260 280 30O 320 .¢ ~500 ,. ~ ....... soo -- e~oo ¢~o~°° ....... q{oo ~,,, 1 700 e~?0. ........ ~soo q 700 ~ zoao ~ 6o ', ~20o k x.,j 0oo 1500 ~o t~ Eas+ (feel) -> 6O ARCO Alaska, East (feel) -> 240 280 520 360 400 440 480 520 560 600 640 680 720 760 800 840 BSO 92O 960 1000 1040 "- . 3 700 I ~2o i / East (feel) -> 160 120 A Z ~ 200 ARCO Alaska, Inc. Eost (feel) -> 2100 500 Eost (fee~} -> ARCO Alaska, Inc. S~rucfur~ : Pod 1C Well : 27 East (fee'0 -> 2~00 2600 2800 3000 3200 .~400 5600 3800 4000 4200 4400 4500 4800 5000 5200 5400 5600 5800 6000 6200 6400 A Eas± (feel) -> ARCO Alaska, Inc, Structure : P~d 1C Well : 27 Fleid: Kuporuk River UnH Loeo~lon : Norlh Slope, Alasko EoM (feet) -> 6000 6500 6800 6900 7200 7500 1800 8100 8400 8700 90OO 9300 9800 99OO 1O2OO ~0500 !0800 1~00 11400 !~700 12000 125OO 300 4 6100 6300 6500 5~x5~500 5700 5900 51 O0 6500 0'3 I goo 900 300 0 F 900 F P 1200 Eost (feet) -> 15O0 1500 / 1800 ] 1600 ARCO Alaska, Inc, Structure : Pad lC WeB : 27 Field : Kuporuk River Unit Location : North Slope, Ataskei .................................... ~TRUE NOR] 550 0 340 350 ,520 ~ ~0 20 3O 5 4O 6O 290 7O 280 270 8O 9O 260d~ 250 ' 1300 250 220 ~ 2OO Norc'/o P{one Trovelng CF[rider - Feet 190 i 80 170 i00 1i0 120 150 140 150 160 All depths shown ore Measured depths on Reference Well ARCO Alaska. Inc. Pad lC 27 slot~7 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 27 Version #11 Our ref : prop3323 License : Date printed : 27-Apr-99 Date created : 18-Feb-99 Last revised : 27-Apr-99 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w14930 19.124 Slot location is n70 19 28.354,w149 29 39.662 Slot Grid coordinates are N 5968529.338. E 562359.365 Slot local coordinates are 1710.00 S 1352.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel 1 path GMS <O-7615'>,.2.Pad 1C PMSS <0 - 8095'>,,18,Pad 1C PMSS <0-9390'>,,15,Pad 1C PMSS <0-10980'>,.14,Pad 1C PMSS <0 - 11918'>,,16,Pad 1C GMS <0-7575'>,,4,Pad 1C PMSS <0 - 10969')..17,Pad 1C MSS <0-7000'>,.gGI,Pad 1C PGMS <O-9002'>,.lOGI.Pad 1C GMS <O-9600'>,,8,Pad 1C GMS <0-9784'>,,7,Pad 1C GMS <0-10243'>,.6,Pad 1C GMS <0-7753'>,,5.Pad 1C GMS <0-9700'>,.3,Pad 1C PMSS <O-8677'>,.13,Pad 1C Unknown Data.,WS1,Pad 1C PMSS <O-11300'>,.11,Pad 1C MMS <6948-7570'>,,WS~24.Pad 1C PMSS <0-17089'>,,12,Pad 1C GMS <0-7780'>,.1.Pad lC PMSS <O-????'>,,25,Pad 1C Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 18-Dec-98 106.5 300.0 300.0 22-Feb-99 413.3 100.0 100.0 17-Dec-98 121.7 788.9 788.9 18-Mar-98 219.5 811.1 811.1 8-Jan-99 528.1 700.0 700.0 18-Dec-98 345.7 314.3 314.3 2-Dec-98 849.6 100.0 100.0 2-Jan-98 874.3 300.0 300.0 18-Dec-98 718,9 0.0 314.3 18-Dec-98 826.5 0,0 328.6 18-Dec-98 705.6 300.0 10550.0 18-Dec-98 586.1 300.0 300.0 18-Dec-98 465.1 371.4 371.4 18-Dec-98 226.0 300.0 300.0 1-Dec-98 561.5 314.3 314.3 2-Nov-98 7769.6 40.0 40.0 19-Mar-97 862.8 300.0 300.0 17-Dec-97 4309.4 10531.5 10531.5 7-Jan-98 453.9 2680.0 2680.0 11-Mar-99 13.4 500.0 500.0 26-Apr-99 30.2 0.0 811.1 ARCO Alaska, Inc. Diverter Schematic Pool #6 Flowline 21¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet 21 ¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. POOL #6 13-5/8" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT L, J L J I J L 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi wP Shaffer GATE VALVE MANUAL GATE V KILL LINE / 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / I / BSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP ~raulic actuator ~,-~~'~ ~0 psi wC~~cKTE' LINE 13-5/8" 5,000 psi WP DRILLING SPOOl. ~'~ w/two 3" 5M psi WI:' outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams ARCO Alaska, Inc.~t Post Office Box 100360 Anchorage, Alaska 99510-0360 May 3, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill: KRU :1C-27 Surface Location: :!.7:10' FNL :1352' FWL Sec :12 T:1:1N R:1OE~ UPi Target Location: :1905' FNLt 750' FEL Sec. ?t T:1:1N~ R:1:1E~ UPi Bottom Hole Location: 2:363' FSL¢ 2:1:16' FWL Sec. 8~ T:1:1Nt R:1:IE¢ UPi Dear Commissioner Christenson, ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1C pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of lC pad. The well is designated as a horizontal production well to the Kuparuk C4 zone using a 9 5/8" surface casing string, a 7" intermediate casing string to the top of the producing horizon, a 4-1/2" slotted liner in the horizontal reservoir section, and 4-1/2" production tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) 2) 3) 4) 5) 6) 7) 8) 9) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. RECEt'VED Alaska 0il & Gas Cons. Oommis$iet" Anchorage Robert Christenson Application for Permit to Drill - 1C-27 Page 2 10) Due to the large volume of regional information available, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned.The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) 2) Completion Report Technologist (20 AAC 25.070) Geologic Data and Logs (20 AAC 25.071) Sharon AIIsup-Drake, Drilling 263-4612 Meg Kremer, Geologist 265-6460 The anticipated spud date for this well is May 15, 1999. If you have any questions or require further information, please contact Bill Lloyd at (907) 263-6531 or Chip Alvord at (907) 265-6120. Sincerely, /-)//~//~ CC: Kuparuk 1C-27 Well File Chip Alvord ATO-1200 MJ Loveland NSK6 ¢' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X Annular Injection 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1693' FNL, 1327' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 1478' FNL, 1998' FEL, Sec. 7, T11N, RllE, UM At effective depth At total depth 1470' FNL, 1656' FEL, Sec. 7, T11N, R11E, UM 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service __ 6. Datum elevation (DF or KB feet) RKB 95 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 C-25 9. Permit number / approval number 99-31 10. APl number 50-029-22941 11. Field / Pool Kuparuk River Field 12. Present well condition summar Total depth: measured Effective depth: Casing Conductor Surface Production 10242 true vertical 6693 measu red 10242 true vertical 6693 Length Size 114' 16" 6567' "9.625'' 7" Liner Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth N/A =ackers & SSSV (type & measured dePth) N/A feet Plugs (measured) feet feet Junk (measured) feet Cemented 9 cu yds High Early 796 sx AS IIIL, 653 sx Class G 180 sx Class G Measured Depth True vertical Depth 114' 114' 6567' 4550' 9570' 6304' 13. Attachments Description summary of proposal__ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: May 1, 1999 16. If proposal was verbally approved Oil __X I Name of approver 17. I hereby certify that th~or~~~r~ct to the best of my knowledge. Signed Title: Drilling Team Leader Paul MazzoTtni /( ~ ~/ FOR COMMISSION USE ONLY COnditions of approval: Notify Corflmission so representative may witness Plug integrity_ ,,~t__,~ / Location clearance__ Mechanical In~/~.~~/ o S;bsz;t~~r~Z 10' Appr. gved by cider of the Commissi ,(~.~.~' Gas __ Suspended __ Questions? Call William Lloyd 265-65,?,1 / Date /~- ,,,~2o, gQ // Prepared by Sharon All. sup-Drake I Approval no.c~ Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ARCO Alaska, Inc. GKA 1C-25 TUBING 1 C-25 (0-9452, APl: 500292294100 Well Type; PROD Angle @ TS: 53 deg @ 9781 OD:3.$00, SSS¥ Type: Orig Completion: Angle @ TD: 52 deg @ 10140 ID:2.992) Annular Fluid: Last W/O: Rev Reason: TAG, PERF, GLM BY VG Reference Log; Ref Log Date: Last Update: 10/7799 LastTag~ '10023 TD: 10140 flKB Last Tag Date: g/30/gg Max Hole Angle: 56 deg @ 4002 Casin~l String -ALL CASINGS Size Top Bottom TVD Wt Grade Thread 16.000 0 115 115 62.58 H-40 WELDED 9.625 0 6567 4554 40.00 L-80 BTC-MOD 7.000 0 9570 6305 26.00 L-80 BTC-MOD 3.500 9416 10138 6648 9.30 L-80 EUE 8rd Tubin[I Strin[~ - TUBING 3.500 0 9452 6234 9.30 L-80 EUE 8rd SURFACE Perforations Summary (0-6567, IntervalI TVD I Zone IStatusIFeetlSPFI Date I Type 2.5 HC, Comment 9788- 9824 6437- 6456 c-4 / I 361 418/27/9911PERF DP, 180 deg. phasing OD:9.625, 9834 - 9844 6464 - 6470 C-4 ! I 101 1018/27/99 IIPERF 2.5 HC, DP, 180 deg. phasing Wt:40.00) Gas: Lift: MandrelS/Valves Stn MD TVD Man Man VMfr VType VOD Latch Port TRO Date Vlv Mfr Type Run ;omment 1 3230 2612 CAMCO KBMM CAMCO OV 1.0 BK-5 9.250 0 10/4/99 2 5166 3734 CAMCO KBMM CAMCO DMY 1.0 BK-5 0.000 0 4/25/99 3 6594 4570 CAMCO KBMM CAMCO DMY 1.0 BK-5 0.000 0 4/25/99 4 7775 5262 CAMCO KBMM CAMCO DMY 1.0 BK-5 0.000 0 4/25/99 5 8616 5749 CAMCO KBMM CAMCO DMY 1.0 BK-5 0.000 0 4/25/99 6 9391 6198 CAMCO MMM CAMCO DMY 1.5 RK 0.000 0 8/27/99 :Other: 'PlU~lsi:equi:p,~;etc;),untitled:: ::: : : ;: Depth TVD Type Description ID 502 502 NIP CAMCO DS nipple 2.875 9410 6209 NIP CAMCO D nipple NO GO profile 2.750 9422 6216 SEAL BAKER 80-40 casing seal assembly 3.000 PRODUCTION (0-9570, OD:7.000, Wt:26.00) NIP (9410-9411, OD:4.500) Per[ (9788-9824) Per[ (9834-9844) ARCO Alaska, Inc. Casing Detail 9.625" Surface Casina Subsidiary of Atlantic Richfield Company WELL: 1C-25 DATE: 04/16/99 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LR = 34.60' TOPS Above RKB 9 5/8" Landing Joint (Jt. 169) 38.70 -4.10 FMC GEN IV- Kuparuk.9 5/8" Csg Hgr 1.96 34.60 jts144-168 9 5/8", 29.7#, L-80 BTC (25 jts) 966.32 36.56 TAM 7 5/8" Port Collar 3.05 1002.88 its. 3-143 9 5/8", 29.7#, L-80 BTC (141 its) 5476.82 1005.93 Gemeco Float Collar 1.50 6482.75 its 1-2 9 5/8", 29.7#, L-80 BTC (2 its) 81.34 6484.25 Gemeco Float Shoe 1.75 6565.59 Casing shOe @ 6567.34 T.D. @ 6580' leaving 12.66' of rathole 13 Gemeco BoW Spring CENTRALIZERS Run centralizers in center of Jts. 1, 2 over. stop collars and over casing collars on Jts. 3-12 and over collar of it. 168 Run 1 ROTCO Rigid Straight Blade Centralizer in middle of joints 143 and 144 W/stop tings Joint 169 will be used as the landing joint . , , , , , . . Remarks: String Weights with Blocks: 295k Up, 180k Dn, 70k Blocks.' Ran 168 joints of casing. Drifted caSing with 8.679" plastic rabbit. Used 'Arctic Grade APl Modified No Lead thread compound on all cOnnections. Casing is non-coated. , Pool 6 Drilling Supervisor: Fred Herbert / SCoff Reynolds ARCO Alaska, Inc. Cementing Details Well Name: lC-25 Report Date: 04/16/99 Report Number:. 2 Rig Name: Pool 6 AFC No.: AK0023 Field: KRU . Casing Size Hole Diameter:. Angle thru KRU: Shoe Depth: J LC Depth: % washout: 9-S/8" 12-1/4" N/A 6567[ 648~ 66 Centralizers State type used, intervals covered and spacing Comments: Run centralizers In center of Jts. 1, 2 over stop collars and over casing collars on Jts. 3-12 and over collar of Jt. 168 Run 1 13 Gemeco Bow Spring ROTCO Rigid Straight Blade Centralizer In middle of Joints 143 and 144 w/stop rings. CENTRALIZERS Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 10.3 42 18[ 44 10 Gels before: Gels after, Total Volume Circulated: 2~59 3/7 1920 bbls Wash 0 Type: Volume: Weight: Comments: ARCO B47 19.78 8.2 ppg Spacer 0 Type: Volume: Weight: Comments: ARCO B45 51.45 12.56 ppg · Lead Cement 0 Type: Mix wtr tamp: No. of Sacks: Weight: Yield: Comments: AS III Lite 70 deg F 796 10.8 ppg 4.43 Additives: 50% D124, 9% D44, 0.4% D46, 30% D53,1.5% S1,1.5% D79 Tall Cement: 0 Type: I Mixwtrtemp; I No. of Sacks; Weight; Yield: Comments: · . G[ [70 deg F 653 15.8 1.17 ' . ..... . . : Additives: ' .: i : . . 1%S1,0.2%D46,0.3%D65 Displacement 0'.... Rate(before tail at shoe): Rate(tall around shoe): Str. Wt. Up: Comments' 8 bpm 6 bpm 295K Displaced with Rig Pumps Reciprocation length: Reciprocation speed: Str. Wt. Down: . : . 20' 10 ft/mln 180K ,,, · ' ' :: :: . Theoretical Displacement: Actual Displacement: Str. Wt. in mud: " :: : 461.6 bbls 464.2 bbls 222K Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:4/16/99 yes yes Time:13:58 hfs Remarks:Cite and cond mud 7 bpm 650 psi, pumped 20 bbls of preflush, 50 bbls of spacer, 628 bbls of lead and 136 bbls of tall cement. Displaced with 10 bbls tall cement & 20 bbls of wash up water and 464.2 bbls of mud, bumped plugs to 1600 psi. Had 114 bbls of 10,7 ppg cement returns to surface, reciprocated pipe until dropped top plug, casing stuck at this time, had full returns throughout. Celloflakes added to wash for surface Indication of cement returns. Cement Company: Rig Contractor: POOL IApproved By: Scott Reynolds / Fred Herbert DS CASING TEST and FORMATION INTEGRITY TEST Well Name: SuperVisor: 1 C-25 Scott Reynolds 7 5/8", 29.7 ppf, L-80, BTC Date: 4/18/99 Casing Size and Description: Casing Setting Depth: Mud Weight: 8.8 ppg Hole Depth: 4,573' TVD 6,567' TMD 4,561' TVD EMW = Leak-off Press. + MW 0.052 x TVD LOT = 1,700 psi + 8.8 ppg EMW (0.052 x 4.573') -- 15.9 Ppg Fluid Pumped = 3.6 bbI Pump output = 0.0846 bps 3.100 psi 2.700 psi Z4~0 ps~ 2.50O 2.4C0 p~ 2,300 psi 2.2OO 2,100 psi 1,~o p~ 1,7OO psi 1,60(] psi ]~3OOp~ 1,]oo psi ],0OO psi 7OO ioo psi 0 pd I I I I I I I I l-TI I I I I I I I I I.l.J.i.l.l.l.J.l.l.l.l.l.l.J.l.l.J.J.J.l.i.l.l.l.l.l I I I I I I I I I I,I I I ' I I I I J I~/:~'l'l'l'l'l'l'l'l't'l'l'~'l'l'l'l'l'l'1'l'l'l'l'l ~_L~_L~JTIME UNE ~ r l I I I I I I I I I ~~% I I~1 I~.; ;~; ;~ I I I I I I I I I I1~ ~ ,~ ~ I I I I I I I I I I I I ~ I I I I I I I I I I I I I I I I I I I I I IIu'~='v'"~u'= I I ~1 I I 1 I I I I I I I I I I I I I I I I I I I I_._1 I I..I_LJ_] I ~ I I I I I I I I I I I I I I I I I I IIIIIIIIIIIIIII1.1/1t1111111 ~ IIIIIIIIIIIIIIIIIII _1 I I_1 I 1..1 I I I I I I I I ~ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I LJ I I I I I I I [~t' I I I I I I I I I I I I I I I I I I I I I IIIIIIIIIIIII Il Jlllllll ~ IIIIIIIIIIIIIIIIIIIIII I I I I I I I I I I I I I I I I I I I I I I I J~'t'l I I I I t I I I I I I I I I I I I I I I I I I ~ I'J~J~_:l_l I I I I,~1 I I t I I I t I I I I I I I I I I I I I I I I I I I I I I I I I I I-I I I ~ I I l I I I I~1 I I I I I I I I I I I I I I I I I I I'1 I I I I I I LLL~ I I / I I I~1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I'I~_L_LLI I I~1 l~l I I I t I I I I I I I I I I I I I I I I I I I I i i_ I I i-~-I~1.~1 ,L,I~-L I I I I I I I I I I I I I I I I I I I I I I I I I I [~;'~+-;:~ ........ ~1 I I I I I I I I } I I J I I I J J I I I I I I £1~-~ I I I I I I I I I I I I I/~*T~I I I I I I t t I I I I I I I I I I I I I I I ~.,.,~_L.~ ~ : ~A~OFFTEST II I I I I I I I I I I I I I IIII1~~ ""e--CASIN~TEST IIIIIIIIIIIIII I I~.Wl' -.~ II I I I I I II II t I I I I I I I.,~1 I I I I I I I I II ..... ~o~m~/[monu~.~.wl[ II I I I I I I I I I I I I I i t TIME UNE I { J ltl I I I I I L~I~'I I I I J J I J J J J I I I I I I I I I I I I I I I I I I I I I I~rl I I I I I I'J I I I I I i I I J I I I I I I I I I I I I I I I I I I I I I 02 4 6 8 I012141618~24~32~42~~~~707274267B~~94 s~ s~ s~ s~ s~ s~ s~ s~ s~ S~ s~ s~ s~ s~ s~ s~ ~ s~ ~ ~ s~ s~ s~ s~ s~ ~ s~ s~ s~ s~ ~ s~ ~ s~ s~ s~ s~ ~ ~ s~ s~ s~ s~ ~ s~ s~ s~ s~ STROKES LEAK-OFF DATA ~INUTES FOR LOT STROKES PRESSURE ................ q ................... _~. ................... , j_______ _ _~0 stks 0 psi , ~ j 12stks 500 psi [ ............... j ..... l_6_s..Lk.s___._i _ Z.o_.o__P..S.[ ..... i i 20stks 900 psi = ~ 26 stks 1,110 psi i i 32 stks 1,300 psi ; .... : .............. i--~i~T~'~ ....... i','~'~tY~,]i'-'l , = 40 stks 1,600 psi [ ................ j_..4_~_~.Lk~_ ...... !:_6!o_.P_.s_L__l = [ 43 stks 1,700 psi '~ .............. i ...................................... F ............. I ................ T ................... [---, ......... i ................... -i-", .................... ~ ............. -4 ................. ~ .................... , CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE .......................................... r .................... · -*- .................... ~- .................... 0 stks i 0 psi :::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .................... i ..... ~._s_t3.s. ..... [ .... ~Z~_P_.s.! ..... ~- 12stks J 580p. si :::::::::::::::::::::::::::::::::::::::::::::::::::::::: 20stks i 990 psi 28stks i 1,300psi ..................... i .... .... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 40stks i 1,85Op..si ! .................... t .................... f ................... .................... ± .... ~__s.!.k..s. .... L_..2.,__o__5.g...p_.sl...= .......................... .4..s_..s.t..~..s. .... L_.~,.~_o..o.._p..~j.._j i 52stks i 2,400 psi ~ .................... T .... ~iF~'ik%' .... ["'~;i~'6'6"1~%T'I .................... T .... ~%iE~- .... ["-~iff-~-b"/;~T-'i .................... ,-I- ....................r ................ii--~, i 64stks [ 3,000 ps i '- ...................T .................... ~ .................... ..................... f .................... ,~ .................... , I I SHUT IN TIME, SHUT IN PRESSURE ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 1.0min ~ 2,990 psi [ ;--'616-bi~'--; ................... i--'7:FSb-'F~i'"~[J ....... 4.0" .......... min +; .................... i' .................... 2,985 psi 'i [:i-i~::.C~6 i-]ii:iiii!::~i.~:.~:C~_:s!::! ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 6.0 min i 1,400 psi ! i ........................ r-li:~i~-'i' .................. T---1-,-~-6i~-~i--" · I .............. + .................... 15.0min i i 1,270psi .................. T 20.0min j j 1,220psi 22.0min i ~ 1,200 psi ['-Y3'.~'7~Fn-"T .................. l'--i';'f,-6'6-i;'~T-" ................. -I ................... + .................. 24.0min i i 1,200 psi 6.0min ~ 2,970 psi j ..... ~:6-Tfii~i .... ~ ........................ ~;~-~%'~:.~):" ~ ..... /~':b"&ii~ .... T .................... ['-'~;~i~'~' i~'~¥--] 9.0min ~ ! 2,965 psi ! .... i-5:b'-&~TC'T ........................ ~;~%'6'~:{"i .... !-%-9---m-J-"-----L ........................ -2-'--9-f--°---P.-S!--i 20.0min j 2,960psi j .... .................... .................... ] .................... · ................ ii-" .... ~o.o..__o_~j~..__~ .................... L...2.,.9..6..o_..p..$.._..,,' NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1C-25 Supervisor: Scott Reynolds & Fred Herbert Date: 4/20/99 Casing. Size and Description: Casing Setting Depth: Mud Weight: 9.3 ppg Hole Depth: 6,307' TVD LOT = 7 5/8", 29.7 ppf, L-80, BTC 6,567' TMD 4,554' TVD EMW = Leak-off Press. + MW 0.052 x TVD 975 psi + 9.3 ppg EMW (0.052 x 6,307') = 12.3 ppg Fluid Pumped = 8.9 bbl Pump output = 0.0846 bps 1.200 ],]oo p~ 1,000 psi 7OO p~ lO0 psi o~ STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE I .............. ,~ ................... ..,. .................... i 0 stks 0 psi ............... ..... .... ..... ! 10 stks 190 psi ................. i ..... {~i"ii-i~-~ ........ iii~i'iiiii ..... .............. ] .... . .2. .5_ _s_ !. .k_ .s_ _ _ _ i .... _3_!.5__p_.s.! ..... ............... ] .... _3_9..s3?_s- ...... .4_~.0__~_s_[ ..... ................ J .... 2-s--s-!--~-s-- ......... ~.o__p_.s_! .... ! 40stks 620 psi .................... I ................. "- .................... : 46stks 750 psi .................. ~ ..................... r .................. ................. ] .... .-5-.O--s!--k--s---! --- ~-2-P---P--S-! .... i 55stks 899 psi i 62stks 975 psi .............. i .... .... .... ................. 1 ................... -I' ................... ............... ] .... -6- -4-s t- -k-s----!-- --s-!.s--P--S-[ .... i 68stks 950 psi .................... .~ ................ _~. ................... ..~ i .70 stks 900 psi ............ ---i .... -f-~"~¥i~'i---T .... ii;ii:i-ii~-i .... i 86stks i 830 psi ! 90stks 820 psi ................. ~, ................... '~- ................... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r I I i .......................................... t .................... i ' i ! i ! .......................................... ,r .................... i .......................................... [ .................... ......................................... [ .................... .......................................... [ ............ ........................................ I- .................... ..................... - ................... f .................... I .......................................... i .................... I SHUT IN TIME SHUT IN PRESSURE : i 95 stks 820 psi ,, ..... !:.o___mjp_ .... ~, .................... [ .................... i .................. ] .... i-b-~'-~i'[(-~ ......... it~-6-~i[ .... ] ' 2.0 min i ! ...........................................SHUT IN TIME i SHUT IN PRESSURE 3.0 min i .................... ~ ................. ~ ................... r .............................................................. ~ .................... i 0.0min i i 810psi. 4.0min l ; .......................................................... ~ ......................................... ; .................... i 1.0min i i 800 psi ~ ................... ~ .................... -f ................... : [ 2.0min i i 800 psi l .... .... 1 .................... .... .... i--:-~:~-rgi~-'--i" ................... i-'-~iiii-iiii .... I' ............. -I ................... ~r .................. , ~ 5.0min i i 790 psi l ~ ................. .i .................. -,- .................... , i 6.0min i i 790 psi i 7.0min ~ ~ 790 psi ................. I- .............. ,'I'- .............. ; .... t 9.0rain i i 790 ps, ............... 1 .................. .-i- .................... · : 10.0min i i 790 psi ...... p_._.o..mj.n. ......................... i .................... 6.0 min [ i ..... flb"~;~ ......................... ~ .................... l ..... ~'Tb-~ii .... l .................... [ .................... i 9.0 min i ! l ..... :fE-b--FfiiF-~- .................... ! .................... ..................... -I', .................... f .................... 'I , 15.0 min , i i l .... ~;~",Bih--'T .................... [ .................... i ~ .... ~'E'b-';'f,]i?'-T .................... [ .................... i ..... .3.o_...o..~j.n....i .................... [ .................... NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: T© CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Maximum Pressure @ The Shoe 1C-27 Surface Casing: Size 9-5/8 Weight 40# Grade L-80 Shoe Depth 6,916' MD / 4,547' TVD Burst (100%) 5,750 psi Burst (85%) 4,887 psi Assumptions: Water on Backside of 9-5/8" (Worst Case) 1,500 psi Maximum Injection Surface Pressure Maximum Mud Weight Required to Drill 1C-Pad West Sak Wells = 9.8 ppg Maximum Fluid Density to Burst 9-5/8" Casing: 4,887 psi + 8.3 ppg (.052) (4,547') = 1,500 psi + MW (.052) (4,547') MW = 22.62 ppg Maximum Pressure on 9-5/8" Shoe: Max Pressure = 1,500 psi + 9.8 ppg (.052) (4,547') - 8.3 ppg (.052) (4,547') Max Pressure - 1,500 psi + 2,317 - 1,962 Max Pressure = 1,855 psi Maximum Fluid Density to Collapse 7" Casinq 1C-27 Casin.q: Size Weight Grade Shoe Depth Collapse (100%) Collapse (85%) Assumptions: 11 26# L-80 10,787' MD / 6,403' TVD 5,410 psi 4,598 psi 9-5/8" Casing Shoe @ 4,547' TVD Inside 7" Casing - Diesel from 2,400' TVD to Surface (6.7 ppg) Inside 7" Casing - Seawater from 4,547' TVD to 2,400' TVD (8.4 ppg) Maximum Fluid Density to Collapse 7" Casing: 4,598 psi + 6.7 ppg (.052) (2,400') + 8.4 ppg (.052) (4,547' - 2,400') = 1500 + MW (.052) (4,547) MW = 20.61 ppg ARCO Alaska, Inc. Casing Detail 9.625" Surface Casina Subsidiary of Atlantic Richfield Company WELL: 1 C-27 DATE: 05/28/99 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LR = 34.60' TOPS Above RKB 9 5/8" Landing Joint 33.35 FMC GEN V- Kuparuk 9 5/8" Csg Hgr 1.34' up 1.62 33.35 jts156-180 9 5/8", 40.0#, L-80 BTC-MOD (25 jts) 954.82 34.97 TAM 9 5/8" Port Collar 2.62 989.79 its. 2+4-155 9 5/8", 40.0#, L-80 BTC-MOD (~153 jts~) 5840.45 992.41 Gemeco Float Collar 2.35 6832.86 its 1 & 3 9 5/8", 40.0#, L-80 BTC-MOD (~2 jts~) 78.25 6835.21 Gemeco Float Shoe 2.50 6913.46 Casing shoe @ 6915.96 T.D. @6925' leaving-9' of rathole 24 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1, 3 over stop collars and over casing collars on Jts. 2 & 4 thru 23 and over collar of it. 179 Run 1 ROTCO Rigid Straight Blade Centralizer on joints 155 and 156 Remarks: String Weights with Blocks: 350k Up, 155k Dn, 68k Blocks. Ran 180 joints of casing. Drifted casing with 8.679" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Pool 6 Drilling Supervisor: R, W. SPRINGER ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company Casing Detail 7" 26# Ca$ina WELL: 1C-27 DATE: 06/01/99 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LDS = 30.93' TOPS 7" Landing Joint 30.93 7" FMC GEN V FLUTED MANDREL HANGER 1.88 30.93 jts 3-262 7", 26#, L-80 BTC-MOD (260 jts) 10665.59 32.81 Gemeco Float Collar 1.32 10698.40 its 1-2 7", 26#, L-80 BTC-MOD (2 jts) 86.18 10699.72 Gemeco Float Shoe 1.47 10785.90 BTM OF SHOE @ 10787.37 T.D. @ 10797' leaving 10' of rathol~ 10787.37 25 Gemeco Bow Spring CENTRALIZERS _ Run on stop clrs jt.s. 1&2, o.n clrs its 3-25 .. Remarks: String Weights with Blocks: 300k Up, 150k Dn, 70k Blocks. Ran 262 oints of casing. Drifted casing with 6.151" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Pool 6 Drilling Supervisor: FRED HERBERT / RICK OVERSTREET ARCO Alaska, Inc. Liner Detail 4.5" Slotted Production Liner Subsidiary of Atlantic Richfield Company WELL: 1C-27 DATE: 06/17/99 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Pool 6 RT to LDS = 30.00' TOPS C-2 Neutralizer Setting Tool 11.17 Top of Liner Hanger @ 10528.73 Packer BAKER 7"x 4.5" FAB PACKER w/X-nipple & Plug in tail pipe** 5.17 10528.73 Packer BAKER 7"x 4.5" SLZXP LT PACKER & w/12' Tie Back Sleeve * 21.95 10533.90 Hanger BAKER 5" Butt HMC HANGER 6.64 10555.85 Pup it. 4.5", 12.6#, ABT-MOD 5.80 10562.49 35 Jts 4.5", 12.6#, ABT-MOD Slotted Liner 1121.21 10568.29 15 its. 4.5", 12.6#, ABT-MOD Solid Liner 476.06 11689.50 53 Jts. 4.5", 12.6#, ABT-MOD Slotted Liner 1697.90 12165.56 4.5" 12.6# ABT-MOD Pack off Bushing 1.31 13863.46 1 Jr. 4.5", 12.6#, ABT-MOD Solid Liner 40.23 13864.77 4.5" ABT-MOD Guide Shoe 1.96 13905.00 13906.96 Note* 1st Packer on liner leaked. · * Landed minus 1' space out Note: These depth's are by DP measurement's Remarks: String Weights with Blocks: 165k Up, 120k Dn, 70k Blocks. Ran 104 joints of liner. Drifted casing with 3.833" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Pool 6 Drilling Supervisor: Rick Overstreet ARCO Alaska, Inc. Cementing Details We;I Name: 1C-27 Report Date: 06/03/99 Report Number:. 2 Rig Name: Pool 6 AFC No.: AK0024 Field: - Casing Size Hole Diameter. Angle thru KRU: Shoe Depth: LC Depth: % washout: 7' 10,787' 10,698 Centralizers State type used, intervals covered and spacing Comments: Run 1 bow spring centralizer per Joint for Joints 1-25 Mud Weight: PV(prior cond): PV(affer cond): I YP(prior cond): YP(after con(I): Comments: · 11.0 26 27I 36 20 · ' Gels before: Gets after:. Total Volume Cimulated: 15/22 6/8 1254 bbls .:. · Wash 0 Type: Volume: Weight: c~;mmentsi ' '. :: ARCO 20 6.a6 ~:el~.. =:.0 :.: ii.i:' I: Type: Volume: Weight: .Co~nments: ...' :i .'=.:'i;.i. ::"; !i =[:~ · ARCO B45 40 12.0 Comments:·Lead Cement'::!O: :: '::':'i : 'i: '::~" ' ' Type:....::'. ::i '~:. :.:. · ..' '. ': ' IMix wtr temp: No. ofSacks: [ Weight: Yield: ~i' ::.'~::'" ....:. ;'i' : .': .::,. · ' : ?i! ": Additives: .. · . :. · .=~ ...:... · . . · :..:: :::.: .: .. : .. .... ~ali :c:~ment.: 0:i; :ii:;::i'. ;;.' ': :: ': :..'! .:;. Type: Mix wtr temp: No. of Sacks: Weight: Yield: comments: =: i.."'..: .i :..::: ::!::.i G 70 173 15.8 1.21 :i .;! ii!' ?: :~i: ;:' ?.!i Additives: ...~... :.. :. · . . .: :: .~ .~ .:. :.:. ':: i:~i!: i:." :.' '. ' · ::' ' :' .~i !;i' !;i :i. i :;; ::.. Class 'G' w/3% DS;), 0.6% D6S, 0.130% DS00, 0.80% S001, 0.2 gal/ak 047, 0.1 gal/ak D135, 2.0 gal/ak D600 DisPlacement' =0 ::i :i' i~:::.' ':'"~'? Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: ~m~r~ts: . .: ~ i:~: ~;.:." i'll!i;..:: ¥' 6 bpm 2 bpm 300k :.:: i i Reciprocation length: Reciprocation speed: Str. Wt. Down: 20 15 fpm 150k .... i~:i. il i!' ii ii ~ ' . .: 'i i' .::. :..:: '...':..;.;" Theoretical Displacement: Actual Displacement: Str. Wt. in mud: ?!i.":::i=. [ii :::i ,:.: ...;!::. :.::i ii ~.::. ':::~.':i .' :!: ::'" ..." 399 bbls 461 bbla (see remarks) Calculated top of cement': CP: Bumped plug:. Floats held: 9987' Date: 06/03/99 yes yes 'i3me:05:25 Remarks:Casing went bottom & circulated with no problems. Pumped 20 bbls wash, 40 bbls Arco Spacer, 37.5 bbls 15.8 cement & Displaced with rig pumps. At calculated displacement (by strokes) It was determined that the mud pumps were not operating at the expected output as the pressure build wee not enough, casing on vacuum. The plugs were confirmed to have left the head. Continued pumping until bumping the plug 62 bbls over by the etrokes. Reclp ceslng until within 100 strokes of bumping plugs (calculated). ! ICement Company: Rig Contractor: Approved By: DS POOL Fred Herbert / Rick Overstreet ,41l, ARCO Alaska, Inc. Cementing Details Wall Name: lC-27 Report Date: 05/28/99 Report Number. 1 Rig Name: Pool 6 AFC No.: AK0024 Field: KRU 9-5/8' 40# L-80 BUT-MOD 12-114' n/a 6916 MD Centralizers State lype used, intervals covered and spacing Comments: Run centralizers In center of Jts. 1, 3 over atop collars and over casing collara on Jts. 2 & 4 thru 23 and over collar of it. 179. 24 Gemeco Bow Spring CENTRALIZERS & 2 Straight Run I ROTCO Rigid Straight Blade Centralizer on Joints 155 and 156. Blade Centralizers. . ~ · MUd Weight: PV(prior cond): Pr(after cond): YP(prior cond): YP(after cond): comments: 10.3 42 24 56 26 .. · Gels before: Gels after. Total Volume Circulated: · i · · 23/48 10/16 1215 bbla Wash: 0 '. ::::" II== Type: Volume: Weight: Comments::" i' ': ': :" i ':: .:::: ARCO B47 19 bbls 8.3 PPg · ..: . · .: · SPacer: '..'Oii: :' .. ::..'::: :?.' ::i: ':: Type: Volume: Weight: Coi-nnients: ~: .:.'. · .:'..: :... i ARCO B45 60 10.7 ppg :L~d'C~men,' :~O ' i ~. i':;i'i' :~;' i'::" Type: I Mixwtrtomp: No. of Sacks:I Weight: Yield: i~omme~ts:il .:. ': ~:~ :i ..... :i '::~': :~i ~.i::.:~:; ':~:.: ;ii AS III Ute 70 822 10.7 ppg 4.43 Additives: 50% D124, 9.0% D44, 0.4% D46, 30°/. D53,1.5% S1 & 1.5% D79 :~<~n~eht~: :~': !i .;; ;' ~ ::.::! !. ::: .:!:!i:::i:: 70 663 15.8 ppg 1.17 :. ~:..;: .:...... . · .. ~.. .". ~'.. :i: :.~ii::' '::: G ................. 1% 81, 0.2% D45, & 0.111% DSS. isia~ii~meht.: !.O::.' :! .ii ii~ 'iii iii;! :~;:~:~ii Reta{before tail at shoe): Rata{tall eround shoo): Str. Wt. Up: Fl~iproeatlon length: Ro~ipre~ation speed: Sir. Wt. Down: ':' :: : 10' 10ft/mln 175k Theoretical Displacement: Actual Displacement: Str. Wt. In mud: i: :i 5820 stke 5924 stk~ Calculated top of cement: CP:. Bumped plug: Floats held: surface Date:5/28/99 NO Y ES Time:13:30 Remarks:Reciprocate casing until 1000 strks Into rig displacement then landed In hanger. Pulled up 1' to allow cmt flow thru tlutes on hanger. Could not get casing to land back on hanger upon slack off. Overdlsplaced by 3 bbls on top of plug and 3 bbls of shoe volume-did not see plug bump. Held 1200 psi on cig for two hours. Floats Held. i ICement Company: DS Rig Contractor: POOL Approved By: Scott Reyno ds / Ray Springer CASING TEST and FORMATION INTEGRITY TEST Well Name: 1C-27 Date: 5/30/99 Supervisor: Springer/Reynolds Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40# L-80 BTC Casing Setting Depth: 6,916' TMD 4,551' TVD Mud Weight: 8.4 ppg Hole Depth: 6,945' TMD Length of Open Hole Section: 4,562' TVD 29' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 1,330 psi + 8.4 ppg 0.052 x 4,562' EMW for open hole section = 14.0 ppg Pump output = 0.0846 bps Fluid Pumped = 2.6 bbl 3.200 psi 3.100 psi 3.000 psi 2.900 psi 2.800 psi 2.700 psi 2,600 psi 2,500 psi 2.400 psi 2,300 psi 2,200 psi 2,100 psi 2.000 psi 1.900 psi 1.800 psi 1.700 psi 1.600 psi 1.500 psi 1.400 psi 1.300 psi 1.200 psi 1.100 psi 1.000 psi 900 psi 800 psi 700 psi ~ psi 500 psi - - · 400 psi 300 psi 200 psi 100 psi 0 p~ I, l."'l'"l"'l'"l'" l'" --e----e--LEAK-OFF TEST ....... ' , ~ --, I , l, ,- -1 ....... i ~ CASING TESTI I j iT,ME LINE : J ~-J ~--->~:,'~' LOT SHUT IN TIME I I I I I/I I I I I°NE MINUT,E TICKS I I I H ~,~ CASING TEST SHUT IN TIME J .~.- i~?' ..... J'":--T7 J H` TIMELINE I ' 't"-_-?-.F-'.: STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE i ~;~i' .................................. ~' ............ '"" ............... , ............... , ............ :___j ................ L._§..s.!_k.s. .... L___?__s_°..P._S:.__~ j. 10 stks L 450 psi .j [ 10 stks j 500 psi ............... i ............... i · i ............... i ................ ~ ............ %--- ............... l 15stks I 675 psi I [ 15stks 690p_s}___.j , 20 stks 950 psi ............... -"J ............................... 25 stks J 1,120 psi J jr ............... ,[ ................ 25 stks " .............. 1,150 psi;-...~. I 30stks j 1,300psi j : 30stks 1,360psi , : 31stks i 1,330 psi j I i i i r .............. -r ............... ~' ................ '1 ! ! ! ! , ! ! ! ! ............... -;- ............... t' ................ '1 , , i i , r ............... ~ ............... ~ ................ 1 ................ ? ............... ? ................ i i i i ................ ? ............... ? ................ ! I I I I ................ I- ............... I- ................ i I i , ,' ............... ~ ............... ~ ................ I i ............... r ................ r .............. I 35 stks 1,600 psi ; : 40 stks 1,850 psi i ............... ..... i ! i , 50 stks , 2 300 DSl , ............... I- ................ ,,..._2_ ..... ~ .... q ............... i_._s__s.__~_t_k~ ...... _2_,Eo_9_~L_i ............... i___?_o._?.t_k~ ...... _2_,~_o_9__e~[__j ............... ! i i i / _i i i i i i i i i i i SHUT IN TIME J SHUT IN PRESSURE 0.0 minj 3,000ps~ I ' i j 1.0min : 2,970 psi : ' SHUTIN TIME i SHUT IN PRESSURE : 3.0 mini 2,945 psi , 0.0 min ~ 1,330 >si i 4.0 minj 2,940 psi i 2.0 mini 1,330 ~si i 6.0 min i 2,935 psi i 3.0 min i ""Eb"~[,~"-[ .................. 'q--~:b-'~;[~--r ................... ~-,~,~-i;~;i'-~ ""~§~"r~[~"[ ................ 2,925 psi r 20.0 min 25.0 min ' I I ' _3..o_.o._.m_.p._.~ ................ NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1C-27 Date: 5/30/99 Supervisor: Scoff Reynolds Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40# L-80 BTC Casing Setting Depth: 6,916' TMD 4,551' TVD Hole Depth: 10,097' TMD 6,250' TVD Mud Weight: 9.3 ppg Length of Open Hole Section: 3,181' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 1,050 psi + 9.3 ppg 0.052 x 6,250' EMW for open hole section = 12.5 ppg Pump output = 0.0846 bps Fluid Pumped = 6.4 bbl 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi o TIME LINE ,, ~ STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ................... ........ ..... 4 stks 175 psi ................... ..8_.s__t.k_.s_ ...... J__9_.o_._p._s_i__. .................. j_2__.s. Lk_.s' ..... .2_.s_.o_._p._s_~ .... .................. j .6_ _ _s. t_ .k_ .s_ ..... .3_.7__S_._p._s_i .... .................. _2_.O___s. Lk_.s_ ..... .4_.7_.S_._R_s_i .... ................. .2_.S___s.t__k..s_ .... .S_.8_.O_._p._s_~ .... ................. .3_.O___s.t__k..s_ .... Z!.O_._p._s.i__j ................. .~_.5__.s_t_.k..s_ .... .8_!_O_.R_s_i___~ ................. .4_.O__.s_t__k..s_ .... .9..l_.O_._p._s_i__j 45stks 1,000psi J L. .............. ..~ ............... .J ................. .................. .4_ .S_ _ .s. t_ _k. .s_ .... .1_,.9.0_.5__R.s_i_ j 47stks 1,010psi J ~ .............. .J ............... J ................. .................. .4_~_.s.t__k..s_ .... _b.9~.o__R.s_i_.~ .................. .4_ ~_ _s. t_ .k_ .s_ .... .b._o.4_.o__R.s.i.. ~ .................. _5_ _O_ _ _s. t_ .k_ .s_ .... .1_,.9.5..0__ p_.s_i_. ~ .................. _sJ _.s.!.k_.s_ .... .b._o.s_.o__R.s_i_. ~ 52stks 1,000psi ~ 54 stks 990 psi ~ 62 stks 890 psi ................... ?_ .s_s_Lk s__ ..... .8.8_0._£_sJ ..... 76 stks 880 psi SHUT IN TIME SHUT IN PRESSURE .___o:_o____m_i_n__ ..................... _8_.8_.O__p__sj__. ~.._l__._O____m_i_n_ ...................... .8_.l_.O_..p~.s.i .... .___2:_O_._m..i_n__ ..................... .7..7..O.._p._s_i .... .___3:_O___m_i_n__ ..................... .7_.6_.0_. _p.s__i .... .___4:_O___m__i_n__ ..................... .7_ .4_ .0_..p..s.i .... .___5:_O_..m__i_n__ ..................... .7_.2_.O.._p._s_i .... .___6_._O____m_i_n__ ................... .7_.l..O_._p._s_i .... _?:_o____m_i_n___/ .............. /__Z.o_9_.R_s_i___j L ___8:_O___m__i_n___ L .............. .,,_ _.7_.0_.0...p.s..i__j 9.0min J J 700 psi J L.... .......... ,...............,............ .... j_9:_o__m._i_n__£ .............. j___.7_.o_.o_.R_sj___ [ CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ~ 0.0 min i 0 psi 1 0 min i ..... '_ ......... ~- .............. -~- ............... 2.0 min 3.0 min 4.0 min 5.0 min 6.0 min 8.0 min 9.0 min ................................................ 10.0 min 20.0 min ' ' NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ARCO Alaska, Inc. ALPINE DISBURSEMENT ACCOUNT CHECK,~.. 2490032 10 P.O. Box 103240 Anchorage, AK 99510-3240 PAY TO THE ORDER OF: APRIL 9, 1999 The First Nati°n~li.~n.k:of Chicago-0710 ChicagO~ ::t I:l~i no i s Payable Thr0ugh~:Republic Bank Shelbyville, Kentucky 73-426 839 0990337 ALASKA DEPT OF REVENUE ..... '" ::' ALASKA OIL & : GAS: 'CONSERVATION COMMI :::. 3001 PORCUPINE 'DRIVE ~.: . *~ ?.:VOID:i'AFTER 90 DAYS *** ' :: :' .. :-.*..j :.. --.: ::i ':'::' : '::' i :: ':!: ': '~::!! '!: .... ::: " .: ~ ~: :: EXACTLY ***********'100 DOLLARS AND O0 CENTS ,~*********** 100.00 TRACE NUMBER: 249003210 WELL PERMIT CHECKLIST COMPANY ,~/"~_..,~-~_ WELL NAME, ..~?e_/..~ .,)z~--.2 7 PROGRAM: exp_ FIELD & POOL ~ ~;>4::~/~>c"3 INIT CLASS ,_~;Z~' ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor stdng provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive hodzons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to 5(~3C) psig. GEOL AREA ~N ¥ N ¥ N ¥ N ¥ N ¥ N g N ¥ N dev ~ redrll~ serv APPR DATE 27. Choke manifold complies w/APl RP-53 (May 84) ........ ¢,~ N 28. Work will occur without operation shutdown ........... ~ N 29. Is presence of H2S gas probable ................. Y (~ ~ Permit can be issued w/o hydrogen sulfide measures ..... Y~NNI~Y N~/ ,,~,~ 31. Data presented on potential overpressure zones ....... Y " 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratory ~y] Y N GEOLOGY R DAT'Ej ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... Y to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N G EOL(j},G..Y: ENGINEERING: UIC/Annular COMMISSION: BE~-~ wa DWJ ~. JDH ,,..- ' RNC - co (~ ~/j~/? ~. APPR DATE Comments/Instructions: __ wellbore seg ~ ann. disposal para req ~ UNIT# ./'./..,),~'~ ON/OFF SHORE ~._~ O O Z c:\msoffice\wordian\diana\checklist 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 APPENDIXi No Special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Nov 01 09:23:21 1999 Reel Header Service name ............. LISTPE Date ..................... 99/11/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/11/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record tAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MM-90124 A. PIEPER R. SPRINGER 1C-27 500292294300 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 29-OCT-99 MWD RUN 6 AK-MM-90124 A. PIEPER F. HERBERT MWD RUN 7 AK-MM-90124 M. HANIK F. HERBERT JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 7 AK-MM-90124 M. HANIK F. HERBERT 12 lin 10E RECEIVED I,!OV 04 1999 Alaska 011 & Gas Cons,. Canmis~lon AnYone FNL: 1710 FSL: FEL: FWL: 1352 ELEVATION (FT FROM MSL 0) KELLY BUSHING: 95.10 DERRICK FLOOR: 95.10 GROUND LEVEL: 60.20 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 16.000 115.0 2ND STRING 12.250 9.625 6915.0 3RD STRING 8.500 7.000 10787.0 PRODUCTION STRING 6.125 13910.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 THROUGH 3 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 5,6, AND 7 ARE DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 {EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). 5. A MEASUREMENT AFTER DRILLING (MAD) PASS WAS PERFORMED OVER THE INTERVAL 10965'MD, 6408'TVD TO 13910'MD, 6411'TVD WHILE PULLING OUT OF THE HOLE FOLLOWING MWD RUN 7. THIS DATA IS PRESENTED AS A TAIL TO THE LOG. 6. SLD DATA FROM 13284'MD, 6401'TVD TO 13845'MD, 641t'TVD IS CONVENTIONAL BULK DENSITY, PHOTOELECTRIC EFFECT, AND STANDOFF CORRECTION. THE SLD RAPID SAMPLE MEMORY FILLED BEFORE COMPLETION OF THE BIT RUN. 7. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E MAIL FROM D. SCHWARTZ OF ARCO ALASKA, INC. ON 10/26/99. THIS DATA IS PDC. 8. MWD RUNS 1-7 REPRESENT WELL 1C-27 WITH API%: 50-029-22943-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13910'MD, 6411'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. CURVES WITH THE SUFFIX "M" DENOTE MAD PASS DATA. TNPS = SMOOTHED COMPENSATED NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE). SBU2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). POROSITY LOG PROCESSING PARAMETERS: HOLE SIZE: 6.125" MUD WEIGHT: 10.5-10.8 PPG MUD SALINITY: 54000 - 60000 PPM CHLORIDES FORMATION WATER SALINITY: 13000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP PEF NCNT FCNT NPHI FET RPD RPM RPS RPX DRHO RHOB $ START DEPTH 6800.0 6925 0 10777 0 10777 0 10777 0 10777 0 10777 0 10777 0 10777 0 10777 0 10777 0 10788 0 10788 0 STOP DEPTH 13867.5 13909.5 13845.5 13829.5 13829.5 13829.5 13874 5 13874 5 13874 5 13874 5 13874 5 13845 5 13845.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA {MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 4 6925.0 10797.0 6 10797.0 11912.0 7 11912.0 13910.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD API 4 1 68 ROP MWD FT/H 4 1 68 RPD MWD OHMM 4 1 68 NPHI MWD PU 4 1 68 FET MWD HOUR 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 ' 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT GR ROP RPD NPHI FET RPX RPS RPM FCNT NCNT RHOB Min 6800 27.57 0 36 1 29 17 04 0 32 0 12 0 14 1 47 156 35 13499.4 1.62 Hax 13909.5 518.4 2880.81 1969.43 50.23 124.5 1300.08 1485.16 2000 745.59 30616.2 4.16 Mean Nsam 10354.8 14220 110.49 14136 119.41 13970 14.0237 6196 27.2999 6106 3.42481 6196 9.33473 6196 11.153 6196 14.0937 6196 417.242 6106 23676.3 6106 2.35918 6138 First Reading 6800 6800 6925 10777 10777 10777 10777 10777 10777 10777 10777 10639 Last Reading 13909 5 13867 5 13909 5 13874 5 13829 5 13874 5 13874 5 13874 5 13874 5 13829 5 13829 5 13845 5 DRHO 0 1.69 0.0696485 6116 PEF 0.61 14.14 2.15409 6138 10788 10777 13845.5 13845.5 First Reading For Entire File .......... 6800 Last Reading For Entire File ........... 13909.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR RAT $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: .5000 START DEPTH 10965.0 10965 0 10965 0 10965 0 10965 0 10965 0 10965 0 STOP DEPTH 13876.0 13876.0 13876.0 13876.0 13876.0 13869.0 13909.5 MAD RUN NO. MAD PASS NO. MERGE TOP 7 10965.0 MERGED MAD PASS. $ MERGE BASE 13910.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MAD AAPI 4 1 68 RAT MAD FT/H 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHMM 4 t 68 RPM MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 FET MAD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 10965 13909.5 12437.2 5890 GR 37.81 195.21 79.904 5809 RAT 0.52 6300.59 352.042 5890 RPX 1.22 25.05 4.52744 5823 RPS 1.8 44.7 6.66001 5823 RPM 1.61 130.96 8.30926 5823 RPD 1.56 49.67 9.76921 5823 FET 16.74 134.97 87.3555 5823 First Reading 10965 10965 10965 10965 10965 10965 10965 10965 Last Reading 13909.5 13869 13909.5 13876 13876 13876 13876 13876 First Reading For Entire File .......... 10965 Last Reading For Entire File ........... 13909.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6800.0 RO? 6925.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10744.0 10795.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: 01-JUN-99 INSITE 3.2.(UPGRADE 3) CIM 5.46/ EWR 1.34/ SLD 10.87 MEMORY 10797.0 6925.0 10797.0 55.3 85.8 TOOL NUMBER P1305HG6 8.500 8.5 LSND 11.10 48.0 8.5 35O 3.8 .000 .000 .000 .000 50.0 # Dat MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ a Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 6800 10795.5 8797.75 7992 6800 GR 27.57 518.4 136.573 7889 6800 ROP 0.97 2880.81 152.726 7742 6925 Last Reading 10795.5 10744 10795.5 First Reading For Entire File .......... 6800 Last Reading For Entire File ........... 10795.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10744 5 PEF 10777 0 NCNT 10777 0 FCNT 10777 0 NPHI 10777 0 FET 10777 0 RPD 10777 0 RPM 10777 0 RPS 10777 0 RPX 10777 0 DRHO 10788 0 RHOB 10788 0 ROP 10796 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11869 5 11847 5 11831 5 11831 5 11831 5 11876 5 11876 5 11876 5 11876 5 11876 5 11847.5 11847.5 11912.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: 09-JUN-99 INSITE 3.2.(UPGRADE 3) CIM 5.46/ EWR 1.34/ SLD 10.87 MEMORY 11912.0 10817.0 11912.0 84.6 92.3 TOOL NUMBER P1321NLM4 P1321NLM4 P1321NLM4 P1321NLM4 6.130 6.1 BARADRIL-N MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 10.50 50.0 8.8 3.2 .100 .055 .060 .340 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 API 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 RPX MWD 6 OHMM 4 1 68 12 4 RPS MWD 6 OHMM 4 1 68 16 5 RPM MWD 6 OHMM 4 1 68 20 6 RPD MWD 6 OHMM 4 1 68 24 7 FET MWD 6 HRS 4 1 68 28 8 NPHI MWD 6 PU-S 4 1 68 32 9 FCNT MWD 6 CNTS 4 1 68 36 10 NCNT MWD 6 CNTS 4 1 68 40 11 RHOB MWD 6 G/CM 4 1 68 44 12 DRHO MWD 6 G/CM 4 1 68 48 13 PEF MWD 6 BARN 4 1 68 52 14 50.8 First Name Min Max Mean Nsam Reading DEPT 10744.5 11912 11328.2 2336 10744.5 GR 40.82 167.3 84.4864 2251 10744.5 ROP 0.36 2268.11 65.1225 2233 10796 Last Reading 11912 11869.5 11912 RPX 0.12 1300.08 8.79399 2200 RPS 0.14 1485.16 10.804 2200 RPM 1.47 2000 20.2916 2200 RPD 1.29 1969.43 20.0983 2200 FET 0.41 124.5 4.85083 2200 NPHI 17.75 50.23 27.4378 2110 FCNT 156.35 698.27 408.623 2110 NCNT 13499.4 30546.3 22968.7 2110 RHOB 2.05 4.16 2.38415 2120 DRHO 0 1.69 0.0740566 2120 PEF 1.38 14.14 2.20833 2142 10777 10777 10777 10777 10777 10777 10777 10777 10788 10788 10777 11876 5 11876 5 11876 5 11876 5 11876 5 11831 5 11831 5 11831 5 11847 5 11847 5 11847 5 First Reading For Entire File .......... 10744.5 Last Reading For Entire File ........... 11912 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 11832.0 13830.0 FCNT 11832.0 13829.5 NPHI 11832.0 13829.5 PEF 11848.0 13845.5 DRHO 11848.0 13845.5 RHOB 11848.0 13845.5 GR 11870.5 13867.5 FET 11877.5 13874.5 RPD 11877.5 RPM 11877.5 RPS 11877.5 RPX 11877.5 ROP 11913.5 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION {DEG MINIMUM ANGLE: MAXIMUM ANGLE: 13874.5 13874.5 13874.5 13874.5 13909.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 15-JUN-99 INSITE 3.2.(UPGRADE 3) CIM 5.46/ EWR 1.34/ SLD 10.87 MEMORY 13910.0 11912.0 13910.0 87.6 94.5 TOOL NUMBER P1321NLM4 P1321NLM4 P1321NLM4 P1321NLM4 6.130 6.1 BARADRIL-N 10.60 48.0 9.6 4.0 .O8O .044 .060 .260 55.7 .6 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 7 FT/H 4 1 68 4 2 GR MWD 7 API 4 1 68 8 3 RPX MWD 7 OHMM 4 1 68 12 4 RPS MWD 7 OHMM 4 1 68 16 5 RPM MWD 7 OHMM 4 1 68 20 6 RPD MWD 7 OHMM 4 1 68 24 7 FET MWD 7 HOUR 4 1 68 28 8 NPHI MWD 7 PU-S 4 1 68 32 9 FCNT MWD 7 CNTS 4 1 68 36 10 NCNT MWD 7 CNTS 4 1 68 40 11 RHOB MWD 7 G/CM 4 1 68 44 12 DRHO MWD 7 G/CM 4 1 68 48 13 PEF MWD 7 BARN 4 1 68 52 14 Name Min DEPT 11832 ROP 1.24 GR 42.68 RPX 2.92 RPS 3.4 RPM 3.54 RPD 3.44 FET 0.32 NPHI 17.04 FCNT 268.29 NCNT 19746.4 RHOB 2.04 DRHO 0 PEF 0.61 Max 13909.5 2013 43 139 34 1147 22 1148 27 63 39 42 79 49 57 36 84 745 59 30616.2 2.93 0.47 5.4 Mean Nsam 12870.8 4156 85.1865 3993 73.6423 3995 9.63393 3995 11.347 3995 10.6832 3995 10.6811 3995 2.63638 3995 27.2271 3996 421.793 3996 24050.2 3997 2.34949 3996 0.0673098 3996 2.12501 3996 First Reading 11832 11913 5 11870 5 11877 5 11877 5 11877 5 11877 5 11877 5 11832 11832 11832 11848 11848 11848 Last Reading 13909 5 13909 5 13867 5 13874 5 13874 5 13874 5 13874 5 13874 5 13829 5 13829 5 13830 13845.5 13845.5 13845.5 First Reading For Entire File .......... 11832 Last Reading For Entire File ........... 13909.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 7 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 10964 5 10965 0 10965 0 10965 0 10965 0 10965 0 10965 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED {RPM): HOLE INCLINATION {DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13869 0 13876 0 13876 0 13876 0 13876 13876 13909 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ 15-JUN-99 INSITE 3.2.(UPGRADE 3) CIM 5.46/ EWR 1.34/ SLD 10.87 MEMORY 13910.0 11912.0 13910.0 87.6 94.5 TOOL NUMBER P1321NLM4 P1321NLM4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.130 6.1 BARADRIL-N 10.60 48.0 9.6 4.0 .O8O .044 .060 .260 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MAD 7 API 4 1 68 4 2 RAT MAD 7 FT/H 4 1 68 8 3 RPX MAD 7 OHMM 4 1 68 12 4 RPS MAD 7 OHMM 4 1 68 16 5 RPM MAD 7 OHMM 4 1 68 20 6 RPD MAD 7 OHMM 4 1 68 24 7 FET MAD 7 HOUR 4 1 68 28 8 55.7 First Name Min Max Mean Nsam Reading DEPT 10964.5 13909.5 12437 5891 10964.5 GR 37.81 195.21 79.9117 5810 10964.5 RAT 0.52 6300.59 352.042 5890 10965 Last Reading 13909.5 13869 13909.5 RPX 1.22 25.05 4.52744 5823 RPS 1.8 44.7 6.66001 5823 RPM 1.61 130.96 8.30926 5823 RPD 1.56 49.67 9.76921 5823 FET 16.74 134.97 87.3555 5823 10965 13876 10965 13876 10965 13876 10965 13876 10965 13876 First Reading For Entire File .......... 10964.5 Last Reading For Entire File ........... 13909.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/11/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 99/11/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File