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Home My WebLink About203-216Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/22/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221122-1 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# SRU 213-15 50133206520000 215100 6/24/2022 Yellowjacket PERF KBU 33-06X 50133205290000 203183 6/26/2022 Yellowjacket PERF BCU 7A 50133202840100 214060 6/28/2022 Yellowjacket GPT-PERF END 3-17F 50029219460600 203216 7/2/2022 Yellowjacket PERF-RETAINER KBU 32-08 50133206240000 214014 7/12/2022 Yellowjacket PERF BCU 7A 50133202840100 214060 7/15/2022 Yellowjacket GPT-PERF SRU 213-15 50133206520000 215100 7/19/2022 Yellowjacket GPT-PLUG MPU I-17 50029232120000 204098 7/19/2022 Yellowjacket TUBING CUT CLU 05RD 50133204740100 215160 7/21/2022 Yellowjacket PLUG CLU 10 50133205530000 205106 7/21/2022 Yellowjacket RCT-JET CUT SRU 213-15 50133206520000 215100 7/22/2022 Yellowjacket PERF Please include current contact information if different from above. By Meredith Guhl at 8:52 am, Nov 23, 2022 T37295 T37295 T37295 T37296 T37297 T37297 T37298 T37299 T37300 T37301 T37302 END 3-17F 50029219460600 203216 7/2/2022 Yellowjacket PERF-RETAINER Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.23 09:08:15 -09'00' By Anne Prysunka at 1:20 pm, Aug 04, 2022 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:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: END 3-17F (PTD# 203-216) RWO Production Casing Repair Date:Monday, July 18, 2022 4:38:34 PM Attachments:image002.png image003.png DIU 3-17F (PTD 2032160) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Monday, July 18, 2022 4:11 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: OPERABLE: END 3-17F (PTD# 203-216) RWO Production Casing Repair Mr. Regg, END 3-17 (PTD# 203-216) was a Produced Water Injector that was designated NOT OPERABLE after a failing MIT-IA and identification of two production casing leaks in May 2021. A recent RWO and conversion to a Producer has been completed with a 7” tie back being ran and cement to surface and new completion installed. A passing CMIT-TxIA to 2500 psi on 7/13/2022 and MIT-IA to 2500 psi on 7/16/2022 confirm two competent barriers to formation. The well is now reclassified as OPERABLE. Please respond with any questions or comments. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not anintended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this messageand any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checksas it considers appropriate. Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 07/11/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes BCU 18RD 50133205840100 222033 6/11/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/18/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/7/2022 Yellowjacket GPT-PLUG + Report BCU 24 50133206390000 214112 6/16/2022 Halliburton PPROF BCU 24 50133206390000 214112 5/23/2022 Yellowjacket GPT-PERF + Report BCU 24 50133206390000 214112 5/26/2022 Yellowjacket GPT-PERF + Report BCU 7A 50133202840100 214060 6/21/2022 Yellowjacket CBL BCU 7A 50133202840100 214060 6/15/2022 Yellowjacket GAMMA RAY + Report BRU 232-26 50283200770000 184138 5/25/2022 Yellowjacket CBL CLU 01RD 50133203230100 203129 5/19/2022 Yellowjacket PERF + Report CLU 01RD 50133203230100 203129 5/24/2022 Yellowjacket PERF + Report CLU 09 50133205440000 204161 5/27/2022 Yellowjacket PERF + Report CLU-1RD 50133203230100 203129 5/28/2022 Halliburton PPROF + Report END 1-17A 50029221000100 196199 5/26/2022 Halliburton LDL END 1-45 50029219910000 189124 5/23/2022 Halliburton LDL + Report END 3-17F 50029219460600 203216 6/15/2022 AK E-Line PLUG CUT FALLS CREEK 3 50133205240000 203102 6/4/2022 Yellowjacket PERF + Report HVB B-16 50231200400000 212133 6/14/2022 AK E-Line CIBP KALOTSA 1 50133206570000 216132 7/7/2022 Yellowjacket PERF + Report KBU 11-07 50133205560000 205165 6/16/2022 Yellowjacket GPT-PERF + Report KBU 11-07 50133205560000 205165 6/20/2022 Yellowjacket GPT-PERF + Report KBU 33-06X 50133205290000 203183 6/22/2022 Yellowjacket CBL MPU B-28 50029235660000 216027 5/27/2022 Halliburton LDL MPU B-28 50029235660000 216027 5/27/2022 Halliburton MFC + Report MPU B-30 50029235710000 216153 5/18/2022 Halliburton PERF MPU E-06 50029221540000 191048 5/28/2022 Halliburton MFC + Report Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: MPU E-35 50029236150000 218152 6/15/2022 Halliburton MFC + Report MPU L-50 50029235550000 215132 6/24/2022 Read COIL FLAG PAXTON 10 50133206910000 220064 5/27/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton RBT PBU GNI-03 50029228200000 197189 6/25/2022 Read CALIPER PBU GNI-03 50029228200000 197189 6/25/2022 Read TEMP-PRESS PBU K-01 50029209980000 183121 6/21/2022 Halliburton PPROF + Report PBU M-13A 50029205220100 201165 5/27/2022 Halliburton TMD3D-WFL + Report PBU NGI-05 50029201960000 176014 6/7/2022 Halliburton CAST PBU W-01A 50029218660100 203176 6/8/2022 Halliburton RBT SRU 241-33 50133206630000 217047 6/13/2022 Yellowjacket PERF SRU 241-33B 50133206960000 221053 5/25/2022 Halliburton TEMP-PRESS SRU 32A-33 50133101640100 191014 6/11/2022 AK E-Line PPROF Please include current contact information if different from above. BCU 18RD PTD:222-033 T36747 BCU 24 PTD:214-112 T36748 BCU 7A PTD:214-060 T36749 BRU 232-26 PTD:184-138 T36750 CLU 01RD PTD:203-129 T36751 CLU 09 PTD: 204-161 T36752 CLU1RD PTD:203-129 T36751 END 1-17A PTD:196-199 T36753 END 1-45 PTD:189-124 T36754 END 3-17F PTD:203-216 T36755 Falls Creek 3 PTD:203-102 T36756 HVB B-16 PTD:212-133 T36757 Kalosta 1 PTD:216-132 T36758 KBU 11-7 PTD:205-165 T36759 KBU 33-06X PTD:203-183 T36760 MPU B-28 PTD:216-027 T36761 MPU B-30 PTD:216-153 T36762 MPU E-06 PTD: 191-048 T36763 MPU E-35 PTD:218-152 T36764 MPU L-50 PTD:215-132 T36765 Paxton 10 PTD:220-064 T36766 PBU C-24B PTD:212-063 T36767 PBU GNI-03 PTD:197-189 T36768 PBU K-01 PTD:183-121 T36769 PBU M-13A PTD:201-165 T36770 PBU NGI-05 PTD:176-014 T36771 PBU W-01A PTD:203-176 T36772 SRU 241-33 PTD:217-047 T36773 SRU 241-33B PTD:221-053 T36774 SRU 32A-33 PTD: 191-014 T36775 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.12 12:56:51 -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:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:FW: END3-17F (PTD 203-216) RWO BOP Test Extension Request Sundry 322-311 Date:Wednesday, June 29, 2022 12:29:07 PM From: Rixse, Melvin G (OGC) Sent: Wednesday, June 29, 2022 10:59 AM To: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Joleen Oshiro <Joleen.Oshiro@hilcorp.com>; Arvell Bass - (C) <Arvell.Bass@hilcorp.com>; aogcc.inspectors@alaska.gov Subject: END3-17F (PTD 203-216) RWO BOP Test Extension Request Sundry 322-311 Torin, As discussed on the phone this morning, this decision is historically made by Jim Regg. As you have not been able to contact him, I will approve Hilcorp to slickline set a downhole plug, swap the shear out valve to a dummy with slickline, drop ball and set packer before performing BOPE test. I would like to see down hole barriers in place before the BOPE test. A leak detect log should be run after BOPE testing. I will note that the weekly BOPE test was due at midnight yesterday, June 28th. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Jim Regg, AOGCC Inspectors, Arvell Bass, Joleen Oshiro From: Torin Roschinger <Torin.Roschinger@hilcorp.com> Sent: Wednesday, June 29, 2022 10:26 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Joleen Oshiro <Joleen.Oshiro@hilcorp.com>; Arvell Bass - (C) <Arvell.Bass@hilcorp.com> Subject: RE: END3-17F (PTD 203-216) RWO BOP Test Extension Request Good morning Mel, Please see our request below for a BOP extension on END3-17 before moving forward with the job. Thank you, Torin From: Torin Roschinger Sent: Wednesday, June 29, 2022 9:00 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Joleen Oshiro <Joleen.Oshiro@hilcorp.com>; Arvell Bass - (C) <Arvell.Bass@hilcorp.com> Subject: END3-17F (PTD 203-216) RWO BOP Test Extension Request Mr. Regg, The Thunderbird Rig was due for a BOP test at midnight on Tuesday the 28th. Earlier on Tuesday, Joleen received approval from Mel to use slickline to run a downhole plug in the X-nipple right above the packer to ensure we have competent tubing before setting the packer due to having found 4 bad joints in the pipe tally that were removed after more than 50 joints were run in the hole. At midnight, slickline had finished setting the plug and the rig was pressure testing the tubing which lasted until about 0130-0200 this morning at which time the completion was landed. The pressure test on the casing previously passed, but the MIT-T earlier this morning failed. With the tubing landed, I would like to request permission to proceed with slickline resetting the downhole plug and swapping the shear out valve to a dummy valve and re-testing the tubing before performing another rig BOP test. If the test passes we would like to proceed by dropping the ball and rod and setting the packer. However, if the MIT-T fails and the tubing needs to be pulled, we would run a LDL to identify the leak point and perform the BOP test that was scheduled for 10am this morning with the Slope AOGCC inspector (Bob Noble). Notification was made to the AOGCC yesterday morning (Tuesday, June 28th) at 10am. Thank you, Torin Roschinger Hilcorp Energy Alaska Alaska Islands Team - Operations Manager c. 406 570 9630 Torin.roschinger@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 5HJJ-DPHV%2*& )URP1LFN)UD]LHU&QIUD]LHU#KLOFRUSFRP! 6HQW:HGQHVGD\-XQH30 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*& &F3%:HOOV5:2:66 6XEMHFW+LOFRUS7KXQGHUELUG $WWDFKPHQWV+LOFRUS7KXQGHUELUG[OV[ WůĞĂƐĞĨŝŶĚĂƚƚĂĐŚĞĚƚŚĞKWdĞƐƚ&ŽƌŵĨŽƌ,ŝůĐŽƌƉdŚƵŶĚĞƌďŝƌĚϭĨŽƌϲͲϮϭͲϮϬϮϮ͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨǇŽƵŚĂǀĞĂŶǇ ƋƵĞƐƚŝŽŶƐ͘ dŚĂŶŬƐ͕ EŝĐŬ&ƌĂǌŝĞƌ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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:Thunderbird 1 DATE: 6/21/22 Rig Rep.: Rig Phone: 307-321-6563 Operator: Op. Phone:907-444-7218 Rep.: E-Mail Well Name: PTD #22032160 Sundry #322-311 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:250/2500 Valves:250/3000 MASP:2900 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" x 5M P Pit Level Indicators PP #1 Rams 1 2 7/8 x 5" VBR P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0 4" x 7" VBR P H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8"P Inside Reel valves 0NA HCR Valves 1 3 1/8"P Kill Line Valves 3 3 1/8"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)2950 P CHOKE MANIFOLD:Pressure After Closure (psi)1450 p Quantity Test Result 200 psi Attained (sec)26 p No. Valves 11 P Full Pressure Attained (sec)179 P Manual Chokes 2P Blind Switch Covers: All stations Yes Hydraulic Chokes 1NA Nitgn. Bottles # & psi (Avg.): 3@2333 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:0 Test Time:5.0 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 6/19/22 03:30 Waived By Test Start Date/Time:6/20/2022 19:30 (date) (time)Witness Test Finish Date/Time:6/21/2022 2:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Hilcorp Tested 4" x 7" VBR with 7" test jt 250 low and 5000 high (new set of ram). Test 2-7/8 x 5" VBR with 2-7/8 & 4-1/2". 250 low & 3000 high annular 2500 high. Tested with fresh water. Joshua Noel/Adan Flores Hilcorp Nick Frazier/Anthony Knowles DIU SDI 3-17F Test Pressure (psi): pbrwowss@hilcorp.com Form 10-424 (Revised 02/2022) 2022-0621_BOP_Hilcorp_Thunderbird1_DIU_3-17F +LOFRUS$ODVND//& 9 9 9 9 9 9 9 99 9 9 9 -5HJJ Tested 4" x 7" VBR with 7" test jt 250 low and 5000 high (new set of ram). 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^Ğƚϰ͘ϱ͟ĐŽŵƉŽƐŝƚĞďƌŝĚŐĞƉůƵŐĂƚΕϵ͕ϴϯϯ͛D͘ ϴ͘ D/dͲdƚŽϯ͕ϬϬϬƉƐŝ͘ ϵ͘ ƵƚƚƵďŝŶŐĂƚΕϮĨƚďĞůŽǁƚŚĞƚŽƉŽĨƚŚĞƉƵƉũŽŝŶƚƌŝŐŚƚďĞůŽ ǁƚŚĞyŶŝƉƉůĞĂƚϵ͕ϳϳϴ͛D͘ ϭϬ͘ ŝƌĐƵůĂƚĞǁĞůůƚŽϲϰϰďďůƐŽĨϵ͘ϴƉƉŐďƌŝŶĞĂŶĚϲďďůĚŝĞƐĞů ĨƌĞĞǌĞƉƌŽƚĞĐƚĐĂƉ;ϲϱϬďďůƚŽƚĂů ƉƵŵƉĞĚǀŽůƵŵĞͿ o ϰͲϭͬϮ͟ƚƵďŝŶŐǀŽůƵŵĞĨƌŽŵƐƵƌĨĂĐĞƚŽϵ͕ϳϴϬ͛D;ƚƵďŝŶŐĐƵƚͿсϭϱϬďďů o ϵͲϱͬϴ͟ǆϰͲϭͬϮ͟/ǀŽůƵŵĞĨƌŽŵƐƵƌĨĂĐĞƚŽϵ͕ϳϴϬ͛D;ƚƵďŝŶŐĐƵƚͿсϱϬϬďďů o ϲďďůŝŶϵͲϱͬϴ͟ǆϰͲϭͬϮ͟ĂŶŶƵůƵƐсϭϭϴĨƚ ϭϭ͘ WƵƌŐĞĐŽŶƚƌŽůůŝŶĞƐ͘ tĞůůŚĞĂĚͬdƌĞĞ͗ ϭϮ͘ ƌǇƌŽĚϰ͟d^Ws͘ ϭϯ͘ EƉƌŽĚƵĐƚŝŽŶƚƌĞĞĂŶĚƚƵďŝŶŐŚĞĂĚĂĚĂƉƚĞƌ͘ ϭϰ͘ /ŶƐƉĞĐƚůŝĨƚƚŚƌĞĂĚƐŽŶƚƵďŝŶŐŚĂŶŐĞƌ͘ŽŶƐŝĚĞƌƐĐƌĞǁŝŶŐŝŶůĂŶĚŝŶŐũŽŝŶƚ;d^ĐƌŽƐƐŽǀĞƌͿĂƚƚŚŝƐ ƚŝŵĞ͘ ϭϱ͘ /ŶƐƚĂůůƉůƵŐŝŶd^͘ ϭϲ͘ EhϭϯͲϱͬϴ͛͛KW o dŽƉĚŽǁŶ͗ŶŶƵůĂƌ͕ϮͲϳͬϴ͟ǆϱ͟sZƐ͕ůŝŶĚƐ͕&ůŽǁƌŽƐƐ͕ϰͲϭͬϮ͟ǆϳ͟sZƐ͘ ZŝŐWƌŽĐĞĚƵƌĞ͗ ϭ͘ D/ZhdŚƵŶĚĞƌďŝƌĚηϭƌŝŐ͕ĂŶĐŝůůĂƌǇĞƋƵŝƉŵĞŶƚĂŶĚůŝŶĞƐ͘ Ă͘ ZhĂƌĞƚƵƌŶůŝŶĞĨƌŽŵƚŚĞKƚŽƚŚĞĨůŽǁďĂĐŬƚĂŶŬ͘ŽŶĨŝƌŵŶ ŽĨůŽǁĨƌŽŵK͘ Ϯ͘ dĞƐƚKWƚŽϮϱϬƉƐŝ>Žǁͬϯ͕ϬϬϬƉƐŝ,ŝŐŚ͕ĂŶŶƵůĂƌƚŽϮϱϬƉƐŝ>ŽǁͬϮ͕ϱϬϬƉƐŝ,ŝŐŚ;ŚŽůĚĞĂĐŚ ƌĂŵͬǀĂůǀĞĂŶĚƚĞƐƚĨŽƌϱͲŵŝŶͿ͘ZĞĐŽƌĚĂĐĐƵŵƵůĂƚŽƌƉƌĞͲĐŚĂƌŐĞƉƌĞƐƐƵƌĞƐĂŶĚĐŚĂƌƚƚĞƐƚƐ͘ Ă͘ WĞƌĨŽƌŵdĞƐƚƉĞƌdŚƵŶĚĞƌďŝƌĚηϭKWƚĞƐƚƉƌŽĐĞĚƵƌĞ͘ ď͘ EŽƚŝĨǇK'ϮϰŚƌƐŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚ͘ Đ͘ ŽŶĨŝƌŵƚĞƐƚƉƌĞƐƐƵƌĞƐƉĞƌƚŚĞ^ƵŶĚƌǇŽŶĚŝƚŝŽŶƐŽĨĂƉƉƌŽǀĂů͘ Ě͘ dĞƐƚƚŚĞϮͲϳͬϴ͟ǆϱ͟sZ͛ƐǁŝƚŚϰͲϭͬϮ͟ĂŶĚϮͲϳͬϴ͟ƚĞƐƚũŽŝŶƚƐ͘dĞƐƚƚŚĞŶŶƵůĂƌ ƉƌĞǀĞŶƚĞƌǁŝƚŚĂϮͲϳͬϴ͟ƚĞƐƚũŽŝŶƚ͘dĞƐƚƚŚĞϰͲϭͬϮ͟ǆϳ͟sZƐǁŝƚŚϰͲϭͬϮ͟ĂŶĚϳ͟ƚĞƐƚ ũŽŝŶƚƐ͘ Ğ͘ ^ƵďŵŝƚƚŽK'ĐŽŵƉůĞƚĞĚϭϬͲϰϮϰĨŽƌŵǁŝƚŚŝŶϱĚĂǇƐŽĨKWƚĞƐƚ͘ ϯ͘ WƵůůd^ƉůƵŐ͘ %39 ϰ ϯͲϭϳ&tŽƌŬŽǀĞƌ tĞůů͗ϯͲϭϳ& Wd͗ϮϬϯͲϮϭϲ W/͗ϱϬͲϬϮϵͲϮϭϵϰϲͲϬϲ ϰ͘ ŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞĂŶĚŝĨϬƉƐŝ͕ƉƵůůd^Ws͘/ĨƉƌĞƐƐƵƌĞŝƐƐĞĞŶŽƌƐƵƐƉĞĐƚĞĚ͕ZhůƵďƌŝĐĂƚŽƌ͘ ϱ͘ ZhĐŽŶƚƌŽůůŝŶĞƐƉŽŽůĞƌ͘ǆƉĞĐƚƚŽƌĞĐŽǀĞƌϯϲďĂŶĚƐŽŶƚŚĞĐŽŶƚƌŽůůŝŶĞ͘ ϲ͘ K>^͕ƵƐĞůĂŶĚŝŶŐũŽŝŶƚ;d^ĐƌŽƐƐŽǀĞƌͿƚŽWhƚƵďŝŶŐŚĂŶŐĞƌ͘hƐĞƐƉĞĂƌŝĨŶĞĐĞƐƐĂƌǇ͘ ϳ͘ WƵůůŚĂŶŐĞƌƚŽƚŚĞĨůŽŽƌĂŶĚĐŝƌĐƵůĂƚĞďŽƚƚŽŵƐƵƉǁŝƚŚϵ͘ϴƉƉŐEĂů͘ o ǆƉĞĐƚĞĚWhǁĞŝŐŚƚŝŶϵ͘ϴƉƉŐEĂůсϭϬϱ͕ϬϬϬůďƐ o EŽƚĞ͗tĞŝŐŚƚŽĨϰ͘ϱ͟ĐŽŵƉůĞƚŝŽŶƐƚƌŝŶŐƵƉŽŶŝŶŝƚŝĂůĐŽŵƉůĞƚŝŽŶŝŶϯͬϮϬϬϯсϭϱϬ͕ϬϬϬůď ƉŝĐŬƵƉ͖ϭϯϬ͕ϬϬϬůďƐůĂĐŬŽĨĨ o dĞŶƐŝůĞƐƚƌĞŶŐƚŚŽĨϰͲϭͬϮ͟сϮϲϬ͕ϬϬϬůď;ĚĞƌĂƚĞĚϭϬйďĂƐĞĚŽŶϲйǁĂůůůŽƐƐĨƌŽŵ ϭϭͬϭϳͬϬϵĐĂůŝƉĞƌͿ o sDĐŽŶŶĞĐƚŝŽŶƐƚƌĞŶŐƚŚсϮϴϴ͕ϬϬϬůď ϴ͘ sĞƌŝĨǇĐƌŽƐƐŽǀĞƌĨŽƌ^ĂĨĞƚǇǀĂůǀĞƚŽsDĐŽŶŶĞĐƚŝŽŶŝƐŽŶƚŚĞĨůŽŽƌĨŽƌƉƵůůŝŶŐƚŚĞĞǆŝƐƚŝŶŐ ϰͲϭͬϮ͟d'͘ ϵ͘ 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acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 4/20/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL SDI 3-17F (PTD 203-216) PERF 4/09/2022 Please include current contact information if different from above. 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Galloway Cc:Wallace, Chris D (OGC); AOGCC Records (CED sponsored) Subject:20220222 0927 APPROVAL to Flow Under Evaluation for 30 days: Endicott 3-17F (PTD 203-216) Date:Tuesday, February 22, 2022 9:32:34 AM Attachments:image001.png image002.png Jerimiah, Hilcorp is approved to flow ‘Under Evaluation’ well PTD 203-216, Endicott 3-17F for 30 days. No gas lift will be allowed. Continuous annular pressure monitoring will be required. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Chris Wallace, AOGCC Records From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Friday, February 18, 2022 2:55 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] RE: Endicott 3-17F (PTD# 203-216) Request to flow under evaluation for 30 days Mel, Here is the additional information you requested Frac Gradient: 0.62 TOC: There is no cement behind the 9-5/8 at that point. IA Fluid Gradients: 2000’ @ 0.353 7800’ @ 0.44 Please let me know if you need anything further. Jerimiah Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, February 11, 2022 3:13 PM To: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] RE: Endicott 3-17F (PTD# 203-216) Request to flow under evaluation for 30 days Jerimiah, Hilcorp could receive approval for a 30 day flow evaluation test as you described below. No gas lift will be allowed. Add perforations will require an approved 10-403. Continual annular monitoring. No IA pressure greater than 700 psi. Please provide a fracture gradient for the overburden at your surface casing shoe and for overburden from surface casing shoe to the TOC external to the 9-5/8”. Expected fluid gradients and lengths in the IA during the flow test. (to be described in the 10-403). NOTE: Do not expect an extension to this flow evaluation test. For long term production, the IC casing leaks will need to be isolated. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). 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. Some people who received this message don't often get email from jerimiah.galloway@hilcorp.com. Learn why this is important From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Friday, February 11, 2022 2:32 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: Endicott 3-17F (PTD# 203-216) Request to flow under evaluation for 30 days Mel, Here is the information you requested. Please let me know if you need anything further. Reservoir Pressure: 4000 psi Pressure testing: 5/1/2021: MIT-T Passed to 2500 psi 4/27/2021: MIT-IA Failed. Unable to achieve test pressure. Leak Detect Log: 5/20/2021: An acoustic leak detect log was conducted. Two PC leaks were identified: 3,100’ MD and 4,578’ MD. The leak rate was determined to be 1 bpm @ 1500 psi. Planned Activity: 1. Pull plug from 9,823’ 2. Open sliding sleeve at 13,603’ 3. Install SSSV 4. (Pending well flow) Add perforations; add perf range: 13,418’ – 13,610’ 10-403 to be submitted and notification to be made prior to perforations 5. Engineer to evaluate Barrier Monitoring/Risk Mitigation During UE Period: Continual monitoring of inner annulus pressure through the control room. Maintain inner annulus pressure under 700 psi after thermal stabilization. Annular fluid level monitoring: Baseline IA fluid level shot prior to bringing well online Weekly fluid level shot to monitor for TxIA communication depressing the fluid level Any indication of potential impairment to the primary barrier will result in the well being shut in immediately. Thank you, Jerimiah Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, February 10, 2022 5:27 PM To: Jerimiah Galloway <jerimiah.galloway@hilcorp.com> Subject: [EXTERNAL] RE: Endicott 3-17F (PTD# 203-216) Request to flow under evaluation for 30 days Jeremiah, Chris Wallace oversees injectors. I look after well integrity on producers. Can you give me a call? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Thursday, February 3, 2022 3:13 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Joleen Oshiro <Joleen.Oshiro@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: Endicott 3-17F (PTD# 203-216) Request to flow under evaluation for 30 days Mr. Wallace, Produced Water Injector Endicott 3-17F (PTD# 203-216) was made NOT OPERABLE after a failing MIT-IA on 4/27/2021 (1 bpm at 1500 psi). Two PC leaks (3,100’ MD and 4,578’ MD) were identified in a May 2021 leak detect log. Currently the well is secured with a plug set at 9,823’ MD and confirmed with a MIT-T to 2500 psi proving the competency of the primary barrier. Hilcorp requests permission to temporarily produce Endicott 3-17F UNDER EVALUATION for 30 days in order to assess well economics for repair and permanent conversion to a producer. All gas lift mandrels are currently dummied and no gas lift will be used for the evaluation period. IA/OA pressures will be monitored for anomalies. If permission is given, Hilcorp will continue with the following: Plan Forward 1. Pull plug from 9,823’ 2. Open sliding sleeve at 13,603’ 3. (Pending well flow) Add perforations 13,418’ – 13,610’ 10-403 to be submitted and notification to be made prior to perforations 4. Engineer to evaluate Please let me know if you have further questions or comments. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above,then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systemsor data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above,then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systemsor data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: Endicott 3-17F (PTD# 203-216) Request to flow under evaluation for 30 days Date:Tuesday, February 15, 2022 8:14:40 AM Attachments:image001.png image002.png From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, February 11, 2022 3:13 PM To: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] RE: Endicott 3-17F (PTD# 203-216) Request to flow under evaluation for 30 days Jerimiah, Hilcorp could receive approval for a 30 day flow evaluation test as you described below. No gas lift will be allowed. Add perforations will require an approved 10-403. Continual annular monitoring. No IA pressure greater than 700 psi. Please provide a fracture gradient for the overburden at your surface casing shoe and for overburden from surface casing shoe to the TOC external to the 9-5/8”. Expected fluid gradients and lengths in the IA during the flow test. (to be described in the 10-403). NOTE: Do not expect an extension to this flow evaluation test. For long term production, the IC casing leaks will need to be isolated. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Friday, February 11, 2022 2:32 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: Endicott 3-17F (PTD# 203-216) Request to flow under evaluation for 30 days Mel, Here is the information you requested. Please let me know if you need anything further. Reservoir Pressure: 4000 psi Pressure testing: 5/1/2021: MIT-T Passed to 2500 psi 4/27/2021: MIT-IA Failed. Unable to achieve test pressure. Leak Detect Log: 5/20/2021: An acoustic leak detect log was conducted. Two PC leaks were identified: 3,100’ MD and 4,578’ MD. The leak rate was determined to be 1 bpm @ 1500 psi. Planned Activity: 1. Pull plug from 9,823’ 2. Open sliding sleeve at 13,603’ 3. Install SSSV 4. (Pending well flow) Add perforations; add perf range: 13,418’ – 13,610’ 10-403 to be submitted and notification to be made prior to perforations 5. Engineer to evaluate Barrier Monitoring/Risk Mitigation During UE Period: Continual monitoring of inner annulus pressure through the control room. Maintain inner annulus pressure under 700 psi after thermal stabilization. Annular fluid level monitoring: Baseline IA fluid level shot prior to bringing well online Weekly fluid level shot to monitor for TxIA communication depressing the fluid level Any indication of potential impairment to the primary barrier will result in the well being shut in immediately. Thank you, Jerimiah Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, February 10, 2022 5:27 PM 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. Some people who received this message don't often get email from jerimiah.galloway@hilcorp.com. Learn why this is important To: Jerimiah Galloway <jerimiah.galloway@hilcorp.com> Subject: [EXTERNAL] RE: Endicott 3-17F (PTD# 203-216) Request to flow under evaluation for 30 days Jeremiah, Chris Wallace oversees injectors. I look after well integrity on producers. Can you give me a call? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Thursday, February 3, 2022 3:13 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Joleen Oshiro <Joleen.Oshiro@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: Endicott 3-17F (PTD# 203-216) Request to flow under evaluation for 30 days Mr. Wallace, Produced Water Injector Endicott 3-17F (PTD# 203-216) was made NOT OPERABLE after a failing MIT-IA on 4/27/2021 (1 bpm at 1500 psi). Two PC leaks (3,100’ MD and 4,578’ MD) were identified in a May 2021 leak detect log. Currently the well is secured with a plug set at 9,823’ MD and confirmed with a MIT-T to 2500 psi proving the competency of the primary barrier. Hilcorp requests permission to temporarily produce Endicott 3-17F UNDER EVALUATION for 30 days in order to assess well economics for repair and permanent conversion to a producer. All gas lift mandrels are currently dummied and no gas lift will be used for the evaluation period. IA/OA pressures will be monitored for anomalies. If permission is given, Hilcorp will continue with the following: Plan Forward 1. Pull plug from 9,823’ 2. Open sliding sleeve at 13,603’ 3. (Pending well flow) Add perforations 13,418’ – 13,610’ 10-403 to be submitted and notification to be made prior to perforations 4. Engineer to evaluate Please let me know if you have further questions or comments. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above,then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systemsor data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above,then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systemsor data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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. Some people who received this message don't often get email from jerimiah.galloway@hilcorp.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Endicott 3-17F (PTD# 203-216) Request to flow under evaluation for 30 days Date:Wednesday, February 9, 2022 11:15:23 AM Attachments:image001.png image002.png From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Thursday, February 3, 2022 3:13 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Joleen Oshiro <Joleen.Oshiro@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: Endicott 3-17F (PTD# 203-216) Request to flow under evaluation for 30 days Mr. Wallace, Produced Water Injector Endicott 3-17F (PTD# 203-216) was made NOT OPERABLE after a failing MIT-IA on 4/27/2021 (1 bpm at 1500 psi). Two PC leaks (3,100’ MD and 4,578’ MD) were identified in a May 2021 leak detect log. Currently the well is secured with a plug set at 9,823’ MD and confirmed with a MIT-T to 2500 psi proving the competency of the primary barrier. Hilcorp requests permission to temporarily produce Endicott 3-17F UNDER EVALUATION for 30 days in order to assess well economics for repair and permanent conversion to a producer. All gas lift mandrels are currently dummied and no gas lift will be used for the evaluation period. IA/OA pressures will be monitored for anomalies. If permission is given, Hilcorp will continue with the following: Plan Forward 1. Pull plug from 9,823’ 2. Open sliding sleeve at 13,603’ 3. (Pending well flow) Add perforations 13,418’ – 13,610’ 10-403 to be submitted and notification to be made prior to perforations 4. Engineer to evaluate Please let me know if you have further questions or comments. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above,then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systemsor data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. David Dempsey Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: David.Dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: DATE: 6/18/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL END SDI 3-17F (PTD 203-216) LeakPointTM Acoustic LDL Survey 05/20/2021 Please include current contact information if different from above. 06/29/2021 eceived By: 37' (6HW By Abby Bell at 12:55 pm, Jun 29, 2021 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: Bradenhead Repair Hilcorp Alaska Development Exploratory 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 15,436 feet N/A feet true vertical 10,225 feet N/A feet Effective Depth measured 15,385 feet feet true vertical 10,221 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / 13CR80 / N/A 9,857' 7,648' Packers and SSSV (type, measured and true vertical depth)N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 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: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone:777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: 10,570psi Collapse N/A 2,260psi 10,078' Burst N/A 5,020psi 6,870psi 8,430psi 11,170psi 10,530psi10,160psi 2,496' 7,648' 10,129' 10,219' 4,760psi 7,500psi 9,857' Surface Production 30" 13-3/8" 9-5/8" Liner Liner Casing Conductor Liner 1,767' Length 142' 2,498' DUCK IS UNIT SDI 3-17F 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 200 Casing Pressure Tubing Pressure 0 N/A measured 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 0 Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com 200 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-216 50-029-21946-06-00 Plugs ADL0312828 5. Permit to Drill Number: ENDICOTT / ENDICOTT OIL Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 00 measured true vertical Packer 3-1/2" 2-7/8" 13,733' 13,669' Size 4-1/2" 15,436' TVD 142' 0 Oil-Bbl 3,876' 22' N/A 9,799, 9,837 & 13,647 7,608, 7,634 & 10,060 9-5/8" x 4-1/2" S-3, 9-5/8” X 4-1/2” ZXP LTP & 3.70” Baker LTP WINJ WAG 0 Water-Bbl MD 142' 2,498' 9,857' PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 2:20 pm, Apr 23, 2021 Chad Helgeson (1517) 2021.04.23 13:46:36 - 08'00' SFD 4/23/2021RBDMS HEW 4/23/2021 ADL 047502, ADL 047503, DSR-4/26/21 SFD 4/23/2021 MGR30JUL2021 END 3-17F (BH Repair) END 3-17F Wellhead Schematic: The OA was leaking through the WH threads where the 13- 3/8” Surface CSG pup joint threads into the base of the starting head. END 3-17F UT Inspection 3/23/21: Completed a UT inspection on the 6” section of the 13-3/8” surface CSG at the base of the starting head. No internal wear or external corrsion was identified, confirmed a BH weld would be the best repair option. END 3-17F Welded BH Repair 4/19/2021: BH weld repair completed and the OA was pressure tested to 500 psi with no pressure loss and no visible external leak. _____________________________________________________________________________________ Revised By: TDF 3/25/2021 SCHEMATIC Endicott Unit Well: END 3-17F Last Completed: 3/13/2004 PTD: 203-216 TD =15,436’ (MD) / TD = 10,225(TVD) 30” Whipstock w/ 3 RA PIPTags @ 13,720’ KBE = 52.6’/ Water Depth = 12’ MSL 4-1/2” 3 5 6 7 8 9 10 11 13 9-5/8” 1 2 14 15 16 17 Mill-Out Window 13,725’ to 13,733’ PBTD =15,385’ (MD) / PBTD = 10,221’(TVD) 4 13-3/8” 18 19 2-7/8” 12 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 30" Conductor NA NA Surf 142’ 13-3/8" Surface 68 / NT80CYTHE / BTC 12.259 Surf 2,498’ 9-5/8" Production 47 / NT80S / NA 8.525 Surf 9,857’ 4-1/2" Liner 12.6 / 13Cr810 / HYDR 563 3.958 9,857’ 13,733’ 3-1/2" Liner 9.3 / Cr80 / STL NA 13,647 13,669’ 2-7/8” Liner 6.5 / Cr80 / STL 2.441 13,669’ 15,436’ TUBING DETAIL 4-1/2” Tubing 12.6 / 13Cr80 / NA 3.958 Surf 9,857’ JEWELRY DETAIL No Depth Item 1 1,521’ 4-1/2” HXO SVLN, ID=3.813” 2 3,807’ Gas Lift Mandrel MMG w/ Dummy Valve & RK Latch 3 5,971’ Gas Lift Mandrel MMG w/ Dummy Valve & RK Latch 4 7,510’ Gas Lift Mandrel MMG w/ Dummy Valve & RK Latch 5 8,882’ Gas Lift Mandrel MMG w/ Dummy Valve & RK Latch 6 9,750’ Gas Lift Mandrel MMG w/ Dummy Valve & RK Latch 7 9,778’ 4-1/2” HES X NIP, ID=3.813” 8 9,799’ 9-5/8” X 4-1/2” BKR S-3 PKR, ID= 3.875” 9 9,823’ 4-1/2” HES X NIP, ID=3.813”w/ 4-1/2” xx Plug 3/31/2014 10 9,826’ 8.25” BKR TIE BACK SLV, ID= 7.51” 11 9,837’ 9-5/8” X 4-1/2” Baker ZXP Packer LTP, ID=6.187” 12 9,844’ 4-1/2” HES XN NIP, Milled to 3.80” 13 9,848’ 9-5/8” X 7-1/2” BAKER Liner Hanger, ID= 6.187” 14 9,857’ 4-1/2” WLEG, ID= 3.958” 15 9,858’ 7-1/2” X 4-1/2” XO, ID= 3.890” 16 13,538’ 4-1/2” Marker Joint 17 13,647’ 3.70” Baker LTP, ID= 2.390” 18 13,659’ 3.70” Deploy SLV, ID= 3.00” 19 13,669’ 3-1/2” X 2-7/8” XO, ID= 2.380” PERFORATION DETAIL Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status 13,610’ 13,615’ 10,035’ 10,039’ 5 7/4/2008 Open 13,632’ 13,642’ 10,053’ 10,062’ 10 7/4/2008 Open 13,910’ 13,930’ 10,183’ 10,185’ 20 4/18/2007 Open 14,215’ 14,235’ 10,183’ 10,183’ 20 4/18/2007 Open 14,490’ 14,510’ 10,178’ 10,178’ 20 4/18/2007 Open 14,780’ 14,800’ 10,198’ 10,198 20 4/30/2005 Open 14,816’ 14,836’ 10,199’ 10,199’ 20 4/30/2005 Open 14,856’ 14,876’ 10,198’ 10,198’ 20 4/30/2005 Open 15,015’ 15,035’ 10,198’ 10,199’ 20 5/16/2009 Open 15,200’ 15,220’ 10,203’ 10,204’ 20 5/16/209 Open 15,307’ 15,382’ 10,213’ 10,221’ 75 3/13/2004 Open OPEN HOLE / CEMENT DETAIL 30" Driven 13-3/8" 4,185cu / ft of Permafrost in 17-1/2” Hole 9-5/8" 575 cu / ft of Class “G” in 12-1/4” Hole 4-1/2” 1,038 cu / ft of Class “G” in 8-1/2” Hole 3-1/2” & 2-7/8” 118 cu / ft of Class “G” in 3-3/4” Hole WELL INCLINATION DETAIL Max Hole Angle = 98 deg. @ 14,184’ TREE & WELLHEAD Tree CIW Wellhead FMC SAFETY NOTES Well Angle ग़70 Deg. @ 13,781’***H2S Readings Average 230 to 260 PPM on A/L @ Gas Injectors***Well Requires SSSV***4-1/2” Chrome Tubing & 2-7/8” Chrome Liner*** GENERAL WELL INFO API: 50-029-21946-06-00 Drilled and Cased by - Nordic 2 on 3/10/2004 Completed 3/13/2004 . STATE OF ALASKA AL -,KA OIL AND GAS CONSERVATION COMMIo6ION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Patch Perfs Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development El Exploratory ❑ 203-216-0 • 3.Address: P.O.Box 196612 Stratigraphic Service 0 6.API Number: Anchorage,AK 99519-6612 50-029-21946-06-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312828 • EPA 3-17F/K-30 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): ENDICOTT,ENDICOTT OIL • 1 11.Present Well Condition Summary: RECEIVED Total Depth measured 15436 feet Plugs measured None feet true vertical 10224.97 feet Junk measured None feet NOV N O ,(� 2 013 Effective Depth measured 15385 feet Packer measured See Attachment feet AOGCC true vertical 10221.27 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 142 30"Conductor 37-179 37-179 0 0 Surface 2462 13-3/8"68#NT8OCYHE 36-2498 36-2495.54 5020 2270 Intermediate None None None None None None Production 9941 9-5/8"47#NT8OS 35-9976 35-7734.03 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 33-9857 33-7653.21 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4-1/2"HES HXO SSV 1520 1518.98 SSSV 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 Casing Pressure Tubing Pressure Prior to well operation: 431 22777 30 0 2265 • Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Explorator,❑ Development❑ Service Q ' Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas U WDSPLU GSTOR ❑ WINJ El, WAG ❑ GINJ ❑ SUSP ❑ SPLUd 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: 313-320 Contact Nita Summerhays Email Nita.Summerhays(zhBP.com Printed Name Nita Summerhays Title Petrotechnical Data Technician - %S7� / Phone 564-4035 Date 9/4/2013 ' - 1700,/%/ mil/t l�- 1/1-1- —r 1/14 /1 ,1- RBDMS NOV " 2 i Form 10-404 Revised 10/2012 / 'Z'37‘ Submit Original Only Daily Report of Well Operations ADL0312828 .,,. I ***WELL INJECTING • - - V pa c -using finer DRIFT 3.84" NOGO CENT. TO MCX VALVE @ 1,489' SLM (1,521' MD) PULLED 4-1/2" MCX(ser.# NM02) @ 1,489' SLM (1,521' MD) 7/23/2013 ***WELL S/I ON DEPARTURE, WELL TENDER NOTIFIED OF STATUS*** CTU-8 1.75" COIL. Scope: Drift& set Patch. Rih w/3.70" patch drift 8/11/2013 Continue on 8-12-13 wsr CTU-8 1.75" COIL. Scope: Drift&set Patch. Rig up. Perform weekly BOP test. RIH w/CTC 3.313" x .93', DCV 3.313"x 1.55', BiDi JARS 3.313"X 7.67', DISCO 3.38"X 1.53' (7/8" BALL), G-SPEAR 3.5"X 1.85', DFIFT 3.69 X 5.05', PUP 2.88"X 9.77', XO 3.51"X .42', SNAP LATCH 3.51"X 4.10'. OAL= 32.87'. Sat down on LTP at 13610' CTM. Stacked 15k DW on packer, picked up and saw 2k over pull indicating snap latch sheared. Repeat and pickup was clean.. pooh. Pins on snap latch are sheared indicating drift was in place. RIH w/ BHA#2; 3.13"ctc, dfcv, 3.38" disco, 3.5" GS, 3.69" snap latch receptacle, 3.51" cross over, three 2.88" pup joints, 3.51" 8/11/2013 crossover, 3.51" snap latch (oal= 33.41') **job continued on WSR 08-12-13** Continued from WSR 08-11-13, CTU 8 w/ 1.75" CT. Scope; Set Patch Continue RIH w/ BHA#2; 3.13" ctc, dfcv, 3.38"disco, 3.5" GS, 3.69" snap latch receptacle, 3.51" cross over, three 2.88" pup joints, 3.51" crossover, 3.51" snap latch (oal= 33.41') Set lower patch assembly at 13616'. pull tested to 2k overpull. released and pooh. **job in 8/12/2013 progress** Continued from WSR 08-11-13, CTU 8 w/ 1.75" CT. Scope; Set Patch Continue RIH w/ BHA#2; 3.13" ctc, dfcv, 3.38" disco, 3.5" GS, 3.69" snap latch receptacle, 3.51" cross over, three 2.88" pup joints, 3.51" crossover, 3.51" snap latch (oal= 33.41') Set lower patch assembly at 13616'. pull tested to 2k overpull. released and pooh, Rih BHA# 3 LTP spacer pipe w/sliding sleeve and snap latch, top of patch 13601'md, ME is 13603'md, good set POOH, Fp well w/23bbls 50/50, RDMO »Patch has 2 7/8" sliding sleeve CMD, shift down to open w/ Baker HB-3 shifting tool, min id =2.313"<< 8/12/2013 . **job complete** ***WELL S/I ON ARRIVAL*** SET 4-1/2" MCX @1521' MD (.875 bean, serial#NM17, x eq. device, 4 x 3/16" ports) 8/13/2013 ***CONT ON WSR 8/14/13*** ***CONT FROM WSR 8/13/13**4 CHECK SET 4 1/2" MCX @ 1521'MD (good set) 8/14/2013 ***WELL S/I ON DEPARTURE*** FLUIDS PUMPED BBLS 2 DIESEL 237 I% SLICK KCL WITH SAFELUBE 23 50/50 METH 262 TOTAL N w m N- co CO M , N- N- N. U) m . N- (0 . CA CO CO C'1 co a) o w M 4 C: 00 00 00 c0 M ° COO C` a) OOOON Q a 0 0 ' 0 0 0 0 0 0 0 o W Z - - a m0 W p U 0 > i_• M Lc) N N- N CO N- N. CO UC) Uf) U V f' O` uj uj t O CO O O t` O Nr a0 Q Q W W ce a La M N N a0 N- 00 a0 00 M _N W 0_ 0_ Z p OOCDO � CACAOCANN JO J J n C9 g p O 0 0 0 0 0 0 0 0 0 0 0 = ❑ ❑ a W a ❑ ❑ Z 4a E Z 1... Z 0 CO CO a) u) CO - - a) (a O m t U) N 0 U) 0 0 CO CO U) 0 N t [F8M7OCN- MNCO t.C G M M co ct Nr 'V LO LO LO E O d t 2 = I- I- a J a o 0 cn cn u) co cn CO N a Q O = p w 0N0 (C) 0000011) 0N _1 1 Mci CA a0 Cn ' 00 < 0 MMMid .0 .U) U) L a) O 2 . it 1 CL a) O C) c ° aaaaaaaaaaa Ioaaaaaaaaaaa mmm'mmmmmmmm 0 t a) 0. • U)a W C') M M M C') M C) CY) M CY) M p ( O Q Q c 00000000000 J Z U- O N N N N N N N N N N N 0_ < N N LL N N. N- N. N. n N. N. N. N. N. N. W J W W C` N N N N N N N N N N N 0 U W W W W avvv �tvvvvvvv ❑ _1 _1 » a! a m u. LI vim) O) a CC 00000000000 O M co M co M M co CO M M CO E Y Y Y Y I I I I I I Y Z LL LL LL LL LL LL LL LL LL LL LL 3 ti ti N. N. N. N. N. N. N N- C` CO 1 1 1 1 i i i d 0 J O NU' W d M M M M M M M M M M M m LL LL U) U) 0_ 0: • a) Q. oN- r,) o00 s o) otti oN tO 0 C (.1 t• V e 0 (000 ° 7 Mr 0000Omr m CO CO LA CO Mr CO CO Mr a- O) N r. O 0o to s- O co O) �f) a a r- CO N f� CO r- r- co N p M co co O O r � COCOCOr- _ � O) LO r M M N CO V CO co CO v r co co M co COQ) M C 0 7 J 0 2 o 0 Q mo (4 >— oUV co oC C M co ~ o M Z N N C CEO Z CEO (N! N.- col t _ _ ON f- NMtCCON • co N O)) (NI a) J Z 0 w y > > UC� MOCLCLOu_ Z OZWW0ctcyi O Z Z > U = = 0- U) Packers and SSV's Attachment ADL0312828 SW Name Type MD TVD Depscription 3-17F/K-30 SSSV 1520 1466.38 4-1/2" HES HXO SSV 3-17F/K-30 PACKER 9799 7561.02 4-1/2" Baker SAB-3 Packer 3-17F/K-30 PACKER 9837 7586.98 4-1/2" Baker ZXP Packer 3-17F/K-30 PACKER 9848 7594.48 4-1/2" Liner Hanger 3-17F/K-30 PACKER 13647 10013.34 _Baker Liner Top Packer IIII TTY= CW Sti :NOTES:WELL ANGLE>70°@ 13781""H2S .WELLHEAD= FMC E ND 3-17 F READINGS AVERAGE 230-260 PPM ON All&GAS I ACTUATOR= BAKER C NJBCTORS'"'WELL REQUIRES A SSSV"""4-1/2" MIAL KB.FIE 55' CHROME TBG&2-718"CHROME LNR"'ON G,B,C,0 BF.ELEV= 15.75' &E WELLBORES NOT SHOWN KOP= JMD DRAFT Max Angle= 98°(�14184' 1521' H4-12"HXO SV LN,D=3.813" Datum NO= 13631' GAS LFT MANDRELS 'Datum TVD= 10000 SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3807 3716 35 MMG-M OMY RK 0 12/22/08 13-3/8"CSG,72#,L-80 BTC,D=12.347" 2498' 4 5971 5117 55 MMG-M OMY RK 0 12/22/08 3 7510 6071 48 MMGM CAW RK 0 11/25/03 2 8882 6985 48 MMGM MK RK 0 03/16/03 Minimum ID =2.380" @ 13669' I 1 9750 7579 47 MMGM DMY RK 0 12/22/08 3-1/2" X 2-7/8" XO I 9778' I—+4-12"FESX NP,D=3.813" I ..M1 �� 9799' J-19-5/8"X 4-1/2"BKR S-3 PKR,D=3.875- I I 9823' I—I4-12"HES X NP,D=3.813" J 9826' H8.25"BKR TE BACK SLY,D=7.51' I MA J 9837' H9-5/8"X 7-12"BKR ZXP LTP D=6.187" 4-1/2"TBG,12.6#,13CR-80 VAM ACE, H 9857" 1;\ D 9844' H4-12"F ES XN NP,PALLED TO 3.80"(??/??/??) I .0152 bpf, =3.958" ` 9848' H9-5/8"X 7-12'BKR LNR FIGR D=6-187" I 9867' H4-12'VVLEG,D=3.958" 9658' H7-1/2 X 4-12"X0,13=3.890- 9-5/8-CSG,47#,NT130S,D=8.681" —I 9976' M LOUT VVI DOW(3-17E) 9976'-10004' ' 13538' 1-14-1/2-MARKER JOINT I WHPSTOCK w/3 RA RP TAGS H 13720' 13647' —13.70"BKR LTP,D=2.390" 4-1/2"LNR,12.6#,13CR-810 HYDR563, —13725 13659' I-13.70"DEPLOY SLV,D=3.00" .0152 bpf,D=3.958" 13669' I-13-12"X 2-7/8"XO,D=2.380" I PERFORATION SUMMARY REF LOG:SVIi6 PDC on 03/22/03 - ANGLE AT TOP PERF: 34°@ 13610' MLLOU T WINDOW(3-179 13725'-13733' Note:Refer b Production DB for historical pert data I ' SIZE SPF 14TERNAL Cpn/Sqz DATE SQZ 2-7/8' 6 13610-13615 0 07/04/08 2' 6 13632-13642 0 07/04/08 I 2" 6 13910-13930 0 04/18/07 2" 6 14215-14235 0 04/18/07 2" 6 14490-14510 0 04/18/07 I 2" 6 14780-14800 0 04130/05 2" 6 14816-14836 0 04/30/05 I 2" 6 14856-14876 0 04/30/05 2" 6 15015-15035 0 05/16/09 2" 6 15200-15220 0 05/16/09 I 2" 6 15307-15382 0 03/13/04 PBTD I-r 1538571 2-7/8'LNR,6.5#,13CR-80 STL,.0058 bpf,D=2.441" H 15436' ,k DATE REV BY COMMBffS DATE REV BY COMMENTS ENDICOTT UNT 10/15/98 D15 CTD ST(END3-170) 02/04/12 PJC DRAWING CORRECTIONS WELL: 3-17/K-30 03/22/03 D15 SDTRACK(B433-17E) 08/17/12 ?/JMD DRAWING CORRECTIONS RR MT No: 2032160 03/13/04 NORDIC 2 SDTRACK(803-17F) 02/13/13 LEGJMD SET PX PLUG(01/20/13) AR No: 50-029-21946-06-00 05/30/09 RLAVILH C1U FERFS(05/16/09) 05/10/13 JIVIJMD PULLED PX RUG(04/27/13) SEC 8,T11N,R17E,2524'FNL&799'FR 03/18/10 JLW/SV CSG CORRECTIONS 01/05/11 ?/JMD FORMATTED BP Exploration(Alaska) • I Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, September 30, 2013 5:40 AM To: AK, OPS END OIM; AK, OPS END Facility& FieldO&M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead;AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Wallace, Chris D(DOA); Cinelli, Steven Cc: AK, D&C DHD Well Integrity Engineer; Shane.Wills©bp.com; AK, D&C Well Integrity Coordinator; Sayers, Jessica; Regg, James B Subject: NOT OPERABLE: Injector END3-17F/K-30 TD#2032160)Confirmed Starting Head Leak All, Injector END3-17F/K-30(PTD#2032160)was confirmed to have a starting head leak on 09/29/2013. The well is reclassified as Not Operable until the starting head can be repaired and tested. The well is currently shut in,and will be added to the Quarterly Not Operable Injector Report. Plan forward: 1. DHD: MITOA to 1200 psi,and nitrogen pending liquid test results 2. APE: Evaluate for well secure and starting head repair options Please call with any questions. Thank you, Jack Disbrow BP Alaska-Well Integrity Coordinator SCANNED + GWOrganiz ion Office: 907.659.5102 WIC Email:AKDCWellIntegritvCoordinator @bp.com 1 PTh6 Z030160 Regg, James B (DOA) From: Redmond, Randy[RedmonRF @BP.com] Sent: Friday, August 16, 2013 10:54 AM geff 1011143 To: Regg, James B (DOA) Cc: Williams, Bruce J; Price, Bruce; AK, OPS END OIM; AK, OPS FF Well Ops Comp Rep; Daniel, Ryan; Kiorpes, Steve T; Youngmun, Greg L Subject: (PTD 2032160 )Endicott Water Injection SSSV 3-17F Dear Mr. Regg, This is a follow up to the August 13 telephone message that was left with your office, informing the Commission that Endicott water injection well, 3-17F, went 4 days beyond the prescribed 14 day interval for SSSV replacement in accordance with 20 AAC 25.265.(j)(1). Well 3-17F was scheduled for coiled tubing work and the SSSV (MCX) was removed July 23rd of this year, two days prior to the rig work. However, the rig was delayed with the well in operation and was subsequently shut in on August 10th upon discovery. Well work interval 8/11-12 is complete and its SSSV has been reinstalled in accordance with regulations during 8/13-14 with the well in service. In addition, improvements in cross functional communication, operating procedure updates, and additional training relative to Well Water Injection SSSV regulation applicability shall be performed to mitigate further reoccurrence of this oversight. Please contact me directly if there are any concerns or issues to be further discussed. Sincerely, Randy Redmond Mote — nicgv ccute,A $1<ou ) kwe beeµ•,4:2 - fro U cc -( - 2t/ c vrlc- car. h44.423 NEB t 61.96/- w acv Randy Redmond, PE tksikalefrr, BPXA,Operations Full Field OSM Ce —C-14 aC S 4tPk, .- acs RedmonRFABP.com 907-564-4889 cell 907-529-2689 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 S A P �1Z Mr. Jim Regg aci3- �1 SfJ Alaska Oil and Gas Conservation Commission 1, 3 d 333 West 7 Avenue CAsIV 3 1 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 3 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 3 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Endicott Row 3 Date:10/03/10 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement , date inhibitor sealant date ft bbls ft na dal END3-01 / N -29 1861900 50029216780000 7.0 4.4 0.3 9/6/2010 1.70 10/3/2010 END3-03 / J -33 1921210 50029223060000 8.0 6.1 0.3 9/6/2010 2.55 10/3/2010 END3-05 / 0 -29 1861300 50029216240000 3.0 2.0 0.5 9/6/2010 3.40 10/3/2010 END3-07A / L -29 1981470 50029219110100 2.0 0.5 0.3 9/6/2010 1.70 10/3/2010 END3 -09 / L -28A 1950190 50029217800100 0.1 NA 0.1 NA 1.00 10/3/2010 END3 -15 / K-33 1870940 50029217510000 _ 0.1 NA 0.1 NA 1.00 10/3/2010 �.2END3 -17F / K-30 2032160 50029219460600 1.5 0.5 0.5 9/6/2010 2.55 10/3/2010 END3 -19 / R -28 1940490 50029224630000 10.0 17.0 0.3 9/6/2010 1.70 10/3/2010 END3 -21 / L -34 1870330 50029217140000 23.0 14.5 1.1 9/6/2010 13.60 10/3/2010 END3 -23 / N-32 1861550 50029216450000 1.5 1.0 0.5 9/6/2010 3.40 10/3/2010 END3 -27 / M-33 1860830 50029215860000 1.0 0.1 0.6 9/6/2010 2.55 10/2/2010 END3 -29 / J-32 1901560 50029221060000 2.0 1.0 0.6 9/6/2010 3.40 10/2/2010 END3 -31 / K -32 1972270 50029228380000 2.0 3.0 _ 0.5 9/6/2010 3.40 10/2/2010 END3 -33A / J -35 2032150 50029216680100 0.5 NA 0.5 NA 3.40 10/2/2010 END3 -35 / L -36 1870200 50029217010000 10.0 7.0 0.4 9/6/2010 3.40 10/2/2010 END3 -37 / L -35 1950510 50029225540000 8.0 7.3 0.3 9/6/2010 1.70 10/2/2010 END3 -39A /1-37 1970910 50029217640100 1.0 0.8 0.7 9/6/2010 3.40 10/2/2010 END3 -49A / M-40 1970570 50029217350200 0.4 NA 0.4 NA 1.70 10/2/2010 • WELL LQG S TRAAISII~f/TTAL PROACTIVE DIACIN0Si1C SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 [907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and 1) Injection p~,f~lA 2] Signed Print Name: ~~ ~c. ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road suite C Anchorage, AK 99518 Fax: (907) 245-8952 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL _~,~..,,~.~~~~ .,nt+""..~a.3:.7~; i.~Ji?1 WEBSITE t ,tu 7:~, j~_ ~ z ~. 2b3-ar ~ ~9~~~ :~-17F / K-$0 BL/ EDE 50-029-21946-06 :_.~ C'\Documents and Settings\Diane Wilfiarns\Desktop\Transmit_BP.docz 07l14/09 n~~~W~~~~~~~ N0. 5310 ~4laska ~ata & Gonsuiting Services ;`~s:;~ ~~~ i ~:~ r; , t Company: State of Alaska 2525 Gambell Street, Suite 400 *~r» , «~ s~:~ Alaska Oil & Gas Cons Comm nnchorage, ,4EC ss5o3-2838 Attn: Christine Mahnken FsTYN: Beeh 333 West 7th Ave, Suite~ 100 Anchorage, AK 99501 ~11e'I Job # Log Description Date BL Color CD ~ ~~~ a ~-20 AP3Q-00043 SBHP SURVEY O6H7/09 1 1 P2-31 AZCM-00029 LDL G-/ , ' 06/17/09 1 1 12-03 AY1M-00022 SBHP SURVEY 06/15/09 1 1 Z-14~ AYQQ-00036 TEMP SURVEY & BHP . 06/23/09 1 1 RI-16 AP3Q-00042 SBHP SURVEY 6 °- ~ 06/16/09 1 1 V~Q~a, _:;: 11999053 USIT 10/12/08 1 1 ," N-11~ AP3Q-00042 SBHP SURVEY 06/16/09 1 1 ""` 13-12 AY3J-00030 LDL ._ O6/12/09 1 1 L9-30 AVY5-00049 PRODUCTION PROFILE -nj ~ ~ 06/22/09 1 1 17-07B AYQQ-00031 SBHPSURVEY "3 / 3~ O6l11/09 1 1 _ OS-256 AP3~-00040 SBHP SURVEY - 06/11/09 1 1 B-271# AXBD-00028 MEM INJ PROFILE 06/12/09 1 1 11-36 6148-00066 CROSSFLOW & IBP ~- 06/23/09 1 1 ~-214 B14B-00065 SBHP SURVEY 06/21/09 1 1 X-17 AYTU-00043 PROD PROFILE -/ 06/08/09 1 1 ~-25 AWLB-00018 LDL l~~ '(~}`j~ - 05/28/09 1 1 02-338 AYTU-00033 USIT ''~ l 05l19/09 1 1 P2-07 AVY5-00051 PRODUCTION PROFILE ~f ~ 06/25/09 1 1 i3-03 AWLB-00020 LDL O6/01/09 1 1 3-17F/K30 B2NJ-00008 MEM INJ PROFILE U 06/15/09 1 1 MPS-08 AYS4-00080 LDL O6/15/09 1 1 13-1?_ AViH-00019 LDL 07/05/09 1 1 Oi-25 AYTU-00046 USIT ° ~,~ O6/28/09 1 1 UV-390a AWLB-00023 STATIC TEMP SURVEY ~ , O6/26/09 1 1 ~-35 AYTO-00022 SBHP SURVEY - ~ ~ 06/29/09 1 1 Z-16 AV1H-00017 SBHP SURVEY f (} ' 06/29/09 1 1 18-20 8581-00004 LDL - ~ ,~ 06/27/09 1 1 Z-29 AVYS-00053 SBHP SURVEY '~ "~' ~~ a~~~~ ~~~ v~ '~ 07/03l09 1 1 L5-09 AYQQ-00032 . RST C, ~ 06/13/09 1 1 07-10,4 1'fl GACG I~/~V~.If~~1I1 ~ 61JJ-00022 MCNL -- Q( 05/26/09 1 •.-....-~ ~•~.-.~..+~ ..rvv~~ ~ a.r ~ vr~a~~~~v~a e~~~v n~. ~ vn~e~~~V VItlC l~Vf 1 GNVII 1 V. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 • ~ ~ t~ffELL LOG TRAfIfS/t~/Tl~4L pa~ P D'agnosric Seevice, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907} 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing. Inspection(Caliper / MTn The technical data listed below Ls being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the foflowing : ° BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ~~~~ava Cr''~ X03 -2~ ~ ~_--- ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ,~~c/ 130 West International Airport Road Suite C / b0~5 Anchorage, AK 99518 Fax: (907) 245,8952 1} Jevl~lry Log 15-May-09 3-17F/K-30 EDE 50-029-2194Er06 2} Coil Flag 15-May09 3-17F/K-30 EDE • 6 ~- ~. Date : ~~V ~ 3 20G0 Signed ,~l~s: Vii! ~ Cap ~. ~a~stii~~io~ Print Name: ~~c§~~ra~e PROACTIVE DIAGNOSTIC SERVICES, ING., 130 W. INTERNATIONAL AIRPORT ItD SUITE C, ANCiHORAGE, AK 99518 PHONE: (907)245.8951 FAX: (907)245-88952 ^ E-MAIL : ~dsanchoraaeCa?memorvloo.com WEBSITE : .memoryloa.com ` C:\Documenls and Settings\Owner\Desktop\ltans¢dt BP.docx STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS r+~~V ~ ~ EipC 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated ~S ,~ ~~QNV:T,TO Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extensi~ WATER INJ ^°" " 0 Change Approved Program ~ Operat. Shutdown ~ ~ i~~ Perforate Q - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development - Exploratory ~~ 203-2160 - 3. Address: P.O. Box 196612 StratigraphiC Service (~ 6. API Number; Anchorage, AK 99519-6612 50-029-21946-06-00 - 7. KB Elevation (ft): 9. Well Name and Number: 52.6 KB ' 3-17F/K-30 - 8. Property Designation: 10. Field/Pool(s): ADLO-312828 - ENDICOTT Field/ ENDICOTT OIL Pool 11. Present WeII Condition Summary: Total Depth measured 15436 -` feet Plugs (measured) None true vertical 10224.97 - feet Junk (measured) None Effective Depth measured 15385 - feet true vertical 10221.27 - feet Casing Length Size MD TVD Burst Collapse Conductor 142 30" 37 - 179 37 - 179 Production 9941 9-5/8" 47# NT80S 35 - 9976 35 - 7734 6870 4760 Surface 2462 13-3/8" 68# NT80CHY 36 - 2498 36 - 2496 5020 2270 Liner 22 3-1/2" 9.2# 13CR80 13647 - 13669 10066 - 10084 10160 10530 Liner 2871 4-1/2" 12.6# 13CR80 9827 - 13698 7633 - 10108 8430 7500 liner 1716 2-7/8" 6.4# 13CR80 13669 - 15385 10084 - 10221 10570 11160 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 33 - 9856 0 0 - Packers and SSSV (type and measured depth) 4-1/2" HES HXO SSV 1520 " '~' 4-1/2 Baker SAB-3 Packer 9799 S( 4-1/2" Baker ZXP Packer ~~ 9837 4-1/2" Liner Hanger 9848 BAKER LINER TOP PKR 13647 12. Stimulation or cement squeeze summary: Intervals treated (measured): `~ "°y £"a r r ZQv~ ' ~~`` f""~'' ~~,~ '' Treatment descriptions inGuding volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 410 23068 34 2267 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory r Developm ent (~ Service - Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas WAG ~ GINJ ~ WINJ ~- WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-406 Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 z Date 5/18/2009 Form 10-404 Rev' d 04/200 , , _ y ~` ~ ~ r - F j ;- .. __ ~-~~`~ t r Submit Original Only • • 3-17F/K-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY ? 12/18/2008 ""*CONT. WSR FROM 12-17-08*** (pre WI conversion) RAN 2.25" CENT TO 13,661' SLM :RAN PETREDAT GAUGES AS PER PROGRAM (SEE DATA TAB) -GOOD ~ DATA. j RAN 2.25" X 5' PUMP BAILER TO 13,659' SLM, (RECOVERED 2 TBSP SAND) 3 RAN 2.0" LIB TO 13,659' SLM, IMPRESSION OF IBP FN. i ;MADE MULTIPLE ATTEMPTS TO LATCH 2-7/8" IBP AT 13 659' SLM *'*CONT WSR ON 12-19-08**" 12/19/2008"""CONTWSR FROM 12-18-08'*'(WI conversion) PULLED 2-7/8" IBP FROM 13,659' SLM (RECOVERED 2 ELEMENTS, 1 STIFFNER RING) SET 4.5" SLIP STOP CATCHER AT 6,158' SLM PULLED STA.#4 (1.5" RK-S/O) FROM 5,970' MD PULLED STA.#5 (1.5" RK-LGLV) FROM 3,806' MD ;SET STA. #5 (1.5" RK-DMY) AT 3,806' MD jSET STA.#4 (1.5" RK-DMY) AT 5,970' MD PULLED 4-1/2" SLIP STOP CATCHER FROM 6,158' SLM (EMPTY) ;RAN 4.5" WHIDDON C-SUB, UNABLE TO SET DUE TO RESTRICTION AT 10,953' SLM !"""CONY WSR ON 12-20-08"*" 12/20/2008=*** WELL S/I ON ARRIVAL**'(WI conversion) BRUSHED X-NIPPLE AT 9,778' MD W/ 4-1/2" BRUSH, 3.805" G.RING $ET 4-1/2" X- CATCHER AT 9,764' SLM CURRENTLY IN HOLE W/ 4-1/2" OM-1, 1-5/8" JDS ***CONT WSR ON 12-21-08*'`* 12/21/2008 ; Load fluids, road to location ~~~~~~~~~~~~~~~~~~~ ~~ 12/21 /2008 • `** CONT WSR FROM 12-20-08 *"*(WI conversion) PULLED RK-DMY GLV FROM STA #1 @ 9740' SLM *** EMPTY POCKET IN STA #1 **" *** 4-1/2" X-CATCHER SUB LEFT IN HOLE @ 9764' SLM **" *''" WELL LEFT S/I ON DEPARTURE''** 12/21 /2008; ~`*W ELL S/I ON ARRIVAL"*"(W I conversion) R/U SLICKLINE, STBY FOR LRS *"*CONT WSR ON 12-22-08**" 12/22/2008T/I/O=2600/2200/0 Assist S-Line MIT-IA PASSED to 3000 3rd attempt. (Injection Conversion) Load IA with a 10 bbl neat methanol spear, 675 bbls inhibited 1 %KCL. Freeze protected IA w/ 45 bbls inhibited 60/40. while pumping ldown IA Tbg pressured to 3000 psi. bled Tbg pressure down FL. to prevent over pressuring the tbg. Freeze protected Tbg w/ 15 bbls of neat methanol and 5 bbls 3diesel. S-Line set DGLV. Pumped 29.2 bbls of neat methanol into the IA to reach test pressure. MIT IA lost 0 psi in the 1st 15 min and 0 psi in the 2nd 15 min for a ;total loss of 0 psi in the 30 min test. Bled IAP back down to 600 psi before ;getting fluid. gas back to surface during rig down. Final WHP's =1000/1100/0. 12/22/2008 3/8/2009 ***CONT WSR FROM 12-21-08''*"(injection conversion) LRS PUMPED 675 BBLS 1 %KCL TO LOAD IA, 45 BBLS 60/40 ON TOP FOR FREEZE PROTECT. RAN 1.5" DUMMY VALVE WITH RK LATCH SET @ 9733'-SLM, 9749'-MD. LRS FREEZE PROTECTEDTUBING. MIT-IA TO 3000 PSI PASSED. PULLED X-LOCK CATCHER FROM 9764' SLM, RAN 4.5" MCX WITH 1.57" BEAN 4 1/2 X EQ SUB w/ 4ea 3/16" holes {SERIAL # BPX4-67} GOOD CLOSURE TEST. """ RIGGING DOWN TURN WELL BACK TO WELL TENDER.**" T/I/0=2500/950/240. Temp=Hot.- Bleed IA FL to surface (pre-state witness MIT). IA FL @ 942' (51 bbl). Bled IAP to production of well # 21, from 950 psi to 450 psi in 1.5 hr. IA FL unchanged. Final WHPs=2500/450/240. SV=Closed. WV, SSV, MV=Open. IA&OA=OTG. NOVP. ~ • • 3/9/2009iT/1/O=2340/460/160. Temp=Hot. Monitor WHP's & IA FL. (FB). IA FL @ 936' ~ (50 bbl), (rose 6' overnight). TP decreased 160 psi overnight. IAP increased 10 psi overnight. OAP decreased 80 psi overnight. SV=CLOSED. WV, SSV & MV=OPEN. IA & OA=OTG. NOVP. 3/9/2009T/I/O= 2500/600/200 Temp= PWI Pre AOGCC MIT-IA to 2500psi (Reg Compl- ,convert to injection) Pumped 47 bbls 30* 60/40 MW followed by 15.4 bbls neat methanol down IA to reach pressure, IA lost 220 psi in 1st 15 min and 0 psi in 2nd 15 min for a total loss of 220 psi in 30 min test, -----Job In Progress---- ***WSR Continued to 03-10-09*** 3/10/2009]***WSR Continued from 03-09-09*** Temp= PWI Pre AOGCC MIT IA to 2500 ~ ~ PASSED 3rd attempt, (Reg Compl- convert to injection) Pumped .3 bbls (for a ,total of 15.7 bbls neat methanol down IA to bump pressure back up to test ;pressure, IA lost 0 psi in 1st 15 min and 0 psi in 2nd 15 min for a total loss of 0 :.psi in 30 min test, OA pressure climbed to 360 psi due to thermal expansinon, Bleed IAP, Bled back - 4 bbls, Final WHP's 2500/625/220 "Valve 'position @ departure- Swab= SI /Wing, SSV, Master, IA & OA= Open" 3/12/2009~T/I/O= 2290/650/250. Temp= Hot. IA FL. Bleed IAP < 500 psi (pre AOGCC MIT-IA). No integral installed. IA FL @ 30' (2 bbl). Bled IAP to production using 'well END3-15 from 650 psi to 450 psi in 10 min. Monitored for 30 min, IAP sincreased 10 psi, IA FL unchanged. Final WHPs= 2290/460/250. SV= C. WV,SSV,MV= O. IA,OA= OTG. NOVP. 3/14/2009~T/I/O=2420/540/210. Temp=Hot. MIT-IA -PASS with triplex. IA FL near surface. Bled IAP to 400 psi, fluid to surface. Used 6.59 bbl neat meth to pressure IA from `400 psi to 2500 psi. IA lost 0 psi in first 15 min and 0 psi in the second 15 min for ~a total loss of 0 psi in 30 min. OAP increased 10 psi during test. Bled IAP to 540 ;psi (4.42 bbl). Final WHPs=2420/540/210. SV=Closed. WV, SSV, MV=Open. IA&OA=OTG. NOVP. • 3/15/2009 T/I/O = 2260/810/200. Temp = 160". WHP's, IA FL (pre AOGCC MITIA). PWI. IA FL @ surface.. "**No Integral installed***. SV = C. WV, SSV, MV = O. IA, OA = OTG. NOVP. 3/18/2009~T/I/O = 2320/710/170. Temp = 160*. IA FL (pre AOGCC MIT-IA). PWI. IA FL @ surface. '""*No integral installed*** SSV = C. WV, SSV, MV = O. IA, OA = OTG. NOVP. 3/20/2009~T/I/O = 2000/380/0 Temp =Hot AOGCC MIT IA PASSED to 2600 psi ;(Witnessed by Bob Noble) Pumped 5.9 bbls meth to reach test pressure. IA lost 110 psi 1st 15 mins and 0 psi 2nd 15 mins for a total loss of 10 psi in 30 mins. Bled to starting. FWHP's = 2000/450/0 Well is online, casing valves open to ;gauges. Swab closed. T/I/0= 2000/380/0. Temp= Hot. Assist FB w/AOGCC MITIA w. by B. Noble µ (PASSED). IA FL near surface. OA FL near surface. Increased IAP from 380 psi to 2600 psi in 20 min with 5.9 bbls of methanol. OAP remained unchanged during pumping. IAP decreased 10 psi in first 15 min and remained unchanged in second 15 min for a total loss of 10 psi. Final WHPs= 2000/2590/0. ***LRS is bleeding IAP*"". Turned over well to LRS. FLUIDS PUMPED BBLS 97.79 NEAT 675 1 % KCL 92 60/40 METH 5 DIESEL 869.79 Total 3-17F/K-30 203-216 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 3-17F/K-30 3/13/04 PER 15,307. 15,382. 10,212.85 10,221.05 3-17F/K-30 4/30/05 APF 14,816. 14,836. 10,198.77 10,198.61 3-17F/K-30 4/30/05 APF 14,856. 14,876. 10,198.47 10,198.27 3-17F/K-30 5/1/05 APF 14,780. 14,800. 10,197.98 10,198.63 3-17F/K-30 4/17/07 APF 13,910. 13,930. 10,182.92 10,184.68 3-17F/K-30 4/17/07 APF 14,215. 14,235. 10,182.67 10,182.8 3-17F/K-30 4/18/07 APF 14,490. 14,510. 10,178.02 10,177.96 3-17F/K-30 4/18/07 APF 14,215. 14,235. 10,182.67 10,182.8 3-17F/K-30 4/18/07 APF 13,910. 13,930. 10,182.92 10,184.68 3-17F/K-30 7/3/08 APF 13,610. 13,615. 10,035.13 10,039.3 3-17F/K-30 7/3/08 APF 13,632. 13,642. 10,053.45 10,061.77 3-17F/K-30 7/4/08 BPS 13,710. 13,718. 10,118.14 10,124.25 3-17F/K-30 12/19/08 BPP 13,710. 13,718. 10,118.14 10,124.25 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 04/14/09 e7~~~~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth N0.5188 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 well _r.,ti ~ v ~---- ~_. :' a.,i ;+'t t~t~' W-18 11968978 RST -~ YdIC 12/22/08 OL 1 color (~V 1 07-02B AXBD-00013 MCNL - 02/12/09 1 1 K-05C AWJB-00016 MCNL ~ =~ 12!30/08 1 1 F-18A AYLF-00020 CEMENT IMAGE LOG f ~- 03/19/09 1 1 J-09A AP30-00024 STP CROSS FLOW CHECK ~ ~ ~ 03/25/09 1 1 X-05 AYTO-00014 PFCS CALIPER LOG) _ C 04/09/09 1 1 O-04A AYTU-00023 LDL & PLUG SET j~s _ ~~ 04/02/09 1 1 04-40 AYTU-00025 USIT ~ ~ ~- 04/10/09 1 1 06-14B AVYO-00021 SCMT ~ _ ~- 04/01/09 1 1 Z-01 B AVYO-00025 INJECTION PROFILE - /b ~~ 04/11/09 1 1 L3-15 AYTU-00023 _ ~ _ PRODUCTION PROFILE ~ ' 04/06/09 1 1 11-30 AXBD-00021 MEM PROD PROFILE ~ cJ _ ~- 04/14!09 1 1 3-03/J-33 AZ4D-00013 RST WflNJ PROFILE - j - ~ a 04/05/09 1 1 3-17F/K-30 BIJJ-00006 MEM INJECTION PROFILE - ( J 04/03/09 1 1 3-49A/M-40 AXBD-00019 MEM INJECTION PROFILE: 04/07/09 1 1 V-114A ~ ~'- AVY500032 INJECTION PROFILE - j ~shb 04!02/09 1 1 L ---- i t.,3 I ` ~. ~_ THESE 2 WELLS WERE DELIVERED SEPARETLY TO MEET COMPLIANCE TRANS # 5185 E-36A AYTU-00006 OH MWD/LWD EDIT (IFLEX) j _~- ~l-a9 01/14/09 1 1 MPS-43 AXML-00020 OH LDWG EDIT 12!29/08 2 1 PLEASE ACKNOWLEDGE RE CE~pr av crr_nn nrr_ n~in ocrno~uw~n .,.~~ ...,..., ~..... ~.._ BP Exploration (Alaska) Inc. -- °° " ~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503 838 ATTN: Beth Received by: 1I u ._ ~~` MEMORANDUM To~ Jim Regg ~ ~ ~ 3~Z-7~p~ P.I. Supervisor FROmI: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, Mazch 24, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 3-17F(K30 DUCK IS iTNIT SDI 3-17FlK30 Src: Inspector 1V[lN_(`n1vFmFNTIAL Reviewed By: P.I. Suprv r~,~- Comm Well Name: DUCK IS UNIT SDI 3-17F/K30 API Well Number: 50-029-21946-06-00 Inspector Name: Bob Noble Insp Num: mitRCN090321150640 permit Number: 203-216-0 ~ Inspection Date: 3/20/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3-17FiK3° Type Inj. W TVD 7614 ~ 390 2600 - 2590 ?590 P.T. zo3zl6o TypeTest SPT Test psi z6oo pA o 0 0 0 Interval ~T~ ~ P/F P `' Tubing zooo zooo 200o zooo Notes: ~~~- TUB ~~~ ~ ~ ~~Z ~ ~ ~z C~t~.~'t„-~ ~ q ~ 4 `~z. `' ~3 ~~~- s~g~ 3 ~t f e~.~~,,n1t' Stvrt,~.~ ~ ~CUw~ 7.~.c~l. ~3-~ 7 ~ ~ i ~j~-c~a 3 \ ~~ `rU 5 1 ~'~ ~~ k ` ~4~ _r itb3E,-- `3~9r1) \7 7~ -144&`\ l~o~~ ~?44 X = ~ S~z-~ ~TU~ Xs Tuesday, Mazch 24, 2009 Page 1 of 1 ~~V~~[~ OG~~,1L~~'SI~F';l ALA5SA OII, A1~TD GAS CO1~T5ERQATIOI~T COMl-II55I01~ Jack Lau PE BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Endicott Field, Endicott Oil Pool, 3-17/K-30 Sundry Number: 308-406 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 2,b1~ ~~~~ ~~ [~ 2~0~ Dear Mr. Lau: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants far 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. Sincerely, 0~~ Cathy P. Foerster Commissioner DATED this ~ day of November, 2008 Encl. • ~~ STATE OF ALASKA X135 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Q ~~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Othe ~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate^ Time Extension ^ CONVERT TO Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ WATER INJECTOR 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development^~ Exploratory ^ 203-2160- 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21946-06-00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: 3-17F/K-30 ~ Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ~ ADLO-312828 52.6 KB ENDICOTT Field / ENDICOTT OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15436 _ 10224.97 - 15385 10221.27 , 13715 ~ NONE Casing Length Size MD TVD Burst Collapse Conductor 142 30" 37 179 37 179 Production 9941 9-5/8" 47# NT80S 35 9976 35 7734 6870 4760 Surface 2462 13-3/8" 68# NT80CHY 36 2498 36 2496 5020 2270 Liner 22 3-1/2" 9.2# 13CR80 13647 13669 10066 10084 10160 10530 Liner 2871 4-1/2" 12.6# 13CR80 9827 13698 7633 10108 8430 7500 Liner 1716 2-7/8" 6.4# 13CR80 13669 15385 10084 10221 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see attached - - 4-1/2" 12.6# 13Cr80 33 - 9856 Packers and SSSV Type: Baker Liner Top Packer Packers and SSSV MD (ft): 13647 4-1/2" Baker SAB-3 Packer 9799 4-1/2" Baker ZXP Packer 9837 4-1/2" Liner Hanger 9848 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/20/2008 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ i WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Lau Printed Name ack au Title PE Signature Phone 564-5102 Date 11/6/2008 COMMISSION USE ONLY Conditions of app val: Notify Commission so that a representative may witness Sundry Number: ~ - ~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: ~_ 17~,~ ~V APPROVED BY p Approved by: COMMISSIONER THE COMMISSION Date: ~~- -Q~ Form 10-403 Rewsed 06/200 `~~ ~ ~ t~ Submit in Duplicate ~I~AL ~~~~ ~ ~oo~ 3-17/K-30 203-2160 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 3-17E/K-30 3/22/03 PER 13,854. 13,879. 10,238.63 10,259.52 3-17E/K-30 3/29/03 APF 13,854. 13,874. 10,238.63 10,255.34 3-17E/K-30 4/1/03 APF 13,816. 13,826. 10,206.9 10,215.24 3-17E/K-30 11/29/03 APF 13,772. 13,777. 10,170.19 10,174.36 3-17E/K-30 118/04 BPS 13,797. 13,879. 10,191.04 10,259.52 3-17E/K-30 1/27/04 APF 13,719. 13,729. 10,125.96 10,134.31 3-17E/K-30 2/20/04 AB 13,719. 13,879. 10,125.96 10,259.52 3-17F/K-30 3/13/04 PER 15,307. 15,382. 10,212.85 10,221.05 3-17F/K-30 4/30/05 APF 14,816. 14,836. 10,198.77 10,198.61 3-17F/K-30 4/30/05 APF 14,856. 14,876. 10,198.47 10,198.27 3-17F/K-30 5/1/05 APF 14,780. 14,800. 10,197.98 10,198.63 3-17F/K-30 4/17/07 APF 13,910. 13,930. 10,182.92 10,184.68 3-17F/K-30 4/17/07 APF 14,215. 14,235. 10,182.67 10,182.8 3-17F/K-30 4/18/07 APF 13,910. 13,930. 10,182.92 10,184.68 3-17F/K-30 4/18/07 APF 14,215. 14,235. 10,182.67 10,182.8 3-17F/K-30 4/18/07 APF 14,490. 14,510. 10,178.02 10,177.96 3-17F/K-30 7/3/08 APF 13,610. 13,615. 10,035.13 10,039.3 3-17F/K-30 7/3/08 APF 13,632. 13,642. 10,053.45 10,061.77 3-17F/K-30 7/3/08 BPS 13,715. 15,382. 10,121.99 10,221.05 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SOF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SOZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • Endicott DIU :~-1zJK-:~o (ZO:~2160) Current Status Natural producer End 3-i~F/K-3o is a coil tubing sidetrack targeting the 2A sands of the Kekiktuk formation. A MITOA passed to iooo psi in Dec-o3 demonstrating surface casing integrity. A MITIA passed to 300o psi pre-Coil Tubing Drilling in Feb-o4 demonstrating tubing and production casing integrity. A subsequent TIFL passed in Nov-off verifying tubing integrity. The reservoir management plan forward is to convert ENDS-i~ to 2A and 2B water injection to support offset producers 4-ioA and 3-25B. 3-17A will be in compliance with BP internal well integrity policy for operation seeing that the IA passes a MITIA. Completion In 2004 the well of interest, 3-1~F/K-3o, was sidetracked out of 3-i~E with a 3.75" bit at 13,697'MD. A 2-~/8" liner was run to i5,385'MD and hung off from the 41/2" liner at ~3,647'MD. It was cemented with 21 bbls of class G cement with no recorded losses. The 41/2" liner was run to i4,o48' and hung off the 9-5/8" casing at 9,837'MD. It was cemented with 185 bbls of class G cement with no recorded losses. The completion crossed the Kekiktuk formation at 13,4i3'MD. The K2A was initially perforated and produced until Jul-o8 when an inflatable bridge plug was set to for zonal isolation. Perforations were subsequently added to the K2B and are currently the sole producing interval. Plan Forward• i) Obtain Sundry for conversion to water injection 2) Pull IBP from i3,~15'MD. Pull LGLV's. Set DGLV's. 3) Place well on water injection (confirm AOGCC approval prior to injection) 4) AOGCC witnessed MITIA to 250o psi once injection has stabilized 7A~E: x-9,2° 9 Asa Gtuc~ ~CdvV ~Y`E~HE~:93 5,~° 5&7L1r~ psi FMS NS ft's. ELEt~' = 52.~,f SF ELEV = 95.'~ ~3 ~'~.~°' 72~t,~rt 2~`~d$` ~ 228 .f~5 3-7;`2' 1'7 ~x4.~ft 13 ~.~9 "~~~1.~ r'~C E 'UB1Ni, ~q saF~~ ~T~: ~C~~°~ 8 a t 3' -A,Fi. ~ ~I I.1;5T F~P~~3 ~~ .,t --- - i ~: _ - ~~.a t . --- _ , i ~. _ ~ +a-trz xrart?~E ~77a :_ 3..81.3°9Ld .'A' x 4 -1 ~ ~~' $~1JiEFi~. ~3 ~'tt~Z 9794 4:~~"a° ~;' frSF'PLE 3.813 ~L 9A23 kSLlt r~ ~~;~ r 2s :~G x 7s~ 3~ r r e~r4 ~~~vE ~z~ ~~5,'8`xR-t2`i{.~ L.il~€~ F:>k:KER 1383T 9.5.x` x 4~i12:"LiNEtY hi~fi;rE.,l~. }898 ' E 1$ L1tw~3$ 7~~' ;a.Av~ ~,a38t~ I~ S 3+5p7 '.f:x?718X•~JV~K 13€fi4 +1.1,"Ft26kTHt?f1A~~5-~M(5g~7 ~ Z 71~ ~H,. L.~}{1:13%.r S TL LING h" 2:371 c :^~:_ }~ ~TQ 793E"YI~.~"Y,'H'+1 i~@ '~VtTN3'fiA" ~'9G`.S ~! '37~fJMS3 ~R~}tJ! 13579 - i'.SG3n ~. -. I - - ., ~ - _., t '-. C f 6. _ _. .. • Area of Review -Endicott DIU :~-17F/K-~o (2o:~2i6o) Subsequent to the conversion of we113-1~F/K-3o from producer to water injector an Area of Review (AOR) is obligatory. This AOR will discuss the wells within 1/a mile of said well's entry point into the Kekiktuk Formation to the bottom of well bore completion. Nine individual well bores enter the AOR of 3-1'J at the top of the Kekiktuk to bottom of wellbore completion. The following table illustrates the nine wells within the AOR, their respective distances from 3-~~, completions detail, and any annulus integrity comments based on an in-depth review of each well. Well Name PTD Distance, Ft. Annulus Inte rity 3-o7A/L-29 i98i47o 2489 TOC calculated to be above injection zone 3-o9A/L-28 i95oi9o 1564 TOC calculated to be above in~ection zone 3-11/M-3o 1880870 1009 TOC calculated to be above injection zone 3-17/J-3o i89o530 1150 P8tA, TOC calculated to be above injection zone 3-17A/J-3oa i94o460 1093 P&A, TOC calculated to be above injection zone 3-17E/K-3o 2022470 o P8rA, TOC calculated to be above injection zone 3-31/x-32 1972270 2268 TOC calculated to be above injection zone 4-1o/M-28 1940500 1896 P&A, TOC calculated to be above injection zone 4-loA/L-28 2022380 1273 TOC calculated to be above injection zone Figure is Wells within AOR Well Name Casing Size Hole Size Vol Cement Kekiktuk De th 3-o7A/L-29 2 7/8" 33/4" 25 bbls 12,487' MD 3-o9A L-28 5" 8'/z" i bbls 13,390' MD 3-11/M-3o 7" 8'/z" 57 bbls 12,697 MD 3-17/J-3o 2 7 8" 33/a" 21 bbls 13,385' MD 3-17A/J-3oa 7" 8'/z" 67 bbls 13430' MD 3-17E/K-3o 41/z" T/z" 185 bbls 13,413' MD 3-31 K-32 7 5 8" 9 7 8" 84 bbls 12,550' MD 4-to/M-28 7 5 8" 9 7 8" 9o bbls 12,630' MD 4-1oA/L-28 41/2" 63/a" 75 bbls 13,208' MD Figure 2: Completion Detail In we113-o~A/L-2g (PTD 1981470), a ~" liner was run to 13,o5o'MD and hung off at 11,83o'MD. It was cemented with 69 bbls of class G cement with no recorded losses. o • In we113-o9/L-28A (PTD i95o190) a 5" liner was run to 14650 MD and hung off at 12,477 MD. The completion crossed the Kekiktuk formation at 13930' MD. The 5" liner was cemented with 195 bbls of class G cement and no losses were noted. In we113-~~/M-3o (PTD 188080) a 5" liner was run to 14650 MD and hung off at 12477 MD. The completion crossed the Kekiktuk formation at 13930' MD. The 5" liner was cemented with 195 bbls of class G cement and no losses were noted. In well 3-1~/J-3o (PTD 1890530) a 2 ~~s" liner was run to 15436' MD and hung off at 13,647' MD. The completion crossed the Kekiktuk formation at 13,385' MD. The 2 ~~s" liner was cemented with 21 bbls of class G cement, full returns were noted. We113-1~ A /J-3o (PTD 1940460) was sidetracked from 3-1~A. A ~" liner was run to 14,109 MD and hung off at 12,446 MD. The completion crossed the Kekiktuk formation at 13430' MD. The ~" liner was cemented with 6~ bbls of class G cement and no losses were noted. We113-1~E/K-3o (PTD 2022470) was plugged and abandoned with 185 bbls of class G cement and no losses were reported. A 41/2" liner had been run to 14,048' MD and hung off at 9,82' MD. This sidetrack completion had been drilled in Feb. 2003 and crossed the Kekiktuk formation at 13,413' MD. It serves as the parent wellbore for 3-1~F/K-3o which ends up outside the 1/4 mile limit. We113-31/K-32 (PTD 197220) is just 50' beyond the 1/4 mile limit and thus included here as well. A ~ 5~8" liner was run to 13,1oy' MD and hung off at 39' MD. The completion crossed the Kekiktuk formation at 12,550' MD. The ~ 5~s" liner was cemented with 84 bbls of class G cement and no losses were noted. We114-1o/M-28 (1940500) is the parent well for 4-1oA/L-28 whose original ~ 5/8" casing was hung from 41' and run to 14,4og and cemented with go bbls of class G cement. This completion was plugged and abandoned with 26 bbls of class G cement with a top at 13,730. The cemented portion of the completion crossed the Kekiktuk at 13,630' MD. We114-1oa/L-28 (PTD 2022380) was sidetracked from parent we114-1o/L-28 in 2003. A 41/2" liner was run to 13,864'MD and hung off at ~1,57o'MD. The 41/2" liner was cemented with 75 bbls of class G cement and no losses were indicated. The completion crossed the Kekiktuk formation at 13,208' MD. __ STATE OF ALASKA ~ ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ~~~~~ ~`1'" .~ LOi-~S 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ " "°` ~';~tYyer ~ • - Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ ~X;'? Change Approved Program ~ Operat. Shutdown ~ Perforate ~' Re-enter Suspended Well[] e 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ ~ Exploratory 203-2160 3. Address: P.O. Box 196612 Stratigraphic ~' Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21946-06-00 ` 7. KB Elevation (ft): 9. Well Name and Number: 52.6 KB' 3-17F/K-30 - 8. Property Designation: 10. Field/Pool(s): ADLO-312828' ENDICOTT Field/ ENDICOTT OIL Pool 11. Present Well Condition Summary: Total Depth measured 15436 - feet Plugs (measured) l~1e ~~~ ~ c'? ~, ` J true vertical 10224.97 ~ feet Junk (measured) None ~,y~ ~ //~ Effective Depth measured 15385 - feet ~~~ JUL ~. '~ 200 true vertical 10221.27 ~ feet Casing Length Size MD TVD Burst Collapse Conductor 142' 30" Conductor 37' - 179' 37' - 179' Production 9941' 9-5/8"47# NT80S 35' - 9976' 35' - 7734' 6870 4760 Surface 2462' 13-3/8" 68# nt80cyh 36' - 2498' 36' - 2496' 5020 2270 Liner 22' 3-1/2" 9.2# 13CR80 13647' - 13669' 10066' - 10084' 10160 10530 Liner 3871' 4-1/2" 12.6# 13CR80 9827' - 13698' 7633' - 10108' 8430 7500 Liner 1716' 2-7/8" 6.4# 13CR80 13669' - 15385 10084' - 10221' 10570 11160 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 33 - 9856 0 0 - Packers and SSSV (type and measured depth) 4-1/2" HES HXO SSV 1520 4-1/2" Baker SAB-3 Packer 9799 4-1/2" Baker ZXP Packer 9837 4-1/2" Liner Hanger 9848 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 Casing Pressure Tubing pressure Prior to well operation: 1039 26591 51 2542 Subsequent to operation: 1273 23031 57 629 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development ~ Service !~' Daily Report of Well Operations X 16. Well Status after proposed work: Oil ` Gas ~`'~'' WAG ~ GINJ WINJ ~ WDSPL ~' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 7/11/2008 C~ Form 10-404 F,~bvised 04/200 ~ ` ~ ~ ~~ / ~ L ~' `~~~- ~ ~ 108 Submit Original Only ,!~-~ ~ ~ ~ 3-17/K-30 203-2160 PERF ATTACHMENT L' Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 3-17F/K-30 3/13/04 PER 15,307. 15,382. 10,212.85 10,221.05 3-17F/K-30 4/30/05 APF 14,816. 14,836. 10,198.77 10,198.61 3-17F/K-30 4/30/05 APF 14,856. 14,876. 10,198.47 10,198.27 3-17F/K-30 5/1/05 APF 14,780. 14,800. 10,197.98 10,198.63 3-17F/K-30 4/17/07 APF 13,910. 13,930. 10,182.92 10,184.68 3-17F/K-30 4/17/07 APF 14,215. 14,235. 10,182.67 10,182.8 3-17F/K-30 4/18/07 APF 13,910. 13,930. 10,182.92 10,184.68 3-17F/K-30 4/18/07 APF 14,215. 14,235. 10,182.67 10,182.8 3-17F/K-30 4/18/07 APF 14,490. 14,510. 10,178.02 10,177.96 3-17F/K-30 7/3/08 APF 13,610. 13,615. 10,035.13 10,039.3 3-17F/K-30 7/3/08 APF 13,632. 13,642. 10,053.45 10,061.77 3-17F/K-30 7/3/08 BPS 13,715. 15,382. 10,121.99 10,221.05 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE '~ r 3-17F/K-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY TIVITYDATE i SUMMARY 7/3/2008' T/I/0=2800/1900/vac Temp S/I Assist E-line.(Perforate) Pumped 3 bbls neat 'meth, 279 bbls 1 % KCL, and 15 bbls inhibited 60/40 meth down TBG to kill the 'well. FWHPs= 400/1850/0 Valve positions upon departure; Swab open (E- line still on well), Wing shut, SSV open, Master open, IA open, OA open. 7/3/2008 ***CONTINUED FROM 3-JUL-2008'`*'` ELINE SET 1.69" BAKER IBP MID-ELEMENT IN 2-7/8" LINER AT 13.715 FT, TOP LOCATED 13710 FT. BOTTOM 13718.15 FT. FISHING NECK 1.188" OD, REQUIRES 1-1/2" PULLING TOOL WITH 5520# TO RELEASE. PERFORATED 13.632-13,642 FT WITH 2.0" HSD OMEGAJET, 6 SPF, 60 DEGREE PHASE. PERFORATED 13.610-13.615 FT WITH 2-7/8" HSD OMEGAJET, 6 SPF, 60 DEGREE PHASING. `***JOB COMPLETE*** FLUIDS PUMPED BBLS 1 diesel 1 Total • ~ ~-..~ . t _: --, ~~°':, _ a ~` <:.. :~ ,~: MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CvrPgs_Inserts\Microfilm_Marker. doc Schlumbel'ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 10/25/07 f)GA.~NED OCT S 1 2007 NO. 4464 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Aurora, Milne Pt., pt. Mac Well Job# Loa Descri[ Ition Date BL Color CD W-19AL 1 11890312 SBHP & TEMP ;::)1"\:4 - ~ I~ "' 09/29/07 1 17-19A 11855512 SBHP SURVEY lo,~~f1< -. ~ 09/26/07 1 V-04 11855513 SBHP SURVEY .:-.1f"1(/> - 1:-:< <-I 09/27/07 1 Z-21A 11594526 SBHP SURVEY .:::vJO -I/') I 10/07/07 1 Z-03 11767142 LDL IC "+--f; I 1 0/01/07 1 05-38 11686787 LDL ICJ _ -11 ;ç,:,:- 09/27/07 1 Y-29A 11855514 DDL IC 'lð - l "91. I 09/28/07 1 B-16 11676969 PRODUCTION PROFILE f-:¡ -n:JS 10/12/07 1 Z-22B 11594525 SBHPSURVEY--- ~~. :A_fL. 10/06/07 1 Z-14B 11849935 SBHP SURVEY ':;1"'1(o-rR 1 0/02/07 1 P2-45A 11594529 SBHP SURVEY J C; q - N...J (f 10/16/07 1 17 -09 11846820 LDL ì1rI-(')Q () 10/19/07 1 F-33 11661176 MEMORY SBHPS I &)lL, - ("\(")~ 1 0/19/07 1 4-08/P-27 11630506 LDL I)-a'. 115"1- - {)l....-K 10/04/07 1 3-17F/K-30 11649961 MCNL .;;)t>'?, -::J.il A 'it ¡¿:;lA/4 04/17/07 1 1 MPB-50 40011604 OH MWD/LWD EDIT Ü ," ""I...L /- ~ 157/'1/,'<, 02/27/05 2 1 S-125 40015467 OH MWD/LWD EDIT "::>()~-rY7'i?" It. #~ l,Q 07/14/07 2 1 . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 8 ATTN: Beth Received by: ~ .. STATE OF ALASKA . ~-J¿)--o~ AlðA Oil AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS D D o 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing [] Change Approved Program D Ope rat. Shutdown [] 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 52.6 KB' 8. Property Designation: ADLO-312828 I 11. Present Well Condition Summary: Total Depth measured 15436 / true vertical 10224.97 Effective Depth measured 15385 true vertical 10221 .27 Casing CONDUCTOR Production Liner Liner Surface Liner Length 142' 9941' 22' 3871' 2462' 1716' Size 30" Conductor 9-5/8" 47# NT80S 3-1/2" 9.2# 13Cr80 4-1/2" 12.6# 13Cr80 13-3/8" 68# NT80CYH 2-7/8" 6.4# 13CR80 Perforation depth: Measured depth: 13910' - 15382' True Vertical depth: 10182' - 10221' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 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: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations OiI-Bbl 999 801 x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development W Stratigraphic feet feet RECEIVED APR 2 6 2007 StimulateD mä2fa[öì & Gas CeRs Cemmi sion Waiver D Time Extension D A h . Re-enter Suspended Well D nc orage 5. Permit to Drill Number: 203-2160 / Exploratory Service 6. API Number: 50-029-21946-06-00 - 9. Well Name and Number: 3-17F/K-30 ' 10. Field/Pool(s): ENDICOTT Field/ ENDICOTT OIL Pool F Plugs (measured) Junk (measured) SCI1NNE[.ì MAY () 2 2007 None None feet feet MD 37' - 179' 35' - 9976' 13647' - 13669' 9827' - 13698' 36' - 2498' 13669' - 15385' - - 4-1/2" 12.6# TVD 37' - 179' 35' - 7734' 10066' - 10084' 7633' - 10108' 36' - 2496' 10084' - 10221' Burst Collapse 6870 4760 10160 10530 8430 7500 5020 2270 10570 11160 - - 13Cr80 33 - 9856 4-1/2" HES HXO SSV 4-1/2" Baker SAB-3 Packer 4-1/2" Baker ZXP Packer 4-1/2" Liner Hanger Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 25815 16 0 23549 24 0 15. Well Class after croposed work: Exploratory Development W 16. Well Status after proposed work: Oil W Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Printed Name Signature Title Phone ORIGJNAL 1520 9799 9837 9848 Tubing pressure 2339 2375 Service WINJ WDSPl Data Management Engineer 564-4944 Date 4/24/2007 Submit Original Only . . 3-17FIK-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/17/2007 *** #5 job from 4/16/2007*** RIH w. SLB Load well and log per procedure. Stop @ 14100' paint white flag for gun runs, POOH, Good data recovered + 44' correction, RIH w. gun #1 perf per procedure 14490'-14510' POOH ***Continue job on 4/18/2007*** 4/18/2007 *** CTU #5 Continue job from 4/17/2007 *** RIH. Correct at coil flag to 14125' (top shot). RIH and perforate 14215' to 14235'. POOH. Confirm guns fired and recover 1/2" ball. PT MHA to 3500psi. MU final gun. RIH. Correct at coil flag to 14125' (top shot). PUH and perforate 13910' to 13930'. POOH. At surface, confirm all shots fired and recover 1/2" ball. Pump N2 to displace fluid from CT. *** Job continued on WSR 04/19/2007 *** 4/19/2007 #5. Rig down *** from WSR 04/18/2007 *** Blow down CT with N2. RD CTU. Notify well tender of well status. Well popped by well tender. Go to weather standby at 04:00 due to high winds until 17:00. RDMO CTU *** Job complete *** FLUIDS PUMPED BBLS I 72 60/40 Meth 72 Total i 04/05/07 Scblullburger .............,-_. ..,,~ NO. 4210 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, Ate 99503·2838 ATTN: Beth 003 - 8}(o -¢ 1'-I5~L..f SCANNED APR 1 0 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Loa Description Date BL Color CD VI/-25 10980555 RST(REDO) 05/02/05 1 N..07A 11296715 RST 09/11/06 1 1 F-06A 11258688 RST 03/03/06 1 1 18-16B 11588702 MCNL 12/27/06 1 1 06-09 11320999 RST 08/02/06 1 1 X-15A 10928631 MCNL 05/11/05 1 1 01i-09 11223132 RST 08/02/06 1 1 3-17F/K-30 10728392 MCNL 03/12/04 1 1 . . PLEASE ACKIIIIOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Aoc""""., AK ""'U ATTN: Beth e Received bY:, ~ RECEIVED Date Delivered: .APR 0 {) 7007 f\ïæka Oil & Gas Cons. Commission AnchoragE'. DATA SUBMITTAL COMPLIANCE REPORT 10/2/2006 Permit to Drill 2032160 Well Name/No. DUCK IS UNIT SDI3-17F/K30 Operator BP EXPLORATION (ALASKA) INC S,,~l. ~~ ~J, ~'-I API No. 50-029-21946-06-00 MD - 15436 TVD 10225./ Completion Date 3/13/2004 ".- Completion Status 1-01L Current Status 1-01L UIC N --~.~--~- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes -~- DATA INFORMATION Types Electric or Other Logs Run: MWD GR / ROP/ RE, MGR / CCL / CNL (data taken from Logs Portion of Master Well Data Maint Well Log Information: . Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Tyee Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~ D Asc Directional Survey 4/19/2004 f: Directional Survey 4/19/2004 C Lis 12569 Induction/Resistivity 0 0 7/15/2004 INTEQ META, TIF, GR, MPR, GRAPHICS Iyg Gamma Ray 25 Blu t\b 13698 15436 Open 7/15/2004 INTEQ META, TIF, GR, MPR, GRAPHICS, DSN ~g 12569 Induction/Resistivity 25 Blu 1 ".0 13698 15436 Open 7/15/2004 DSN 12569 E Induction/Resistivity 25 Blu 1 'Tv 0 13698 15436 Open 7/15/2004 DSN 12569 LIS Verification 0 0 7/15/2004 DSN12569 C Lis 12570 Gamma Ray 0 0 7/15/2004 GRAPHIC IMAGE FILES, GR, LlS-TIF, MWD 09 Gamma Ray 25 Blu MD 0 0 Open 7/15/2004 GRAPHIC IMAGE FILES, . I GR, LlS-TIF, jSN12570, r MWD 1} I Gamma Ray 25 Blu 1 TV}) 0 0 Open 7/15/2004 GRAPHIC IMAGE FILES, GR, LlS-TIF, DSN12570, MWD f?t) f I Rpt LIS Verification 0 0 7/15/2004 DSN12570 .k'-- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Permit to Drill 2032160 MD 15436 TVD 10225 ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? ~ ------ Analysis Y / N Received? DATA SUBMITTAL COMPLIANCE REPORT 10/2/2006 Well Name/No. DUCK IS UNIT SDI3-17F/K30 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21946-06-00 UIC N Comments: Completion Date 3/13/2004 Current Status 1-01L Completion Status 1-01L Daily History Received? ~N "/N Formation Tops Com~lan'e Revlewe. By, ---=~ Date: ~, ~¿J- ~ \p . . , . STATE OF ALASKA . ALAS~IL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS N 1. Operations Performed: c'· ;, Qth~r.O Abandon D Repair WellD Plug PerforationsD Stimulate D Alter CasingD Pull TubingD Perforate New Pool D WaiverD Time ExtensionO Change Approved Program D Operation Shutdown 0 Perforate IKI Re-enter Suspended wellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD 203-2160 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D ServiceD 50-029-21946-06-00 7. KB Elevation (It): 9. Well Name and Number: 52.60 3-17F/K-30 8. Property Designation: 10. Field/Pool(s): ADL-312828 Endicott Field / Endicott Oil Pool 11. Present Well Condition Summary: Total Depth measured 15436 feet true vertical 10225.0 feet Plugs (measured) None Effective Depth measured 15385 feet Junk (measured) None true vertical 10221.3 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 142 30" Conductor 37 - 179 37.0 - 179.0 LINER 22 3-1/2" 9.2# 13Cr80 13647 - 13669 10065.9 - 10084.3 10160 10530 LINER 3871 4-1/2" 12.6# 13Cr80 9827 - 13698 7632.8 - 10108.4 8430 7500 LINER 1716 2-7/8" 6.4# 13CR80 13669 - 15385 10084.3 - 10221.3 10570 11160 PRODUCTION 7699 9-5/8" 47# NT80S 35 - 9976 35.0 - 7734.0 6870 4760 SURFACE 2462 13-3/8" 68# NT80CYH 36 - 2498 36.0 - 2495.5 5020 2270 Perforation depth: Measured depth: 14780 -14800,14816 -14836,14856 -14876,15307 -15382 True vertical depth: 10197.98 -10198.63,10198.77 -10198.61,10198.47 -10198.27,10212.85 -10221.05 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 33 - 9856 Packers & SSSV (type & measured depth): 4-1/2" Liner Hanger @ 9848 4-1/2" Baker SAB-3 Packer @ 9799 4-1/2" Baker ZXP Packer @ 9837 4-1/2" HES HXO SSV @ 1520 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Me! Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 9 28930 0 0 1721 Subsequent to operation: 3354 7109 287 0 2384 14. Attachments: 15. Well Class alter proposed work: ExploratoryD Development ŒI Service D Copies of Logs and Surveys run _ 16. Well Status alter proposed work: Daily Report of Well Operations_ ~ Oil[!] GasD WAGD GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 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: Contact DeWayne Schnorr N/A Printed Name DeWayne Schnorr Title Petroleum Engineer AI ð'>/ ~_-1~¡ Signature .A 'JO b7 . Phone 564-5174 Date 6/8/05 '.I I Þ\L RBDMS BFl JUN 092005 Form 10-404 Revised 4/2004 . . 3-17F/K-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/30/05 CTU #5, ADD PERF; RIH IN HOLE WITH PDS GR/CCL WHILE DISPLACING WELL WITH 1% KCL W/2% LUBTEX. PUH LOGGING FROM 15000' TO 14200' CTMD. FLAG PIPE @ 14900' CTMD. POOH. GOOD DATA (+23' CORRECTION). MU AND RIH WITH GUN #1 (SWS 20' - 2" PJ2006 HMX @ 6 SPF). MAKE DEPTH CORRECTION AT FLAG. PERFORATE 14856' TO 14876'. PUMP 1% KCL W/ LUBTEX DOWN BACKSIDE AT MIN RATE WHILE POOH. MU AND RIH WITH GUN #2 (SWS 20' - 2" PJ2006 HMX @ 6 SPF). PERFORATE 14816' TO 14836'. PUMP 1% KCL W/ LUBTEX DOWN BACKSIDE AT MIN RATE WHILE POOH. MU AND RIH WITH GUN #3 (SWS 20' - 2" PJ2006 HMX @ 6 SPF). 05/01/05 CTU #5, ADD PERF; CONTINUE RIH WITH PERF GUN #3 (SWS 20' - 2" PJ2006 HMX @ 6 SPF). MAKE DEPTH CORRECTION AT FLAG. PERFORATE AT 14780' TO 14800'. PUMP 1% KCL W/ 2% LUBTEX WHILE POOH. AT SURFACE PUMP 6 BBLS METH FOR FREEZE PROTECT. LEAVE WELL SHUT IN. ******JOB COMPLETE****** 05/05/05 *** WELL FLOWING UPON ARRIVAL *** RAN 4 1/2 BRUSH, 3.75 GAUGE RING, BRUSHED 1486 SLM. RAN 41/2 X-LINE, 41/2 BBE VALVE SERIAL#. (BB-469), SET @ 1487 SLM. PREFORMED CLOSURE TEST. BLED DOWN 300 PSI, HOLDING GOOD, RDMO *** LEFT WELL SHUT IN. ,TURNED WELL OVER TO WELL TENDER.*** FLUIDS PUMPED BBLS 118 60/40 METHANOL 154 1 % KCL WITH 2% LUBTEX 272 TOTAL Page 1 TREE: 4-1/2" 5000 psi Chrome CIW WELLHEAD:13 5/8" 5000 psi FMC NS RT. ELEV = 52.60' BF. ELEV = 15.75' 13 3/8" 72#/ft L-80 BTC CSG I 2498' . 228 JTS 4-1/2" 12.6#/ft 13 CR L-80 VAM ACE TUBING GAS LIFT MANDRB...S (CAMCO-MMGM) ST MD TVD VLV LATC PORT DATE 5 3806 3620 RK 4 5970 5015 RK 3 7510 6008 RK 2 8882 6915 RK 1 9749 7521 RK 4 1/2" 12.6# CHROME HYDRIL 563 LINER PERFORA TION SUMMARY REF LOG: SWS PDC 03/22/03 ANGLE AT TOP PERF: ?? @ 14780' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL OA TE 2" 6 14780 - 14800 0 04/30/05 2" 6 14816 - 14836 0 04/30/05 2" 6 14856 - 14876 0 04/30/05 2" 6 15307 - 15382 0 ** KEY: 0 = OPEN / C = CLOSED / SQZ=SQUEEZED END3-17F FETY NOTES: o HES 'HXO' SVLN 3.813" MIN. ID 1520 4-1/2" MMGM GAS LIFT MANDRELS 4-1/2" 'X' NIPPLE 3.813" ID 9778 -5/8" x 4-1/2" BAKER S-3 PACKER 9799 4-1/2" 'X' NIPPLE 3.813 ID 9823 4-1/2" 'XN' NIPPLE 3.80" ID 9844 MILLED OUT 4-1/2" x 5-1/2" WLEG 9856 8.25" OD x 7.5" ID TIE BACK SLEEVE 9826 9-5/8" x 4-1/2" ZXP LINER PACKER 9837 9-5/8" x 4-1/2" LINER HANGER 9848 BAKER LINER TOP PACKER 2.390 ID 13647 31/2 x 27/8 X-OVER 13669 27/8 6.4# L-80 13Cr STL LINER 2.372 ID CTD SIDETRACK INFO PBTD 15385 WEATHERFORD WHIPSTOCK WITH 3 "RA" PIPS @ 13720'MD 2 7/8" 6.4# L-80 13 Cr STL FROM 13670 - 15436 COMMENTS ENDICOTT UNIT WB...L: 3-17F / K-30 PERMIT No: . .t03-..('/' (\ API No: 50-029-21946-06 SEC T N R E BP Exploration (Alaska) OA TE REV BY COMMENTS DA TE REV BY 03/17/03 WRR SIDETRACK (DOYON) 03/22/03 RLW ADPERF 03/13/04 WRR CTD SDTRCK 05/10/05 SRB/TLH ADPERF (04/30/05) e Transmittal Form e (;(03...,..;¿¡' " ) 25(0 ? '&ill BAKEl HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: 3-17F IK -30 Contains the following: I LDWG Compact Disc (Includes Graphic Image files) I LDWG lister summary I bluelines - GRlDirectional Measured Depth Log I bluelines - MPR Measured Depth Log 1 bluelines ~ MPR TVD Log LAC Job#: 638506 Sent By: Glen Borel Received BC//iL} lr.Lt'- J PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY F~:(907)267-6623 Date: July 9, 2004 Date: 7 ¡; i-' /0 c.f. / / Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 e Transmittal Form e rÆ()~''-~ l.~ / ¿ S l¡ð "ill BAKER HUGHES INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: 3-17F /PB 1 Anchorage GEOScience Center Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth Log 1 blueline - GR/Directional TVD Log LAC Job#: 638506 Sent By: Glen ,~~ ell/ Received a. . (,j , Date: July 9, 2004 Date: ýz </0 J PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 -,~ .. _ STATE OF ALASKA .. .. ALASKA'llJlrL AND GAS CONSERVATION COM~SIOIQ E CE IVED WELL COMPLETIION OR RECOMPLETION REPORT AND tðG ";004 APR 1 5 L 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2524' SNL, 799' WEL, SEC. 08, T11 N, R17E, UM Top of Productive Horizon: 289' NSL, 1141' WEL, SEC. 32, T12N, R17E, UM Total Depth: 65' NSL, 5186' WEL, SEC. 33, T12N, R17E, UM 4b, Location of Well (State Base Plane Coordinates): Surface: x- 270243 y- 5970974 Zone- ASP3 TPI: x- 270125 y- 5979074 Zone- ASP3 --- Total Depth: x- 271353 y- 5978813 Zone- ASP3 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD GR / Rap / RES, MGR / CCL / CNL 22. One Other 5. Date Camp., Susp., or Aband. 3/13/2004 6. Date Spudded 2/26/2004 7. Date T.D. Reached 3/8/2004 8. KBIElevation (ft): KBE = 52.6' 9. Plug Back Depth (MD+ TVD) 15385 + 10221 10. Total Depth (MD+TVD) 15436 + 10225 11. Depth where SSSV set (Nipple) 1522' MD 19. Water depth, if offshore 6' - 12' MSL CASING SIZE 30" 13-3/8" 9-5/8" 4-1/2" 3-1/2" x 2-7/8" GRADE Drive Pipe NT80CYHE NT80S 13Cr 13Cr80 C ASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH. TVD HOLE TOp BOTTOM TOP IBoTTOM SIZE Surface 142' Surface 142' Surface 2498' Surface 2496' Surface 9976' Surface 7734' 9827' 13698' 7633' 10108' 13647' 15436' 10066' 10225' WT. PER FT. Structural 68# 47# 12.6# 9.3# x 6.16# 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 2" Gun Diameter, 6 spf MD TVD MD TVD 15307' -15382' 10213' - 10221' 26. Date First Production: March 17, 2004 Date of Test Hours Tested PRODUCTION FOR 4/12/2004 4 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED ........ Press. 24-HoUR RATE""" OIL-BBL 2,441 17-1/2" 12-1/4" 8-1/2" 3-3/4" 24. SIZE 4-112", 12.6#, 13Cr / L-80 "··on Ala )Þ. ...... "'" : "V- 181 Devll6~Mge 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-216 13. API Number 50- 029-21946-06-00 14. Well Name and Number: END 3-17F/K-30 15. Field / Pool(s): Endicott Field I Endicott Pool Ft Ft 16. Property Designation: ADL 312828 17. Land Use Permit: 20. Thickness of Permafrost 1465' (Approx.) CEMENTING RECORD ~ Driven 4185 cu ft Permafrost 575 cu ft Class 'G' 1038 cu ft Class 'G' 118 cu ft Class 'G' T J$ING DEPTH SET (MD) 9857' PACKER SET (MD) 9799' 25. ACID, FRACTURE, CEMENT SQUEEZE, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH n Q , h I t\1 A , CONTINUED ON REVERSE SIDE .- PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing OIL -BBL 407 GAs-McF 1,478 GAs-McF 8,869 W A TER-BBL 0.17 W A TER-BBL 4 GAS-OIL RATIO 3,634 CHOKE SIZE 124" OIL GRAVITY-API (CORR) 23 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core ch~ps; if none, state "none". None ~ \17.:',....;'1'· .~¿.,',.. Form 10-407 Revised 12/2003 ~fJf*S Ht·L Øíf2lM~ 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kekituk 2A2 13931 ' 10185' None Kekituk 2A1 14038' 10187' RECE\VEO ~?R 15 2004 . commiss\OfI '\ & Gas Cot's. Mas~a 0\ ~"chora\}e 30. List of Attachments: Summary of Daily Drilling Reports, Wellbore Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge, Signed Terrie Hubble Title Technical Assistant Date END 3-17F/K-30 Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Mark Johnson, 564-5666 203-216 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness, ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". U # .~ U I ~ ...~ j-\ L Form 10-407 Revised 12/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 2/20/2004 3/13/2004 N2 Spud Date: 2/23/2004 End: 3/13/2004 2/21/2004 05:00 - 06:00 1.00 MOB P PRE Released from END 3-33 at 0500 hrs Warm moving system. General preparations for moving 06:00 - 06:15 0.25 MOB P PRE Safety mtg re: move off well 06:15 - 07:15 1.00 MOB P PRE Move off 3-33 and move to center of pad directly in front of 3-17 Phz 1 -24F, -74 CF 07: 15 - 09:00 1.75 MOB P PRE Move cellar liner and pickup/reset matting boards 09:00 - 09:15 0.25 MOB P PRE Safety mtg re: move over well 09:15 - 10:00 0.75 MOB P PRE Move over 3-17 and set down. Had trouble climbing onto mats w/ front of rig 10:00 - 11 :00 1.00 BOPSU P PRE Accept for operations at 1000 hrs Note: Revised accept time back to 0800 hrs on 2/23/04 because Nordic whinned about the time it took to move the matting boards and liner NU BOPE 11 :00 - 11 :30 0.50 MOB PRE Jack up and relevel rig 11 :30 - 15:00 3.50 BOPSU PRE Fin NU BOPE and lub 15:00 - 20:45 5.75 BOPSU PRE Test BOPE. 500psi/3500psi Check Koomey bottle pressures and perform accumulator test. Witness waived by AOGCC 20:45 - 22: 15 1.50 BOPSU PRE R/U lubricator and pull TWC. WHP = 340 psi close MV SV bleed down stack RID lubricator. Phase II driving conditons. 25-30 mph winds -25' 22:15 - 22:30 0.25 KILL P DECOMP PJSM. Review plan forward - cut 100' coil rehead and test. BHA and well kill procedures. 22:30 - 00:00 1.50 KILL P DECOMP RlU hydraulic cutter. Cut 118' of coil. Rehead pull test to 35K. 2/22/2004 00:00 - 00:15 0.25 KILL P DECOMP PT coil connector to 3500 psi. Phz 1/2 00:15 - 00:45 0.50 KILL P DECOMP M/U nozzle BHA. 00:45 - 01 :30 0.75 KILL P DECOMP Stab on well. Chase down frozen lines - choke / return line in cellar. Setback injector. 01 :30 - 03:00 1.50 KILL N DECOMP Circulate through bung hole. Unthaw lines in cellar. 03:00 - 03:10 0.17 KILL P DECOMP PJSM. Discuss strategy for taking returns to Tiger Tank. (without freezing everything up) 03:10 - 06:15 3.08 KILL P DECOMP Stab on well. Line-up through Swaco choke to Tiger Tank. Open MV SV 340 psi. RIH maintaining 450psi on well. RIH to 13800' 06:15 - 09:15 3.00 KILL P DECOMP POOH jetting wI 3.5" sidejet nozzle 3.5/1950 52.8k holding 400 psi BP to 13000'. POOH 2.5/1200 holding 200-400 psi BP to bottoms up+ at 9500'. Chk for flow and none. Start keeping returns. FP hardline w/ MeOH. POOH 1.67/450, 2.3/800 circ'ing from/to pits 09:15 - 09:30 0:25 KILL P DECOMP Chk well for flow-none. LD nozzle assy. Recovered 1/3 of an IBP rubber on BHA 09:30 - 10:05 0.58 STWHIP P WEXIT MU WII dummy drift onto SWS GRlCCL flow thru carrier 10:05 - 11 :35 1.50 STWHIP P WEXIT RIH w/ BHA #2 to 9300' 0.4/60 11 :35 - 12:20 0.75 STWHIP N SFAL WEXIT Gus found a dripping O-ring on lubricator below drip pan. PJSM. Lift injector and replace O-ring. Will replace and PT all O-rings on lub when OOH 12:20 - 13:00 0.67 STWHIP P WEXIT Resume RIH 13:00 - 13:20 0.33 STWHIP P WEXIT Log down from 13000' to 13810' at 60'/min 0.4/40 13:20 - 13:45 0.42 STWHIP P WEXIT Log up from 13810' 49k 0.44/30 at 30'/min. PVT 331 Paint flags at 13650' and 13000' EOP's Printed: 3/15/2004 10:17:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 2/22/2004 13:45 - 16:20 2.58 STWHIP P WEXIT POOH w/ drift assy 16:20 - 16:45 0.42 STWHIP P WEXIT LD WS drift and GR/CCI carrier. Download data. -4.25' correction to SLB PDC log. Replace O-rings on lub and PT 16:45 - 17:50 1.08 STWHIP P WEXIT MU WII 4-1/2 WS-R-BB Packer (anchor) assy w/ setting adaptor and fury tool. MU SS ESS tool. WO SWS to put GR/CCI tool back together. MU GRlCCL carrier, WII MHA w/ divert sub 17:50 - 20:40 2.83 STWHIP P WEXIT RIH w/ BHA #3 (46.59') to first EOP flag at 13000' correct depth -8.6'. RIH to second flag no correction. RIH placing bottom of packer at 13738'. 20:40 - 21 :45 1.08 STWHIP P WEXIT Load and launch .625" Delron ball. Pump first 40bbls at 2.0 bpm reduce rate to .6bpm 115psi ball on seat after 53.5 bbls. wt 21 k Pressure up to 2325 and set packer continue pumping at ,15bpm holding 2200-2300psi for 3 minutes bring pressure up to 3000psi hold while pumping .19bpm increase to 3500psi and hold increase to 4000psi and hold increase toward 4500psi and sheared at 4350psi. Setdown to 16k. 21:45 - 22:35 0.83 STWHIP P WEXIT Log GLUGr up 30'/min to 13000' then back down to 13650'. 22:35 - 00:00 1.42 STWHIP P WEXIT TOH 2/23/2004 00:00 - 01 :30 1.50 STWHIP P WEXIT Finish TOH 01 :30 - 01 :45 0.25 STWHIP P WEXIT UD SWS MCCUgr and Sperry ESS tools. 01 :45 - 04:20 2.58 STWHIP P WEXIT Wait on CCUgr log & survey processing. CLUgr correction +6' on up pass, -2' on down pass. Sperry ESS showing packer face of the mule shoe slot is 319.5' Call into Weatherford to dress WS without 3' spacer and setup latch lug 320' for a HS-WS TF. Once run and latched into packer this will make the distance from the bottom of the packer to the top of the WS 16.42' Based on log correction results best to err on the lower depth interval called out in the procedure to avoid csg collar at +1- 13718'. Top of the WS with the downpass correction will be +/-13720', with up pass correction it is 13728'. 04:20 - 05:20 1.00 STWHIP P WEXIT Make up BHA #4 (29.16' ) Weatherford equipment. Install 3 SWS "pip" tags on backside of WS tray 7.84' below top of WS. 05:20 - 08:05 2.75 STWHIP P WEXIT RIH to 13693.8' and corr -13' to flag at 13650' EOP by GRlGGI. Chk wt 49.2k, 21.3k 0.35/30 RIH 08:05 - 08:15 0.17 STWHIP P WEXIT Tag at 13727' and stack 5k, PUH and engaged. PUH to 62k and sheared off leaving WS in hole 08:15 - 10:40 2.42 STWHIP P WEXIT POOH wI setting tool 10:40 - 11 :00 0.33 STWHIP P WEXIT LD setting BHA 11 :00 - 12: 10 1.17 STWHIP P WEXIT RU cutter and cut 100' CT, Install DS connector. PT 45k, 3500 psi MU cement nozzle BHA MIRU DS cementers. Safety mtg re: cementing. Batch up cement 12:10 - 14:15 2.08 STWHIP P WEXIT RIH wI BHA #5 0.4/60 Cement to wt at 1400 hrs TT 5:58 14:15 - 14:30 0.25 STWHIP P WEXIT 13600' 48.5k, 19.2k RIH and tag at 13740' CTD. PUH and park at 13715' 14:30 - 14:45 0.25 STWHIP P WEXIT Injectivity test-pressure wellbore to 2150 psi. Bled to 1750 psi in 5 min. Bleed off pressure 14:45 - 15:30 0.75 STWHIP P WEXIT Cementers load CT w/ 5 bbl FW. PT at 4000 psi. Load 10 Printed: 3115/2004 10:17:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 2/23/2004 14:45 - 15:30 0.75 STWHIP P WEXIT bbls 15.8 ppg G cement wI latex 2.6/1300 followed by 10 bbls FW. Displace w/ rig 2% KCI at 2.3/1300 15:30 - 15:42 0.20 STWHIP P WEXIT Red rate to 1.0 bpm when cement at nozzle. Let 2 bbls come out then POOH 65'/min 53k 15:42 - 15:50 0.13 STWHIP P WEXIT Last bbl out at 13077'. PUH to safety 0.6/100 at 65'/min 56k 15:50 - 16:30 0.67 STWHIP P WEXIT Circ 0.5/70, 1.1/300 while circ biozan to CT and let cement settle 16:30 - 17:00 0.50 STWHIP P WEXIT Pressure well bore to 2500 psi and hold for 25 min w/150 psi loss (thru pump). IA gained 10 psi to 134 psi 17:00 - 17:40 0.67 STWHIP P WEXIT RIH while fin circ biozan to nozzle at 2.1/900. Jet/dilute cement 2.0/900 @ 44'/min while RIH to 13725' 17:40 - 20:20 2.67 STWHIP P WEXIT POOH jetting 3.0/2500 and recip over GLM's 20:20 - 20:50 0.50 STWHIP P WEXIT P/U swizzle stick and jet BOP stack clean. 20:50 - 21 :20 0.50 STWHIP P WEXIT Wait on N2. 21 :20 - 22:15 0.92 STWHIP P WEXIT R/U SLB N2 equipment. Install pig catcher on coil. 22:15 - 22:30 0.25 STWHIP P WEXIT PJSM review plan foward for coil N2 blowdown. 22:30 - 23:30 1.00 STWHIP P WEXIT Test N21ines to 3k. Pump 10 bbl methanol ahead followed by N2 and coil pig. 23:30 - 00:00 0.50 STWHIP P WEXIT Start swap to EL coil. 2/24/2004 00:00 - 07:50 7.83 STWHIP P WEXIT Prep coil reel for removal. Lower coil to flatbed. Change reel bushings. Lift and secure E-line coil. Install internal grapple and PT 07:50 - 08:05 0.25 STWHIP P WEXIT Safety mtg re: THA on pull CT to floor 08:05 - 11 :45 3.67 STWHIP P WEXIT Pull 2-318" E-CT to floor and stab. Cut off 50' CT. Install CTC and PT 35k. Install wet connect and test 11 :45 - 13:30 1.75 STWHIP P WEXIT Fill CT w/1 0 bbls MeOH followed by 2% KCI. Pump at reduced rate to avoid moving slack. Coil pressured up after pumping 14 bbls. Ice plugged. Maintain 50psi on coil and 100+ degree heat inside reel house. Decide better to P/U BHA and RIH to help thaw reel. 13:30 - 14:15 0.75 STWHIP P WEXIT P/U milling BHA #6 (43.78') 14:15 - 18:30 4.25 STWHIP P WEXIT RIH maintaining 150 psi on frozen coil. Thawed at 8000'. Slowly increase circ rate. Begin displacement to flo pro through EDC. Continue to RIH. 18:30 - 20:00 1.50 STWHIP P WEXIT Record casing collar log from 13500' to 13600'. Add 1.5' correction, although tie in with marker joints on casing collar log was not clear. 20:00 - 20:45 0.75 STWHIP P WEXIT Tag cement at 13714'. Mill ahead at 0.4 fpm. 3400 psi fs @ 2.33 bpm. 3.5-4.0K# DH WOB. Cement very firm. Stall at 13725'. Appear to be on whipstock, 60K# pick up wt 20:45 - 00:00 3.25 STWHIP P WEXIT Mill ahead as per RP & well plan. Follow conservative time mill sequence as per Weatherford recommendation. 2.4 bpm@ 3400 psi FS. 3.0k# WOB. Mill to 13729'. Replace leaking hardline seal in side reel. Check magnets for metal, some found, cleaned off. 2/25/2004 00:00 - 01 :30 1.50 STWHIP P WEXIT Continue milling ahead. PU off btm to switch pumps, repair washed out pot bladder. Metal on magnets. 01 :30 - 06:00 4.50 STWHIP P WEXIT Continue milling ahead at 13735'. 3450 psi@2.5 bpm fs. Checking shakers for sand. Calling bottom of window at 13733'. There is some type of surface electrical problem affecting BHi surface computers that in turn affects communications with downhole tools. Have turned off BHi surface equipment. Printed: 3/15/2004 10: 17:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 2/25/2004 01 :30 - 06:00 4.50 STWHIP P WEXIT 06:00 - 06:50 0.83 STWHIP P WEXIT Drill formation from 13733' to 13744'. Nordic electrican has determined that BHi's surlace transfomer is shot. Mostly likely cause do to having 2 - single pole/single throw circuit breakers (verses double pole/single throw). Throwing these breakers individually over time has damaged the transformer. 06:50 - 07:50 1.00 STWHIP P WEXIT Ream up - down - up from 13744' to 13725' Down pass wlo pump. Window looks great. 07:50 - 10:45 2.92 STWHIP P WEXIT TOH. Flag EOP at 13400'. Locating another 11 0/240v generator that can be used until BHi can replace the faulty transformer used to convert rig power back to 11 0/240v Rebuilding mud pump #1 10:45 -11:15 0.50 STWHIP N SFAL WEXIT Surlace test communication with BHi tools while still in the hole at surlace. Using a separate small BHi transformer. If this works we can p/u the next BHA while waiting for the located 110/240v generator. To make good use of downtime we also plan to replace 1 drive bushing on the coil reel after I/d of window milling BHA. Small transformer doesn't work. 11: 15 - 11 :45 0.50 STWHIP P WEXIT UD BHA #6. Mill 3.80" SR 3.78+ 11:45-12:15 0.50 DRILL N SFAL PROD1 Change out off drillers side coil reel bushing. Waiting on generator for BHi. 12:15 - 14:45 2.50 DRILL N SFAL PROD1 Continue waiting on generator. Checking BHi data cable at reel for possilbe bad connection. Found waterproof junction box flooded from las tnights o-ring seal failure on 2" hardline. All connections fried. Repair wire connections. We now have comms while using surlace test cables. Making necessary connections to make generator useable. SLB J box failure down time: previous 3.5 hrs. 14:45 - 15:15 0.50 DRILL P PROD1 P/U BHA #7 (65.70') build assembly. 15:15 - 15:40 0.42 DRILL N SFAL PROD1 RI H to 1000' seems to a short within the tools. 15:40 - 16:10 0.50 DRILL N SFAL PROD1 TOH with BHA. 16:10 - 20:00 3.83 DRILL N SFAL PROD1 Setback injector. Trouble shoot & test tools. Surlace equipment, e-line, tools all test ok separately, but not in combination. BHI found crossed wires in MWD cabin. previous 4.0 hrs down time due to BHI. 20:00 - 23:15 3.25 DRILL P PROD1 Get on well. RIH at 75 fpm due to high angle motor. 23: 15 - 00:00 0.75 DRILL N DFAL PROD1 Log initial GR tie in log. Unable to communicate with lower half of MWD tool. Trouble shoot same. Check surlace equipment & reel components. Apparently a down hole problem. 2/26/2004 00:00 - 00:30 0.50 DRILL N DFAL PROD1 Continue to trouble shoot MWD tools. Determine fault is downhole. 00:30 - 03:30 3.00 DRILL N DFAL PROD1 POOH to repair mwd tools. 03:30 - 05:00 1.50 DRILL N DFAL PROD1 At surlace. Get off well. Unstab from coil. LD tools. Test replacement tools on catwalk. OK. PU tools. Stab coil. Communication to tool lost once coil was stabbed. Unstab. Clean connections and try again. Test ok. Problem with previous tools was a short in the orienter. 05:00 - 08:00 3.00 DRILL N DFAL PROD1 RIH to 13400. Correct to flag -18'. 08:00 - 08:30 0,50 DRILL P PROD1 Log Gr tie-in -2' correction. Printed: 3/15/2004 10: 17:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 2/26/2004 08:30 - 08:45 0.25 DRILL P PROD1 RIH tag bottom 13738', No problems through window. 08:45 - 12:45 4.00 DRILL P PROD1 Directionally drill f/13738' 2.4bpm 3380 FS 10.95 ECD 2k wob slow start on drilling ahead, frequent stalls with high bend motor. Avg 1 0-20'/hr picked up RA marker at 13727' 6' higher than previously antcipated. This puts top of window at 13720', bottom at 13727'. Drilled to 13790 12:45 - 13:35 0.83 DRILL P PROD1 Continue drilling ahead f/13790' 2.5bpm 3450 free-spin, 10.95ppg ECD 2-300psi motor work 2-3k wob. Continues to be very touchy about motor stalls, motor's strong just maybe the high angle short radius motor combo. 1 0-20'/hr rop's. Drilled to 13796'. First good survey at 13755' showing only a 31* DLS, NBI angles dont show the DLS getting any higher. Open EDC. 13:35 - 16:00 2.42 DRILL P PROD1 TOH up wt 44.7k down wt 14k paint EOP flag at 13300'. Discuss with town next options. Need +/-53* DL to reach landing at 13874'md 1 0147'tvd. Setting motor to 3.96* and p/u "old" style M09 bit. Stack/tree clearance will determine maximum setting. 16:00 - 16:30 0.50 DRILL P PROD1 TOH inspecting the last 150' for wear. 16:30 - 17:15 0.75 DRILL P PROD1 Stand back BHA. Change AKO 3.98* 17:15 - 18:30 1.25 DRILL P PROD1 Prep to cut 50' of coil. 18:30 - 19:00 0.50 DRILL P PROD1 Hold fallen object incident review in ops cab. A 2 Ib round teflon roller fell from goose neck to rig floor, approximately 15', while moving injector. Retaining ring had come loose allowing roller to part. Stopped job to discuss plan forward and inspect goose neck. 19:00 - 20:45 1.75 DRILL P PROD1 MU e-line connector. Pull & pressure test same. Test continuity. 20:45 - 21 :45 1.00 DRILL P PROD1 MU build assembly (3.9 deg mtr w/old style M-09 bit). Work through well head & BOPS (no significant hang ups, but had to turn BHA by hand). Stab coil. Get on well. 21 :45 - 23:00 1.25 DRILL N SFAL PROD1 Inspect goose neck. Remove teflon coil guide assemblies. Check for other dropped object potential from injector assembly. 23:00 - 00:00 1.00 DRILL P PROD1 RIH, slowly, to protect bit. Watch for jewelry in tbg. 2/27/2004 00:00 - 03:45 3.75 DRILL P PROD1 Continue to RIH with 3.9 mtr & M09 bit. No hang ups on jewelry, slowing down for GLM's etc. 03:45 - 04:45 1.00 DRILL P PROD1 Log gr tie in from 13500'. Extra long section to verify previous tie in correlation. Add 5' correction from tie in on previous run. Found corrected RA tag at 13732'. Corrected top of WS and window is 13724.16' (13724') bottom of window 8' lower than top of window. 04:45 - 06:30 1.75 DRILL P PROD1 Drill ahead from 13801'. Through window no problem. 3800 psi@ 2,67 bpm fs. 200-300 dpsi. 3K# WOB. 10.69 ECD Drilled to 13815'. Orienter showing signs of not being able to maintain highside TF's. PUH into csg. Comms with tool is good but appears the hydraulic motor is not functioning to turn orienter to assigned TF. No surveys taken to confirm motor setting is giving desired DL's. NBI confirms previous 3.1* motor setting was only giving low 30's, 06:30 - 09:25 2.92 DRILL N PROD1 Open EDC TOH for orienter. Paint EOP flag at 13200'. 09:25 - 10:20 0.92 DRILL N PROD1 UD BHA #8 and p/u BHA #9 (65.58') Surface continuity test Printed: 3/15/2004 10:17:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 2/27/2004 09:25 - 10:20 0.92 DRILL N PROD1 good. 10:20 - 13:35 3.25 DRILL N PROD1 RIH taking care while passing GLM's, XN etc. Tagged on GLM at 5970' with 90R TF move to 45R and went through. Surface tested the orienter and found it will turn when sent the command. The unknown is will it turn with torque. We cannot test that on the rig. Sending to Deadhorse for testing and returning with another orienter for back-up. Correct to flag -19'. RI H to 13740' 13:35 - 14:40 1.08 DRILL N PROD1 Log tie-in at RA tag no correction. PUH 13720' and log to TD at min rate maintaining HS TF. 14:40 - 15:15 0.58 DRILL P PROD1 Directionally drill ahead f/13815' 2.6bpm 3340psi fs 4-500psi mw 2k wob 50-60'/hr 10.87ppg ECD drill to 13846'. Surveys showing 41' DL's 15:15-14:15 23.00 DRILL P PROD1 Pull up into csg. Geologist evaluating log data to determine dip of S2A2 shale and options with 40' DL's. Decide to continue drilling ahead. Current DL's should land us 6' higher than S2A2 in parent well. Unable to determine dip angle of S2A2. RIH to bottom 14:15 - 17:45 3.50 DRILL P PROD1 Directionally drill ahead from 13846'. 40'/hr 2-3k wob. Drilled to 13867.5' and rop slowed to 0 no motorwork. P/U rem back to bottom. Drill ahead to 11870 rop > 11 O/hr pick-up clean back on bottom drilling normal again. Drill ahead 40-50'/hrto 13880'. P/U clean. Drill ahead to 13888'. Small wiper trip into csg and back to bottom. Drill ahead. Dips calculated at 9.5' 17:45 - 19:00 1.25 DRILL P PROD1 Drill ahead f/13888' 30'/hr 3-4k wob. Drill to 13898'. Some coal on shaker. Slow ROP to make sure we don't get buried. 19:00 - 20:00 1.00 DRILL N DFAL PROD1 Lost comms to orienter. Short trip while trouble shooting same. Open EDC, Orienter working. RIH to near btm. Orienter cut out again. 20:00 - 22:30 2.50 DRILL N DFAL PROD1 Open EDC. Circulate OOH at 2.5 bpm. Continue to see small quantities of coal & sand over shaker. 22:30 - 00:00 1.50 DRILL N DFAL PROD1 At surface. Get off well. Unstab coil. CHange out mwd tools. Adjust motor angle to 3.4 deg. Sit in excellent condition. Re-run same. 2/28/2004 00:00 - 03:30 3.50 DRILL N DFAL PROD1 Stab coil. Get on well. Check mwd tools. RIH. Tag up at SSSV nipple at 1520'. Work through. Smooth to tie in point. 03:30 - 04:00 0.50 DRILL N DFAL PROD1 Open EDC to go through window. Log gr tie in from 13770'. Subtract -28' correction. 04:00 - 04:30 0.50 DRILL N DFAL PROD1 Attempt close EDC. Positional error. Power up & down, reset everything. Cannot regain position, cannot open or close, cannot disconnect. 04:30 - 07:20 2.83 DRILL N DFAL PROD1 POOH to check mwd. Unstab injector at 150' and check coil for wear. None found to warrent cutting coil. 07:20 - 07:55 0.58 DRILL N DFAL PROD1 UD SHA check it for wear patterns also, none found. Report on yesterdays orienter: tested within specs for tool in the Deadhorse shop. 07:55 - 14:00 6.08 BOPSU P PROD1 Weekly test of BOPE. AOGCC waived witnessing test. O-ring leak on lubricator. Discussion with town engs about continued drilling with the coal zones opened up and the hazards they present. Also the tortuous well path that is needed to successfully hit the next predicted fault at the desired TVD and not unintentionally sidetrack in future trips with stiffer BHA's. Printed: 3/15/2004 10:17:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 14:00 - 16:10 16:10 - 16:45 16:45 - 19:30 19:30 - 21: 15 2/29/2004 21 :15 - 00:00 00:00 - 00:15 00:15 - 02:00 02:00 - 05:30 05:30 - 06:15 06:15 - 09:00 09:00 - 09:40 09:40 - 14:15 14:15 - 15:15 15:15 - 15:30 15:30 - 16:55 16:55 - 19:45 19:45 - 20:45 3/1/2004 20:45 - 23:30 23:30 - 00:00 00:00 - 00:45 00:45 - 03:45 03:45 - 12:00 I 2.17 STWHIP N 0.58 STWHIP N 2.75 STWHIP N 1.75 STWHIP N 2.75 STWHIP N 0.25 STWHIP N 1.75 STWHIP N 3.50 STWHIP N 0.75 STWHIP N 2.75 STWHIP N 0.67 STWHIP N 4.58 STWHIP N 1.00 STWHIP N 0.25 STWHIP N 1.42 STWHIP N 2.83 STWHIP N 1.00 STWHIP N 2.75 STWHIP N 0.50 STWHIP N 0.75 STWHIP N 3.00 STWHIP N 8.25 STWHIP N WAIT WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT Based on all the uncertainty and associated hazards to drill ahead in this hole we will set another whipstock and kick off at 13698'. This will be 26'md, 21.7'tvd higher than present KOP. Wait on Weatherford MU Wf CIBP and BHi tools. Stab coil. Get on well. RIH at 75 fpm with CIBP assembly. No problem getting to logging depth. Begin down pass tie in log from 13558' (gr 15' above btm of CIBP) using PDC log. Subtract -29.5' correction. Pull back to 13575'. Log down confirmation pass. Still on depth. RIH to 13718.1 '. Close EDC. Pressure up to 4500 psi to set CIBP. Set indications good. Stack 5K# down wt. Circulate OOH. Circulate OOH. Get off well. Inspect 150' coil for wear. Coil looks good. Unstab coil. LD BHA. MU BHA with W-ford whipstock and setting tool. Install RA tags. Test mwd/orienter on catwalk. MU tools & scribe high side to ws tray. STab coil. Get on well. RIH with WS assembly at 65 fpm. Log gr tie in down. Tool quit. No comms with BHi downhole tools. TOH paint EOP at 13200'. Checking last 150' of coil and found some wear spots enough to warrent cutting pipe. UD BHi tools. Inspect WF whipstock. Okay Cut-off CTC. Pumping Slack Management. First try pumping 4bpm only pushed back 6'. Re-dress e-line and try again. No movement. Cut off a total of 50' of coil. Dress end and install Kendle connector. Pull test to 35k. Rehead with BHi flowsub and Meg test - ok and pressure test to 3500psi. Install new mechanical counter on reel. MU WF LSX-N whipstock and BHi CoilTrack tools. Scribe toolfaces. Stab on injector. RIH. Seeing electrical trouble at FlowSub. P/U injector and Meg test connector. Bad test in the head. Found nick/short in primary wire just above the Kemlon boot attached to the flowsub. Make-up new connector and tested good. Changed out the lower quick connect found what looked like a nick in one of the two o-rings. Stab on injector. Visitors on the rig: Gary Christman and Greg Mattson RIH w/ whipstock assy. Correct to EOP flag at 13150'. Add 12.3' correction. Log down from 13580. 47k# up, 20k# down wt. Subtract 2' correction. TF: 10R. Close EDC. Pressure coil to set wstock. Setting tool sheared at 3300 psi. Wait one minute. Set down 5K# to verify set. PU to verify release from ws. TOWS at 13698', BOWS at 13711' as per PDC log. RA tag at 13707'. POOH with setting tool. EOP flag still visible. At surface. Get off well. Unstab coil. Check coil coonector. LD wstock setting tool. MU window milling assy with DPS, W-ford motor, string mill, HTC 1-step mill. Stab coil. Get on well. RIH. Correct to EOP flag (-12'). Tag top of WS at 13696.6'. Begin time milling window f/13696.6' 3200 psi fs @ 2.58 bpm. Printed: 3/15/2004 10:17:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 3/1/2004 03:45 - 12:00 8.25 STWHIP N DPRB WEXIT Time mill window at 0.1' per 6 minutes. TOW 13696.6' BOW 13703.4' (not confirmed until RA's are passed when drilling build section) 12:00 - 13:40 1.67 STWHIP N DPRB WEXIT Drill 8' of formation to 13711.5' Swap out to new Flo-Pro mud. 13:40 - 15:00 1.33 STWHIP N DPRB WEXIT Ream up down and up with diamond string mill. RIH w/o motor window looking good. 15:00 - 18:30 3.50 STWHIP N DPRB WEXIT TOH with window mill. 18:30 - 20:00 1.50 DRILL N DPRB PROD1 LD milling assembly. MU build assy (3.4 deg xtreme w/ M-09). Stab coil. Test mwd. Get on well. 20:00 - 23:15 3.25 DRILL N DPRB PROD1 RIH with build assembly. 23:15 - 00:00 0.75 DRILL N DPRB PROD1 Log gr tie in from 13570'. Add 8' correction. 3/2/2004 00:00 - 03:00 3.00 DRILL N DPRB PROD1 Begin drilling ahead. Having trouble keeping high side orientation. TF keeps rolling to left. Drill ahead very slowly. 3240 psi @ 2.6 bpm fs. 49k# up, 19k# dn wt. 10.91 ECD. PU back above window to try and regain high side TF. Repeat several times to try and scratch out a high side trough. 03:00 - 06:15 3.25 DRILL N DPRB PROD1 Drill ahead. 3240 psi@ 2.5 bpm fs. 250 dpsi mw. 3.0k# dhwob. 60 fpm rop. 10.9 ppg ECD. Appear to be getting 45 deg/100 build rate, based on near bit inc (NBI) and surveys. Pump a low/high vis sweep. Drill to 13830'. Picked up RA tag at 13707'. The RA's were placed 8.87' below the top of whipstock. This puts the top of window at 13698' and the bottom at 13705'. 06:15 - 09:50 3.58 DRILL N DPRB PROD1 TOH for lateral BHA pumping full rate to surface then back to 500'. Pull up to 150', pick-up injector and inspect coil for Cr wear. 09:50 -11:10 1.33 DRILL N DPRB PROD1 Adjust Extreme motor to 1.5* and p/u DS-49 bit. BHA #15 (64.89') Stab coil. Get on well. 11:10 -14:30 3.33 DRILL N DPRB PROD1 RIH with lateral assembly. 14:30 - 15:00 0.50 DRILL N DPRB PROD1 Log gr tie in from 13450 15:00 - 17:45 2.75 DRILL N DFAL PROD1 MWD tool shorted out. POOH to repair same. 17:45 - 19:00 1.25 DRILL N DFAL PROD1 Changed out MWD tool Set counters to 64.9 ft Inspected top 100 ft of CT of abnornal wear. 1 section, 8 ft above CTC has a flat spot 20k under 19:00 - 21 :25 2.42 DRILL N DFAL PROD1 RIH with EDC closed to 13,640 ft Wt check = 51k (up), 19k (down) (wo pumps). RIH to Tie-in. Tagged top of window at 13,703 ft with HS TF 21 :25 - 22:26 1.02 DRILL N DPRB PROD1 At 13,703 ft. Working different TF to get through window up to 145R, Turned TF left due to high amp and tried at L TF with (min rate) and without pumps.well drilled initially w/ 45 to 48 deg DLS and with lower AKO (1.5) setting, the bit is tagging 12' past window. 22:26 - 11 :45 13.32 DRILL N DPRB PROD1 PUH to Tie-in at 13575' (bit), Tie-in (+15 ft) RIH and tagged at 13,713 ft corrected. 11 :45 - 00:00 12.25 DRILL N DPRB PROD1 POOH to cut CT off and change AKO setting on motor 3/3/2004 00:00 - 01 :30 1.50 DRILL N DPRB PROD1 POOH, Pumped 30 bbl 9.3ppg brine prior to cutting off 100 ft CT (Coiled tubing Cr Management) Conducted PJSM on BHA handling and cutting off CT 01 :30 - 02:22 0.87 DRILL N DPRB PROD1 Finished pumping 9.3ppg brine. Blow 3 bbl fluid to mud tanks using air 02:22 - 04:00 1,63 DRILL N DPRB PROD1 Cut off CTC and 100 ft CT for pipe management. CT length = 14571 ft. Pull tested CTC to 35k, OK 04:00 - 05:30 1.50 DRILL N DPRB PROD1 Rehead BHI CTC as per BHI's SOP. Pressure tested to 3500 Printed: 3/15/2004 10:17:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 3/3/2004 04:00 - 05:30 1.50 DRILL N DPRB PROD1 psi 05:30 - 07:15 1.75 DRILL N DPRB PROD1 PU DS100 bicenter bit, motor set at 2.2 deg and flex sub. Open SV. Displace brine from coil. MU BHA. Stab coil. Get on well. 07:15 - 10:15 3.00 DRILL N DPRB PROD1 RIH with 2.2 deg mtr w/ bi center. Stop at 13500', Add 15' correction. Get high side TF. Set down at 13720' ( uncorrected) 10:15-11:00 0.75 DRILL N DPRB PROD1 Log gr tie in from 13570'. Subtract 5' correction. Close EDC. 11 :00 - 11: 15 0.25 DRILL N DPRB PROD1 RIH. Tag up at 13715'. PU and circ at min rate (0.7 bpm). RIH. Past "ledge" by rolling bit. RIH. Tag TD at 13831'. 11:15 -12:30 1.25 DRILL N DPRB PROD1 Drill ahead. 3200 psi @ 2.6 bpm fs. 200-300 dpsi mw. 1K-2K# wob. TF:90L. 10.9 ppg ECD. Drill to 13853'. 12:30 - 13:00 0.50 DRILL N DPRB PROD1 Lost sync between genset #2 & #3. Pull into csg to trouble shoot. 13:00 - 13:30 0.50 DRILL N DPRB PROD1 RIH. Trouble getting past ledge at 13715'. Work pipe & pump. Run at it fast, popped through. Back ream 13715' area twice with HS tool face. Unable to get past. PU and orient to 45R, no pump rate. RIH, through with a bobble. 13:30 - 16:00 2.50 DRILL N DPRB PROD1 Drill ahead. 3000 psi@2.6 bpm fs. 16:00 - 18:00 2,00 DRILL P PROD1 Drill ahead. 3150 psi@ 2.56 bpm fs. 200-350 dpsi mw. 1.5K-2.5K# wob. ROP:50-80 fph. 10.94 ppg ECD. Large pieces of coal in sample at 13,950 ft. 18:00 - 18:50 0.83 DRILL P PROD1 Wiper trip to 13750' Qp = 2.63 bpm. Pumped 15 bbl HV sweep while RIH 18:50 - 19:23 0.55 DRILL P PROD1 Tagged at 13986' Drilling w/80deg R TF ROP = 40-50 fph. PU at 13992' Clean, RIH drilling. ECD = 11.00 ppg 19:23 - 19:35 0.20 DRILL P PROD1 PU, pulled tight 10k over, RIH tagged 3 ft high, drill back to 14010 ft. PU and clean 19:35 - 21 :43 2.13 DRILL P PROD1 Drilling, ROP @ 50-60 fph, Qp = 2.63 bpm, CTP = 3500psi ECD @ 10.87 ppg. Pumped 18 bbl HV pull 21 :43 - 21:45 0.03 DRILL P PROD1 PU, orientTF to 110 FR 21 :45 - 22:16 0.52 DRILL P PROD1 Drilling w/ TF@ 120R ROP @ 50-60 fph, Qp = 2.63 bpm, CTP = 3600psi ECD @ 10.97 ppg. Pumped 18 bbl HV with Lube tech, KlaGard, caustic. 22:16 - 22:25 0.15 DRILL P PROD1 Wiper trip to Tie-in casing Clean with HS TF 22:25 - 22:30 0.08 DRILL P PROD1 Tie-in before going back in the window for depth control. Tie-in from 13575 ft to 13620 ft (+4 ft). Circulated 15 bbl H/L Vis sweep while in casing. No extra cutting were seen at shaker. 22:30 - 22:35 0.08 DRILL P PROD1 RIH, no problem at 13,714ft with HS TF. 22:35 - 23:35 1.00 DRILL P PROD1 PP of btm, 3060 psi at 2.64 bpm. TF @ 98R. Tagged bottom at 14,100 ft Drilling from 1410.2 ft. Having trouble with vibration and turn rates to low to stay in pologan. With present DLS unable to stay in pologon. 23:35 - 00:00 0.42 DRILL P PROD1 PUH to 13685' Orient TF to TH and RIH and tagged @ 13714' PU and oriented to 45 R tagged. PUH and oriented TF 60 and bounced through. Notified AOGCC on upcoming weekly BOP test. Left message on pager to have call back 3/4/2004 00:00 - 00:15 0,25 DRILL N DPRB PROD1 PUH and oriented TF 60 and bounced through. Back ream trouble area at 13,714 ft at varous TF 00:15 - 01:05 0.83 DRILL N DPRB PROD1 Back ream trouble area at 13,714 ft at varous TF, HS, 45R, 90R, 125R, 180R. No trouble RIH after back reaming at any TF 01 :05 - 03:25 2.33 DRILL P PROD1 POOH at Qp = 2.3 bpm, Held PJSM while POOH on BHA Printed: 3/15/2004 10: 17:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 3/4/2004 01 :05 - 03:25 2.33 DRILL P PROD1 Handling 03:25 - 04:00 0.58 DRILL P PROD1 OOH and closed SV. LD BHA 04:00 - 04:20 0.33 DRILL P PROD1 PJSM on N2 blow down of coiled tubing 04:20 - 04:35 0.25 DRILL P PROD1 Pumped 5 bbl water, 5 bbl meoh 04:35 - 05:30 0.92 DRILL P PROD1 Blow down CT 05:30 - 06:15 0.75 DRILL P PROD1 Cut CTC off. Dress coil. Install grapple connector w/ tugger cable. 06:15 - 06:30 0.25 DRILL P PROD1 Work inside reel. 06:30 - 07:00 0,50 DRILL P PROD1 PJSM to discuss sim ops for BOP test, unstabbing coil, dropping reel. 07:00 - 08:00 1.00 DRILL P PROD1 Unstab coil and spool back onto reel. Secure coil to reel. Begin weekly BOP test. Called AOGCC twice, no response. 08:00 - 09:15 1.25 DRILL P PROD1 Spot empty flat bed. Open bay door. Lower reel to trailer & secure 09:15 - 10:45 1.50 DRILL P PROD1 Remove old reel bushings using torch. Install new bushings. 10:45 - 12:00 1.25 DRILL P PROD1 Open bay doors. RU up to and lift replacement reel into place. Secure same, Close door. 12:00·13:00 1.00 DRILL P PROD1 Secure reel mounts. Prep to stab pipe. Dress coil end. Install tugger grapple. 13:00 - 14:45 1.75 DRILL P PROD1 Unsecure coil from reel flanges. BOP test completed, no failure. Pull coil across pipe shed and through injector. 14:45 - 19:00 4.25 DRILL P PROD1 Cut & dress coil. MU ELCTC. Meg line. OK. Test same. Pull tested to 30k OK. Line out to fluid pack CT 19:00 - 21 :00 2.00 DRILL P PROD1 Fluid pack CT w/ 5 bbl MEOH and 12 bbl H20 followed by Flo-Pro at 0.75 bpm Using 90 bbl. PT ECTC to 4000 psi 21:00-22:10 1.17 DRILL P PROD1 PU BHI BHA w/3.5 deg AKO setting and DS49 bit. Scribed to HS (174 deg) Tested tool OK. 22:10 - 00:00 1,83 DRILL P PROD1 RIH 3/5/2004 00:00 - 01 :00 1,00 DRILL PROD1 RIH 01 :00 - 01 :30 0.50 DRILL N DFAL PROD1 Tie-in at 13575 ft with GR. BHI tool shorted. Checked all surface leads and rebooted computer without results. Dead electrical short down hole. Conducted PJSM while POOH on BHA handling 01 :30 - 04:00 2.50 DRILL N DFAL PROD1 POOH 04:00 - 05:10 1.17 DRILL N DFAL PROD1 Blow down tool. Break off upper connect sub, found exposed wire. Arc against the housing. Redo cable connection and test. 05:10·08:00 2.83 DRILL N DFAL PROD1 RIH. 08:00 - 08:15 0.25 DRILL P PROD1 Log gr tie in from 13560'. Add 9' correction. 08:15 - 08:45 0.50 DRILL P PROD1 RIH through window at 45R. No bobble at window or "ledge", Orient to 75R. Hole clean to btm, some mtr work while RIH. but not much. 08:45 - 09:15 0.50 DRILL P PROD1 Drill ahead 3750 psi@ 2.6 bpm fs. 300-500 dpsi. 3K-4K# wob. 50-70 fph ROP. 10,9 ppg ECD. A lot of thumb sized coal chunks over shaker with btms up. 09:15 - 10:15 1.00 DRILL P PROD1 Drilling break. Short trip to window. 7K # overpull off btm. , Some motor work while RIH. Otherwise fairly smooth. 10:15 - 12:30 2.25 DRILL P PROD1 Drill ahead. Getting 45 deg doglegs. ROP:60-80 fph. Projected azimuth is 92 deg. Drilled trajectory is south of original plan. Inc: 90 deg. 12:30 - 13:30 1.00 DRILL P PROD1 Wiper to window. POOH for BHA change. Clrc pressure indicates trying to pack off in csg. Open EDC. RIH. Circ 5 bbls 10 vis followed by 5 bbls hi vis pills. Printed: 3/15/2004 10:17:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 3/5/2004 13:30 - 17:15 3.75 DRILL P PROD1 POOH at 60 fpm to clean hole. Return micro motion keeps packing off with coal. Trouble shoot SLB ops cab computer. System keeps locking up, need to re-start several times. Check last 150' coil for wear and ovality. OK. 17:15 - 18:45 1.50 DRILL P PROD1 At surface. Get off well. Unstab coil. Replace set screws on ELCTC. PU BHA with Resitivity Tool. AKO setting at 1.6 deg 18:45 - 21 :10 2.42 DRILL P PROD1 RIH with BHA # 21 21 :10 - 21 :24 0.23 DRILL P PROD1 Tie-in at 13575'. Corrected +7 ft from 13,615 ft to 13,622 ft 21 :24 - 21 :58 0.57 DRILL P PROD1 RIH with TF at 30R TF. No problem at 13,714 ft Tagged at 14282' Pp (off btm=3650 psi), PU WI = 46k at 2.5 bpm. RIH WI =20k down. 21 :58 - 23:00 1.03 DRILL P PROD1 Drilling at 90 L TF, Qp = 2.5 bpm Pp = 3889 on btm. ECD = 10.85 ppg. Getting lots harmonics from tool. Taking survey with reduced Qp. ROP = 80 to 90 fph 23:00 - 23:05 0,08 DRILL P PROD1 Orient TF to right side 23:05 - 23:35 0.50 DRILL P PROD1 Drilling at 90 RTF, Qp = 2.5 bpm Pp = 3918 on btm. ECD = 10.95 ppg. ROP 90-120 fph Stacking 23:35 - 23:42 0.12 DRILL P PROD1 100 ft wiper trip due to stacking 23:42 - 00:00 0,30 DRILL P PROD1 Drilling at 90 RTF, Qp = 2.5 bpm Pp = 4100 on btm. ECD = 10.83 ppg. ROP80-90fph Vol pits = 358 bbl Stacking problem. Ordered new 500bbl mud system 3/6/2004 00:00 - 00:05 0.08 DRILL P PROD1 Drilled to 14400 ft 00:05 - 01 :55 1.83 DRILL P PROD1 Wiper trip to above whipstock 13,500 ft, Pumped sweep in casing, Checked survey at 13805' RIH and tagged at 14254' MD. 180 deg directional orientation Went through 14254 with HS TF. Orient TF to 90 R while RIH 01 :55 - 02:00 0.08 DRILL P PROD1 Drilled to 14414'. PU = 53k Survey not coming up 02:00 - 02:10 0.17 DRILL P PROD1 Pump up survey at lower pump rates 02:10 - 03:35 1.42 DRILL P PROD1 Drilling wI 125 RTF. Qp = 2.48bpm, Pp (on btm)=3950psi, Vp = 373 bbl. ROP 60 to 80 fph. ECD = 10.91 03:35 - 04:35 1.00 DRILL P PROD1 Wiper trip after drill 125 ft Pumped 10/10 HI bbl sweep while in the tubing RIH and tagged the bottom of window at 13,705' with HS, twice Orient TF to 10R, tagged, oriented TF ti 45R and bounce through 04:35 - 04:50 0.25 DRILL P PROD1 Log RA Tag at 13,705.5' Corrected + 5ft 04:50 - 05:25 0.58 DRILL P PROD1 RIH at min flowrate Qp = 0.50bpm and 20 fpm. 05:25 - 07:00 1.58 DRILL P PROD1 Drilling, TF 180, Pp 3600/3950 psi, Qp = 2.48 psi, ROP = 90 fpm 07:00 - 08:30 1.50 DRILL P PROD1 Wiper trip to window. 3520 psi @ 2.48 bpm fs. 10.84 ppg ECD. Some motor work while POOH. 2380 pSi@ 1.52 bpm fs while RIH @ 20 fpm. Again, some mtr work, minor, hole quite smooth. 53k# up, 16k# dn WI. 08:30 - 12:00 3.50 DRILL P PROD1 Drill ahead. 3560 psi@ 2.58 bpm fs. ROP:60-90 fpm. Printed: 3/15/2004 10:17:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 3/6/2004 08:30 - 12:00 3.50 DRILL P PROD1 WOB:2K-3k#. Getting some overpulls off btm. Acting like mud is wearing out. Doyon 15 off of Endicott access road. Begin mud swap to new 9.5 ppg flo pro system. Hole much less sticky when PU off btm with new mud, 12:00·14:00 2.00 DRILL P PROD1 Drill to 14807'. 14:00· 14:45 0.75 DRILL P PROD1 Wiper trip above window. Pump 5 bbllo/1 0 hi vis sweep, timed for above window. 14:45 - 15:15 0.50 DRILL P PROD1 Log gr tie in from 13585'. Add 5' correction. 15:15 - 16:00 0.75 DRILL P PROD1 RIH through window, etc, Smooth with some motor work, nothing major. 16:00 - 18:00 2.00 DRILL P PROD1 Drill ahead, 3700 psi@ 2.53 bpm fs. 400-600 dpsi. WOB: 3K#-4.5k# ROP: 60-90 fph. Some stacking 18:00 - 18:29 0.48 DRILL P PROD1 Drill ahead, TF @ 90 L. 3660 psi@ 2.50 bpm fs. 400-600 dpsi. WOB: 3K#-4.5k# ROP: 60-90 fph. Some stacking occurring Vp = 278 bbl 18:29 - 20:38 2.15 DRILL P PROD1 Wiper trip to above window Bypassed micro motion Pumped sweep around. RIH and tagged 13710 ft Tried several TF and was unable to get past 13698 and 13710' 20:38 - 21 :05 0.45 DRILL N DPRB PROD1 Tie-in casing at 13575 ft Corrected to +6 ft 21:05-22:10 1.08 DRILL N DPRB PROD1 Working to get past DLS at 13714 ft at various TF's. Worked TF around 3 times and still tagging at 13714 ft corrected 22:10 - 00:00 1.83 DRILL N DPRB PROD1 POOH to PU bigger AKO setting motor 3/7/2004 00:00 - 00:25 0.42 DRILL N DPRB PROD1 POOH, PJSM on BHA handling while POOH 00:25 - 02:11 1.77 DRILL N DPRB PROD1 Change out motors AKO setting from 1.6 to 2.2 deg. PU used DS100 BC bit. Scribed HS and confirmed @ 208 deg 02:11 - 03:55 1.73 DRILL N DPRB PROD1 RIH to 9890ft 03:55 - 04:20 0.42 DRILL N DFAL PROD1 Working to function test BHI Orientor. Getting amp but will not function. Tried several things and it didn't move 04:20 - 06:30 2,17 DRILL N DFAL PROD1 POOH to change Orienter. Get off well. Check 50' for coil wear. Unstab coil. 06:30 - 09:00 2.50 DRILL N DFAL PROD1 LD BHA. Cut 50' coil due to wear, Test orienter at surface - would not function, MU replacement orienter-would not funtion. Change out orienter assembly again, 3rd one tested. MU tools 09:00 - 12:15 3.25 DRILL N DFAL PROD1 RIH with 2.2 deg mtr & bicenter (DS100) bit. 12:15 - 12:30 0.25 DRILL P PROD1 Log gr tie in from 13560'. Add 6' correction. 12:30 - 14:00 1.50 DRILL P PROD1 RIH. TF:45R. Set down at 13714'. PU and orient to 90R. Set down again. PU. Orient to 15R. RIH. Bounce through. Continue in hole at 20 fpm orienting to maintain drilled TF. 46k# up, 18.5k# dn wt, 14:00 - 18:20 4.33 DRILL P PROD1 Drill ahead. Op = 2.52 bpm, CTP = 4113 psi/3720 psi off bottom. ROP = 31 fph, ECD = 11.01 ppg 18:20 - 19:41 1.35 DRILL P PROD1 Drill ahead.TF at 120 R Op = 2.52 bpm, CTP = 4113 psif3720 psi off bottom. ROP = 31 to 40 fph, ECD = 11..01 ppg Vp = 274 bbl 19:41-21:30 1.82 DRILL P PROD1 Wiper trip just below window. Some motor work in the coal at 13,950 ft while PUH. Sample of HOT in samples. Will turn TF to left and build hole angle 21 :30 - 22:50 1.33 DRILL P PROD1 Drill ahead TF at 30L. Op = 2.52 bpm, CTP = 4113 psi/3830 psi off bottom. ROP = 40 to 60 fph, ECD = 11..01 ppg Vp = 268 bbl 22:50 - 23:14 0.40 DRILL P PROD1 100 ft wiper trip, having some trouble getting back to bottom after making 180 deg turn. Pulled 70k once Printed: 3/15/2004 10: 17:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 3/7/2004 23:14 - 00:00 0.77 DRILL P PROD1 Wiper trip to just below window. Clean trip out 3/8/2004 00:00 - 00:45 0.75 DRILL P PROD1 RIH to 14900 ft. 00:45 - 01 :35 0.83 DRILL P PROD1 MADD pass for Geologist at 300 fph from 14,900 ft to 15,107' 01 :35 - 02:45 1.17 DRILL P PROD1 Drill ahead TF at 120L. Qp = 2.47 bpm, CTP = 4,450 psi/3730 psi off bottom. ROP = 40 to 60 fph, ECD = 11..11 ppg Vp = 256 bbl. Some fluid seepage during wiper trips due to surge pressures. Showing some Res separation on the log 02:45 - 04:45 2.00 DRILL P PROD1 Wiper trip, ECD increasing from 11.0 to 11.16 ppg. Vp1 = 256 bbl. Pumped 10 bbl H-Vis Sweep ESC back on bottom still at 11.2ppg 04:45 - 05:35 0.83 DRILL P PROD1 Drill ahead TF at 75R. Qp = 2.42 bpm, CTP = 4,543 psi/3,730 psi off bottom. ROP = 40 to 60 fph, ECD = 11.20 ppg Vp = 256 bbl. Swapped to MP#1 at 15,191 ft. MP#2 down due to corrosion/seal ring leak. 05:35 - 10:00 4.42 DRILL P PROD1 Wiper trip while repairing MP#1, Decide not to drill ahead with one pump due to concern of high volume of large cuttings possibly in annulus. POOH to just below window. Circulate at full rate while tripping through build section with HS tool face to try and clean up tbg annulus. Pump #2 back on line. 10:00 - 12:00 2.00 DRILL P PROD1 Drill ahead. 3900 psi@ 2.4 bpm fs. 250-400 dpsi. WOB: 2k#-3k#. ROP:25 fph. TF: various, trying to drop. Pit Vol: 238. Lost 18 bbls since 0530 hrs. ECD: 11.0 ppg 12:00 - 14:00 2.00 DRILL P PROD1 Drill ahead. 3850 psi @ 2.41 bpm, 300-400 dpsi. WOB: 2K#-2.5k#. ROP:20-25 fph. Continue to drop angle/TVD. 14:00 - 16:00 2.00 DRILL P PROD1 Drill ahead, 16:00 - 18:00 2.00 DRILL P PROD1 Drill ahead. Start new mud down hole. 3650 psi@ 2.51 bpm fs. 400-500 dpsi. WOB:3K-4K#. ROP:50-70 fph. TF: 90L Inc: 82deg. 18:00 - 18:57 0,95 DRILL P PROD1 Wiper trip at 15,350 ft to 14,101 ft 18:57 - 19:40 0,72 DRILL P PROD1 MADD pass Restivity Tools to check its integrity for town from 14,100 ft to 13,950 ft at 300 fph. 19:40 - 19:50 0.17 DRILL P PROD1 Finish PUH to 13,750 ft Pull tight at 13970 ft and 13975' (Coals) 19:50 - 20:50 1.00 DRILL P PROD1 RIH at reduced speeds & Qp through coal areas 20:50 - 22:06 1.27 DRILL P PROD1 Tagged bottom at 13,530 ft Drilling at 70L Qp = 2.48bpm, Pp of btm = 3700/4093 psi ROP at 40 to 60 fph, ECD=11.07ppg TD well at 15,422 ft 22:06 - 22:11 0.08 DRILL P PROD1 PUH to MADD pass as per Geologist 22:11 - 23:45 1.57 DRILL P PROD1 MADD pass up at 282 fph from 15310 ft to 14890 ft. Pulled tight at 15,222 ft (oriention change) 23:45 - 00:00 0.25 DRILL P PROD1 PUH for tie-in 3/9/2004 00:00 - 00:45 0.75 DRILL PROD1 PUH to 13575' to Tie-In 00:45 - 01 :00 0.25 DRILL PROD1 Tie in (+18 ft) 01 :00 - 02:45 1.75 DRILL N DPRB PROD1 Orient TF to HS and RIH and tagged 13,714 ft. Tried various TF and unable to get through. 02:45 - 06:30 3.75 DRILL N DPRB PROD1 POOH to PU Dummy Liner running BHA. Inspecting 100 ft CT while POOH 06:30 - 07:00 0.50 DRILL N DPRB PROD1 LD drilling BHA. 07:00 - 08:45 1.75 DRILL N DPRB PROD1 MU dummy liner assembly with crayola guide shoe and 3.7" od centralizer. 08:45 - 10:00 1.25 DRILL N DPRB PROD1 Decide to remove and modify centralizer. LD 5 jts tbg. Remove centralizer. MU 4 jts 2-7/8" with 1 jt 2-3/8" with tappered guide float shoe. First Energy on location to heat up Printed: 3/15/2004 10: 17:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K -30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 3/9/2004 08:45 - 10:00 1.25 DRILL N DPRB PROD1 crude transport. Hold PJSM with crew before heating operation. 10:00 - 12:30 2.50 DRILL N DPRB PROD1 RIH with dummy liner assy. MWD shorted out at 5860'. Discuss with town and continue to RIH. Plan is to not let turbos go out through window. Corrected to flag at 10300 ft, (+9.30 ft with BHA of 189.9 ft) Failure in MWD was short in EDC downhole, then found short in flow sub on surface 12:30 - 12:55 0.42 DRILL N DPRB PROD1 Tagged at 13718'/13714' uncorrected. Worked several times with pump and different Qp. 12:55 - 15:14 2.32 DRILL N DPRB PROD1 POOH to 300 ft 15:14 - 15:35 0.35 DRILL N DPRB PROD1 PUH inspecting CT 15:35 - 16:00 0.42 DRILL N DPRB PROD1 LD dummy liner assy #1-no visible scars 16:00 - 17:00 1.00 DRILL N DPRB PROD1 WO centralizer from BTT (stuck behind impassable load on Endicott access) 17:00 - 17:55 0.92 DRILL N DPRB PROD1 MU dummy liner assy #2 (added 3.70" centralizer above FS of dummy liner assy #1) 17:55 - 20:15 2.33 DRILL N DPRB PROD1 RIH w/ BHA #25. Stop at flag at 10482.5'. Corr +7.6',0.4/1230 20:15 - 20:40 0.42 DRILL N DPRB PROD1 13650' 53k. RIH at tag at 13718' CTD. Work to get by with all known tricks wI and wlo pump and set down at same place every time 0.4/1350, 2.38/3230 20:40 - 22:45 2.08 DRILL N DPRB PROD1 POOH 22:45 - 23:30 0.75 DRILL N DPRB PROD1 LD dummy liner assy #2-no visible scars 23:30 - 00:00 0.50 DRILL N DPRB PROD1 Surface test orientor, okay 3/10/2004 00:00 - 00:50 0.83 DRILL N DPRB PROD1 MU 2-7/8 STL dummy liner run consisting of round nose guide shoe, 3.70" cent, 3* bent 2-7/8 STL pup, WII orientor, 4 jts 2-7/8 STL w/ turbos on BHI BHA 00:50 - 03:00 2.17 DRILL N DPRB PROD1 RIH w/ BHA #26. Corr +5' at flag at 10300' EOP 13650' 52.2k, 21.4k, 0.66/1770 03:00 - 03:30 0.50 DRILL N DPRB PROD1 Tag at 13714' CTD. Orient 2 clicks in 4-1/2" each attempt and get by ledge w/ sli bobble after three attempts. RIH to 13776', clean. PUH thru window, clean 1.7/3070 03:30 - 03:55 0.42 DRILL N DPRB PROD1 Log tie-in down from 13692' bit depth and tie-in to GR character at 13563' 1.7/3070 Clean thru window and by ledge. Add 1.0' 03:55 - 04:45 0.83 DRILL N DPRB PROD1 RIH in open hole at 30'/min 1.713100. Red rate to 0.7/1880 thru 13950-14080', clean. Start 60 bbls fresh mud 1.3/2700 while RIH, clean to TD. Tag at 15436' (revised TD) 04:45 - 05:05 0.33 DRILL N DPRB PROD1 PUH 48.4k, clean while fin circ fresh mud to shoe 05:05 - 06:00 0.92 DRILL N DPRB PROD1 POOH laying in fresh mud in OH from TD 1.0/2440 at 30'/min 49k, clean 06:00 - 09:30 3.50 DRILL N DPRB PROD1 POOH for liner 09:30 - 09:45 0.25 DRILL N PROD1 Surface test orientor.OK. 09:45 - 10:50 1.08 CEMT P COMP Pump N2 10:50 - 11:30 0.67 CEMT P COMP Bleed off N2 11 :30 - 13:00 1,50 CEMT P COMP Cut coil 20'.lnstall grapple and cable. Spool back coil to reel and secure. 13:00 - 13:50 0.83 CEMT P COMP Clear rig floor. Prep reel for swap. Stand back injector. 13:50 - 14:10 0.33 CASE P COMP RU floor for liner running. 14:10 - 14:20 0.17 CASE P COMP PJSM for liner running. 14:20 - 18:00 3.67 CASE P COMP PU 2-7/8" 13% CR STL liner. Sim opsr prep to exchange reel continues. 18:00 - 18:15 0,25 CASE P COMP Safety mtg re: pull CT to floor and stab 18:15-19:50 1.58 CASE P COMP Install internal grapple and PT. Pull CT to floor and stab into Printed: 3/15/2004 10:17:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 2/20/2004 3/13/2004 N2 Spud Date: 2/23/2004 End: 3/13/2004 3/10/2004 18:15 -19:50 1.58 CASE P COMP injector. Install BTT CTC. PT 40k 19:50 - 21:40 1.83 CASE P COMP Pump 8 bbls MeOH, 40 bbls FW followed by mud. Load CT wiper dart and displace w/ mud. Dart on seat at 57.5 bbls-sheared BTT catcher at 2700. RD catcher, install test plate. PT reel 9402/CTC to 4725 psi for 5 min and flatline 21 :40 - 23:45 2,08 CASE P COMP RIH w/liner assy on CT 23:45 - 00:00 0,25 CASE P COMP 13650' 49k, 18k 0.5/1730. RIH and set down at 13704' CTD. Begin orienting wI shoe in 4-1/2" 2 clicks/attempt 3/11/2004 00:00 - 00:25 0.42 CASE P COMP Continue orienting and attempting to get by ledge at 13704' CTD. After 12 clicks (360 deg), bounced thru 00:25 - 01 :40 1.25 CASE P COMP RIH w/liner in OH 45'/min 0.5/1550 Set downs began at 15130'. Work to 15250' and progress stopped. Orient 3 clicks, SD pump. Continue to work to TD tagged at 15424' CTD. Recip 6 times and no more progress (pulling to 75k just to move up hole) TOL @ 13659' (for you, JCM) 01 :40 - 02:20 0.67 CASE P COMP Confirm circulation. Load 3/8" steel ball and circ to seat w/ mud 1.95/3200 w/ full returns. Ball hit at 69.5 bbls. New rate 2.0/2300 w/ circ sub open 02:20 - 02:55 0.58 CASE P COMP Load 5/8" steel ball and circ to seat wI mud 2.0/2320 (noted lots of small coal chips in returns). Ball seat sheared at 3600 psi. PUH 42k and released from liner. Stack 6k 02:55 - 04:30 1.58 CASE P COMP Displace 9.5# mud w/9.5# NaCI w/3% KCI/w 3% L T 2.8/2830 MIRU DS cementers. Safety mtg re: cementing 04:30 - 05:00 0.50 CEMT P COMP Fin batch up cement. Wellbore displaced to 9.5# brine, circ 2.8/2160 full returns 05:00 - 05:35 0.58 CEMT P COMP PT DS @ 4000 psi. Load CT w/21.0 bbls G expandable cement w/latex 2.0/1200, TT 4:40 05:35 - 06:30 0.92 CEMT P COMP Load CT wiper dart and check. Displace w/ 30 bbls biozan followed wI 9.5# brine 2.6/1800. Took 15 bbl to catch cement. Continue to displace. PU liner wiper plug at57.7bbls. Pressure to 3300 psi to shear. Bumped at 67.3 bpm calculated 67.6 bpm,. Floats held. Pressure to 500 psi up observe pressure fall off as seals unsting. No indications of packoff during displacement. 06:30 - 09:30 3.00 CEMT P COMP POH filling replacement volume. 09:30 - 19:00 9.50 BOPSU P COMP Weekly BOP test. AOGCC John Chrisp waived witnessing the test. Repl and test #14 choke valve while wo XO for BHA 19:00 - 19:15 0.25 EVAL P COMP TUsafety mtg re: source 19:15 - 21:45 2.50 EVAL P COMP MU safety jt. MU CNL carrier assy w/ motor and mill Drift while MU 30 stands CSH Kick drill 21:45 - 23:10 1.42 EVAL P COMP RIH w/ BHA #27 0.5/500 Cement comp str=1300 psi 23:10 - 00:00 0.83 EVAL P COMP Begin logging down at 30'/min 1.5/2130 from 9700' 3/12/2004 00:00 - 01 :30 1.50 EVAL P COMP Continue logging down wI CNL at 30'/min 1.5/2090 16k Cement comp str=2000 psi Lost 2k wt at 12430' and 12460' momentarily, but no motor work 01 :30 - 02:30 1.00 EVAL P COMP Enter TOL, clean 19k. Continue log to PBD 1.5/2150 23k. Start 13 bbls fresh Hi LSRV mud 02:30 - 03:00 0.50 EVAL P COMP Tag at 15376' CTD. PUH 51k logging 60'/min 0.5/760 while leaving mud in liner 03:00·04:10 1.17 EVAL P COMP Log from TOL to 9700' 60'/min 1.5/2180 Dump 40 bbls of cement contaminated mud w/ max density of 10.1 # Printed: 3/15/2004 10:17:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3-17E/K-30 3-17E/K-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 2/20/2004 Rig Release: 3/13/2004 Rig Number: N2 Spud Date: 2/23/2004 End: 3/13/2004 3/12/2004 04:10 - 05:20 1.17 EVAL P COMP POOH 05:20 - 06:30 1.17 EVAL P COMP Prep to Standback CSH workstring. Crew change, PJSM. 06:30 - 08:15 1.75 EVAL P COMP Stand back CSH. 08:15 - 08:30 0.25 EVAL P COMP Remove source from tool. LD logging tools. 08:30 - 09:15 0.75 EVAL P COMP LD BHA. Recovered tip of brass from tail of wiper dart. Definately at landing collar. 09:15 - 10:10 0.92 EVAL P COMP MU cleanout. BHA. 3.78" D331 motor + one joint. 10:10 - 12:50 2.67 EVAL P COMP RIH at max rate 100 fpm seen one bobble 13260 slow to 42 fpm. Tag 15,648 as Hi vis sweep turned corner. 12:50 - 15:30 2.67 EVAL P COMP POH. 15:30 - 16:00 0,50 EV AL P COMP LD cleanout BHA. 16:00 - 16:30 0.50 PERF P COMP Test Liner lap. Lost 190 psi in 30 minutes. Good test. 16:30 - 18:05 1.58 PERF P COMP Prep floor for perforating. MU perf guns 18:05 - 18:20 0.25 PERF P COMP Safety mtg re: CSH 18:20 - 19:35 1.25 PERF P COMP MU 30 stds CSH 19:35 - 22:15 2.67 PERF P COMP RIH Iw BHA #29 Begin moving mise equiment to MPI 22: 15 - 22:35 0.33 PERF P COMP Tag at 15376' CTD 0.3/130, PUH 49k 3 times to verify PU wt at 15369' and corr to 15389' CNL up pass. Park at ball drop and fin circ 11 bbl Flo Vis pill to CT 22:35 - 23:05 0.50 PERF P COMP Load 5/8" steel ball and circ to seat 1.9/2400, 1.0/650. Ball seat sheared at 3000 psi while PUH at 3'/min 48.5k. No other indicators of firing. PVT 168 Perforated 15307-15382' CNL w/ SWS 2" PJ guns @ 6 spf 23:05 - 00:00 0.92 PERF P COMP POOH, clean 3/13/2004 00:00 - 01 :30 1.50 PERF P COMP Finish POOH w/ CT 1,0/600 PVT 97 01 :30 - 02:50 1.33 PERF P COMP Standback CSH workstring 02:50 - 03:00 0.17 PERF P COMP Safety mtg re: LD perf guns 03:00 - 04:00 1.00 PERF P COMP LD perf guns and load out-all shots fired 04:00 - 04:50 0.83 CASE P COMP Load BTT L TP assy to floor Safety mtg re: MU BHA MU L TP assy on 1 jt PH6 04:50 - 08:10 3.33 CASE P COMP RIH w/ BHA #30 to 13600'. 08:10 - 08:30 0.33 CASE P COMP PU 45K, SO 22K .44 bpm at 80 psi. Sting in at 13650. Take weight at 13654. stack 10K at 13658.7' PU to 13610. Ball drop position. 08:30 - 09:10 0.67 CASE P COMP Displace ball with 2 bpm @ 1223 psi. After 43 bbl slow to .5 bpm. 80 psi. Ball on seat.52,7 bbl. 09:10 - 09:45 0.58 CASE P COMP RIH to 13,653. Pressure to 2000 psi. with .6bbls. Stack 10K, Over pull 5K. OK. SO to 20K. Bleed off coil to 1000 psi. Test packer to 2000 psi. Good Test. Stack 10K. Shear ball seat with 3300 psi. Top off liner tie back sleeve. 13645'. 09:45 - 12:15 2.50 CASE P COMP POH t. FP with neet methanol from 2000'. 12:15 - 13:00 0.75 CASE P COMP LD L TP setting assy 13:00 - 14:30 1.50 CASE P COMP WO DSM. RU DSM. Set 4-1/2" BPV. RDMO DSM 14:30 - 18:00 3.50 BOPSU P POST ND BOPE. NU tree cap and test Fin clean pits. Gen RD Rig released from 3-17F at 1800 hrs 3/13/2004 Printed: 3/15/2004 10:17:02 AM ,--", ObP e e ... u_ IIIIGIIIS INTEQ 1 û 1.- Company: BP Amoco Date: 4/6/2004 Time: 10:11:18 Page: 1 Field: Endicott Co-ordinate(NE) Reference: Well: 3-17/J-30, True North Site: End SDI Vertical (TVD) Reference: 3-17E: 52.6 Well: 3-17IJ-30 Section (VS) Reference: Well (0.00N,0.00E,60.00Azi) Wellpath: 3-17F/K-30 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Endicott North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 3 Geo Datum: NA027 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2003 Site: End SOl TR-11-17 UNITED STATES: North Slope Site Position: Northing: 5969322.46 ft Latitude: 70 19 4.709 N From: Map Easting: 272231.79 ft Longitude: 147 50 47.497 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 14.50 ft Grid Convergence: -1.74 deg Well: 3-17/J-30 Slot Name: 3-17/J-30 Well Position: +N/-S 1590.34 ft Northing: 5970973.83 ft Latitude: 70 19 20.347 N +E/-W -2037.70 ft Easting : 270243.36 ft Longitude: 147 51 46.966 W Position Uncertainty: 0.00 ft Wellpath: 3-17F/K-30 Drilled From: 3-17E/K-30 500292194606 Tie-on Depth: 13698.00 ft Current Datum: 3-17E: Height 52.60 ft Above System Datum: Mean Sea Level Magnetic Data: 3/4/2004 Declination: 25,79 deg Field Strength: 57629 nT Mag Dip Angle: 80.97 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 38,10 0.00 0.00 60.00 Survey Program for Definitive Well path Date: 4/6/2004 Validated: Yes Version: 11 Actual From To Survey Toolcode Tool Name ft ft 96.10 9946.10 1: Gyrodata cont.drillpipe m/ (96.10-10446. myI(9CT-DMS Gyrodata cont.drillpipe m/s 9976.00 13652.51 3-17E/K-30 (9976.00-14048.00) (1) MWO MWD - Standard 13698.00 15436.00 MWO (13698.00-15436.00) MWO MWO - Standard Annotation MD TVD ft ft 13652.51 10069.74 TIP 13698.00 10107.65 KOP 15436.00 10224.19 TO Survey: MWD Start Date: 3/8/2004 CoilTrak Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWO - Standard Tied-to: From: Definitive Path RECE\VEO RECEIVFr ',.,-",.. .J APR 1 9 2004 'i 9 ?n04 .~ Comtn\Ss\on 0'\ & Gas Cons. þ.\aska \ ~nchoraQe BP-GDB Baker Hughes INTEQ Survey Report ;ll~ Obp e BP-GDB Baker Hughes INTEQ Survey Report e Bit. .....1tIIa HUG,,, lNT£Q Company: BP Amoco Date: 4/6/2004 Time: 10:11:18 Page: 2 Field: Endicott Co-ordinate(NE) Reference: Well: 3-1?/J-30, True North Site: End SDI Vertical (TVD) Reference: 3-17E: 52.6 Well: 3-17IJ-30 Section (VS) Reference: Well (0.OON,0.00E,60.00Azi) Wellpath: 3-17F/K-30 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD lncl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/10OO 13652.51 33.66 344.42 10069.74 10017.14 7758.44 -395.96 5978740.44 270085.11 3536.30 0.00 13698.00 33.44 344.32 10107,65 10055.05 7782.65 -402.74 5978764.85 270079.08 3542.54 0.50 13733.30 48.66 353.35 10134.22 10081.62 7805.33 -406.93 5978787,64 270075.58 3550.25 46.18 13763.50 62.64 358.14 10151.22 10098.62 7830,12 -408.69 5978812.48 270074.59 3561,13 48.09 13780.76 70.85 0.34 10158.03 10105.43 7845.97 -408.89 5978828.32 270074.87 3568.88 48.98 13808.40 78.02 3.63 10165.45 10112.85 7872.55 -407.95 5978854.87 270076.62 3582.98 28.36 13830.32 77.95 12.63 10170.02 10117.42 7893.76 -404.92 5978875.96 270080.30 3596.20 40.16 13872. 70 80.52 1.03 10177.96 10125.36 7935.02 -400.00 5978917.05 270086.48 3621.10 27.56 13903.46 85.75 3.53 10181.64 10129.04 7965.52 -398.78 5978947.50 270088.63 3637.40 18.82 13930.25 84.49 9.92 10183.92 10131,32 7992.01 -395.66 5978973.89 270092.56 3653.36 24.23 13964.55 87.23 11.50 10186.39 10133,79 8025.62 -389.30 5979007.29 270099.95 3675.67 9.22 13996.15 90.71 17.89 10186.96 10134.36 8056.16 -381.29 5979037.57 270108.89 3697.87 23.02 14031.54 90,65 24.06 10186.54 10133.94 8089.19 -368.63 5979070.19 270122.55 3725.35 17.43 14075.48 89.20 28.92 10186.60 10134.00 8128,51 -349.04 5979108.88 270143.34 3761.98 11.54 14097.97 86.63 30.02 10187.42 10134.82 8148.07 -337.98 5979128,10 270154.99 3781.34 12.43 14155.76 93.29 62.50 10187.46 10134.86 8187.47 -296.81 5979166.22 270197.35 3836.69 57.34 14184.24 98.91 72.47 10184.43 10131.83 8198.31 -270.70 5979176.25 270223.78 3864.72 40.00 14220.24 89.08 87.56 10181.91 10129.31 8204.48 -235.4 7 5979181.35 270259.18 3898.32 49.90 14242.31 90.55 92.00 10181.98 10129.38 8204.57 -213.41 5979180.75 270281.23 3917.47 21.19 14281.82 86.79 79.03 10182.90 10130.30 8207.64 -174.12 5979182.63 270320,59 3953.03 34.16 14317.39 88.89 70.06 10184.24 10131,64 8217.11 -139.90 5979191.04 270355.09 3987.40 25.88 14355.18 93.25 72.64 10183.54 10130.94 8229.19 -104.11 5979202.02 270391.23 4024.43 13.40 14384.04 93.65 81.41 10181.80 10129.20 8235.65 -76.06 5979207.62 270419.45 4051.95 30,36 14429.81 93.48 90.44 10178.94 10126.34 8238.89 -30.55 5979209.47 270465.05 4092.99 19.69 14454.07 91.38 94.56 10177.92 10125.32 8237.83 -6.34 5979207.67 270489.21 4113.43 19.05 14493.14 90.74 100.13 10177.19 10124.59 8232.84 32.39 5979201.49 270527.77 4144.47 14.35 14531.77 87.63 106.70 10177.74 10125.14 8223,89 69.94 5979191.39 270565.02 4172.51 18.81 14563.63 82.88 106.23 10180.38 10127.78 8214.89 100.38 5979181.47 270595.17 4194.37 14.98 14580.17 83.70 108.36 10182.31 10129.71 8210.01 116.06 5979176.11 270610.69 4205.51 13.72 14615.26 87.08 103.63 10185.13 10132.53 8200.38 149.67 5979165.45 270643.99 4229.81 16.53 14640.37 86.62 108.84 10186.51 10133.91 8193.37 173.73 5979157.71 270667.83 4247.14 20.80 14671.21 85.94 115,42 10188.51 10135.91 8181.78 202.22 5979145.26 270695.95 4266.02 21.40 14700.01 85.24 119.74 10190.73 10138,13 8168.49 227.67 5979131.20 270720.98 4281.41 15.15 14730.92 84.24 126.65 10193.57 10140.97 8151.65 253.41 5979113.58 270746.19 4295.29 22.49 14760.95 86.06 133.10 10196.11 10143.51 8132.48 276,36 5979093.71 270768.54 4305.58 22.24 14790.30 88,13 137.88 10197.60 10145.00 8111.58 296.90 5979072.20 270788.43 4312.92 17.73 14820.40 90.49 132.05 10197.96 10145.36 8090.32 318.19 5979050.30 270809.06 4320.72 20.89 14850.18 90.40 127.05 10197.73 10145.13 8071.37 341.14 5979030,65 270831.42 4331.12 16.79 14880.70 90.74 122.68 10197.42 10144.82 8053.93 366.18 5979012.45 270855.91 4344.08 14.36 14931.77 90.06 111.05 10197.07 10144.47 8030.89 411.65 5978988.03 270900.66 4371,95 22.81 14961.38 90.46 114.72 10196.93 10144.33 8019.38 438.93 5978975.69 270927.56 4389.81 12.47 14992.47 89.63 121.24 10196.91 10144.31 8004.80 466.37 5978960.28 270954.54 4406.29 21.14 15020.37 88.03 126.51 10197.48 10144.88 7989.26 489.52 5978944.04 270977.21 4418.57 19.74 15049.22 89.50 129.42 10198.10 10145.50 7971.51 512.26 5978925.61 270999.39 4429.38 11.30 15082.16 92.34 124.68 10197.57 10144.97 7951.68 538.53 5978904.98 271025.04 4442.22 16.77 15110.73 88.07 120.64 10197.47 10144.87 7936.27 562.57 5978888.84 271048.60 4455.34 20.57 15124.47 86.12 117.95 10198.16 10145.56 7929.55 574.54 5978881.76 271060.36 4462.34 24,16 15153.75 85.42 111.84 10200.33 10147.73 7917.27 601.01 5978868.67 271086.44 4479.13 20.95 15176.29 87.26 107.55 10201.77 10149.17 7909.69 622.19 5978860.45 271107.37 4493.67 20.67 15208.88 88.81 114.71 10202.89 10150,29 7897.95 652.55 5978847.79 271137.36 4514.10 22.47 15243.96 86.41 113.20 10204.35 10151.75 7883.72 684.57 5978832.59 271168.93 4534,72 8.08 15275.71 81.98 109.79 10207.56 10154.96 7872.15 713.95 5978820.12 271197.94 4554.38 17.57 15306.74 81.49 102.05 10212.03 10159.43 7863.73 743.46 5978810.80 271227.17 4575.72 24.73 ... ObP e BP-GDB Baker Hughes INTEQ Survey Report e .ii. 8AIC& IIUGIIIS L~TEQ Company: BP Amoco Date: 4/6/2004 Time: 10:11:18 Page: 3 Field: Endicott Co-ordinate(NE) Reference: Well: 3-17/J-30, True North Site: End SDI Vertical (TVD) Reference: 3-17E: 52.6 Well: 3-17IJ-30 Section (VS) Reference: Well (O.OON,O.OOE,60.00Azi) WeJlpath: 3-17F/K-30 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD loci Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 15339.49 83.40 92.81 10216.34 10163.74 7859.55 775.61 5978805.63 271259.18 4601.47 28.57 15378.81 85.84 80.84 10220.04 10167.44 7861.72 814.62 5978806.61 271298.24 4636.34 30.93 15436.00 85.84 80.84 10224.19 10171.59 7870.80 870.94 5978813.96 271354.80 4689.65 0.00 '. 7F/K~30) Date: 4/6/200 3-17/J-30/3 SUlVey: MWO Created By: Srii Potni AzImuths to True North Magnetíc North: 25.79' Magnetíc FIeld Strength: 5762gnT DIp Angle: 80,97" Date: 3/4/2004 Model: bggm2003 SP Amoco DETAILS H7FIK-30 500292194606 h: J-17EIK-JO D: 1369a.oO Ref. g: .: 52.6011 Co-ordInate ~E¡ Reference North VertIcal ( 0 Reference: SectIon (VS Reference: Measured Depth Reference: Calculatíon Method: TVD MD I · Obp e BP-GDB Baker Hughes INTEQ Survey Report e _íï. BAtœa 1UG1_ INTEQA ).. I Þ : C\~- Company: BP Amoco Date: 4/6/2004 Time: 10:18:29 Page: 1 Field: Endicott Co-ordinate(NE) Reference: Well: 3-17/J-30, True North Site: End SDI Vertical (fVD) Reference: 3-17E: 52.6 Well: 3-17IJ-30 Section (VS) Reference: Well (0.00N,0.00E,356.92Azi) Wellpath: 3-17FPB1/K-30 Survey Calcutation Method: Minimum Curvature Db: Oracle Field: Endicott North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 3 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2003 Site: End SDI TR-11-17 UNITED STATES: North Slope Site Position: Northing: 5969322.46 ft Latitude: 70 19 4.709 N From: Map Easting: 272231.79 ft Longitude: 147 50 47.497 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 14.50 ft Grid Convergence: -1.74 deg Well: 3-17/J-30 Slot Name: 3-17/J-30 Well Position: +N/-S 1590.34 ft Northing: 5970973.83 ft Latitude: 70 19 20.347 N +E/-W -2037.70 ft Easting : 270243.36 ft Longitude: 147 51 46.966 W Position Uncertainty: 0.00 ft Wellpath: 3-17FPB1/K-30 Drilled From: 3-17E/K-30 500292194671 Tie-on Depth: 13724.00 ft Current Datum: 3-17E: Height 52.60 ft Above System Datum: Mean Sea Level Magnetic Data: 3/1/2004 Declination: 25.80 deg Field Strength: 57629 nT Mag Dip Angle: 80.97 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 38.10 0.00 0.00 356.92 Survey Program for Definitive Wellpath Date: 3/1/2004 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 96.10 9946.10 1: Gyrodata cont.drillpipe m/ (96.10-10446.myI(DCT-DMS Gyrodata cont.drillpipe m/s 9976.00 13705.48 3-17E/K-30 (9976.00-14048.00) (1) MWD MWO - Standard 13724.00 13898.00 MWD (13724.00-13898.00) MWD MWD - Standard Annotation MD TVD ft ft 13705.48 10113.90 TIP 13724.00 10129.36 KOP 13898.00 10215.18 TO Survey: MWO Start Date: 2/28/2004 Company: BakerHugheslNTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path t Obp e BP-GDB Baker Hughes INTEQ Survey Report - BiI. -ao- HUG,,, INTE.Q Company: BP Amoco Date: 4/6/2004 Time: 10:18:29 Page: 2 Field: Endicott Co-ordinate(NE) Reference: Well: 3-17/J-30, True North Site: End SDI Vertical (TVD) Reference: 3-17E: 52.6 Well: 3-17/J-30 Section (VS) Reference: Well (0.OON,0.00E,356.92Azi) Wellpath: 3-17FPB1/K-30 Survey Catculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S EIW MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/10Oft 13705.48 33.40 344.30 10113.90 10061.30 7786.61 -403.85 5978768.84 270078.09 7797.06 0.00 13724.00 33.42 344.21 10129.36 10076.76 7796.43 -406.62 5978778.74 270075.62 7807.01 0.29 13780.98 47.07 344.85 10172.75 10120.15 7831.83 -416.39 5978814.42 270066.94 7842.89 23.97 13810.45 57.84 347.25 10190.68 10138.08 7854.48 -421.98 5978837.23 270062.05 7865.80 37.11 13842.50 67.57 353.36 10205.37 10152.77 7882.51 -426.70 5978865.39 270058.19 7894.05 34.75 13898.00 92.00 6.00 10215.18 10162.58 7936.60 -426.77 5978919.46 270059.78 7948.07 49.31 e RT. ELEV = 52.60' BF. ELEV = 15.75' 133/8" 72#/ft L-80 BTC CSG I 2498' 228 JTS 4-1/2" 12.6#/ft 13 CR L-80 VAMACE TUBING GAS LIFT MANDRELS (CAMCO) 'MMGM' 1.5" 'RK' LATCH NO MD TVD #5 3806 3620 #4 5970 5015 #3 7510 6008 #2 8882 6915 #1 9749 7521 41/2"12.6# CHROME HYDRIL 563 LINER CTD SIDETRACK INFO WEATHERFORD WHIPSTOCK WITH 3 "RA" PIPS @ 13720'MD 27/8"6.4# L-80 13 Cr STL FROM 13670 -15436 PERFORATION SUMMARY REF LOG:SWS PDC 03/22/2003 CO SIZE SPF INTERVAL SW S 2" 6 1 5307 - 15382 e END 3-17F I K-30 TREE: 4-1IZ' 5000 psi Chrome CIW WELLHEAD:13 5/8" 5000 psi FMC NS o HES 'HXO' SVLN 3.813" MIN. ID 1520 ~ 4-1/2" MMGM GAS LIFT MANDRELS 4-1/2" 'X' NIPPLE 9778 3.813" ID -5/8" x4-1/2" BAKER S-3 PACKER 9799 4-1/2" 'X' NIPPLE 3.8131D 9823 4-1/2" 'XN' NIPPLE 3.80" ID 9844 MILLED OUT 4-1/2" x 5-1/2" WLEG 9856 8.25" OD x 7.5" ID TIE BACK SLEEVE 9826 9-5/8" x 4-1/2" ZXP LINER PACKER 9837 9-5/8" x 4-1/2" LINER HANGER 9848 BAKER LINER TOP PACKER 2.390 ID 13647 31/2 x 2 7/8 X-OVER 13669 27/8 6.4# L-80 13CrSTL LINER 2.372 ID xx XX XX PBTD 15385 DATE REV. BY COMMENTS ENDICOTT WELL 3-17F/K-30 3/17/03 WRR DOYON15 Sidetrack API NO: 50-029-21946-06 3/22/03 RLW Add Perfs COMPLETION DIAGRAM 3/13/04 WRR NORDIC 2 CTD sidetrack BP EXPLORATION bp . . Terrie Hubble Technical Assistant GPB Drilling & Wells March 15, 2004 " /1 ""'" I ¡, L Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Reference: API # 50-029-21946-06-00 Permit # 203-216, 3-17F/J-30 Direct: (907) 564-4628 hubbletl@bp.com To Whom It May Concern: ~,. ,\".,~. -...~ ~~.- ~..- ~..~ .,~ ¡t.-. ·/I'~~.\" ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 The operator respectfully requests that the following well within the Duck Island Unit (Endicott Field & Pool) be re-named as follows: Current Name New Name 3-17F/J-30 3-17F/K-30 The J-30 indicates a specific bottom hole location that is incorrect for this well, The correct bottom hole location shall be indicated by the correct name of 3- 17F/K-30. Thank you very much for your assistance in this matter. Sincerely, ~~~ Terrie Hubble xc: Well Files PDC Performance Unit 'i r "\1'10 1 ù t.u . . . FRANK H. MURKOWSKI, GOVERNOR AItA.SIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FACK (907)276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: END 3-17F/J-30 BP Exploration (Alaska), Inc. Permit No: 203-216 Surface Location: 2524' SNL, 799' WEL, Sec. 08, TllN, R17E, UM Bottomhole Location: 16' NSL, 5254' WEL, Sec. 33, TI2N, RI7E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, BY ORDER O~ THE COMMISSION DATED thisJ.l day of December, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. \¡,.J GA- P.' I '5 / we!> _ STATE OF ALASKA . ALASKA O~ND GAS CONSERVATION COM SION PERMIT TO DRILL 20 MC 25.005 1a. Type of work DDrill BRedrill rb. Current Well Class D Exploratory . Development Oil D Multiple Zone D Re-Entry D Stratigraphic Test D Service D Development Gas D Single Zone 2. Operator Name: 5. Bond: IBI Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 END 3·17F/J·30 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 15390 TVD 10182 Endicott Field I Endicott Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 312828 2524' SNL, 799' WEL, SEC. 08, T11 N, R17E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 5254' NSL, 1178'WEL, SEC. 05, T11N, R17E, UM 01/21/04 // Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 16' NSL, 5254' WEL, SEC. 33, T12N, R17E, UM 2560 2143' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation KBE= 15. Distance to Nearest Well Within Pool Surface: x-270243 Y-5970974 Zone;6.SP3 (Height above GL): 52.6' feet 3-11/M-30 is 824' away at 13740' 16. Deviated Wells: 17. Anticipated pressure (see 20 AAC 25.035) /" Kickoff Depth 13715 ft Maximum Hole Angle 97 0 Max. Downhole Pressure: 4296 psig. Max. Surface Pressure: 3290 psig 1 a;Çasing Pr()Qram i··,Si·· 'Te 16settJnØ~ ................ ·.·..·...·....qtl~~ Size ...... i (è,f..or Hole Casina Weiqht Grade Couplinq Lenqth MD TVD MD TVD (includina staae data 3-3/4" 3-1/2" x 2-7/8" 9.3# x 6.16# 13Cr80 STL 1745' 13645' 10064' 15390' 10182 o cu ft Class 'G' ,/ 19. PRe:SENT WELL CØNDITION' SUMM/sRY(T9t>Ø¢ornpleted forRE!Qfill~NPR~Ôt!ýppe~tion$) ·.....···..Ii. Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft):1 Junk (measured): 14048 10403 NIA 13957 10325 N/A ii. :\....l'Otti ii >. i.QI"~. H" "'ii H "1 Ii" li..i / i !i'!!4?'i\" i.'.' t Conductor 142' 30" Driven 142' 142' Intp.rmp.rli::!tA 2498' 13-3/8" 4185 cu ft Permafrost 2498' 2495' Production 9976' 9-5/8" 575 cu ft Class 'G' 9976' 7734' I inAr 4221' 4-1/2" 1038 cu ft Class 'G' 9827' - 14048' 7633' - 10403' Perforation Depth MD (ft): 13772' - 13963' perfOration Depth TVD (ft): 10170' - 10330' 20. Attachments IBI Filing Fee IBI BOP Sketch IBI Drilling Pr()Qram o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report IBI Drilling Fluid Program IBI 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Mark Johnson ~ Title CT Drilling Engineer ~A~ O. \ ~ í'2. It /0 3 Prepared By NamelNumber: Signature r hone 564-5666 Date Sondra Stewman, 564-4750 ................ ,i i.i·.....i>...··...;,. 'i.I·~)~ 1"> ... ··i;.{. .>~¡.....";....Iijj.6.i·t····I.·.j..·.·I.;···.¡I;·I.· Permit To Drill API NL(RÖer: Permit Approval I L .....l.. l See cover letter for Number: ;203 - 2/,6 50- 029-21946-06-00 Date: ¡ '} I .:L. ts Conditions of Approval: Samples Required DYes ~No Mud Log Required · ~,,~ ~~ . + ß . - ~ogen Sulfide M~asures ~ Yes D No Directional Survey Reqff~ AYlO03 No Other: T~~ OPe ~çoo pS.c, , Pw 't<>ML 'tS,"~(}(~)) lll<\.e...-- Clte",,"{&t.f,' V4t').t,n.~ " c'fpr-ove iraska Oil & Gas Cons. Commission ¡OS Original Signed By ORIGINAL Anchorage BY ORDER OF I t./n )O~ Aooroved Bv: Sarah Palin COMMISSIONER THE COMMISSION Date ., Form 10-401 Revised 3/2003 Submit In Duplicate e e BP 3-17F/K-30 Sidetrack Summary of Operations: Endicott we1l3-17E/K-30 is scheduled for a through tubing sidetrack with the SLBlNordic 2 Coiled Tubing Drilling rig on 1/21/04. The sidetrack, 3-17F /K -30, will exit.D8t.9fthe existing 4 J;2" liner from a whipstock at 13715' md. All existing perforations in 3-17E/K-30 will be abandoned by a CIBP set at 13732' md (P&A sundry fonn already submitted). The following describes the planned sidetrack. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary (phase 1) 1) Slickline -Drift tubing. Dummy GLVs, Pressure test IA to 3000 psi. 2) CT -mill XN nipple to 3.80" ID, cleanout liner, drift for whipstock. 3) EL - Set CIBP at 13732' md (P&A of 3-17E/K-30 is complete) pressure test wellbore to 1000 psi, /' set 4 Yz" whipstock at 13715' md CTD Sidetrack Summary (phase 2) 1) MIRV CTD rig. 2) Mill window with 3.80" OD diamond speed mill. 3) Drill 3.75" openhole sidetrack to ~15390' TD with MWD~g a ray/resistivity. 4) Run 3 1/2" x 2 7/8" solid liner completion and cement wit 6 bls of 15.8 ppg class G cement. Bottom ofliner at TD, top ofliner at ~13645' md. WOC. res sure test liner and lap to 2000 psi. Run liner top packer if needed. 5) Perforate 3-17F/K-30 liner. 6) RDMO. Mud Program: · Phase 1: 8.6 ppg brine / · Phase 2: 8.6 ppg used Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 3 1/2" x 27/8" 13Cr solid cemented liner completion from 13645' to TD at 15390'. The 3 1/2" will /' run from 13645' to 13775' and the 27/8" will run from 13775' to TD at 15390'. The liner cement volume is planned to be ~16 bbls of 15.8 ppg class G. Well Control: · BOP diagram is attached. / · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 97 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · MWD directional and Gamma Ray will be run over all ofthe open hole section. · MWD Resistivity is planned. e e Hazards /c · Endicott row 3 has H2S readings over 100 ppm and is designated as an IDS pad, Maximum recorded IDS on the pad was 2000 ppm from 3-43. The last 3-17E/K-30 H2S level was 70 ppm on 9/1912003. All IDS monitoring equipment will be operational. · Two small fault crossings (20' throw) are anticipated. Lost circulation risk is considered "low", but LCM material will be on location as a contingency. Reservoir Pressure . Res. press. is estimated to be 4296 psiPt 10057'ss (8.2 ppg EMW). (0.10 psi/ft) to surface is 3290 psi. / Max. surface pressure with gas Distance to Endicott Unit boundary line . 3 -17F /K -30 is 2143' from the Endicott unit boundary line at TD of 15390' md. Distance to nearest well within pool / · 3-11/M-30 is 824'md away at 13740' in the 3-17F/K-30 directional plan. The 3-17F/K-30 wellbore will also approach wellbores 3-17/J-30 & J-30A, but this is a none issue since these wellbores are abandoned (earlier sidetracks of 3-17). Casin2lLiner Information 13 3/8", L-80, 72#, Burst 5380 psi; collapse 2670 psi 95/8",47# NT80S, Burst 6870 psi; collapse 4760 psi 4 Y2" 13Cr-80, 12.6#, Burst 8440 psi; collapse 7500 psi 3 1/2" 13Cr-80 STL, 9.3#, Burst 10180 psi; collapse 10540 psi (connection same as body rating) / 2 7/8" l3Cr-80 STL 6.16#, Burst 10570 psi; collapse 11170 psi (connection same as body rating) MOJ 12/9/03 RT. ELEV = 52.60' SF. ELEV = 15.75' E_-17E/K-30 TREE: 4-1/2" 5,000 psi Chrome CIW WELLHEAD: 135/8" 5,000 PS¡eC NS 13 3/8", 72#/ft, L-80, BTC. CSG. I 2498' ... e HES 'HXO' SVLN 3.813" MIN. ID 1.520" 228 JTS 4-1/2" 12.6#/ft, 13 CR L-80 VAM ACE TUBING EJ.,S1/P(r- CO SIZE SPF SWS 2-7/8" 6 SWS 2-7/8" 6 SWS 2-7/8" 6 SWS 2-7/8" 6 INTERVAL 13,772-13,777 13,805-13,815 13,854-13,879 13,943-13,963 4-112" MMGM GAS LIFT MANDRELS GAS LIFT MANDRELS (CAMCO) 'MMGM' 1.5" 'RK' LATCH NO. MD TVD #5 3806 3620 #4 5970 5015 #3 7510 6008 #2 8882 6915 #1 9749 7521 4-1/2" 'X' NIPPLE 3.813" ID 9,778' -5/8" x 4-112" BAKER 5-3 PACKER 9,799' 4-112" 'X' NIPPLE 3.813 10 9,823' 4-1/2" 'XN' NIPPLE 3.725" ID 9,844' sidetrack info SECTION MILL 50' WINDOW 9,976' - 10,026' 9-5/8" BRIDGE PLUG AT 10,180' 8-1/2" HOLE X 4-112" LINER 13 CR HYDRIL 563 LINER TD 14,048' MD, 10,403' TVD 4-1/2" x 5-1/2" WLEG 8.25" OD x 7.5" ID TIE BACK SLEEVE 9-5/8" x 4-112" ZXP LINER PACKER 9-5/8" x 4-1/2" LINER HANGER 9,856' 9,826' 9,837' 9,848' MARKER JOINTS 13,537' PERFORATION SUMMARY REF LOG: SLB CR/CCL 03/22/03 2-7/8" 6.4# ST-Liner 9-5/8", 47#/ft, I 10,500' I~ PBTD I 12,940' I ~ DATE 3/17/03 REV. BY Rochin COMMENTS sidetrack completion Add Perfs ENDICOTT WELL 3-17E/K-30 API NO: 50-029-21946-05 COMPLETION DIAGRAM BP EXPLORATION, INC. 3/22/03 Warner RT. ELEV = 52.60' BF. ELEV = 15.75' 13 3/8", 72#/ft, L-80, BTC. CSG. /2498' 228 JTS 4-112" 12.6#/ft, 13 CR L-80 VAM ACE TUBING GAS LIFT MANDRELS (CAMCO) 'MMGM' 1.5" 'RK' LATCH NO. MD TVD #5 3806 3620 #4 5970 5015 #3 7510 6008 #2 8882 6915 #1 9749 7521 siqE?trªçk.infC?.. ............... ª8it?mt!ºI;.ßx~i1fgm..4.!N§R....·. 13CR HYDRIL 563 LINER TD 14,048' MD, 10,403' TVD PERFORATION SUMMARY REF LOG: SLB CR/CCL 03/22/03 CO SIZE SPF INTERVAL SWS 2-7/8" 6 13,772-13,777 SWS 2-7/8" 6 13,805-13,815 SW 2-7/8" 6 13,854-13,879 SWS 2-7/8" 6 13,943-13,963 DATE 3/17/03 REV. BY END 3-17F Proposed TRE -1/2" 5,000 psi Chrome CIW WELLHEAD: 135/8" 5,000 psi FMC NS e HES 'HXO' SVLN 1,520" 3.813" MIN. ID .. 4-1/2" MMGM GAS LIFT MANDRELS 4-1/2" 'X' NIPPLE 3.813"ID 9,778' -5/8" x 4-1/2" BAKER S-3 PACKER 9,799' 4-1/2" 'X' NIPPLE 3.813 ID 9,823' 4-1/2" 'XN' NIPPLE 3.725" ID 9,844' 4-1/2" x 5-1/2" WLEG 8.25" OD x 7.5" ID TIE BACK SLEEVE 9-5/8" x 4-1/2" ZXP LINER PACKER 9-5/8" x 4-1/2" LINER HANGER 9,856' 9,826' 9,837' 9,848' Potential adperfs in K2B with / ~ straddle shutoff capability (post CTD) Proposed 3-17F/K-30 CTD Sidetrack Cll~ t" 01 'L.T Rochin COMMENTS sidetrack completion 3/22/03 12/9/03 Add Perfs Proposed CTD sidegtrack Warner MOJ ENDICOTT WELL 3-17E/K-30 API NO: 50-029-21946-05 COMPLETION DIAGRAM BP EXPLORATION, INC. BP Amoco 0...-·· :, "':'. '.)$." ~:""":;:' ~. ~..... WI!U.JIATM Dl!TM.S .......1 S.17PM-J1 -.- ..... ~ )..i7eM-M T.... -= 13TM.A1 w. ..::: Y.- - ...... ...... D..... ".'If.; '= ==~ H.1' 8800 ...1 .... REFERENCE INFORMATION CcHxdInøt8 (NIE\Ref'etence: WeD Cenue: 3-11/J·30. True Nor1h Ver1iœl (TVD Reference: System: Mean Sea Level Section (VS Role""""" Slot· (O.OON,O.OOE) M_ DepIh RefenInœ' 3·17E, ~2.60 C81wt8tJon Me1hOd: Mirimum Oxvature ... ... ... .... M4.ao ...,.... aaA. aM.aI ._014 .... M4.Ø ......,. ..... aIM .,".u.n ..... ..... ..,..'.n ....,. ,.... 10'1..... tLU "0031 ...4".11 ..... ..... 101U'" ... .... 1...... 71.... ,.. ,......, 7'"'' ..... ,....... 71 If." ...... ,......, ..... ,"04' ,l1a.oo .u ..... .ø.Af .11Q.DD .u .... ,,"'1' .l1o.aa ... ,PM.ll\JlllltAflihll '01a.a , TYD MI MMtIrIIeft '.'.31 'I""'" TIP ,IIO.M ,.7'.... KOP ,.....,. 111'.... J 111147.'111317.....,. .. ,"41'.72 'J"'.1I . 1111&. 1:1147,". . """"" 1Ø11.ft t 11U7.24 ta1LfI . 1111S1.111.aLfI . tl1H.4f 14317.71 "' ...131.21 1431".71 n 111142.11 14111.7' 1. ....43.11,........ UI " ,l1o.M 1HU.1t "' "' 111aM tHU.II i' n ,II1U.o 1.H.,..... . .'tea.-. 9600"] . 9650-) .. :i··· 9700··:¡·.... :~ ' 975O··:¡ . :.1 9800 ·r 9850':J" ...... 9900 :.1 .... I: ~ In .... .c: .. Do & 8700 8800 1a:r1CNl K1',..u 8500:: ...... ,.,...., ,,,.... ,...a. 191"" ......, ...,... ......' llØ1.." ,,"... 011.11 -.., .,..., -... "04.'" IUI.n ...... .... Tf'_ ........ÆO 0.00 H4a.se ......, tMA1 U44.U ...oa.aa ... o.ao 3841.113 ...QO.14 ..... 1o.H ;1881.31 -4atod .... ..... HMAG ........ ,..80 ...... ..... ....,.. ....0 a.II H."" 44&1. 1LG1 1'" a1.u.a1 ""11 1... ...DIII 3....0. .1H.1. ".01 .... ....... ..... 12.00 1..... 4ua., D 1".u ,..1tI ..... 4....12 1...1' 1..01 ....., ....,.1. .,..... 1.... ft.OO .uU.01 ...... 1L11 .n.oo 44ft.B 1..~lØIM.11 'M) >MI-S "f.~ SI\8III 101J! IS -~~ ær 101:14,01) 62'\72'\ -20'102 J'I)M 10143,CO II02OUo 41131& f'Ot'II 10143.CO S22'UM 17900 Po", '01I2CO 1114111& 19980 PoìII LEIJE/ID ~~" '.:.,. ~(: ~ .l.: ~~..~~..~.-.: ~:: . ." #",', ,. ~,:~'; -. .................................... .;..... ,-' ;:."'1 PIant123·17FIK.:JO PIlnt12 INTf..;Q ., .:."'" . .. ' . . .. . . · . . . · .... . .. - .,' · . . ...-- .,..-.................,...'......... · . - . " ' . , " . · . . ..-...-.-..-...............................--..... ··e··· .. . .. · '. ". - . . . . . . . . . . . . . . . . . . . - . . . . . - . - . . . .. '..... · .. .. ' .' · . - . .. ...'..... ... :... ......,. .:... .. ....'........ ....... .. ... ............ ',. ... ......"......... · . '.' " .' · . . · . . · -. ..' . , . ' . -. . ····.··t ...·.·..X · " . ......... .................... · " . . . '" .,' - . · . .. .. ........-- ..... ..--....... . . · . -, . .....'...................,............. .'...E;....' · . , . . ...'"... ..."........ , . . . . · . .. , . ··1'. .....1·......·....1.·.·.[ .. ::¡ -.,.. . . :. ...... AzImuths to True North Magnetic North: 25.94' Magnetic Field Strength: 57620n T Dip Ängle: eo.97' Oate: 11/18/2003 Model: bggm2003 Cm8led By, Brij Pot"", Plan: Plan #12 (3-17/J-30/Plan#12 3-17FM:.30) Date: 11121/2003 Contacllnformation: ~-=¡~!> ~:6~~qcom Baker Hughes INTEQ, (:;(!:!)267!600 ., ::.:.'j'.':' .......,..... ;.¡ 8400'·:· . 'i:;! ¡¡ 8300' ..... ..' . ~ ' " 082oo~: ; .. . 13-17FIK-30Potyoon1221 .... : :' "",. _8100', . :.'" + . .' - I:.: - - ¡-7800 .. ! 7700 ., 7600· ).1J'f4<-JDFIUII1 ¡~~~1.12 ).11F1K-3O,"11 ).17FJ"-JD"'4 ).'7FII(-3D"2..1 ).'1fII'.JD1U3 '. ... .. 7500 .. 7400'::; 7300· .,'. 7200 . 7 ., ·,/eLl ' -~~ ...............:\'ttt¡. ';-\' .....,.. ..'....... .............................. : ' I 3-17/J..30 (3-1TÈ1K-3oj ....¡..'.:..- .,.... .... ...... . - . . . . . . \. - . ~ . . . .' u~._: ~...:u.~....~n.:.. .....-- .. ....;.,... :1 "-c" ,.... .. .. ............. " : .. .. . :-¡- .h." . ' . " .............................. . -, . .\-.~~,-+~..., ;..~.+.....~..;...~..~..~._.~...,..~.+.~..; , . .-·~··¡···,··;_·~_·;·.....~..i···(";..~·~~··~·+¡···(-: . . -11'00 -1(joo -900 -800 -700 -800 ..sOO -400 -300 .....-...j..:. :: I . ,- " . : .:. .r.~·,~ 3·17/J-30 ó-; l/J-~OA)' '·lU. ·····.·t--j3.~7IJ-30(3.;;;;1)1 ...,.. ........ .......'. ..... :. , . ·:·:··:·..1·....: . ',j ·i·..· ..1 :-:-:--:',:,j': ',: : ~: -: - ; ¡ -:.......;-.,.. ... qui. . ~ .:- :. .....'. :.:::\:)..\ .'.. :-..,.,.........,.....-.. : . " "f ,-," ,..¡.,..'...:...., '··'·:··F; '+(").:" .....,...,.,... -200 -100 Ó 160 200 300 400 sOO 600 700 8ÒO West(-)/East(+) [100ft/In] · , "·~···~·-"-i··~· ., , , 900 1000 1100 1200 1300 1400 1500 e ~ .. '. ., ,..............-.... '(i"¡-"(':":'-:":";'-¡"-' e 9950--.:.t,i.··· .,., . ': ,! \ j 1(){)()Q-':1 u\uuu,u\. . .·u\:'''uu' 1:: +. ..J!fJ " : . .u,'u\u: ~ 10050"~¡ .,...u. ... ....pj!@] ._ .. ..... , ...-...: ......¡.... ... . . ...:_+,..,...:\~..:.u, i ::1.~~~""~-;"~:~:,J '~,jiI~;,i~,,:f4...~~,,: ( . 10250.::1"..... ..: \~.. . ......... . ................ ~\:. ................'.....'........ . : . :: ; :::: : t;' .:':,.. . . \ . ,':' . . . .. \ . , ... ..... uuuI3~17/J-3ô¡3-17IJ~(Io\IH:':"'j . ¡:i.I71J~(3.17/J:"")1 103OOu::113117IJ~(3·,~~j<X . . . ...; ,.: ...,.':.. '. J~.....~.: ;i.:.;.....-;-. .;.i.f....;-:...~.~.f.H.:.;...~.i...~.; i-;";';~-;-, -,-..-t....!-~·..r:~~·..:-f·; ....·;-:·1·:-, -;':";-"1'~',--. ;';"í-;T;-;T' ':-~:-~-~'''1T~- ;-~·;·:-·t~·i-t~"i·, i':'; ,~-;"..1·~+;~-:···i;-~~-~·:·; ~-:.:. i ;: i ' it: ··..1 ' f-'" ; .~': " ;i"'"r-:"i';'; ,,;-;";1'; :- "¡';', -;':', ;i':-"~';': '1':-;"' :';';';';-. .. 3300 3350 3400 3450 3sOO 3550 36'00 3650 3700 3750 3800 3850 3900 3950 4000 4050 4100 4150 4200 4250 4300 4350 4400 4450 4500 4550 4600 4650 4700 4750 4800 4850 4000 4950 5000 5050 5100 5150 5200 Vertical Section at 60.00· [50ft/In] ',- i ,.;-.-~- ·.-·~··:·~.-··;··~··í . .. O"·i.."'."¡;'O"> ""'}: tJ~., I .:..:.:.... BP-GDB Ba.e Hughes INTEQ Planning Re. 1IIf.~.. BAua NUCJaS IN'rEQ Company: Field: Site: Well: Wellpath: BP Amoco Endicott End SDI 3-17/J-30 Plàn#123-17F/K-30 Date: 11/21/2003 Time: 15:07:41 Page: 1 Co-ordinate(NE) Reference: Well: 3-17/J-30. True North Vertical (TVD) Reference: System: Mean Sea Level Sedion (VS) Reference: Well (0.00N,0,ooE,60.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Endicott North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datnm: NAD27 (Clarke 1866) Sys Datum: Mean Sea level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 3 Well Centre bggm2003 Site: End SDI TR-11-17 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 14.50 ft 5969322.46 ft 272231.79 ft Latitude: 70 19 Longitude: 147 50 North Reference: Grid Convergence: 4.709 N 47.497 W True -1.74 deg Well: 3-17IJ-30 Slot Name: 3-17IJ-30 Well Position: +N/-S 1590.34 ft Northing: 5970973.83 ft Latitude: +EI-W-2037.70 ft Easting: 270243.36 ft Longitude: Position Uncertainty: 0,00 ft 70 19 20.347 N 147 51 46.966 W +N/-S ft 0.00 Drüled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +EI-W ft 0.00 3-17EIK-30 13705.48 ft Mean Sea level 25.94 deg 80.97 deg Direction deg 60.00 Wellpath: Plan#123-17FIK-30 500292194606 Current Datnm: 3-17E: Magnetic Data: 11/18/2003 Field Strength: 57620 nT Vertical Section: Depth From (TVD) ft 38.10 Height 52.60 ft Targets 3-17F/K-30 Fault 1 0.00 8233.71 -1687.28 5979255.01 268809.00 70 2041.323 N 147 52 36.264 W -Polygon 1 0.00 8233.71 -1687.28 5979255.01 268809.00 70 2041.323 N 147 5236.264 W -Polygon 2 0.00 8227.60 -1200.85 5979234.01 269295.00 70 2041.264 N 147 5222.052 W -Polygon 3 0.00 8090.51 -744.42 5979083,01 269747.00 70 20 39.916 N 147 52 8.716 W -Polygon 4 0.00 8083.36 198.28 5979047.01 270689.00 70 20 39.846 N 147 51 41.174 W -Polygon 5 0.00 8161.22 519.06 5979115.01 271012.00 70 20 40.612 N 147 51 31.802 W -Polygon 6 0.00 8082.08 1103.78 5979018.01 271594.00 70 20 39,833 N 147 51 140719 W -Polygon 7 0.00 8093.52 1803.79 5979008.01 272294.00 70 20 39.944 N 147 50 54.267 W -Polygon 8 0.00 8082.08 1103.78 5979018.01 271594.00 70 20 39.833 N 147 51 14.719 W -Polygon 9 0.00 8161.22 519.06 5979115.01 271012.00 70 20 40.612 N 147 51 31.802 W -Polygon 10 0.00 8083.36 198.28 5979047.01 270689.00 70 20 39.846 N 147 51 41.174 W -Polygon 11 0.00 8090.51 -744.42 5979083.01 269747.00 70 20 39.916 N 147 52 8.716 W -Polygon 12 0.00 8227.60 -1200,85 5979234.01 269295.00 70 2041.264 N 147 5222.052 W 3-17F/K-30 Polygon12.2 0.00 8086.48 -451.15 5979070.01 270040.00 70 20 39.877 N 147 52 0.148 W -Polygon 1 0.00 8086.48 -451.15 5979070.01 270040.00 70 20 39.877 N 147 52 0.148 W -Polygon 2 0.00 8176.44 -453.90 5979160.01 270040.00 70 2040.762 N 147 52 0.228 W -Polygon 3 0.00 8273.98 -274,80 5979252.01 270222.00 70 2041.721 N 147 51 54.996 W -Polygon 4 0.00 8307.64 236.43 5979270.01 270734,00 70 20 42,052 N 147 51 40,059 W -Polygon 5 0.00 8194.40 459,01 5979150.01 270953.00 70 20 40.938 N 147 51 33.556 W -Polygon 6 0.00 7870.39 954.18 5978811.01 271438.00 70 20 37.751 N 147 51 19.090 W -Polygon 7 0.00 7722.11 816.65 5978667.01 271296.00 70 20 36.293 N 147 51 23.108 W -Polygon 8 0.00 8164.52 136.76 5979130.01 270630.00 70 20 40.644 N 147 51 42.971 W -Polygon 9 0.00 8177.77 -83.75 5979150.01 270410.00 70 20 40.775 N 147 51 49.414 W -Polygon 10 0.00 8089.75 -181.11 5979065.01 270310.00 70 20 39.909 N 147 51 52.258 W 3-17F/K-30 T12.1 10128.00 8230.35 -98.37 5979203.01 270397.00 70 2041.292 N 147 51 49.841 W 3-17F/K-30 T11.1 10134.00 8217.21 -201.02 5979193.01 270294.00 70 2041.163 N 147 51 52.840 W 3-17F/K-30 T11.4 10143.00 8020.45 496.36 5978975.01 270985.00 70 20 39.227 N 147 51 32.465 W bp BP-GDB Bae Hughes INTEQ Planning Re. 1IIf~.. BAK.. NUCMliS INTEQ Company: Field: Site: Well: Wellpath: Targets BP Amoco Endicott End SDI 3-17/J-3O Plan#123-17F/K-30 Date: 11121/2003 Time: 15:07:41 Page: 2 Co-ordinate(NE) Reference: Wefl: 3-17/J-30, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Wefl (0.00N,0.OOE.60.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Name Des4:riptiOR Dip. Dir. 3-17FIK-30 T12,2 TVD It 10143.00 +N/-S ft 8221.84 +EI-W ft 179.03 Map Northing ft 5979186.01 Map Easting ft 270674.00 <-- Latitude --> <- Longitude -> Deg Miø See Deg MiD See 70 2041.208 N 147 51 41.736 W 3-17F/K-30 T12.3 10182.00 7847.66 799.80 5978793.01 271283.00 70 20 37.528 N 147 51 23.600 W Annotation 13705,48 10061.30 TIP 13715.00 10069.24 KOP 13735.00 10085.76 3 13874.75 10147.72 4 13917.75 10147.72 5 13947.75 10145.95 6 13992.75 10141.09 7 14072.75 10137.24 8 14222.75 10135.25 9 14327.75 10130.47 10 14397.75 10130.20 11 14617.75 10142.13 12 14652.22 10143.00 13 14852.22 10143.00 14 15002.22 10143.00 15 15092.22 10148.44 16 15390.00 10182.02 TD Plan: Plan #12 New KOP and profile Principal: Yes Date Composed: Version: Tied-to: 11/18/2003 4 From: Definitive Path Plan Section Information 13705.48 33.40 344.30 10061.30 7786.61 -403.85 0.00 0.00 0.00 0.00 13715.00 33.41 344.26 10069.24 7791.66 -405.27 0.25 0.11 -0.42 294 .41 13735.00 35.21 344.26 10085.76 7802.51 -408.33 9.00 9.00 0.00 0.00 13874.75 90.00 352.46 10147.72 7919.77 -430.14 39,50 39.21 5.87 10.00 13917.75 90.00 9.44 10147.72 7962.61 -429.43 39.50 0.00 39.50 90.00 13947.75 96.76 19.20 10145.95 7991.58 -422.05 39.50 22.55 32.51 55.00 13992.75 95.53 37.03 10141,09 8030.87 -401.05 39.50 -2.75 39.63 93.00 14072.75 89.98 44.88 10137.24 8091.14 -348.72 12.00 -6.93 9.81 125.00 14222.75 91.53 62.82 10135.25 8179.25 -228.11 12.00 1.03 11.96 85.00 14327.75 93.66 75.25 10130.47 8216.72 -130.36 12.00 2.03 11.84 80.00 14397.75 86.78 80.06 10130.20 8231.67 -62.04 12.00 -9.84 6.88 145.00 14617.75 87.11 106.50 10142.13 8219.20 155.33 12.00 0.15 12.02 90.00 14652.22 90.00 109.47 10143.00 8208.56 188.10 12.01 8.37 8.62 45.87 14852.22 90.00 133.47 10143,00 8104.91 357.44 12.00 0.00 12,00 90.00 15002.22 90.00 115.47 10143.00 8020.36 480.60 12.00 0.00 -12.00 -90.00 15092.22 83.08 107.16 10148.44 7987.74 564.16 12.00 -7.69 -9.24 -130.00 15390.00 84.39 143.09 10182.02 7820.20 802.14 12.00 0.44 12.07 90.00 ObP BP-GDB Ba..eHughes INTEQ Planning Re. III~.. BAua NUCMIIS .................. INTEQ Company: BP Amoco Date: 11/2112003 Time:> 15;07:41 Page: 3 Field: Endicott Co-ordinate(NE)..RefereQœ: Welt:3-17IJ-30, TroeNorth Site: End SDI Vertieat.(TVD).Referenee: System: Mean Sea Level Well: 3-17/J-30 Section (VS)Referenee: Well·(O.00N,O.OOE,60..00Azi) Wellpath: Plan#123-17FIK-30 Survey CalenlatìonMethod: Minimum Curvature Db: Oracle Survey MD Inel Azim SysTVD N/S E/W .. . MapN MßE VS DLS no Tool ft deg deg ft ft ft ft deg/l00ft deg e 33.40 344 .30 10061.30 7786.61 -403.85 5978768.84 270078.09 3543.56 0.00 0.00 TIP 13715:00 33.41 344.26 1(1069.24 7791.66 -405.27 5978773.93 270076.82 3544.85 0.25 294.41 KOP 34.31 344.26 10077.55 7797.02 -406.78 5978779.34 270075.48 3546.23 9.00 0.00 MWD 13735.00 35.21 344.26 10085.76 7802.51 -408.33 5978784.87 270074.10 3547.63 9.00 360.00 3 13750.00 41.06 345.82 10097.56 7811.45 -410,71 5978793.88 270071.99 3550.04 39.50 10.00 MWD 13775.00 50.83 347.76 10114.92 7828.93 -414.79 5978811.47 270068.45 3555.25 39.50 8.77 MWD 13798.03 59.86 349.11 10128.00 7847.47 -418.57 5978830.12 270065.24 3561.24 39.50 7.42 3-17FIK- 13800.00 60.64 349.21 10128.98 7849.15 -418.89 5978831.81 270064.97 3561.80 39.50 6.65 MWD 13810.98 64.95 349,76 10134.00 7858.75 -420.67 5978841 .46 270063.48 3565.06 39.50 6.60 3-17F/K- 13825.00 70.45 350.41 10139.32 7871.52 -422.90 5978854.29 270061.64 3569.52 39.50 6.35 MWD 13837.54 75.38 350.95 10143.00 7883.35 -424.84 5978866.17 270060.07 3573.75 39.50 6.10 3-17FIK- 13850.00 80.27 351.47 10145.63 7895.38 -426.70 5978878.26 270058,58 3578.15 39.50 5.94 MWD 13874.75 90.00 352.46 10147.72 7919.77 -430.14 5978902.74 270055.88 3587.37 39.50 5.83 4 13875.00 90.00 352.46 10147.72 7920.02 -430.18 5978902.99 270055.86 3587.46 0.35 5.75 MWD 13900.00 90,00 2.43 10147.72 7944.96 -431.27 5978927.95 270055.53 3598.99 39.89 90.00 MWD 13917.75 90.00 9.44 10147.72 7962.61 -429.43 5978945.53 270057.91 3609.40 39.50 90.00 5 13925.00 91,64 11.79 10147.62 7969.73 -428.10 5978952.61 270059.46 3614.12 39.50 55.00 MWD 13947.75 19.20 10145.95 7991.58 -422.05 5978974.26 270066.17 3630.28 39.50 55.03 6 13950.00 ~ 20.09 10145.69 7993.68 -421.30 5978976.34 270066.99 3631.98 39.50 93.00 MWD 13975.00 .9 30.01 10142.89 8016.16 -410.79 5978998.48 270078.18 3652.32 39.50 93.10 MWD 13992.75 95.53 37.03 10141.09 8030.87 -401.05 5979012.89 270088.37 3668.12 39.50 94.21 7 14000.00 95.03 37.75 10140.43 8036.61 -396.66 5979018.49 270092.92 3674.78 12.00 125.00 MWD 14025.00 93.30 40.21 10138.61 8055,99 -380.98 5979037.38 270109.19 3698.05 12.00 125.07 MWD 14050.00 91.57 42.66 10137.55 8074.71 -364.46 5979055.59 270126.28 3721.73 12.00 125.24 MWD 14072.75 89,98 44.88 10137.24 8091.14 -348.72 5979071.53 270142.51 3743.57 12.00 125.35 8 14075.00 90.01 45.15 10137.24 8092.73 -347.13 5979073.07 270144.15 3745.74 12.00 85.00 MWD 14100.00 90.27 48.14 10137.18 8109.89 -328.95 5979089.66 270162.84 3770.06 12.00 85.00 MWD 14125.00 90.53 51.13 10137.01 8126.08 -309.91 5979105.26 270182,37 3794.65 12.00 85.01 MWD 14150.00 90.79 54.12 10136.72 8141.25 -290.05 5979119.82 270202.69 3819.44 12.00 85.03 MWD 14175.00 91.05 57.11 10136.32 8155.37 -269.42 5979133.30 270223.74 3844.36 12.00 85.06 MWD 14200.00 91.30 60.10 10135.81 8168.39 -248.09 5979145.66 270245.46 3869.34 12.00 85.11 MWD 14222.75 91.53 62.82 10135.25 8179.25 -228.11 5979155.91 270265.76 3892.08 12.00 85.17 9 14225.00 91.58 63.08 10135.19 8180.28 -226.11 5979156.87 270267.79 3894.32 12.00 80,00 MWD 14250.00 92.09 66.04 10134.38 8191.01 -203.54 5979166.90 270290.67 3919.23 12.00 80.01 MWD 14275.00 92.61 69.00 10133.36 8200.56 -180.47 5979175.74 270314.03 3943.99 12.00 80,10 MWD 14300.00 93.11 71.96 10132.11 8208.90 -156.94 5979183.36 270337.80 3968.54 12.00 80.22 MWD 14325.00 93.61 74.92 10130.65 8216.01 -133.02 5979189.73 270361.93 3992.81 12.00 80.37 MWD 14327.75 93.66 75.25 10130.47 8216.72 -130.36 5979190.36 270364.60 3995.46 12.00 80.54 10 14350.00 91.48 76.78 10129.47 8222.09 -108.80 5979195.07 270386.32 4016.82 12.00 145.00 MWD 14375.00 89.02 78.50 10129.37 8227.44 -84.38 5979199.67 270410.89 4040.64 12.00 145.07 MWD 14397.75 86.78 80.06 10130.20 8231.67 -62.04 5979203.21 270433.35 4062.10 12.00 145,08 11 14400.00 86.78 80.33 10130.33 8232.05 -59.83 5979203.52 270435.57 4064.21 12.00 90.00 MWD 14425.00 86.78 83.34 10131.73 8235,59 -35.13 5979206.31 270460.37 4087.38 12.00 89.98 MWD 14450.00 86.80 86.34 10133.13 8237.84 -10.27 5979207.79 270485.28 4110.03 12.00 89.82 MWD 14475.00 86.82 89.35 10134.52 8238.78 14,67 5979207.97 270510.24 4132.09 12.00 89.65 MWD 14500.00 86.85 92.35 10135.90 8238.41 39.63 5979206.83 270535.17 4153.52 12.00 89.48 MWD 14525.00 86.89 95.36 10137.27 8236.73 64.53 5979204.39 270560.01 4174.25 12.00 89.31 MWD 14550.00 86.94 98.36 10138.61 8233.75 89.31 5979200.65 270584.69 4194.22 12.00 89.15 MWD 14575.00 87.00 101.36 10139,94 8229.47 113.91 5979195.63 270609.14 4213.38 12.00 88.99 MWD 14600.00 87.06 104.37 10141.23 8223.91 138.24 5979189.33 270633.29 4231.68 12.00 88.83 MWD 14617.75 87.11 106.50 10142.13 8219.20 155.33 5979184.09 270650.23 4244.12 12.00 88.67 12 14625.00 87.72 107.13 10142.46 8217.10 162.26 5979181.78 270657.09 4249.08 12.01 45.87 MWD 14650.00 89.81 109.28 10143.00 8209.29 186.00 5979173.25 270680.58 4265.73 12.01 45.84 MWD O:::·:·::::·t.,,,> '::.,:.: dr., . ··~W··· ~ BP-GDB Ba_ Hughes INTEQ Planning Re. nii.. BAld.. NlJ:CME$ INl'EQ Company: BP Amoco Date: 11/21/2003 Time: 15:07:41 Page: 4 Field: Endicott Co-itrdinate(NE) Referenu: Well: 3-17/J-30, True North Site: El1dSDI VerticaI(TVÐ) Reterence: System: Mean,SeaLevel Well: 3-17/J-30 Section (VS) ReferenCe: Well (0.00N,O.OOE,60.00Azi) Wellpath: Plan#123-17F/K-30 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel ADm Sys TVD N/S EIW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100fl deg 14652.22 90.00 109.47 10143.00 8208.56 188.10 5979172.45 270682.66 4267.18 12.01 45.79 13 14675.00 90.00 112.20 10143.00 8200.46 209.39 5979163.70 270703.68 4281.56 12.00 90.00 MWD 14700.00 90.00 115.20 10143.00 8190.41 232.28 5979152.96 270726.25 4296.36 12.00 90.00 MWD 14725.00 90.00 118.20 10143.00 8179.17 254.61 5979141.05 270748.23 4310.08 12.00 90.00 MWD 14750.00 90.00 121.20 10143.00 8166.79 276.32 5979128.00 270769.55 4322.69 12.00 90.00 MWD 14775.00 90.00 124.20 10143.00 8153.28 297.35 5979113.86 270790.16 4334.16 12.00 90.00 MWD 14800.00 90.00 127.20 10143.00 8138.69 317.65 5979098.66 270810.00 4344.44 12.00 90.00 MWD 14825.00 90.00 130.20 10143.00 8123.06 337.16 5979082.44 270829.02 4353,52 12.00 90.00 MWD 14850.00 90.00 133.20 10143.00 8106.43 355.82 5979065.25 270847.17 4361,37 12.00 90.00 MWD 14852.22 90.00 133.47 10143.00 8104.91 357.44 5979063,67 270848.74 4362.01 12.00 90.00 14 14875.00 90.00 130.74 10143.00 8089,64 374.34 5979047.89 270865.16 4369.01 12.00 270.00 MWD 14900.00 90.00 127.74 10143.00 8073.83 393.70 5979031.50 270884.02 4377.87 12.00 270.00 MWD 14925.00 90.00 124.74 10143.00 8059.05 413.86 5979016.11 270903.72 4387.94 12.00 270.00 MWD 14950.00 90.00 121.74 10143.00 8045.35 434.77 5979001.78 270924.20 4399.20 12.00 270.00 MWD 14975.00 90.00 118.74 10143.00 8032.76 456.37 5978988.53 270945.40 4411.61 12.00 270.00 MWD 15000.00 90.00 115.74 10143,00 8021.32 478.59 5978976.42 270967.27 4425.13 12.00 270.00 MWD 15002.22 90.00 115.47 10143.00 8020.36 480.60 5978975.40 270969.24 4426.39 12.00 270.00 15 15025.00 88.24 113.38 10143.35 8010.95 501.33 5978965.35 270989.68 4439.64 12.00 230.00 MWD 15050.00 86.32 111.07 10144.54 8001.50 524.44 5978955.21 271012.49 4454.93 12.00 230.03 MWD 15075.00 84.40 108.76 10146.56 7993.01 547.87 5978946.01 271035.64 4470.98 12.00 230.14 MWD 15092.22 83.08 107.16 10148.44 7987.74 564.16 5978940.23 271051.76 4482.44 12.00 230.33 16 15100.00 83,08 108.10 10149.37 7985.40 571.51 5978937.67 271059.04 4487.64 12.00 90.00 MWD 15125.00 83.10 111.12 10152.38 7977.07 594.89 5978928.63 271082.15 4503.72 12.00 89,89 MWD 15150.00 83.13 114.14 10155.38 7967.52 617.79 5978918.39 271104.75 4518.79 12.00 89.52 MWD 15175.00 83.19 117.16 10158.36 7956.78 640.17 5978906.96 271126,78 4532.79 12.00 89.16 MWD 15200.00 83.26 120.18 10161.31 7944.87 661.95 5978894.39 271148.19 4545.70 12.00 88.80 MWD 15225.00 83.35 123.20 10164.22 7931.83 683.07 5978880.71 271168.90 4557.47 12.00 88.44 MWD 15250.00 83.46 126.22 10167.10 7917,69 703.48 5978865.95 271188.87 4568.08 12.00 88.09 MWD 15275.00 83.59 129.23 10169.92 7902.49 723.13 5978850.16 271208.04 4577.49 12.00 87.75 MWD 15300.00 83.73 132.25 10172.68 7886.28 741.95 5978833.38 271226.36 4585.69 12.00 87.41 MWD 15325.00 83.89 135.26 10175.38 7869.09 759.90 5978815.65 271243.77 4592.64 12.00 87.07 MWD 15350.00 84.07 138.27 10178.00 7850.98 776.93 5978797.03 271260.24 4598.33 12.00 86.75 MWD 15375.00 84.26 141.28 10180.54 7831.99 792.99 5978777.56 271275.71 4602.74 12.00 86.43 MWD 15390.00 84.39 143.09 10182.02 7820.20 802,14 5978765.49 271284.49 4604.77 12.00 86.13 TO G·········~ :¡dO:: t~p . ':'W e BP-GDB Anticollision Report B e INTEQ Company: Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Endicott EndSDI 3-17/J-3O Plan#12 3-17F/K-30 Date: 11/19/2003 Time: 09:44:58 ..age: 1 Co-ordinate(NE) Reference: Verticat (TVD) Reference: Well: 3-17/J-30, True North 3-17E: 52.6 Db: Oracle GLOBAL SCAN A....LIED: All wellpaths within 200'+ 10011000 of reference - There ar~ftells in thBlRmFlan #12 & NOT PLANNED PROG M Interpolation Method: MD + Stations Interval: 10.00 ft Error Model: ISCWSA Ellipse Depth Range: 13705.48 to 15390.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1735,19 ft Error Suñace: Ellipse + Casing Casing "oints MD ft 3993.00 9976.00 13715.00 15390.00 TVI> ft 3864.19 7733.25 10121.84 10234.62 Diameter in Name 10.750 9.625 4.500 2.875 12.250 12.250 6.000 3.750 10 3/4" 9 5/8" 4 112" 27/8" "'an: Plan #12 New KOP and profile ..rincipal: Yes Date Composed: Version: Tied-to: 11/18/2003 3 From: Definitive Path Summary End SDI 3-07 AIL-29 3-07A1L-29 V5 Out of range End SDI 3-09/L-28 3-09/L-28 V1 13890.00 14370.00 1490.51 351.49 1139.02 Pass: Major Risk End SDI 3-09/L-28A 3-09/L-28A V2 Out of range End SDI 3-11/M-30 3-11/M-30 V1 13740.00 13550.00 262.10 562.57 Pass: Major Risk End SDI 3-17/J-30 3-17/J-30 V18 15333.07 13670.00 0.00 198.16 Pass: NOERRORS End SDI 3-17/J-30 3-17/J-30A V6 15163.04 13730.00 0.00 193.57 Pass: NOERRORS End SDI 3-17/J-30 3-17E1K-30 V3 13710,00 13710.00 0.00 0.00 FAil: NOERRORS End SDI 3-29/J-32 ~-29A1K30 VQ§)4890.50 14180.00 300.23 116.87 Pass: Major Risk End SDI 3-31/K-32 -31/K-32 V6 Out of range End SDI 4-10/M-28 4-10/M-28 V1 13920.00 13640.00 1265.67 340.78 924.89 Pass: Major Risk End SDI 4-10/M-28 4-10AIL-28 V16 13707.10 13380.00 1284.74 333.48 951.25 Pass: Major Risk Site: End SDI Well: 3-09/L-28 Rule Assigned: Major Risk Wellpath: 3-09/L-28 V1 Inter-Site Error: 0.00 ft 13880.00 10200.32 14200.00 9829.80 51.17 56.05 278.93 284.40 9.625 1503.17 345.10 1158.07 Pass 13880.00 10200.32 14210.00 9834.02 51.17 56.14 278.78 284 .25 9.625 1501.58 345.58 1156.00 Pass 13880.00 10200.32 14220.00 9838.23 51.17 56.24 278.63 284.10 9.625 1500.10 346.05 1154.04 Pass 13880.00 10200.32 14230.00 9842.42 51.17 56.33 278.48 283.95 9,625 1498.72 346.52 1152,21 Pass 13880.00 10200,32 14240,00 9846.60 51.17 56.42 278.33 283.80 9.625 1497.49 346.98 1150.51 Pass 13880.00 10200.32 14250.00 9850.75 51.17 56,52 278.18 283.65 9.625 1496.40 347.45 1148.95 Pass 13884,67 10200.32 14260.00 9854.87 51.03 56.45 279.86 283.49 9.625 1495.38 347.21 1148.17 Pass 13890.00 10200.32 14270.00 9858.98 50.88 56.28 281.82 283.34 9.625 1494.59 346.64 1147.95 Pass 13890.00 10200.32 14280.00 9863.08 50.88 56.38 281.67 283.19 9.625 1493.79 347.12 1146.67 Pass 13890.00 10200.32 14290.00 9867.15 50.88 56.48 281.51 283.03 9.625 1493.07 347.61 1145.46 Pass 13890.00 10200.32 14300.00 9871.16 50.88 56.59 281.36 282.88 9.625 1492.43 348.10 1144.34 Pass 13890.00 10200.32 14310,00 9875.11 50.88 56.70 281.21 282.73 9.625 1491.89 348.59 1143.30 Pass 13890.00 10200,32 14320.00 9879.01 50.88 56.80 281.06 282.58 9.625 1491.43 349,08 1142.35 Pass 13890.00 10200.32 14330.00 9882,84 50.88 56.91 280.91 282.43 9.625 1491.07 349.57 1141.50 Pass 13890.00 10200.32 14340.00 9886.61 50.88 57.02 280.76 282.28 9.625 1490.80 350.06 1140.74 Pass 13890.00 10200.32 14350.00 9890.34 50.88 57.13 280.62 282,14 9.625 1490.60 350.54 1140.07 Pass 13890.00 10200.32 14360.00 9894.05 50.88 57.24 280.48 281.99 9.625 1490.50 351.01 1139.49 Pass 13890.00 10200.32 14370,00 9897.68 50.88 57.35 280.33 281.85 9.625 1490.51 351.49 1139.02 Pass 13894.68 10200.32 14380.00 9901.25 50.65 57.17 282.04 281.71 9.625 1490.53 350.58 1139.96 Pass 13900,00 10200.32 14390.00 9905.04 50.39 56.88 284,00 281.57 9.625 1490.54 349.24 1141.30 Pass 13900.00 10200.32 14400.00 9908.89 50.39 56.98 283.84 281 .41 9.625 1490.43 349.71 1140.72 Pass 13900.00 10200.32 14410.00 9912.64 50.39 57.09 283.70 281.26 9.625 1490.43 350.17 1140.26 Pass "]:h 7fjk-30 C-é'W1~v1 f 3 -( L/~-{ý Ceh1~"f Utff~.J I3Þ/~ - r. 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Nordic 2 CTD BOP Detail --- CT Injector Head -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ - 7" Riser Methanol Injection Otis 7" WLA Quick Connect - 7-1/16" 10, 5000 psi working pressure Ram Type Dual Gate BOPE Annular BOP (Hydril),7-1/16" 10 5000 psi working pressure Manual over Hydraulic 8 I Blind/Shear I / J / 123/8" Combi Pipe/Sli~ Fire resistant Kelly Hose to Flange by Hammer up 1/4 Tur~ Kill line check valve or Valve on DS Hardline to Standplp( HCR manifold Flanged Fire Resistant Kelly Hose to Dual Choke Manifold 7-1/16" 10, 5000 psi working pressure Ram Type Dual Gate BOPE I TOT I Manual over Hydraulic 23/8" X 3 1/2" VBRs 2 3/8" Combi Pipe/Slip I~ 1/ XO Spool as necessary 2 flanged gate valves Full production christmas tree Inner Annulus MOJ 9/15/02 o ~ Outer Annulus p 055194 CHECK NO. 055194 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 11/25/200 PR 1118030 PERMIT TO DRILL EES H ¿-nø ~-{7f;I~r{) e TOTAL ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. e 111055 ~ ~"'". I:O"'~· 20 ~8 ~ 51: 0 ~ 2 ?8 ~ bill I , . e TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WBA T ADD-ONS "CLUE" APPLIES (OPTIONS) M1JLTI The permit is for a new wellbore segment of LATERAL existing well . Permit No, API No. . (If API num ber Production should continue to be reported as last two (2) digits a function· of the original API number. stated are between 60-69) above. Pn.,OT HOLE In accordance with 20 AAC 25.005(t), all (PH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION . compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes tbe liability of any protest to the spacing . exception tbat may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals tbrough target zones. Rev: 07/10/02 C\jody\templates Field & Pool ENDICOTT, ENDICOTT OIL - 220100 Well Name: DUCK IS UNIT SDI 3-17F/K30 Program DEV Well bore seg PTD#: 2032160 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV /1-0IL GeoArea 890 Unit 10450 On/Off Shore Off Annular Disposal 1 Permittee attache_d _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Lease_numberapprORri<:lte_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_nique well_n_ame_and Ollmb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ . _ _ _ 4 WeJUoc;ated ina d_efinedpool_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WeJUoc<:lted proper _distance_ from driJling unitb.ound_a[y_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WellJoc<:lted pr.oper _distance_ from otber welJs_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 _S_utfjcientacreage_aYail<:lble in_dJilliog llnjt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 Jf.deviÇlted, js_ weJlbore plaUncJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 _Oper_ator onl]' affected party _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . 10 _Operator bas.appropriate_b.ond inJorce . . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ Yes _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ 11 Permit can be iSSlled wjtbout co_nservation order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ Appr Date 12 Permit can be iSSlled wjtbout Çldministrati\(e_approvaJ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ . RPC 12/15/2003 13 Can permit be approved before 15-day wait Yes 14 WelUocated within area Çll1d.strat<:lauthorized by_lnjectioo Order # (putlO# in_commeots) (For_ NA _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ . . 15 AJlweUs_withtn.1l4_l1Jite_area_ofreyiewjdeotified(Forservjcew.etlonly). _ _ _ _ _ _ _ _ _ _ _ _ _ _ .NA _ _ _ _ _ _. _. _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 16 PJe-produj;:edinjector; dur<ltion.ofpre-production/ess_thÇlI13mol1ths(For_servtcewellonJy) _ _ NA.. _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ __ 17 ACMPF=il1ding.ofCon,Si,Stencyhasbee_nJssuedforJhispr_oject _ _ _ _ _ NA _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _.. 18 _C_onductor stril1g_PJovided _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _NA _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . 19S_urface _cÇlsing_ pJotects alLknowl1 USDWs . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ 20 _CMTv_oJ.adequateJo circuJ.ate_on.COl1ductor_& su_rf_C$g _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ NA _ _ . . . . _ _ _ _ . _ _ _ _ . _ . _ _ _ _ _ . _ _ _ _ ... _ _ _ _ _ . _ _ _ _ . . . _ _ _ _ _ _ 21 _CMT v_oJ. adequ_ateJo tie-in Jong _string to.surf cs.g_ _ _ . _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _NA . _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ 22 _CMTwill coyera]l koown-Pfo.duetiye horizon_s_ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ 23 _C_asiog designs adequa_te for C,T, B&_Rerl1Jafr.ost _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . 24 Adequ<:lte.tankage_oJ reserve pit. . _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ Yes. . . _ _ _ _ CTDU. _ . _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ . _ . _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . 25 Jf.are-drilt has_a_ 10,403 for <lbandOl1me.nt beeo apPJoved _ . _ _ . . _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _Y_es . _ _ 12112/2_003. _ . . _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ . _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ 26 _Adequ<ltewetlbore sepÇlr<:ltion_proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jf.diverter JeQ.uiJed, does iLmeet reguJations_ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _NA _ _ _ _ _ _ . Sidetrack. _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 28 _DJiUiogfJujd_Rrogramsc.hematic_&eQ.uipJistadequ<:lte_ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ Yes_ _ _ _ _ _ _MaxMW_8_.6.ppg. _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _. _ _ _ _ __ WGA 12/15/2003 29 _BOPEs,_d.o_they meetreguJa_tion. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ Yes _ _ . _ _ _ _ _ _ _ _ _. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ 30 _BOPEpress ra.tiog appropriate; test to_(put psig tn_comments). _ _ . _ _ _ _ _ _ _ _ _ _ _ .. _ _ Yes . _ Test to 35QO_RsL .MSF' 32_90 psi._ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . 31Chokel1Janifold compJies w/API RF'-53 (May 84). _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ Yes _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 32 Work wi)1 occ_ur withouLoperation _shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y_es _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 33 .Is presence_ of H2S gas_ Rrollable _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ Yes _ _ _ _ _ _ 70_ ppm. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ 34 Mecba_nicaLcoodJllonof wells within ,ð.OR yerified (Fors_ervice weU onJy) _ _ _ _ _ _ _ _ . _NA _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ Administration Engineering - - - - - - - - - - - -- - - - - - - - - - - - - - - - - Geology 35 36 Date 37 12/15/2003 38 39 Permit can be iSSlled wlo hydrogen_ s_utfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _D_ata_PJeseoted 011 pote_ntial oveJJ~ressurezOl1e$ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _SetsmicanalysJs_ of sbaJlow gas_zooes_ _ _ _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _Seabed _col1djtjoo Sllrvey .(if off-sh.ore) _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ Contact l1amelphOl1eJorweekly progress reports [explorato[yonIYl _ _ _ _ _ _ No _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _.. _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _.. _ _ _ _ _ _ _ _ _ __ _ _ _ _ _NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ NA_ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _. ___ _ _ _ _ N_A _ _ .._ _ _ _ _ _ _ _ _ _ ___ ____ _ _ _ _ _ . __ _ _ _ __ _ _ _ _ _ _ _ _ _ __ _ _ _ _ __ _ _ _ _ _ _ ___ ___ _ _ __ Appr RPC Geologic Commissioner: Engineering Comm issioner: Date Public Commissioner'/ Date ~;J Date: lSrs ) ¿( { £ ¡; o o - -- e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . **** REEL HEADER **** MWD 04/07/14 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/07/09 638506 01 3.125" CTK *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: Idwg.las !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 13725.0000: STOP.FT 13898.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 8 TOWN.N IlN RANG. 17E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 52.6 DMF KB EKB .F 52.6 EDF .F N/A EGL .F N/A CASE.F 13733 OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. 3-17F/PBl Endicott Unit 70 deg 19' 20.347" N, 147 deg 51' 46.966" W North Slope Alaska Baker Hughes INTEQ 3.125" CoilTrak - Gamma Ray 28-Feb-04 500292194671 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 .;2ô3- :2-1 G I 25 70 . . All depths are Bit Depths unless otherwise noted. All Gamma Ray data (GRAX) presented is real time data. Baker Hughes INTEQ utilized CoilTrak downhole tools and the ADVANATGE surface system. (5) Tools run in the string include Casing Coil Locator, Electrical Disconnect and Circulating sub, a Drilling Performance Sub (inner & outer downhole pressure, downhole weight on bit, downhole temperature), a Gamma and Directional Sub, and a Hydraulic orienting Sub with near bit inclination sensor. (6) The data presented here is final. It has not been adjusted to a PDC (Primary Depth Control) log. Per BPX instructions, the MWD Gamma Ray is the depth reference for this wellbore. (7) The sidetrack was drilled from milled window in the 4.5" chrome tubing Top of Window 13724 ft. MD (10076.7 ft. TVD) Bottom of Window 13733 ft. MD (10084.0 ft. TVD) Note the presence of a Radioactive Marker at 13732 ft MD (10083' TVD). (8) The interval from 13871 ft. to 13898 ft. MD (10160.4-10162.3 ft. TVD) was not logged due to sensor offset. (9) Tied into 3-17E/K-30 at 13563 ft. MD. MNEMONICS: GRAX -> ROPA -> TVD -> (2) (3) (4 ) Gamma Ray MWD-API [MWD] (MWD-API units) Rate of Penetration, feet/hour Subsea True Vertical Depth, feet Tape Subfile: 1 65 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT final. xtf 150 BP Exploration (Alaska) Inc. 3-17F/PBl Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). Per BP Exploration instructions, the MWD Gamma Ray is the PDC for this borehole. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX ROPA 0.0 0.0 . . * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 5 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 13725.500000 13898.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 14 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 3-17Fpbl.xtf 150 BP Exploration (Alaska) 3-17F/PBl Prudhoe Bay Unit North Slope Alaska . . *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPA GRAX ROPA GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROPA MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 9 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 13725.250000 13898.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 18 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 04/07/09 638506 01 **** REEL TRAILER **** MWD 04/07/14 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: . . 2 records... 132 bytes 132 bytes . . Tape Subfile 2 is type: LIS DEPTH GR ROP 13725.5000 21.0700 -999.2500 13726.0000 20.1150 -999.2500 13750.0000 24.9500 20.1100 13800.0000 19.5500 17.6000 13850.0000 57.6200 43.4600 13898.0000 -999.2500 -999.2500 Tape File Start Depth 13725.500000 Tape File End Depth 13898.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet .' . 't" .. . . Tape Sub file 3 is type: LIS DEPTH GRAX ROPA 13725.2500 21. 3700 -999.2500 13725.5000 21. 0700 -999.2500 13750.0000 24.9500 20.1100 13800.0000 19.5500 17.6000 13850.0000 57.6200 43.4600 13898.0000 -999.2500 -999.2500 Tape File Start Depth 13725.250000 Tape File End Depth 13898.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet . . **** REEL HEADER **** MWD 04/07/09 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/07/09 638506 01 3.125" CTK *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: Idwg.las !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 13700.0000: STOP.FT 15436.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 8 TOWN.N 11N RANG. 17E PDAT. MSL EPD . F 0 LMF . RKB FAPD.F 52.6 DMF KB EKB .F 52.6 EDF .F N/A EGL .F N/A CASE.F 13703 OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. 1.20 : NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. 3-17F/K-30 Endicott Unit 70 deg 19' 20.347" N, 147 deg 51' 46.966" W North Slope Alaska Baker Hughes INTEQ 3.125" CoilTrak - USR 09-Mar-04 500292194606 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 Y) / '/,n - ( . ê-,( f') 3 '7// A ( . \..1-..-"', ~'t?\...,· P /') --¿I l' I ~5 C(,; . . All depths are Bit Depths unless otherwise noted. All Gamma Ray data (GRAX) presented is realtime data. Baker Hughes INTEQ utilized CoilTrak downhole tools and the ADVANATGE surface system. (5) Tools run in the string include Casing Coil Locator, Electrical Disconnect and Circulating sub, a Drilling Performance Sub (inner & outer downhole pressure, downhole weight on bit, downhole temperature), Ultra Slim Resistivity Sub, a Gamma and Directional Sub, and a Hydraulic Orienting Sub with near bit inclination sensor. (6) The data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) curve supplied by BP Exploration (SWS, 12-Mar-04). (7) The sidetrack was drilled from milled window in the 4.5" chrome tubing Top of Window 13724 ft. MD (10076.7 ft. TVD) Bottom of Window 13733 ft. MD (10084.0 ft. TVD) Note the presence of a Radioactive marker at the depth of 13707 ft. MD (10062 ft. TVD) (8) For the sake of maximum data coverage, resistivity data from a MAD pass was included over the interval 13924 ft, to 14067 ft. MD (10131 ft. to 10134 ft. TVD). All resistivity data outside this interval was acquired while drilling. (9) The interval from 15397 ft. to 15436 ft. MD (10168.6-10170.2 ft. TVD) was not logged due to sensor offset. (10) Tied into 3-17E/K-30 at 13563 ft. MD. MNEMONICS: GRAX -> ROPA -> RPCLX -> RPCHX -> RAC1X - > RACHX - > (2) (3) (4) Gamma Ray MWD-API [MWD] (MWD-API units) Rate of Penetration, feet/hour Compo Phase Resistivity (1S), 400 kHz, ohmm Compo Phase Resistivity (LS), 2 MHz, ohmm Compo Attenuation Resistivity (1S), 400 kHz, ohmm Compo Attenuation Resistivity (LS), 2 MHz, ohmm Tape Subfile: 1 72 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VA1U ------------------------------------ WDFN 1CC CN WN FN COUN STAT finaldata 5.xtf 150 BP Exploration (Alaska) Inc. 3-17F/K-30 Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS, 12-Mar-04 . . *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAXOl 0.0 ROP ROP ROPAOl 0.0 RACL RACL RACLXOl 0.0 RACH RACH RACHXOl 0.0 RPCL RPCL RPCLXOl 0.0 RPCH RPCH RPCHXOl 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RACL MWD 68 1 OHMM 4 4 4 RACH MWD 68 1 OHMM 4 4 5 RPCL MWD 68 1 OHMM 4 4 6 RPCH MWD 68 1 OHMM 4 4 ------- 24 Total Data Records: 97 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 13700.000000 15436.000000 0.500000 feet **** FILE TRAILER **** Tape Sub file: 2 110 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 . . *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT finaldata.xtf 150 BP Exploration (Alaska) 3-l7F/K-30 Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 ROPA ROPA ROPA 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (va1ue= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROPA MWD 68 1 F/HR 4 4 3 RACL MWD 68 1 OHMM 4 4 4 RACH MWD 68 1 OHMM 4 4 5 RPCL MWD 68 1 OHMM 4 4 6 RPCH MWD 68 1 OHMM 4 4 ------- 24 Total Data Records: 193 Tape File Start Depth Tape File End Depth 13700.000000 15436.000000 . . Tape File Level Spacing Tape File Depth Units 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 206 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 04/07/09 638506 01 **** REEL TRAILER **** MWD 04/07/09 BHI 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes . . Tape Subfile 2 is type: LIS DEPTH GR ROP RACL RACH RPCL RPCH 13700.0000 -999.2500 15.5700 -999.2500 -999.2500 -999.2500 -999.2500 13700.5000 16.3395 3.7974 -999.2500 -999.2500 -999.2500 -999.2500 13750.0000 8.9058 57.7818 -999.2500 -999.2500 -999.2500 -999.2500 13800.0000 28.5880 12.5124 -999.2500 -999.2500 -999.2500 -999.2500 13850.0000 21. 2338 24.8310 -999.2500 -999.2500 -999.2500 -999.2500 13900.0000 11. 6147 21. 6594 -999.2500 -999.2500 -999.2500 -999.2500 13950.0000 50.1917 25.1227 32.2684 24.5328 33.0999 68.4686 14000.0000 96.5901 55.3384 74.8848 52.5430 36.1400 31. 5900 14050.0000 49.9554 76.2816 158.4870 119.5862 70.7629 65.1802 14100.0000 47.3210 107.3215 -999.2500 -999.2500 -999.2500 -999.2500 14150.0000 29.3178 66.5953 -999.2500 -999.2500 -999.2500 -999.2500 14200.0000 37.1236 79.9676 -999.2500 -999.2500 -999.2500 -999.2500 14250.0000 23.0481 34.9277 2179.3999 324.7603 239.3000 216.2200 14300.0000 11.0815 53.9807 2179.3999 3320.6250 197.0291 173.4200 14350.0000 26.0068 102.8505 2179.3999 3789.9204 281.4714 266.1738 14400.0000 17.8148 77.6938 2179.3999 3865.1655 314.2600 291.9700 14450.0000 27.9175 98.4673 2179.3999 6064.5400 314.2600 284.5374 14500.0000 12.2493 74.6674 2179.3999 6064.5400 284.7600 268.8400 14550.0000 16.5851 81.5575 2179.3999 6064.5400 284.7600 254.8793 14600.0000 15.3840 92.2900 2179.3999 583.8025 260.1400 248.8800 14650.0000 12.0740 71.8717 2179.3999 414.6995 . . 235.0486 221.5947 14700.0000 50.4074 22.2344 2179.3999 6064.5400 508.6647 351.3200 14750.0000 41. 3501 91. 8817 2179.3999 338.5266 200.8486 198.1707 14800.0000 11. 9863 100.8994 2179.3999 298.3386 216.2030 211.6631 14850.0000 24.7905 71.6663 2179.3999 870.3523 284.7600 252.7750 14900.0000 14.8377 84.4325 2179.3999 819.1920 181. 2200 170.7303 14950.0000 13.4152 3.6542 1016.9998 274.3514 182.6956 181.8859 15000.0000 28.9832 27.5102 2179.3999 348.4583 284.7600 291.9700 15050.0000 23.8196 51.2465 2179.3999 224.0600 251.0143 268.8400 15100.0000 16.4961 57.9250 2179.3999 231.5724 226.3869 236.3208 15150.0000 30.3562 66.5571 2179.3999 436.1340 291.3030 291. 9700 15200.0000 11.6355 9.1582 2179.3999 257.5073 270.8006 297.5375 15250.0000 35.3815 15.1942 2179.3999 257.6224 187.8676 177.8776 15300.0000 20.2414 39.6117 1830.0452 160.7075 143.9700 139.1100 15350.0000 15.0852 48.8770 88.9572 55.4445 65.2200 71. 2244 15400.0000 -999.2500 61.9630 -999.2500 -999.2500 -999.2500 -999.2500 15436.0000 -999.2500 64.3644 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 13700.000000 Tape File End Depth 15436.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet . . Tape Subfile 3 is type: LIS DEPTH GRAX ROPA RACL RACH RPCL RPCH 13700.0000 17.1400 0.9400 -999.2500 -999.2500 -999.2500 -999.2500 13700.2500 19.4000 0.8500 -999.2500 -999.2500 -999.2500 -999.2500 13750.0000 9.1000 54.2600 -999.2500 -999.2500 -999.2500 -999.2500 13800.0000 22.6200 18.2600 -999.2500 -999.2500 -999.2500 -999.2500 13850.0000 21. 0500 21. 3500 -999.2500 -999.2500 -999.2500 -999.2500 13900.0000 10.3300 32.4200 -999.2500 -999.2500 -999.2500 -999.2500 13950.0000 40.7400 46.2700 39.1100 35.3516 75.0300 221.6470 14000.0000 104.6700 58.5800 64.5082 53.1515 34.0687 29.6569 14050.0000 52.7100 82.0000 166.4505 104.0548 79.8469 70.7471 14100.0000 21.7600 89.5000 -999.2500 -999.2500 -999.2500 -999.2500 14150.0000 29.9400 65.7800 -999.2500 -999.2500 -999.2500 -999.2500 14200.0000 34.8800 76.2700 -999.2500 -999.2500 -999.2500 -999.2500 14250.0000 21.7450 7.0300 2179.3999 268.7000 221. 4200 202.6900 14300.0000 12.3700 96.8400 2179.3999 6064.5400 213.6750 196.6600 14350.0000 25.2300 104.6300 2179.3999 488.9500 284.7600 248.8800 14400.0000 20.6100 79.7700 2179.3999 6064.5400 314.2600 268.8400 14450.0000 34.0300 91. 0300 2179.3999 6064.5400 350.2600 291. 9700 14500.0000 13.5800 71.4200 2179.3999 6064.5400 284.7600 268.8400 14550.0000 17.9000 82.1800 2179.3999 6064.5400 284.7600 268.8400 14600.0000 14.8067 94.0700 2179.3999 780.5399 284.7600 248.8800 14650.0000 10.9700 70.5900 2179.3999 602.9077 .. . . 225.7222 231. 4900 14700.0000 44.4600 72.9800 2179.3999 6064.5400 1974.2200 681.7100 14750.0000 12.8200 93.5000 2179.3999 383.3000 221. 4200 231.4900 14800.0000 11. 9900 98.0400 2179.3999 335.1800 205.9300 202.6900 14850.0000 23.3800 69.4500 2179.3999 6064.5400 284.7600 248.8800 14900.0000 18.0700 89.1400 2179.3999 692.4099 192.3700 190.6300 14950.0000 13.3200 5.2000 2179.3999 252.6400 221.4200 231.4900 15000.0000 27.6100 28.4800 2179.3999 624.5100 284.7600 291. 9700 15050.0000 27.3400 50.0300 2179.3999 245.4100 260.1400 268.8400 15100.0000 18.7600 58.8600 2179.3999 297.7800 221.4200 231. 4900 15150.0000 29.7900 68.0100 2179.3999 430.0900 260.1400 268.8400 15200.0000 11. 6700 5.7800 2179.3999 260.3900 260.1400 291. 9700 15250.0000 28.9800 17.4700 2179.3999 287.3000 192.3700 190.6300 15300.0000 17.3700 39.5000 2179.3999 159.5900 124.6400 121.8800 15350.0000 15.2850 48.6100 87.0500 59.0400 63.5300 70.8100 15400.0000 -999.2500 61. 6600 -999.2500 -999.2500 -999.2500 -999.2500 15436.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 13700.000000 Tape File End Depth 15436.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet