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Home My WebLink About198-147Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/12/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250912 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 8/28/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/19/2025 AK E-LINE CIBP BRU 224-34T 50283202050000 225044 8/17/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/22/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/27/2025 AK E-LINE Perf BRU 241-23 50283201910000 223061 8/20/2025 AK E-LINE Plug/Perf GP 11-13RD 50733200260100 191133 8/29/2025 AK E-LINE Perf KALOTSA 6 50133206850000 219114 8/14/2025 AK E-LINE PPROF MGS ST 17595 06 50733100730000 166003 8/19/2025 AK E-LINE Drift MGS ST 17595 06 50733100730000 166003 8/26/2025 AK E-LINE Drift MGS ST 17595 11 50733200130000 167017 8/17/2025 AK E-LINE CBL MGS ST 17595 20 50733203770000 185135 8/21/2025 AK E-LINE CBL MPI 1-61 50029225200000 194142 8/19/2025 AK E-LINE Patch NCIU A-21A 50883201990100 225075 8/23/2025 AK E-LINE Perf END 1-23 50029225100000 194128 7/14/2025 HALLIBURTON MFC40 END 2-74 50029237850000 224024 7/12/2025 HALLIBURTON MFC40 END 3-07A 50029219110100 198147 7/13/2005 HALLIBURTON COILFLAG END 3-15 50029217510000 187094 7/15/2025 HALLIBURTON MFC24 NS-20 50029231180000 202188 9/2/2025 HALLIBURTON COILFLAG PBU 01-13A 50029202700100 225052 8/18/2025 HALLIBURTON RBT-COILFLAG PBU 07-24A 50029209450100 225045 8/3/2025 HALLIBURTON RBT-COILFLAG PBU C-34C 50029217850300 225068 8/25/2025 HALLIBURTON RBT SD-07 50133205940000 211050 8/14/2025 HALLIBURTON TMD3D ODSK-14 50703206100000 209155 9/8/2025 READ CaliperSurvey Please include current contact information if different from above. T40874 T40875 T40875 T40875 T40875 T40876 T40877 T40878 T40879 T40879 T40880 T40881 T40882 T40883 T40884 T40885 T40886 T40887 T40888 T40889 T40890 T40891 T40892 T40893 END 3-07A 50029219110100 198147 7/13/2005 HALLIBURTON COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.12 14:33:03 -08'00' From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: END 3-07A (PTD# 1981470) Request to Pop Under Evaluation with TxIA for up to 60 days Date:Wednesday, February 5, 2025 5:12:48 PM From: Lau, Jack J (OGC) Sent: Wednesday, February 5, 2025 5:08 PM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: END 3-07A (PTD# 1981470) Request to Pop Under Evaluation with TxIA for up to 60 days Hello Ryan Thompson, Hilcorp’s request to flow well END3-07A under evaluation, after completed the well work listed below, for up to 60 days to evaluate production rates for well economics to support repair of the tubing is approved. Jack Lau From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Wednesday, February 5, 2025 4:51 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: END 3-07A (PTD# 1981470) Request to Pop Under Evaluation with TxIA for up to 60 days Jack, Below is an email history with prior approval to flow END 3-07A for 60 days for economic evaluation with known TxI communication from Nov 2024. The well was successfully popped and tested following approval in November, but the wells production was uncompetitive and therefore uneconomic to fix the TxI. The wells current completion (WBS attached), includes toe perforations isolated with a CIBP set in 1998. After milling out the CIBP, Hilcorp requests permission to flow the well under evaluation for up to 60 days to evaluate production rates for well economics to support repair of the tubing. The IAP will be maintained below MOASP and the well resecured at the end of the under eval period. The well will be gas lifted during the under eval period. Following the previous under eval period the well was secured and passed a CMIT-TxIA to 2433 psi on CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 1/20/2024. General steps that will be completed prior to popping the well: 1. Pull TTP. 2. Pull two retrievable packers from the tubing. 3. Pull patch from the liner. 4. Mill CIBP @ 14,850’. 5. Re-perf select open perforations. 6. Set SSSV. 7. Pop well, test SVS. Prior to popping the well in November, an updated SBHPS was obtained updating our BHP and MASP value from below to now be: BHP = 4,145 psi @ 10,000’ TVD, MASP = 3145 psi (.1 psi/ft gas gradient). Please respond with any questions, Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Friday, November 8, 2024 12:01 PM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] APPROVED: END 3-07A (PTD# 1981470) Request to Pop Under Evaluation with TxIA for up to 60 days Ryan – Hilcorp’s request to flow the well END3-07A under evaluation for up to 60 days to evaluate production rates for well economics to support repair of the tubing is approved. Jack From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, November 8, 2024 11:51 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Subject: RE: [EXTERNAL] RE: END 3-07A (PTD# 1981470) Request to Pop Under Evaluation with TxIA for up to 60 days Jack – Answers below, please reach out if you need any further information or clarification. What is the MASP with a gas gradient to surface? BHP in offset well 3-25B (3/29/23) = 3776 psi @ 10,000’ TVD, MASP = 2776 psi (.1 psi/ft gas gradient). What is the MOASP of the IA and OA? IA = 2500 psi, OA = 1000 psi (CO 501) What is the current pressure and condition of the OA? OA pressure is stable @ ~100 psi. An MIT-OA last passed to 1200 psi 12/12/07, post Bradenhead weld. A CMIT-TxIA passed to 2690 psi on 5/29/24 verifying competent production casing & packer. Will gas lift be utilized during the POP Under Eval? Yes Was the problematic PGLM pulled or is it still set? The bottom packer of the POGLM patch is still in the well (see attached schematic item #4, below tubing punch @ 6138-6140) Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Friday, November 8, 2024 10:27 AM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: END 3-07A (PTD# 1981470) Request to Pop Under Evaluation with TxIA for up to 60 days Ryan – What is the MASP with a gas gradient to surface? What is the MOASP of the IA and OA? What is the current pressure and condition of the OA? 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. Will gas lift be utilized during the POP Under Eval? Was the problematic PGLM pulled or is it still set? Jack From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, November 8, 2024 10:19 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: FW: END 3-07A (PTD# 1981470) Request to Pop Under Evaluation with TxIA for up to 60 days From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, November 1, 2024 10:11 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: END 3-07A (PTD# 1981470) Request to Pop Under Evaluation with TxIA for up to 60 days Mel, Producer END 3-07A (PTD# 1981470) was made Not Operable on 8/3/22 after breaking IA MOASP. The well has a tubing punch @ 6138-6140 from 2002 that has historically been isolated with a POGLM patch (patch over gas lift mandrel). Following the Not Operable classification, the POGLM patch was pulled in Oct 2022. Adperfs were completed on 5/11/24, subsequent attempts to re-set the POGLM patch and achieve a passing MIT-T have been unsuccessful. The well is currently secured with a plug set in the retrievable packer @ 12,050’ and passed a CMIT-TxIA to 2690 psi on 5/29/24 confirming the secondary barrier. Further repair attempts of the tubing require updated production rates from those last acquired 2 years ago as the 2024 adperfs have not been tested. After pulling the tubing tail plug and setting a SSSV, Hilcorp requests permission to flow the well under evaluation for up to 60 days to evaluate production rates for well economics to support repair of the tubing. The IAP will be maintained below MOASP and the well resecured at the end of the under eval period. The well will be gas lifted during the under eval period. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis 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 theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis 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 responsibilityis 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 theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis 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. From:Lau, Jack J (OGC) To:Ryan Thompson Cc:Rixse, Melvin G (OGC) Subject:APPROVED: END 3-07A (PTD# 1981470) Request to Pop Under Evaluation with TxIA for up to 60 days Date:Friday, November 8, 2024 12:00:51 PM Ryan – Hilcorp’s request to flow the well END3-07A under evaluation for up to 60 days to evaluate production rates for well economics to support repair of the tubing is approved. Jack From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, November 8, 2024 11:51 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: END 3-07A (PTD# 1981470) Request to Pop Under Evaluation with TxIA for up to 60 days Jack – Answers below, please reach out if you need any further information or clarification. What is the MASP with a gas gradient to surface? BHP in offset well 3-25B (3/29/23) = 3776 psi @ 10,000’ TVD, MASP = 2776 psi (.1 psi/ft gas gradient). What is the MOASP of the IA and OA? IA = 2500 psi, OA = 1000 psi (CO 501) What is the current pressure and condition of the OA? OA pressure is stable @ ~100 psi. An MIT-OA last passed to 1200 psi 12/12/07, post Bradenhead weld. A CMIT-TxIA passed to 2690 psi on 5/29/24 verifying competent production casing & packer. Will gas lift be utilized during the POP Under Eval? Yes Was the problematic PGLM pulled or is it still set? The bottom packer of the POGLM patch is still in the well (see attached schematic item #4, below tubing punch @ 6138-6140) Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Friday, November 8, 2024 10:27 AM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: END 3-07A (PTD# 1981470) Request to Pop Under Evaluation with TxIA for up to 60 days Ryan – What is the MASP with a gas gradient to surface? What is the MOASP of the IA and OA? What is the current pressure and condition of the OA? Will gas lift be utilized during the POP Under Eval? Was the problematic PGLM pulled or is it still set? Jack From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, November 8, 2024 10:19 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: FW: END 3-07A (PTD# 1981470) Request to Pop Under Evaluation with TxIA for up to 60 days From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, November 1, 2024 10:11 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: END 3-07A (PTD# 1981470) Request to Pop Under Evaluation with TxIA for up to 60 days Mel, Producer END 3-07A (PTD# 1981470) was made Not Operable on 8/3/22 after breaking IA MOASP. The well has a tubing punch @ 6138-6140 from 2002 that has historically been isolated with a POGLM patch (patch over gas lift mandrel). Following the Not Operable classification, the POGLM patch was pulled in Oct 2022. Adperfs were completed on 5/11/24, subsequent attempts to re-set the POGLM patch and achieve a passing MIT-T have been unsuccessful. The well is currently secured with a plug set in the retrievable packer @ 12,050’ and passed a CMIT-TxIA to 2690 psi on 5/29/24 confirming the secondary barrier. Further repair attempts of the tubing require updated production rates from those last acquired 2 years ago as the 2024 adperfs have not been tested. After pulling the tubing tail plug and setting a SSSV, Hilcorp requests permission to flow the well under evaluation for up to 60 days to evaluate production rates for well economics to support repair of the tubing. The IAP will be maintained below MOASP and the well resecured at the end of the under eval period. The well will be gas lifted during the under eval period. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis 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 theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Patch tubing with POGLM 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 14,995 feet 12,050', 14,850'feet true vertical 10,172 feet 14,602'feet 6,154', 12,050', Effective Depth measured 14,928 feet 12,157', 14,390',feet true vertical 10,151 feet 5,591', 9,498', 9,571', 9,993' feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 12.6# / L-80 12,142' 9,562' Tubing (size, grade, measured and true vertical depth)2-7/8" 6.4# / L-80 14,995' 10,172' Packers and SSSV (type, measured and true vertical depth)See Above 1,487' 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Same 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: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Well Integrity Engineer Contact Phone: 324-241 Sr Pet Eng: 10,540psi Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Brenden Swensen brenden.swensen@hilcorp.com 908-748-8581 N/A Mono pkr (x2), 9-5/8" TIW HBP, 2.2" Straddle (x2)4-1/2” Otis HXO SSSV measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 131' 200 Size 131' 2,500' 0 13000 0 9250 NA measured TVD 9-5/8" NT95HS 10,160psi 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-147 50-029-21911-01-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0047502 ENDICOTT / ENDICOTT OIL DUCK IS UNIT SDI 3-07A Plugs Junk measured Length Liner Liner 2,282' 699' 114' Casing Conductor 9,813' 10,094' 3-1/2" 12,504' 12,906' 12,271' 9,650' 10,222' 2,502'Surface Intermediate Intermediate 30" 13-3/8" 9-5/8" NT80S 131' 2,502' 5,090psi 7,020psi 5,020psi 6,870psi 8,150psi 8,160psi 10,222' 8,285' Burst N/A Collapse N/A 2,260psi 4,760psi PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 4:07 pm, Jul 08, 2024 Digitally signed by Ryan Thompson (3984) DN: cn=Ryan Thompson (3984) Date: 2024.07.08 15:46:47 - 08'00' Ryan Thompson (3984) WCB 12-6-2024 RBDMS JSB 071124 Well Name Rig API Number Well Permit Number Start Date End Date END 3-07A Slickline / CTU 1 50-029-21911-01-00 198-147 5/8/2024 6/8/2024 LRS CTU 1, 1.5" Blue coil. Job Objective: Push strip gun debis to patch and Perforate POOH with logging tools. Log shows a +46' correction, correlated to SLB production profile 5-4-2002. Confirmed with OE and GEO. Make up and RIH with 10' of 2" HES max force perf gun. Perforate 14,100'-14,110'. POOH. L/D HES spent gun. RDMO ***Job Complete*** 5/11/2024 - Saturday 5/25/2024 - Saturday Slickline: ***WELL S/I ON ARRIVAL*** RIH W/ 20' X 3.70'' DUMMY WHIPSTOCK ***CONTINUE WSR ON 5-26-24*** 5/10/2024 - Friday LRS CTU 1, 1.5" Blue coil. Job Objective: Push strip gun debis to patch and Perforate Function test BOPs upon installation. Make up and RIH with 2.35" BOT venturi. Dry drift into the liner. Begin pushing debris at 13023. Reciprocate venturi through heel and then resume drifting/working debris downhole. Ultimately worked debrist to 14114 CTM and could not get any deeper. POOH and make up 1.69" motor and 2.36" venturi burnshoe. Worked debris down to 14192 CTM. Relayed results to OE and depth called good enough. Dry drift liner with 2.36" burnshoe. POOH. Make up and RIH with HES memory GR/CCL. Log from the tag at 14200 to 11950 CTMD. Pipe flagged at 14100. POOH. ***Job Continued on 5/11/2024*** 5/8/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary ***WELL S/I ON ARRIVAL*** FUNCTION TEST WLV SET WHIDDEN CATCHER SUB ON EVO-TRIEVE @ 10,080'MD PULL 1-1/2" RK-DMY GLV FROM STA #3 @ 3,737' MD SET -1/2" RK-DMY GLV IN STA #3 @ 3,737' MD ***CONT WSR ON 05/09/2024*** 5/9/2024 - Thursday Slickline: SET 1.5" RK-DMY GLV IN STA #3 @ 3,737' MD PULL WCS FROM X-NIPPLE @ 12,080'MD PULL EVO TRIEVE FROM X-NIPPLE @ 12,080' MD LRS CTU 1, 1.5" Blue coil. Job Objective: Push strip gun debis to patch and Perforate MIRU. Drill - H2S/Man Down ***Job Continued on 5/10/2024*** The adperfs are correctly shown on the WBS below. -WCB Perforate 14,100'-14,110'. Well Name Rig API Number Well Permit Number Start Date End Date END 3-07A Slickline / CTU 1 50-029-21911-01-00 198-147 5/8/2024 6/8/2024 Hilcorp Alaska, LLC Weekly Operations Summary Slickline: ***CONTINUE FROM 5-26-24*** RAN 3.70'' GAUGE, TAG @ 11,705' SLM, WORK DOWN & BROKE OUT @ 11,855' SLM, TAG TIEBACK SLV. @ 12,040' SLM / 12,085' MD RAN 3.77'' GAUGE, TAG @ 11,937' SLM, WORK DOWN & BROKE OUT @ 12,010' SLM, TAG TIEBACK SLV. @ 12,040' SLM / 12,085' MD RAN 10' X 3.70" DMY WHIPSTOCK S/D @ 12,040' SLM / 12,085' MD T-BIRD PUMP 20bbl DIESEL FOLLOWED BY 160bbls WATER, RIH WITH 3' X 1 7/8 STEM, 4.5" BLB, 3.5" GAUGE RING, BRUSH AREA ABOVE TIEBACK SLV RAN 3.77'' GAUGE TAG TIEBACK SLV @ 12,040' SLM / 12, 085' MD (PREFORM MSN DOWN DRILL) ***WELL S/I ON DEPARTURE*** Slickline: ***CONTINUE WSR FROM 5-25-24 RAN 20' X 3.70'' DUMMY WHIPSTOCK, COULDN'T GET PAST 10,640' SLM RAN 10' X 3.70'' DUMMY WHIPSTOCK TAG @ 10,758' SLM, WAS ABLE TO WORK TOOLS DOWN FROM 10,758' SLM TO 10,758' SLM, COULDN'T WORK PAST, HAD TO PULL 200# OVER PICKUP WEIGHT RAN 3.73'' CENT, 3' X 1-7/8'' STEM, 3.69'' CENT., 3' X 1-7/8'' STEM, 3.70'' GAUGE (OAL= 72'') TAG @ 10,838' SLM, WAS ABLE TO WORK TOOLS DOWN FROM 10,838' SLM TO 10,848' SLM, COULDN'T WORK PAST, HAD TO PULL 200# OVER PICKUP WEIGHT RAN 3" SAMPLE BAILER TAG 10,925' SLM, BAILER FULL OF POWDERY SUBSTANCE MADE RUNS 7 w/ 3" DD BAILER (ball), CLEAN OUT TUBING FROM 11,013' SLM, BROKE OUT @ 11,595' SLM, TAG TIEBACK SLV @ 12,040' SLM / 12,085' MD ***CONTINUE WSR ON 5-27-24*** 5/27/2024 - Monday 5/26/2024 - Sunday 5/28/2024 - Tuesday *** WELL SI ON ARRIVAL*** PT TO 250 LOW AND 2200 PSI HIGH USING GAS. RIH HEAD (1-7/16" FH)/2" 7FT WB/ 2-1/8" CCL/BAKER 10/PACKER WITH NIPPLE REDUCER. OAL: 25' MAX OD: 3.68" WEIGHT 400#. MID ELEMENT: 12050'. CCL-MID ELEMENT: 9.3' ; CCL STOP DEPTH: 12040.7' LOG CORRELATED TO WELL SKETCH DATED 6-14-19 *** JOB CONTINUED ON 29-MAY-24*** Well Name Rig API Number Well Permit Number Start Date End Date END 3-07A Slickline / CTU 1 50-029-21911-01-00 198-147 5/8/2024 6/8/2024 Hilcorp Alaska, LLC Weekly Operations Summary 5/29/2024 - Wednesday Slickline: ***CONTINUE WSR FROM 5-28-24*** SET XX-PLUG, SET IN X-NIPPLE @ 12,017' SLM / 12,050' MD, SEEN TOP OF PACKER @ 12,010' SLM TB TO U-TUBE AND PERFORM COMBO, GOOD TEST. ** WELL LEFT OPEN W/ THUNDERBIRD ATTACHED TO TREE ** *** END TICKET *** Fullbore: *Job continues from 5-28-24* (Assist Slickline/ CMIT-TxIA) Pumped 13 bbls of seawater down the TBG to finish TBG load from previous day. Followed seawater with 30 bbls of DSL to freeze protect TBG. Swaped over to IA taking returns up the TBG through the FL. Pumped 60 bbls of seawater followed by 100 bbls of DSL down the IA. Utubed DSL from IA to TBG for FP ~4 hours 40 minutes for both strings to equalize, Pumped 15 bbls od DSL down the IA for a CMIT-TIA MAP @2750 psi ***PASS*** Starting pressure TBG/IA/OA= 2700/2750/100, First 15 minutes TBG lost 10 PSI/ IA lost 5 PSI/ OA 0 loss, Second 15 minutes TBG lost 0 PSI/ IA lost 0 PSI/ OA lost 0 PSI resulting in a PASSING CMIT-TIA. bled down both strings to 1500 psi before departure. PO notified of well status upon departure. 5/30/2024 - Thursday E-Line: *** JOB CONTINUED FROM 28-MAY-24*** PT TO 300 PSI LOW AND 2100 PSI HIGH. RIH HEAD (1-7/16" FH)/2" 7FT WB/ 2-1/8" CCL/BAKER 10/LOWER PACKER FOR POGLM. OAL: 20' MAX OD: 3.68" WEIGHT 320#. CCL STOP DEPTH: 6146.7' CCL-MID ELEMENT: 9.3' MID ELEMENT DEPTH: 6156' TOP OF PACKER AT 6154', BOTTOM OF PACKER AT 6161' LOG CORRELATED TO SLB TUBING PUNCH RECORD DATED 19-OCT-2002. *** JOB COMPLETE*** Well Name Rig API Number Well Permit Number Start Date End Date END 3-07A Slickline / CTU 1 50-029-21911-01-00 198-147 5/8/2024 6/8/2024 Hilcorp Alaska, LLC Weekly Operations Summary 6/2/2024 - Sunday Fullbore: T/I/O=1063/1115/100 Temp=S/I (Assist SL with MIT-T) MIT-T *****PASSED****** to 2741 psi. Pumped 25 bbls of DSL down the TBG to reach a Max applied pressure of 2750 psi with a target of 2500 psi. 1st 15 min TBG lost 52 psi, 2nd 15 min TBG lost 8 psi for a total loss of 60 psi. in a 30 min test. Bled TBG down to 900 psi bleeding back 13 bbls. ********WSR Continued on 6-3-2024******* Slickline: ***WELL S/I ON ARRIVAL*** FUNCTION TEST WLV=PASS SET NORTHERN SOLUTIONS 450-368 STRADDLE POGLM(WFT glm1.88"id) AT 6,125' MD. (oal=35.5' ME to ME= 36' 6156 - 6120 MD) T-BIRD PERFORM FAILING MIT-T 2500# (see log for details) SET LTT TOOL IN UPPER POGLM @ 6,125' SLM T-BIRD PERFORM PASSING MIT-T 2500# (see log for details) PULL LTT TOOL FROM UPPER POGLM @ 6,125' SLM T-BIRD PERFORM PASSING MIT-T 2681# (see log for details) SET 4-1/2" WCS ON POGLM @ 6,125' SLM ***CONT WSR ON 06/03/2024*** 6/3/2024 - Monday Fullbore: *****WSR Continued from 6-2-2024******** Pumped 17 bbls of DSL down the TBG to establish IA not tracking with TBG. Pumped an additional 31 BBLS of diesel for brush and flush. Final WHPS=1682/867/110 Fullbore: T/I/O=1000/950/0 (Assist slickline) Pumped 36 bbls of seawater down the IA and TBG to attempt pressure test. Unable to get pressure to equalize pumped 3 bbls of seawter down the IA only to pressure up both strings. let TBG Utube to IA for ~2.5 hours through 1 inch jumper. *Job continues to 6-4-24*. Slickline: ***CONT WSR FROM 06/02/2024*** PULL 1-1/2" RK-DMY GLV FROM STA #3 @ 3,737' MD SET 1-1/2" RK-LGLV (16/64" ports, 1669# tro) IN STA #3 @ 3,737' MD T-BIRD MIT-T TO 2500# - PASS (see log for details) PULL 4-1/2" WCS FROM POGLM @ 6,125' MD EQ & PULL 2-3/8" XX PLUG FROM 12,050' MD BRUSH OTIS SSSV LAND NIP W/ 30 BBLs DIESEL ATMPT TO SET 4-1/2" BBE STAND PKG STACKS (ser # HBB4-39) SEC LOCK DOWN INSTALLED. @ 1487' MD SET 2-3/8" XX PLUG (4x3/16" PORTS 22" LIH) @ 12,050' MD ***CONT WSR ON 06/04/2024*** T-BIRD PERFORM FAILING MIT-T 2500# T-BIRD PERFORM PASSING MIT-T 2500# T-BIRD PERFORM PASSING MIT-T 2681# SET NORTHERN SOLUTIONS 450-368 STRADDLE POGLM(WFT glm1.88"id) AT 6,125' MD Well Name Rig API Number Well Permit Number Start Date End Date END 3-07A Slickline / CTU 1 50-029-21911-01-00 198-147 5/8/2024 6/8/2024 Hilcorp Alaska, LLC Weekly Operations Summary Slickline: ****CONT WSR FROM 6/5/24*** (perforating). SAFETY STAND-DOWN. FUNCTION TEST WLV=PASS. PULLED UPPER POGLM FROM 6,087' SLM (lower snap latch/seals never engaged). SET MIDDLE POGLM SECTION (31.38' oal) IN LOWER ANCHOR @ 6,123' SLM (confirmed w/ 1000# over pull). PULLED 2 3/8" XX-PLUG FROM NIPPLE REDUCER @ 12,022' SLM. ***CONT WSR ON 6/7/24*** 6/4/2024 - Tuesday Fullbore: *Job continues from 6-3-24* (Assist slickline, CMIT-TxIA,MIT-IA) Continue Utube from previous night. Shut in jumper with 150 psi differential. Pumped 2.1 bbls of seawater down the IA only to attempt an CMIT-TxIA MAP 3400 psi pass above 3200 psi. Reached test pressure @ 3400 psi TBG, 3250 psi IA. First 15 minutes TBG lost 5 psi, IA lost 5 psi. Second 15 minutes TBG lost 5 psi, IA lost 5 psi. Total loss of 10 psi on both strings. ****PASSED***. Bled back 12 bbls of seawater off the IA to bring IA to 1500 psi, TBG tracked down with IA to 1750 psi. Pumped 11.5 bbls of Seawater down the TBG to attempt pressure test unable to attempt test due to IA tracking with TBG. PO bled well down flowline to bring strings down to ~1000 psi on TBG and IA. Pumped an additional 16 bbls of seawater down the TBG to attempt and surge the SO valve check closed. IA again tracked with TBG. Pumped 2 bbls of seawater while slickline tapped on plug downhole to test for stoppage in communication. Pumped 9 bbls of seawater down the IA to test for an MIT-IA MAP @ 2500 psi ***FAILED***. Reached test pressure at 2465 psi TBG, 2500 psi IA. MIT-IA failed due to communication into TBG. Standby for slickline to change valves. ***Job continues to 6-5-24*** Slickline: ***CONT WSR FROM 06/03/2024*** T-BIRD PERFORM PASSING CMITxIA 3200# (see log for details). T-BIRD PERFORM FAILING MIT-T 3200# (see log for details). SET & PULL LTTP IN TOP SECTION OF POGLM @ 6,140' MD. T-BIRD PERFORM PASSING PRESSURE TEST TO 2500# ON LTTP IN POGLM @ 6,140' MD. PULL 1" BK-OGLV FROM POGLM W/K-KOT @ 6,140' MD. SET 1" BK-DMY GLV IN POGLM W/K-KOT@ 6,140' MD. T-BIRD PERFORM FAILING PRESSURE TEST ON TBG TO 2500# (see log for details). SET 4-1/2" WCS ON POGLM @ 6,140' MD. PULL 1-1/2" RK-LGLV FROM STA #3 @ 3,737' MD. SET 1- 1/2" RK-DMY GLV IN STA #3 @ 3,737' MD. PULL 4-1/2" WCS FROM POGLM @ 6,140' MD. ***CONT WSR ON 06/05/2024*** 6/5/2024 - Wednesday Slickline: ***CONT WSR FROM 06/04/2024*** RUN MULTIPLE 4.5" GS JAR 2HRS 45 MIN .125" STAINLESS 2 HRS .125" CARBON (4HRS 45 MIN TOTAL). SAFETY STAND DOWN.***CONT WSR ON 6/6/2024*** 6/6/2024 - Thursday PULLED UPPER POGLM FROM 6,087' SLM SET & PULL LTTP IN TOP SECTION OF POGLM @ 6,140' MD. T-BIRD PERFORM PASSING PRESSURE TEST TO 2500# ON LTTP IN POGLM @ 6,140' T-BIRD PERFORM FAILING MIT-T 3200# SET MIDDLE POGLM SECTION (31.38' oal) IN LOWER ANCHOR @ 6,123' SLM Well Name Rig API Number Well Permit Number Start Date End Date END 3-07A Slickline / CTU 1 50-029-21911-01-00 198-147 5/8/2024 6/8/2024 Hilcorp Alaska, LLC Weekly Operations Summary 6/7/2024 - Friday Slickline: ***CONT WSR FROM 6/6/24*** (perforating). SET 4 1/2" LTTP IN TOP OF MID POGLM SECTION @ 6,092' SLM. T- BIRD PERFORMED FAILING PRESSURE TEST OF T&IA TO 2000psi (see log). PULLED/SET/PULLED 4 1/2" LTTP IN TOP OF MID POGLM SECTION @ 6,092' SLM (t-bird performed failing pressure test). PULLED MID POGLM SECTION FROM 6,092' SLM (lower snap latch sheared). SET/PULLED 4 1/2" LTTP IN LOWER ANCHOR @ 6,124' SLM (failed pressure test). RAN 4 1/2" D&D HOLE FINDER FROM LOWER ANCHOR TO 3,800' SLM (failed pressure tests) T-BIRD F/P TUBING W/ 23bbls DIESEL ***CONT WSR ON 6/8/24*** Fullbore: *Job continues from 6-6-24* (Assist slickline) Pumped 29 bbls of DSL down the TBG to attempt and pressure up both strings to verify LT test plug is holding. unable to maintain pressure integrity. Pumped an additional 27 bbls of DSL down the TBG after slickline reset test plug, again unable to maintain pressure on both strings. Pumped 38 bbls DSL down the TBG to pressure up both strings still unable to mantain integrity. Swap to seawater for remainder of job. Pumped 38 bbls of seawater while slickline ran D&D hole finder still unable to maintain integrity on TBG only, IA gaining pressure. Pumped 23 bbls of DSL down the TBG to FP before slickline set plug downhole *Job continues to 6-8-24* 6/8/2024 - Saturday Slickline: ***CONT WSR FROM 6/7/24*** (perforating) SET 2 3/8" XX-PLUG IN NIPPLE REDUCER @ 12,022' SLM T-BIRD PERFORM PASSING CMIT TxIA TO 2200psi (see log) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** Fullbore: *Job continues from 6-7-24* (Assist slickline, CMIT-TxIA) Pumped 14 bbls of DSL down the TBG to pressure up both strings for a CMIT-TxIA MAP @ 2500 psi. ***PASSED*** reached test pressure @ 2252 psi TBG and 2450 psi IA. First 15 minutes TBG lost 37 psi, IA lost 50 psi. Second 15 minutes TBG lsot 4 psi, IA lost 5 psi. ***PASSED*** Bled back 11.9 bbls of DSL to bring both TBG and IA down near starting pressures. Slickline left in control of well upon departure FWHPS= 975/1190/100. PULLED MID POGLM SECTION FROM 6,092' SLM (lower snap latch sheared). Tubing patch not set. -WCB _____________________________________________________________________________________ Revised By: DH 7/8/2024 Duck Island Unit Well: END 3-07A Last Completed: 9/15/1998 PTD: 198-147 SCHEMATIC CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 30" Conductor NA / NA / NA NA Surface 131’ 13-3/8” Surface 68#/ NT80/ Btrs 12.415 Surface 2,502’ 9-5/8" Intermediate 47# / NT80S / NSCC 8.681 Surface 10,222’ 9-5/8” Intermediate 47# / NT95HS / NSCC 8.681 10,222’ 12,504’ 7" Liner 26#/ L-89 / Btrs TKC 6.184 12,207’ 12,906’ 2-7/8” Liner 6.4# / L-80 / ST-L 2.441 12,085 14,995 TUBING DETAIL 4-1/2" Tubing 12.6#/ L-80 / NSCT 3.958 Surface 12,142’ 3-1/2” Tubing Tailpipe 9.2# / L-80 2.992 12,168 12,271’ TD = 14,995’ (MD) / TD =10,169’(TVD) 30” KB Elev.: 55.4’/ BF Elev.: 16.5’ 2-7/8” 3 8 5 7 9 10 9-5/8” 1 2 11 16 PBTD =14,928’ (MD) / PBTD =10,148(TVD) 4 13-3/8” 6 Min ID=1.31” @ 14,390’ 12 13 7” 2-7/8” HES CIBP @ 14,850’ 14 15 Fish: 3 POGLM Slips @ ~14,602’ (4/30/09 JEWELRY DETAIL No Depth Item 1 1,487’ 4-1/2” Otis HXO SSSV Landing Nipple, ID=3.813” GLM DETAIL: Camco 1-1/2” and 1” 2 3,737’STA 3:Vlv= Dummy, Latch= RK, TVD= 3,575’, 5/8/2024 3 6,149’ STA 2: Vlv= 1” SO, Latch= BK, Port = 20, TVD= 5,588’, 8/3/2009, POGLM 4 6,154’NS Mono Packer w/Snap Latch Receptacle, bottom @ 6,161’, ID=2.37” 5 12,010’STA 1: Vlv= Dummy, Latch= RK, TVD= 9,470’ 6 12,050’ NS Mono Packer w/1.875 “X” Nipple and WLEG set 5-28-24, w/XX Plug set 6/8/24 7 12,080’ 4-1/2” HES “X” Nipple, ID = 3.813” 8 12,085’’ 2-7/8” Baker Tie-Back Sleeve w/XO 9 12,155’ TIW Overshot Assembly, ID = 5.438” 10 12,157’ 9-5/8” x 4-1/2” TIW HBP Packer, ID = 4.00” 11 12,168’ 4-1/2” x 3-1/2” Crossover, ID=3.958” 12 12,202’ 3-1/2” Otis “X” Nipple, ID = 2.75” 13 12,234’ 3-1/2” Otis “XN” Nipple, ID = 2.7” 14 12,271’ 3-1/2” WLEG 15 14,390’ 2.20” WFD Straddle Packer, bottom @ 14,432’, ID = 1.31” 16 14,850’ 2-7/8” HES CIPB, 12/27/2008 PERFORATION DETAIL Sands MD TVD FT Status Shot Closed Size SPF K2B 12,566-12,572 9,854-9,859 6 Open 4/4/22 1.69” 6 K2B 12,582-12,590 9,866-9,871 8 Open 4/3/24 1-11/16” 6 K2B 14,100-14,110 10,031-10,029 10 Open 5/11/24 2” 6 K2B 14,400-14,420 9,992-9,992 20 Closed 9/23/08 7/3/09 1.56” 6 K2B 14,515-14,546 10,006-10,014 31 Open 1/4/99 1.58” 4 K2B 14,595-14,610 10,030-10,035 15 Open 1/4/99 1.58” 4 K2A 14,617-14,648 10,038-10,049 31 Open 1/4/99 1.58” 4 K2A 14,705-14,765 10,071-10,096 60 Open 10/25/98 1-11/16” 4 K2A 14,786-14,794 10,104-10,107 8 Open 1/4/99 1.58” 4 K2B/M 14,870-14,890 10,131-10,137 20 Closed 9/13/98 12/27/08 1-11/16” 4 K2A 14,908-14,928 10,142-10,148 20 Closed 9/13/98 12/27/08 1-11/16” 4 Reference Log: Sigma RST on 10/23/1998 OPEN HOLE / CEMENT DETAIL 13-3/8” 2,690 cu ft Permafrost in 17.5” Hole 9-5/8" 575 cu ft Class ‘G’ in a 12-1/4” Hole 7” 410 cu ft Class “G” in 8-1/2” Hole 2-7/8” 125 sks Class “G” in 3-3/4” Hole WELL INCLINATION DETAIL Max Hole Angle =103 deg. @ 13,223’ Angle at Top Perf = 46 Deg. @ 12,594’ WELLHEAD McEvoy GENERAL WELL INFO API: 50-029-21911-01-00 Initial Completion – 03/11/89 Sidetracked by Doyon 15 – 9/15/1998 SAFETY NOTE: H2S Reading Average 230 – 260 PPM on A/L & Gas Injectors. Well Requires a SSSV. Trouble setting BPV, bad tubing hanger. Well angle > 70 degrees @ 14,584’. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/27/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240627 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 43-07Y 50133206250000 214019 6/6/2024 AK E-LINE Perf KBU 43-07Y 50133206250000 214019 6/10/2024 AK E-LINE Perf KBU 43-07Y 50133206250000 214019 6/12/2024 AK E-LINE Perf MPU F-6650029226970ϭ00 1961ϲϮ 5/17/2024 AK E-LINE Perf MRU K-03RD2 50733200740200 217029 5/25/2024 AK E-LINE TubingPunch PAXTON 2 50133205730000 207164 5/16/2024 AK E-LINE Pref PAXTON 2 50133205730000 207164 5/30/2024 AK E-LINE TubingPatch PAXTON 11 50133207040000 221114 5/20/2024 AK E-LINE Perf SCU 13-09 50133203430000 181098 6/2/2024 AK E-LINE Cement/JetCut SDI 3-07A 50029219110100 198147 5/28/2024 AK E-LINE Pkr/Poglm SRU 14B-27 50133206040000 212089 6/15/2024 AK E-LINE JewelryLog SRU 32C-15 50133206130000 213070 6/13/2024 AK E-LINE TubingCut Revision Explanation: There are additional images added to the final report and a few new .las files. In the Emeraude folder there are 2 new .las files and in the Field Data folder the RIH and POOH are new .las files Please include current contact information if different from above. T39076 T39076 T39076 T39077 T39078 T39079 T39079 T39080 T39081 T39082 T39083 T39084 SDI 3-07A 50029219110100 198147 5/28/2024 AK E-LINE Pkr/Poglm Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.27 13:09:17 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/21/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240521 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 3-07A 50029219110100 198147 5/11/2024 HALLIBURTON Coilflag MPU E-19 50029227460000 197037 3/25/2024 READ CaliperSurvey MPU F-66A 50029226970100 196162 5/8/2024 READ CaliperSurvey MPI 1-27 50029216930000 187009 5/7/2024 READ PPROF MPU L-17 50029225390000 194169 5/8/2024 READ CaliperSurvey NCI A-12B 50883200320200 223053 5/2/2024 READ MAPP NCI A-17 50883201880000 223031 5/3/2024 READ MAPP PBU 11-41 50029237820000 224017 5/11/2024 HALLIBURTON RBT/Coilflag PBU D-31B 50029226720200 212168 5/12/2024 HALLIBURTON RBT PBU F-31A 50029216470100 212002 5/8/2024 READ CaliperSurvey PBU J-19 50029216290000 186135 5/2/2024 HALLIBURTON RBT PBU L-292 50029237510000 223025 5/6/2024 HALLIBURTON PPROF Please include current contact information if different from above. T38831 T38832 T38833 T38834 T38835 T38836 T38837 T38838 T38839 T38840 T38841 T38842 END 3-07A 50029219110100 198147 5/11/2024 HALLIBURTON Coilflag Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.22 09:57:50 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/9/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240509 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 3-07A 50029219110100 198147 4/17/2024 HALLIBURTON MFC END 3-25B 50029221250200 203021 3/31/2024 HALLIBURTON PPROF MPU J-16 50029226150000 195169 3/28/2024 HALLIBURTON WFL-TMD3D NCIU A-18 50883201890000 223033 5/1/2024 READ Multiple Array PProf PBU B-05D 50029202760400 213069 4/24/2024 HALLIBURTON RBT PBU C-16C 50029204380300 213191 4/26/2024 HALLIBURTON RBT PBU D-18B 50029206940200 215001 4/21/2024 HALLIBURTON RBT TBF A-07 50733200360000 167046 4/17/2024 HALLIBURTON RBT TBF A-18 50733201430000 168076 4/16/2024 HALLIBURTON RBT Please include current contact information if different from above. T38771 T38772 T38773 T38774 T38775 T38776 T38777 T38778 T38779 END 3-07A 50029219110100 198147 4/17/2024 HALLIBURTON MFC Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.13 12:46:46 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Patch tubing with POGLM 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: ENDICOTT 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14,995 ~14602 Casing Collapse Conductor N/A Surface 2,260psi Intermediate 4,760psi Intermediate 5,090psi Liner 7,020psi Liner 10,540psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 4-1/2" 45 KB Straddle Pkr, 9-5/8" x 4-1/2" TIW HBP Packer, 2.20" Straddle Packer (x2) 6,119' MD (5,567' TVD) / 12,157' MD (9,572' TVD) / 14,390' MD (9,995' TVD) / 14,432' (9,995' TVD) 14,850' 12,906 12,504 699 3-1/2" See Schematic 907-748-8581 brenden.swensen@hilcorp.com Operations Manager May 8, 2024 12,271114 2-7/8" 9,650 Perforation Depth MD (ft): See Schematic 10,0947" 131 30" 13-3/8" 9-5/8" NT80S 2,502 9-5/8" NT95HS2,282 10,222 5,020psi 6,870psi 2,500 8,285 9,813 2,502 10,222 131 131 6.4# / L-80 TVD Burst 14,995 8,160psi MD N/A 8,150psi Hilcorp Alaska, LLC Length Size Proposed Pools: 10,172 14,928 10,151 3,200 ENDICOTT OIL Same STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047502 198-147 C.O. 462.007 DUCK IS UNIT SDI 3-07A 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21911-01-00 PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 10,160psi Tubing Grade: 12.6# / L-80 Tubing MD (ft): 12,142'Perforation Depth TVD (ft): Brenden Swensen Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: 4-1/2" No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:55 pm, Apr 22, 2024 Digitally signed by Sara Hannegan (2519) DN: cn=Sara Hannegan (2519) Date: 2024.04.22 15:30:49 - 08'00' Sara Hannegan (2519) 10-404 MGR22APR2024 DSR-4/23/24 Perforate SFD 4/23/2024 3,200 *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.26 08:24:25 -08'00'04/26/24 RBDMS JSB 042624 Page 1 of 8 Fish Eline Tool String, Add Perf Well: END 3-07A PTD: 198-147 Well Name: END 3-07A API Number: 50-029-21911-01 Current Status: Non-Operable Producer PTD # 198-147 Estimated Start Date: 5/8/2024 Rig: SL / EL / Coil Reg.Approval Req’std? Yes – For Perfs Estimated Duration: 15 days Regulatory Contact: Darci Horner 907-777-8406 (O) First Call Engineer: Brenden Swensen 907-748-8581 (M) Second Call Engineer: Ryan Thompson 907-301-1240 (M) Current Bottom Hole Pressure: Low range 3776 psi @ 10,000’ TVD (SBHPS 3-25B 3/29/2023) High range 4196 psi @ 10,000’ TVD (SBHPS 3-23A 5/23/2020) Maximum Expected BHP: 4200 psi @ 10,000’ TVD (est.) 8.1ppg EMW Max. Anticipated Surface Pressure: 3200 psi Gas Column Gradient (0.1 psi/ft) H2S Level (Most Recent / Highest): 500ppm 06/09/2022, 800ppm 1/27/2021 Well Deviation: 60deg @ 12,975’ MD, 92deg @ 13,130’ MD Reference Log: 4/5/2002 Schlumberger Production Profile Wellbore Condition END 3-07A passed a CMIT-TxIA to 3150psi on 4/15/2024 with an EVO plug in the tubing at 12,063’. A known hole in the tubing is at GLM #2 at 6149’ MD. A POGLM patch has successfully been set over this hole in the past but was pulled in 2022. The wellbore is currently non-operable with TxIA communication. History A hole in the tubing at GLM#2 was found in 2002. The tubing was punched to ensure flow at this depth, and a POGLM patch was set across the hole / GLM. In 2009, the POGLM was pulled to run a patch down to the 2- 7/8” production liner as a production profile modification. A caliper was run on 5/1/2009 and indicated that the tubing was in fair shape with most of the corrosion occurring below the POGLM patch and in the 20-35% penetration range. A subsequent POGLM was run with successful MIT-IA to 3000psi on 8/3/2009. In 2022, eline attempted to add perforations with strip guns and got hung up on the way out of hole. The decision was made to drop the tool string and return with slickline to fish. After several failed attempts to fish the eline tool string, the POGLM was pulled to remove it as a restriction for fishing operations. The majority of the eline tool string was recovered, but an estimated 11’ of strip guns remain in hole. An EVO plug was set to secure the well and it has remained shut in since. Objective Fish remaining eline tool string. If successful, add K2B perfs from 14100 - 14110', set POGLM patch and return well to production. NOTE: Guns are considered to be live. Please take the necessary precautions to prevent an HSE event. add K2B perfs from 14100 - 14110' 500ppm Guns are considered to be live. Page 2 of 8 Fish Eline Tool String, Add Perf Well: END 3-07A PTD: 198-147 Procedure (page 1 of 2) Slickline 1. Prior to rigging up, review well history in detail and ensure proper tools are on location. a. One such tool we will need to have on hand ready to go is another EVO plug. If at any point the job becomes unsuccessful, we will need to be prepared to secure the well again. b. Ensure someone from AK Eline is available if/when tool string is obtained. Follow live gun procedure when getting tool string to surface. 2. MIRU. Pressure test PCE to 250psi low, 3500psi high. 3. Pull EVO-trieve plug from X nipple at 12,080’ MD. 4. Run 40 arm caliper from top of fish at 12,085’ MD to surface. a. Request rush processing and send logs and processed data to OE. i. Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 STOP POINT 1: If caliper log data suggests the tubing is in reasonable condition and the well passes the CMIT-IA, proceed with attempting to fish e-line tool string. 5. Drift to top of tool string. a. Recommend drift to top of fish with bailer bottom first, check for fill. b. If no fill recovered, run LIB to top of tool string. Recommend ~3.5” barbell tool string for LIB. NOTE: Guns are considered to be live. Please take the necessary precautions to prevent an HSE event. 6. Fish eline tool string from 12,085’ MD. a. Fish is either 1.69” firing head and then strip gun or just strip gun. i. If LIB indicates anything 1.69” and round, recommend overshot. ii. If LIB inconclusive, recommend 3 or 4 prong wire grab. Possible wadded up flat bar with det cord and external charges. 7. If fish on, stop 500’ from surface and proceed with live gun protocol. STOP POINT 2: If fishing is unsuccessful, will need to resecure well with another EVO plug. If fishing is a success, coil tubing will be up next to add perforations. Guns are considered to be live. Page 3 of 8 Fish Eline Tool String, Add Perf Well: END 3-07A PTD: 198-147 Procedure (page 2 of 2) Coil Tubing (Contingent) – Sundry Work 8. MIRU. Pressure test PCE 250psi low, 3500psi high. 9. Make tie in run. Flag coil. Correct depths using Schlumberger Production Profile dated 5/4/2002. a. Final tie in will be done by town GEO or OE. Send LAS and pdf files to both for tie in. i. OE Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 ii. GE Brock Rust brust@hilcorp.com 907-777-8394 10. Perforate K2B from 14100 - 14110' MD. Eline (Contingent) 11. MIRU. Pressure test PCE 250psi low, 3500psi high. 12. Run POGLM patch. Fullbore / Well Integrity (Contingent) 13. Perform MIT-IA to 3200psi. a. If patch is 2 run patch, will have to MIT-IA after set. Slickline (Contingent) 14. MIRU. Pressure test PCE 250psi low, 3500psi high. 15. Set top of POGLM if it is not a 1 run patch. a. If patch is 2 run patch, will have to MIT-IA after set. 16. Install live GLV’s. 17. Set SSSV. Page 4 of 8 Fish Eline Tool String, Add Perf Well: END 3-07A PTD: 198-147 Figure 1: E-line Tool String Fish Remaining Fish Already Retrieved Page 5 of 8 Fish Eline Tool String, Add Perf Well: END 3-07A PTD: 198-147 Reference Tie In Log Page 6 of 8 Fish Eline Tool String, Add Perf Well: END 3-07A PTD: 198-147 Proposed Perforation Interval ±14,100 – ±14,110’ MD Page 7 of 8 Fish Eline Tool String, Add Perf Well: END 3-07A PTD: 198-147 CURRENT SCHEMATIC Page 8 of 8 Fish Eline Tool String, Add Perf Well: END 3-07A PTD: 198-147 PROPOSED SCHEMATIC Proposed Perfs ±14,100 – ±14,110’ POGLM Patch at ±6,140 – ±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y Anne Prysunka at 9:25 am, Nov 08, 2022 'LJLWDOO\VLJQHGE\7RULQ 5RVFKLQJHU '1FQ 7RULQ5RVFKLQJHU RX 8VHUV 'DWH 7RULQ5RVFKLQJHU RBDMS JSB 111022 MGR12NOV2022 DSR-11/8/22 tĞůůEĂŵĞ ZŝŐ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ EϯͲϬϳ^ůŝĐŬůŝŶĞͬ &ƵůůďŽƌĞ ϱϬͲϬϮϵͲϮϭϵϭϭͲϬϭͲϬϬ ϭϵϴͲϭϰϳ ϭϬͬϯͬϮϬϮϮ ϭϬͬϵͬϮϬϮϮ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϬͬϴͬϮϬϮϮͲ^ĂƚƵƌĚĂǇ ϭϬͬϵͬϮϬϮϮͲ^ƵŶĚĂǇ dͬ/ͬKсϲϯϰͬϵϮϳͬϱϰdDWс^ͬ/;>Z^hE/dϰϲͿΎΎD/dͲdǆ/ƚŽϯϬϬϬW^/;ϯϮϱϬW^/DyWW>/ͿΎΎW^^ΎΎ;^>K' &KZd/>^Ϳd',hE'KEtsΘ/s>s͘&t,WΖ^сϴϴϬͬϴϴϬͬϱϬ͘ ϭϬͬϳͬϮϬϮϮͲ&ƌŝĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϬͬϱͬϮϬϮϮͲtĞĚŶĞƐĚĂǇ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞĞŬůǇKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ dͲ/Z>K/E'/tͬϮϵϬ>^<>͕ϱϬ>&W͘dͲ/Z>K^d'tͬϮϵϬ>^<>͕ϭϱ>&W͘^dϰͲϭͬϮΗsKdZ/sd ϭϮ͕ϬϮϵΖ^>DͬϭϮ͕ϬϲϯΖD;ĞůĞŵĞŶƚĂƚϭϮ͕ϬϲϬΖŵĚͿ͘ ϭϬͬϲͬϮϬϮϮͲdŚƵƌƐĚĂǇ EŽŽƉĞƌĂƚŝŽŶƐƚŽƌĞƉŽƌƚ͘ ϭϬͬϰͬϮϬϮϮͲdƵĞƐĚĂǇ KEdEϯͲϬϳt^Z&ZKDϭϬͲϯͲϮϮ͘D<ϮddDWd^tͬϯ͘ϳϴΗǆϯWZKE't/Z'ZdKϭϮ͕ϬϬϬΖ^>DdKZKsZ D/^^/E'>DEd^;ŶŽƌĞĐŽǀĞƌǇͿ͘ZEϮ͘ϴϬΗEd͕Ϯ͘ϲϮΗt/Z'ZdKϭϮ͕ϬϮϱΖ^>D;ŶŽƌĞĐŽǀĞƌǇͿ͘Z/&d&KZsKtͬϯ͘ϳϬΗ Ed͕ϯ͘ϲϲ͘'hE͕ϯ͘ϳϱΗEd͕ϯ͘ϳϬΗ>/d'dKWK&Ͳ>/Ed͘^͘dϭϮ͕ϬϭϬΖ^>D͘ZEϮͲϭͬϮΗZtͬ/dϭͲϯͬϴΗ'hdd :;ƐĞĞůŽŐĨŽƌĚĞƚĂŝůƐͿ͘ZEϮͲϭͬϮΗ:͕Wh>>Ͳ>/EdKK>^dZ/E'&ZKDϭϮ͕ϬϬϵΖ^>D;ƌĞĐŽǀĞƌĞĚĞͲůŝŶĞƚŽŽůƐƚƌŝŶŐ͕ϭϭΖǆϭ͘ϲϵΗ ƐƚƌŝƉŐƵŶƐ>/,Ϳ >^<Ͳ>/EKE>KdKZKsZd͘^͘Z/&d&KZsKtͬϯ͘ϳϬΗEd͕ϯ͘ϲϲ͘'hE͕ϯ͘ϳϱΗEd͕ϯ͘ϳϬΗ>/d'dKWK&^dZ/W 'hE^dϭϮ͕ϬϯϴΖ^>D;ŝŵƉƌĞƐƐŝŽŶŽĨƉŽƐƐŝďůĞϭ͘ϮϱΗƌŽƉĞƐŽĐŬĞƚͿ͘ZEϯ͘ϲϬΗ>>'h/͕Ϯ͘ϲϬΗ>>'h/͕ϭͲϱͬϴΗ:͕dK ϭϮ͕ϬϯϴΖ^>DͲZKsZ^>Ͳ&/^,;ϭ͘ϮϱΗZKW^K<d͕ϭ͘ϳϱΗEd͕ϭͲϯͬϴΗ:ͲϰͬϭϬͬϮϮͿ͘dͲ/Z^dZd^>K/E'/tͬϮϵϬ >^<>͕ϱϬ>&W͘KEdEϯͲϬϳt^ZKEϭϬͲϱͲϮϮ͘^dηϮKWEWK<ddϲ͕ϭϰϵΖD͘ϭϭΖǆϭ͘ϲϵΗ^dZ/W'hE^>/,ͲEKd ZKsZ;>/,KEϰͲϲͲϮϮͿ͘ZKsZ^>Ͳ&/^,;ϭ͘ϮϱΗZKW^K<d͕ϭ͘ϳϱΗEd͕ϭͲϯͬϴΗ:ͲϰͬϭϬͬϮϮͿ͘ ϭϬͬϯͬϮϬϮϮͲDŽŶĚĂǇ Z/'KtE͘ϭϮϱͬZ/'hW͘ϭϲϬ͘dͲ/Z>K^ͬ</>>t>>tͬϲϬϬ>^<>͘:Z&KZϯ,Z^tͬ͘ϭϲϬΗt/ZdϯϭϬϬͲϯϰϬϬ>^͘ Wh>>ϰϱ<^dZ>W<ZtͬWK'>Ddϲ͕ϭϭϵͲϲ͕ϭϲϬΖD;ŵŝƐƐŝŶŐϭĞůĞŵĞŶƚĨƌŽŵƵƉƉĞƌƐĞĐƚŝŽŶĂŶĚϭĞůĞŵĞŶƚĨƌŽŵ ůŽǁĞƌƐĞĐƚŝŽŶͿ͘Z/'KtE͘ϭϲϬͬZ/'hW͘ϭϮϱ͘ZEϯ͘ϳϴΗǆϯWZKE't/Z'ZdKϭϮ͕ϬϬϬΖ^>D;ĨŝƐŚŝŶŐŵŝƐƐŝŶŐĞůĞŵĞŶƚƐͿ͘ KEdEϯͲϬϳt^ZKEϭϬͲϰͲϮϮ͘ ^dZ/W'hE^>/,ͲEKd ZKsZ;>/,KEϰͲϲͲϮϮͿ͘ Wh>>ϰϱ<^dZ>W<ZtͬWK'>Ddϲ͕ϭϭϵͲϲ͕ϭϲϬΖD :)'675$''/(3.5 ,' 3HUIRUDWLRQVVKRW 0' 0' +LOFRUS$ODVND//& 6OLSVWRSVHW # 6/0 (/WRROVWULQJZVWULSJXQV 2$/ # (9275,(9(3/8*6(721 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: NOT OPERABLE: Producer END 3-07A (PTD# 198-147) IA Exceeded MOASP Date:Friday, September 9, 2022 8:29:34 AM Attachments:image001.png image002.png 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: Thursday, September 8, 2022 4:38 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: RE: NOT OPERABLE: Producer END 3-07A (PTD# 198-147) IA Exceeded MOASP Mr. Regg, Producer END 3-07A (PTD# 198-147) is a Not Operable well after exceeding IA MOASP. Initial diagnostics and GLV changeout did not repair the IA repressurization and the IA exceeded MOASP again on 9/7/2022. Due to a facility shutdown, we are currently unable to load the well. The well will be loaded and killed at the first available opportunity. Plan Forward: Ops: Bleed IAP FB: Load well with kill weight fluid SL: Leak detect log Eng: Secure or repair well as required Please respond if there are questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Wednesday, August 3, 2022 9:17 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Producer END 3-07A (PTD# 198-147) IA Exceeded MOASP Mr. Regg, Producer END 3-07A (PTD# 198-147) exceeded MOASP during the facility TAR operations. Due to operational constraints, diagnostics could not be completed during the evaluation period. The well is currently shut in until operational capacity is available. The well is now classified as NOT OPERABLE. Plan Forward: 1. Cold TIFL 2. Engineer to evaluate additional diagnostics as required 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 From: Jerimiah Galloway Sent: Wednesday, July 6, 2022 12:51 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Producer END 3-07A (PTD# 198-147) IA Exceeded MOASP Mr. Regg, Producer END 3-07A (PTD# 198-147) was recently shut in for the facility TAR. After being shut in, the inner annulus pressure began to climb and exceeded MOASP to 2600 psi. Currently the well is and will remained shut in until TAR activities are completed. The well is now classified as UNDER EVALUATION and is placed on a 28 day clock for further evaluation and repair. Plan Forward: 1. POP Well 2. Warm TIFL 3. Engineer to evaluate additional diagnostics as required 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. Kaitlyn Barcelona Hilcorp North Slope, 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 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 MPI 3-07A (PTD 198-147) PERF 4/06/2022 Please include current contact information if different from above. PTD:198-147 T36588 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.11 11:52:42 -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:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Producer END3-07A (PTD# 198-147) Date:Friday, April 15, 2022 10:58:20 AM Attachments:image001.png image002.png 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: Friday, April 15, 2022 10:34 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Producer END3-07A (PTD# 198-147) Mr. Regg, Producer END3-07A (PTD# 198-147) inner annulus pressure has recently exceeded MOASP and was placed UNDER EVALUATION for diagnostics and repair. The gas lift valves were determined to be the source of the failure and have been replaced. The inner annulus pressure was bled and no additional repressurization was identified. This confirms competent barriers to formation. The well is now reclassified as OPERABLE. Please respond if there are questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Friday, April 8, 2022 11:08 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Producer END3-07A (PTD# 198-147) Mr. Regg, Producer END3-07A (PTD# 198-147) has recently had perforations added to the well. While shut in, the inner annulus began to repressurize and has exceeded MOASP to 2625psi. Currently the well is shut in awaiting further intervention activities. The well is now classified UNDER EVALUATION and is placed on a 28 day clock for further evaluation and repair. Plan Forward: 1. C/O OGLV 2. Evaluate repressurization 3. Engineer to evaluate additional diagnostics as required 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 thismessage 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'sphone 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 affectits 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. 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: UNDER EVALUATION: Producer END3-07A (PTD# 198-147) Date:Friday, April 8, 2022 11:27:52 AM Attachments:image001.png image002.png 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: Friday, April 8, 2022 11:08 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Producer END3-07A (PTD# 198-147) Mr. Regg, Producer END3-07A (PTD# 198-147) has recently had perforations added to the well. While shut in, the inner annulus began to repressurize and has exceeded MOASP to 2625psi. Currently the well is shut in awaiting further intervention activities. The well is now classified UNDER EVALUATION and is placed on a 28 day clock for further evaluation and repair. Plan Forward: 1. C/O OGLV 2. Evaluate repressurization 3. Engineer to evaluate additional diagnostics as required 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 thismessage 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'sphone 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 affectits systems or data. 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convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "/" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp Orig • New • API_WeIINo I PermitNumber' WelMName WellNumber WellNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-306/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/S14 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/S09 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-66SD12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/517 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/128 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 150029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-17B 150029219460300 !1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 11982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~'//-/~' File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts Pages: ._7~, ~ ? / 5-2, ~'_,,~ , ?.2, 7_5 Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds Other COMMENTS: Scanned by: Beverly Mildred Daretha~ TO RE-SCAN Lowell Date: ~//-~/ /s/ ,~ / Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ • S bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 n 0 `Lille 5—kott4F 5T. Mr. Jim Regg I T ` LII. 7 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 3 Ld?-g Anchorage, Alaska 99501 4 V 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 • III 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 gal 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 END3-17F / 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 STATE OF ALASKA ALAS~L AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS ~~`~ ~ I~~`~ ~~°~~ ~~9-09 ~UG 7 7 2t~~~ =:sa~r~~ r'~~s ~. r~~..~ :~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ Other Q STRA 7 . Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time E~ctension ~ ~~~~_~'~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permif to Dritf Number: Name: De~lopment ~! Exploratory I~ 198-1470- 3. Address: P.O. Box 196612 Stratigraphic I'r Service r 6. API Number: Anchorage,AK 99519-6612 50-029-21911-01-00- 7. KB Elevation (ft): 9. Well Name and Number: 56 KB ~ 3-07A/L-29 ~ 8. Property Designation: 10. Field/Pool(s): ADLO-047502 - ENDICOTT Field/ ENDICOTT OIL Pool 11. Present Well Condition Summary: Total Depth measured 14995 ~ feet Plugs (measured) 14850' 14560' true vertical 10169.93 - feet Junk (measured) None Effective Depth measured 14928 feet true vertical 10149 feet Casing Length Size MD TVD Burst Collapse Structural 2502' 13-3/8" 68# L-80 SURFACE - 2502' SURFACE - 2483' S020 2260 Surface 10222' 9-5/8" 47# NT80S SURFACE - 10261' SURFACE - 8254' 6870 4760 Intermediate 2882' 9-5/8" 47# NT95HS 10222' - 12543' 8251' - 9783' 8150 5080 Liner 2915' 4-1/2" 12.6# L-80 SURFACE - 12080' SURFACE - 9517' 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ 7ubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 12080 2-7/8" 6.4# L-80 12085 - 14995 Packers and SSSV (type and measured depth) 9-5/8" TIW PKR HBBP 12157' 45 KB STRADDLE PKF ID=1.83" °-° -°~6119' - 6160' / 2.20" WFD STRADDLE ID=1.31" 14390' - 14432' / 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ,. SS ~ , ,~ ~ ~ ; `_~ ~. ~ S~~> `~'`""~` ~~ ~""y ~~ Treatment descriptions induding 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: 5 6 6879 319 Subsequent to operation: SI 14. Attachments: 15. Well Class after qroposed work: Copies of Logs and Surveys Run Exploratory ~ De~elopment ~- Service 1~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~- Gas I~ WAG ~ GINJ 1~ WINJ f~ ~NDSPL ~ 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 Prebl Title Data Management Engineer Signature Phone 564-4944 Date 8/14/2009 Form 10-404 Revised 04/2006 ~~~.~+~.~~ ~~~ u;; `3 ~ 7!~~~ ~~~ ~~~~/~ Submit Original Only i~F~ 3-07AIL-29 198-147 PERF ATTACHMENT ~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 3-07AIL-29 9/13/98 PER 14,870. 14,890. 10,132.15 10,138.08 3-07AIL-29 9/13/98 PER 14,908. 14,928. 10,143.35 10,149.34 3-07AIL-29 10/23/98 BPS 14,850. 14,855. 10,126.04 10,127.58 3-07A/L-29 10/25/98 APF 14,705. 14,765. 10;072.57 10,097.5 3-07AIL-29 1/4/99 APF 14,786. 14,794. 10,105.53 10,108.32 3-07AIL-29 1/4/99 APF 14,617. 14,648. 10,038.83 10,050.19 3-07AIL-29 1/4/99 APF 14,515. 14,546. 10,006.79 10,015.06 3-07AIL-29 1/4/99 APF 14,595. 14,610. 10,031.08 10,036.32 3-07AIL-29 9/23/08 BPS 14,560. 14,870. 10,019.47 10,132.15 3-07AIL-29 9/23/08 PER 14,400. 14,420. 9,992.75 9,992.94 3-07AIL-29 12/27/08 BPP 14,560. 14,870. 10,019.47 10,132.15 3-07A/L-29 7/3/09 STO 14,390. 14,432. 9,993.01 9,993.54 3-07A/L-29 7/6/09 STO 6,119. 6,160. 5,566.97 5,595.25 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 • • • 3-07A/L-29 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY CTU #5 w/1.75" OD CT. Job scope - Drift w/venturi, Log and caliper, set patch. «< InterACT not publishing »> Job continued from WSR 06-30-2009. MU Wthf MHA & 2.25" OD venturi. RIH to 14,600'. Circulated across patch setting depth. POOH. MU& RIH PDS GR/CCL/24 Arm Caliper. POOH, retrieve good, Correct depth -2 ft to PDS Coil flag dated 22-Sept-08. POOH. LD PDS MEM tools. MU Wthf 13Cr "ER" packer and settinq tool assv. RIH. Taqged liner top at 12,076' CTM. Could not work past 2.875" liner top. POOH. ...Job continued on WSR 07-02-2009. ~ 7/2/2009~CTU #5 w/1.75" OD CT. Job scope - Set liner straddle assy. «< Interact not ~ ~publishing »> Job continued from WSR 07-01-2009. POOH w/lower straddle ~ j ~packer, could not get past 2.875" liner top at 12,076' CTM. POOH. MU Wthf ~ ~ ~"ER" packer w/double muleshoe. RIH. Set lower straddle packer at 14432' at 3 ~ ~center of packer, POOH, MU& R . spacer pipe and latch in to lower ~ ' ap cker' pump off and POOH, MU & RIH upper straddle packer. Tagged up @ ;14,405', could not latch into Tieback rece tp acle. POOH. Job continued on tWSR 07-03-2009. .__ ~ .~ ~ 7/3/2009aCTU #5 w/1.75" OD CT. Job scope - Set liner straddle assy. «< Interact not ~ ~publishing »> Job continued from WSR 07-02-2009. POOH. Weatherford ? ~took tools into shop to trouble shoot problem. Found that the latch on the upper ~ jTieback assy would not reach the latch profile on the Tieback receptacle._ I iWeatherford designed a ring to place on top of the latch to allow it to reach the ~ ~ ~profile in the receptacle.MU & RIH upper straddle packer. Set top straddle ~ `packer Ca~ 14391.77' middle element, POOH. '`'`'`JOB COMPLETE*'"' j **"Liner 7/4/2009~""*WELL SHUT IN ON ARRIVAL*"* ; i INITAL T/I/O: 700/1400/100. jRIGGING UP TO SET PATCH. €"""JOB CONTINUED ON 05-JULY-2009.'`'`* 7/5/2009j'"`*JOB CONTINUED FROM 04-JULY-2009."** ~SET 35.68' (ELEMENT TO ELEMENT) BAKER 9CR - 45 KB STRADDLE ~'PATCH. SET FROM 6120' TO 6155.68'. SURFACE AND VISUAL CONFIRMATION ON PATCH SETTING. OAL = 41.24', TOP OF PATCH = 6118.82', BTTM OF PATCH = 6160.06'. MIN. ~RESTRICTION = 1.83" I.D. LOCATED AT 6154.63'. ~MASTER SHUT, WING SHUT, SSV SHUT. TREECAP INSTALLED, PT. 3SWA6 SHUT. NOTIFY DSO. ~FINAL T/I/O: 650/1400/100 PSI ""'JOB COMPLETE*** ~ ~ ~ 7/6/2009 T/I/0=1370/730/30. Temp=Sl. T&IA FL. TBG FL @ 1200' (19 bbls). IA FL @; ~ 3737' sta#3 DOME (200 bbls) SV, WV=Closed. SSV, MV=Closed per DSO. IA & OA=OTG. NOVP. ; 8/2/2009 LRS T-90 - fluid support € 8/2/2009 """WELL S/I ON ARRIVAL'`** ~ SET 4 1/2" WHIDDON CATCHER SUB @ 6085' SLM. ~ ~ PULL RK-LGLV FROM STA #3 (3719'SLM/3737'MD). ; ***CONT JOB ON 8-3-09**" l 8/3/2009 T/I/0= 580/1380/100 Temp= SI Assist Slickline - MIT IA to 3000 psi PASSED Set perf and gas lift straddles) Pumped 240 bbls 60* diesel down IA to load for SSL. MIT-IA. Pumped 6 bbls diesel to pressure up IA to 3000 psi. MITIA lost 40 psi in first 15 mins, and 0 psi in second 15 mins, for a total of 40 psi in 30 mins. Bled IAP down. Bled back --30 bbls fluid. FWHP's= 1500/50/40. **"Annulus ~ casing valves tagged and left open to gauges*** SSL still on well at time of departure. 8/3/2009 '`**CONT JOB FROM 8-2-09"*' ~ LRS LOAD IA W/ 240 BBLS DIESEL. SET RK-DGLV IN STA #3 (3719' SLM/3737' MD). MIT-IA TO 3000# (PASS) ~ PULL RK-DGLV FROM STA #3 (3719' SLM/3737' MD), SET RK- LGLV IN STA # 3 (3719' SLM/3737' MD). ~ PULL BK-DGLV FROM STA #2 "'POGLM"* (6121' SLM/6149' MD). ~ ~ *""CONT JOB ON 8-4-09*"* ~ 8/4/2009 "*"*CONT JOB FROM 8-3-09**'"" ~ SET BK-OGLV IN STA #2 *"POGLM**(6121' SLM/6149' MD). ~ RUN 3.84" NO-GO CENT,2' 1 7/8" STEM, 4 1/2" BRUSH, 3.805" GAUGE RING ~ TO SSSV NIPPLE ( 1461' SLM/1487' MD). j SET 4 1/2" HES BBE SSSV SER# NBB-40B, (1461' SLM/1487' MD). , ~ PERFORM SUCCESSFUL CLOSURE TEST. ~ ""*"`WELL LEFT S/I, WELL TENDER NOTIFIED*""* ~ ~ ~ ~ i FLUIDS PUMPED BBLS 509 1 % KCL 247 DIESEL 756 TOTAL STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMf~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other ~ SET IBP Perfotattsd: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ - Exploratory '~~~~~ 1sa-147o 3. Address: P.O. Box 196612 Stratigraphic SenACe ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21911-01-00- 7. KB Elevation (ft): 9. Well Name and Number: 56 KB - 3-07A/L-29 8. Property Designation: 10. Field/Pool(s): ADLO-047502 ENDICOTT Field/ ENDICOTT OIL Pool 11. Present Well Condition Summary: / ~/ Total Depth measured 14995 - feet Plugs (measured) 14850' 14560' true vertical 10169.93 - feet Junk (measured) None Effective Depth measured 14928 feet true vertical 10149 feet Casing Length Size MD TVD Burst Collapse Structural 2502' 13-3/8" 68# L-80 SURFACE - 2502' SURFACE - 2483' 5020 2260 Surface 10222' 9-5/8" 47# NT80S SURFACE - 10261' SURFACE - 8254' 6870 4760 Intermediate 2882' 9-5/8" 47# NT95HS 10222' - 12543' 8251' - 9783' 8150 5080 Liner 2915' 4-1/2" 12.6# L-80 SURFACE - 12080' SURFACE - 9517' 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 12080 2-7/8" 6.4# L-80 12085 - 14995 Packers and SSSV (type and measured depth) 9-5/8" TIW PKR HBBP 12157' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): f 1 ~ 'L { ff t'" C'/n Sr4 f 5 a,„e,i'1~. t L~RNi`.• W L t E.. iv l<a ~.~'. 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: 250 195 5638 298 Subsequent to operation: 212 201 5957 332 14. Attachments: 15. Well Class after proposed work' copies of Logs and surveys Run Exploratory ' Development ~'' ' Service ~`u' 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 Prebl Title Data Management Engineer Signature Phone 564-4944 Date 10/6/2008 Form 10-404 Revised 04/2006 :.-.-- i~~~ Submit Original Only ~~ . 3-07A/L-29 198-1470 PFRF ~TTOrHMFNT • Sw Name Operation Date Perf Operation Code Meas De th Top Meas Depth Base Tvd Depth Top Tvd Depth Base 3-07/N-28 3/9/89 PER '~ 13,130. 13,270. 10,249.16 10,347.58 3-07/N-28 8/10/98 SQZ 13,130. 13,270. 10,249.16 10,347.58 3-07/N-28 8/12/98 AB 13,130. 13,270. 10,249.16 10,347.58 3-07A/L-29 9/13/98 PER 14,870. 14,890. 10,132.15 10,138.08 3-07A/L-29 9/13/98 PER 14,908. 14,928. 10,143.35 10,149.34 3-07A/L-29 10/23/98 BPS 0 1.4,850. 14,855. 10,126.04 10,127.58 3-07A/L-29 10/25/98 APF p' 14,705. 14,765. 10,072.57 10,097.5 3-07A/L-29 1/4/99 APF 14,515. 14,546. 10,006.79 10,015.06 3-07A/L-29 1/4/99 APF 14,595. 14,610. 10,031.08 10,036.32 3-07A/L-29 1/4/99 APF ~ 14,617. 14,648. 10,038.83 10,050.19 3-07A/L-29 1/4/99 APF 14,786. 14,794. 10,105.53 10,108.32 3-07A/L-29 9/23/08 BPS 14,560. 14,595. 10,019.47 10,031.08 3-07A/L-29 9/23/08 PER 14,400. / 14,420. 9,992.75 9,992.94 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 • • 3-07A/L-29 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIViTYDATE SUMMARY ', 9/20/2008°**** CTU 6 1.75" -IBP/Perf **** MITU - MU/RIH w/ PDS logging tools - **** Continued on 9/21/08 WSR **** 9/20/2008:****WELL S/I ON ARRIVAL****(pre ctu adperf) `PULLED 4 1/2" BBE SSSV (SER# BB-440) FROM 1487 MD "****WELL S/I ON DEPARTURE. WELL TENDER NOTIFIED OF ALL VALVE ``:POSITIONS**** 9/21/2008'°`CTU #6, IBP/PERF; Continued from 9/20/08 WSR ... RIH w/ PDS logging ``:tool. Tag TD at 14827 ctmSi. Log up to 14000 at 35 fpm -paint flag at 14375' ctmd. POH w/ log -verify good data (+16' correction). MU and RIH w/ BOT 'i' 1.69" IBP. Sat down in POGLM at 6118' ctmd. Could not pass through '' POGLM. POOH w/ IBP. Found IBP mangled. Appears IBP may have been ';:,partially inflated causing it to lodge in the POGLM. IBP may have inflated 'while filling coil prior to RIH. All rubber elements were recovered, but some of !'the metal banding may have been lost. RIH with dummy IBP. Passed ':':through POGL with no problem. POOH. MU and RIH with new 1.69" Baker 'IBP. Set IBP on depth at 14560' (saw 5k over Pump ball -let IBP !'acclimate to BHTfor 3 hrs. °**** Continued on 9/22/08 WSR **** 9/22/2008 **** CTU 6 - 1.75" IBP-Perf **** Continued from 9/21/08 WSR **** Set IBP at ';14560' -Attempt to set IBP -able to place pressure on valve but it will not ''hold, bleeds off rapidly. believe IBP still on tool after several attempts POH - 'Tag at 6120 ctmd (POGLM)- drop down pull back thru no problems. OOH w/ !'IBP -lost tea 6" i ea 1 "elements in hole. recovered all bands. Stand by for 'plan forward. RIH with 1.69" dummy IBP drift w/ 1.75" nozzle. gifted to „ 14660' ctmd. Did not see anv sian of IBP rubbers. POOH. Found original ',flag 25' deeper than originally painted due to new pipe stretch over 5 runs. !'RIH with PDS memory GR/CCL for new depth control flag. Tag at 14821 ctmd ''-Log from 14821 - 14000 ctmd -Flag pipe at 14375' - POH **** Continued on 9/23/08 WSR **** __ _ 9/23/2008' CTU #6, Log /IBP / Perf; Continued from 9/22/08 WSR ... POH with memory GR/CCL. Verify good data (+28' correction). MU and RIH w/ Baker 1.69" IBP. `i' Set IBP at 14560' Corrected depth - center elementl. Set 3 k# weight down to verify set. POOH. RIH with 20' - 1.56" HSD Power Jet HMX loaded at 6 spf. Correct depth at flag. Perforate interval 14400' to 14420' ,(Ref. Sperry -.:Sun MWD -Sept 1998). Good indication gun fired. POOH. All shots fired - RDMO **** Notify Operator of well status ***" **** Job complete **** FLUIDS PUMPED BBLS 1 diesel 1 Total • VV~~L~ ~O - T14~4/1~Sf7~~4L #~~ ProActive Diagnostic 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/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the fotlovving BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Bhrd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A.. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 22Sep08 3-07 / L-29 EDE 1) Coil Flag 2) Signed Print Name: ~=~ ~ ,~ ~ , l°~~,/~i~ /(095' ._----- 50-029-21911-01 Date ; ~~~~ P ~D 20~ ~' PROACTIVE DIAGNOSTIC SERVES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 n E-MAIL : 13ds~r~c^.~c~5ae~atca?~,:esr~s~~*71t3t3.w® WEBSITE : vt~N~,v,s'I'7rr~tss~~/9tas~.,~ar~a C:\Documenis and Settings\Owner\Desktop\Transmit_BP.doc • • 1~ 1/~~~ ~~,~ ~~~ ProActive Diagnostic Services, Inc. To: Ao~cc 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/ MTT) l~he 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 E. Denson Dlvd. Anchorage, Alaska 99508 and PraActive Diagnostic Services, Inc, Attn: Robert A. Richey 130 West International Airport: Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 ~~ ~ ~ - ~ ~. r~ i ~ »~ (~._.~ `1) ~ Coil Flag 20,Sep-D~3 3-07/L-29 EDE 2) Coil Flay 1 t3Sep-08 3-37/L-35 EDE ^, ~ Signed Print Name: ~ ~ ~ ~~,~-~~~~~ ~,~~~r.L~LIG~.-~ _~~ 50-029-21911-01 ,, ~ ;. SEf' ~, ? 2~-03 Date ti ~~~3r) II )'l l t t L ~ ? t ~ P~ltt-. -. .: ,1. 0~.'1'~~'1` ~~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, APICHORAGE, AK 99516 PHONE: (907)246-8951 FAX: {907)245-88952 E-MAIL: r~cls~nch^ract~nt~ti_ai~.~nstr3or~.cr~r3i WESSITE:~s~rrrrl.m*_anor~rlc~+_I.coEi~ n J C:\DocnmenL and SetBugs\prvucr\Uesktop~Tranvmil_HP.doc ~~ STATE OF ALASKA ,, ALASKA OIL AND GAS CONSERVATION COM~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ ~ e Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension 1C _ r , Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development (~' Exploratory 1ss-1470 3. Address: P.O. Box 196612 Stratigraphic ~' Service 6. API Number: Anchorage, AK 99519-6612 50-029-21911-01-00 7. KB Elevation (ft): 9. Well Name and Number: 56 KB 3-07A/L-29 8. Property Designation: 10. Field/Pool(s): ADLO-047502 ENDICOTT Field/ ENDICOTT OIL Pool 11. Present Well Condition Summary: Total Depth measured 14995 feet Plugs (measured) 12250' BKR IBP 7/21/07 true vertical 10169.93 feet Junk (measured) None Effective Depth measured 14928 feet ~ta~ 1~N ~ ~ ~0~~ C~ J true vertical 10149 feet Casing Length Size MD TVD Burst Collapse Structural 2502' 13-3/8" 68# L-80 SURFACE - 2502' SURFACE - 2483' 5020 2260 Surface 10222' 9-5/8" 47# NT80S SURFACE - 10261' SURFACE - 8254' 6870 4760 Intermediate 2882' 9-5/8" 47# NT95HS 10222' - 12543' 8251' - 9783' 8150 5080 Liner 2915' 4-1/2" 12.6# L-80 SURFACE - 12080' SURFACE - 9517' 8430 7500 Perforation depth: Measured depth: C 14515 - 14546 C 14595 - 14610 C 14617 - 14648 C 14705 - 14765 C 14786 - 17794 C 1 4870 - 14890 C 14908 - 14928 True Vertical depth: 9951 - 9951 9975 - 9980 9983 - 9994 10017 - 10041 10050 - 10052 10076-10082 10087-10093 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 12080' 2-7/8" 6.4# L-80 12085' - 14995' Packers and SSSV (type and measured depth) 9-5/8" PACKER TIW '12157' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: `~'S~ ~ ~ ~ ~ ~ ~S' ®~ Intervals treated (measured): Treatment descriptions including volumes used and final pressure p},qQ € p u 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SHUT-IN 101 Subsequent to operation: SHUT-IN 260 14. Attachments: 15. Well Class after proposed work' copies of Logs and surveys Run Exploratory ~ Development ~' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~'. Gas WAG ~!! GINJ WINJ ~' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 12/28/2007 • 3-07A/L-29 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYbATE SUMMARY 12/6/2007 ;Load & Transport 1 %KCL 12/6/2007 T/I/O=SSV/10/40. Temp=Sl. Prep for WH Weld. OA FL @ 30 '. Bled OAP to 0 psi in 10 mins. Pressured up OAP to 50 psi w/N2, bleed to slop trailer all gas ;returns, OAP at 0 psi. Post OA FL @ 48'. Cleaned out flutes and Starting Head ', area. Grease crew out to service valves on Wellhead. OA needs companion ';valve installed. A/L line needs to be blinded (WT will have it done). Final WHPs 'SSV/10/0. T . ~_ _. 12/7/2007T/I/O=SSV/VAC/0, Temp=SL Voidage test (verify primary seal is holding). Pre braiden head weld. External checks installed. Stung into test port to check pressure (40 psi), bled to 0 ', psi (fluid). Pressured OAP to 700 psi with gas, no pressure increase in void. Monitored void pressure for 30 min, 15 min 0 psi, 30 min 0 psi. Primary seal ', appears to be holding. 12/7/2007 T/I/0= 260/vac/0 Temp=S1 *"*Circ Out*** (Bradenhead weld) Pumped 5 bbl ':meth spear followed by 407 bbls 1 %KCL down IA taking returns up Tbg to ``flowline. Final WHPs 200/180/0 `( IA/OA casing valves open to gauges, swab shut needle valve open to gauge at ', time of departure) 12/7/2007,T/I/O=SSV/vac/10. Temp=S1. Prep for WH Weld. Assist Cameron in voidage test. Pressured up OAP to 700 psi with A/L gas. OAP lost 0 psi in first 15 mins and 0 ,psi in second 15 mins for a total loss of 0 psi in 30 mins. No pressure increase in !. 'voidage area. Bled OAP to 0 psi all gas. Final WHPs SSV/vac/0. WT out to Blind i' Flowline and A/L line. __ _ _ _ 12/8/2007;. T/I/0=220/Vac/40 Temp=S1 CMIT TxIA to 3000 PASSED on 2nd attempt. Circ ;Out (Bradenhead weld) CMIT TxIA with 22.2 bbls of neat methanol and 20 bbls of 1%KCL CMIT TxIA lost 20/20 psi in the 1st 15 min and 10/0 psi in the 2nd 15 ;min for a total loss of 30/0 psi in the 30 min test. Circ Out well bore with 380 bbls of 120" 1 % KCI by pumping into the IA taking returns up the tubing, through the ,jumper loop and into the flow line of END3-09. Final WHP's = 200/150/50 Annulus valves tagged and left open to the gauges at the time of departure. • 12/8/2007 12/9/2007 • T/I/0=10/0/10. Temp=S1. Prep for WH Weld. OA FL @ 48'. Bled OAP to 0 psi all gas. Pressured up TBG w/N2 taking returns up the IA to a bleed trailer (10 bbls of returns). TBG FL @ 120'. IA FL @ 114'. TBGP &IAP equlized at 200 psi. Final WHPs 200/200/0. . _.._.. T/I/0=60/50/0. Temp=S1. WH Welding (WH weld). TBG Q 120'. IA FL @ 160'. Purge OA w/N2, taking 02 and LEL readings. Continued to purge across OA w/N2 while WH welding procdure was preformed. There were 7 passes made on the upper starting head and 8 passes made on the lower starting head. Wrapped wellhead with heating blankets. Fire watch and monitor for 30 mins. Final WHPs =12/36/0. 12/9/2007'T/I/O = 180/140/0+. Temp SI. N2 Cap (post circ). AL line removed & blinded w/ 0 ',:psi. Flowline Blinded w/ 0 psi. Bled TBGP from 180 psi to 60 psi in 5 min, ending 'TBG FL @ 120'. Bled IAP from 140 psi to 70 psi in 5 min, ending IA FL @ 180'. ""Valve crew on location they pulled VR Plug & installed a new flange with 1/2" `needle valve opposite of the OA gate valve. Purged across the OA with N2, to a bleed trailer. Purge = a total of 2 bottles. Monitored 15 min. Final WHP's = 60/70/0. 12/12/2007 T/I/0= 0/0/0 Temp= S/I MIT OA PASSED to 1200 psi (POST WH WELD) :Pressured up OA with 2.5 bbls diesel. OA lost 40 psi in 1st 15 min and 0 psi in 2nd 15 min for a total loss of 40 psi in 30 min test. Bled pressures back to starting. Saw no indication of leaks or wetness on welded area during MITOA. Final WHPs 0/0/0 ( IA/OA casing valves open to gauges, swab shut, needle valve open to gauge at time of departure) 12/15/2007 "'*W ELL S/I ON ARRIVAL*** DRIFT W/ KJ 1.80 CENT, BULLNOSE THROUGH POGLM TO 6200'SLM RAN KJ 2 3/8 GR, BAIT SUB, BAKER PULLING TOOL, LATCHED UP IBP@ 12231' POOH IN PROGRESS **CONTINUED ON WSR 12/16/07**" • • 12/16/2007'.. ***CONTINUED FROM WSR 12/15/07"`*(post BH weld) PULLED IBP FROM 12231'SLM IBP MISSING 1 RUBBER & 1 STIFFENER RING RAN 1.80 CENT, 1.905 BLB, BULLNOSE TO 12994'SLM STOP DUE TO DEV. PULL 1" S/O GLV (BK) 28/64 FR. STA. # 2 @ 6,119' SLM. SET 1" S/O GLV (BK) 20/64 IN ST. # 2 @ 6,119' SLM SET C-SUB @ 3,818' SLM. SET 1.5" DOME GLV (RK) 16/64 1500 TRO TO STA. # 3 @ 3,716' SLM. PULL C-SUB FROM 3,818' SLM (empty) SET 4.5 BBE SER.# BB-414. 3 SETS OF STANDARD PACKING (GOOD CLOSURE TEST) **'NOTIFIED DSO OF WELL CONDITIONS LEFT WELL S/I*** FLUIDS PUMPED BBLS 22.2 NEAT METH 400 1 % KCL 422.2 TOTAL Well Compliance Report File on Left side of folder 198-147-0 DUCK IS UNIT SDI Roll #1: Start: Stop Roll #2: MD 14995 TVD 10170 Completion Date: 3-07A/L29 50- 029-21911-01 }~P EXPLORATION (ALASKA) lNG Start Stop 9/15/98 Completed Status: 1-©IL Current: Name D 8725 1-7 SPERRY GR OH L DGR-TVD FINAL 10099-10170 OH L DGR/MD FINAL 12915-14995 OH L MCNL FINAL 12600-14900 CH 5 L PROD-SPINfI'EM/ F1NAL PRES 12000-14920 CH 2 L PROD-SPIN/TEM/ FINAL PRES 1200-14920 CH 2 L RST/S FINAL 12000-14920 CH 5 R SRVY RPT SPERRY 12871.99-14921.10 OH T 8699 1 SCHLUM MCNL CH T 8923 1 SCHLUM RST CH Daily Well Ops __ -- __ Are Dry Ditch Samples Required? yes Was the well cored? yes no Analysis Description Received? yes no Comments: Interval Sent Received T/C/D no 9/23/98 9/23/98 9/30/98 9/30/98 9/30/98 9/30/98 10/1/98 10/2/98 T 12/7/98 12/10/98 12/7/98 12/10/98 11/23/98 11/6/98 T 10/15/98 10/16/98 9/29/98 10/2/98 11/23/98 11/6/98 And Received? yes no Sample Set # Wednesday, November 08, 2000 Page 1 of 1 STATE OF ALASKA ALASK,.' -'L AND GAS CONSERVATION COMMISSIC REPORT O SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.qe, Alaska 99519-6612 4. Location of well at surface 2531' NSL, 848 WEL, SEC. 8, T11N, R17E, UM At top of productive interval 5890' NSL, 2018" WEL, SEC., 5, T11N, R 17E, UM At effective depth 4909'NSL, 1953' WEL, SEC., 5, T11N, R17E, UM At total depth 4940'NSL, 1911' WEL, SEC. 5, T11N, R17E, UM 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-07A/L-29 9. Permit number/approval number 98-147 398-195 10. APl number 50- 029-21911-01 11. Field/Pool Prudhoe Oil ffo~ C ~ l '~ / ~,. _j'~ 12. Present well condition summary Total depth: measured true vertical 14995 feet 10170 BKB feet Plugs (measured) IBP plug set at 14,850' Effective depth: measured true vertical 14928 feet 10149 BKB feet Junk (measured) Naska. Oil & Gas Cons. CornmL~ Anchora§~ Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 2502' 13-3/8" 2541' 2483' 10222' 9-5/8" 10261 8254' 2882' 9-5/8" 12543 9783' 2915' 2-7/8" 125 sx Class 'G' 12119'- 15o34' 9488' - 10126' measured 14515'-14546'; 14595'-14610'; 14617'-14648'; 14705'- 14765'; 14786'-14794'; 14870'- 14890' (ALL OPEN); 14870'-14890'; 14908'- 14928' (Mechanically Isolated/Plugged) true vertical 9951'-9951'; 9975'-9980'; 9983'-9994'; 10017'-10041'; 10050'-10052' (ALL OPEN); 10076'- 10082'; 10087'- 10093' (Mechanically Isolated/Plugged) Tubing (size, grade, and measured depth) 13-3/8", 68#/ft, L-80; 9-5/8", 47#/ft, NT80S XO to NT95HS; 9-5/8", 47#/ft, NT95HS, NSCC; 2-7/8", 6.4#/ft, L-80, ST-L Packers and SSSV (type and measured depth) 9-5~8"packer TIW (HBBP) @ 12157'; SSSV @ 1487' 13. Stimulation or cement squeeze summary Add perforations,(1/04/99) Intervals treated (measured) Perforate 14515'-14546'; 14595'-14610'; 14617'-14648'; 14786'-14794'(MD) Treatment description including volumes used and final pressure (see attached) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 812 97 3965 0 1726 1330 4793 0 4O8 422 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas__ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. , ... , .(,. .-~ ~ /' :Form 10-404 Rev 06/15/~88/ %_/ Date SUBMIT IN DUPLICATE WSA- Well Operations Telex To: From: Re' Anchorage Engineering Luecker Endicott 3-07 Perf Ops. 1/1/9,,8'?1/4/9~ Date: January 1, '1999 Summary Rigged up and RIH with PDS GR/CCI toolstring.. POP w/o'gaslift in attempt to achieve the same flowing conditions of 500-1000 psi drawdown while perforating. Ran PDS log from TD of 14822 coil depth to 14000. PDS log give corrected TD @ 14852.5. Place flag @ 14500 CTD. 1-2-99 RIH with gun #1, a 8' gun. All guns are 1 11/16", 4 spf, loaded with 20j charges. 0 degee phasing. Tagged plug, corrected depth and pulled up to 14786-14794 interval. Saw pressure increase to 2200 with 36 bbls away. Pressure only fell to 1900, increased rate and saw firing head shear @ 2730 and fall. For safety considerations increased rate to get coil pressure up to 3800. S/D pump and POOH. All shots fired. RIH with gun #2, a 31' gun. Tagged plug and pulled to 14617-14648 interval. Gun fired at 3800. POOH, all shots fired. 1-3-99 Pick up gun #3. Packoff failed during pressure test. RD lubricator and c/o. RIH, tagged, and pulled to 14595-14610 interval. Gun fired with 3340 coil pressure. POOH, all shots fired. RIH with 31' gun. Tagged, pull to 14515-14546. Gun deployed with 2800 coil pressure. POOH, all shots fired. Blow down coil with N2 and RD. Time Operation 1-1-99 08:00 MIRU Camco 4932 ctu, ctv-38.4 bbl. 500k running feet of 17.2k feet 09:45 Safety meeting. 10:30 Make up Radius BHA., Make up PDS depth odometer. Pull test 15k. Pressure test BHA to 4000. 11:15 Make up PDS toolstring. 11:45 Pressure test 4000. 12:00 RIH, SIWHP-1100, IAP-1900,OAP-200. Bring well on w/o liftgas. 1-2-99 06:00 Safety meeting, pick up gun #1. All guns are I 11/16" 4 spf, loaded with 20J charges, o degree phasing. 07:15 RIH, FWHP-300,FWHT-53, lAP-1200 1-3-99 06:00 Pick up gun#3, a 15' gun. 06:45 Pressure test lubricator. Packoff failed. RD lubricator and set injector head on deck. 09:10 Pull test new coil connector 15k. Press test 4000. 09:45 Pick up gun #3 again. 10:00 Pressure test 2000. 10:10 Safety meeting. RIH, FWHP-370, FWHT-159, IAP-1420, OAP-200 Time Depth CTP WHP Vol. 12:50 5000 0 310 0 9.3k up wt., FWHT-84. 13:50 12000 300 330 0 211<: up wt. FWHT-82. 14:10 14000 360 330 0 231<: up wt. FWHT-77. Pause and then log down 40 fpm. 14:30 14500 360 330 0 Pause 14:37 14820 320 335 0 Tag TD 14820.5' ctd up, 14829' ctd down, pause, log off, place flag @ 14500' 17:20 0 20 310 0 OOH, rig back for night. FWHT-70. PDS log puts top of plug @ 14851.5' 1-2 08:45 10200 100 340 0 S/I liftgas. FWT-123. 09:20 14806 80 313 0 Tag plug, reset depth to 14843.4 top shot (1482.5-9.1) 10:35 14786 315 36 Ball or trash on seat. Sheared @2730 after 42 bbl pumped. 10:45 14786 2700 315 42/0 Switch to meth to f/p coil on reel 10:50 50 320 8/0 POOH. Put liftgas on. 13:10 0 30 35 0 OOH, all shot fired. Pick up gun #2, top shot - bottom of gun- 32.4' 16:05 10800 20 310 0 S/I lifgas. 131<: up @ 12000. 16:41 14819 60 305 0 Tag TD, set counter to 14819.1, top shot, drop ball. Pull to 14617- 14648. 17:05 14617 570 310 0 Start with filtered water. 17:14 14617 530 310 18 Switch to meth 17:20 27 Caught f/t. 17:22 870 320 32 Decrease rate to .75 bpm. 17:27 310 35 Catch pressure. 17:35 3800 320 40 Pressure drop 17:47 320 57 coil/p'd 19:55 0 60 320 0 OOH,all shots fired. 1-3-99 12:00 12000 193 372 0 S/I liftgas. 19.51<: up @ 12000. 12:30 14813 480 315 0 Tag, drop ball, pull to corrected depth of 14595. 13:10 14595 520 320 32 Slow rate to .75 bbl. Swap to meth. 35 bbl. Caught ball @ 36 bbl. 13:17 14595 3340 315 38 Gun deployed, pump 4 bbl more meth POOH. 1400 12000 20 347 0 liftgas on 21k up @12000 15:40 0 20 360 0 OOH, all shots fired. Pick up gun #4, top shot - bottom of gun- 32.4' 16:30 0 20 380 0 RIH with gun #-4 18:45 13700 80 330 0 S/I liftgas, appears getting hydraulically locked out of 2 7/8" with LG on. 19:00 14020 70 310 0 Pull out of 2 7/8" liner 19:22 14826 80 310 0 Reset 14820.1, pull to 14815-14846, drop ball. 20:29 14815 1930 300 25 Catch f/I. Dcrease rate to 1.4 20:37 670 300 34 Ball on seat. Sheared @ 2800 ps~. 20:42 1600 300 42 POOH 21:24 11200 20 320 Put liftgas on. 23:00 0 10 300 OOH, all shots fired. Start cooling down N2. 23:30 0 Pressure test Dowell lines. Start N2 blowdown. 1-3 00:00 0 1870 25k Still fluid at lubricator. 00:10 0 1750 35k All N2, Blow down coil. 01 ;00 RD coil. Fluids Summary Fluids Pumped BBLS. 61 98 Description methanol SW End 3-07 01/12/99 Page 2 I 159 I Total Fluids Pumped Perf Summary Perforated the following intervals with SWS's 1.58" scallop guns. 4spf loaded with 20J charges. 0 degrees phasing. Depths are referenced to SWS RST log of 10-24-96. 14515-14546 14595-14610 14617-14648 14786-14794 BHA #1 Tool string Description II O.D. II I.D. II Length II Comments Fishing Neck 1.90" .92" .24' Check Valve .75 Hydraulic Disconnect .625 5/8" ball. Blind Circ sub 1.71' Ported Sub/crossover .47' Radius total-2.415' PDS ccl/gr/s/p/t 1.69 11.65' 10.56' cci- top os toolstring, 3.50' cci- bottom of ts. Total Length t3.07' BHA #2, 3, 4 Tool String Descriptions O.D. I.D. Length Comments Radius CTC, checks, 1.70" 0.75 2.42 1.90" No Go disconnect 5/8" Ball Firing head, crossover 1.69" .50" 3.42' %" Ball 1 11/16" gun 1.56" 11.80 Coil connector to top shot-6.1' Top shot to bottom of gun-9.1'(gun#1 ), 31.1' (gun #2 and 4), 16.1' (gun#-4). 17.64' Total Tool string End 3-07 01/12/99 Page 3 12/7/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 12139 Company Field: Alaska Oil & Gas Cons Corem Attn: Lorl Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) Well Job # Log Description Date BL Sepia LIS Tape 3-07A/L-29 PRODUCTION PROFILE 981028 1 I 4-14/R-34 f~l ~ INJECTION PROFILE 981031 1 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND' RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: , , ,RECEIVED DEC 1.0 1998 .... , *.. [ iiiii Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie STATE OF ALASKA ALASK/ -"L AND GAS CONSERVATION COMMISSI("" REPORT O, SUNDRY WELL OPE ,ATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Pull tubing Alter casing __ Repair well __ Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.~Te, Alaska 99519-6612 4. Location of well at surface 2531'NSL, 848 WEL, SEC. 8, T11N, R17E, UM At top of productive interval 5890' NSL, 2018" WEL, SEC., 5, T11N, R17E, UM At effective depth 4909' NSL, 1953' WEL, SEC., 5, T11N, R17E, UM At total depth 4940' NSL, 1911' WEL, SEC. 5, T11N, R17E, UM 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-07A/L-29 9. Permit number/approval number 98-147 398-195 10. APl number 50- 029-21911-01 11. Field/Pool Duck Island Unit/Endicott 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length 2502' 14995 feet 10170 BKB feet 14928 feet 10149 BKB feet Plugs (measured) Junk (measured) IBP plug set at 14,850' Size Cemented Measured depth True vertical depth BKB BKB 13-3/8" 2541' 2483' 10222' 9-5/8" 10261 8254' 2882' 9-5/8" 12543 9783' 2915' 2-7/8" 125 sx Class 'G' 12119'- 15o34' 9488' - 10126' measured 14870'- 14890'; 14908'- 14928' (Mechanically Isolated/Plugged) 14705'- 14765' (OPEN) true vertical 10076'- 10082'; 10087'- 10093' (Mechanically Isolated/Plugged) 14705'- 14765' (OPEN) Tubing (size, grade, and measured depth) 13-3/8", 68#~fl, L-80; 9~,5/8", 47#/ft, NT80S XO to NT95HS; NT95HS, NSOC; 2-7/8,6 4#~fl, L-80, ST-L Packers and SSSV (type and measured depth) 9-5~8"packer TIW (HBBP) @ 12157'; SSSV @ 1487 Stimulation or cement squeeze summary Set bridge plug, addperforation,(10/25/98) Intervals treated (measured) IPB set @ 14850'; Perforate 14705' - 14765' (MD); r~, · Treatment description including volumes used and final pressure ~' ..... 13. 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure n/a n/a n/a n/a 2792 6024 4426 0 Tubing Pressure n/a 4O5 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. · . ', , ~ ~ i Signed '~i~,'¢~ ¢~r~-'~r/~)k--~ 1 '~' 'k~~-L l~,_.~..~ Q~[ Title ~,nior Technical Assistant IV [562-5234} Date 11/23/98 Form 10-404 Rev 06/1'5)/88 SUBMIT IN DUPLICATE , To: , Anchorage Production ]ineering ! ition: Endicott From: Bundy I Quesenbury I Murphy Operation: 3-07a/L-29 CT E-Line Logging - Set IBP - Perforate Cost Code: ~ ,,-- AFE' 727028 P ~'(,..-,,-- 9335 - 070 -770 Job Id: n/a Detail Code: Sidetrack /CTU E-Line Logging I xxx Summary 10/22-25/98 MIRU DS CTU #2 with an external reel package configured with 1.75" e-line pipe. Rig up SWS. RIH with 'RST / PST' logging suite. Log 'RST' in sigma mode @ 60 fpm from TD @ 14,900' to 12,000'. Logged 3 passes in 'CO' mode @ 3 fpm from TD to +/-13,000'. Logged repeat pass in sigma mode @ 30 fpm from TD to 12,880'. Put well on production. Logged 'PST' up and down passes @ 40, 60 and 80 fpm with repeats at 60 fpm and stop counts at 14,775', 14,825' and 14,875'. POH. Logs indicated that the well was perforated in a water bearing interval. No apparent contribution was coming from the area of the 2 7/8" liner top. Logs also indicated that there is oil beadng intervals above the current perforations. Logs were reviewed in town and the decision was made to plug back the well and perforate up hole from 14,705' to 14,765'. 10/26/98 RIH with HES 2 7/8" CIBP and set at 14,850' (above current perforated intervals). Open well to flowline with gas lift shut in. RIH with Gun #1 (20' 1-11/16"). Shoot interval 14,745' to 14,765'. POH. All shots fired. RIH with Gun #2 (20' 1-11/16"). Shoot interval 14,725' to 14,745'. POH. All shots fired. Gun at surface indicates oil in wellbore. RIH with Gun #3 (20' 1-11/16"). Shoot interval 14,705' to 14,725'. POH. Gun did not fire. Fault was found to be the fidng head. DS #2 off 24 hour operation- rig back for the evening. Put well on production with gas lift. 10/27/98 - RIH with Gun #3 (20' 1-11/16"). While RIH at 5200', lost signal from CCL. Attempted to trouble shoot, but appeared to be an intermittent short at the tool. POOH. At surface, e-line had pulled out of logging head. Perform additional slack management and cut 50' of coil from string. Re-headed and ran back in hole with Gun #3 (20' 1-11/16"). Shoot interval 14,705' to 14,725'. POH. All shots fired. Rigged D-S equipment off tree, and returned well to oil board control flowing into the test separator. 10/28/98 Rigged down D-S equipment. Perforated interval 14,705' - 14,765' ApF Ref. Log: Sigma RST (10/23/98), Run #1 - File 12 Time Operation 10/22 1930 Pre-job Safety Meeting with Endicott personnel 2100 MIRU DS CTU #2 with external reel package ( 16,000' of 1.75" tubing. CTV = 32.6 bbls) and support equipment 10/23 0100 Stab coil into injector 0230 Stab BOPE's. Stab injector in prep for slack management 0330 RU hardline to reel and backside lines. Safety Meeting 0745 Load lines with methanol. PT to 4000 psi 0840 Begin slack management ... reverse MeOH into coil (2100 psi) ( 72 bbls total MeOH) Stop pump / bleed off 0925 W.O. Peak to fix fiats on remote reel lowboy. Re-do iron to use Micro-motion and block up front of remote reel 1040 Break off injector, 6 ft. Of E-Line cable still out CT. Cut off same. MU c-roll and nozzle. RU to WH 1130 PT to 4k. Re-pump cable ( 66 bbls MeOH). Bleed off, break off nozzle. E-line cable at end of CT. 1421 SWS MU head to e-line 1655 Head on with good signal. PU lubricator. MU logging tools (BHA#1) Fit oF Operation: 3-07a/L-29 CT E-Line Lo,.._~_..j - Set IBP - Perforate Page: 2 I 250 I 0 I 1900 I 250 I 9s I Time Depth Rate Ctp Whp Total Remarks ft bpm psi psi bbls 1830 surf 0 50 0 138m RU to wellhead (methanol total from slack management above) 1833 0.50 3000 3000 2m PT lubricator and all surface lines to 3000 psi 1902 0 198 165 RIH w/logging tools. WIND: 45+ mph 2005 5000 70 180 Wt. check 11.5k up 2105 10200 340 177 Wt. check 20kup 2130 12200 440 180 Passed through 2-7/8" linertop with no problem, continue RIH. WIND: 50+ mph 2145 13300 450 178 At the top of the "Hill". Weight check - 25k up 2210 14700 400 176 Over the "Hill", Weight check - 26k up 2220 14892 416 179 Tagged TD at 14903' ctmd. PU ¢_.. 14892' ctmd. Stop - prep to log. 2232 438 180 PUll logging RST (sigma porosity) and PSP @ 60 fpm. Pass #1 2321 11900 60 185 End logging pass. RIH to TD. 2338 13244 67 177 Sat down at 13244'. PU at 13226' - 24K up weight. RIH passed through OK. Packoff?? 2343 13380 70 180 Sat down at 13380' (Top of"hill"). PU weight good. Theory: wind is blowing lubricant out of pack-off. WIND: 45+ mph. RIH - OK .::10124:: : :' ' : .............. :.:::~.-::..:~ ......... . ............................. '::',ii..:-.." ...... ::~:':':':"~':~:':~'::~":::~'~":":"~:' : : :::::,: : "~'~ ::' .: :' "-'": '".: .:' ::: :' : :~ : 0003 14892 400 180 At TD - 14900'. PU heavy off bottom - 32k. Pipe won't move. Work pipe- appears to be packoff problems. PUH. Pipe moving but slightly erratic. 0040 14898 370 180 Begin Pass #2 up at 3.6 fpm 1008 12783 410 190 End Pass #2, RIH, wind died down 1037 14892 445 200 Begin Pass #3 up at 3.4 fpm 1728 13395 200 200 End Pass #3, RIH 1753 14890 200 200 Begin Pass #4 up at 3.4 fpm 0120 13550 70 190 End Pass#-4, RIH 0132 14888 70 190 Begin logging up hole at 30 fpm 0242 12880 0 190 End pass, open g/I, PUH to 4.5" tubing 0300 11900 0 190 Park coil, begin flowing well 0504 11900 60 900 RIH 0513 12312 60 580 Park coil, PUH, open choke further 0522 11900 60 610 RIH logging 80 fpm 0601 14880 63 520 Log up at80 fpm 0606 14700 63 520 Stoplog, RIH 0611 14880 60 530 Log up at40 fpm 0616 14700 60 540 Park coil 0623 14700 60 550 Log down at40 fpm 0631 14880 60 550 End pass, log up at 60 fpm 0635 14700 60 550 End pass, log down at 60 fpm 0641 14880 60 550 End pass, log up at 60 fpm 0648 14775 60 550 Stop count 0651 14825 60 550 Stop count 0657 14875 60 550 Stop count 0703 14875 60 500 Begin logging up at 60 fpm Operation: 3-07a/L-29 CT E-Line Lc g - Set IBP - Perforate ? Page: 3 0754 11800 End logging pass 0812 11380 1600 1100 Park coil, flood filters with MeOH 0827 1600 1100 Problems with filter pod, hand load filter pods (not enough hydrostatic from tank) 0917 11380 0.4 400 1500 Om POOH pumping MeOH 1109 surf 0 1500 1500 37 OOH, close swab, bleed down 1130 Rig off SWS logging tool sting 1205 surf Call for radio silence on pad 1210 Make up BHA #2- Halliburton tool sting ( bridge plug) 1225 PT lubricator to 2000 psi- OK 1232 surf 1460 1460 Open swab and RIH, IA-1500 psi, OA-0 psi, FLP-200 psi, FLT-120° F 1305 1100 1500 1470 Release radio silence 1356 6500 1490 1460 Wt. check 13k up, 8.7k down, open wing and begin bleeding WHP 1424 8975 1400 1370 Park coil, chain on spooling reel attempting to back out, call for parts 1540 1060 1010 Parts on location, repair chain 1617 990 930 Chain repaired, continue RIH 1646 12000 840 780 Wt. check 22k up, 11.2k down 1700 12040 800 740 Begin tying in to liner top 1735 14000 650 590 Wt. check 25kup 1747 14920 Begin up pass to check tie in 1758 14800 On depth, RIH to set depth 1803 14850 Set top of bridge plug at 14850' 1808 390 460 Pull up hole 1809 14800 RIH andtag 1811 14850 380 450 Tag bddgeplug, POOH 1902 12000 490 540 Park coil for safety stand down meeting 1950 12000 0.4 480 620 Om Start POH. Pump MeOH at min. rate for slack management. 2130 200 0 140 495 33m At 200' ... call for radio silence. Continue POH. 2142 surf 140 520 At surface. Close swab (24 turns). Bleed down. Break off lubricator. 2200 surf 0 0 Break off BP setting tool. Looks good. 2235 surf Safety Meeting 2240 surf Power down. Make up SWS firing head and Gun #1 (BHA #3). 2300 surf 2500 PT lubricator to 2500 psig 2313 surf 250 310 RIH with Gun #1 (20') 10126: 0112 11990 205 300 Weight check - 21k# 0118 12215 208 295 Stop. PUH logging to tie-in with liner top. 0125 14869 204 290 Stop. RIH to bottom. 0200 14814 195 300 Tagged TD @ 14,845' (14,814' cci depth + 31' of tool). 0208 14814 190 295 PUH Iogging to tie-in 0213 14625 190 295 Stop. Run back in hole to TD. 0220 14827 190 305 Tag TD at 14,812'. Make depth correction of + 15'. 0224 14742 185 305 PUH to shooting depth. Gun #1: CCL @ 14,742'. Top shot @ 14,745'. Bottom shot @ 14,765' 0230 14742 185 300 IA- 500 psig, OA- 100 psig, WHP= 300 psig, WriT = 60 deg F 0232 14742 185 300 Well is open to flowline pressure. Fired gun. Good indications at surface. 0233 14742 185 300 17m POH with Gun #1. Pump slack management as necessary. 0455 surf 105 270 At surface. Close swab (24 tums). Bleed down. Break off lubricator. 0510 surf Break down gun. All shots fired. Operation: 3-07a/L-29 CT E-Line Lo~,~_ ,,j - Set IBP - Perforate ~-- '~ Page: 4 · 0535 surf Power down. Make up SWS fidng head and Gun #2 (BHA #-4). 0550 surf 2500 PT lubricator to 2500 psig 0605 surf 210 235 RIH with Gun #2 (20') 0759 11830 440 260 Wt. check 20.8k up, 12k down 0839 14827 500 240 Tag top of plug, begin logging pass up 0859 14723 420 250 Tied in on depth (+14' correction), Gun #2' CCL @ 11723'. Top shot at 11,725'. Bottom shot @ 11745', IA-500, OA-0, FLP-275, FLT-61° 0904 420 250 Good indications that gun fired on surface, log up 0910 11600 0.3 700 270 Om POOH pumping methanol down coil for slack management 1132 1000 650 270 44 Call for radio silence on SDI 1140 200 0 280 280 47 SAFETY MEETING 1150 270 270 Finish POOH 1200 surf 260 245 At surface, close swab, bleed down, dg back 1230 All shots fired, gun covered with oil, put on Gun #3 1248 2000 2000 lm PT lubricator down backside to 2000 psi- OK 1300 surf 280 220 Open swab, RIH 1315 1000 280 220 Release radio silence on SDI 1448 11500 160 250 Wt. check 19.5k up, 12.7k down, log down counting collars 1524 14820 130 250 Tag top of plug, 22.2k up weight 1531 130 250 Begin tie-in pass at 40 fpm 1538 14700 130 250 Correctto CCL depth (+14'), RIH 1542 14808 125 250 PUH to set depth 1554 14703 130 250 Attempt to fire gun, no good indication at surface gun fired, Gun #3 'CCL @ 11703'. Top shot at 11,705'. Bottom shot @ 11725' IA-500, OA-0, FLP-310, FLT-69° 1556 14703 0.4 130 250 Om POOH logging up, online with MeOH for slack management 1559 14600 800 280 POOH 1812 1000 0 300 280 39m Out of fluid, shut down pump 1816 800 280 280 Call for radio silence on SDI 1833 surf 250 290 OOH, close swab valve, begin bleeding down 1845 Gun #3 did not fire, rig off gun, 3 polar bears heading down causeway toward SDI 1900 SWS determined that the fidng head was at fault. Decided to dg down for the night and return in the morning for the final gun run. 1945 300 Open gas lift. Well on production. FWHP- 300 psig, FWHT- 87 o, IA- 550 psig and climbing (GL), OA- 0 psig 2000 Secure location. Leave it for the bears. 0700 Om AOL, well flowing 6000+ bpd flow rate on gas lift, begin rigging up 0725 Check for continuity through logging head 0750 Call for radio silence on SDI, Safety Meeting 0806 Arm gun #3 0825 surf - 2500 2500 3m PT all surface lines to 2500 psi 0833 180 370 Open swab, RIH with repeat of BHA #5 (with a new firing head) 0839 300 120 390 Release radio silence for SDI 0925 5200 80 380 Lost signal from CCL, PUH attempting to see if signal returns, reboot SWS computer 0930 5080 80 300 Park coil, check collector ring 0940 4930 80 320 Still no good signal, continue investigating Operation: 3-07a/L-29 CT E-Line Lo .~ - Set IBP - Perforate ~' Page: 5 1058 5450 0.3 75 320 Om Appears to be intermittent short downhole, POOH pumping MeOH for slack management 1145 800 0.3 350 310 Call for radio silence on SDI 1153 surf 0 400 300 17m OOH, close swab, bleed down 1215 E-line cable pulled out of logging head, release radio silence on SDI 1320 1.5 20 3700 Om Begin pumping MeOH down backside for slack management 1340 0 0 0 30m Shut down pump, cut off 50' of coil, put on roll-on TC and nozzle 1433 1.5 3800 20 Om Begin pumping down coil with MeOH 1455 0 0 0 30m Shut down pump, dg off and begin cutting pipe looking for cable 1507 Cable at nozzle, begin re-heading process 1637 Perform shoot through on head - OK, standby on rig-up due to bear in vicinity of SDI 1648 Radio silence on SDI, arm gun #3 1707 surf 2000 2000 PT lubricator to 2000 psi 1715 230 390 Open swab, RIH with BHA #5 again IA-1800 psi, OA-200 psi, FLP-360 psi, FLT- 140° F 1723 250 360 360 Release radio silence on SDI 1917 11900 150 330 Wt. check 20.2k up, 11.2k down 1950 14820 90 330 Tag top of plug, 20k up weight 1952 90 330 Log up at 40 fpm 2002 14550 100 340 Correct to CCL (+21'), can't go done, PUH 2010 14400 200 600+ Wing in choke, RIH to plug 2022 14836 280 1000 Tag plug, PUH to shoot depth, reopen choke 2025 14703 200 310 On depth with CCL, fire gun #3, weight change on weight indicator, only indication of good shot, Gun #3: CCL @ 11703'. Top shot at 11,705'. Bottom shot @ 11725', IA-1750, OA-200, FLP-300, FLT-130°F 2027 200 310 Log off from shoot depth 2033 14550 0.4 200 310 Om POOH, begin pumping MeOH for slack management from tank used for slack management fluid 2250 800 .5 800 410 Call for radio silence on SDI 2300 200 0 350 340 60m Out of MeOH, power down SWS logger 2313 surf 230 400 OOH, close swab, bleed down 2322 - Gun #3 fired, rig off BHA and begin rig down 2335 - Rig down BOPs and secure wellhead ::10/28 ::::: :i': : :ii: "..:': - :..' -':!:-::!:.::.i:'.'::':~';'.'i.':-i:?'. ................ ',:~:::,.,. i..:.-':':; :.'.'"::-' ,i ~: :::i:. -..:.!::.:,:~::i:.:':"-i.:':::'-..':::~::!' , , 0100 Wellhead secured and well flowing to test separator, crew off location 0800 Rig down D-8 equipment 1300 Rig down complete, D-S to yard to swap reels Final Well Status Fwhp lap 0ap GIp FIp Fit , .. psi psi psi psi psi °F 420 1750 250 1650 460 144 Fluid Summary MeOH Total ~Operation: 3-07a/L-29 CT E-Line Lo., ..... ,1 - Set IBP - Perforate Page: 6 SWS Logging String Bottom Hole Assembly #1 Tool String Descriptions O.D. I.D. Length Comments SWS CTLH (logging head) 2.0 6.0 SWS PSPT-A 1-11/16"13/16 8.0 Production Services Platform Tool (Temp, GR, COL) SWS PILS-A 1-11/16" 2.60 Spinner SWS RST-A 1-11/16" 23.00 Reservoir Saturation Tool Total Length 39.6 Bridge Plug String Bottom Hole Assembly #2 Tool String Descriptions O.D. I.D. Length Comments SWS CTLH (logging head) 2.0 6.0 SWS CCL 1-11/16"13/16 1.5 Halliburton Firing Head 2.0 0.41 Halliburton running tool 2.0 7.54 Halliburton 2-7~8" Model M Bddge plug 2.19 1.0 element to CCL- 9.08' Total Length 16.45 SWS 1-11/16" Scallop Gun (20') Bottom Hole Assembly #3 Tool String Descriptions O.D. I.D. Length Comments SWS CTLH (logging head) 2.0 6.0 SWS CCL 1-11/16" 1.5 CCL to Top Shot = 3.0 SWS Firing Head 1-11/16" 1.4 20' 1-11/16" Scallop Gun 1-11/16" 21.5 XO 1-11/16" 0.1 Blank 1-11/16" 6.5 Bullnose 1-11/16" 0,2 Total Length 37.2 SWS 1-11/16" Scallop Gun (20') Bottom Hole Assembly #4 Tool String Descriptions O.D. I.D. Length Comments SWS CTLH (logging head) 2.0 - 6.0 SWS CCL 1-11/16" 1.5 CCL to Top Shot = 2.0 SWS Fidng Head 1-11/16" 0.5 20' 1-11/16" Scallop Gun 1-11/16" 21.5 XO 1-11/16" 0.2 Blank 1-11/16" 0.6 Bullnose 1-11/16" 0.2 Total Length 30.5 SWS 1-11/16" Scallop Gun (20') Bottom Hole Assembly #5 Tool Stdng Descriptions O.D. I.D. Length Comments SWS CTLH (logging head) 2.0 - 6.0 SWS CCL 1-11/16" 1.5 CCL to Top Shot = 2.0 SWS Firing Head 1-11/16" 0.5 · Operation: 3-07a/L-29 CT E-Line Lc....__ .~ - Set IBP - Perforate Page: 7 20' 1-11/16" Scallop Gun 1-11/16" 21.5 XO 1-11/16" 0.2 Blank 1-11/16" 0.6 Bullnose 1-11/16" 0.2 Total Length 30.5 B.~'~.~i!lii ,:~iE~:~ Jt GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'rN: Sherrie NO. 12087 Company Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) 11/23/98 Well Job # Log Description Date BL Sepia LIS Tape 3-07A/L-29 '--+~ ~ {'Z~ '~') 98597 RST 981024 i 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 3940 Arctic BIvd AA n. fl.CNh,, o rs~ ge r~ieA: 9p3' R e c eiv ~by..~.--- ,"~ "'~~.,/,,'~/(.,)'~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND 1. Status of Well Classification of ~e~v~¢~_,~,_',_[;Ol'18, Corl[t~l~ [~ oil [~ Gas I-~ Suspended [~ Abandoned I~ Service ~"ul~,l'lOl~,~p, "'-" 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-147 398-195 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21911-01 4. Location of well at surface ! ,:ii;: i.~:~.:. :~i;~;.~ !~~ 9. Unit or Lease Name Duck Island Unit/Endicott 2531' SNL, 848 WEb, SEC. 8, T11N, R17E, UM .... ~ i: .~¢t~.._'~2.. ~ i10. Well Number At top of productive interval ! ~-~"~'"~- ~,~"" i !i~ 4890, NSL, 2018' WEb, SEC.5, T11 N, R17E, UM ~! ~.}i:~ ! *',~ ...._ 3-07A/L-29 At total depth ~ ~~ i11. Field and Pool 4940' NSL, 1911 WEb, SEC. 5, T11 N, R17E, UM ~ Endicott Field / Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 56'I ADb047502 12. Date Spudded8/29/98 113' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' ? °ffsh°re 16' N°' °f C°mpleti°ns9/9/98 9/15/98 6 - 12 MSL One 17. Total Depth (MD+TVD) 118. Plug B~ck Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 14995 10170 FTI 14928 10149 FTI [~Yes l--INoI N/A MD 1465' (Approx.) 22. Type Electric or Other Logs Run MwD 1"'t D 1 kl A I 23. CASING, LINER AND CEMENTING RECORD U I ~ I U I i '~ /--~ g CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 2-7/8" 6.4# L-80 12080' 14995' 3-3/4" 125 SX Class 'G' ....... 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 1-11/16" gun diameter, 4 spf N/A MD TVD MD TVD ..... 14870' - 14890' 10132'-10138' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 14908' - 14928' 10112'-10105' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12906' Kick-off depth Freeze protect with 7.5 bbls diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) September 18, 1998I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-MCF iWATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing ;Casing Pressure CALCULATED OIL-BBb GAS-MCF WATER-BBb OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Kekiktuk Zone K2A 14781' 10103' Kekiktuk Zone 2300F 14594' 10031' Kekiktuk Zone 2350C 14568' 10022' 31. List of Attachments Summary of Daily Drilling Reports, Survey Signed ! (~/~,~.~-~ Title Drilling Superintendent D 3-07A/L-29 ~ ~,,--c/ 98-147 3¢8-195 Prepared By Name/Number: Carol Withey, 564-4114 Well Number Permit No. / Approval 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5-' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility End SDI Well 3-07A/L-29 Rig ~ Page 1 Date 29 September 98 Date/Time 25 Aug 98 16:30-18:00 18:00-18:30 18:30-20:00 20:00-22:00 22:00-00:00 26 Aug 98 00:00-01:30 01:30-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-18:00 18:00-18:30 18:30-21:30 21:30-22:30 22:30-23:30 23:30-00:30 27 Aug 98 00:30-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-15:30 15:30-16:30 16:30-18:00 18:00-18:30 18:30-21:00 21:00-21:30 21:30-22:00 22:00-03:00 28 Aug 98 03:00-06:00 06:00-06:30 06:30-09:00 09:00-13:00 13:00-13:30 13:30-14:00 14:00-18:00 18:00-18:30 18:30-02:30 29 Aug 98 02:30-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-09:00 09:00-10:00 10:00-10:30 10:30-11:00 11:00-14:30 14:30-16:30 16:30-18:00 18:00-18:30 18:30-23:00 23:00-23:30 23:30-06:00 30 Aug 98 06:00-06:30 06:30-09:00 Duration 1-1/2 hr 1/2 hr 1-1/2 hr 2hr 2hr 1-1/2 hr 3-1/2 hr lhr 1/2 hr lhr 10-1/2 hr 1/2 hr 3hr lhr lhr lhr 4-1/2 hr lhr 1/2 hr lhr 8hr lhr 1-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 5hr 3hr 1/2 hr 2-1/2 hr 4hr 1/2 hr 1/2hr 4hr 1/2 hr 8hr 3-1/2 hr 1/2hr 1-1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 1/2 hr 3-1/2 hr 2hr 1-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 6-1/2 hr 1/2hr 2-1/2 hr Activity Rig moved 40.00 % Held safety meeting Rig moved 50.00 % Rigged up Additional services Rig waited': Other delays Skid rig Skid rig Retrieved Hanger plug Held safety meeting Removed Wellhead primary components Rigged up BOP stack Held safety meeting Tested BOP stack Retrieved Hanger plug Rigged up Bell nipple Made up BHA no. 1 R.I.H. to 12902.0 ft Circulated at 12880.0 ft Held safety meeting Functioned downhole tools at 12875.0 ft Milled Casing at 12906.0 ft ~ Held safety meeting Pulled out of hole to 10100.0 ft Held safety meeting Pulled out of hole to 27.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 12906.0 ft Milled Casing at 12909.5 ft Held safety meeting Milled Casing at 12911.0 ft Pulled out of hole to 21.0 ft Pulled BHA Made up BHA no. 3 R.I.H. to 12900.0 ft Held safety meeting Milled Casing at 12916.0 ft Pulled out of hole to 6200.0 ft Held safety meeting Pulled out of hole to 20.0 ft Pulled BHA Serviced Top drive R.I.H. to 945.0 ft Circulated at 945.0 ft Pulled out of hole to 0.0 ft Rig waited: Equipment Fished at 12930.0 ft Made up BHA no. 4 Held safety meeting R.I.H. to 12890.0 ft R.I.H. to 12916.0 ft Drilled to 13074.0 ft Held safety meeting Drilled to 12125.0 ft Progress Report Facility End SDI Well 3-07A/L-29 Rig ~ L~)-i~ Page 2 Date 29 September 98 Date/Time 09:00-11:00 11:00-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-23:00 23:00-23:30 23:30-06:00 31 Aug 98 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-20:00 20:00-20:30 20:30-06:00 01 Sep 98 06:00-06:30 06:30-07:00 07:00-07:45 07:45-08:00 08:00-13:00 13:00-14:00 14:00-14:15 14:15-17:15 17:15-17:30 17:30-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-20:30 20:30-21:00 21:00-22:30 22:30-23:00 23:00-04:00 02 Sep 98 04:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 03 Sep 98 06:00-06:30 06:30-07:00 07:00-08:00 08:00-08:30 08:30-09:00 09:00-18:00 18:00-18:30 18:30-04:30 04 Sep 98 04:30-04:45 04:45-06:00 06:00-06:30 06:30-10:30 10:30-11:30 11:30-12:00 12:00-12:45 Duration 2hr 5-1/2 hr lhr 1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 6-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 9-1/2 hr 1/2 hr 1/2 hr 3/4 hr 1/4 hr 5hr lhr 1/4 hr 3hr 1/4 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 5hr 2hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 9hr 1/2 hr 10hr 1/4 hr 1-1/4 hr 1/2 hr 4hr lhr 1/2 hr 3/4 hr Activity Circulated at 12125.0 ft Pulled out of hole to 145.0 ft Pulled BHA Made up BHA no. 5 Held safety meeting R.I.H. to 12900.0 ft R.I.H. to 13125.0 ft Drilled to 13195.0 ft Held safety meeting Drilled to 13261.0 ft Held safety meeting Drilled to 13162.0 ft Pumped out of hole to 12890.0 ft Serviced Top drive R.I.H. to 13162.0 ft Drilled to 13315.0 ft Held safety meeting Drilled to 13326.0 ft Pumped out of hole to 12890.0 ft Flow check Pulled out of hole to 145.0 ft Pulled BHA Retrieved Wear bushing Tested All functions Installed Wear bushing Serviced Top drive Held safety meeting Singled in drill pipe to 945.0 ft Made up BHA no. 3 Functioned M.W.D. tool Pulled BHA Made up BHA no. 3 Tested M.W.D. tool - Via string R.I.H. to 13226.0 ft Drilled to 13370.0 ft Held safety meeting Drilled to 13554.0 ft Held safety meeting Drilled to 13790.0 ft Held safety meeting Drilled to 13804.0 ft Circulated at 13804.0 ft Pulled out of hole to 12892.0 ft R.I.H. to 13804.0 ft Drilled to 14035.0 ft Held safety meeting Drilled to 14109.0 ft Flow check Pulled out of hole to 12900.0 ft Held safety meeting Pulled out of hole to 145.0 ft Pulled BHA Singled in drill pipe to 379.0 ft Made up BHA no. 4 Progress Report Facility End SDI Well 3-07A/L-29 Rig ~ D..-i,,.~ Page 3 Date 29 September 98 Date/Time 12:45-13:00 13:00-17:30 17:30-18:00 18:00-18:30 18:30-19:30 19:30-06:00 05 Sep 98 06:00-06:30 06:30-18:00 18:00-18:15 18:15-06:00 06 Sep 98 06:00-06:30 06:30-07:00 07:00-08:00 08:00-09:00 09:00-10:00 10:00-10:30 10:30-11:00 11:00-14:30 14:30-15:00 15:00-18:00 18:00-18:30 18:30-21:30 21:30-22:00 22:00-22:30 22:30-23:00 23:00-05:00 07 Sep 98 05:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 08 Sep 98 06:00-06:30 06:30-08:00 08:00-15:30 15:30-16:30 16:30-17:00 17:00-18:00 18:00-18:30 18:30-20:00 20:00-20:30 20:30-21:30 21:30-02:00 09 Sep 98 02:00-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-14:30 14:30-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-20:30 20:30-23:00 23:00-06:00 Duration 1/4 hr 4-1/2 hr 1/2 hr 1/2 hr lhr 10-1/2 hr 1/2 hr 11-1/2 hr 114 hr 11-3/4 hr 1/2 hr 1/2 hr lhr lhr lhr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 3hr 1/2 hr 3hr 1/2 hr 1/2hr 1/2 hr 6hr lhr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1-1/2 hr 7-1/2 hr lhr 1/2 hr lhr 1/2 hr 1-1/2 hr 1/2 hr lhr 4-1/2 hr lhr 2hr lhr 1/2 hr 8hr 2-1/2 hr lhr 1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 7hr Activity Tested M.W.D. tool - Via string R.I.H. to 12895.0 ft Serviced Block line Held safety meeting R.I.H. to 14109.0 ft Drilled to 14278.0 ft Held safety meeting Drilled to 14377.0 ft Held safety meeting Drilled to 14993.0 ft Held safety meeting Drilled to 14494.0 ft Took MWD survey at 14494.0 ft Pulled out of hole to 13560.0 ft R.I.H. to 14494.0 ft Circulated at 14494.0 ft Set tool face Drilled to 14507.0 ft Flow check Pulled out of hole to 9680.0 ft Held safety meeting Pulled out of hole to 151.0 ft Pulled BHA Made up BHA no. 5 Tested M.W.D. tool - Via string R.I.H. to 14507.0 ft Drilled to 14517.0 ft Held safety meeting Drilled to 14677.0 ft Held safety meeting Drilled to 14765.0 fi Held safety meeting Circulated at 14765.0 ft Pulled out of hole to 145.0 fi Pulled BHA Retrieved Wear bushing Tested All functions Held safety meeting Tested All functions Installed Wear bushing Made up BHA no. 6 R.I.H. to 12890.0 ft Serviced Block line R.I.H. to 14765.0 ft Drilled to 14775.0 fi Held safety meeting Drilled to 14995.0 fi ~ Circulated at 14995.0 fi Pulled out of hole to 14210.0 ft Held safety meeting Pulled out of hole to 12900.0 ft R.I.H. to 14995.0 ft Circulated at 14995.0 fi Pulled out of hole to 500.0 ft Progress Report Facility End SDI Well 3-07A/L-29 Page 4 Rig ~ ~)-~ 1~ Date 29 September 98 Date/Time 10 Sep 98 06:00-06:30 06:30-07:00 07:00-08:00 08:00-08:15 08:15-08:30 08:30-09:00 09:00-09:30 09:30-10:00 10:00-10:30 10:30-17:30 17:30-18:00 18:00-18:30 18:30-23:30 23:30-00:00 11 Sep 98 00:00-01:00 01:00-02:00 02:00-03:30 03:30-04:00 04:00-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-08:00 08:00-09:00 09:00-15:30 15:30-16:30 16:30-17:00 17:00-17:15 17:15-17:30 17:30-18:00 18:00-18:30 18:30-19:00 19:00-22:00 22:00-02:00 12 Sep 98 02:00-02:30 02:30-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-13:30 13:30-14:00 14:00-14:30 14:30-15:00 15:00-18:00 18:00-18:30 18:30-20:30 20:30-03:30 13 Sep 98 03:30-06:00 06:00-06:30 06:30-08:30 Duration 1/2 hr 1/2 hr lhr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 7hr 1/2 hr 1/2 hr 5hr 1/2 hr lhr lhr 1-1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr 6-1/2 hr lhr 1/2 hr 1/4 hr 1/4 hr 1/2hr 1/2 hr 1/2 hr 3hr 4hr 1/2 hr 1/2 hr lhr lhr lhr 1/2 hr 1/2 hr 6-1/2 hr 1/2 hr 1/2 hr 1/2 hr 3hr 1/2 hr 2hr 7hr 2-1/2 hr 1/2 hr 2hr Activity Held safety meeting Pulled out of hole to 151.0 ft Pulled BHA Removed Wear bushing Installed BOP test plug assembly Rigged up Top ram Tested Top ram Rigged up Casing handling equipment Held safety meeting Ran Liner to 2900.0 ft (2-7/8in OD) Circulated at 2900.0 ft Held safety meeting Ran Drillpipe on landing string to 12890.0 ft Rigged up Cement head Circulated at 12890.0 ft Ran Liner on landing string to 14995.0 ft Circulated at 14995.0 ft Held safety meeting Rigged up High pressure lines Rig waited: Materials Tested High pressure lines Held safety meeting Mixed and pumped slurry - 25.000 bbl Displaced slurry - 55.200 bbl Functioned Tie back packer Circulated at 12084.0 ft Pulled Drillpipe in stands to 0.0 ft Serviced Top ram Tested Top ram Retrieved BOP test plug assembly Installed Wear bushing Rigged up sub-surface equipment - Mud motor Held safety meeting Serviced Draw works Singled in drill pipe to 2877.0 ft Ran Drillpipe in stands to 14830.0 ft Washed to 14929.0 ft Circulated at 14929.0 ft Tested Casing Circulated at 14929.0 ft Pulled Drillpipe in stands to 12085.0 ft Held safety meeting Circulated at 12085.0 ft Pulled Drillpipe in stands to 0.0 ft Serviced Top drive Held safety meeting Rigged up sub-surface equipment - Production logging tools R.I.H. to 6130.0 ft Held safety meeting R.I.H. to 12700.0 ft Ran logs on tubulars Pulled out of hole to 2830.0 ft Held safety meeting Pulled out of hole to 29.0 ft Progress Report Facility End SDI Well 3-07A/L-29 Page 5 Date 29 September 98 Date/Time 14 Sep 98 15 Sep 98 08:30-09:00 09:00-10:00 10:00-10:30 10:30-14:30 14:30-17:00 17:00-18:00 18:00-18:30 18:30-20:00 20:00-23:00 23:00-00:00 00:00-00:15 00:15-00:30 00:30-02:00 02:00-02:30 02:30-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-10:30 10:30-13:30 13:30-14:00 14:00-14:30 14:30-16:00 16:00-18:00 18:00-18:30 18:30-00:00 00:00-01:30 01:30-02:30 02:30-03:30 03:30-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-08:00 Duration 1/2 hr lhr 1/2 hr 4hr 2-1/2 hr lhr 1/2 hr 1-1/2 hr 3hr lhr 1/4 hr 1/4 hr 1-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr lhr 1-1/2 hr 3hr 1/2 hr 1/2 hr 1-1/2 hr 2hr 1/2 hr 5-1/2 hr 1-1/2 hr lhr lhr 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr Activity Rigged down sub-surface equipment - Drilling tool / logs Serviced Block line Serviced Draw works Rig waited: Orders Rig waited: Equipment Rigged up sub-surface equipment - TCP Held safety meeting Ran Drillpipe in stands to 2639.0 ft Ran Drillpipe in stands to 14929.0 ft Circulated at 14929.0 ft Perforated from 14870.0 ft to 14928.0 ft Flow check Circulated at 14864.0 ft Flow check Pumped out of hole to 2939.0 ft Held safety meeting Pulled out of hole to 74.0 ft Rigged down sub-surface equipment - TCP Ran Tubing in stands to 2860.0 ft Laid down 2860.0 ft of Tubing Ran Drillpipe to 500.0 ft (2-3/8in OD) Freeze protect well - 7.500 bbl of Diesel Installed Hanger plug Rigged down Drillfloor / Derrick Held safety meeting Rigged down Fluid system Rigged down BOP stack Installed Xmas tree Removed Hanger plug Installed Hanger plug Held safety meeting Installed Hanger plug Held safety meeting Skid rig 3-07a/L-29 Gun Diam 4 spf 1-11/16" Top 14870' 14908' Perforations September 14, 1998 Bottom Len~h Zone -- 14890' 20' 2A 14928' 20' 2A Page 1 Endicott Alaska State Plane Zone 3 Endicott SDI 3-07A/L-29 RECEIVED OCT 0 7 1998 BPXA PDC SURVEY REPORT ORiGiNAL 5 October, 1998 Your Ref: API-500292191 Last Day of Survey 09-September-98 Job# AKMW80352 KBE- 56.00' DRILLING SERVICES k DI~'I~ION OF DR~I~R INDUST~IE.~, INC. Survey Reft svy52'l Endicott Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for 3-07A/L-29 Your Ref: API-500292191101 12871.99 44,750 355.910 10012.19 12905.00 44,830 355.940 10035.62 12942.20 53.150 6.480 10060.04 12975.21 60.340 14.060 10078.15 13006.95 67.580 21,110 10092.09 13037.84 72.680 30.410 10102.61 13074.05 79.600 38.160 10111.29 13098.85 85,810 45.790 10114.44 13130.41 92.210 52.210 10114.99 13162.56 100.290 51.740 10111,49 13193.32 102.280 48,440 10105,47 13223.19 102.640 46.690 10099.02 13256.06 102.200 44.400 10091.95 13286.37 101.050 42.660 10085.84 13323.26 100,630 42.730 10078.91 13356.48 101.~90 42.560 10072.56 13387.28 100.610 41.380 10066.68 13418.00 99.520 40.370 10061.32 13451.57 96.300 42.130 10056,70 13482.08 94.750 38.710 10053.76 13512.64 94.550 40.810 10051.28 13546.20 94.720 42.590 10048.57 13577.08 94.600 43.380 10046.06 13606.39 95.050 41.080 10043.59 13640.56 95,320 43.490 10040.51 13670.61 95.580 43.230 10037.65 13698.89 96,770 41.200 10034.61 13732.87 97,990 40.670 10030.24 13764.35 98.560 40.210 10025.71 13857.73 97.920 40.820 10012.33 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 10068.19 6101.21N 2508.92W 10091.62 6124.41N 2510.57W 10116.04 6152.37 N 2509.82W 10134.15 6179.47 N 2504.83W 10148.09 6206.60 N 2496.17W 10158.61 6232.70 N 2483.54W 10167.29 6261.69 N 2463.73W 10170.44 6279.94 N 2447.29W 10170.99 6300.62 N 2423.50W 10167.49 6320.29 N 2398.35W 10161.47 6339.64 N 2375.21W 10155.02 6359.32 N 2353.68W 10147.95 6381.80 N 2330.77W 10141.84 6403,32 N 2310.33W 10134.91 6429,95 N 2285.76W 10128.56 6453,94 N 2263.67W 10122.68 6476,42 N 2243.45W 10117.32 6499.29 N 2223.66W 10112.70 6524.28 N 2201.74W 10109.76 6547.40 N 2182.05W 10107.28 6570.81N 2162.57W 10104.57 6595.79 N 2140.32W 10102.06 6618.30 N 2119.33W 10099.59 6639.92 N 2099.71W 10096.51 6665.10 N 2076.81W 10093.65 6686.85 N 2056.27W 10090.61 6707.67 N 2037.38W 10086.24 6733.13 N 2015.30W 10081.71 6756.84 N 1995.10W 10068.33 6827.09 N 1935.06W Alaska State Plane Zone 3 Endicott SDI Dogleg Rate (o/looft) Vertical Section (ft) 5977143.78 N 267872,72 E 6393.78 5977167.01N 267871,78 E 0.251 6416.98 5977194.94 N 267873.39 E 30.889 6444.56 5977221.87 N 267879.20 E 29.015 6470,69 5977248.72 N 267888.68 E 30.292 6496.33 5977274.43 N 267902.12 E 32.762 6520.39 5977302.79 N 267922.80 E 28,220 6546.29 5977320.54 N 267939.79 E 39.463 6562.05 5977340.48 N 267964.20 E 28.714 6579.18 5977359.37 N 267989.95 E 25,174 6595.11 5977378.00 N 268013.67 E 12.350 6611.00 5977397.01N 268035.78 E 5.846 6627.45 5977418.78 N 268059.37 E 6.934 '6646.48 5977439.66 N 268080.47 E 6.783 6664.91 5977465.53 N 268105.84 E 1.154 6687,81 5977488.83 N 268128.66 E 2.342 6708.45 5977510.68 N 268149.55 E 4,534 6727.86 5977532.93 N 268170.04 E 4.803 6747.71 5977557.24 N 268192.71 E 10.907 6769.37 5977579.74 N 268213.10 E 12,259 6789.48 5977602.55 N 268233.28 E 6.880 6809.92 5977626.83 N 268256.29 E 5.311 6831.51 5977648.69 N 268277.95 E 2.579 6850.84 5977669.70 N 268298.24 E 7,969 6869.48 5977694.17 N 268321.89 E 7.068 6891.18 5977715.28 N 268343.08 E 1.221 6909.82 5977735.51 N 268362.60 E 8,285 6927.78 5977760.28 N 268385.45 E 3.909 6949.87 5977783.36 N 268406.38 E 2.317 6970.50 5977851.74 N 268468.54 E 0.942 7031.59 Comment Tie-on Survey Window Point Continued... 5 October, 1998 - 11:55 - 2- DrillQuest Endicott Measured Depth (ft) Incl. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for 3-07A/L-29 Your Ref: API-500292191101 13952.42 99.070 38.950 9998.34 14047.36 98.770 41.520 9983.62 14082.22 98.390 39.700 9978.42 14114.12 98.300 42.810 9973.79 14145.90 99.770 44.860 9968.79 14174.84 99,400 43.160 9963.98 14207.82 99.000 44.430 9958.70 14239.88 97.800 45.100 9954.02 14269.04 97.390 43.710 9950.16 14302.33 98.270 45.760 9945.63 14329.74 97.130 48.930 9941.96 14359.40 94.800 53.310 9938.87 14393.39 91.760 56.910 9936.93 14423.53 87.570 58.700 9937.10 14453.66 82.650 58.150 9939.67 14489.06 791000 61.260 9945.32 14520.54 75.950 62.690 9952.14 14551.77 71.570 63.900 9960.87 14584.00 70.420 62.440 9971.37 14615.02 68.920 63.190 9982.15 14644.23 68.230 63.610 9992.82 14677.27 66.840 62.370 10005.44 14708.44 65.560 61.870 10018.02 14732.12 65.010 61.370 10027.92 14765.81 66.120 62.000 10041.86 14796.94 70.610 64.010 10053.33 14826.47 71.960 65.230 10062.81 14861.06 72.160 65.340 10073.46 14891.78 73.130 64.890 10082.63 14921.10 72.510 64.820 10091.29 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 10054.34 6898.95 N 1875.01W 10039.62 6970.54 N 1814.43W 10034.42 6996.71N 1791.99W 10029.79 7020.43 N 1771.19W 10024.79 7043.07 N 1749.45W 10019.98 7063.60 N 1729.63W 10014.70 7087.09 N 1707.09W 10010.02 7109.61N 1684.76W 10006.16 7130.26 N 1664.54W 10001.63 7153.69 N 1641.33W 9997.96 7172.09 N 1621.35W 9994.87 7190.60 N 1598.39W 9992.93 7210.00 N 1570.57W 9993.10 7226.06 N 1545.07W 9995.67 7241.77 N 1519.50W 10001.32 7259.40 N 1489.34W 10008.14 7273.84 N 1462.21W 10016,87 7287.31N 1435.44W 10027.37 7301.06 N 1408.24W 10038.15 7314.35 N 1382.37W 10048.82 7326.53 N 1358.06W 10061.44 7340.39 N 1330.86W 10074.02 7353.73 N 1305.65W 10083.92 7363.95 N 1286.72W 10097.86 7378.50 N 1259.72W 10109.33 7391.62 N 1233.94W 10118.81 7403.61 N 1208.67W 10129.46 7417.37 N 1178.78W 10138.63 7429.71N 1152.18W 10147.29 7441.61 N 1126.82W 5977921.73 N 268530.76 E 5977991.43 N 268593.50 E 5978016.90 N 268616.73 E 5978039.98 N 268638.25 E 5978061,94 N 268660.67 E 5978081.85 N 268681.12 E 5978104.64 N 268704.36 E 5978126,47 N 268727.37 E 5978146.49 N 268748.22 E 5978169.19 N 268772.13 E 5978186.97 N 268792.66 E 5978204.77 N 268816.18 E 5978223.31N 268844.58 E 5978238.58 N 268870.56 E 5978253.50 N 268896.60 E 5978270.20 N 268927.29 E 5978283.80 N 268954.84 E 5978296.45 N 268982.02 E 5978309.36 N 269009.62 E 5978321.85 N 269035.89 E 5978333.28 N 269060.56 E 5978346.30 N 269088.17 E 5978358.86 N 269113.78 E 5978368.50 N 269133.01E 5978382.21 N 269160.44 E 5978394.54 N 269186.61 E 5978405.75 N 269212.24 E 5978418.58 N 269242.54E 5978430.10 N 269269.50 E 5978441.22 N 269295.21 E Alaska State Plane Zone 3 Endicott SDI Dogleg Rate (°/100ft) Vertical Section (ft) Comment 2.300 2.693 5.276 9.650 7.873 5.932 3.990 4.276 4.930 6.649 12.192 16.655 13.848 15.117 16.430 13.472 lO.655 14.510 5.574 5.341 2.715 5.452 4.361 3,012 3,709 15.621 6.017 0.653 3.453 2.127 7094.28 7156.62 7179.37 7199,93 7219.28 7236,80 7256.89 7276.04 7293.63 7313.56 7328.96 7344.05 7359.34 7371.65 7383.60 7396.81 7407.28 7416.85 7426.63 7436.15 7444.77 7454.67 7464.32 7471.78 7482.38 7491.74 7500.O4 7509.46 7517.92 7526.14 Continued... 5 October, 1998 - 11:55 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 3-07A/L-2g Your Reft API-500292'191101 Endicott Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 14953.32 72.030 65.310 10101.10 10157.10 7454.55 N 1098.99 W 14995.00 72.030 65,310 10113.96 10169.96 7471.11 N 1062.97 W 5978453.30 N 269323.42 E 5978468.75 N 269359.94 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 351.902° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14995.00ft., The Bottom Hole Displacement is 7546.35ft., in the Direction of 351.902° (True). Comments Measured Depth 12871.99 12905.00 14995.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10068.19 6101,21N 2508.92W Tie-on Survey 10091.62 6124.41N 2510.57W Window Point 10169.96 7471.11N 1062.97W Pr~ected Survey Alaska State Plane Zone 3 Endicott SDI Dogleg Vertical Rate Section (°/100ft) (ft) Comment 2.078 7535.03 0.000 7546.35 Projected Survey 5 October, 1998 - 11:55 - 4 - DrillQuest ~'~'~l Iml LI 1 oile]::.]i[~[~] -J GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 11525 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 3-07A/L-29 '~ '~:)(/:~C'T1 98477 blCHL 980912 I I I 9/29/98 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99 _~3- e e,ved WELL LOG TRANSMITTAL To: State of Alaska 'Alaska Oil and Gas Conservation Comm. .Attn.: Lori Taylor 3001 Porcupine St. :Anchorage, Alaska 99501 MWD Formation Evaluation Logs 3-07/UL-29, September 30, 1998 AK-I~LM-80352 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of~ ,Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #~ Anchorage, AK 99518 3-07A/L-29: e"~ II51! ~ x .MD Gamma Ray Logs: 50-029-21911-01 2" x 5" TVD Gamma Ray Logs: 50-029-21911-01 1 Blueline 1 Rev Folded Sepia i Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Dresser Industries. Inc. Company I::] FI I I--I-- I IM G SE FIL/I C I:: S To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive. Anchorage, Alaska 99501 September 23, 1998 RE: MWD Formation Evaluation Logs - 3-07A/L-29, AK-MW-80352 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21911-01 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Dresser Industries. Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 26. i998 Lowell Crane Drilling Engineering Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Duck Island 3-07AFL-29 BP Exploration (Alaska) Inc. Permit No. 98-147 Sur Loc: 2748~SL. 848%VEL, Sec. 8. T1 IN. R17E. UM Btmholc Loc. 5043~SL, 1652'WEL. Sec. 5, T11N, R17E. UM Dear Crane: Enclosed is thc approved revised application for permit to drill the above referenced well. The pro,,fsions of the original approved permit dated August 7, 1998. are in effect for this revision. Chairm'al~~ BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game. Habitat Section W/o cncl Department of Environmental Conservation w/o cncl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 REVISED 08/19/98 la. Type ofwork [] Drill [~Redrill Ilb. Type ofwell []Exploratory F-lStratigraphic Test [] Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 56' Endicott Field / Endicott Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047502 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2748' NSL, 848'WEL, SEC. 8, T11N, R17E, UM Duck Island .... At top of productive interval 8. Well Number Number 2S100302630-277 3585' NSL, 3340' WEL; SEC. 5, T11N, R17E, UM 3-07A/L-29 Attotal depth 9. Approximate spud date Amount $200,000.00 5043' NSL, 1652' WEL. SEC. 5: T11N, R17E, UM 08/05/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TV[:)) ADL 312828, 237'I 3-09/L-28,451' at 13700 MD 1280 15323' MD / 10200' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 12895' MD Maximum HoleAngle 51° Maxirnumsurface 3845 psig, At total depth (TVD) 10050' /4850psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4# L-80 STL 3324' 12000' 9408' 15324' 10200' 103 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 13550 feet Plugs (measured) true vertical 10545 feet Effective depth' measured 13468 feet Junk (measured) true vertical 10487 feet Casing Length Size Cemented MD TVD Structural Conductor 92' 30" Driven 131' 131' Surface 2463' 13-3/8" 2690 cu ft. Permafrost 'E' 2502' 2500' Intermediate 12465' 9-5/8" 575 cu ft. Class 'G' 12504' 9811' Production 1342' 7" 410 cu ft. Class 'G' 12206' - 13550' 8604' - 10545' Liner Perforation depth: measured 13130' - 13270' true vertical 10194' - 10292' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer NamelNumber: Chris West, 564-5089 Prepared By NamelNumber: Carol Withey, 564-4114 21. I hereby certify that the foj~going is tru¢,gnd correct to the best of my knowledge Signed Lowell Crar~C~?Z~¢~ ~"~,,,-J/ ~....----.-T4t:le--Drilling Engineering Supervisor Date i Commission Use Only Permit Number ~"'/ I APlNumber I ApprovalDate I See cover letter ,~ .-,/,~/~ 50- O,2-~'- ~_, ,2 I:~,/'// -~ / ~-" ,~- ~ ~' for other requirements Conditions of Approval: Samples Required I--IYes l~No Mud Log Required I--lYes .[~"No Hydrogen Sulfide Measures ~Yes [] No Directional Survey Required ~Yes [] No Required Working Pressure for BOPE E]2M' E]3M' ,[~5M' []10M; []15M °theruriginal*'-- Signed By by order of Approved By David W. Johnston Commissioner the commission Dateo~),, STATE OF ALASKA ALASKA I~'(L AND GAS CONSERVATION corv~lSSlON PERMIT TO DRILL 20 AAC 25.005 REVISED 08/19/98 la. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 110. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 56' Endicott Field / Endicott Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047502 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2748' NSL, 848~WEL, SEC. 8, T11 N, R17E, UM Duck Island At top of productive interval 8. Well Number Number 2S100302630-277 3585' NSL, 3340' WEL, SEC. 5, T11N, R17E, UM 3-07A/L-29 At total depth 9. Approximate spud date Amount $200,000.00 5043' NSL, 1652' WEL, SEC. 5, T11N, R17E, UM 08/05/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 312828, 237'I 3-09/L-28, 451' at 13700 MD 1280 15323' MD / 10200' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 12895' MD Maximum Hole Angle 54 ° Maximum surface 3845 psig, At total depth (TVD) 10050' / 4850 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4# L-80 STL 3324' 12000' 9408' 15324' 10200' 103 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 13550 feet Plugs (measured) true vertical 10545 feet Effective depth: measured 13468 feet Junk (measured) true vertical 10487 feet Casing Length Size Cemented M D TVD Structural Conductor 92' 30" Driven 131' 131' Surface 2463' 13-3/8" 2690 cu ft. Permafrost 'E' 2502' 2500' Intermediate 12465' 9-5/8" 575 cu ft. Class 'G' 12504' 9811' Production 1342' 7" 410 cu ft. Class 'G' 12206' - 13550' 8604' - 10545' Liner Perforation depth: measured 13130' - 13270' true vertical 10194' - 10292' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Chris .West, 564-5089 Prepared By Name/Number: Carol Withey, 564-4114 21. I hereby certify that,the fo/going is true, nd correct to the best of my knowledge Signed k,.....,,¢ ! ,,~ // ~' Lowell Crar~'-~ //~,~/_.../~/ ((,,//~/.~, _....-----Ti-t+e-Drilling Engineering Supervisor Date ~ - I ? -~¢¢ ( ~'-~, ' - Commission Use Only Permit Number ¢ I APl Number ! Approval Date See cover letter .~7'~_.,,/z./'.~ { 50- ~ ~.. ~ - ~-- ,/?,///"'4:3 ! I ~" ~'- ~'~' for other requirements Conditions of Approval: Samples Required []Yes []No Mud Log Required []Yes D~INo Hydrogen Sulfide Measures ]~]Yes []No Directional Survey Required J~Yes [--INo Required Working Pressure for BOPE []2M; []3M; J~5M; []1OM; []1 'SM Other: 0r~ginat Signea ~ by order of Approved By David W. johnston Commissioner the commission Date ~.-~;,-'- Form 10-401 Rev. 12-01-85 Submit In Triplicate TREE: 4-1/16" ~ ~.~00 psi/Cooper R.T. ELEV = 55.4' WELLHEAD: 13-5/8" / 5000 psi / McEvoy B.F. ELEV = 16.5' MAX. DEV. = 51:43 8600' M D SSSV LANDING NIPPLE 13-3/8", 68#/ft, L-80, Btrs Csg W/SSSV DIN I.D. is 2" 2502' I ~ 4-1/2", 12.6#/ft, L-80, NSCT GEM's (CAMCO), (1-1/2" RK) Latch No. TVDSS MD-BKB 9-5/8", 47#/ft/ #2 3668' 3737' NT80S XO to NT95HS ~-- #1 9483' 12010' 10222' · OTIS "X" NIPPLE 12080' I · '~ (3.813" I.D.) _.~ 9-5/8" PACKER [ ~ -~' TIW (HBBP) 12157' TOP OF 7" LINER ~ ~ 3-1/2", 9.2#/ft L-80, TAILPIPE J '~" 3_1/2,, ,SWS, NIPPLE 12207' ~,--I" I I _.!~___ Parker (2.750" I.D.) 12202' 9-5/8", 47#/ft, NT95HS, NSCC ---.. 3-1/2" 'SWN' NIPPLE l ~ ,~ ?, · Parker (2.635" I.D.) 12234' 1 2504' / ~' ' (---- 3-1/2" WLEG 12270' PERFORATING SUMMARY Ref. Log: DEL-GE (MSFL 3/2/89) CO. GUN SPF INTER~AL BAKER 5" DPC 4 13130'- 13270' · ii! .... 7", 29#/ft, SM-110, ~ 13550' "~ Btrs-TKC[ Date . By Comments ENDICOTT WELL: 3-07 / N-28 o2-01-89 FH PROPOSED COMPLETION APl NO. 50-029- 21 91 1 03-14-89 JLH INITIAL COMPLETION COMPLETION DIAGRAM -- 10-25-94 JTP ~osm BP EXPLORATION, INC. R"T. ELEV = 55.4' B.F. ELEV = 16.5' MAX. DEV. = 51:43 8600' MD 13-3/8", 68#/ft, L-80, Btrs Csg 9-5/8", 47#/ft NT80S XO to NT95HS I 10222 ' I ~ TREE: 4-1/16" / ~. ) psi/Cooper WELLHEAD: 13-5~di' / 5000 psi / McEvoy SSSV LANDING NIPPLE OTIS (3.813" I.D.) W/SSSV MIN I.D. is 2" 1487' 4-1/2", 12.6#/ft, L-80, NSCT GLM's (CAMCO), (1-1/2" RI<) Latch No. TVDSS MD-BKB #2 I 3668' 3737' #1 9483' 12010' Well loaded with 8.6 ppg seawater TOP OF 7" LINER i 12207' 9-5/8", 47#/ft, NT95HS, NSCC 12504' ~ pERFORATING ~UMMAI=IY Ref. Log: DLL-GR (MSFL 3/2/89) 'CO. GUN ~;PF I IBNZKEERRV'~Ls" DPC 4 13130' - 13270' I PBTD 7", 29#/ft, SM-110, Btrs-TKC Tagged PBTD @ 13307' I13550' I (3.813" I.d.) TIW SBR ! 12140' I TIW (HBBP) 9-5/8"PACKER I 12157' I 12167' Milled 5-1/2" x 3-1/2" Crossover 3.80" Drift Proposed whipstock setting dePth @ 12895' MD 11 bbl 15.6 ppg cement plug f/13307- 13000' Milled off 3-1/2" tail pipe Overall Length: 103' Date 02-01-89 03-14-89 10-25-94 7-20-98 By Comments PROPOSED COMPLETION JLH INITIAL COMPLETION JTP POST RWO JLH Pre TrRD ST ENDICOTT WELL: 3-07 / N-2t~ APl NO. 50-029-21911 PROPOSED COMPLETION DIAGRAM BP EXPLORATION, INC. TREE: 4-1/16"/' ~0 psi/Cooper R.T. ELEV = 55.4' '~- WELLHEAD: 13~.~_?" / 5000 psi / McEvoy B.F. ELEV = 16.5' MAX. DEV. = 51:43 8600' h MD ~ SSSV LANDING NIPPLE I ~ ~' ' OTIS (3.813" I.D.) I 1487' 13-3/8", 68#/ft, L-80, Btrs Csg I ' W/SSSV MIN I.D. is 2" ~ --- 4-1/2", 12.6~/ff, L-80, NSCT ~ GLM's (CAMCO), (1-1/2" R~ Latch ' ~ No. WDSS MD-BK~ 9-E8", 47~/fl J ¢2~ 3668', 3737 , NTSOS XO to NT95HS -- .1 9483 12010 I10222' I ' I II~ OTIS "X" NIPPLEI1PORn'I ' / (3.813" I.D.) ' I ..... I Est. 2-7/8",linerTop ~ ~ ~/ "- ~ ~ { ~am 9-5/8 PACKER I , I 1.207' ~i I ~ ~ I~ Milled 5-1/2' x 3-1/2 Crossover ,-5/8,47¢/~,"T95HS, NSOCi12504' I > '. '1 3.80" Drift ~ 2-7/8 ~ er / 12115-15324 Proposed ~ ~ ~ whipstock se*ing depth ~ 12895' ~ Ref. Log: DLL-GR (MSFL 3/~89) CO. ' GUN ~PF ' 3-3/4 Hole to 15324 MD INTERV,~L BAKER 5" DPC 4 13130'- 13270' ~~ cement plug f/13307-13000 ~ Ddled off3-1/2 tad p~pe Tagged PBTD ~ 13307' t ' ~ Overall Leng h: 103 ,,. .... PBTD I13468' I 7", 29ff/,, SM-110, I ] ~~ ¢', '~.'.S ~-.3, :; ' , ' -': ?V,;;:;. ~:.. .... Btrs-TKC 13550' Date By Comments ENDICO~ WELL: 3-07 / N-28 02-01-89 FH PROPOSED COMPLETION APl NO. 50-029- 2191 1 03-14-89 JLH INITIAL COMPLETION PROPOSED COMPLETION BIAGRAB 10-25-94 JTP POST RWO 7-20-9~ JLH P.~ ~RD ST BP EXPLORATION, INC. I I Well Name: 13-07a/L-29 Weft Plan Summary Type of Well (Producer or injector): I Producer Well Design (Conventional, slimhole, etc.): I -II-RD SIDETRACK FSL FEL SEC TWP RNG Surface Location: 2748 848 8 11N 17E Top of Kekiktuk is above KOP: Target I Location: 3585 3340 5 11N 17E Target 2 - Bottom Hole Location: 5043 1652 5 11N 17E I AFE Number: 1727028 I I Rig: I DOYON 15 Estimated Start Date: IAugust 25, 1998 I I Operating days t° drill andcomplete: 12+3 Formation Markers Well Bore: Formation Tops MD TVDSS EMW RESERVOIR PRESSURE : KBE -56 Max surface pressure =3596 psi TOP WEST SAK Above KOP TOP SEABEE/AYLYAK Above KOP TOP SHALE WALL/TUFFS Above KOP TOP HRZ Above KOP BASE HRZ 9718 Above KOP PUT RIVER Above KOP LCU 9739 Above KOP KEKIKTUK- Top 3A2S 9.3 ppg Above KOP 3A1 Above KOP K2B(2900F) 14037 9906 9.0 ppg Above KOP (Note inverted well) K2M (2400SB) 13700 9954 KOP 12,895' MD / 10028' TVDss K2A (2300F) 14037 10010 8.7 ppg 44000psi @ 9901' TVDss Target COWC 15264 10180 K1 (2000) 15323 10200 8.0 ppg 4850 psi @ 10050' TVDss Target TD 15323 10200 Logging Program: MWD-GR ILogs: 3.75" Hole Curve and Tangent DPC Open Hole Cased Hole: GR/Res NA Casinc /'Fubinc Proc ram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVDSS 3.75 2.875" 6.4 L-80 STL 3324 12000/9408 15324/10200 TBG* 4.5" 12.6 L-80 NSCT 12,119 38 12,157/9515 Note: The existing tubing will be left in place and re-used. The 3.5" tubing tail will have to be milled off, and the 2.875" liner hung 150 feet above the existing packer. 3-07a/L-29 Drilling Program - DRAFT Directional Plan WP# 5 8/19/98 Page 3 Drilling Discussion General The proposed sidetrack of the 3-07a/N-28 to the L-29 location will access the lower 2A oil column, which not been sufficiently depleted by 3-07/N-28 due to high water production. This will establish an offtake point away from the east-west trending fault system just north of the 3-07/N-28. The L-29 BHL targets a drainage area of 70 acres with a P50 estimate of 0.96 MMSTBOIB Expected initial rate is 2000 BOPD at a GOR of 1500 scf/stb and a watercut of 40%. The well will be sidetracked in the 7" casing below the P3 coals. The present 4-1/2" L-80 completion will remain in place during the sidetrack operation. A 2-7/8" liner will be run and cemented in place. The liner will be selectively perforated using coil tbg after the rig moves off location. The 3-07a/L-29 sidetrack represents the third implementation of 'Ir'RD technology at Endicott as a cost effective alternative to conventional sidetracking. The 3-07a well on SDI at Endicott will target the Kekiktuk in the 2A in accordance with the 1998 development plan. We will have to abandon the existing perforation in the 3-07a/N-28 well by setting a cement plug with coil-tubing. The well will be sidetracked off the cement plug to the new L-29 BHL utilizing the 2.875" liner STL design. The existing production packer or tubing will not be pulled. The 2.875" liner length will be +_ 3324 feet, with the top of the tie back into the 4.5" production tubing just below the 7" x 4- 1/2" production packer. The existing 2 valve slimhole (4.5" x 1.0" for 7.0" casing) GLM design will be used after the well is completed. The 4.5" L-80 tubing design will remain. Directional Plan: The directional plan for the 3-07a/L-29 well consists of kicking off with a whipstock and conventional BHA's for the Kekiktuk Flow sands. The plane KOP will be in the 2B Sand below the LCU and HRZ. Current plans call for up to 22"/100' doglegs in this section, but this may be adjusted pending results during the drilling process. After sidetracking, drill the inverted tangent at 110°, and then dropping angle @6°/100' through the two targetS. The planned TD is 15,324' MD (10200' TVDss) in Zone 1. The only close approach is the existing 3-07 well which quickly diverges from the sidetrack path. The closest offset well is 3-09/L-28 which is 451 feet away at 13,700' MD. The KOP below the HRZ is a result of the HRZ and coal problems encountered in Well 3-17/M-31. Ensure that any and all tolerance lines are not crossed to avoid policy violations. Please coordinate this through both the Operations Drilling Engineer and the Endicott Drilling Superintendent. There are not any known close approaches which require wells be shut in. Any BHA's indicating less than required BUR should ~ ..- . ;~. ~ ..~-, ~-._ immediately be pulled for a more aggressive assembly. : . ;--: ~.~:- :-.- .. . .~-. .~ ';;.: :-.. Recommended BHA's All motors should NOT be jetted to account for the propOsed flowrate performance. Hole conditions and directional objectives should dictate actual flowrates. As mentioned previously, flex collars should be utilized to minimize potential differential sticking. We will be using bent housing motors with either 7/8 for a roller cone or 5/6 rotor/stator configurations for PDC bits. Sperry proposed BHA's are attached, however the actual BHA with motor design, MWD tool configuration, MWD battery life, bit hydraulics will be discussed at the daily wellsite meeting. DRILLING CLOSE APPROACH WELL SHUT-INS The closest well bore is the original well 3-07/N-28 which quickly diverges from the sidetrack. The closest offset well is 3-09/L-28 which is 451 feet away at 13,700' MD. This well will meet the deep intersection risk assessment. Close attention to the tolerance lines are necessary to avoid this well. See the TC plot for details. 3-07a/L-29 Drilling Permit Directional Plan WP# 5 7/30/98 PORE PRESSURE / LOST CIRCULATION Production Interval (3.75"): The Kekiktuk Sands (3A) reservoir pressure could be higher than normal at 8.95 ppg (based on well 1-39/P-17 SBHP). The formation also has the (slight) potential for lost circulation (see Geologic Prognosis for faulting details). Lubricant additions (see above) should be utilized if torque and drag become troublesome, and after extensive testing of mud on location. Flex collars should be utilized in the BHA to minimize potential differential sticking. Liquid casing and OM seal should be on location to help combat severe lost circulation. NOTE' See the Geologic Prognosis for a detailed description of the expected fault locations and sizes. Review the Pad Data Sheet for trouble highlights throughout MPI history. Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Special XOS for drillpipe are available for this well. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Waste Disposal Cuttings Handling: CC2A Fluid Handling: Annular injection is not available at Endicott for this well. Directional Survey Program The survey program for 3-07a/L-29 calls for use of Sperry's SOLAR MWD surveys the entire well. Because of Sperry's standard practice of changing the MWD probes after every bit run, an electronic single shot (ESS) will not be needed, and a gyro is not warranted. Close attention to JORPS is required, with the use of checkshots and survey data validation. A PWD sub will be run with the MWD probe to record actual bottom hole pressures. Bit Program After milling a 3.80" window off of a whipstock, a 3.75" build section followed by a short tangent section and a drop section is planned. The entire well will be drilled with the PDC bits (depending on directional control) to allow for more flow area around the BHA. The penetration rate will vary due to the variable lithology, but these bits have proven durable when CT drilling the Sadlerochit in the PBU. Recommended Jet Sizes Expected Interval Bit Type Flowrate HSI Casing Section Standard Baker TTRD 90 - 120 gpm Window Mills Kickoff 3.75" HTC 335 90 - 100 gpm 0.371 < 1 Tangent 3.75"x4.25"Bicenter DPI 566 90- 100 gpm 0.371 < 1 3.75" (If bicenter not HTC 335 90 - 110 gpm 0.371 < 1 drilling) NOTE: Real time rigsite information such as condition of bits previously pulled, hole conditions, drilling fluids, downhole motor constraints (if any) will be instrumental in actual final bit selection. 3-07a/L-29 Drilling Permit Directional Plan WP# 5 7/30/98 Mud Program: The cement pilot hole and ramp to the casing wall will be milled using slick seawater (1- 1.5 ppb N-vis). The well will displaced to a 10.0 ppg brine prior to P©H to mill the wind9w. The 10.0 ppg brine will be used to mill through the casing and drill 5 ft of new 3-3/4" open hole. Hi-vis sweeps in the 10.0 ppg brine will be used to clean the metal cuttings from the well. The 10.0 ppg brine will be displaced with 10.0 ppg Quik Driln. Save the 10.0 ppg brine to be used as a tripping fluid to reduce the surge and swab pressures. The brine may have to be replaced due to hi-vis sweeps increasing the fluid rheology. Immediately after displacing the well to 10.0 ppg mud, add 0.5 ppb of Barascav D. Tourly sulfite checks should be made to ensure that residual sulfites of 150mg/L are maintained with Barascav D. Make sure DITCH MAGNETS are used both in the possum belly and suction pits f°r maximum metal removal benefit throughout milling and drilling operations of this well. See Bariod mud recommendation for exact mud parameters. While milling the window, run the solids control equipment (shakers and rig centrifuge) to remove the cement and metal from the brine. The Bariod solids control van should be operational prior to drilling any new formation with Quik Dril fluid. This will help keep the PV down, which is the main driver of circulating pressure. Since the mud weight is maintained with NaBr, the centrifuges can be run continuously without reducing the mud weight. Whole mud dilution or complete swapout may be needed to keep as clean a system as possible. Calcium must be under 100 ppm prior to adding EP Mudlube. Maintain a ~ ppb buffer of Bicarb/Soda ash if EP Mudlube is added. A Iow vis, weighted brine sweep prior to the cement slurry may be needed to clean the hole. This will facilitate a better cement job. Tripping Practices / Stuck Pipe / Hole Cleaning / Reaming Tripping should be undertaken with caution due to swabbing possibilities with high viscosity fluids and the tight annular clearance. A 10.0 ppg brine trip fluid will be needed due to the high swab pressures encountered while drilling the SDI 3-17C TTRD well. The bottom hole pressure could be as high as 4700 psi (+/- 9.3 ppg ). The mud weight is recommended to be maintained in the 10.0 ppg range to allow for formation pressure uncertainties. If swabbing becomes a problem, the well will be displaced to a trip fluid (10.0 ppg brine) to minimize swab pressures. Faulted intervals may require additions of LCM prior to tripping to insure that the hole remains full at all times. Keep the pipe moving and have an ample supply of lost circulation materials on hand. Baroid recommends utilization of Iow viscosity sweeps to assist with hole cleaning and to minimize the formation of cuttings beds on the Iow side of the hole. After getting back to bottom after a trip, bring pump on very slowly to minimize surge pressures. Pipe should be pulled and run very slowly (4-5 minutes/stand) in the open - !:- :. '.... ....... hole to reduce pressure fluctuations. '- . ~' Hole Cleaning Based on the PWD (Pressure while Drilling) review from the SDI 3-17C well,~.hole- packo, ff due to elevated ECD through the HRZ shale was the primary cause Of` i~le instability. The planned well (3-07a/L-29) will be kicked off below the HRZ in the Kekiktuk formation to eliminate the exposure to the HRZ. Hole cleaning in the sand will be one of the primary functions of the drilling fluid. The Quik Driln fluid has been used extensively on the North Slope as a Reservoir drill in mud. The reservoir studies have show~ that this fluid causes little formation damage. The polymer based mud is shear thinning is an excellent hole cleaning mud. This fluid type is used exclusively by the CT drilling group. The ECD data also showed that numerous short trips and circulating is needed to clean the hole. If any coal is encountered, drill only 1-2 ft prior to circulating the hole clean. Coal also caused packoff problems in the 3-17C well. The coals will probably not be 3-07aiL-29 Drilling Permit 7/30/98 Directional Plan WP# 5 id'entified until the cuttings re~ch the shaker. During the expe~'ed coal interval, we should control drill no more than 3 - 5 feet at a time, and circulate bottoms up before continuing. The warning signs for coal packoff are pressure or torque fluctuations, coal cutting across the shaker, hole fill after connections, return flow fluctuations, and increase of drag. To identify and minimize problems, this information must to recorded on the driller handover sheet to track trends. Reaming Reaming in 'Fl'RD wells require much closer attention while reaming than conventionaI; wells due to the affect of ECD and pipe movement in very close annular clearance. This is important both while drilling the reservoir, and any time there are unstable formations such as coals or the HRZ exposed. Mud properties must be maintained within the specified parameters at all times. If mud properties are not within range, drilling operations should cease, and the mud conditioned before continuing. Every attempt to rotate rather than slide will assist hole cleaning, and minimize reaming. If we do have to ream, it should be at reduced ( < 50% of drilling circulation rate) circulation rate and only up-ream. The combined affects of ECD and down-reaming put excessive pressure on the formation and will cause hole collapse. Equivalent Circulating Density The PWD (recorded data) sub will be run in this well to record the downhole pressure parameters. This data was very useful in evaluating the problems encountered in the previous well. Confirm with the onsite Sperry Sun personnel that the PWD software has been upgraded for quick data output. The higher ECD due to the high rheoiogy Quik Dril mud should not be a problem in the Kekiktuk sand. This fluid type was used in the PBU TTRD wells to drill the Sadlerochit sand without problems. Any hole problems should be immediately reported so a revised drilling plan can be formulated. H2S Concerns The SDI 3-07/N-28 production stream recorded XXX ppm of H2S in 3/98. There have been H2S reading on offset MPI wells of over 1000 ppm. Ensure rig gas detectors are calibrated prior to N/D tree and/or circulating to kill the well. Logging Program: The MWD-GR log will be the only MWD log. A PWD sub will be run while drilling the 3- 3/4" hole to record downhole pressures. Drill pipe conveyed (DPC) GR/Res will be run for WOC determination. Schlumberger will provide the side door sub and wet connect for the DPC tool string. Sample catchers and a wellsite Geologist are planned to be used while drilling reservoir. Casing and Cementing This TTRD sidetrack will require a 2.875" 6.4# L-80 liner with STL connections tobe run across the entire interval. The top of the 2-7/8" liner will in the 4.5" tubing at 12,000+/- MD (Just above the 7" x 4-1/2" packer @ 12,157'md). Ensure that prior to running liner that the hole is in good condition and that the mud has been conditioned to run casing. Before POH to run liner, spot lubricant across the open hole section. If this is considered essential to getting the pipe to bottom ensure that adequate lubricant testing has been performed prior to doing this. Also, consideration must be given to a hole o. pener trip prior to running liner if hole conditions suggest that there may be problems running pipe. The liner should be filled every 5 joints, and circulated prior to going into open hole. Any problem intervals identified while drilling, such as ledges, will require special care while running casing through. The liner will require 1 turbolator (2-7/8" x 3-5/8") centralizers on every other joint to the window. Integral centralizers (STL connections) may be run in place of the latch-on turbolators to eliminate turbolators moving on the 3-07a/L-29 Drilling Permit Directional Plan WP# 5 7/30/98 lir~er. If the liner starts to pack~ff in the open hole, establish circulati'~n and try to wash through. Do not continue to run casing without circulation. If necessary, we will pull the liner and make a wiper trip prior to running the liner. The liner running procedure in the detail section should be reviewed. This liner will be run with a PBR only. There is an option to run a packer after cementing operations. The cementing program is designed to place cement back to within 350' (12,495' MD) the production tubing tail. The approximate volume will be 100 sacks (21 bbls) of Class 'G' with additives as specified in the casing detail section. Cementing operations at Endicott are continue to be critical with the advancement of both the waterflood and gas · fronts. Close attention to detail for this part of the well is critical for the economical success of our drilling program. CT Conveyed Perforating This sidetrack well will require coil tubing perforating across the intervals picked from LWD GR and GR/RES logs after the rig is released. 3-07aiL-29 Drilling Permit Directional Plan WP# 5 7/30/98 Endicott Measured Depth (ft) 12895.00 12900.00 12925.00 13000.00 13100.00 13200.00 13252.07 13300.00 13400.00 13500.00 13600.00 1360'1.85 13700.00 13900.00 14000.00 14037.14 14100.00 14200.00 14242.94 14300.00 14400.00 14500.00 14598.07 14600.00 14700.00 14800.00 14874.43 14900.00 15000.00 Incl. 44.808 45.288 47.722 61,497 80,871' 100.545 110.697 110.697 110.697 110.697 110.697 110.697 ' 106,602 102,337 98,005 93~630 92.00O ~.2~ 82,241 79.668 79,668 79.668 79,668 79.668 79.602 76.189 72.883 70.5O9 70.509 70.509 355.927 356.436 358.855 10.072 21.156 31 ~052 36'.570 36.570 36.570 36:570. 36.570 36.570 41.039 45.398 49.616 53.745 55.266' 55.073 54.765 54.630 54.630 54.630 54.630 54.726 59.774 64.970 68.955 68,955 68,955 Sub-Sea 'Depth (ft) Vertical Depth (ft) Sperry-Sun Drilling Services Proposal Report for 3-07ALL-29 Wp5(r) ,, OP, FI OtlL¥ Local Cz3ordinates Northings Eastings (ft) (ft) Alaska State Plane Zone 3 Endicott SD! 10028.52 10084.52 6117.38 N 2510.07 W 10032.05 10088.05 6120.91 N 2510.31 W 10049.26 . 10105.26 6139.03 N 2511.04 W 10092.68 10148.68 6199.63 N 2505.80 W 10124.87 10180.87 6290.05 N 2479.98 W 10123.64 10179.64 6379.30 N 2436.27 W 10109.63 10165.63 6420.92 N 2408.46 W 10092.69 10148.69 6456.93 N 2381.75 W 10057.35 10113.35 6532.06 N 2326.01 W 10022.01 10078.01 6607.19 N 2270.28 W 9986.66 10042.66 6682.32 N .. 2214.54 W g986.01 10042.01 6683.72 N 2213.5.1 W 9954;62 10010.62 6756.12 N 2155;23 W 9929.62 9985.62 6826.62 N 2088.93 W 9911.96 9967.96 6893.06 N 2016.37 W .. 990! .82 9957.82 6954.71 N 1938.35 W 9900.00 9956.00 6976.24 N 1908.15 W 9899.87 9955.87 7012.14 N 1856.56 W 9908.17 9964.17 7069.39 N 1775;04 W 9914.92 9970.92 7093.89 N 1740.44 W 9925.16 9981.16 7126.39 N 1694.66 W 9943.09 9999.09 7183.33 N ,, 1614.44 W 9961.03 10017.03 7240.28 N 1534.22 W 9978.61 10034.61 7296.13 N 1455.55 W 9978.96 10034.96 7297.23 N 1454.00 W 9999.94 10055.94 7350.12 N 1371182 W 10026.62 10082.62 7394.82 N 1286.49 W 10050.00 10106.00 7422.48 N 1221.49 W 10058.53 10114.53 7431.13 N 1199.00 W 1.0091.90 10147.90 7464.99 N 1111.01 W Global Coordinates ' Dogleg Vertical Northings Eastings Rate Section (ft). (ft) ('/~OOft) (fl) Comment 5977159.97 N 5977163.51 N 5977181.64 N 5977242.05 N 5977331.64N 5977419;51 N 5977460.26 N 5977495.44 N 5977568.82 N 5977642.2'1 N ,, . 5977715,60 N 59777.16,96 N 5977787,55 N' 5977855,99 N 5977920. i7 N 5977979.40 N 5978000.00 N 5978034.30 N 5978089.03 N 5978112.46 N 5978143.54 N 5978198.00 N 5978252.46 N 5978305.88 N 59783O6.93 N 5978'"~57.28 N 5978399.34 N 5978425.00 N 5978432.96 N 5978464.11 N 267872.06 E 267871.94 E 12.000 267871.75 E 12.000 267878.85 E 22.000 267907.43 E 22.000 267953.85 E 22.000 267982.92 E 22.000 268010.72 E 0.000' 268068.73 E . 0.000 268126174 E 0.000 268184.75 E 0.000 268185.83 E 0.000 268246.30 E 6.000 268314,72 E 6~000 268389,28 E 6,0oo 268469.16 E 6,000 268500.00 E 6.000 268552.67 E 6.000 268635.90 E 6.000' 268671.23 E 6.000 268717.98 E 0.000 268799.91 E 0.000 268881:84 E 0.000 268962.18 E 0.000 268963.76 E 6.000 269047.52 E 6.000 269134.i8 E 6.000 269200.00 E 6.000 269222.75 E 0.000 269311.73 E 0.000 2104.77 2106.90 2118.20 2161.82 2240.51 2331.96 2380 -23 2423.99 2515.30 2606.61 2697.92 2699.61 2791.06 2887.32 2985.67 ' 3085.01 '3121.93 3164.44 3283.54 3325.74 3381.62 3479,54 3577,47 3673~50 '3675.39 3772,14 '3933,17 3955,85 4044 Target: 3-07A/L-2.9 Int · . Target:. 3-07A/L-29 T1, GeologiCal 6 July, 1998 - 17:36 -1- DrillQuest Sperry-Sun Drilling Services Proposal Report for 3-07ALL-29 Wp5(r) Endicott MeasUred Sub-Sea Vertical Local C.<~ordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft)' . (ft) (fi) (ft) (ft) 15100.00 70.509 68.955 10125.26 10181.26 7498.84 N 1023.03 W 15200.00 70.509 68.955 10158.63 10214.63 7532.69 N 935.05 W 15300.00 70.509 68.955 10192.00 10248.00 7566.54 N 847.07 W 1 5323.99 70.508 68.956 10200~00 10256.00 7574.66 N 825.97 W DRAFT ONLY Global Coordinates Northings Easfings (ft) 5978495.25 N 269400.70 E 5978526.39 N . 269489.68 E 5978557.53 N 269578.66 E 5978565.00 N 269600.00 E Dogleg Vertical Rate Section (°~ OOn) (~t) , Comment Aa data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. · . The Dogleg Severity is in Degrees per lOOft. vertical section is from Well and calculated along an Azimuth of 49.130° (True). Based .upon Minimum Curvature type calculations, at a Measured Depth of 15323,99ft., The Bottom Hole Displacement is 7619.56ff., in the Direction of 353.777° (True).' 'o.o00 4133.21 0.00o 4221.90 0.000 4310.58 0.000 4331.'85 Target: 3-07A/L-29 T2, Ddllers Alaska State Plane Zone 3 Endicott SDI 6 July, 1998 - 17:36 .2- DrigQu~-Z [ Drill uest- Endicott Alaska State Plane Zone 3 Endldott SDi 3-07A/L-29 Proposal Data for 3-07A~-29 WpS(r) oeadO~.: Wd No~ P~e~nm: T~e Nodh 100S452 6tt?3a N ~0.07 W 2t04.77 7000 - 10105.26 6139,03 lq 2511.04 W 2IIL~3 l'~ O00 10]~5.63 6420.92 N 2.40~46 W 23~0 ~.~3 2~000 10042.01 ~3.~ N ?~13J! W 2699.61 o.~o 9~-~.oo 6~76.24 N t906,15 w 312L93 6.000 997~2 ' 7093.~ N 1740.44 W 33~.74 6.000 1(]034.61 72~,13 N 14.55_5.5 W 36~3...~0 0.000 IOI0~.00 74Zl.4S N 1~3L49 IN 3~3~.11 6.000' 102.~.Q0 7574.~ N 835.97 W 4131.85 O.0O0 .. Scale:. linch = 5OOft I -3000 -2500 Scale= 1 inch = 500ft Eastings -2~oo -t~oo -~qoo P~ -200o -1500 Enstlngs -lOOO -500 Refe~ is Tme No~th o - 6000~ ' = 10000 - > .~0500 - i I 2250 Ir~cale: 1inch = 50Oft I I [ I 2750 3250 3750 4250 Vertical Sectionsecti°n Azimuth: 49.130' (True North) NW Sec5 T11N R17E Umiat X:265980.55 Y:5978913.24 MD12895.00 X:267872,06 Y:5977159,97 5280 91046'08'' N Sec 5&4 o~ O0 5280 91043'42'' N Sec 4&3 o~ 5280 91°41'17" NE Sec3 T11N R17E Umiat X:281812.67 Y:5978435.49 SDI Well 3-07A/L-29 Wp5r Downhole Location Scale: 1"= 2000' 7/27/98 Jeff Cotton NW Sec 8 o~ 528O 91o46'07" N Sec 8&9 3-07A/L29 "3-07" SURFACE LOC. X=270193.64 Y=5970968.60 o~ 5280 91o43'42'' o~ N Sec 9&10 528O 91o41'16" [13 NE Sec 10 SW Sec8 T11N R17E Umiat X=265688.10 Y=5968357.70 5280 271o46'06'' S Sec 8&9 5280 271o43'40" S Sec 9&10 528O 271o41'16'' SE Sec10 T11N R17E Umiat X=281520.22 Y=5967880.08 NW Sec 5 T11N R17E Umiat X=265980.55 Y-5978913.24 NW Sec 8 528O 91 °46'08" MD12895.00 X=267872.06 Y=5977159.97 MD15323.99 TARG~ X=269600.00 I 1652 Y=5978565.00 I I I 3340 I I I o I I I I 5280 _. \ 91°46'07" ~ N Sec 5&4 528O 91 °43'42" o~ N Sec 8&9 528O 91o43'42" SDI WELL 3-07A / L-29 (Wp5r) - SURFACE & DOWNHOLE LOCATIONS 7~27~98 ITEM NAME I COMMENTS ALASKA STATE PLANE ZONE 3 (NAD 27) DECIMAL DEGREES (NAD 27) S & E SEC LINE OFFSETS SECTION, TOWN., NEAREST SECTION LINE OFFSETS NO. Y X LATITUDE (N°) LONGITUDE (VV°) , FSL FEE RANGE, UMIAT, AK DIST. LINE DIST. LINE 1 SDI 3-07A/L-29 Surface @ SDI Surface Location 5,970,968.60' 270,193.64' 70.322300° 147.863448° 2748 848 SEC 08 T11N R17E 2531 N 848 E --~-~ 5¥~3':-0'~L~:2 9- -I~b-i':i'~ ~'§-~'.'i~b ~ ;-~ ~'~';i"5-g~7 ......... -~'~7~-§~J~':~~-- - -~-~-39-0-;I-~ ....... ~1-~'~'~;~-:3-§~-4~ ............ ~§~ ........ ~3-3-~-~- ..... -§~-0-~-'¥-~-:~"~"-~-~-'/1~ ..... i-~-~ ............. ~ ............ ~-~- ....... i~-~1_.._7~~i~.~'~_~i_~ii~iiii.ii'i ................................ ~-~'~'t': ...................... i;i;_?~_~'~i~?~:~ ...... ~'~7~o:~-c~ .... ~-o:~,~-~:~-' -~-~:~-~,-o-.i'~"~'~ .......... ~-c~'~- ............ ~-~ ..... ~'~-~-~'~-~-~' ...... -~ ......... i-,- ....... ~ ......... Notes: All coordinates shown are North American Datum 1927 (NAD 27). Alaska State Plane Coordinates shown are Zone 3 (Feet). F. Robert Bell & Assoc. Jeff Cotton 564-4969 File Name: DIUBH727.xls 7/27/98 ~ALASKA4~ L) BP Exploration / Arco Alaska Date: August 19, 1998 To: Alaska Oil & Gas Conservation Commission Attn: From: Mr. Blair Wondzell Carol Withey Technical Assi~ Shared Services Drilling Mr. Blair Wondzell: On August 7, 1998, AOGCC approved a permit to drill well number 3-07A/L-29, permit approval number 98-147, APl #50-029-21911-01. However, the surface location, productive interval and total depth were incorrect. I have attached a revised permit to reflect the corrections with a copy of the well plan summary corrections. Since this package will need a full review, I expect you will need ten working days for processing and approval. We anticipate to begin drilling operations on August 24, 1998, however, we will delay the operations until we have approval to proceed. Please contact me at 564-4114 if you need additional information, or the drilling engineer, Mr. Chris West at 564-5089. On behalf of the drilling engineer, I apologize to you and your staff for any inconvenience this may cause. Cc: S. McMains Well File R.T. ELEV = 55.4' B.F. ELEV = 16.5' MAX. DEV.: 51:43 8600' M D 13-3/8", 68#/ft, L-80, Btrs Csg I 2502' 9-5/8", 47#/ft NT80S XO to NT95HS I 10222' TOP OF 7" LINER j 12207' J PERFORATING SUMMARY Ref. Log: DLL~GR (MSFL3/2/89) co.,-N/ INTERV, AL BAKER/ 5" DPC 13130' - 13270' 7", 29#/ft, SM-110, Btrs-TKC Date 02-01-89 03-14~89 10-25-94 ---RWO '- 13468' 13550' I I B~y J Comments JLH I INITIAL COMPLETION TREE: 4-1/16" / 5000 psi/Cooper WELLHEAD: 13-5/8" / 5000 psi / McEvoy SSSV L_ANDING NIPPLE OTIS (3.813" I.D.) W/SSSV MIN I.D. is 2" 4-1/2", 12.6#/ft, L-80, NSCT 1 487' GLM's (CAMCO), (1-1/2" RK) Latch No. TVDSS MD~BKB 3737' 12010' #2 } 3668' #1 9483' 12080' 12140' 12157' 12202' 12270' I OTIS "X" NIPPLE (3.813" I.D.) TIW SBR 9-5/8" PACKER TIW (HBBP) 3-1/2", 9.2#/ft L-80, TAILPIPE 3-1/2" 'SWS' NIPPLE Parker (2.750" I.D.) 3-1/2" 'SWN' NIPPLE Parker (2.635" I.D.) 3-1/2" WLEG ENDICOTT WELL' 3-07 / N-28 AP! NO. 50-029- 21 911 COMPLETION DIAGRAM BP EXPLORATION, INC. R..T. ELEV = 55.4' B.F. ELEV = 16.5' MAX. DEV. = 51:43 8600' MD 13-3/8", 68#/ft, L-80, Btrs Csg I2502' I ~ ~ 9-5/8", 47#/ft NT80S XO to NT95HS 10222' ~ TREE: 4-1/16"/500(~ psi/Cooper WELLHEAD: 13-5/8" / 5000 psi / McEvoy SSSV LANDING NIPPLE OTIS (3.813" I.D.) W/SSSV MIN I.D. is 2" I 1487' I 4-1/2'% 12.6#/ft, L-80, NSCT GLM's (CAMCO), (1-1/2" RK) Latch No. TVDSS MD-BKB #2 3668' 3737' #1 9483' 12010' Well loaded with 8.6 ppg seawater TOP OF 7" LINER I12207' ! 9-5/8", 47#/ft, NT95HS, NSCC I12504' I ~ PERFORATING SUMMARY Ref. Log: DLL-GR (MSFL3/2./89) ~NATKEERRVIL5" DPC 13130' - 13270' Tagged PBTD @ 13307' PBTD 7", 29#/ft, SM-110, Btrs-TKC 13468' J 13550' I Date BV FH Comments 02-01-89 PROPOSED COMPLETION 03-14-89 JLH INITIAL COMPLETION 1 (3-PR-.q4 JTP POST RWO ~ OTIS "X" NIPPLE ! 12080, (3.813" I.D.) TIW SBR 12140' TIW (HBBP) 9-5/8"PACKER I 12157' ! 12167' Milled 5-1/2" x 3-1/2" Crossover 3.80" Drift Proposed whipstock setting depth @ 12895' MD 11 bb115.6 ppg cement plug f/13307- 13000' Milled off 3-1/2" tail pipe Overall Length: 103' ENDICOTT WELL' 3-07 / N-28 APl NO. 50-029- 2191 1 PROPOSED COMPLETION DIAGRAM I I , · I II I I I TREE: 4-1116"1 50¢' psi/Cooper R.T. ELEV = 55.4' WELLHEAD: 13-5/8" / 5000 psi/McEvoy B.F. ELEV = 16.5' MAX. DEV. = 51:43 8600' MD SSSV LANDING NIPPLE ~ OTIS (3.813" I.D.) 13-3/8'", 68#/ft, L~80, Btrs Csg ! W/SSSV MIN I.D. is 2" 2502' 4-1/2", 12.6#/ft, L-80, NSCT GLM's (CAMCO), (1-1/2" RK) Latch No. TVDSS MD-BKB I 9-5/8", 47#/ft #2 3668' I 3737' NTSOS XO to NT95HS #1 i 9483' 12010' 10222' ' (3.813" i.D.) 12080' Est. 2-7/8" liner Top 12115' i .~,~_~. TIW SBR [ 12140' 9-5/8" PACKER TOP OF 7" LINER ~ ~ TIW (HBBP) 12157' -""- ~ I~1 Milled 5-1/2" x 3-1/2" Crossover 9-5/8", 47#/ft, NT95HS, NSCC 3,80" Drift I 12504' Proposed ~,..... 2-7/8" liner F/12115-15324' whipstock setting depth @ 12895' MD ~ - ~ ...................... PERFORATING SUMMARY Ref. Log: DLL-GR (MSFL 3/2/89) ;~,.:~.~ ... CO.iNTERV,\LGUN ,~.PF " '~ 3-3/4" Hole to 15324' MD BAKER 5" DPC 4 13130'- 13270' 18 bbl 15.6 ppg ~ ~.~ cement plug f/13307-13000' Tagged PBTD @ 13307' ~ OveralIMilled off 3-1/2°' 103'tail pipe Length: '. I I Date By Comm.ents ENDICO'I-T WELL: 3-07 / N-2R 02~01-89 FH PROPOSED COMPLETION AP! NO. 50-029- 2191 1 03-14-89 JLH INITIAL COMPLETION PROPOSED COMPLETION DIAGRAM 10-25-94 JTP POST RWO --- RP F'X'Pl ~RATIf]N I Well Name: 3-07a/L-29 Well Plan Summary Type of Well (Producer or injector): Well Design (Conventional, slimhole, etc.)' Producer TTRD SIDETRACK FSL FEL SEC TWP RNG Surface Location: 2748 848 8 11N 17E Top of Kekiktuk is above KOP: Target 1 Location: 3585 3340 5 11N 17E Target 2 - Bottom Hole Location: 5043 1652 5 11N 17E I AFENumber: 1727028 Estimated Start Date: IAugust I Rig: I DOYON 15 I Formation Markers Well Bore: Formation Tops MD TVDSS EMW RESERVOIR PRESSURE KBE -56 Max surface pressure =3596 psi TOP WEST SAK Above KOP TOP SEABEE/AYLYAK Above KOP TOP SHALE WALL/TUFFS Above KOP TOP HRZ Above KOP BASE HRZ 9718 Above KOP PUT RIVER Above KOP LCU 9739 Above KOP KEKIKTUK - Top 3A2S 9.3 ppg Above KOP 3A1 Above KOP K2B(2900F) 14037 9906 9.0 ppg Above KOP (Note inverted well) K2M (2400SB) 13700 9954 KOP 12,895' MD / 10028' TVDss K2A (2300F) 14037 10010 8.7 ppg 44000psi @ 9901' TVDss Target COWC 15264 10180 K1 (2000) 15323 10200 8.0 ppg 4850 psi @ 10050' TVDss Target TD 15323 10200 Logging Program: MWD-GR ILogs: 3.75" Hole Curve and Tangent DPC Open Hole Cased Hole: GR/Res NA Casin.c/Tubinc. Pro . ram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVDSS 3.75 2.875" 6.4 L-80 STL 3324 12000/9408 15324/10200 TBG* 4.5" 12.6 L-80 NSCT 12,119 38 12,157/9515 N-ote: The existing tubing will be left in place and re-used. The 3.5" tubing tail will have to be milled off, and the 2.875" liner hung 150 feet above the existing packer. 3-07a/L-29 Drilling Program - DRAFT Directional Plan WP# 5 8/19/98 Page 3 Brilling Discussion General .!. The proposed sidetrack of the 3-07a/N-28 to the L-29 location will access the lower 2A oil column, which not been sufficiently depleted by 3-07/N-28 due to high water production. This will establish an offtake point away from the east-west trending fault system just north of the 3-07/N-28. The L-29 BHL targets a drainage area of 70 acres with a P50 estimate of 0.96 MMSTBOIB Expected initial rate is 2000 BOPD at a GOR of 1500 scf/stb and a watercut of 40%. The well will be sidetracked in the 7" casing below the P3 coals. The present 4-1/2" L~80 completion will remain in place during the sidetrack operation. A 2-7/8" liner will be run and cemented in place. The liner will be selectively perforated using coil tbg after the rig moves off location. The 3-07a/L-29 sidetrack represents the third implementation of 'I-I-RD technology at Endicott as a cost effective alternative to conventional sidetracking. The 3-07a well on SDI at Endicott will target the Kekiktuk in the 2A in accordance with the 1998 development plan. We will have to abandon the existing perforation in the 3-07a/N-28 well by setting a cement plug with coil-tubing. The well will be sidetracked off the cement plug to the new L-29 BHL utilizing the 2.875" liner STL design. The existing production packer or tubing will not be pulled. The 2.875" liner length will be +_ 3324 feet, with the top of the tie back into the 4.5" production tubing just below the 7" x 4- 1/2" production packer. The existing 2 valve slimhole (4.5" x 1.0" for 7.0" casing) GLM design will be used after the well is completed. The 4.5" L-80 tubing design will remain. Directional Plan: The directional plan for the 3-07a/L-29 well consists of kicking off with a whipstock and conventional BHA's for the Kekiktuk Flow sands. The plane KOP will be in the 2B Sand below the LCU and HRZ. Current plans call for up to 22°/100' doglegs in this section, but this may be adjusted pending results during the drilling process. After sidetracking, drill the inverted tangent at 110°, and then dropping angle @6°/100' through the two targets. The planned TD is 15,324' MD (10200' TVDss) in Zone 1. The only close approach is the existing 3-07 well which quickly diverges from the sidetrack path. The closest offset well is 3-09/L-28 which is 451 feet away at 13,700' MD. The KOP below the HRZ is a result of the HRZ and coal problems encountered in Well 3-17/M-31. Ensure that any and all tolerance lines are not crossed to avoid policy violations. Please coordinate this through both the Operations Drilling Engineer and the Endicott Drilling Superintendent. There are not any known close approaches which require wells be shut in. Any BHA's indicating less than required BUR should immediately be pulled for a more aggressive assembly. Recommended BHA's All motors should NOT be jetted to account for the proposed flowrate a'nd:"rhotor, performance. Hole conditions and directional objectives should dictate actual flowrates. As mentioned previously, flex collars should be utilized to minimize potential differential sticking. We will be using bent housing motors with either 7/8 for a roller cone or 5/6 rotor/stator configurations for PDC bits. Sperry proposed BHA's are attached, however the actual BHA with motor design, MWD tool configuration, MWD battery life, bit hydraulics will be discussed at the daily wellsite meeting. DRILLING CLOSE APPROACH WELL SHUT-INS The closest well bore is the original well 3-07/N-28 which quickly diverges from the sidetrack. The closest offset well is 3-09/L-28 which is 451 feet away at 13,700' MD. This well will meet the deep intersection risk assessment. Close attention to the tolerance lines are necessary to avoid this well. See the TC plot for details. 3-07a/L-29 Drilling Permit Directional Plan WP# 5 7/30/98 PORE PRESSURE / LOST CIRCULATION Production Interval (3.75"):. The Kekiktuk Sands (3A) reservoir pressure could be higher than normal at 8.95 ppg (based on well 1-39/P-17 SBHP). The formation also has the (slight) potential for lost circulation (see Geologic Prognosis for faulting details). Lubricant additions (see above) should be utilized if torque and drag become troublesome, and after extensive testing of mud on location. Flex collars should be utilized in the BHA to minimize potential differential sticking. Liquid casing and OM seal should be on location to help combat severe lost circulation. NOTE: See the Geologic Prognosis for a detailed description of the expected fault locations and sizes. Review the Pad Data Sheet for trouble highlights throughout MPI history. Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Special XOS for drillpipe are available for this well. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Waste Disposal Cuttings Handling: CC2A Fluid Handling: Annular injection is not available at Endicott for this well. Directional Survey Program The survey program for 3-07a/L-29 calls for use of Sperry's SOLAR MWD surveys the entire well. Because of Sperry's standard practice of changing the MWD probes after every bit run, an electronic single shot (ESS) will not be needed, and a gyro is not warranted. Close attention to JORPS is required, with the use of checkshots and survey data validation. A PWD sub will be run with the MWD probe to record actual bottom hole pressures. Bit Program After milling a 3.80" window off of a whipstock, a 3.75" build section followed by a short tangent section and a drop section is planned. The entire well will be drilled with the PDC bits (depending on directional control) to allow for more flow area around the BHA. The penetration rate will vary due to the variable lithology, but these bits have proven durable when CT drilling the Sadlerochit in the PBU. Recommended Jet Sizes Expected Interval Bit Type Flowrate HSI Casing Section Standard Baker TTRD 90 - 120 gpm ' Window Mills Kickoff 3.75" HTC 335 90 - 100 gpm 0.371 < 1 Tangent 3.75"x4.25"Bicenter DPI 566 90- 100 gpm o.371 < 1 '3.75" (If bicenter not HTC 335 90 - 110 gpm 0.371 < 1 drilling) , NOCE~: Real time rigsite information such as condition of bits previously pulled, hole conditions, drilling fluids, downhole motor constraints (if any) will be instrumental in actual final bit selection. 3-07aJ'L-29 Drilling Permit Directional Plan WP# 5 7/3O/98 Mud Program' The cement pilot hole and ramp to the casing wall will be milled using slick seawater (1- 1.5 ppb N-vis). The well will displaced to a 10.0 ppg brine prior to POH to mill the window. The 10.0 ppg brine will be used to mill through the casing and drill 5 ft of new 3-3/4;' open hole. Hi-vis sweeps in the 10.0 ppg brine will be used to clean the metal cuttings from the well. The 10.0 ppg brine will be displaced with 10.0 ppg Quik Driln. Save the 10.0 ppg brine to be used as a tripping fluid to reduce the surge and swab pressures. The brine may have to be replaced due to hi-vis sweeps increasing the fluid rheology. Immediately after displacing the well to 10.0 ppg mud, add 0.5 ppb of Barascav D. Tourly sulfite checks should be made to ensure that residual sulfites of 150mg/L are maintained with Barascav D. Make sure DITCH MAGNETS are used both in the possum belly and suction pits for maximum metal removal benefit throughout milling and drilling operations of this well. See Bariod mud recommendation for exact mud parameters. While milling the window, run the solids control equipment (shakers and rig centrifuge) to remove the cement and metal from the brine. The Bariod solids control van should be operational prior to drilling any new formation with Quik Dril fluid. This will help keep the PV down, which is the main driver of circulating pressure. Since the mud weight is maintained with NaBr, the centrifuges can be run continuously without reducing the mud weight. Whole mud dilution or complete swapout may be needed to keep as clean a system as possible. Calcium must be under 100 ppm prior to adding EP Mudlube. Maintain a 1/2 ppb buffer of Bicarb/Soda ash if EP Mudlube is added. A Iow vis, weighted brine sweep prior to the cement slurry may be needed to clean the hole. This will facilitate a better cement job. Tripping Practices / Stuck Pipe / Hole Cleaning / Reaming Tripping should be undertaken with caution due to swabbing possibilities with high viscosity fluids and the tight annular clearance. A 10.0 ppg brine trip fluid will be needed due to the high swab pressures encountered while drilling the SDI 3-17C TTRD well. The bottom hole pressure could be as high as 4700 psi (+/- 9.3 ppg ). The mud weight is recommended to be maintained in the 10.0 ppg range to allow for formation pressure uncertainties. If swabbing becomes a problem, the well will be displaced to a trip fluid (10.0 ppg brine) to minimize swab pressures. Faulted intervals may require additions of LCM prior to tripping to insure that the hole remains full at all times. Keep the pipe moving and have an ample supply of lost circulation materials on hand. Baroid recommends utilization of Iow viscosity sweeps to assist with hole cleaning and to minimize the formation of cuttings beds on the Iow side of the hole. After getting back to bottom after a trip, bring pump on very slowly to minimize surge pressures. Pipe should be pulled and run very slowly (4-5 minutes/stand) in the open hole to reduce pressure fluctuations. Hole Cleaning Based on the PWD (Pressure while Drilling) review from the SDI 3-17C well.,, hole packo, ff due to elevated ECD through the HRZ shale was the primary cause of hole instability. The planned well (3-07a/L-29) will be kicked off below the HRZ in the Kekiktuk formation to eliminate the exposure to the HRZ. Hole cleaning in the sand will be one of the primary functions of the drilling fluid. The Quik Driln fluid has been used extensively on the North Slope as a Reservoir drill in mud. The reservoir studies have showy5 that this fluid causes little formation damage. The polymer based mud is shear thinning is an excellent hole cleaning mud. This fluid type is used exclusively by the CT drilling group. The ECD data also showed that numerous short trips and circulating is needed to clean the hole. If any coal is encountered, drill only 1-2 ft prior to circulating the hole clean. Coal also caused packoff problems in the 3-17C well. The coals will probably not be 3-07aiL-29 Drilling Permit 7/30/98 Directional Plan WP# 5 id'entified until the cuttings reach the shaker. During the expected coal interval, we should control drill no more than 3 - 5 feet at a time, and circulate bottoms up before continuing. The warning signs for coal packoff are pressure or torque fluctuations, coal cutting across the shaker, hole fill after connections, return flow fluctuations, and increase of drag. To identify and minimize problems, this information must to recorded on the driller handover sheet to track trends. Reaming Reaming in TTRD wells require much closer attention while reaming than conventional wells due to the affect of ECD and pipe movement in very close annular clearance. This is important both while drilling the reservoir, and any time there are unstable formations such as coals or the HRZ exposed. Mud properties must be maintained within the specified parameters at all times. If mud properties are not within range, drilling operations should cease, and the mud conditioned before continuing. Every attempt to rotate rather than slide will assist hole cleaning, and minimize reaming. If we do have to ream, it should be at reduced ( < 50% of drilling circulation rate) circulation rate and only up-ream. The combined affects of ECD and down-reaming put excessive pressure on the formation and will cause hole collapse. Equivalent Circulating Density The PWD (recorded data) sub will be run in this well to record the downhole pressure parameters. This data was very useful in evaluating the problems encountered in the previous well. Confirm with the onsite Sperry Sun personnel that the PWD software has been upgraded for quick data output. The higher ECD due to the high rheology Quik Dril mud should not be a problem in the Kekiktuk sand. This fluid type was used in the PBU TTRD wells to drill the Sadlerochit sand without problems. Any hole problems should be immediately reported so a revised drilling plan can be formulated. H2S Concerns The SDI 3-07/N-28 production stream recorded XXX ppm of H2S in 3/98. There have been H2S reading on offset MPI wells of over 1000 ppm. Ensure rig gas detectors are calibrated prior to N/D tree and/or circulating to kill the well. Logging Program: The MWD-GR log will be the only MWD log. A PWD sub will be run while drilling the 3- 3/4" hole to record downhole pressures. Drill pipe conveyed (DPC) GR/Res will be run for WOC determination. Schlumberger will provide the side door sub and wet connect for the DPC tool string. Sample catchers and a wellsite Geologist are planned to be used while drilling reservoir. Casing and Cementing This TTRD sidetrack will require a 2.875" 6.4# L-80 liner with STL connections to-be run across the entire interval. The top of the 2-7/8" liner will in the 4.5" tubing at 12,000+/- MD (Just above the 7"x 4-1/2" packer @ 12,157'md). Ensure that prior to running liner that the hole is in good condition and that the mud has been conditioned to run casing. Before POH to run liner, spot lubricant across the open hole section. If this is considered essential to getting the pipe to bottom ensure that adequate lubricant testing has been performed prior to doing this. Also, consideration must be given to a hole o. pener trip prior to running liner if hole conditions suggest that there may be problems running pipe. The liner should be filled every 5 joints, and circulated prior to going into open hole. Any problem intervals identified while drilling, such as ledges, will require special care while running casing through. The liner will require 1 turbolator (2-7/8" x 3-5/8") centralizers on every other joint to the window. Integral centralizers (STL connections) may be run in place of the latch-on turbolators to eliminate turbolators moving on the 3-07a/L-29 Drilling Permit Directional Plan WP# 5 7/30/98 lirier. If the liner starts to packoff in the open hole, establish circulation and try to wash through. Do not continue to run casing without circulation. If necessary, we will pull the liner and make a wiper trip prior to running the liner. The liner running procedure in the detail section should be reviewed. This liner will be run with a PBR only. There is an option to run a packer after cementing operations. The cementing program is designed to place cement back to within 350' (12,495' MD) the production tubing tail. The approximate volume will be 100 sacks (21 bbls) of Class 'G' with additives as specified in the casing detail section. Cementing operations at Endicott are continue to be critical with the advancement of both the waterflood and gas fronts. Close attention to detail for this part of the well is critical for the economical success of our drilling program. CT Conveyed Perforating This sidetrack well will require coil tubing perforating across the intervals picked from LWD GR and GR/RES logs after the rig is released. 3-07a/L-29 Drilling Permit Directional Plan WP# 5 7/30/98 Endicott Measured Depth (ft) 12895.00 12900.00 12925.00 13000.00 13100.00 13200.00 13252-07 13300.00 13400.00 13500.00 13600.00 13601.85 13700.00 13900.00 14000.00 14037.14 14100.00 14200.00 14242.94 14300.00 14400.00 1450O.00 14598.07 14600.0O 14700.00 14800.00 14874.43 14900.00 150O0.00 Incl. 44.808 45.288 47.722 61.497 8o.871 lOO.545 110.697 110.697 110.697 1 lO.697 11o.697 11o.697 lO6.602 lO2.337 98.005 93.630 92,000 88.233 82.241 79.668 79.668 79.668 79.668 79.668 79.602 76.189 72.8&3 70.509 70.509 70.509 Sub-Sea Depth Vertical Depth (.) Sperry-Sun Drilling Services Proposal Report for 3-07ALL-29 Wp5(r) ONLY Local Coordinates Northlngs Eastings (ft) (ft) Alaska State Plane Zone 3 Endicott SD! 355.927 10028.52 10084.52 6117.38 N 2510.07 W 356.436 10032.05 10088.05 6120.91 N 2510.31 W 358.855 10049.26 . 10105.2.6 6139.03 N 2511.04 W 10.072 10092.68 10148.68 6199.63 N 2505.80 W 21.156 10124.87 10180.87 6290.05 N 2479.98 W 31,052 10123.64 10179.64 6379.30 N 2436.27 W 36.570 10109.63 10165.63 6420.92 N 2408.46 W 36.570 10092.69 10148.69 6456.93 N 2381.75 W 36.570 10057.35 10113.35 6532-06 N 2326.01 W 36.570 10022.01 10078.01 6607.19 N 2270.28 W 36.570 9986.66 10042.66 6682.32 N 2214.54 W 36.570 9986.01 10042_01 6683.72 N 2213.5.1 W 41.039 9954~62 10010.62 6756.12 N 2155;23 W 45.398 9929.62 9985.62 6826.62 N 2088.93 W 49.616 9911.96 9967.96 6893.06 N 2016.37 W .. 53.745 9901.82 9957.82 6954.71 N 1938.35 W 55.266 9900.00 9956.00 6976.24 N 1908.15 W 55.073 9899.87 9955.87 7012.14 N 1856.56 W 54.765 9908.17 9964.17 7069.39 N 1775.04 W 54.630 9914.92 9970.92 7093.89 N 1740.44 W 54.630 '9925.16 9981.16 7126.39 N 1694.66 W 54.630 9943.09 9999.09 7183.33 N ,, 1614.44 W 54.630 9961.03 10017.03 7240.28 N 1534.22 W 54.630 9978.61 10034.61 7296.13 N 1455.55 W 54.726 9978.96 10034.96 7297.23 N 1454.00 W 59.774 9999.94 10055.94 7350.12 N 1371.82 W 64.970 10026.62 10082.62 7394.82 N 1286.49 W 68.955 10050.00 10106.00 7422.48 N 1221.49 W 68.955 10058.53 10114.53 7431.13 N 1199.00 W 68.955 10091.90 10147.90 7464.99 N 1111.01 W Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (fi) (°/lOOff) (fl) Comment 5977159.97 N 267872-06 E 2104.77 5977163.51 N 267871.94 E 12.000 2106.90 5977181.64 N 267871.75 E 12.000 2118.20 5977242.05 N 267878.85 E 22.000 2161.82 5977331.64 N 267907.43 E 22-000 2240.51 5977419.51 N 267953.85 E 22.000 2331.96 5977460.26 N 267982.92 E 22.000 2380.23 5977495.44 N 268010.72 E 0.000 ' 2423.99 5977568.82 N 268068.73 E 0.000 2515.30 597764221 N 268126.74 E O.000 2606.61 5977715.60 N 268184.75 E 0.000 2697.92 59777.16.96 N 268185.83 E ' 0.000 2699.61 5977787.55 N 268246.30 E 6.000 2791.06 5977855.99 N 268314.72 E 6;000 2887.32 5977920.17 N 268389.28 E 6.000 2985.67' 5977979.40 N 268469.16 E 6.000 3085.01 5978000.00 N 268500.00 E. 6.000 3121.93 5978034.30 N 268552.67 E 6.000 3194.44 5978089.03 N 268635.90 E 6.000 3283.54 5978112.46 N 268671.23 E 6.000 3325.74 5978143.54 N 268717.98 E 0.000 3381.62 5978198.00 N 268799.91 E 0.000 3479.54 5978252.46 N 268881.84 E 0.000 3577.47 5978305.88 N 268962.18 E 0.000 3673.50 5978306.93 N 268963.76 E 6.000 ' 3675.39 5978357.28 N 269047.52 E 6.000 3772.14 5978399.34 N 269134.18 E 6.000 3865.92 5978425.00 N 269200.00 E 6.000 '3933.17 5978432.96 N 269222.75 E 0.000 3955.85 5978464.11 N 269311.73 E 0.000 4044.53 Target: 3-07AIL-2,9 Int Target 3-07A/L-29 T1, Geological Con#hued... July, 1998 - 17:36 -1- Drill(2uest .. Sperry-Sun Drilling Services Proposal Report for 3-07ALL-29 Wp5(r) Endicott Measured Sub-Sea Vertical Local C6ordinates Depth incl. Azim. Depth Depth Nc, things Eastings (ft) (ft) (ft) (ft) (ft) DRAFT ONLY Global Coordinates Northings Eastings (ft) Dogleg VedJcal Rate Section (°/~00ft) (ft) Comment 1510o.oo 70.509 68.955 10125.26 10181.26 7498.84 N 1023.03 W 5978495.25 N 269400.70 E 15200.00 70.509 68.955 10158.63 10214.63 7532.69 N 935.05 W 5978526.39 N 269489.68 E 15300.00 70.509 68.955 10192.00 10248.00 7566.54 N 847.07 W 5978557.53 N 269578.66 E 15323.99 70.508 68.956 10200.00 10256.00 7574.66 N 825.97 W 5978565.00 N 269600.00 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. 0.000 4133.21 0.000 4221.90 0.000 4310.58 0.000 4331.85 Tan:jet: 3-07A/L-29 T2, Ddliers The Dogleg Severity is in Degrees per lO0ft. Vertical Section is from Well and calculated along an Azimuth of 49.130° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15323.99ff., The Bottom Hole Displacement is 7619.56ft., in the Direction of 353.777° ('r'rue).' Alaska State Plane Zone 3 Endicott SD! 6 July, 1998 - 17:36 - 2 Endicott Alasl~a State Plane Zone 3 Endldott SD! 3-07A/L-29 Proposal Data for 3-O?A/L-29 WpS{r) v~tic~ Sectioa Deecr~x~Wea -" Vertical S~c~ 0dgln: O.00 N,0.00 E .~_alo: linch = 500ft Eastings -2q00 -l~jO0 -tqOO 7500 - 7000- 6500 - .-. 3-OZg/L-29 let Point ~7~.24 ~ Ig~8.15 IY I -3000 -2500 Scale: linch = 50Oft -2000 -.1500 Eastings .t: I 0000 0500 1750 l~cale:, linch = 500ft . % tm,~.~ · ~-' ~ :,'.": "-"* i"'.'~' 7574.fl8 ~ 825.97 ~i~ I I I I I 2250 2750 3250 3750 4250 Vertical Sectionsection Azimuth: 49.130' (True North) I DrillQuest" 1O2OO $-07~l,-2g 1'I 7422.~4~ ~ I ZI L 49 ~K 7574~ ~ ~ - 7500 ~.97 kV - 7OO0 - 65O0 e- - 6000~ ' o -t oo0 -500 Reference is Tme North NW Sec5 T11N R17E Umiat X=265980.55 Y=5978913.24 o~ 528O 91%6'08" N Sec 5&4 q,~O~ ///'FM D 15323.9 q'.,~-~5'~,'''/:I:,~RGET q,"bO ~' X=269600 _~ Y=597856 MD12895.00 ~ ~"-" ~ o~' 5280 91 °43'42" N Sec 4&3 528O 91o41'17,, o~ NE Sec3 T11N R17E Umiat X=281812.67 Y=5978435.49 SDI Well 3-07A/L-29 Wp5r Downhole Location Scale' 1"= 2000' 7/27/98 Jeff Cotton NW Sec 8 N Sec 8&9 528O 91o46'07'' 3-07A/L29 "3-07"SURFACE LOC.,.¢\ X=270193.64 Y=5970968.60 o~ 5280 91o43'42'' o~ N Sec 9&10 5280 91o41'16'' NE Sec 10 !'"' '?:': · ';i-i :: SW Sec8 T11N R17E Umiat X=265688.10 Y=5968357.70 5280 271o46'06'' S Sec 8&9 528O 271043'40'' S Sec 9&10 528O 271o41'16'' SE Sec 10 T11N R17E Umiat X=281520.22 Y=5967880.08 NW Sec5 T11N R17E Umiat X=265980.55 Y=5978913.24 NW Sec 8 528O 91 "46'08" MD12895.00 X=267872.06 Y=5977159.97 MD15323.99 TARGET 1652 X=269600.00 Y=5978565.00 I I I 3340 I I I I I I I I I I I I I i ,I 5280 _ \ 91':'46'07" N Sec 5&4 528O 91 °43'42" N Sec 8&9 5280 91o43'42'' I ~ SDI WELL 3-07A / L-29 (Wp5r) - SURFACE & DOWNHOLE LOCATIONS 7/27/98 ITEM, NAME i COMMENTS ALASKA STATE PLANE ZONE 3 (NAD 27) DECIMAL DEGREES (NAD 27) !S & E SEC L NE OFFSETS! SECTION, TOWN., ! NEAREST SECTION LINE OFFSETS NO. i r I Y ; x LATITUDE (U°) I LONGITUDE (VV~) 'FSL t FEL I RANGE, UMIAT, AK ! DIST. I LINEt DIST. ILINE i 1 j SDI 3-07A/L-29 Surface @ SDI Surface Location 5,970,968.60' 270,193.64' 70.322300° 147.863448° 2748 848 SEC 08 T11N R17E 2531 N I 848 E ..... 2'-I ....... '~'D-i" ~3'L'~¢A~L229'MD':'i28'9'5-.00''i .......................................................................... 5;'977,';i'59:'9'~'r''I .... '26~78-~-:~'.-(~'~ ......... ~-b-5~'~-°-~-2-~--'i"--~-~,¢':8i~-~-'i-~:~"--I ..... ~'i~ .... i'-~-:~-5--?§~-i~.~-?-~"~"fi-R¥?'E~i ......... ~'i~ ..... !-N"; ...... ~'-¢~ ..... '-3-'-i ..... -§'b'1--3':57-~'1'-:~29'-M5i'1~53-5~3~'9 ..... i ¥~Tg'~t': i'-"8;978;56'81b-8'--'7 ...... 2'6~,-~8'~':b-0; ...... ~b~.~29--~';~~'-'-'''! :i"~7.§'f0-i-5':1'¥"'"i ..... 8'0'4~ .... i ..... ;i'~-~-'-i--S-~'~ 0--5--~'1-~1"N-i~"~-TE"i ..... ~-3'~ ....... 'N-'"I ......... i'~8;~ ...... i" Notes: All coordinates shown are North American Datum 1927 (NAD 27). Alaska State Plane Coordinates shown are Zone 3 (Feet). F. Robert Bell & Assoc. Jeff Cotton 564-4969 File Name: DIUBH727.xls 7/27/98 BP Exploration / Arco Alaska Date: August 19, 1998 To: Alaska Oil & Gas Conservation Commission Attn: From: Mr. Blair Wondzell · ,, ,- ~.[,, Carol Wlthey · · ., ~ Technical Ass~/~' Shared Services Drilling Mr. Blair Wondzell: On August 7, 1998, AOGCC approved a permit to drill well number 3-07A/L-29, permit approval numbe~.~~API #50-029-21911-01. However, the surface location, productive intervaT~-~d total depth were incorrect. I have attached a revised permit to reflect the corrections with a copy of the well plan summary corrections. Since this package will need a full review, I expect you will need ten working days for processing and approval. We anticipate to begin drilling operations on August 24, 1998, however, we will delay the operations until we have approval to proceed. Please contact me at 564-4114 if you need additional information, or the drilling engineer, Mr. Chris West at 564-5089. On behalf of the drilling engineer, I apologize to you and your staff for any inconvenience this may cause. Cc: S. McMains Well File WELL PERMIT CHECKLIST FIEl`.D & POOl... ............ ADMINISTRATION ENGINEERING DATE ... ~_~. ,,.~ GEOLOGY ANNULAR DISPOSAL 35. COMPANY _Z/:2 WELl_ NAME ,~..Z"Z../' .~ -~, PROGRAM' exp [_--I de serv [] wellbore segll ann. disposal para req'l __ /-,'~a~/ GEOL INIT CLASS ~_~_~ .... 1. Permil fee attached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number .................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N 14. Conductor string provided ................... ~,~/Y~NNi -- 15. Surface casing protects all known USDWs ........... N 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ,~;"~o~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N APPR DATE Y N Y N Y N 30. Permit can be issued w/o hydrogen sulfide measures ..... ~YYv N~,~. ~_.. . 31. Data presented on potential overpressure zones ....... Y ....... 32. Seismic analysis of shallow gas zones. ' 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports ...... ,/' Y N [exploratory only] With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEO--: ENGINEERING: UIC/Annular COMMISSION: BEV~d~z~.~ ~/'Z.~ WM .~ ~j?Jo DWJ~.,,.~ RP/~...~.~ ...... JDH ./'- - ' RNC '"'~ CO Comments/Instructions: Vl:r;hcklist u~v 05/29/98 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 o3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 6, 1998 Lowell Crane Drilling Engineering Supervisor BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Duck Island 3-07A/L-29 BP Exploration (Alaska) Inc. Permit No. 98-147 Sur. Loc. 2748~SL, 848'WEL. Sec. 36. T12N. R16E. UM Btmnholc Loc. 5043'NSL. 1652"vVEL, Sec. 31, T12N. R17E. UM Dcar Mr. Crane: Enclosed is the approved application for permit to rcdrill thc above referenced well. The permit to redrill docs not exempt you from obtaining additional pcrmits required by law from othcr governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient noticc (approximatcly 24 hours) must bc givcn to allow a r~prcscntativc of the Com~nission to witness a test of BOPE installed prior to drilling new hole. Notice max, be given bx' contacting thc Commission pctroleum ficld inspector on the North Slope pager at 659-3607. · Chairm,~~ BY ORDER OF THE COMMISSION dlffEnclosurcs CC~ Departmcnt of Fish &Gamc. Habitat Section w/o cncl. Dcpartmcnt of Environmental Conservation w/o cncl. STATE OF ALASKA ALASKA ~.~--.,-AND GAS CONSERVATION COM: iSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory I--I Stratigraphic Test [] Development Oili [] Re-Entry [] DeepenI []Service [] Development Gas [] Single Zone r'-I Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 56' Endicott Field / Endicott Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL312828 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2748' NSL, 848' WEL, SEC. 36, T12N, R16E, UM Duck Island At top of productive interval 8. Well Number Number 2S100302630-277 3585' NSL, 3340' WEL, SEC. 31, T12N, R17E, UM 3-07A/L-29 At total depth 9. Approximate spud date Amount $200,000.00 5043' NSL, 1652' WEL, SEC. 31, T12N, R17E, UM 08/05/98 lj5. Distance to near~st property line113. Distance t~ nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 034633I 3-09/L-28,451' at 13700 MD 4299.74 15323' MD / 10200' TVD 1 ~. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.O35 (e) (2)} KickOff Depth 12895' MD Maximum HoleAngle 51° Maximum surface 3845 psig, At total depth (TVD) 10050'/4850psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4# L-80 STL 3324' 12000' 9408' 15324' 10200' 103 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 13550 feet Plugs (measured) true vertical 10545 feet Effective depth: measured 13468 feet Junk(measured) true vertical 10487 feet Casing Length Size Cemented MD TVD Structural Conductor 92' 30" Driven 131' 131' Surface 2463' 13-3/8" 2690 cu ft. Permafrost 'E' 2502' 2500' Intermediate 12465' 9-5/8" 575 cu ft. Class 'G' 12504' 9811' Production 1342' 7" 410 cu ft. Class 'G' 12206' - 13550' 8604' - 10545' LinerRECEIVED ORIGINAl_ Perforation depth: measured 13130' - 13270' ' true vertical 10194' - 10292' ~.$~ 0]~ 8: Gas Colts. A,qch0mge 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ohris West, 564~5089 ~ 4,~ .~4¢2 'r~'~ ~8 Prepared By Name/Number: Carol Withey, 564-4114 21. I hereby certify that the fo/going is true/~d correct to the b6fst of my knowledge Signed ~ ~' _ ~ ~, L°well Cra~,~~~ /('~ CommissionTitle------D-rilling Engineering S u perviS°ruse Only Date '? "~/" ~"~ Permit Number I APl Number ~)pro?l D~e I See cover letter ~"_//.,,44'~ 50- O.Z_ ~-- .~,//~,,'"./--'<:2'/ - - ~ for other requirements Conditions of Approval: Samples Required []Yes J~ No Mud Log Required []Yes [] No Hydrogen Sulfide Measures I~lYes [] No Directional Survey Required J~Yes [-I No Required Working Pressure for BOPE 1-12M; E]3M; ]~5M; [-I10M; [-115M Other: Original Signed By by order of Approved By David W. Johnston Commissioner the commission Date ~::~- Form 10-401 Rev. 12-01-85 Submit In Triplicate STATE OF ALASKA ALASK~-;-OIL AND GAS CONSERVATION CO.¢IMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [-I Drill I~Redrill Ilb. Typeofwell [-]Exploratory [-I Stratigraphic Test I~ Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 56' Endicott Field / Endicott Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL312828 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2748' NSL, 848' WEL, SEC. 36, T12N, R16E, UM Duck Island At top of productive interval 8. Well Number Number 2S100302630-277 3585' NSL, 3340' WEL, SEC. 31, T12N, R17E, UM 3-07A/L-29 · Attotal depth ~9. Approximate spud date Amount $200,000.00 5043' NSL, 1652' WEL, SEC. 31, T12N, R17E, UM 08/05/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 034633I 3-09/L-28, 451' at 13700 MD 4299.74 15323' MD / 10200' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e) (2)} Kick Off Depth 12895' MD Maximum HoleAngle 51° Maximum surface 3845 psig, At total depth (TVD) 10050'/4850psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stagedata) 3-3/4" 2-7/8" 6.4# L-80 STL 3324' 12000' 9408' 15324' 10200' 103 sx Class 'G' · 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 13550 feet Plugs (measured) true vertical 10545 feet Effective depth: measured 13468 feet Junk (measured) true vertical 10487 feet Casing Length Size ' ".". Cemented MD TVD Structural Conductor 92' 30" Driven 131' 131' Surface 2463' 13-3/8" 2690 cu ft. Permafrost 'E' 2502' 2500' Intermediate 12465' 9-5/8" 575 cu ft. Class 'G' 12504' 9811' Production 1342' 7" 410 cu ft. Class 'G' 12206' - 13550' 8604' - 10545' Liner Perforation depth: measured 13130'- 13270' ~ "~ true vertical 10194'- 10292' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements ContactEngineerNarne/Nurnber: ChfisWest, 564-5089 ~4,~ 2¢:2¢.~/~ ?8 ProparedByNamo/Number: CarolWithoy, 564-4114 21. I hereby certify that the fo/going is true/~nd correct to the b6fst of my knowledge Signed ~ ~' , ~ / LewD,. C~¢' '-~7~. ,/?~,,4,,- .. Title_.__.__Drilling Engineering Supervisor Date '7 --~/'- ~"~ // Commissio'n Use Only , _ Permit Number I APl Number I Approval Date ....,I See cover letter 50 02. ~- / I - 7- ' - I ¢- 7 -forother requirements Conditions of Approval: Samples Required []Yes []No Mud Log Required []Yes [] No Hydrogen Sulfide Measures l~Yes •No Directional Survey Required J~Yes []No Required Working Pressure for DOPE []2M; []3M; [~ 5M; [] 10M; I--I 15M Other: dnginal Signed By by order of Approved By 9~,:!d W..Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate TREE: 4-1/16 ~000 psi/Cooper R.T. ELEV = 55.4' ~- ~ WELLHEAD: ~r~-~5/8" / 5000 psi / McEvoy S.F. ELEV = 16.5' MAX. DEV. = 51:43 8600' · D i I ~- SSSV LANDING NIPPLE O OTIS (3.813" I.D.) 1 487' 13-3/8", 68#/ft, L-80, Btrs Csg I W/SSSV MIN I.D. is 2" A 2502' ~-- , ~-- 4-1/2", 12.6#/ft, L-80, NSCT GLM's (CAMCO), (1-1/2" RK) Latch , No. TMUSS MD-BKB 9-5/8", 47#/ft i #2 3668' 3737' NT80S XO to NT95HS I i~__ #1 9483' 12010' I , 10222' ~'~ I I ' OTIS "X" NIPPLE I · ( -- (3.813" I.D.) 12080' 9-5/8" PACKER [ ~' ( TIW (HBBP) 12157' TOP OF 7" LINER ~ 3-1/2", 9.2#/ft L-80, TAILPIPE 12207' I ,~ I I~-- 3-1/2" 'SWS' NIPPLE ~! Parker (2.750" I.D.) 12202' 12504' I ~ · '~' ! ' · Parker (2.635" I.D.) 12234' / ~ '(-- 3-1/2" WLEG I 12270' PERFORATING SUMMARY Ref. Log: DLL-GR (MSFL 3/2/89) CO. ' GUN SPFI i ; I I . PBTD 13468' ~ i 7", 29#/ff, SM-110, 13550' ~ ! Alaska Oil?.. ¢ Cas r, . -,.-*,,,,-'. Btrs-TKC ~ ~. n r~,h n r,q ~.p. Date By Comments ENDICOTT WELL: 3-07 / N-28 02-01-89 FH PROPOSED COMPLETION APl NO_ 50-029- 2191 1 03-14-89 JLH INITIAL COMPLETION COMPLETION DIAGRAM 10-25-94 JTP 3OST F~wo BP EXPLORATION, INC. R.T. ELEV = 55.4' B.F. ELEV = 16.5' MAX. DEV. = 51:43 8600' MD 13-3/8", 68#/ft, L-80, Btrs Csg I2502' I ~ ~ 9-5/8", 47#/ft NT80S XO to NT95HS TREE: 4-1/16" / ~00 psi/Cooper WELLHEAD: 1~. 8" / 5000 psi / McEvoy SSSV LANDING NIPPLE I OTIS (3.813" I.D.) I 1487' W/SSSV MIN I.D. is 2" 4-1/2", 12.6#/ft, L-80, NSCT GLM's (CAMCO), (1-1/2" RK) Latch No. TVDSS MD-BKB I #2 I 3668' #1 9483' 3737' 12010' Well loaded with 8,6 ppg seawater TOP OF 7" LINER I12207, I ~ 9-5/8", 47#/ft, NT95HS, NSCC pI=RFORATIN~ ~UMMARY Ref. Log: DLL-GR (MSFL3/2/89) CO. GUN 5~PF INTERV,~,L BAKER 5" DPC 4 13130'- 13270' PBTD 7", 29#/ft, SM-110, Btrs-TKC Date 02-01-89 EH 03-14-89 JLH 10-25-94 JTP 7-20-98 JLH Comments PROPOSED COMPLETION INITIAL COMPLETION POST RWO Pre TI'RD ST OTIS "X" NIPPLE (3.813" I.D.) TIW SBR TIW (HBBP) 9-5/8" PACKER 12080' 12140' I 12157 ' I 12167' Milled 5-1/2" x 3-1/2" Crossover 3.80" Drift Proposed whipstock setting depth @ 12895' MD 11 bbl 15.6 ppg cement plug fl 13307- 13000' Milled off 3-1/2" tail pipe Overall Length: 103' ENDICOTT WELL' 3-07 / N-28 APl NO. 50-029- 21911 PROPOSED COMPLETION DIAGRAM BP EXPLORATION, INC. TREE: 4-1/16" / ~000 psi/Cooper R.T. ELEV = 55.4' WELLHEAD: ' ;/8" / 5000 psi / McEvoy B.F. ELEV = 16.5' .. MAX. DEV. = 51:43 '-~ J -- ~ ~= MD 8600' 1 sssv AN !NG I ~ ~1 -- OTIS (3.813 I.D.) I 13-3/8", 68#/ft, L-80, Btrs Csg : ~ W/SSSV MIN I.D. is 2" ~-- 4-1/2 , 12.6#/ft, L-80, I :~ NSCT i~ GLM's (CAMCO), (1-1/2" RK) Latch :~ No. TVDS~ MD-BKB 9-5/8", 47#/ft ~ #2 3668, 3737' NT80S XO to NT95HS ~-_ #1 9483 12010' I10222' I ~ --- I ~ ~----OTIS X NIPPLE I ,, ' _ :~ (3.813 I.D.) I Est. 2-7/8 liner Top ~'---~1 ~1 12 ' .,~ ~ TIW SBR I' 12140' TOP OF 7" LINER ~ ~~ ' i i~l ~~ I ..~.~-~, I ~ :~ ~ ~ Milled 5-1/2" x 3-1/2" Crossover 9-5/8", 47#/ft, NT95HS, NSCC ~ ~ [-- 3.80" Drift 2-7/8" liner F/12115-15324' Proposed /I~~~~J~ ..... whipstock setting depth @ 12895' MD J ~?.~. ~.~:~¥~::~.,,~:~:~,:~,:~?~i BAKER 5" DPC 4 13130' - 13270' J I ! I1~~ I ~ 8 bb115.6 ppg ' ' ' I cement plug f/,i 3307'13000' PBTD 13307' l~~ Milled off 3 1/2 tail pipe Tagged @ ~ ~l~'~e~;~: '~)'~'~"~"~ 7", 29#/ft, SM-110, ! , ! Btrs-TKC [ 13550 J Date By Comments ENDICOTI' WELL: 3-07 / N-28 02-01-89 FH PROPOSED COMPLETION APl NO. 50-029- 21911 03-14-89 JLH INITIAL COMPLETION PROPOSED COMPLETION DIAGRAM 10-25-94 JTP POST RWO 7-20-98 . JLH Pre~RO ST BP EXPLORATION, INC. CO. GUN 5;PF I NTERV~L BAKER 5" DPC 4 13130'- 13270' Drilling Discussion General iThe proposed sidetrack of the 3-07a/N-28 to the L-29 location will access the lower 2A oil column, which not been sufficiently depleted by 3-07/N-28 due to high water production. This will establish an offtake point away from the east-west trending fault system just north of the 3-07/N-28. The L-29 BHL targets a drainage area of 70 acres with a P50 estimate of 0.96 MMSTBOIB Expected initial rate is 2000 BOPD at a GOR of 1500 scf/stb and a watercut of 40%. The well will be sidetracked in the 7" casing below the P3 coals. The present 4-1/2" L-80 completion will remain in place during the sidetrack operation. A 2-7/8" liner will be run and cemented in place. The liner will be selectively perforated using coil tbg after the rig moves off location. The 3-07a/L-29 sidetrack represents the third implementation of 'I-I'RD technology at Endicott as a cost effective alternative to conventional sidetracking. The 3-07a well on SDI at Endicott will target the Kekiktuk in the 2A in accordance with the 1998 development plan. We will have to abandon the existing perforation in the 3-07a/N-28 well by setting a cement plug with coil-tubing. The well will be sidetracked off the cement plug to the new L-29 BHL utilizing the 2.875" liner STL design. The existing production packer or tubing will not be pulled. The 2.875" liner length wi~-be _ 3324 feet, with the top of the tie back into the 4.5" production tubing just below the 7" x 4- 1/2" production packer. The existing 2 valve slimhole (4.5" x 1.0" for 7.0" casing) GLM design will be used after the well is completed. The 4.5" L-80 tubing design will remain. Directional Plan: The directional plan for the 3-07a/L-29 well consists of kicking off with a whipstock and conventional BHA's for the Kekiktuk Flow sands. The plane KOP will be in the 2B Sand below the LCU and HRZ. Current plans call for up to 22°/100' doglegs in this section, but this may be adjusted pending results during the drilling process. After sidetracking, drill the inverted tangent at 110°, and then dropping angle @6°/100' through the two target"s. The planned TD is 15,324' MD (10200' TVDss) in Zone 1. The only close approach is the existing 3-07 well which quickly diverges from the sidetrack path. The closest offset well is 3-09/L-28 which is 451 feet away at 13,700' MD. The KOP below the HRZ is a result of the HRZ and coal problems encountered in Well 3-17/M-31. Ensure that any and all tolerance lines are not crossed to avoid policy violations. Please coordinate this through both the Operations Drilling Engineer and the Endicott Drilling Superintendent. There are not any known close approaches which require wells be shut in. Any BHA's indicating less than required BUR should immediately be pulled for a more aggressive assembly. Recommended BHA's All motors should NOT be jetted to account for the proposed flowrate and motor performance. Hole conditions and directional objectives should dictate actual flowrates. As mentioned previously, flex collars should be utilized to minimize potential differential sticking. We will be using bent housing motors with either 7/8 for a roller cone or 5/6 rotor/stator configurations for PDC bits. Sperry proposed BHA's are attached, however the actual BHA with motor design, MWD tool configuration, MWD battery life, bit hydraulics will be discussed at the daily wellsite meeting. DRILLING CLOSE APPROACH WELL SHUT-INS ._ Uh The closest well bore is the original well 3-07/N-28 which quickly diverges from t~ska sidetrack. The closest offset well is 3-09/L-28 which is 451 feet away at 13,700' MD. This well will meet the deep intersection risk assessment. Close a~ention to the tolerance lines are necessa~ to avoid this well. See the TC plot for details. 3-07a/L-29 Drilling Permit Directional Plan WP# 5 7/30/98 PORE PRESSURE / LOST CIR~-~LATION Production Interval (3.75"): The Kekiktuk Sands (3A) reservoir pressure could be higher than normal at 8.95 ppg (based on well 1-39/P-17 SBHP). The formation also has the (slight) potential for lost circulation (see Geologic Prognosis for faulting details). Lubricant additions (see above) should be utilized if torque and drag become troub!esome, and after extensive testing of mud on location. Flex collars should be utilized in the BHA to minimize potential differential sticking. Liquid casing and OM seal should be on location to help combat severe lost circulation. NOTE: See the Geologic Prognosis for a detailed description of the expected fault locations and sizes. Review the Pad Data Sheet for trouble highlights throughout MPI history. Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Special XOS for drillpipe are available for this well. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Waste Disposal ; Cuttings Handling: CC2A Fluid Handling: Annular injection is not available at Endicott for this well. Directional Survey Program The survey program for 3-07a/L-29 calls for use of Sperry's SOLAR MWD surveys the entire well. Because of Sperry's standard practice of changing the MWD probes after every bit run, an electronic single shot (ESS) will not be needed, and a gyro is not warranted. Close attention to JORPS is required, with the use of checkshots and survey data validation. A PWD sub will be run with the MWD probe to record actual bottom hole pressures. Bit Program After milling a 3.80" window off of a whipstock, a 3.75" build section followed by a short tangent section and a drop section is planned. The entire well will be drilled with the PDC bits (depending on directional control) to allow for more flow area around the BHA. The penetration rate will vary due to the variable lithology, but these bits have proven durable when CT drilling the Sadlerochit in the PBU. Recommended Jet Sizes Expected Interval Bit Type Flowrate HSI Casing Section Standard Baker 'I-I'RD 90 - 120 gpm Window Mills Kickoff 3.75" HTC 335 90 - 100 gpm 0.371 < 1 Tangent 3.75"x4.25"Bicenter DPI 566 90 - 100 gpm 0.371 < 1 3.75" (If bicenter not HTC 335 90 - 110 gpm 0.371 < 1 drilling) NOTE: Real time rigsite information such as condition of bits previously pulled, hole conditions, drilling fluids, downhole motor constraints (if any) will be instrumental in actual final bit selection. 3-07aiL-29 Drilling Permit Directional Plan WP# 5 7/3O~98 Mud Program: The cement pilot hole and ramp to the casing wall will be milled using slick seawater (1- 1.5 ppb N-vis). The well will displaced to a 10.0 ppg brine prior to POH to mill the window. The 10.0 ppg brine will be used to mill through the casing and drill 5 ft of new 3-3/4" open hole. Hi-vis sweeps in the 10.0 ppg brine will be used to clean the metal cuttings from the well. The 10.0 ppg brine will be displaced with 10.0 ppg Quik Driln. Save the 10.0 ppg brine to be used as a tripping fluid to reduce the surge and swab pressures. The brine may have to be replaced due to hi-vis sweeps increasing the fluid rheology. Immediately after displacing the well to 10.0 ppg mud, add 0.5 ppb of Barascav D. Tourly sulfite checks should be made to ensure that residual sulfites of 150mg/L are maintained with Barascav D. Make sure DITCH MAGNETS are used both in the possum belly and suction pits for maximum metal removal benefit throughout milling and drilling operations of this well. See Bariod mud recommendation for exact mud parameters, While milling the window, run the solids control equipment (shakers and rig centrifuge) to remove the cement and metal from the brine. The Bariod solids control:_.van should be operational prior to drilling any new formation with Quik Dril fluid. This will help keep the PV down, which is the main driver of circulating pressure. Since the mud weight is maintained with NaBr, the centrifuges can be run co~ntinuously without reducing the mud weight. Whole mud dilution or complete swapout may be needed to keep as clean a system as possible. Calcium must be under 100 ppm prior to adding EP Mudlube. Maintain a 1~ ppb buffer of Bicarb/Soda ash if EP Mudlube is added. A Iow vis, weighted brine sweep prior to the cement slurry may be needed to clean the hole. This will facilitate a better cement job. Tripping Practices / Stuck Pipe / Hole Cleaning / Reaming Tripping should be undertaken with caution due to swabbing possibilities with high viscosity fluids and the tight annular clearance. A 10.0 ppg brine trip fluid will be needed due to the high swab pressures encountered while drilling the SDI 3-17C TTRD well. The I:Jottom hole pressure could be as high as 4700 psi (+/- 9.3 ppg ). The mud weight is recommended to be maintained in the 10.0 ppg range to allow for formation pressure uncertainties. If swabbing becomes a problem, the well will be displaced to a trip fluid (10.0 ppg brine) to minimize swab pressures. Faulted intervals may require additions of LCM prior to tripping to insure that the hole remains full at all times. Keep the pipe moving and have an ample supply of lost circulation materials on hand. Baroid recommends utilization of Iow viscosity sweeps, to assist with hole cleaning and to minimize the formation of cuttings beds on the Iow side of the hole. After getting back to bottom after a trip, bring pump on very slowly to minimize surge pressures. Pipe should be pulled and run very slowly (4-5 minutes/stand)in the open hole to reduce pressure fluctuations. Hole Cleaning Based on the PWD (Pressure while Drilling) review from the SDI 3-17C well, pack~ff due to elevated ECD through the HRZ shale was the prima~ cause of hole instability. The planned well (3-07~L-29) will be kicked off below the HRZ in the Keki~uk formation to eliminate the exposure to the HRZ. Hole cleaning in the sand will be one of the prima~ functions of the drilling fluid. The Quik Driln fluid has been used e~ensively on the No~h Slope as a Rese~oir drill in mud. The rese~oir studies have shown that this fluid causes li~le formation damage. The polymer based mud is shear thinning is an excellent hole cleaning mud. This fluid type is used exclusively by the CT drilling group. The ECD data also showed that numerous short trips and circulating is needed to clean the hole. If any coal is encountered, drill only 1-2 ft prior to circulating the hole clean. Ooal also caused packoff problems in the 3-17C well. The coals will probably not be 3-07aiL-29 Drilling Permit 7/30/98 Directional Plan WP# 5 identified until the cuttings reach e shaker. During the expected c '1 interval, we should control drill no more than ~ 5 feet at a time, and circulate botr0ms up before continuing. The warning signs for coal packoff are pressure or torque fluctuations, coal Cutting across the shaker, hole fill after connections, return flow fluctuations, and increase of drag. To identify and minimize problems, this information must to recorded on the driller handover sheet to track trends. Reaming Reaming in TTRD wells require much closer attention while reaming than conventional wells due to the affect of ECD and pipe movement in very close annular clearance. This is important both while drilling the reservoir, and any time there are unstable formations such as coals or the HRZ exposed. Mud properties must be maintained within the specified parameters at all times. If mud properties are not within range, drilling operations should cease, and the mud conditioned before continuing. Every attempt to rotate rather than slide will assist hole cleaning, and minimize reaming. If we. do have to ream, it should 'be at reduced ( < 50% of drilling circulation rate) circulation rate and only up-ream. The combined affects of ECD and down-reaming put excessive pressure on the formation and will cause hole collapse. ~;- Equivalent Circulating Density The PWD (recorded data) sub will be run in this well to record the downhole pressure parameters. This data was very useful in evaluating the problems encountered in the previous well. Confirm with the onsite Sperry Sun personnel that the PWD software has been upgraded for quick data output. The higher ECD due to the ~high rheology Quik Dril mud should not be a problem in the Kekiktuk sand. This fluid type was used in the PBU TTRD wells to drill the Sadlerochit sand without problems. Any hole problems should be immediately reported so a revised drilling plan can be formulated. H2S Concerns The SDI 3-07/N-28 production stream recorded XXX ppm of H2S in 3/98. There have been H2S reading on offset MPI wells of over 1000 ppm. Ensure rig gas detectors are calibrated prior to N/D tree and/or circulating to kill the well. Logging Program: The MWD-GR Icg will be the only MWD Icg. A PWD sub will be run while drilling the 3- 3/4" hole to record downhole pressures. Drill pip,e conveyed (DPC) GR/Res will be run for WOC determination. Schlumberger will provide the side door sub and wet connect for the DPC tool string. Sample catchers and a wellsite Geologist are planned to be.~.. used while drilling reservoir. ~ ~., ,..' I l.qfi Casing and Cementing This TTRD sidetrack will require a 2.875" 6.4# L-80 liner with STL connections t~.b~.~ 0" ~,. ~:~.s-'-~'~ ~,%.'~- ~ ¢~:,~,::~,:~,~,-'~-~'"~-¥"~ run across the entire interval. The top of the 2-7/8" liner will in the 4.5" tubing a{'~'s-'~' '~ A~:~0~tg~ 12,000+/- MD (Just above the 7" x 4-1/2" packer @ 12,157'md). Ensure that prior to running liner that the hole is in good condition and that the mud has been conditioned to run casing. Before POH to run liner, spot lubricant across the open hole section. If this is considered essential to getting the pipe to bottom ensure that adequate lubricant testing has been performed prior to doing this. Aisc, consideration must be given to a hole opener trip prior to running liner if hole conditions suggest that there may be problems running pipe. The liner should be filled every 5 joints, and circulated prior to going into open hole. Any problem intervals identified while drilling, such as ledges, will require special care while running casing through. The liner will require I turbolator (2-7/8" x 3-5/8") centralizers on every other joint to the window. Integral centralizers (STL connections) may be run in place of the latch-on turbolators to eliminate turbolators moving on the 3-07aiL-29 Drilling Permit Directional Plan WP# 5 7~30/98 liner. If the liner starts to packoff ir 'he open hole, establish circulation r '~ try to wash through. Do not continue to run c~ing without circulation. If necessary;~we will pull the liner and make a wiper trip prior to running the liner. The liner running procedure in the detail section should be reviewed. This liner will be run with a PBR only. There is an option to run a packer after cementing operations. The cementing program is designed to place cement back to within 350' (12,495' MD) the production tubing tail. The approximate volume will be 100 sacks (21 bbls) of Class 'G' with additives as specified in the casing detail section. Cementing operations at Endicott are continue to be critical with the advancement of both the waterflood and gas fronts. Close attention to detail for this part of the well is critical for the economical success of our drilling program. CT Conveyed Perforating This sidetrack well will require coil tubing perforating across the intervals picked from LWD GR and GR/RES logs after the rig is released. 3-07a/L-29 Drilling Permit Directional Plan WP# 5 7~30/98 o Endicott MeaSured, (ft). 12895.00 ~29oo.o0. 12925.00. '13000~00. 13100.00 . .. 80.871:. . 13200.00.' 100.545. '13252,07" 110.697 13300.00 . 1!0'697 !3400:00. 110.697., 13500.00 i 10.697 · 1360'1.85' 110;897.:: ~3700,00, ~06.602 ". 13800.00. 102.337 13900.00'. 98.005.- .. ,, 14000.00' 93.630 ' 14037.'!'4 92°000 14100.00' ' as.233 14200;00' 82.241'.. 14242.94 79.668 79.668. 79.668. 79.668 .. 79.so2. ,.., 76. i 89 72.883 70.509 70.5O9 70.509. 14598.07 . 14700.00' 14800.00 14874.43 . .. 14900.00 15000.00 " Sub-Sea Incl.' ' "Azim'. .. "Depth' . . .. 44:808. 355:927 ' '10028-52 .45.288' 356.436 10032:05 47.722 ..358~855 10049'26 '. 61.497 . 10.072 10092.68. ' "21.1'56 .' 10124.87 · , 31;o52 36.570 36.570 36;S7o. 36'.57o'. ., 36.570 lo~23:64 .' 101O9.63 10092.69 '1.0057:35, 9986.66 9986.01 · 41 '.039'"' '9954:!62. '45'.398. 9929.62. '49.616 : 991.1.96 '53-745 990.i.82 55.266' 9900,00. ' 55.073' "' 989~.87' 54.765 54.63O '54.630 ' 54.630' '54.630 .. 54.630 54.726 59.774 64.970 9908.17 9914.92 . '9925:i6 9961.03' 9978,61 9978.96 ~999.94 10026.62 '68.955 :. ' 10050.00 68.955.. 10058.53 '68,955 1:o09!.90 Vertical Depth · (ft). 10084.52' 10088.05 10105.26 101.48.68. 10180.87 .lO~79.64 10165.63 101 48.69 10113.35. .10078~01. %o~2.66 10042.01 10010.62 9985.62 9967.96 9957.82 9955.87. 9964.17 9970,92 9981.16 9999.09 10017.03 10034.61 10034.96 10055.94 10082.62 10106.00 10114.53 10147.90 Sperry-Sun Dr 71in g SerVices Proposal RePOrt for 3-07A/L-29 WpS(r) ' · .. OHL'f . . Alaska State .Plane Zone 3 Endicott SDi Local Coordinates -Global Coordinates Dogleg Vertical Northlngs Eastings No'ri .hl,.ngs Rate Section (ft) (ft) ' (ft)':. '(~/l:00ft) (ft) 6117;38 N 2510.07 W 5977159~97. N .. 6120.91 N 2510.31 W 5977163.51 N 6139.03 N 2511.64 W 5977181,64 N 6199.63 N 2505.80 W 5977242.05 N 6290.05 N 2479.98 W 5977331..64'N 6379.30 N 2436.27 W 59774~[9;51 N 6420.92 N 2408.46 W 5977460.26' N 6456.93 N - 2381.75 W 5977495..4~. N 6532.06 N 2326.01 W 5977568.82 N 6607.19 N 2270.28 W 5977642.2'1 N . ..... 6682.3T2 N.. 22'14.54 W 597771'5.60 N 6683.72 N 2213.5.1 W 59777.1.6.96 N 6756.12 N 2155;23 W. 5977787.55 N' 6826.62 N 2088.93 .W 5977855.99 N 6893.06 N 2016.37 W 5977920.i7 N 6954.71 N 1938.35 W 5977979A0 N 6976.24 N 1908.15 W 5978000.00 N 7012.14 N 1856.56 W 5978034.30 N 7069.39 N 1775.04 .W 5978089.03.N 7093.89 N 1740.44 W 5978112.46 N 7126.39 N 1694.66 W 5978143.54 N 7183.33 N ~, 1614,44W 5978198.00 N 7240'.28 N 1534.22 W 5978252.46 N 7296.13 N 1455.55 W 5976305.88 N 7297.23 N 1454;00 W 5978306.93 N 7350.12 N 1371.82 W 5978357.28 N 7394.82 N 1286.49 W '5978399.34 N 7422.48 N 1221.49 W 5978425.00 N 7431 .'13 N 1199.00 W 5978432.96 N 7464.99 N 1111.01 .W 5978464.11. N . . 'Easflngs '(~) 26787P-06 E ' 267871.94-E 267871.75 E 267878.85 E 267907.43 E 267953.85 E 267982.92 E 268010.72 E 268068.73 E · 268126174 E .. 268184.75' E 268185.63 E 2.68246.30'E 268314.72 E 268389.28 E 268469.16 E 268500.00 E. 268552.67 E 268635.90. E 268671.23 E 268717.98 E 268799.91 E 268881'84 E 268962:i 8 E 268963.76 E 269047.52 E 269134.18 E 269200.00 E 269222.75 E 269311.73 E 12,000 12.000 22.000 22.000 22.oo0 o.ooo· 0.000 0.000 0.000 0.000 ' 6.000 ' 6[000 6.0bO ~6.000 6.000 6.000 6.000 -6~000 0.000 0.000 0.000 0.000 6.000 6.000. 6.000 6.000 0.000 0.000 2104,77 2106.90 2118.20. 2161.82 2240.51 . 2331.96. 238O23' 2423.99 2515.30 2606.61. 2697.92 2699.61 2791 ;06 2887.32 2985.67 3085.01 '3121.93' 3164.44 3283.54 3325.74 3381.62 3479,54 3577.47 3673:50 3675.39 3772.14 3933.17 3955.85 4044.53 Comment Target: 3-07A/L-29 Int . Target: 3-07A/L-29 T1, Geological 6 July, 1998- !7:36 .1- Dr/I/Quest EndiCott MeasUred .. Depth.. (ft)' 15100.00 70.509 15200.00 70.509 15,.3~.00 70.509 15323.99 70.508 .: AZ~m,I Sub-Sea' Vertical Depth. .Depth · (.). (st), SperrY-Sun = Driiling Services.. ProPosal lRep°rt for. 3'07ALL'29 WpS(r) Local CcTordlnates Northings Eastings ~ (ft) (ft)," '" ' · ., 68.955 10125~6' 10181.26 ' 7498.84 N '68~955 10158.63 10214;63 75,.'.'.'~.69 N 68.955 ' 10192.00 10248.00 7566.54 N 68.956' 10200:00 10256.00 7574.66 N Ali' data is in feet unlesS' otherwise Stated, Directions and coordinates are relative to .True North. Vertic~ depths am relative to'WelL. Northings and EaStings are relative to Well; ' . The Dogleg 'Severity is' in' Degrees per 100ft. ""." vertical'Section is from Well and Calculated along .an Azimuth of. 49.1-30° (True). Based .upon Minimum cUrvatUre typ~ c~lculations, at a Measured Depth of. 15323:99ff., The BOttom' Hole DisPlacement is 7619.56ff, in the Direction of 353.777° (True.): . .. Global Coordinates . · Northings . Fastings · (~t) .(ft), . · ' 1023.03.W 5978495.25 'N 935;05 'W 5978526.39 N · 847.07 W" . 5978557.53 N 825.97 W 5978565.00 N : 269400.70 E 269489~68 E 269578.66 E 269600.00 E Dogleg ver~ Rate.· 'Section ' (°~ooft).' (ft)....i .. , ':0;000" 4133.21" 0.000 4221.90 0.000 4310~58 o:OOO 4331:ss Comment .. . . Target: 3-07A/L-29 T2, Ddllers · Alaska State Plane ZOne 3 Endicott SD! 6 July, 1998 -' 17:36 .2- DriliQuest I Endicott Alaska State Plane Zone 3' Endicott SDI' '3-07A/L-29 Proposal Debt for 3-07A/L-29 WpS(r) Wd Well' It' v~ S~c~a Verli~l Seclm C~gkt: ~OON~..OOE D~h · · ~q~ s~k~- 12:~.00 '44.~0~ 355.YZ7 t(X3M.52 6t 1.7.3~. N 23t0,07 w 2t04.77 129~.00 47.722" ~$ ' 10lO~.,~ 6139.03 N' 2511.04 W 211&.20 12.¢M0 1325Z01 I lO,rd73~90 i016~.63 ~ N 240~46.W 2M023 J3~)1.8~' llO.,6~ 365'70.IiXM2.0I 6683.7'2 N 22t~51 w 2699.61 - '0.ix)0 J403?AA 92.000 ~52f~ 995(~0 ~76.?A N 1908.15 W · 312Lq3 ~ ~9~68 54~30 9970~2 7093.19 N 1740~4 W 3525.74 MSgKO? 59.668 S4.~30"!0034~1 72~6.L1 N 14~!.55 W 367350 14874.4]."M.5~ M.955 lOl(~.00 74?.2.48 lq. t~3.~[.49 W 3e3%!7 6~O00.' ~.99 'M..fM, 68.q5~ iOZ.~.Q0 75'74.66 N 82:~.97 W 4531.~5 scale: ~irich = sooft Easfings '.1 ,I -3000 -2500 Scale: 1inch = 50Oft .2000 · -.~500 Eastings 7OOO - 6SOo .g o .,~ - 6000; · -t 004} -500 Reference is Tme North' 1O0O0 - t750 E~.,ale: qinch =.500ft I i I i i 2250 2750 3250 3750 4250 Vertical Sectionsecu°n Azimuth: 49.130' (True North) SDI WELL 3-07A I L-29 (WpSr) - SURFACE & DOWNHOLE LOCATIONS 7~27~98 . , I'TEM ' ' NAME ........... COMMENTS ' ' ALASKA STATE PLANE ZONE'3 (NAD 27) DECIMAl. DEGREES (NAD 27) ' ' 'S & E SEC LINE OFFSET~ SECTION, TOWN.,' NEAREST ~ECTION LINE OFFSETS NO. . .... . . Y _.. X LATITUDE (..N°.) ,LONGITUDE (W~) ESL ....... FEE .... RAN. GE, UMIAT, AK DIST. .... LINE . D!ST. !LINE I SDI 3-07A/L-29 Surface @ SDI Surface Location 5,970,968.60' 270,193.64' 70.322300° 147.863448° 2748 848 SEC 08 T11N R17E 2531 N 848 ~ E 2' SDI 3-07A/L-29 MD:'12895.00 ' '5,977,159.~7' ' ' 267',872.06' 70.3390120 '~47.883814~ ........ 3585 .... 3340'" SEC 05 TI'IN R17E 1694 N 1939 1W 3 SDI 3-07~L-29 MD:15353.99 Target: ~'51978,565.00' '2691600.00' 70.3429940 147.870151° 5043 1652' SEC05 T11N R17E .... 236 N~ 1652 !E , Notes: All coordinates shown are North American Datum 1927 (NAD 27). Alaska State Plane Coordinates shown are Zone 3 (Feet). F. Robert Bell & Assoc. Jeff Cotton 564-4969 File Name: DIUBH727.xls 7/27/98 NW Sec 5 T11N R17E Umiat X=265980.55 Y=5978913.24 NW Sec 8 o~ SWSec8 T11N R17E Umiat X=265688.10 Y=5968357.70 5280 91046'08" N Sec 5&4 ./~MD 15323.9~ .TARGET X=269600.{ Y=5978565 D oo MD12895.00 X=267872.06 Y=5977159.97 528O 91o46'07'' N Sec 8&9 3~07A/L29 "3-07"SURFACE LOC. X=270193.64 Y=5970968.60 528O 271o46'06'' o~ S Sec 8&9 5280 91 °43'42" N Sec 4&3 5280 91o41'17" 528O 91 °43'42" N Sec 9&10 5280 91o41,16,, o~ 528O 271o43'40'' S Sec 9&10 528O 271o41,16'' NE Sec 3 T11N R17E Umiat X=281812.67 Y=5978435.49 SDI Well 3-07A/L-29 Wp5r Downhole Location Scale: 1"= 2000' 7/27/98 Jeff Cotton NE Sec 10 SE Sec 10 T11N R17E Umiat X=281520.22 Y=5967880.08 NW Sec5 T11N R17E Umiat X=265980.55 Y=5978913.24 NW Sec 8 5280 91 °46'08" MD15323.99 TARGET X=269600.00 Y=5978565.00 MD12895.00 X=267872.06 Y=5977159.97 5280 ~, 91°46'07" 1652 N Sec 5&4 3340 N Sec 8&9 528O 91 °43'42" 528O 91o43'42'' I TREE: 4-1/16" ' ~00 psi/Cooper R.T. ELEV = 55.4' · ~_~_. WELLHEAD: 1 :~/8" / 5000 psi / McEvoy B.F. ELEV = 16.5' MAX. DEV. = 51:43 8600' M D (~ ~ SSSV LANDING NIPPLE ~- OTIS (3.813" I.D.) 1487' 13-3/8", 68#/ft, L-80, atrs Csg i W/SSSV MIN I.D. is 2" 2502' ~'~ ~ 4~1/2% 12.6#/ft, L-80, NSCT GLM's (CAMCO), (1-1/2" RK) Latch No. TVDSS MD-BKB 9-5/8", 47#/ft i ! #2 3668' 3737' NT80S XO to NT95HS ~ I'~ . #1 9483' 12010' 10222' OTIS "X" NIPPLE 12080' I · ~-- (3.813" I.D.) TIwD-5/8"(HBBP)PACKER 12157' TOP OF 7" LINER L , , ~_~ ~ 3-1/2", 9.2#/ft L-80, TAILPIPE : ] mE 3-1/2" 'SWS' NIPPLE 12207' ~ i ~ Parker (2.750" I.D.) 12202' 9-5/8", 47#/ft, NT95HS, NSCCII, " " 3-1/2" 'SWN' NIPPLE I I Parker (2.635" I.D.) 12234' 125O4' / 3-1/2" WLEG 12270' , PERFORATING SUMMARY Ref. Log: DLL-GR (MSFL 3/2/89) CO. ~ GUN SPF INTERVAL BAKER 5" DPC 4 13130' - 13270' ~ I I i : ECEIVED JUL ! !998 PBTD 13468' } ~ A~Sk~I. Oi! & Gss Cons. ComBis¢o~ ~'~ Anchorage 7", 29#/ft, SM-11 O, [ 13550' Btrs-TiC/ Date By Comments ENDICOTT WELL- 3-07 / N-28 02-01-89 FH PROPOSED COMPLETION APl NO. 50-029- 21 91 1 03-14-89 JLH INITIAL COMPLETION COMPLETION DIAGRAM 10-25-94 JTP =CST Rwo BP EXPLORATION, INC. CO. ~ GUN SPF INTERVAL BAKER 5" DPC 4 13130' - 13270' R.T. ELI~V = 55.4' B.F. ELEV = 16.5' MAX. DEV. = 51:43 8600' MD 13-3/8", 68#/ft, L-80, Btrs Csg I 2502' ~ 9-5/8", 47#/ft NT80S XO to NT95HS I 10222 ' J ~ TREE: 4-1/16" / 5r~q0 psi/Cooper WELLHEAD: 13. ' / 5000 psi / McEvoy SSSV LANDING NIPPLE OTIS (3.813" I.D.) W/SSSV MIN I.D. is 2" 1487' 4-1/2", 12.6#/ft, L-80, NSCT GLM's (CAMCO), (1-1/2" RK) Latch No. TVDSS MD-BKB I #2 I 3668' #1 9483' 3737' 12010' Well loaded with 8.6 ppg seawater TOP OF 7" LINER 12207' 9-5/8", 47#/ft, NT95H S, NSCC I12504' I pi=RFC)RATING ~UMMAR¥ Ref. Log: DLL-GR (MSFL 3/2/89) CO. / GUN ~;PF INTERVAL ,, / I BAKER/ 5 DPC / 4 I 13130'-13270' I PBTD I 13468, 7", 29#/ft, SM-110, Btrs-TKC I I ~ ' Date By Comments 02-01-89 PROPOSED COMPLETION 03-14-89 JLH INITIAL COMPLETION 10-25~94 JTP POST RWO 7-20-98 JLH Pre TTRD ST OTIS "X" NIPPLE (3.813" I.D.) TIW SBR TIW (HBBP) 9-5/8" PACKER 12167' 12080' I 12140' I 12157' Milled 5-1/2" x 3-1/2" Crossover 3.80" Drift Proposed whipstock setting depth @ 12895' MD 11 bbl 15.6 ppg cement plug f/13307- 13000' Milled off 3-1/2" tail pipe Overall Length: 103' Alaska 0ii~,~ ° Gas Cons. C0ml~dssi0~ ENDICO~ W~LL: 3-07 / N-28 APl NO. 50-029- 21911 PROPOSED COMPLETION DIAGRAM BP EXPLORATION, INC. TREE: 4-1/16" / 5r~r)0 psi/Cooper R.T. ELEV = 55.4' WELLHEAD: 13. "/5000 psi / McEvoy B.F. ELEV- 16.5' ~-~ MAX. DEV. - 51:43 8600' MD SSSV LANDING NIPPLE I I 13-3/8", 68#/ft, L-80, Btrs Csg ~ W/SSSV MIN I.D. is 2" I 2502' I ~~ ~ ~ 4-1/2", 12.6#/ft, L-80, NSCT GLM's (CAMCO), (1-1/2" RK) Latch No. TVDSS MD-BKB 9-5/8", 47#/ft #2 3668' 3737' NT80S XO to NT95HS ]~ #1 9483' 12010' (3.813" I.D.) Est. 2-7/8" liner Top 12115' i~ i 9-5/8" PACKER I , TOP OF 7" LINER ~ il I -.~ , I12207' I .~ ~ ~ ~ -'~~! ____ 2167 l ~ 't"~ ~ ' ' .... ~ ~,;:: ~ ~ :~ ~ Billed S-I/2 x3-1/2 Crossover 9-5/8", 47fi/fi, NT95HS, NSCC i'""~ ~ ~ ~;~ ~"~' ...... 3.80" Drift ~ ~ ~~ 2-7/8" liner F/12115-15324' Proposed ;;~:~:~ ~:;::::::-~:?~:~::~L,~ ~ ~.~: ...... whipstock seffing depth ~ 12895' MD ;~:~:~;:;':::'~:.::::~:::~'~:~:~.:-::~,~::;:~.;~ ~ PERFORATING SUMM~RY ' Ref. Log: DLL-GR (MSFL3/~89) ~, ......... ; CO. GUN ~;PF ~ 3-3/4" Hole to 15324' MD INTERV. ~L~~ BAKER 5" DPC 4 13130'- 13270' 18 lS.S ppg , Tagged PBTD ~ 13307' ~~ , , ~~~ Overall Length: 103 1.r~ . ~ 1,~8 PBTD 13468' 7", 29~/', SM-110, ] I ~ ~88k8 0iiu. ~' 6SS O0~S. Btrs-TKC 13550' ~ A~ch0rage Date By Comments ENDICO~ WELL: 3-O~ / N-28 02-01-89 FH PROPOSED COMPLETION ~1 ~O. B0-029- 2191 03-14-89 JLH INITIAL COMPLETION PRO~O~E~ COMPLETION DIAGRAM ~o-25-94 JTP POST RWO 7-~0-9S. JL. P~e WRD ST BP EXPLORATION, INC. Drilling Discussion .. General The proposed sidetrack of the 3-07a/N-28 to the L-29 location will access the lower 2A oil column, which not been sufficiently depleted by 3-07/N-28 due to high water production. This will establish an offtake point away from the east-west trending fault system just north of the 3-07/N-28. The L-29 BHL targets a drainage area of 70 acres with a P50 estimate of 0.96 MMSTBOIB Expected initial rate is 2000 BOPD at a GOR of 1500 scf/stb and a watercut of 40%. The well will be sidetracked in the 7" casing below the P3 coals. The present 4-1/2" L-80 completion will remain in place during the sidetrack operation. A 2-7/8" liner will be run and cemented in place. The liner will be selectively perforated using coil tbg after the rig moves off location. The 3-07a/L-29 sidetrack represents the third implementation of TTRD technology at Endicott as a cost effective alternative to conventional sidetracking. The 3-07a well on SDI at Endicott will target the Kekiktuk in the 2A in accordance with the 1998 development plan. We will have to abandon the existing perforation in the 3-07a/N-28 well by setting a cement plug with coil-tubing. The well will be sidetracked off the cement plug to the new L-29 BHL utilizing the 2.875" liner STL design. The existing production packer or tubing will not be pulled. The 2.875" liner length wi~'be _ 3324 feet, with the top of the tie back into the 4.5" production tubing just below the 7" x 4- 1/2" production packer. The existing 2 valve slimhole (4.5" x 1.0" for 7.0" casing) GLM design will be used after the well is completed. The 4.5" L-80 tubing design will remain. Directional Plan: The directional plan for the 3-07a/L-29 well consists of kicking off with a whipstock and conventional BHA's for the Kekiktuk Flow sands. The plane KOP will be in the 2B Sand below the LCU and HRZ. Current plans call for up to 22°/100' doglegs in this section, but this may be adjusted pending results during the drilling process. After sidetracking, drill the inverted tangent at 110°, and then dropping angle @6°/100' through the two target's. The planned TD is 15,324' MD (10200' TVDss) in Zone 1. The only ~lose approach is the existing 3-07 well which quickly diverges from the sidetrack path. The closest offset well is 3-09/L-28 which is 451 feet away at 13,700' MD. The KOP below the HRZ is a result of the HRZ and coal problems encountered in Well 3-17/M-31. Ensure that any and all tolerance lines are not crossed to avoid policy violations. Please coordinate this through both the Operations Drilling Engineer and the Endicott Drilling Superintendent. There are not any known close approaches which require wells be shut in. Any BHA's indicating less than required BUR should immediately be pulled for a more aggressive assembly. ~?~ Recommended BHA's All motors should NOT be jetted to account for the proposed flowrate and motor performance. Hole conditions and directional objectives should dictate actual flowrates. As mentioned previously, flex collars should be utilized to minimize potential differential sticking. We will be using bent housing motors with either 7/8 for a roller cone or 5/6 rotor/stator configurations for PDC bits. Sperry proposed BHA's are attached, however the actual BHA with motor design, MWD tool configuration, MWD battery life, bit hydraulics will be discussed at the daily wellsite meeting. DRILLING CLOSE APPROACH WELL SHUT-INS The closest well bore is the original well 3-07/N-28 which quickly diverges from the sidetrack. The closest offset well is 3-09/L-28 which is 451 feet away at 13,700' MD. This well will meet the deep intersection risk assessment. Close attention to the tolerance lines are necessary to avoid this well. See the TC plot for details. 3-07a/L-29 Drilling Permit Directional Plan WP# 5 7/30/98 PORE PRESSURE / LOST CIRC~o~LATION Production Interval (3.75"): The Kekiktuk Sands (3A) reservoir pressure could be higher than normal at 8.95 ppg (based on well 1-39/P-17 SBHP). The formation also has the (slight) potential for lost circulation (see Geologic Prognosis for faulting details). Lubricant additions (see above) should be utilized if torque and drag become troub!esome, and after extensive testing of mud on location. Flex collars should be utilized in the BHA to minimize potential differential sticking. Liquid casing and OM seal should be on location to help combat severe lost circulation. NOTE: See the Geologic Prognosis for a detailed description of the expected fault locations and sizes. Review the Pad Data Sheet for trouble highlights throughout MPI history. Well Control' Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Special XOS for drillpipe are available for this well. Diverter, .BOPE, and drilling fluid system schematics on file with AOGCC. Waste Disposal · Cuttings Handling: CC2A Fluid Handling: Annular injection is not available at Endicott for this well. Directional Survey Program The survey program for 3-07a/L-29 calls for use of Sperry's SOLAR MWD surveys the entire well. Because of Sperry's standard practice of changing the MWD probes after every bit run, an electronic single shot (ESS) will not be needed, and a gyro is not warranted. Close attention to JORPS is required, with the use of checkshots and survey data validation. A PWD sub will be run with the MWD probe to record actual bottom hole pressures. Bit Program After milling a 3.80" window off of a whipstock, a 3.75" build section followed by a short tangent section and a drop section is planned. The entire well will be drilled with the PDC bits (depending on directional control) to allow for more flow area around the BHA. The penetration rate will vary due to the variable lithology, but these bits have proven durable when CT drilling the Sadlerochit in the PBU. Recommended Jet Sizes Expected Interval Bit Type Flowrate HSI Casing Section Standard Baker TTRD 90 - 120 gpm Window Mills Kickoff 3.75" HTC 335 90 - 100 gpm 0.371 < 1 Tangent 3.75"x4.25"Bicenter DPI 566 90 - 100 gpm 0.371 < 1 3.75" (If bicenter not HTC 335 90 - 110 gpm 0.371 < 1 drillincj) NOTE: Real time rigsite information such as condition of bits previously pulled, hole conditions, drilling fluids, downhole motor constraints (if any) will be instrumental in actual final bit selection. 3-07aJL-29 Drilling Permit Directional Plan WP# 5 7/30/98 Mud Program: The cement pilot hole and ramp to the casing wall will be milled using slick seawater (1- 1.5 ppb N-vis). The well will displaced to a 10.0 ppg brine prior to POH to mill the window. The 10.0 ppg brine will be used to mill through the casing and drill 5 ft of new 3-3/4" open hole. Hi-vis sweeps in the 10.0 ppg brine will be used to clean the metal cuttings from the well. The 10.0 ppg brine will be displaced with 10.0 ppg Quik Driln. Save the 10.0 ppg brine to be used as a tripping fluid to reduce the surge and swab pressures. The brine may have to be replaced due to hi-vis sweeps increasing the fluid rheology. Immediately after displacing the well to 10.0 ppg mud, add 0.5 ppb of Barascav D. Tourly sulfite checks should be made to ensure that residual sulfites of 150mg/L are maintained with Barascav D. Make sure DITCH MAGNETS are used both in the possum belly and suction pits for maximum metal removal benefit throughout milling and drilling operations of this well. See Bariod mud recommendation for exact mud parameters. While milling the window, run the solids control equipment (shakers and rig centrifuge) to remove the cement and metal from the brine. The Bariod solids control- van should be oRerational prior to drilling any new formation with Quik Dril fluid. Thiswill help keep the PV down, which is the main driver of circulating pressure. Since the mud weight is maintained with NaBr, the centrifuges can be run co. ntinuously without reducing the mud weight. Whole mud dilution or complete swapout may be needed to keep as clean a system as possible. Calcium must be under 100 ppm prior to adding EP Mudlube. Maintain a ~,~ ppb buffet'of Bicarb/Soda ash if EP Mudlube is added. A Iow vis, weighted brine sweep prior to the cement slurry may be needed to clean the hole. This will facilitate a better cement job. Tripping Practices / Stuck Pipe / Hole Cleaning / Reaming Tripping should be undertaken with caution due to swabbing possibilities with high viscosity fluids and the tight annular clearance. A 10.0 ppg brine trip fluid will be needed due to the high swab pressures encountered while drilling the SDI 3-17C TTRD well. The ~ottom hole pressure could be as high as 4700 psi (+/- 9.3 ppg ). The mud weight is recommended to be maintained in the 10.0 ppg range to allow for formation pressure uncertainties. If swabbing becomes a problem, the well will be displaced to a trip fluid (10.0 ppg brine) to minimize swab pressures. Faulted intervals may require additions of LCM prior to tripping to insure that the hole remains full at all times. Keep the pipe moving and have an ample supply of lost circulation materials on hand. Baroid recommends utilization of Iow viscosity sweeps to assist with hole cleaning and to minimize the formation of cuttings beds on the Iow side of the hole. After getting back to bottom after a trip, bring pump on very slowly to minimize surge pressures. Pipe should be pulled and run very slowly (4-5 minutes/stand) in the opeq;i! hole to reduce pressure fluctuations. , i ' ~, .'7.- 'i (.~ Hole Cleaning Based on the PWD (Pressure while Drilling) review from the SDI 3-17C well,~,~l_~i!& pack~ff due to elevated ECD through the HRZ shale was the prima~ cause of hole instability. The planned well (3-07~L-29) will be kicked off below the HRZ in the Keki~uk formation to eliminate the exposure to the HRZ. Hole cleaning in the sand will be one of the prima~ functions of the drilling fluid. The Quik Driln fluid has been used e~ensively on the No~h Slope as a Rese~oir drill in mud. The rese~oir studies have shown that this fluid causes liEle formation damage. The polymer based mud is shear thinning is an excellent hole cleaning mud. This fluid type is used exclusively by the CT drilling group. The ECD data also showed that numerous short trips and circulating is needed to clean the hole. If any coal is encountered, drill only 1-2 ft prior to circulating the hole clean. Coal also caused packoff problems in the 3-17C well. The coals will probably not be 3-07aiL-29 Drilling Permit 7/30/98 Directional Plan WP# 5 identified until the cuttings reach 9 shaker. During the expected ~ ! interval, we should control drill no more than ~'~ 5 feet at a time, and circulate boffSms up before continuing. The warning signs for coal packoff are pressure or torque fluctuations, coal cutting across the shaker, hole fill after connections, return flow fluctuations, and increase of drag. To identify and minimize problems, this information must to recorded on the driller handover sheet to track trends. Reaming Reaming in TTRD wells require much closer attention while reaming than conventional wells due to the affect of ECD and pipe movement in very close annular clearance. This is important both while drilling the reservoir, and any time there are unstable formations such as coals or the HRZ exposed. Mud properties must be maintained within the specified parameters at all times. If mud properties are not within range, drilling operations should cease, and the mud conditioned before continuing. Every attempt to rotate rather than slide will assist hole cleaning, and minimize reaming. If we.do have to ream, it should be at reduced ( < 50% of drilling circulation rate) circulation rate and only up-ream. The combined affects of ECD and down-reaming put excessive pressure on the formation and will cause hole collapse. Equivalent Circulating Density The PWD (recorded data) sub will be run in this well to record the downhole pressure parameters. This data was very useful in evaluating the problems encountered in the previous well. Confirm with the onsite Sperry Sun personnel that the PWD software has been upgraded for quick data output. The higher ECD due to the 'high rheology Quik Dril mud should not be a problem in the Kekiktuk sand. This fluid type was used in the PBU 'I-I'RD wells to drill the Sadlerochit sand without problems. Any hole problems should be immediately reported so.a revised drilling plan can be formulated. H2S Concerns The SDI 3-07/N-28 production stream recorded XXX ppm of H2S in 3/98. There have been H2S reading on offset MPI wells of over 1000 ppm. Ensure rig gas detectors are calibrated prior to N/D tree and/or circulating to kill the well. Logging Program: The MWD-GR Icg will be the only MWD Icg. A PWD sub will be run while drilling the 3- 3~4" hole to record downhole pressures. Drill pip,e conveyed (DPC) GR/Res will be run for WOC determination. Schlumberger will provide the side door sub and wet connect for the DPC tool string. Sample catchers and a wellsite Geologist are planned to be used while drilling reservoir. Casing and Cementing This 'Fl'RD sidetrack will require a 2.875" 6.44f L-80 liner with STL connections to be run across the entire interval. The top of the 2-7/8"-liner will in the 4.5" tubing at 12,000+/- MD (Just above the 7" x 4-1/2" packer @ 12,157'md). Ensure that prior to running liner that the hole is in good condition and that the mud has been conditioned to run casing. Before POH to run liner, spot lubricant across the open hole section. If this is considered essential to getting the pipe to bottom ensure that adequate lubricant testing has been performed prior to doing this. Aisc, consideration must be given to a hole opener trip prior to running liner if hole conditions suggest that there may be problems running pipe. Alaska r,,~ ,~. -. ,~, .~ uas Cons. Anchorage The liner should be filled every 5 joints, and circulated prior to going into open hole. Any problem intervals identified while drilling, such as ledges, will require special care while running casing through. The liner will require 1 turbolator (2-7/8" x 3-5/8") centralizers on every other joint to the window. Integral centralizers (STL connections) may be run in place of the latch-on turbolators to eliminate turbolators moving on the 3-07aJL-29 Drilling Permit Directional Plan WP# 5 7/30~98 liner. If the liner starts to packoff ir 'he open hole, establish circulation r ~ try to wash through. Do not continue to run c~ng without circulation. If necessar -,y~we will pull the liner and make a wiper trip prior to running the liner. The liner running procedure in the detail section should be reviewed. This liner will be run with a PBR only. There is an option to run a packer after cementing operations. The cementing program is designed to place cement back to within 350' (12,495' MD) the production tubing tail. The approximate volume will be 100 sacks (21 bbls) of Class 'G' with additives as specified in the casing detail section. Cementing operations at Endicott are continue to be critical with the advancement of both the waterflood and gas fronts. Close attention to detail for this part of the well is critical for the economical success of our drilling program. CT Conveyed Perforating This sidetrack well will require coil tubing perforating across the intervals picked from LWD GR and GR/RES logs after the rig is released, 3-07a/L-29 Drilling Permit Directional Plan WP# 5 7/30/98 z o EndicOtt Measured. · .Depth . (ft). , .. 12895.00 12900.,00.. 12925,00 : '13000~00. Sperry-Sun Drilh'n SerW'ces "Pr. oposa/ RePort for 3-07A/I- 29 WpS(r) . _ .'. '....... . . ~cL~,.. A~m'... · : .. · 45.288 ' 356.436 47.722:358:855 61.497:' ." 10.072 Sub-Sea -Depth · ioo2 .52 10032.05 10049:26 100.92.63. Vertical Depth 10084.52' ' 10088.05 10105.26 10148.68. LOcal Coordinates' · .. Northlngs · Eastings (ft)., (ft)- .. 6117;38 N 6120.91 N 6139.93 N 6199,63 N ~51o.67 w 2510.31 W 2511.04 W 2505.80 W · Global Coordinates'; . North!'ngs , , . 5977159,97. N. .. 5977163.51.'N 597718i .64 N 5977242.05 N · . Easflngs. '.', '(n) . . ., . 267872.06 E · 267871.94. E 2.67871.75 E 267878.85 E ., Rate Section' '(V!:00fl)(fi) 2104,77 12.000 ' 2106.90 12.000 2118.20. 22.000 2161.82: Comment 80.871', '." 21.i56" 10i'24.87 , . . . . . , ,. '13200,00' 100-545" 3i;052 10123,64 '13252,07' 110.697 36.570, .' 10109.63. · 13300.OO' . 1!0:697'. 36...570 10092.69 1~400:00. ' 110.697'. ' ." 36~570. '10057,35' 13500.00.' 1'10,697. ' ,',36.:570'. 1.00.22.:01 '13600.00'" 110'697 ::" .. '36:.570.~!'''' . 9S86.66 ' 13601.85' '110~697',:' .36.570 9986.01. 13700;00' 106.602 ". 41~039,."" "9954~62. 13800.00, 102,337,' '45,398. 9929.62. 13900,00 . 98.O05''' '49-616 '., 991.1.S6' 10180.87 10179.64 10165.63 10148.69 10113.35. .10078,01. ' 10042.66 loo42,01 10O10.62 9985.62 9967.96 6290.05 N 6379.30 'N 6420.92 N 6456.93 N: 6532.06 N 6607.19 N 6682.~2 N.. 6683.72 N 6756.12 N' 6826.62 N 6893.06 N 2479.98 W' 2436:27 W 24O8.46 W 2381.75 W ·. 2326.01W 227o~8 w' · . 2214.54W :. 22,!3.5.~ w 2155;23 W' 2088.93 .W 2016.37 W., ', 5977331..64'N . . .59774~9;51 N '5977460.26 N 5977495, .4~. ' N 5977568.82 N 5977642-~'1 N . · . 597771'5.60 N 59777.1,6.56 N'. 5977787.55 N' 5977'855.99 .' 5977920.iZ N ..,. '. , ',.' , · ,. 14037:! 4, 14100,00 142O0~OO 14242.94 14598.07 146o0.00 147o~.OO 14800.00 14874~43 1490O .00 15000.0O 6 July, 1998- 17:36 93.630' ". 53'745... 990:i'.82 92,000 55.266 9900;00. 88.233 '.: 55.073 .'' "'9899.87 ' 82.241.. 54,765 . 9908.17 7'9.668." 54.630 '9914.92 79.668";. 54,630 . '9925. i6 79,668:. '54..,630... ' '9943.09 79.668.1.. '54.630'.. 9961.03. 79.668 .54.630 9978,61 79.602. ' 54.726' "9978.96 76:i8~'.,. ' 59.774. ".9,999.94 72.883 64.970 10026.62 70,509 '. '68,955 :. ' 10080,00 70,509 ..68:955.. 10058.53 70,509.':'.' '68;955 110091.,90 9957.82 9956.00' 9955 .87 9964.17 9970.92 9981.16 9999,09 10017.03 10034.61. 10034.96 10055.94 10082.62 10106.00 10114.53 10147.90 6954.71 .N 6976,24 N 7012;14 N 7069,39 N 7083:89 N 7126,39 N 7183,33 N" 7240'.28 N 7296,13 N 7297,23'N 7350,12 N · , 7394,82 N 7422,48 N. 7431,'13 N 7464.99 N . . 1938.35 W. 1908.15 W 1856.56 W 1775:04.W 1740.44 W . 1694,66 W 1614,44W ' 1534.22 W 1455.55 W. 1454;00 W 1371182 W... 128679 W 1221.49 W · . !'!99.00 W 1111.0! .W' 5977979:40. N 5978000.00 N ' 5978034.30 N.. 5'978089.03N. 5978112.46'N 5978143.5~N 5978195.00 N .. 5978252.46 N 5978305.88 N 5976306.93 N 5978357.28N' '5978399.3;4 N 5978425.00 N 5978432,9,6: N ' 5978464.11, N . . · .... 267.907.43 E 267953,85 E 267982.92 E 268010.72 E 268068.73 E' 268126~74 E .. · 268184.75 E 268185.83 E 2.68246.30 'E 2683i4.72 E 268389.28 E ,, 268469:16 E 268500,00 E. 26855"2.67 E 268671.23 E 268717.98 ~ 268799.91 E 268881:84 E 268962:18 E 268963.76 E .. , . . 269134.~ 8 E 269200.00 E 269~)~,75 E 269311.73 E 22:000 22.000 O.OO0· 0.000 0.000' O.OO0 0.000 6.000 6;OOO 6.000 6.000 6,000 6.000 .6.000 'O.OO0 0.O00 0.OO0 - 0.000 6.000 6.000 6,000 6.000 0.000 0.000' 2331.96 2380~73 2423.99 2515.30 2606.61: 2697.92 2699.61 2791 ;06 2887.32 2985.67' 3085.01' ·3121.93 3164.44 3283.54 3325.74 3381.62 3479.54 3577.47 3673~50 3675.39' 3772.14' 3933.17 3955.85 4044.53. · Targel; 3'07,AJL~29 lnt .. ~ Target:. 3-07A/L-29 T1. Geo[og!cal AlaSka State .Plane Zone 3 Endicott SDI DrillQuest Con#hued.,. ..' EndiCott . . Mea$~ired .. Depth, Su~Sea' DePth. · (ft)' ' Vertical Depth SperrY-Sun,Drilling Services Proposal lRePort for. 3.07AIL-29 Wp5(r) Local C(7ordlnates Northings Fastings (~) (ft)'" DRAFT'ONLY 'Alaska State plane Zone 3' Endic°tt:SD, Global Coordinates Northlngs Fastings · (f t) .(ft) DOgleg Vertical Rate. Section (0/~o~) 15100.00 70.509 '68:955 10125.26. 10181.26 ' 74S8.84 N 1023.03.W 5978495.25 N 15200.00 70.509 . '68:955 1'0158.63 10214.63 75,.~.69 N 935;05 W 5978526.39 N . 15300.00 70.509 68.955 ' 10192.00 10248.00 7566.54 N 847.07 W' 5978557.53 N 15323.99 70.508 ' 68.956' 10200:00 1 0256.00 7574.66 N 825.97 W 5978565.00. N . ,, . Ali' data is in feet unlesS' Otherwise Stated, Directions and coordinates are relative to True North. '" Vertical depths are relative to Well. Northings and EaStings are relative to Well .. The Dogleg'Severity is in D .egrees per l·ooft. vertical' section is from Well and calculated along .an Azimuth of 49,130° (True)'. Based .upon Minimum CUrvatUre type'Calculations, ata Measured Depth of. 15323:99ft., The Bottom' Hole DisPlaCement is 7619..56ft., in the Direction of 353.777° (True): 269400.70 E ' .'0;000' 4133.21 269489.68 E 0.000 4221.90 269578.66 E 0.000 4310.58 269600.00 E 0.000 4331:85 Comment Target: 3-07A/L-29 T2, Drillers 6 July, 1998 -' 17:36 -2- DrJllQuest Z I Z 0 Endicott · AlaSka State Plane Zone 3' Endlcott SDI' 3-07A/L-29 ' - .. Proposal I:~la for ~07A~-29 Wp/5(r) ... fi- I~f~rmc~: Tn~lqo~h v~ se~om Oeacdl:,~cW~ · -- ' ' v~~~: O.~N~.~G 1o000- >5o Oo Scale= linch = 50Oft -3000 -2500 S. calec '1 inch = 50Oft t750 .Scal~. linch = 5OOft E,se,g, . 1oo .. ... ,~. ... .~oo" ...qsO0 Eastings '.' .,', ~'~, . 10236,00 ?~4~6 ~ 82~.97,W I I I I I 2250 2750 3250 3750 4250 Vertical Sectionsecti°n Az~mutic' 49,130' {True. North) '. . · .t 000, "500 Reference Is True North" NAME SDI 3-07A/L-29 Surface @ 'L-29 895.00 SDI 2 SDI WELL 3-07A I L-29 (Wp5r) - SURFACE & DOWNHOLE LOCATIONS ~MMENTS Surface Location Target: 7127198 ,KA STATE PLANE ZONE 3 (NAD 27) DECIMAL DEGREES (NAD 27) S & E SEC LINE OFFSETS FEL y X 5,970,968.60' 270,193.64' 70.322300° 147.863448° 2748 848 872.06' 70.339012° 3585 3340 5043 1652 ~00.00' SECTION, TOWN., DIST. RANGE, SEC 08 T11N R17E 2531 ;EC 05 T11N 1694 236 SECTION LINE OFFSETS DiST. 848 1939 1652 Notes: All coordinates shown are North American Datum 1927 (NAD 27). Alaska State Plane Coordinates shown are Zone 3 (Feet). F. Robert Bell & Assoc. Jeff Cotton 564-4969 File Name: DIUBH727.xls 7/27/98 NW Sec 5 T11N R17E Umiat X=265980.55 Y=5978913.24 NW Sec 8 SW Sec8 T11N R17E Umiat X=265688.10 Y=5968357.70 528O 91°46'08" N Sec 5&4 q,~o~,~ /'~MD 15323.9 ~o5'".~' TARGET Q,¢5~' X=269600.( ~Y=5978565 00 MD12895.00 X=267872.06 Y=5977159,97 5280 91046'07" N Sec 8&9 3-07A/L29 "3-07"SURFACE LOC. X=270193.64 Y=5970968.60 5280 271046'06" S Sec 8&9 5280 91 °43'42 N Sec 4&3 528O 91o41,17" o~ 5280 91o43'42" N Sec 9&10 5280 91o41'16" o~ [13 5280 271043'40" S Sec 9&10 528O 271 °41'16" NE Sec 3 T11N R17E Umiat X=281812.67 Y=5978435.49 SDI Well 3-07A/L-29 Wp5r Downhole Location Scale: 1"= 2000' 7/27/98 Jeff Cotton NE Sec 10 SE Sec10 T11N R17E Umiat X=281520.22 Y=5967880.08 NWSec5 T11N R17E Umi~ X=265980.55 Y=5978913.24 NW Sec 8 5280 91 °46'08" MD12895.00 X=267872.06 Y=5977159.97 MD15323.99 TARGET X=269600.00 Y=5978565.00 I I I 3340 I I I I I I I I I 5280 ~. 91 °46'07" 1652 N Sec 5&4 N Sec 8&9 5280 91 °43'42" 5280 91 °43'42" H 140259 I ~" ~ °~°~"°' ~ VEN~R ALASKAST 14 OD DATE INVOICE / CRED~ MEMO DESCRIPTION GROSS DI~UNT NET 070g~S CKO7OggSD [00. O0 ~00. O0 HANDLIN~ INST' s/h carol ~ithe~ x 411~ HE A~ACHED CHECK IS IN PAYME~ FOR I~S ~RIBED A~VE. ~~*~ ~ ~ ~ ~ ~ ~ m~ · WELL PERMIT CHECKLIST FIELD & POOL COMPANY INIT CLASS WELL NAME.z:Z~ ~-c),,'~L-.Z.?. PROGRAM: exp [] dev~[ redrll/~serv [] wellbore seg [.)ann. disposal para req II ./-.. ,,~, ? GEOL AREA ,~'~,~ UNIT# /C') '~. ~'C.) ON/OFF SHORE ~ A.) ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. N N N N 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ..... _.. _._~ ....... 26. BOPE press rating appropriate; test to ~..~-OO'~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... GEOLOGY 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... /~NZN __ 31. Data presented on potential overpressure zones ....... I Y,,~ ~/ )/'7 32. Seismic analysis of shallow gas zones ............. ~/' ~1 .~(_./l f"'l ~ 33. Seabed condition survey (if off-shore) ............. 34. Con. tact,nam, e/phone.for weekly progress reports ....... ~' Y N lexplora~ory onlyj APPR D/~TE ,~ ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone;~..~.- .... (B) will not contaminate freshwater; or caus~r-ifl~g waste... to surface' _~-'- (C) will not impair mechan~c_al4ntegnty of the well used for disposal; (D) will not damage.p~ng formation or impair recovery from a pool; and/'t''''' (E) will not~rcumvent 20 AAC 25.252 or 20 AAC 25.412. Y N 'To C~Z.~, · Y N Y N Y N ENGINEER~G: UIC/Annular COMMISSION: JDH ~/' RNC ~ ~ CO Comments/Instructions: M:chel~list rev 05/29198 dlf:C:\msoffice\wordian\diana\chocklisl 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. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION (ALASKA) INC. WELL NAlVI~ : 3-07ALL-29 FIELD NAM~ : ENDICOTT BOROUGH : NORTH SLOPE STATE : ALASKA API ~ER : 500292191101 REFERENCE NO : 98597 LIS Ta~p.~ 'Verification Listing Schlumberger Alaska Computing Center 17-NOV-l~,>~/17:01 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/17 ORIGIN : FLIC REEL NA~E : 98597 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, 3-07A/L-29, ENDICOTT, API# 50-029-21911-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/17 ORIGIN : FLIC TAPE NAlViE : 98597 CONTINUATION # : 1 PREVIOUS TAPE : COROtiNT : BP EXPLORATION, 3-07A/L-29, ENDICOTT, API# 50-029-21911-01 TAPE HEADER ENDICOTT SDI CASED HOLE WIRELINE LOGS WELL NA~E: 3-07A/L-29 API NUMBER: 5002921911 O1 OPERATOR: BP EXPLORATION (ALASKA) INC. LOGGING COMPANY: SCHLUFIBERGER WELL SERVICES TAPE CREATION DATE: 17 -NOV- 98 JOB NUMBER: 98597 LOGGING ENGINEER: PALMER OPERATOR WITNESS: BUNDY/QUESEN SURFACE LOCATION SECTION: 8 TOWNSHIP: 1 IN RANGE: 17E FNL: FSL: 2748 FEL: 848 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 57. O0 DERRICK FLOOR: 56. O0 GROUND LEVEL: 14.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 3. 750 2. 875 14995.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASUR3F~ DEPTH) LIS T~p~,Verification Listing Schlumberger Alaska Computing Center 17 -NOV- 19~/17: O1 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NTgM~ER : PASS NIk4~ER : DATE LOGGED: 09-SEP- 98 LOGGING COMPANY: SPERRY SUN BASELINE DEPTH 88888.0 14893.0 14888.5 14880.0 14874.5 14867.5 14866.0 14863.5 14856.5 14852.5 14837.5 14833.0 14828.0 14818.0 14814.5 14813.0 14808.0 14807.5 14800.5 14799.5 14797.0 14790.5 14786.0 14783.0 14781.5 14777.0 14775.5 14771.5 14770.0 14768.5 14765.5 14757.5 14757.0 14749.0 14748.5 14744.5 14741.0 14724.0 14716.5 14709.0 14699.0 14697.0 14695.5 14689.5 14669.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. 88887.5 88886.5 14891.5 14889.0 14879.5 14873.5 14866.0 14866.0 14863.0 14857.0 14852.0 14835.0 14831.0 14825.5 14817.5 14813.5 14813.5 14808.0 14807.0 14800.5 14800.5 14796.0 14789.5 14787.0 14783.5 14783.5 14778.0 14777.0 14772.5 14773.0 14769.5 14767.5 14760.0 14758.0 14750.5 14751.0 14745.5 14741.0 14721.5 14715.5 14716.5 14707.0 14700.5 14696.0 14696.0 14689.5 14689.0 14668.0 PAGE: LIS T~pw~.Verification Listing Schlumberger Alaska Computing Center 14668.0 14666.5 14664 5 14663 0 14661 5 14658 5 14654 5 14652 5 14650 5 14648 5 14627 5 14624 5 14620 0 14618 5 14612 0 14611.0 14608.5 14603.0 14601.0 14599.0 14597.5 14597.0 14595.0 14588.0 14586.0 14583.5 14579.0 14567.0 14566.5 14561.5 14557.5 14555.5 14552.5 14550.5 14548.0 14546.5 14529.5 14520.0 14518.5 14516.5 14513.5 14512.0 14505.5 14501.5 14500.0 14488.0 14481.5 14476.5 14465.5 14462.0 14460.0 14457.5 14449.5 14442.5 14434.0 14423.5 14665.5 14662.0 14657.5 14653.0 14649.5 14627.5 14624.0 14619.5 14611.0 14607.5 14602.0 14599.0 14596.0 14586.5 14578.0 14566.5 14562.0 14556.0 14550.5 14547.0 14518.0 14514.0 14506.0 14503.0 14488.0 14483.0 14478.5 14467.0 14464.0 14461.0 14450.0 14444.0 14434.0 14422.0 14668.0 14665.0 14662.0 14652.0 14649.0 14619.5 14611.0 14602.0 14599.0 14596.5 14586.5 14583.5 14577.5 14566.5 14556.0 14551.0 14544.0 14531.5 14521.0 14518.0 14514.0 14502.5 14463.5 PAGE: LIS T~p%~ Verification Listing Schlumberger Alaska Computing Center 14402 5 14400 0 14384 0 14383 5 14372 5 14362 5 14356 0 14340.5 14327 0 14319 5 14319 0 14303 0 14300 5 14297 0 14223 5 14219 5 14206 0 14189 0 14182 5 14178 0 14168 5 14166 5 14164 5 14162 5 14160 0 14152 0 14145 5 14142 0 14138 0 14133 0 14131 0 14123 5 14123 0 14091 5 14089 0 14085 0 14068 0 14059.0 14052.0 14043.0 14042.0 14028.0 14023.5 14007.0 14004.5 14003.5 13973.0 13958.0 13957.0 13944.0 13943.5 13934.5 13917.5 13908.5 13898.5 13898.0 14403.0 14384.0 14371.0 14361.5 14339.0 14325.5 14318.5 14301.5 14300.5 14297.0 14223.0 14188.0 14181.5 14178.5 14165.0 14161.5 14152.0 14146.0 14136.5 14130.5 14129.0 14121.5 14088.5 14085.0 14066.5 14059.0 14051.0 14042.5 14021.5 14005.5 14002.5 13956.0 13942.0 13906.0 13897.5 14402.5 14385.5 14358.5 14320.0 14300.5 14218.0 14206.0 14165.0 14161.5 14158.5 14140.0 14124.0 14085.0 14042.5 14029.0 14003.0 13973.0 13955.5 13942.0 13935.0 13917.0 13897.5 17-NOV-i~ .... .t 17: O1 PAGE: LIS T~-p=TM VerificatiOn Listing Schlumberger Alaska Computing Center 13891.0 13888.0 13890.0 13888.0 13879.0 13878.5 13868.0 13865.5 13833.0 13831.0 13827.0 13825.5 13824.5 13824.5 13824.0 13821.0 13822.5 13822.0 13815.0 13813.5 13783.5 13781.5 13776.5 13775.0 13772.0 13769.5 13771.0 13770.0 13767.5 13766.0 13739.0 13737.5 13729.5 13727.5 13714.5 13714.0 13706.0 13706.0 13704.5 13702.5 13698.5 13697.5 13618.0 13618.0 13609.0 13610.0 13599.0 13599.0 13582.5 13583.0 13540.0 13539.0 13505.0 13504.0 13497.0 13496.0 13495.5 13489.5 13489.5 13477.5 13476.0 13470.5 13470.0 13462.5 13461.0 13443.0 13440.5 13429.5 13431.0 13416.5 13415.0 13407.0 13408.5 13402.0 13400.0 13375.5 13375.0 13363.5 13361.5 13352.0 13353.0 13349.5 13348.5 13342.5 13344.0 13331.5 13330.0 13307.0 13306.5 13300.5 13299.0 13268.0 13269.0 13257.5 13259.5 13253.0 13253.0 13249.0 13250.5 13248.5 13250.0 13244.5 13246.0 13236.5 13238.5 13231.0 13232.0 13230.0 13231.5 13221.0 13223.0 13216.5 13218.5 PAGE: LIS T~p~erification Listing Schlumberger Alaska Computing Center 13213.0 13202.0 13200.0 13199.5 13190.0 13175.0 13173.0 13169.5 13169.0 13163.0 13156.0 13153.5 13137.5 13135.0 13134.0 13115.0 13109.5 13102.5 13093 0 13092 0 13089 5 13088 5 13081 5 13079 0 13074 0 13073 0 13069.0 13065.5 13064.5 13057.0 13053.5 13039.0 13034.5 13033.0 13030.0 13029.0 13027.5 13015.0 13012.0 13010.0 13009.5 13007.0 13004.5 12999.0 12997.5 12993.5 12993.0 12973.0 12968.0 12958.5 12952.5 12952.0 12947.5 12931.5 12925.0 12914.0 13201.5 13198.5 13189.5 13174.0 13168.5 13164.5 13156.5 13135.5 13115.5 13110.5 13102.5 13094.5 13091.5 13083.5 13079.0 13074.5 13069.5 13065.5 13053.0 13039.5 13033.5 13031.0 13027.0 13012.0 13009.5 13004.0 12999.5 12994.0 12973.5 12959.0 12952.5 12947.0 12932.5 12925.5 13213.5 13200.5 13173.5 13170.0 13155.5 13138.0 13135.5 13094.5 13091.5 13074.5 13064.5 13058.5 13036.5 13030.5 13018.0 13012.5 13009.0 12998.5 12995.0 12968.5 12953.0 12912.0 17 -NOV-19~r.17: O1 PAGE: LIS T~'Verification Listing Schlumberger Alaska Computing Center 17-NOV-I~117: O1 12911.5 12911.5 12909.5 12909.0 12902.5 12901.5 12891.0 12892.0 12885.5 12885.0 12877.5 12878.0 12871.5 12868.5 12868.5 12860.5 12860.5 12859.5 100.0 100.0 $ REMARKS: 12871.0 12860.5 101.0 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIRED ON BP EXPLORATION'S 3-07A/L-29 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE MWD GAF~A RAY, ALSO BASE PASS #1 SIGMA AND THE MWD GA~4MA RAY, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 98/11/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUFk~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 14891.5 11928.0 RST 14895.5 11929.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST LIS Ta-pre~'Verification Listing Schlumberger Alaska Computing Center 17 -NOV-1-3~~ 17: O1 PAGE: $ REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN** NAME SERVUNIT SERVICE API API API API FILE NURIB NO?4B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 SBNA FIL CU 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 CIRNFIL 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 BSAL RST PPK 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI RST PU-S 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Ta~'~'Verification Listing Schlumberger Alaska Computing Center PAGE: 9 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUM~ SAMP ELEM CODE (HEX) SFNC RST CU 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM RST CU 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 DSIG RST CU 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 FBEF RST UA 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 CRRARST 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH RST GAPI 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 TENS RST LB 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 CCL RST V 1189349 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 14895 500 NBAC.RST 2032.977 FBAC.RST 2994.652 SBNA.FIL SFNA.FIL 28 094 SBFA.FIL 48.611 SFFA.FIL 26.556 TRAT. FIL IRAT.FIL 0 404 CIRN. FIL 0.591 CIRF. FIL 1.512 BSAL.RST SIBF.RST 27 326 TPHI.RST 28.124 SFFC. RST 26.557 SFNC.RST SIGM. RST 26 562 DSIG.RST 1.942 FBEF.RST 57.724 CRRA.RST GRCH. RST -999 250 TENS.RST 13.000 CCL.RST -0.043 68.967 0.965 15.000 28.199 2.481 DEPT. 11928.000 ArBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL -999.250 SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL -999.250 IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST -999.250 SIBF.RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST -999.250 SIGM. RST -999.250 DSIG.RST -999.250 FBEF. RST -999.250 CRRA.RST -999.250 GRCH.RST 45.390 TENS.RST -999.250 CCL.RST -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE . 98/11/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS T~JVerification Listing Schlumberger Alaska Computing Center 17 -NOV- 19->~~ 17: O1 PAGE: 10 FILE HEADER FILE lV73?4~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMzENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 14892.5 12713.0 RST 14896.5 12714.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 14892.0 14887.5 14885.0 14878.5 14877.5 14873.5 14870.0 14865.0 14861.5 14836.0 14830.5 14827.0 14823.5 14813.0 14812.5 14808.0 14806.0 14800.0 14799.0 14795.0 14789.5 14786.5 14785.0 14781.5 14780.0 14775.0 14774.5 14770.5 14769.5 14767.0 14766.5 14760.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88888.5 88887.5 14891.5 14889.0 14885.5 14879.5 14878.5 14873.0 14870.0 14866.5 14863.0 14833.5 14832.0 14825.5 14824.0 14813.5 14813.5 14808.5 14807.5 14800.5 14800.5 14796.5 14789.5 14787.5 14786.0 14783.5 14783.5 14778.0 14777.0 14772.5 14773.0 14769.5 14770.0 14761.5 LIS T~p~'Verification Listing Schlumberger Alaska Computing Center 17-NOV-19~-~17 : O1 PAGE: 11 14751.0 14750.5 14747.5 14739.0 14729.0 14724.5 14722.5 14716.5 14712.5 14708.0 14707.0 14703.0 14699.5 14696.5 14695.0 14692.5 14689.5 14685.5 14676.5 14669.0 14665.0 14661.5 14661.0 14653.5 14652.0 14649 0 14648 5 14642 5 14640 5 14636 5 14625 5 14618 5 14611 0 14610 5 14606 5 14602 0 14596 0 14595.0 14592.5 14591.0 14586.5 14585.5 14578.5 14569.5 14566.5 14566.0 14564.0 14561.0 14556.0 14555.0 14551.0 14550.5 14548.0 14547.0 14546.0 14754.0 14741.0 14724.5 14721.5 14707.0 14702.0 14696.5 14693.0 14689.5 14677.0 14669.0 14665.5 14662.0 14653.5 14649.0 14641.5 14637.0 14627.0 14619.0 14611.0 14607.5 14602.5 14596.0 14592.5 14590.5 14586.5 14578.0 14570.0 14567.5 14565.0 14562.0 14556.0 14550.5 14548.0 14754.0 14750.5 14729.5 14717.0 14713.5 14708.5 14701.5 14696.0 14689.5 14686.0 14662.0 14652.5 14649.0 14643.5 14619.5 14611.0 14607.5 14597.0 14586.5 14577.5 14566.5 14556.0 14551.5 14547.0 14544.0 LIS Tap~Verification Listing Schlumberger Alaska Computing Center 17-NOV-19>-~t17:01 PAGE: 12 14540.5 14541.5 14540.5 14529.0 14531.0 14526.5 14526.5 14526.0 14527.5 14516.5 14517.5 14518.0 14511.0 14513.5 14500.0 14503.0 14498.5 14500.0 14475.0 14478.5 14459.0 14463.0 14457.0 14461.0 14455.5 14458.5 14435.5 14437.5 14423.0 14422.0 14414.0 14417.0 14411.0 14410.0 14408.0 14412.5 14400.0 14402.5 14396.0 14398.5 14392.0 14395.5 14387.0 14387.0 14384.0 14386.0 14371.0 14371.0 14362.5 14361.5 14357.0 14359.5 14355.5 14354.5 14352.0 14351.5 14347.0 14348.0 14339.5 14339.0 14335.5 14335.0 14317.0 14318.0 14311.5 14313.0 14302.5 14302.5 14283.5 14283.5 14282.0 14282.5 14254.5 14254.5 14251.0 14249.5 14232.5 14232.5 14221.5 14220.0 14213.5 14212.0 14206.5 14206.5 14201.5 14203.0 14198.0 14198.0 14183.5 14181.5 14175.5 14174.5 14173.0 14171.5 14168.0 14165.5 14166.5 14165.0 14164.0 14161.5 14161.0 14159.0 14160.0 14158.5 14154.5 14152.0 14150.0 14146.0 14140.5 14138.5 14134.0 14133.0 LIS T~p~ Verification Listing Schlumberger Alaska Computing Center 17-NOV-19~-~l 7: O1 PAGE: 13 14133.0 14131.0 14129.5 14124.5 14113.5 14103.0 14091.0 14086.5 14085.0 14079.5 14072.0 14064.5 14044.5 14042.5 14032.5 14028.5 14010.5 14003.5 14002.0 13992.0 13967.0 13965.0 13957.0 13948.5 13944 0 13941 0 13938 0 13917 5 13908 0 13901 5 13895 0 13874 5 13866 0 13850.0 13846.5 13840.0 13836.0 13825.5 13822.5 13819.5 13806.0 13805.5 13789.5 13783.0 13770.0 13768.5 13720.5 13699.5 13686.0 13681.5 13645.5 13618.5 13588.0 13580.0 13558.0 14131.0 14129.0 14111.5 14088.5 14083.5 14062.0 14043.0 14032.5 14002.5 13990.0 13961.5 13945.5 13942.5 13936.5 13906.0 13893.5 13866.0 13850.0 13821.5 13819.0 13805.0 13783.0 13769.5 13681.5 13557.0 14129.0 14124.5 14102.5 14085.0 14078.5 14072.0 14042.5 14029.0 14010.5 14001.5 13966.0 13955.5 13939.5 13917.0 13901.0 13893.5 13873.0 13847.0 13839.5 13835.0 13824.5 13806.5 13789.5 13767.0 13719.5 13697.0 13682.5 13643.0 13616.0 13586.0 13577.5 LIS T~Verification Listing Schlumberger Alaska Computing Center 17-NOV-19~117: O1 PAGE: 14 13550.0 13545.5 13535.0 13533.5 13506.5 13500.0 13496.0 13489.0 13484.5 13479.5 13427.0 13422.0 13418.5 13409.5 13408.5 13384.5 13371.0 13363.5 13353.5 13350.0 13344.5 13343.5 13334.5 13270.5 13269.5 13262.5 13255.0 13249.5 13245 5 13240 0 13230 5 13224 0 13223 0 13214 0 13204 5 13175 0 13171 5 13170 5 13165 0 13160 0 13157 5 13155 0 13145.5 13142.5 13139.5 13136.0 13134.5 13123.0 13119.0 13113.5 13110.5 13104.0 13097.5 13096.0 13093.5 13550.0 13532.5 13507.0 13496.0 13483.0 13420.5 13407.5 13364.0 13351.0 13343.0 13333.0 13269.5 13260.5 13253.0 13246.0 13231.5 13222.5 13204.0 13174.0 13169.0 13165.5 13156.5 13146.0 13135.5 13110.5 13097.0 13094.5 13543.0 13533.0 13497.5 13486.0 13479.0 13427.5 13419.5 13408.5 13385.0 13371.5 13353.0 13344.5 13272.0 13249.5 13240.5 13231.5 13223.0 13213.5 13170.0 13165~0 13161.0 13155.5 13142.O 13138.5 13135.0 13123.5 13119.0 13113.0 13105.0 13097.0 LIS T~p~e~ Verification Listing Schlumberger Alaska Computing Center 17-NOV-15~-~-' l 7: O1 PAGE: 15 13089.5 13090.5 13083.5 13084.5 13082.5 13083.5 13079.5 13079.0 13075.0 13075.0 13066.0 13064.5 13065.0 13064.0 13038.5 13039.0 13034.0 13034.0 13033.0 13033.5 13031.0 13030.5 13030.5 13030.5 13028.0 13026.5 13016.5 13018.0 13008.5 13007.5 13009.0 13000.0 12999.5 12999.0 12998.5 12995.0 12995.0 12991.0 12990.0 12985.5 12985.5 12984.0 12982.5 12978.5 12977.5 12972.5 12974.0 12965.0 12963.5 12962.5 12962.5 12962.0 12961.0 12953.0 12952.5 12944.5 12943.0 12932.5 12932.5 12931.0 12928.0 12926.5 12925.5 12923.5 12923.0 12916.0 12912.0 12914.5 12914.0 12912.5 12909.5 12911.0 12909.0 12904.0 12901.5 12900.0 12897.0 12896.5 12893.0 12890.0 12890.0 12887.5 12886.5 12885.0 12878.5 12878.0 12873.5 12871.0 12869.5 12868.5 12868.5 12866.5 12862.0 12860.5 12861.5 12861.0 12857.5 12856.5 12856.5 12856.5 12855.5 12855.0 12850.5 12849.5 12848.0 12847.5 12844.0 12841.0 12840.5 12838.0 12839.5 12838.5 LIS T~pe~;erification Listing Schlumberger Alaska Computing Center 17 -NOV- 19>~' 17: O1 PAGE: 16 12828.5 12823.0 12818.0 12817.5 12808.5 12807.0 12803.0 12799.5 12795.0 12792.0 12787.0 12778.0 12768.0 12767.0 12761.5 12761.0 12757.0 12753.0 12751.0 12745 0 12742 5 12739 0 12738 0 12736 5 12735 0 12728 0 12726 0 12724.0 12720.5 12715.0 100.0 $ 12826.5 12817.0 12808.5 12798.5 12793.5 12790.5 12777.0 12766.0 12760.0 12751.5 12741.0 12737.5 12732.5 12725.0 99.0 12822.0 12817.5 12806.5 12802.0 12786.5 12766.5 12761.5 12757.5 12751.0 12745.0 12740.5 12737.0 12728.5 12724.0 12720.5 12715.0 100.0 REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 LIS T~p~Verification Listing Schlumberger Alaska Computing Center 17-NOV-19~17:01 PAGE: 17 TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM29 SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~4 CODE (HEX) FT 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 DEPT NBAC RST CPS 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 CIRN FIL 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 BSAL RST PPK 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 CRRA RST 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1189349 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 14896.500 ArBAC.RST 3737.077 FBAC.RST 5024.049 SBNA.FIL SFNA.FIL 26.735 SBFA.FIL 49.297 SFFA.FIL 25.090 TRAT.FIL IRAT. FIL 0.413 CIRN. FIL 0.651 CIRF. FIL 1.678 BSAL.RST SIBF. RST 27.693 TPHI.RST 26.972 SFFC.RST 25.155 SFNC.RST SIGM. RST 25.032 DSIG.RST 1.372 FBEF. RST 60.553 CRRA.RST 68.637 0.947 16.055 26.853 2.478 LIS T~p~-~Verification Listing Schlumberger Alaska Computing Center 17-NOV-19m~'17:01 PAGE: 18 GRCH. RST -999.250 TENS.RST DEPT. 12713.000 NBAC.RST SFNA.FIL -999.250 SBFA.FIL IRAT.FIL -999.250 CIRN. FIL SIBF.RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH.RST 33.472 TENS.RST 11.000 CCL.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 CIRF. FIL -999.250 SFFC.RST -999.250 FBEF.RST -999.250 CCL.RST 0.005 -999.250 SBNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC.RST -999.250 CRRA.RST -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE ' FLIC VERSION : O01CO1 DATE : 98/11/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, RST $ REMARKS: THIS FILE CONTAINS THE ARITHgfETIC AVERAGE OF BASE PASSES 1 & 2. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA LIS Tap~Veri fi ca ti on Lis ting Schlumberger Alaska Computing Center 17-NOV-19~-~17 '. O1 PAGE: 19 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA RSAV CU 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA RSAV CU 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA RSAV CU 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA RSAV CU 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT RSAV 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT RSAV 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNRSAV 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF RSAV 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 BSAL RSAV PPK 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RSAV CU 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RSAV PU-S 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RSAV CU 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RSAV CU 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RSAV CU 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RSAV CU 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RSAV UA 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 CRRA RSAV 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 1189349 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape--Verification Listing Schlumberger Alaska Computing Center 17-NOV-I~J17 : O1 PAGE 2O ** DATA ** DEPT. 14895. 500 NBAC. RST 2032. 977 FBAC.RST 2994. 652 SBNA.RSAV SFNA.RSAV 28.352 SBFA.RSAV 47.035 SFFA.RSAV 26.519 TRAT. RSAV IRAT. RSAV O. 408 CIRN. RSAV O. 583 CIRF. RSAV 1.514 BSAL. RSAV SIBF.RSAV 27.509 TPHI.RSAV 27.098 SFFC.RSAV 26.499 SFNC.RSAV SIGM.RSAV 26. 491 DSIG.RSAV 1 . 605 FBEF. RSAV 59. 139 CRRA.RSAV GRCH. RST -999. 250 68. 742 O. 948 15. 528 28.381 2.479 DEPT. 11928.000 NBAC.RST -999.250 FBAC. RST -999.250 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT. RSAV -999.250 IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF.RSAV -999.250 BSAL.RSAV -999.250 SIBF.RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF.RSAV -999.250 CRRA.RSAV -999.250 GRCH.RST 45.390 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFiBER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS AK]FiBER: 1 DEPTH INCREFiENT: 0.5000 FILE SUM~J~Y VENDOR TOOL CODE START DEPTH STOP DEPTH RST 14926.0 11855.5 $ LIS Tap~erification Listing Schlumberger Alaska Computing Center 17 -NOV- 19~>~ ~17 : O1 PAGE: 21 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) '. NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): 24 -0CT-98 8Cl -205 1100 23-0CT-98 14929.0 14930.0 11928.0 14897.0 3600.0 TOOL NUMBER GR RST-A 3. 750 14995.0 PRODUCED FLUIDS 214.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 ~ COUNT RATE LOW SCALE (CPS): 0 N~ COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): THERMAL SANDSTONE 2.65 REMARKS: THIS IS THE DEEPEST COIL TUBING ELINE JOB DONE ON THE NORTH SLOPE. LIS TaPe'Verification Listing Schlumberger Alaska Computing Center 17-NOV-19~b=~ J17: O1 PAGE: 22 ORIGINAL DEPTH CONTROL TO PI-MSFL-GR LOG DEPTH CORRELATED TO MWD-GR OF 06-SEP-1998 BY ADDING 10 FT ALL LOG PRESENTED TIED IN TO MWD / MCNL RAN PSP WITH PILS AND RSTA PRODUCED WATER DATA (FROM LAB) CL- 16055 mg/L , Magnesium 666 mg/L "appears to be sea water not normal produced water" THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUPfl~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 CS PS1 F/HR 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 TENS PS1 LB 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 NPHV PS1 V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 NPDE PS1 V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 NSCE PS1 V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 CRRA PS1 1189349 O0 000 O0 0 4 1 i 4 68 0000000000 NSCR PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 AQTMPS1 S 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 CHV PS1 V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 CPSV PSi V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Ta~--'Verification Listing Schlumberger Alaska Computing Center 17-NOV-19L~ '17:O1 PAGE: 23 NAFiE SERV UNIT SERVICE API API API API FILE NUM~ ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CI-~SS MOD NUlVIB Sfi2~IPELt~ CODE CP2V PS1 V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 CM2V PS1 V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 RCFR PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 RCLC PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 RCRC PSl 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 RCAKPS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 RTDF PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 FPHVPS1 V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 FPDE PS1 V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 FSCE PSi V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 FSCR PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 AQTF PS1 S 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SF6P PS1 PSIG 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 HVPV PS1 V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 BMCU PS1 UA 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 GDCU PS1 MA 1189349 O0 000 O0 0 4 i 1 4 68 0000000000 EXCU PS1 UA 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 NBEF PS1 UA 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF PS1 UA 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 NPGF PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 FPGF PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 BSTR PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 BSPR PSi 1189349 O0 000 O0 0 4 i 1 4 68 0000000000 MARC PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 XHV PS1 V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 XPSV PSl V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 XP2V PS1 V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 XM2V PS1 V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 RXFR PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 RXLC PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 RXRC PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 RXAKPS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SHCU PSi MA 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL PS1 PPK 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL SIG PPK 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNPS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF PSI 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNFIL 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF FIL 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG PS1 CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC PS1 CPS 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC PS1 CPS 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA PS1 CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA PS1 CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA PSl CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA PS1 CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA SIG CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA SIG CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA SIG CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Ta~&~-gerification Listing Schlumberger Alaska Computing Center PAGE: 24 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) SBFA SIG CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF PS1 CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC PS1 CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC PS1 CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PS1 CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF SIG CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM SIG CU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT SIG 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT FIL 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 GR PS1 GAPI 1189349 O0 000 O0 0 4 I 1 4 68 0000000000 RDIX PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 CRNI PS1 K~Z 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 CRFI PS1 KHZ 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 CTM PS1 DEGC 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 XTM PS1 DEGC 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 TAV PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 FICU PS1 AMP 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 CACU PS1 AMP 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 BUST PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 BUSP PSi 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 RSXS PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PS1 PU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI SIG PU 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 CCLC PS1 V 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 RSCS PS1 1189349 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 14900.000 NPDE. PS1 1560.823 NSCE. PS1 AQTM. PS1 O . 661 CHV. PS1 CM2V. PS1 -12. 152 RCFR. PS1 RCAK. PS1 O. 000 RTDF. PS1 FSCE. PS1 2.083 FSCR.PS1 HVPV. PS1 162.598 BMCU. PS1 NBEF. PSl 24.167 FBEF. PS1 BSTR.PS1 39.132 BSPR.PS1 XPSV. PS1 5.073 XP2V. PS1 RXLC. PS1 0.000 RXRC.PS1 BSAL.PS1 15.000 BSAL.SIG CIRN. FIL 0.568 CIRF. FIL IRAT. PS1 0.383 IRAT. FIL SFFA.PS1 29.559 SBNA.PS1 SFFA.SIG 0.851 SBNA.SIG CS.PS1 3822.125 TENS.PSi 12.000 NPHV. PS1 1577.150 2.524 CRRA.PS1 2.276 NSCR.PS1 0.395 202.066 CPSV. PS1 5.089 CP2V. PS1 12.056 0.000 RCLC. PS1 0.000 RCRC.PSl 0.000 0.000 FPHV. PS1 1508.790 FPDE.PS1 1493.684 0.214 AQTF. PS1 29.333 GDCU. PS1 55 009 NPGF. PS1 1 12 0 1 1 0 59 4 0.661 SF6P.PS1 153.112 60.545 EXCU. PS1 5.622 0.999 FPGF. PS1 1.000 062 MARC.PSI 0.000 X~V. PS1 200.218 173 XM2V. PS1 -12.368 RXFR.PS1 0.000 000 RXAK. PS1 1.000 SHCU. PS1 30.325 000 CIRN. PS1 0.572 CIRF. PS1 1.418 469 DSIG.PS1 2.055 FBAC.PS1 2907.775 388 NBAC. PS1 2138.174 SFNA.PS1 33.606 246 SBFA.PS1 50.303 SFNA.SIG 0.946 394 SBFA.SIG 5.634 SFNA.FIL 32.031 LIS Ta~"~Zerification Listing Schlumberger Alaska Computing Center 17-NOV-19~l17:01 PAGE: 25 SFFA.FIL 29.054 SBNA.FIL SFNC.PSl 32.007 SFFC.PS1 SIGM. SIG 0.604 TRAT.PS1 GR.PS1 104.012 RDIX. PS1 CTM. PS1 99.121 XTM. PS1 CACU. PS1 2.615 BUST. PSi TPHI.PS1 30.035 TPHI.SIG DEPT. NPDE. PS1 AQTM. PS1 CM2 V. PS1 RCAK. PSl FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR. PS1 XP5 V. PS1 RXLC. PS1 BSAL. PS1 CIRN. FIL IRAT. PS1 SFFA. PSi SFFA. SIG SFFA . FIL SFNC. PS1 SIGM. SIG GR. PS1 CTM. PS1 CACU. PS1 TPHI. PS1 11900. 000 1552. 850 1 322 -12 211 2 000 1 992 161 098 29 974 71 262 5 071 0 000 15 000 0 291 0 436 51 554 3. 173 50. 466 49. 747 3. 029 49. 045 83. 740 2. 629 44. 166 CS.PS1 NSCE. PS1 CHV. PS1 RCFR.PS1 RTDF. PS1 FSCR. PS1 BMCU. PSi FBEF. PS1 BSPR.PS1 XP2V. PS1 RXRC. PS1 BSAL.SIG CIRF.FIL IRAT. FIL SBNA.PS1 SBNA.SIG SBNA.FIL SFFC. PS1 TRAT. PS1 RDIX. PS1 XTM. PS1 BUST. PSi TPHI.SIG 59.311 SBFA.FIL 28.934 SIGM. PS1 1.004 TRAT. SIG 9063. 000 CRNI. PS1 97. 229 TAV. PS1 3 . 000 BUSP. PS1 0.921 CCLC.PS1 3 620. 692 TENS. PS1 2. 497 CRRA. PS1 202. 792 CPSV. PS1 0.000 RCLC. PSl 0.000 FPHV. PS1 -0.279 AQTF. PS1 33.628 GDCU. PS1 67.679 NPGF. PS1 1.175 MARC.PSi 12.182 X~42V. PS1 0.000 RXAK.PS1 1.000 CIRN. PS1 0.522 DSIG.PS1 0.436 NBAC.PS1 76.976 SBFA.PS1 4.470 SBFA.SIG 75.071 SBFA.FIL 49.395 SIGM. PS1 1.245 TRAT. SIG 52296.000 CRNI.PSl 81.229 TAV. PS1 3.000 BUSP.PS1 1.703 CCLC. PS1 51.782 29.087 0.028 459.976 95.031 3.000 0.000 13.000 2.258 5.074 0.000 1497.804 1.322 59.895 0.998 0.000 -12.382 1.000 0.294 0.351 2408.497 71.862 6.236 69.833 49.395 0.063 439.334 94.960 3.000 0.001 SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 FICU. PS1 RSXS. PS1 RSCS. PS1 NPHV. PS1 NSCR.PS1 CP2V. PSl RCRC. PS1 FPDE.PS1 SF6P. PS1 EXCU. PS1 FPGF. PS1 X~fV. PS1 RXFR.PSl SHCU. PS1 CIRF. PS1 FBAC.PS1 SFNA. PSI SFNA. SIG SFNA. FIL SIBF. PS1 SIBF. SIG TRA T. FIL CRFI.PS1 FICU. PS1 RSXS.PS1 RSCS.PS1 27.326 0.348 0.997 202.083 2.487 8878.000 8463.000 1563.722 -0 284 12 121 0 000 1484 262 148 630 3 917 1 000 2OO 075 0.000 34.541 0.511 3189.542 49.071 2.478 49. 727 27.326 0.348 1.273 194. 575 2.599 8878.000 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tap~ ~erification Listing Schlumberger Alaska Computing Center 17 -NOV-19i~-i 7: O1 PAGE: 26 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMFLARY VENDOR TOOL CODE START DEPTH RST 14937.5 $ LOG HEADER DATA STOP DEPTH 12613.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAi~MA RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 24-0CT-98 8Cl -205 1100 23-0CT-98 14929.0 14930.0 11928.0 14897.0 1800.0 TOOL NUMBER GR RST-A 3. 750 14995.0 PRODUCED FLUIDS 214.0 LIS TaP~verification Listing Schlumberger Alaska Computing Center PAGE: 2 7 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THEJAMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COU~Ff RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: THIS IS THE DEEPEST COIL TUBING ELINE JOB DONE ON THE NORTH SLOPE. ORIGINAL DEPTH CONTROL TO PI-MSFL-GR LOG DEPTH CORRELATED TO MWD-GR OF 06-SEP-1998 BY ADDING 10 FT ALL LOG PRESENTED TIED IN TO MWD / MCNL RAN PSP WITH PILS AND RSTA PRODUCED WATER DATA (FROM LAB) CL- 16055 mg/L , Magnesium 666 mg/L "appears to be sea water not normal produced water" THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 3 68 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 LIS TaP~erification Listing Schlumberger Alaska Computing Center 17-NOV-19~-i7:01 PAGE: 28 TYPE REPR CODE VALUE 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 CS PS2 F/HR 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS2 LB 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 NPHVPS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 NPDE PS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 NSCE PS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA PS2 1189349 O0 000 O0 0 $ 1 1 4 68 0000000000 NSCR PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 AQTMPS2 S 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 CHV PS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 CPSV PS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 CM2V PS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 RCFR PS2 1189349 O0 000 O0 0 $ 1 1 4 68 0000000000 RCLC PS2 1189349 O0 000 O0 0 $ 1 1 4 68 0000000000 RCRC PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 RCAKPS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 RTDF PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 FPHVPS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 FPDE PS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 FSCE PS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 FSCR PS2 1189349 O0 000 O0 0 $ 1 1 4 68 0000000000 AQTF PS2 S 1189349 O0 000 O0 0 $ 1 1 4 68 0000000000 SF6P PS2 PSIG 1189349 O0 000 O0 0 $ 1 1 4 68 0000000000 HVPV PS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 BMCU PS2 UA 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 GDCU PS2 MA 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 EXCU PS2 UA 1189349 O0 000 O0 0 $ 1 1 4 68 0000000000 NBEF PS2 UA 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF PS2 UA 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 NPGF PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 FPGF PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 BSTR PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 BSPR PS2 1189349 O0 000 O0 0 $ 1 1 4 68 0000000000 MARC PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 Xh7 PS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 XPSV PS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 XP2V PS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 X~f2V PS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape~erification Listing Schlumberger Alaska Computing Center 17-NOV-19~7:01 PAGE: 29 NAM~ SERV UNIT SERVICE API API API API FILE NUAiB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) RXFR PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 RXLC PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 RXRC PS2 1189349 O0 000 O0 0 $ 1 1 4 68 0000000000 RXAKPS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SHCU PS2 MA 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL PS2 PPK 1189349 O0 000 O0 0 $ 1 1 4 68 0000000000 BSAL SIG PPK 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNPS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF FIL 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG PS2 CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS2 CPS 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC PS2 CPS 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA PS2 CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA PS2 CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA PS2 CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA PS2 CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA SIG CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA SIG CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA SIG CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA SIG CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA FIL CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF PS2 CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC PS2 CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC PS2 CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS2 CU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF SIG CU 1189349 O0 000 O0 0 $ 1 1 4 68 0000000000 SIGM SIG CU 1189349 O0 000 O0 0 $ 1 1 4 68 0000000000 TRAT PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT SIG 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT FIL 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS2 GAPI 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 RDIX PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 CRNI PS2 KHZ 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 CRFI PS2 KHZ 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 CTM PS2 DEGC 1189349 O0 000 O0 0 $ 1 1 4 68 0000000000 XTM PS2 DEGC 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 TAV PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 FICU PS2 AMP 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 CACU PS2 AMP 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 BUST PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 BUSP PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 RSXS PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS2 PU 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI SIG PU 1189349 O0 000 O0 0 $ 1 1 4 68 0000000000 LIS TaP'Y` '~erification Listing Schlumberger Alaska Computing Center 17-NOV-19~z7:01 PAGE: 30 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) CCLC PS2 V 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 RSCS PS2 1189349 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 14900.000 CS.PS2 NPDE. PS2 1572.686 NSCE.PS2 AQTM. PS2 0.661 CHV. PS2 CM2V. PS2 -12.093 RCFR.PS2 RCAK. PS2 2.000 RTDF. PS2 FSCE. PS2 2.106 FSCR.PS2 HVPV. PS2 162.702 BMCU. PS2 NBEF. PS2 23.770 FBEF. PS2 BSTR.PS2 65.022 BSPR.PS2 XPSV. PS2 5.071 XP2V. PS2 RXLC. PS2 0.000 RXRC. PS2 BSAL.PS2 16.055 BSAL.SIG CIRN. FIL 0.548 CIRF. FIL IRAT. PS2 0.394 IRAT.FIL SFFA.PS2 31.110 SBNA.PS2 SFFA.SIG 0.765 SBNA.SIG SFFA.FIL 29.689 SBNA.FIL SFNC. PS2 30.734 SFFC. PS2 SIGM. SIG 0.565 TRAT. PS2 GR.PS2 1421.439 RDIX. PS2 CTM. PS2 102.051 XTM. PS2 CACU. PS2 2.615 BUST.PS2 TPHI.PS2 28.641 TPHI.SIG DEPT. 12613.500 CS.PS2 NPDE. PS2 1560.899 NSCE. PS2 AQTM. PS2 0.661 CHV. PS2 CM2V. PS2 -12.270 RCFR.PS2 RCAK. PS2 0.000 RTDF. PS2 FSCE. PS2 2.070 FSCR.PS2 HVPV. PS2 161.214 BMCU. PS2 NBEF. PS2 27.749 FBEF. PS2 BSTR.PS2 65.621 BSPR.PS2 XPSV. PS2 5.069 XP2V. PS2 RXLC. PS2 0.000 RXRC. PS2 BSAL.PS2 16.055 BSAL.SIG CIRN. FIL 0.476 CIRF. FIL IRAT. PS2 0.359 IRAT. FIL SFFA.PS2 33.007 SBNA.PS2 SFFA.SIG 1.250 SBNA.SIG SFFA.FIL 30.270 SBNA.FIL SFNC. PS2 36.043 SFFC.PS2 SIGM. SIG 0.815 TRAT. PS2 GR.PS2 46.155 RDIX. PS2 1809 582 2 504 203 035 0 000 0 000 -0 447 29 778 56 909 1 167 12 164 0.000 1.000 1.444 0.395 73.197 4.607 68.887 29.493 0.981 30576.000 101.563 3.000 0.795 4588.509 2.518 202.792 0.000 0.000 0.017 32.177 74.126 1.090 12.171 0.000 1.000 1.238 0.360 64.794 4.136 65.045 30.212 1.064 93719.000 TENS. PS2 9.000 NPHV. PS2 CRRA.PS2 2.394 NSCR.PS2 CPSV. PS2 5.069 CP2V. PS2 RCLC. PS2 0.000 RCRC. PS2 FPHV. PS2 1529.542 FPDE. PS2 AQTF. PS2 1.102 SF6P. PS2 GDCU. PS2 60.012 EXCU. PS2 NPGF. PS2 1.003 FPGF. PS2 MARC. PS2 0.000 XHV. PS2 XM2V. PS2 -12.355 RXFR.PS2 RXAK. PS2 1.000 SHCU. PS2 CIRN. PS2 0.533 CIRF. PS2 DSIG. PS2 1.048 FBAC. PS2 NBAC. PS2 3653.762 SFNA.PS2 SBFA.PS2 51.321 SFNA.SIG SBFA.SIG 4.562 SFNA.FIL SBFA.FIL 48.146 SIBF. PS2 SIGM. PS2 29.657 SIBF. SIG TRAT. SIG 0.024 TRAT. FIL CRNI. PS2 481.312 CRFI.PS2 TAV. PS2 94.980 FICU. PS2 BUSP. PS2 3.000 RSXS.PS2 CCLC. PS2 0.011 RSCS.PS2 TENS.PS2 8.000 NPHV. PS2 CRRA. PS2 2.671 NSCR.PS2 CPSV. PS2 5.069 CP2V. PS2 RCLC. PS2 0.000 RCRC. PS2 FPHV. PS2 1501.466 FPDE. PS2 AQTF. PS2 0.661 SF6P.PS2 GDCU. PS2 60.066 EXCU. PS2 NPGF. PS2 0.996 FPGF. PS2 MARC. PS2 0.000 XHV. PS2 XM2V. PS2 -12.374 RXFR.PS2 RXAK. PS2 0.000 SHCU. PS2 CIRN. PS2 0.502 CIRF. PS2 DSIG. PS2 5.063 FBAC.PS2 NBAC. PS2 3244.207 SFNA.PS2 SBFA.PS2 55.075 SFNA.SIG SBFA.SIG 5.757 SFNA.FIL SBFA.FIL 55.042 SIBF. PS2 SIGM. PS2 30.266 SIBF. SIG TRAT. SIG 0.033 TRAT. FIL CRNI.PS2 464.509 CRFI.PS2 1584.474 -0.107 12.041 0.000 1506.196 164.950 5.354 0.996 200.335 0.000 39.906 1.350 4696.202 32.254 1.021 30.761 27.693 0.348 O. 973 201. 038 2. 413 8878.000 8463.000 1569.825 -0.385 12.143 0.000 1488.725 153.229 3.814 1.003 200.248 0.000 43.468 1.097 3368.984 33.668 1.088 35.892 27.693 0.348 1.123 173.885 LIS Tap~-~erification Listing Schlumberger Alaska Computing Center 17-NOV-199~7:01 PAGE: 31 CTM. PS2 81.055 XTM. PS2 CACU. PS2 2.629 BUST. PS2 TPHI.PS2 36.858 TPHI.SIG 79. 346 TAV. PS2 3. 000 BUSP. PS2 1.110 CCLC. PS2 95.008 3.000 -999.250 FICU. PS2 RSXS.PS2 RSCS. PS2 2.556 8878.000 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION : O01CO1 DATE : 98/11/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/11/17 ORIGIN · FLIC TAPE NAME : 98597 CONTINUATION # : 1 PREVIOUS TAPE : COM~IENT · BP EXPLORATION, 3-07A/L-29, ENDICOTT, API# 50-029-21911-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/11/17 ORIGIN : FLIC REEL NAME : 98597 CONTINUATION # : PREVIOUS REEL : COF~4ENT ' BP EXPLORATION, 3-07A/L-29, ENDICOTT, API # 50-029-21911-01 Sperry-Sun Drilling Services LIS Scan Utility Fri Sep 18 23:46:16 1998 Reel Header Service name ............. LISTPE Date ..................... 98/09/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/09/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER ENDICOTT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY:, TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-80352 E. CRIBBS E. VAUGHN . -iVED SEP 25 1998 ~,a Gl & Gas Cons, Commi~ g~ch~mge 3-07A/%-29 500292191101 BP E×?%Olq.ATZON (AT_~SI<A), ZNC. SPERRY-SUN DRILLING SERVICES 18-SEP-98 MWD RUN 2 AK-MW-80352 E. CRIBBS E. VAUGHN MWD RUN 4 AK-MW-80352 E. CRIBBS J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: MWD RUN 5 AK-MW-80352 E. CRIBBS J. CARLILE MWD RUN 6 AK-MW-80352 E. CRIBBS J. CARLILE 8 liN 017 2748 848 MWD RUN 7 AK-MW-80352 M. HANIK J. CARLILE FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE .00 56.00 14.00 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 9. 625 12906.0 PRODUCTION STRING 3. 750 14995.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-7 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS (SOLAR-175). 3. MWD RUN 3 MADE NO FOOTAGE AND IS NOT PRESENTED. 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSAT- ION BETWEEN E GOEBEL OF BP EXPLORATION (ALASKA), INC. AND J GALVIN OF SPERRY-SUN DRILLING SERVICES ON 09/16/98. THIS DATA IS CONSIDERED PDC. 4. MWD RUNS 1,2, AND 4-7 REPRESENT WELL 3-07A/L-29 WITH API#: 50-029-21911-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14995'MD, 10170'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 12851.5 14966.5 ROP 12890.0 14994.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH EQUIVALENT UNSHIFTED DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 4 MWD 5 MWD 6 MWD 7 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 12915.0 13125.0 13125.0 13327.0 13327.0 14109.0 14109.0 14507.0 14507.0 14764.0 14764.0 14995.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12851.5 14994.5 13923 4287 12851.5 GR 3.21 185.85 21.2222 4231 12851.5 ROP 0.04 619.28 37.816 4210 12890 Last Reading 14994.5 14966.5 14994.5 First Reading For Entire File .......... 12851.5 Last Reading For Entire File ........... 14994.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12851.5 ROP 12890.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13096.0 13125.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 30-AUG-98 INSITE 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 13125.0 12915.0 13125.0 53.2 79.6 TOOL NUMBER SOLAR GM 82764 3.750 3.8 QUI KDRI LLN 10.00 43.0 9.0 5.8 .000 .000 .000 .000 71.1 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12851.5 13125 12988.2 548 12851.5 GR 7.96 173.38 25.2128 490 12851.5 ROP 0.82 619.28 67.3232 471 12890 Last Reading 13125 13096 13125 First Reading For Entire File .......... 12851.5 Last Reading For Entire File ........... 13125 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13100.0 ROP 13125.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13298.0 13327.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 01-SEP-98 INSITE 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 13327.0 13125.0 13327.0 85.8 102.6 TOOL NUMBER SOLAR GM 74165 3.750 3.8 QU I KDRI LLN 10.00 46.0 9.1 4.7 .000 .000 .000 .000 76.7 .3 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 13100 13327 13213.5 455 13100 GR 8.82 120.01 30.2744 397 13100 ROP 0.46 145.33 13.4504 404 13125.5 Last Reading 13327 13298 13327 First Reading For Entire File .......... 13100 Last Reading For Entire File ........... 13327 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13298.5 ROP 13327.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 14080.0 14109.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN):- DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 04-SEP-98 INSITE 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 14109.0 13327.0 14109.0 94.6 101.4 TOOL NUMBER SOLAR GM 82764 3.750 3.8 QUIKDRILLN 10.00 50.0 9.6 4.8 .000 .000 .000 .000 78.3 .3 Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 13298.5 14109 13703.8 1622 13298.5 GR 5.65 38.62 11.5492 1564 13298.5 ROP 0.04 243.13 40.8244 1564 13327.5 Last Reading 14109 14080 14109 First Reading For Entire File .......... 13298.5 Last Reading For Entire File ........... 14109 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/18 Maximum Physical Record..65535 'File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH STOP DEPTH 14081.5 14479.0 14110.5 14507.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVA]L (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (Oh74M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 06-SEP-98 INSITE 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 14507.0 14109.0 14507.0 82.6 99.8 TOOL NUMBER SOLAR GM 74165 3.750 3.8 QUIKDRILLN 10.00 48.0 9.5 4.1 .000 .000 .000 .000 76.7 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 5 API 4 1 68 ROP MWD 5 FT/H 4 1 68 0 1 4 2 8 3 Name Min Max Mean Nsam DEPT 14081.5 14507 14294.2 852 GR 3.21 108.38 14.888 796 ROP 0.04 455.04 32.588 794 First Last Reading Reading 14081.5 14507 14081.5 14479 14110.5 14507 First Reading For Entire File .......... 14081.5 Last Reading For Entire File ........... 14507 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14479.5 14735.5 ROP 14509.0 14764.0 $ LOG HEADER DATA DATE LOGGED: 08-SEP-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): INSITE 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 14764.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 14507.0 14764.0 65.6 79.0 TOOL NUMBER SOLAR GM 82764 3.750 3.8 QUIKDRILLN 10.00 50.0 9.3 4.1 .000 · 000 .000 .000 82.2 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 API 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam DEPT 14479.5 14764 14621.8 570 GR 5.88 182.36 37.5004 513 ROP 0.54 129.22 22.4854 511 Reading Reading 14479.5 14764 14479.5 14735.5 14509 14764 First Reading For Entire File .......... 14479.5 Last Reading For Entire File ........... 14764 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 ConYment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14736.5 14966.5 ROP 14765.0 14994.5 $ LOG HEADER DATA DATE LOGGED: 09-SEP-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 70.6 MAXIMUM ANGLE: 73.1 INSITE 3.2 TM3.29/.41 DM3.07/.13 GM 1.22 MEMORY 14995.0 14764.0 14995.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER SOLAR GM 82764 3.750 3.8 QUIKDRILLN 10.00 50.0 8.7 4.7 .000 .000 .000 .000 81.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 API 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 14736.5 14994.5 14865.5 517 14736.5 GR 5.86 185.85 34.9313 461 14736.5 ROP 0.73 300 44.9341 460 14765 Last Reading 14994.5 14966.5 14994.5 First Reading For Entire File .......... 14736.5 Last Reading For Entire File ........... 14994.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/09/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/09/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File