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Home My WebLink About185-088CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Rixse, Melvin G (OGC) To:Todd Sidoti Cc:AOGCC Records (CED sponsored) Subject:20240710 1545 15 Day Extension APPROVAL to flow under evaluation for 45 days MPU C-14A (PTD 185-088) Artificial Lift Date:Wednesday, July 10, 2024 3:47:20 PM Attachments:image001.png image002.png Todd, Additional 15 day extension approved. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Todd Sidoti <Todd.Sidoti@hilcorp.com> Sent: Wednesday, July 10, 2024 3:40 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] 20240529 1349 APPROVAL to flow under evaluation for 45 days MPU C-14A (PTD 185-088) Artificial Lift Hi Mel, We have secured the parts needed to convert MPC-14A to a forward circulating design. The manufacturer is behind schedule, but we are hoping for the equipment to arrive next week. We reach the end of our 45 day evaluation period on Saturday 7/13. Hilcorp would like to request an additional 15 days permission to continue producing this well in a reverse circulating configuration while we wait on the required components. Thanks, Todd From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, May 29, 2024 1:50 PM To: Todd Sidoti <Todd.Sidoti@hilcorp.com> Subject: [EXTERNAL] 20240529 1349 APPROVAL to flow under evaluation for 45 days MPU C-14A (PTD 185-088) Artificial Lift Todd, Hilcorp is approved to flow MPU C-14A for 45 days with a reverse circulating jet pump to evaluate alternative artificial life methods. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Todd Sidoti <Todd.Sidoti@hilcorp.com> Sent: Wednesday, May 29, 2024 1:40 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: MPC-14A (PTD 185-088) Artificial Lift HI Mel, Thank you for your reply. I could not find record of the work being completed but it makes sense that it was. Hilcorp requests to flow the well under evaluation for 45 days in a reverse circulating condition. We will use the under evaluation period for three reasons: to determine the well’s inflow performance, to acquire the necessary downhole equipment, and to engineer and fabricate the surface piping reconfigurations. Please let me know if you need any more supporting information for the request. Thanks, Todd From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, May 29, 2024 9:46 AM To: Todd Sidoti <Todd.Sidoti@hilcorp.com> Subject: [EXTERNAL] RE: MPC-14A (PTD 185-088) Artificial Lift 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. Todd, I found this in the original Conoco PTD for C-14. It appears to me that the drilling plan was to isolate the ArcticPak’d OA from the 9-5/8” shoe. I could not find a drilling report to confirm they completed as planned. CO 808 Rule 2 3. A forward circulating jet pump, at least one barrier to formation, a SC shoe that may be unmonitorable, and an equivalent BHP gradient less than 8.55 ppg. If Hilcorp wants to propose a 30-60 day flow under evaluation request with a reverse circulating jet pump, I can review with commissioners to see if they would approve. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Todd Sidoti <Todd.Sidoti@hilcorp.com> Sent: Tuesday, May 28, 2024 3:08 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: MPC-14A (PTD 185-088) Artificial Lift Hi Mel, While trying to confirm that our well had an open shoe OA, we were unable to establish injectivity. We pressured up to 3000 psi and the leak off was minimal. The shoe is landed in a shale interval within the Schrader OBc formation which may explain why we are unable to inject. There are no productive sands below the shoe that we could monitor until we get to the Kuparuk formation. The OA pressure history on this well is graphed below. When the well is online it appears that the OA has fluctuations that could be indications of one-way formation communication but I am unable to verify this. The well passed a MIT-IA to 3650 on 2/11/24 so I am confident that the well is in a good place to safely operate in the near-term. Thanks, Todd From: Todd Sidoti Sent: Friday, May 24, 2024 3:46 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MPC-14A (PTD 185-088) Artificial Lift Hi Mel, MPC-14A is a recent coiled tubing sidetrack drilled and permitted (Sundry 323-672) as a producer. The well was previously an ESP producer, we installed a sliding sleeve in order to produce it as a reverse circulating jet pump. All conditions of CO808 are met for this well. I am sending this email to ask if you would require any more information before we bring the well online. High pressure IA limit will be 3650 psi (150 psi over power fluid header pressure). Low pressure IA limit will be 1800 psi. High pressure tubing limit will be 650 psi. Thanks, Todd Todd Sidoti | Operations Engineer | Hilcorp Alaska | 907-632-4113 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, thenpromptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems ordata. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, thenpromptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems ordata. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, thenpromptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems ordata. 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. , By Grace Christianson at 11:39 am, May 15, 2024 Abandoned 4/25/2024 JSB RBDMS JSB 060424 xG MGR19DEC2025 DSR-6/10/24 Drilling Manager 05/14/24 Monty M Myers Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.05.15 08:01:15 - 08'00' Taylor Wellman (2143) _____________________________________________________________________________________ Revised By: JNL 5/13/2024 PROPOSED Milne Point Unit Well: MPU C-14 Last Completed: 2/10/2024 PTD: 185-088 TD =8,833 (MD) / TD = 7,306’(TVD) 13-3/8” Last Tag @ 8,720’ w/ Pipe on 7/7/97 Orig. KB Elev.: 52’/ GL Elev.: 17’ 7” 1 2 3 1 6 5 Est. TOC @ ±7,650’ 9-5/8” Whipstock set @8,240’ PBTD =8,240’ (MD) / PBTD =6,865’(TVD) Upper ECP @ 8,519’ Lower ECP @ 8,539’ 7 8 4 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / N/A 12.715 Surface 115' 0.157 9-5/8" Surface 36 / K-55 / BTC 8.921 Surface 5,100’ 0.077 7" Production 29 / L-80 / BTC 6.276 Surface 8,822’ 0.0372 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TXP 3.958 Surface 8,106’ 0.0087 4-1/2” Tubing 12.6 / L-80 / BTC 3.958 8,274’ 8,507’ 0.01521 JEWELRY DETAIL No Depth Item 1 7,891’ 4.5” x 3.813” Sliding Sleeve 2 7,951’ 7” x 4.5” D&L Perm Hyd Iso Packer 3 8,015’ X Nipple 3.813” 4 8,066’ 4.5” WLEG – Bottom @ 8,106’ 5 8,274’ 7” 23# - 29# Versatrieve Packer 6 8,322’ 4-1/2” 12.75# N-80 LLP .20 Ga. Screen – Bottom @ 8,346’ 7 8,431’ 4-1/2” 12.75# N-80 LLP .20 Ga. Screen – Bottom @ 8,461’ 8 8,503’ 7” 23# - 32# BWD Sump Packer –Bottom @ 8,507’ PERFORATION DETAIL, REF LOG: 5/17/85 DIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1 8,327’ 8,344’ 6,931’ 6,943’ 7’ 8/9/1995 Closed 8,327’ 8,344’ 6,931’ 6,943’ 7’ 5/20/1985 Closed B6 8,452’ 8,457’ 7,024’ 7,028’ 5’ 5/20/1985 Closed 8,481’ 8,487’ 7,046’ 7,050’ 6’ 5/20/1985 Closed 8,452’ 8,487’ 7,024’ 7,050’ 5’ 8/9/1995 Closed A3 8,576’ 8,596’ 7,116’ 7,131’ 34’ 8/9/1995 Closed A3 8,576’ 8,610’ 7,116’ 7,142’ 40’ 5/20/1985 Closed A2 8,610’ 8,650’ 7,142’ 7,171’ 40’ 8/9/1995 Closed A2 8,610’ 8,650’ 7,142’ 7,171’ 40’ Reperf Closed PERFS ORIGINALLY SHOT AT 12 SPF. REPERFED AT 6 SPF 8/94 WELL INCLINATION DETAIL KOP @ 1,400’ Max Hole Angle = 46 deg. @ 6,400’ TREE & WELLHEAD Tree FMC Gen 5 11”x4-1/2” TCII Wellhead 11” X11” 5M Adapter 2-7/8” T&B threads 2.5” CIW H Profile GENERAL WELL INFO API: 50-029-21344-00-00 Drilled, Cased and Completed by Alaska United #3 - 5/21/1985 Pull GLM and Install ESP – 5/23/1990 Pull ESP and Install GLM by EWS Rig #4– 6/6/1990 Pull GLM and Install ESP by EWS #1 – 7/9/1990 Remove and Replace ESP – 8/22/1994 Remove and Replace ESP & Upper Screen – 10/27/1994 Remove ESP and Screens. Replace ESP w/ Nabors 4ES – 5/23/1995 ESP Change-out & Wellbore Clean-out w/ Nabors 4ES – 7/9/1996 Remove and Replace ESP Instal Prod Screens w/ Nabors 5S – 5/5/1998 ESP Change-out w/ Nabors 4ES – 1/20/2000, 10/15/2000 & 8/28/2006 ESP Change-out w/ Doyon 16 – 4/12/2013 ESP Change-out w/ ASR 1 – 12/16/2015 & 11/27/2019 Coil Tubing, Tubing Clean-out to Top of ESP - ESP Pull and swap to 4-1/2” Tubing ASR – 2/10/2024 OPEN HOLE / CEMENT DETAIL 9-5/8”1,375sx Permafrost E/ 250sx Class G in a 12-1/2” Hole 7” 273 sx Class G in a 8-1/2” Hole STIMULATION SUMMARY Frac 8/9/94 88.1 M#, 8,327’ – 8,344’ ACTIVITYDATE SUMMARY 2/23/2024 ***CONTINUE WSR FROM 2-2-24.*** RAN READ 40 ARM (extended fingers) CALIPER AS PER PROGRAM (Good data). *** WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED.*** 3/4/2024 *** WEL SI ON ARRIVAL *** PT TO 250 LP AND 2500 PSI HP. RIH WITH ORIENTATION TOOL AND 4.5 X 7" WHIPSTOCK. TOP OF WHIPSTOCK SET AT: 8239 FT ORIENTATION: 4.3 DEG ROHS. STUCK AFTER SETTING WHIPSTOCK. PILLED OUT OF WEAK POINT TO GET FREE. ***E line TS Left in hole 26.55 W/ WHIP STOCK SETTING ADAPTER', RS FISHING NECK -1-3/8 :*** WELL LEFT SI ON DEPARTURE. TO FINISH RIG DOWN IN MORNING. 3/5/2024 *** WELL SHUT-IN ON ARRIVAL.*** RECOVER E-LINE TOOLS FROM 8,232' SLM. *** WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED.*** 3/20/2024 ***WELL S/I ON ARRIVAL*** VERIFY TIGHT SPOT ON WHIPSTOCK @ 8244' MD, TAG TBG END @ 8128' MD (see log) FISH 3.72" CENT FROM 8244' MD ***CONTINUE WSR ON 3-21-2024*** 3/21/2024 ***CONTINUED FROM 3-20-2024 WSR*** FISH 3.71" CENT FROM 8244' MD ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU MPC-14 TOP OF WHIPSTOCK SET AT: 8239 FT ORIENTATION: 4.3 DEG ROHS. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT C-14 JBR 06/12/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Test Results TEST DATA Rig Rep:Coyne/CoyneOperator:Hilcorp Alaska, LLC Operator Rep:Kavanaugh/Moore Rig Owner/Rig No.:Nabors CDR2AC PTD#:1850880 DATE:4/24/2024 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopSAM240427191322 Inspector Austin McLeod Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4.5 MASP: 2430 Sundry No: 324-081 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 0 NA FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2-3/8"P Annular Preventer 1 7-1/16"P #1 Rams 1 B/S P #2 Rams 1 2-3/8" P/S P #3 Rams 1 3" P/S P #4 Rams 1 2-3/8" P/S P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2-1/16"P HCR Valves 2 2-1/16"P Kill Line Valves 2 2-1/16"P Check Valve 0 NA BOP Misc 2 2"P System Pressure P2975 Pressure After Closure P2225 200 PSI Attained P19 Full Pressure Attained P58 Blind Switch Covers:PAll stations Bottle precharge P Nitgn Btls# &psi (avg)P10@2010 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 1 P Annular Preventer P4 #1 Rams P4 #2 Rams P3 #3 Rams P3 #4 Rams P3 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1      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: 3/20/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240320 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 19RD 50133205790100 219188 2/2/2024 AK E-LINE Perf CLU 14 50133206840000 219078 12/11/2023 AK E-LINE Perf IRU 41-01 50283200880000 192109 11/15/2023 AK E-LINE PERF KBU 22-06Y 50133206500000 215044 12/29/2023 AK E-LINE PERF MPU C-14 50029213440000 185088 3/4/2024 AK E-LINE Whipstock MPU L-62 50029236850000 220059 3/3/2024 AK E-LINE TubingPunch NCIU A-17 50883201880000 223031 12/13/2024 AK E-LINE GPT /Plug /Perf Paxton 6 50133207070000 222054 2/27/2024 AK E-LINE Plug/Perf PBU BORE V-109 50029231200000 202202 2/13/2024 AK E-LINE TubingPunch Please include current contact information if different from above. T38657 T38658 T38659 T38660 T38661 T38662 T38663 T38664 T38665 MPU C-14 50029213440000 185088 3/4/2024 AK E-LINE Whipstock Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.21 13:14:02 -08'00' 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: CTD Prep 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 8,833 feet N/A feet true vertical 7,306 feet N/A feet Effective Depth measured 8,742 feet feet true vertical 7,239 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2”12.6 / L-80 / JBEAR 8,106' 6,764' Tubing (size, grade, measured and true vertical depth)4-1/2”12.6 / L-80 / BTC 8,507' 7,065' 7” x 4.5” D&L Perm Hyd Iso Packer 7” 23# - 29# Versatrieve Packers and SSSV (type, measured and true vertical depth)7” 23# - 32# BWD Sump N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: Wells Manager Contact Phone: 7,951, 8,247 & 8,742 6,648, 6,891 & 7,239 323-672 Sr Pet Eng: 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. N/A Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 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 115' 360 Size 115' 4,533' 03500 0 1740 0 measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-088 50-029-21344-00-00 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: ADL0047434 / ADL0047437 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT C-14 Plugs Junk measured LengthCasing Conductor 8,822' 5,100'Surface Production 13-3/8" 9-5/8" 7" 115' 5,100'3,520psi 7,240psi8,822' 7,297' Burst N/A Collapse N/A 2,020psi 5,410psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Coldiron at 1:37 pm, Mar 08, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.03.08 13:07:23 - 09'00' Taylor Wellman (2143) DSR-3/11/24 RBDMS JSB 031424 WCB 2024-07-09 _____________________________________________________________________________________ Revised By: TDF 3/8/2024 SCHEMATIC Milne Point Unit Well: MPU C-14 Last Completed: 2/10/2024 PTD: 185-088 TD =8,833 (MD) / TD = 7,306’(TVD) 13-3/8” Last Tag @ 8,720’ w/ Pipe on 7/7/97 Orig. KB Elev.: 52’/ GL Elev.: 12’ 7” 1 2 3 1 6 5 Est. TOC @ ±7,650’ 9-5/8” PBTD =8,742’ (MD) / PBTD = 7,239’(TVD) Upper ECP @ 8,519’ Lower ECP @ 8,539’ 7 8 4 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / N/A 12.715 Surface 115' 0.157 9-5/8" Surface 36 / K-55 / BTC 8.921 Surface 5,100’ 0.077 7" Production 29 / L-80 / BTC 6.276 Surface 8,822’ 0.0372 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / JBEAR 3.958 Surface 8,106’ 0.0087 4-1/2” Tubing 12.6 / L-80 / BTC 3.958 8,274’ 8,507’ 0.01521 JEWELRY DETAIL No Depth Item 1 7,891’ 4.5” x 3.813”Sliding Sleeve 2 7,951’ 7” x 4.5” D&L Perm Hyd Iso Packer 3 8,015’ X Nipple 3.813” 4 8,066’ 4.5” WLEG –Bottom @ 8,106’ 5 8,274’ 7” 23# - 29# Versatrieve Packer 6 8,322’ 4-1/2” 12.75# N-80 LLP .20 Ga. Screen – Bottom @ 8,346’ 7 8,431’ 4-1/2” 12.75# N-80 LLP .20 Ga. Screen – Bottom @ 8,461’ 8 8,503’ 7” 23# - 32# BWD Sump Packer –Bottom @ 8,507’ PERFORATION DETAIL, REF LOG: 5/17/85 DIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1 8,327’ 8,344’ 6,931’ 6,943’ 7’ 8/9/1995 Open 8,327’ 8,344’ 6,931’ 6,943’ 7’ 5/20/1985 Open B6 8,452’ 8,457’ 7,024’ 7,028’ 5’ 5/20/1985 Open 8,481’ 8,487’ 7,046’ 7,050’ 6’ 5/20/1985 Open 8,452’ 8,487’ 7,024’ 7,050’ 5’ 8/9/1995 Open A3 8,576’ 8,596’ 7,116’ 7,131’ 34’ 8/9/1995 Open A3 8,576’ 8,610’ 7,116’ 7,142’ 40’ 5/20/1985 Open A2 8,610’ 8,650’ 7,142’ 7,171’ 40’ 8/9/1995 Open A2 8,610’ 8,650’ 7,142’ 7,171’ 40’ Reperf Open PERFS ORIGINALLY SHOT AT 12 SPF. REPERFED AT 6 SPF 8/94 WELL INCLINATION DETAIL KOP @ 1,400’ Max Hole Angle = 46 deg. @ 6,400’ TREE & WELLHEAD Tree FMC Gen 5 11”x4-1/2” TCII Wellhead 11” X11” 5M Adapter 2-7/8” T&B threads 2.5” CIW H Profile GENERAL WELL INFO API: 50-029-21344-00-00 Drilled, Cased and Completed by Alaska United #3 - 5/21/1985 Pull GLM and Install ESP – 5/23/1990 Pull ESP and Install GLM by EWS Rig #4– 6/6/1990 Pull GLM and Install ESP by EWS #1 – 7/9/1990 Remove and Replace ESP – 8/22/1994 Remove and Replace ESP & Upper Screen – 10/27/1994 Remove ESP and Screens. Replace ESP w/ Nabors 4ES – 5/23/1995 ESP Change-out & Wellbore Clean-out w/ Nabors 4ES – 7/9/1996 Remove and Replace ESP Instal Prod Screens w/ Nabors 5S – 5/5/1998 ESP Change-out w/ Nabors 4ES – 1/20/2000, 10/15/2000 & 8/28/2006 ESP Change-out w/ Doyon 16 – 4/12/2013 ESP Change-out w/ ASR 1 – 12/16/2015 & 11/27/2019 Coil Tubing, Tubing Clean-out to Top of ESP - ESP Pull and swap to 4-1/2” Tubing ASR – 2/10/2024 OPEN HOLE / CEMENT DETAIL 9-5/8”1,375sx Permafrost E/ 250sx Class G in a 12-1/2” Hole 7” 273 sx Class G in a 8-1/2” Hole STIMULATION SUMMARY Frac 8/9/94 88.1 M#, 8,327’ – 8,344’ Well Name Rig API Number Well Permit Number Start Date End Date MP C-14 ASR #1 50-029-21344-00-00 185-088 2/5/2024 2/13/2024 POOH from 577'' with 7'' Scraper & Test packer assembly. Pumping double displacement. P/U wt = 9K. L/D test PKR / scraper BHA. Clean & clear rig floor. Back out lock down screws & Pull Wear Bushing. Strap & tally 4-1/2" completion. Make up 4 1/2'' WLEG, X-Nipple assembly, 7'' Tripoint Packer and Sliding sleeve assembly. 17 bbls to fill well. Trip in hole with 4 1/2'' 12.6# L-80 JFE BEAR tubing to 8,085'. Pump double displacement. Up WT - 65K. 2/10/2024 - Saturday 2/11/2024 - Sunday Trip in hole with 4 1/2'' 12.6# L-80 JFE BEAR tubing T/ 8,085'. Install tbg hanger and land tbg with WLEG at 8107'. Final P/U wt = 89K S/O wt = 65K. Pump 100 BBLS of 8.8 ppg brine with 1% corrosion inhibitor, followed by 55 bbls diesel freeze protect. Drop ball & rod, allow to seat. Pressure down TBG to 4000 PSI to set 7'' x 4-1/2¿ perm packer and perform a tbg test - 30 minutes - charted. Bleed tbg to 1000 PSI - lock in pressure. Pressure down IA to 3650 PSI for 30 minutes - charted. All tests successful. Bleed all pressures, Install BPV. Prep rig to move. Suck out and clean pits, with 150 BBLS of hot water. Blow down all lines. Prep pipe sheds to move, disconnect all fire & gas and all interconnects. Move pipe sheds to end of location. Continue Rig down rig floor equipment, and swivel. Continue cleaning pits, rig down bales and tong rack. RD pipe skate and move. Rig down tong and slip hoses. Pull rack pins. Pull man basket and prep to pull swivel. Prep pit system for Confined Space entry permit with Hilcorp Safety rep. Rig released at 1800 HRS. 2/9/2024 - Friday Cont M/U 7" test PKR/ scraper BHA consisting of junk mill, 2 x boot baskets, 7" CSG scraper, XO pup XO, AS1X tet PKR, XO pup XO, BS, oil jar, & 4 x 4-1/4" DC. RIH W/ BHA on 3-1/2" workstring F/ 176' to 8000' Pump double displacement for pipe tripped in. Work 7'' casing scraper from 8000' - 8200' Set packer with center of element at 8150'. Continue to circulate & fill lines and stack. Shut in super choke for pressure test. Pressure test down the IA to 3,650 PSI - for 30 minutes on a chart. Successful test. Bleed all pressure. Open rams, and release the ASX-1 test packer. UP WT - 78K Down Weight 52K Allow packer to relax. POOH from 8150' with 7'' Scraper & Test packer assembly T/ 577'. Pumping double displacement. P/U wt = 9K 2/7/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary MIRU on C-14. Rig Accepted at 0700 HRS. Perform BOP test as per approve sundry. T/ 250 psi low & 2500 high f/ 5/5 charted mins. AOGCC waived witness to test. With wellhead rep. pull CTS & BPV. Fill tubing, 4 bbls of 8.8+ to fill. Fill IA 8 bbls of 8.8+ to fill. BOLDS. Pull hanger to rig floor. Off seat at 62K, clean P/U wt = 60 K. POOH w/ ESP completion laying down 2-7/8" 6.5# L- 80 EUE F/ 8,014' T/ 7,801' Pump double displacement. 2/8/2024 - Thursday POOH w/ ESP completion laying down 2-7/8" 6.5# L-80 EUE F/ 7,801' T/ 68' Pump double displacement. Discharge head packed off with sand. L/D ESP assembly consisting of pup, ported discharge, 2 x pumps, gas sep., tandem seals, Motor & zenith gauge with centralizer. Both pump seized up due to sand. Clean & clear rig floor. Clear pipe shed of ESP. M/U wear bushing tool. Install wear bushing. L/D tool. Change over handling equipment to 3-1/2". Remove ESP sheave from derrick. Begin P/U & M/U 7" test PKR/ scraper BHA. Drop ball & rod, allow to seat. Pressure down TBG to 4000 PSI to set 7'' x 4-1/2¿ perm packer and perform a tbg test - 30 minutes - charted. Bleed tbg to 1000 PSI - lock in pressure. Pressure down IA to 3650 PSI for 30 minutes - charted. All tests successful. Bleed all pressures, Install BPV. Trip in hole with 4 1/2'' 12.6# L-80 JFE BEAR tubing T/ 8,085'. Install tbg hanger and land tbg with WLEG at 8107'. 2500 high Back out lock down screws & Pull Wear Bushing. Strap & tally 4-1/2" completion. Make up 4 1/2'' WLEG, X-Nipple assembly, 7'' Tripoint Packer and Sliding sleeve assembly. AOGCC waived witness to test. L/D ESP assembly consisting of pup, ported discharge, 2 x pumps, gas sep., tandem seals, Motor & zenith gauge with centralizer. Both pump seized up due to sand. Perform BOP test as per approve sundry POOH w/ ESP completion laying down 2-7/8" 6.5# L-80 EUE F/ 7,801' Well Name Rig API Number Well Permit Number Start Date End Date MP C-14 ASR #1 50-029-21344-00-00 185-088 2/5/2024 2/13/2024 Hilcorp Alaska, LLC Weekly Operations Summary BEGIN R/U .125 CARBON, 1-7/8'' RS, QC, 8' X 1-7/8'' RS (2.60'' wheels), QC, KJ, 5' X 1-7/8'' RS (2.60'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. RIH w/ QC, 4-1/2 GR (steel), LATCH & PULL RHC @ 8045' SLM 8015' MD, POOH. SIBO, OOH w/ TOOLS. RIH W/ QC, 4-1/2 GR (steel), 20' X 4-1/2 DUMMY WHIPSTOCK DRIFT, NO RESTRICTONS DOWN TO 8250' SLM, POOH. WELL S/I ON DEPARTURE. No operations to report. 2/13/2024 - Tuesday 2/12/2024 - Monday LATCH & PULL RHC RIH W/ QC, 4-1/2 GR (steel), 20' X 4-1/2 DUMMY WHIPSTOCK DRIFT, NO RESTRICTONS DOWN TO 8250' SLM, POOH. 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: 2/28/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240228 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# AN-37 50733203940000 187109 11/8/2023 HALLIBURTON RBT KBU 31-18 50133206490000 215024 2/22/2024 HALLIBURTON PressTemp KBU 42-6 50133205460000 204209 2/23/2024 HALLIBURTON PPROF KU 31-07X 50133204950000 200148 2/2/2024 HALLIBURTON PressTemp MPU C-13 50029213280000 185067 2/23/2024 READ CaliperSurvey MPU C-14 50029213440000 185088 2/23/2024 READ CaliperSurve MPU L-43 50029231900000 203224 2/14/2024 READ CaliperSurvey MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON COILFLAG TBU M-20 50733205870000 209093 1/1/2024 HALLIBURTON COILFLAG Please include current contact information if different from above. T38535 T38536 T38537 T38538 T38539 T38540 T38541 T38542 T38543 2/29/2024 MPU C-14 50029213440000 185088 2/23/2024 READ CaliperSurve Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 09:17:32 -09'00' 4-1/2" D&L Perm Hyd Iso Packer 4-1/2" Versatrieve Packer 4-1/2" BWD Sump Packer 7951 / 6648 8274 / 6891 8503 / 7062 Drilling Manager 02/14/24 Monty M Myers By Kayla Junke at 3:34 pm, Feb 14, 2024 324-081 DSR-2/15/24SFD 2/15/2024 04-MAR-2024To eline set whipstock * BOPE test to 3500 psi. * Variance to 20 AAC 25.112(i) approved for alternate plug placement with fully cemented liner on upcoming sidetrack. Mel Rixse MGR04MAR24 10-407 *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.03.11 17:41:53 -08'00'03/11/24 RBDMS JSB 031324 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: February 14, 2024 Re:MPU C-14 Sundry Request Sundry approval is requested to set a whipstock and mill the window in MPU C-14, as part of the pre-rig and drilling/completing of the proposed MPU C-14A CTD lateral. Proposed plan for MPU C-14A Injector: A rig workover will be conducted to swap out the ESP completion with a 4-1/2" completion. Prior to drilling activities, screening will be conducted to MIT, caliper and drift for whipstock. E-line will then set a 4-1/2"x7" flow through whipstock (if not possible, will set with rig). See C-14A PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. If unable to set pre-rig, the rig will set a 4- 1/2"x7" flow through whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling in the Kuparuk D shale and land in the Kuparuk A sand. A 3-1/2"x3-1/4" protection string will be run. The rig will downsize from 2-3/8" to 2" coil, followed by milling out of the 3-1/4" shoe. The slimhole lateral will then continue drilling in the Kuparuk sands to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” L-80 solid liner and cemented. This completion WILL abandon the parent Kuparuk perfs. The well will be perforated post rig. This Sundry covers plugging the existing Kuparuk perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). Pre-Rig Work - (Estimated to start February 2024): 1. RWO: install 4-1/2” tubing (see separate RWO Sundry) and MIT to 2,500 psi minimum 2. Slickline: Post RWO work, Dummy WS drift and Caliper a. Drift and Caliper past whipstock setting location 3. E-line: Set 4-1/2”x7” whipstock a. Top of whipstock at 8,239’ MD (top of window at 8,244’ MD = pinch point) b. Oriented 0° ROHS (high side) 4. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: x Reference MPU C-14A PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,430 psi a. Give AOGCC 24hr notice prior to BOPE test 2. Mill Window 3. Drill Protection String Section 4. Run Protection String 5. Coil swap from 2-3/8” to 2” and mill out of protection string shoe 6. Drill Production Lateral 7. Run and Cement Liner* 8. Perforate (only if not done post-rig) 9. Freeze Protect and RDMO 10. Set LTP* (if needed) and perforate post rig * Approved alternate plug placement per 20 AAC 25.112(i) Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 pp p This completion WILL abandon the parent Kuparuk perfs. gg flow through whipstock PTD 224-015 Sundry 324-081 _____________________________________________________________________________________ Revised By: JNL 2/13/2024 PROPOSED Milne Point Unit Well: MPU C-14 Last Completed: 2/10/2024 PTD: 185-088 TD =8,833 (MD) / TD = 7,306’(TVD) 13-3/8” Last Tag @ 8,720’ w/ Pipe on 7/7/97 Orig. KB Elev.: 52’/ GL Elev.: 17’ 7” 1 2 3 1 6 5 Est. TOC @ ±7,650’ 9-5/8” Whipstock set @8239’ PBTD =8,742’ (MD) / PBTD = 7,239’(TVD) Upper ECP @ 8,519’ Lower ECP @ 8,539’ 7 8 4 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / N/A 12.715 Surface 115' 0.157 9-5/8" Surface 36 / K-55 / BTC 8.921 Surface 5,100’ 0.077 7" Production 29 / L-80 / BTC 6.276 Surface 8,822’ 0.0372 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TXP 3.958 Surface 8,106’ 0.0087 4-1/2” Tubing 12.6 / L-80 / BTC 3.958 8,274’ 8,507’ 0.01521 JEWELRY DETAIL No Depth Item 1 7,891’ 4.5” x 3.813” Sliding Sleeve 2 7,951’ 7” x 4.5” D&L Perm Hyd Iso Packer 3 8,015’ X Nipple 3.813” 4 8,066’ 4.5” WLEG – Bottom @ 8,106’ 5 8,274’ 7” 23# - 29# Versatrieve Packer 6 8,322’ 4-1/2” 12.75# N-80 LLP .20 Ga. Screen – Bottom @ 8,346’ 7 8,431’ 4-1/2” 12.75# N-80 LLP .20 Ga. Screen – Bottom @ 8,461’ 8 8,503’ 7” 23# - 32# BWD Sump Packer –Bottom @ 8,507’ PERFORATION DETAIL, REF LOG: 5/17/85 DIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1 8,327’ 8,344’ 6,931’ 6,943’ 7’ 8/9/1995 Open 8,327’ 8,344’ 6,931’ 6,943’ 7’ 5/20/1985 Open B6 8,452’ 8,457’ 7,024’ 7,028’ 5’ 5/20/1985 Open 8,481’ 8,487’ 7,046’ 7,050’ 6’ 5/20/1985 Open 8,452’ 8,487’ 7,024’ 7,050’ 5’ 8/9/1995 Open A3 8,576’ 8,596’ 7,116’ 7,131’ 34’ 8/9/1995 Open A3 8,576’ 8,610’ 7,116’ 7,142’ 40’ 5/20/1985 Open A2 8,610’ 8,650’ 7,142’ 7,171’ 40’ 8/9/1995 Open A2 8,610’ 8,650’ 7,142’ 7,171’ 40’ Reperf Open PERFS ORIGINALLY SHOT AT 12 SPF. REPERFED AT 6 SPF 8/94 WELL INCLINATION DETAIL KOP @ 1,400’ Max Hole Angle = 46 deg. @ 6,400’ TREE & WELLHEAD Tree FMC Gen 5 11”x4-1/2” TCII Wellhead 11” X11” 5M Adapter 2-7/8” T&B threads 2.5” CIW H Profile GENERAL WELL INFO API: 50-029-21344-00-00 Drilled, Cased and Completed by Alaska United #3 - 5/21/1985 Pull GLM and Install ESP – 5/23/1990 Pull ESP and Install GLM by EWS Rig #4– 6/6/1990 Pull GLM and Install ESP by EWS #1 – 7/9/1990 Remove and Replace ESP – 8/22/1994 Remove and Replace ESP & Upper Screen – 10/27/1994 Remove ESP and Screens. Replace ESP w/ Nabors 4ES – 5/23/1995 ESP Change-out & Wellbore Clean-out w/ Nabors 4ES – 7/9/1996 Remove and Replace ESP Instal Prod Screens w/ Nabors 5S – 5/5/1998 ESP Change-out w/ Nabors 4ES – 1/20/2000, 10/15/2000 & 8/28/2006 ESP Change-out w/ Doyon 16 – 4/12/2013 ESP Change-out w/ ASR 1 – 12/16/2015 & 11/27/2019 Coil Tubing, Tubing Clean-out to Top of ESP - ESP Pull and swap to 4-1/2” Tubing ASR – 2/10/2024 OPEN HOLE / CEMENT DETAIL 9-5/8”1,375sx Permafrost E/ 250sx Class G in a 12-1/2” Hole 7” 273 sx Class G in a 8-1/2” Hole STIMULATION SUMMARY Frac 8/9/94 88.1 M#, 8,327’ – 8,344’ _____________________________________________________________________________________ Revised By: JNL 2/13/2024 PROPOSED Milne Point Unit Well: MPU C-14A Last Completed: TBD PTD: TBD TD = 11,731’ (MD) / TD = 7,161’ (TVD) 13-3/8” Orig. KB Elev.: 52’/ GL Elev.: 17’ 7” 2 3 Est. TOC @ ±7,650’ 9-5/8” PBTD = 11,700’ (MD) / PBTD = 7,161’ (TVD) 2-3/8” 4 1 3.70” DPY SLV @ 8000’ Whipstock set @ 8239’ Top of Window @ 8244’; 3-1/2 xo 3-1/4” @ 8220’ 3-1/2” (Protection String) @ 8040’ 3-1/4” (Protection String) @ 8848’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / N/A 12.715 Surface 115' 0.157 9-5/8" Surface 36 / K-55 / BTC 8.921 Surface 5,100’ 0.077 7" Production 29 / L-80 / BTC 6.276 Surface 8,822’ 0.0372 3-1/2”x3-1/4”Protection String 9.3 / L-80 / STL 6.6 / L-80 / TCII 8,040’ 8,488’ 2-3/8” Liner 4.6 / L-80 / H511 8,000’ 11,731’ TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / BTC 3.958 Surface 8,106’ 0.0087 JEWELRY DETAIL No Depth Item 1 7,891’ 4-1/2” x 3.813” Sliding Sleeve 2 7,951’ 7” x 4-1/2” D&L Perm Hyd Iso Packer 3 8,015’ X Nipple 3.813” 4 8,066’ 4-1/2” WLEG – Bottom @ 8,106’ PERFORATION DETAIL, REF LOG: 5/17/85 DIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status WELL INCLINATION DETAIL KOP @ 1,400’ / A @ 8244’ 90 Deg Hole Angle = 10,950’ TREE & WELLHEAD Tree FMC Gen 5 11”x4-1/2” TCII Wellhead 11” X11” 5M Adapter 2-7/8” T&B threads 2.5” CIW H Profile GENERAL WELL INFO API: 50-029-21344-01-00 Drilled, Cased and Completed by Alaska United #3 - 5/21/1985 ESP Pull and swap to 4-1/2” Tubing ASR – 2/10/2024 A Sidetrack: TBD OPEN HOLE / CEMENT DETAIL 12-1/4” 1,375sx Permafrost E / 250 sx Class G 8-1/2” 273 sx Class G 4-1/4”x3-1/4” 104 sx Class G Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 1 Davies, Stephen F (OGC) From:Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Sent:Thursday, February 15, 2024 1:44 PM To:Davies, Stephen F (OGC) Cc:Rixse, Melvin G (OGC); Roby, David S (OGC); Dewhurst, Andrew D (OGC); Joseph Lastufka Subject:RE: [EXTERNAL] FW: MPU C-14 (Permit 185-088, Sundry 324-081) - Question Steve, YesthatwillbeŇowthroughwhipstock,buttheCTDlinerisgoingtobecementedtotopofliner.Sothatcementjob and/orlinertoppackerwillshutoīparentperforaƟons. TrevorHyatt HilcorpAlaska,LLC DrillingEngineer 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. 2 Trevor.Hyatt@hilcorp.com Cell:907Ͳ223Ͳ3087 From:Davies,StephenF(OGC)<steve.davies@alaska.gov> Sent:Thursday,February15,202412:43PM To:TrevorHyatt<Trevor.Hyatt@hilcorp.com> Cc:Rixse,MelvinG(OGC)<melvin.rixse@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov>;Dewhurst,Andrew D(OGC)<andrew.dewhurst@alaska.gov> Subject:[EXTERNAL]FW:MPUCͲ14(Permit185Ͳ088,Sundry324Ͳ081)ͲQuestion Trevor, I’dliketoconĮrmthattheplannedŇŽǁͲƚŚƌŽƵŐŚwhipstocktobesetat8,239’MDwillindeedabandontheperforaƟons intheexisƟngwellboreasstatedinthecoverleƩerforHilcorp’sapplicaƟon.Ifthisisnotcorrect,andthoseexisƟng KuparukperforaƟonwillconƟnuetocontributetoproducƟonfromthewell,thismeansthattheplannedwellbore exiƟngthemilledwindowwouldbemoreproperlytermedCͲ14L1ratherthanCͲ14A,andthatallproducƟonfromthat lateralwouldbereportedagainsttheCͲ14well.Pleaseclarifythisforme. ThanksandBeWell, SteveDavies AOGCC CAUTION:Externalsender.DONOTopenlinksorattachmentsfromUNKNOWNsenders. 3 CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyaƩachments,containsinformaƟonfromtheAlaskaOilandGasConservaƟonCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).ItmaycontainconĮdenƟaland/orprivilegedinformaƟon.Theunauthorizedreview,use ordisclosureofsuchinformaƟonmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutĮrstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the “Abandon” box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer SFD 2/15/2024 185-088 MPU C-14 SFD 2/15/2024 324-081 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:Russell Gallen - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Alaska NS - ASR - Well Site Managers Subject:MPU C-14 BOPE test report Date:Thursday, February 8, 2024 4:46:31 AM Attachments:MPU C-14 BOPE test report (initial ).xlsx Some people who received this message don't often get email from russell.gallen@hilcorp.com. Learn why this is important Thanks. Regards, Russell Gallen ASR DSM, Mobile: 907-529-7202 Office: 907-685-1266 russell.gallen@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 0LOQH3RLQW8QLW& 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 2/7/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #11850880 Sundry #323-672 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:2210 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2 7/8" x 5"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result HCR Valves 1 2 1/16"P System Pressure (psi)3000 P Kill Line Valves 3 2 1/16"P Pressure After Closure (psi)1900 P Check Valve 0NA200 psi Attained (sec)14 P BOP Misc 0NAFull Pressure Attained (sec)53 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 / 2,200 PSI P No. Valves 16 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 13 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:8 HR HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2/05/24 11:45 Waived By Test Start Date/Time:2/7/2024 7:00 (date) (time)Witness Test Finish Date/Time:2/7/2024 15:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Hilcorp Tested w/ 2-7/8" & 4-1/2" test joints. Bottle average pre-charge = 1,035 PSI. C. Grueb / M. Boord Hilcorp Alaska LLC S. Heim / R. Gallen MPU C-14 Test Pressure (psi): skans-asr-toolpushers@hilcorp.c ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2024-0207_BOP_Hilcorp_ASR1_MPU_C-14 9 9 9 9 999 9 9 9 9 9 -5HJJ 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Convert to Injector Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: CTD Prep 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: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,833 N/A Casing Collapse Conductor 740psi Surface 2,020psi Production 5,410psi 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: Wells Manager 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 MILNE PT UNIT C-14 2-7/8" 6.5 / L-80 / 8rd EUE 8,050' 7" Versatriev & 7" BWD Sump and N/A 8,274 MD/ 6,891TVD & 8,503 MD/ 7,062 TVD and N/A 115' 13-3/8" 9-5/8" 7" Todd Sidoti todd.sidoti@hilcorp.com 777-8443 Perforation Depth MD (ft): See Schematic See Schematic 4-1/2" 5,100' 8,822' MD 1,730psi 3,520psi 7,240psi 4,533' 7,297' 5,100' 8,822' Length Size Proposed Pools: 115' 115' 12.6 / L-80 / BTC TVD Burst 8,507' KUPARUK RIVER OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047434 / ADL0047437 185-088 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21344-00-00 Hilcorp Alaska LLC C.O. 432E AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 12/30/2023 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: PRESENT WELL CONDITION SUMMARY MILNE POINT N/A 7,306 8,742 7,239 2,210 N/A 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 1:59 pm, Dec 15, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.12.15 12:59:34 - 09'00' Taylor Wellman (2143) 323-672 * BOPE test to 2500 psi. SFD MGR30JAN24 CTD Prep 10-404 DSR-12/18/23SFD 12/19/2023*&:JLC 1/31/2024 1/31/24Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.01.31 15:20:57 -09'00' RBDMS JSB 020124 RWO Well: MPU C-14 Date: 7 DEC 2023 Well Name:MPC-14 API Number:50-029-21344-00-00 Current Status:SI ESP Producer Rig:ASR 1 Estimated Start Date:December 30, 2023 Estimated Duration:5 days Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:185-088 First Call Engineer:Todd Sidoti (907) 777-8420 (O) (907) 632-4113 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 2910 psi @ 7000’ TVD BHP Measured 12/28/2020 |8.0 PPGE MPSP:2210 psi Gas Column Gradient (0.1 psi/ft) Max Inclination: 46° @ 6400’ MD Brief Well Summary: MPU C-14 was drilled in 1985 completed in the Kuparuk sands. The well was originally completed as a gas lift well and converted to ESP in 1990. The well has had multiple ESPs changed out since 1990. Screens were installed in 1998. The last ESP change was done with ASR#1 in October 2020. The pump has failed and the well is in a good location to provide injection support via CTD sidetrack to the block NE of C-14’s surface location. Notes Regarding Wellbore Condition x 2013 caliper indicates that tubing is in good condition. x Lower station is live and upper station is dummied off. Objective: Pull ESP and prepare well for CTD sidetrack. Pre-Rig Work (No Sundry Required) Slickline, Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats, 500 bbl tank and containment. 2. RD well house and flowlines. 3. MIRU pumpers and PT lines to 250 psi low / 3500 psi high. 4. Circulate at least one wellbore volume of water down tubing taking returns up casing to tank. 5. Confirm well is dead and FP if necessary. 6. RU crane. Set BPV. ND tree and NU BOPE. RD Crane. 7. NU BOPE house. Spot mud boat. Approved Sundry Required for Work Below RWO Pull Tubing 8. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 9. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well with source water prior to setting CTS. to provide injection support via CTD sidetrack to the block NE of C-14’s surface location. prepare well for CTD sidetrack. RWO Well: MPU C-14 Date: 7 DEC 2023 10. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 4-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 11. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with KWF as needed. Pull BPV. Lubricate if pressure is expected. 12. Rig up ESP cable spooler and sheave for #2 round cable. 13. MU landing joint or spear and PU on the tubing hanger. 14. Recover the tubing hanger. a. PU weight was not recorded and SO was 38k when last completed. 15. POOH and lay down the 4-1/2” tubing. Wash and all joints and send to GNI for inspection. 16. Recover the following: a. 138 cannon clamps b. 1 motor protectolizer c. 5 pump protectolizers Run Scraper and Test Packer 17. MU and RIH with 7” casing scraper / test packer BHA. 18. Scrape pipe from 8000’-8200’ 19. Set test packer at 8150’ and test casing to 3650 psi. 20. POOH laying down work string. Run CTD Completion 21. RIH with new 4-1/2” 12.6# L-80 completion to ~8100’. Item Notes 4-1/2” WLEG Place at ~8,100’ MD 1 Joint 4-1/2” 4-1/2” Pup 4-1/2” XN Nipple RHC Profile Installed 4-1/2” Pup 1 Joint 4-1/2” 4-1/2” Pup 7” x 4-1/2” Packer 4-1/2” Pup 1 Joint 4-1/2 4-1/2” Pup 4-1/2” Sliding Sleeve 4-1/2” Pup RWO Well: MPU C-14 Date: 7 DEC 2023 Joints 4-1/2” with GLMs Space out Pups 1 Joint 4-1/2” Tubing Hanger 22. Land tubing hanger. RILDS. Lay down landing joint. Note PU and SO weights on tally. 23. Pump 50 barrels of 1% KCL with 1% by volume corrosion inhibitor (CI) down the IA, taking returns up the tubing. a. This is to inhibit the casing from below the sliding sleeve to the top of the packer. 24. Displace CI with 55 barrels of diesel freeze protect down the annulus. 25. Consult OE/WSL on whether to FP tubing prior to RDMO. 26. Drop ball and rod and pump to seat in XN nipple below the packer. Set the packer per vendor setting procedure. 27. Perform MIT-T 3,000 psi, charted for 30 minutes. 28. Perform MIT-IA to 3,650 psi, charted for 30 minutes. 29. Set BPV. Post-Rig Procedure: Well Support 30. RD mud boat. RD BOPE house. Move to next well location. 31. RU crane. ND BOPE and NU tree. 32. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 33. RD crane. Move 500 bbl returns tank and rig mats to next well location. 34. Turn well over to production. RU well house and flowlines. Slickline 35. MIRU slickline and pressure test lubricator to 250 psi low / 2500 psi high. 36. Pull ball & rod. 37. Pull RHC profile. RDMO slickline. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. AOR Map Charted and recorded. - mgr _____________________________________________________________________________________ Revised By: TDF 11/12/2020 SCHEMATIC Milne Point Unit Well: MPU C-14 Last Completed: 11/27/19 PTD: 185-088 TD =8,833(MD) / TD = 7,306’(TVD) 13-3/8” Last Tag @ 8,720’ w/ Pipe on 7/7/97 Orig. KB Elev.: 52’/ GL Elev.: 12’ 7” 3 6 & 7 8 9&10 119 14 13 12 Est. TOC @ ±7,650’ 9-5/8” 1 2 PBTD =8,742’ (MD) / PBTD = 7,239’(TVD) 4 & 5 Upper ECP @ 8,519’ Lower ECP @ 8,539’ 15 16 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / N/A 12.715 Surface 115' 0.157 9-5/8" Surface 36 / K-55 / BTC 8.921 Surface 5,100’ 0.077 7" Production 29 / L-80 / BTC 6.276 Surface 8,822’ 0.0372 TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / 8rd EUE 2.441 Surface 8,050’ 0.00579 4-1/2” Tubing 12.6 / L-80 / BTC 3.958 8,274’ 8,507’ 0.01521 JEWELRY DETAIL No Depth Item 1 140’ Sta 2: Camco 2 7/8 X1'' Side pocket KBMM GLM (Dummy 11/1/20) 2 7,840’ Sta 1: Camco 2 7/8 X1'' Side pocket KBMM GLM (Open pocket 11/1/2020) 3 7,960’ 2-7/8” XN Nipple – ID= 2.205” 4 7,981’ Discharge Head: GPDIS 5 7,982’ Ported Discharge Head: 513/538 6 7,983’ Pump 1: PMSXD 20GINPSHH 7 8,000’ Pump 2: PMSXD 119P23 8 8,010’ Gas Separator: GRSFTX 9 8,015’ Upper Tandem Seal: GSB3DB H6 SB/AB PFSA 10 8,022’ Lower Tandem Seal: GSB3DB H6 SB/AB PFSA 11 8,029’ Motor: XP 250Hp/ 2,505V / 61A 12 8,046’ Motor Guage: ZenithW/ Centralizer – Bottom @ 8,050’ 13 8,274’ 7” 23# - 29# Versatrieve Packer 14 8,322’ 4-1/2” 12.75# N-80 LLP .20 Ga. Screen – Bottom @ 8,346’ 15 8,431’ 4-1/2” 12.75# N-80 LLP .20 Ga. Screen – Bottom @ 8,461’ 16 8,503’ 7” 23# - 32# BWD Sump Packer –Bottom @ 8,507’ PERFORATION DETAIL, REF LOG: 5/17/85 DIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1 8,327’ 8,344’ 6,931’ 6,943’ 7’ 8/9/1995 Open 8,327’ 8,344’ 6,931’ 6,943’ 7’ 5/20/1985 Open B6 8,452’ 8,457’ 7,024’ 7,028’ 5’ 5/20/1985 Open 8,481’ 8,487’ 7,046’ 7,050’ 6’ 5/20/1985 Open 8,452’ 8,487’ 7,024’ 7,050’ 5’ 8/9/1995 Open A3 8,576’ 8,596’ 7,116’ 7,131’ 34’ 8/9/1995 Open A3 8,576’ 8,610’ 7,116’ 7,142’ 40’ 5/20/1985 Open A2 8,610’ 8,650’ 7,142’ 7,171’ 40’ 8/9/1995 Open A2 8,610’ 8,650’ 7,142’ 7,171’ 40’ Reperf Open PERFS ORIGINALLY SHOT AT 12 SPF. REPERFED AT 6 SPF 8/94 WELL INCLINATION DETAIL KOP @ 1,400’ Max Hole Angle = 46 deg. @ 6,400’ TREE & WELLHEAD Tree 2-9/16” 5M CIW Wellhead 11” X11” 5M Adapter 2-7/8” T&B threads 2.5” CIW H Profile GENERAL WELL INFO API: 50-029-21344-00-00 Drilled, Cased and Completed by Alaska United #3 - 5/21/1985 Pull GLM and Install ESP – 5/23/1990 Pull ESP and Install GLM by EWS Rig #4– 6/6/1990 Pull GLM and Install ESP by EWS #1 – 7/9/1990 Remove and Replace ESP – 8/22/1994 Remove and Replace ESP & Upper Screen – 10/27/1994 Remove ESP and Screens. Replace ESP w/ Nabors 4ES – 5/23/1995 ESP Change-out & Wellbore Clean-out w/ Nabors 4ES – 7/9/1996 Remove and Replace ESP Instal Prod Screens w/ Nabors 5S – 5/5/1998 ESP Change-out w/ Nabors 4ES – 1/20/2000, 10/15/2000 & 8/28/2006 ESP Change-out w/ Doyon 16 – 4/12/2013 ESP Change-out w/ ASR 1 – 12/16/2015 & 11/27/2019 Coil Tubing, Tubing Clean-out to Top of ESP - OPEN HOLE / CEMENT DETAIL 9-5/8”1,375sx Permafrost E/ 250sx Class G in a 12-1/2” Hole 7” 273 sx Class G in a 8-1/2” Hole STIMULATION SUMMARY Frac 8/9/94 88.1 M#, 8,327’ – 8,344’ _____________________________________________________________________________________ Revised By: TDF 12/8/2023 PROPOSED Milne Point Unit Well: MPU C-14 Last Completed: 11/27/19 PTD: 185-088 TD =8,833 (MD) / TD = 7,306’(TVD) 13-3/8” Last Tag @ 8,720’ w/ Pipe on 7/7/97 Orig. KB Elev.: 52’/ GL Elev.: 12’ 7” 1 2 3 1 6 5 Est. TOC @ ±7,650’ 9-5/8” PBTD =8,742’ (MD) / PBTD = 7,239’(TVD) Upper ECP @ 8,519’ Lower ECP @ 8,539’ 7 8 4 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / N/A 12.715 Surface 115' 0.157 9-5/8" Surface 36 / K-55 / BTC 8.921 Surface 5,100’ 0.077 7" Production 29 / L-80 / BTC 6.276 Surface 8,822’ 0.0372 TUBING DETAIL 4-1/2” Tubing 12.6 / L-80 / TXP 3.958 Surface ±8,100’ 0.0087 4-1/2” Tubing 12.6 / L-80 / BTC 3.958 8,274’ 8,507’ 0.01521 JEWELRY DETAIL No Depth Item 1 ±X,XXX’ 4.5” Sliding Sleeve 2 ±X,XXX’ 7” x 4.5” Packer 3 ±X,XXX’ 4.5” X Nipple 4 ±X,XXX’ 4.5” WLEG – Bottom @ ±8,100’ 5 8,274’ 7” 23# - 29# Versatrieve Packer 6 8,322’ 4-1/2” 12.75# N-80 LLP .20 Ga. Screen – Bottom @ 8,346’ 7 8,431’ 4-1/2” 12.75# N-80 LLP .20 Ga. Screen – Bottom @ 8,461’ 8 8,503’ 7” 23# - 32# BWD Sump Packer –Bottom @ 8,507’ PERFORATION DETAIL, REF LOG: 5/17/85 DIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1 8,327’ 8,344’ 6,931’ 6,943’ 7’ 8/9/1995 Open 8,327’ 8,344’ 6,931’ 6,943’ 7’ 5/20/1985 Open B6 8,452’ 8,457’ 7,024’ 7,028’ 5’ 5/20/1985 Open 8,481’ 8,487’ 7,046’ 7,050’ 6’ 5/20/1985 Open 8,452’ 8,487’ 7,024’ 7,050’ 5’ 8/9/1995 Open A3 8,576’ 8,596’ 7,116’ 7,131’ 34’ 8/9/1995 Open A3 8,576’ 8,610’ 7,116’ 7,142’ 40’ 5/20/1985 Open A2 8,610’ 8,650’ 7,142’ 7,171’ 40’ 8/9/1995 Open A2 8,610’ 8,650’ 7,142’ 7,171’ 40’ Reperf Open PERFS ORIGINALLY SHOT AT 12 SPF. REPERFED AT 6 SPF 8/94 WELL INCLINATION DETAIL KOP @ 1,400’ Max Hole Angle = 46 deg. @ 6,400’ TREE & WELLHEAD Tree 2-9/16” 5M CIW Wellhead 11” X11” 5M Adapter 2-7/8” T&B threads 2.5” CIW H Profile GENERAL WELL INFO API: 50-029-21344-00-00 Drilled, Cased and Completed by Alaska United #3 - 5/21/1985 Pull GLM and Install ESP – 5/23/1990 Pull ESP and Install GLM by EWS Rig #4– 6/6/1990 Pull GLM and Install ESP by EWS #1 – 7/9/1990 Remove and Replace ESP – 8/22/1994 Remove and Replace ESP & Upper Screen – 10/27/1994 Remove ESP and Screens. Replace ESP w/ Nabors 4ES – 5/23/1995 ESP Change-out & Wellbore Clean-out w/ Nabors 4ES – 7/9/1996 Remove and Replace ESP Instal Prod Screens w/ Nabors 5S – 5/5/1998 ESP Change-out w/ Nabors 4ES – 1/20/2000, 10/15/2000 & 8/28/2006 ESP Change-out w/ Doyon 16 – 4/12/2013 ESP Change-out w/ ASR 1 – 12/16/2015 & 11/27/2019 Coil Tubing, Tubing Clean-out to Top of ESP - OPEN HOLE / CEMENT DETAIL 9-5/8”1,375sx Permafrost E/ 250sx Class G in a 12-1/2” Hole 7” 273 sx Class G in a 8-1/2” Hole STIMULATION SUMMARY Frac 8/9/94 88.1 M#, 8,327’ – 8,344’ Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Blind Ram 2-7/8" x 5" VBRs MP C-14 AOR MAP 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:AOGCC Permitting (CED sponsored) To:Brooks, James S (OGC) Subject:FW: MP C-14 10-403 Withdrawal Request for Sundry # 323-555, PTD 185-088 Date:Thursday, December 7, 2023 10:34:01 AM Hi James, FYI Thanks, Grace From: Tom Fouts <tfouts@hilcorp.com> Sent: Thursday, December 7, 2023 10:19 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Todd Sidoti <Todd.Sidoti@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com> Subject: MP C-14 10-403 Withdrawal Request for Sundry # 323-555, PTD 185-088 Hello, Hilcorp Alaska LLC requests the withdrawal of the 10-403 submittal for MP C-14, Sundry # 323-555. We will be submitting another 10-403 for this well to perform a CTD Prep. Regards, Tom Fouts | Senior Ops/ Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907) 777-8398 Mobile: (907) 351-5749 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. 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: Convert to WAG Injector 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: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 8,833 N/A Casing Collapse Conductor 740psi Surface 2,020psi Production 5,410psi 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: Wells Manager 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 MILNE PT UNIT C-14 2-7/8" 6.5 / L-80 / 8rd EUE 8,050' 7" Versatriev & 7" BWD Sump and N/A 8,274 MD/ 6,891TVD & 8,503 MD/ 7,062 TVD and N/A 115' 13-3/8" 9-5/8" 7" Todd Sidoti todd.sidoti@hilcorp.com 777-8443 Perforation Depth MD (ft): See Schematic See Schematic 4-1/2" 5,100' 8,822' MD 1,730psi 3,520psi 7,240psi 4,533' 7,297' 5,100' 8,822' Length Size Proposed Pools: 115' 115' 12.6 / L-80 / BTC TVD Burst 8,507' KUPARUK RIVER OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047434 / ADL0047437 185-088 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21344-00-00 Hilcorp Alaska LLC C.O. 432C AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/30/2023 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: PRESENT WELL CONDITION SUMMARY MILNE POINT N/A 7,306 8,742 7,239 2,210 N/A 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 1:17 pm, Oct 06, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.10.06 11:50:44 - 08'00' Taylor Wellman (2143) 10-404 WAG Service MGR18OCT23 DSR-10/9/23 * BOPE test to 2500 psi. * MIT-IA to 3500 psi. State to witness. * MIT-IA to 3500 psi within 10 days of stabilized injection. * Approved to pre-produce for 30 days before injection. SFD 10/12/2023 2,210 432E SFD Convert to WAG Injector JLC 10/19/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.19 11:43:22 -08'00'10/19/23 RBDMS JSB 102323 RWO Convert to WAG Well: MPU C-14 Date: 27 Sep 2023 Well Name: MPU C-14 API Number: 50-029-21344-00-00 Current Status: Producer [ESP Failed] Pad: C-Pad Estimated Start Date: October 30th, 2023 Rig: ASR 1 Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 185-088 First Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (M) Second Call Engineer: Scott Pessetto (907) 564-4373 (O) (801) 222-2203 (M) Current Bottom Hole Pressure: 2910 psi @ 7000’ TVD (SBHP measured 12/28/2020) 8.0 PPGE Max. Proposed Surf Pressure: 2210 psi (Using 0.1 psi/ft gas gradient) Max Inclination: 46° @ 6400’ MD Brief Well Summary: MPU C-14 was drilled in 1985 completed in the Kuparuk sands. The well was originally completed as a gas lift well and converted to ESP in 1990. The well has had multiple ESPs changed out since 1990. Screens were installed in 1998. The last ESP change was done with ASR#1 in October 2020. The pump has failed and the well is in a good position structurally to provide WAG injection support. Notes Regarding Wellbore Condition x Caliper ran in 2013 indicates that tubing is in good condition. Objective: Pull ESP completion, run new injection completion and convert well to injector. Hilcorp will pre-produce the injector for 30 days in order to gather productivity data for the block. Slickline Pumping & Well Support (No sundry required): 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. 5. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH or diesel. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 6. RD Little Red Services and reverse out skid. 7. RU crane. Set BPV. ND tree and NU BOPE. RD Crane. 8. NU BOPE house. Spot mud boat. Brief RWO Procedure (Sundry Required): 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl returns tank. convert well to injector. good position structurally to provide WAG injection support. RWO Convert to WAG Well: MPU C-14 Date: 27 Sep 2023 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well with ppg produced water prior to setting CTS. 3. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 3-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. 5. Call out vendor for ESP pull. 6. RU Spooler to pull #2 ESP cable. 7. MU landing joint or spear and PU on the tubing hanger. a. P/U weight was 60,000# and S/O was 38,000# during last RWO. 8. Recover the tubing hanger. 9. POOH and lay down the 2-7/8” tubing. Number all joints a. Keep all tubulars for inspection. b. Tubing caliper indicates that all joints are good. c. Keep XN nipple and GLMs for future use. d. Keep ported discharge head and centralizer for future use. e. Note any sand or scale inside or on the outside of the ESP on the morning report. f. Look for over-torqued connections from previous tubing runs. g. Recover the following amount of clamps/guards from the completion: i. 138 LaSalle Clamps ii. 5 pump protector clamps iii. 1 motor protector clamp 10. Lay Down ESP. 11. MIRU Eline unit. 12. MU and RIH with JB sized for packer drift and CCL. 13. Drift to Versatrieve packer at 8274’. 14. MU and RIH with CBL and log from 8250’ to 5000’. a. Ensure that free-pipe pass is logged. b. Calculated TOC behind 7” casing is 7650’. 15. POOH & RDMO eline. 16. PU 3-1/2” upper completion and RIH. Risk assess for gas below BPV. Lubricate if risk of gas release. - mgr RWO Convert to WAG Well: MPU C-14 Date: 27 Sep 2023 A 3-1/2” Muleshoe Pup Joint, 3-1/2" B Pup Joint, 3-1/2” 3-1/2” XN Nipple with RHC Plug Installed Pup Joint, 3-1/2” C Pup Joint, 3-1/2" 7” x 3-1/2” Packer @ ~8,220’ Pup Joint, 3-1/2" 1 Joint Tubing, 3-1/2" D Pup Joint, 3-1/2" Gauge Carrier, Baker, Zenith Gauge Installed Pup Joint, 3-1/2" 1 Joint Tubing, 3-1/2" E Pup Joint, 3-1/2" Sliding Sleeve, 2.813" X profile, covered ports for I-wire bypass (closed) Pup Joint, 3-1/2" ~187 Joints Tubing, 3-1/2" Pup Joint, 3-1/2" F 3-1/2” X Nipple @ 2500’ Pup Joint, 3-1/2" ~83 Joints Tubing, 3-1/2” 1. Land tubing hanger and space out. RILDS. Lay down landing joint. Note PU and SO weights on tally. 2. Drop Ball & Rod and pressure up tubing to 3500 psi or tool hand’s instructions to set packer. 3. Perform MIT-T to 3500 psi for 30 minutes charted. 4. Perform MIT-IA to 3500 psi for 30 minutes charted. 5. Set BPV & RDMO. Post-Rig Procedure: Well Support & Slickline 1. MIRU SL and pressure test PCE to 2500 psi high / 250 psi low. 2. Pull ball & rod and RHC plug. 3. Open SS and set JP. 4. RDMO SL. 5. RD mud boat. RD BOPE house. Move to next well location. 6. RU crane. ND BOPE and NU tree. 7. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 8. RD crane. Move 500 bbl returns tank and rig mats to next well location. 9. Turn well over to production. RU well house and flowlines. a. Power fluid SSV high pressure trip will not exceed 3650 psi b. Power fluid SSV low pressure trip will be set to 50 percent of header pressure RWO Convert to WAG Well: MPU C-14 Date: 27 Sep 2023 c. Production SSV high pressure trip not to exceed 650 psi d. Production SSV low pressure trip not to be below 75 psi Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Area of Review * Within 10 days of stabilized injection, state to witness MIT-IA to 3500 psi. -mgr * Approved for 30 days of pre-production on jet pump. _____________________________________________________________________________________ Revised By: TDF 11/12/2020 SCHEMATIC Milne Point Unit Well: MPU C-14 Last Completed: 11/27/19 PTD: 185-088 TD =8,833(MD) / TD = 7,306’(TVD) 13-3/8” Last Tag @ 8,720’ w/ Pipe on 7/7/97 Orig. KB Elev.: 52’/ GL Elev.: 12’ 7” 3 6 & 7 8 9&10 119 14 13 12 Est. TOC @ ±7,650’ 9-5/8” 1 2 PBTD =8,742’ (MD) / PBTD = 7,239’(TVD) 4 & 5 Upper ECP @ 8,519’ Lower ECP @ 8,539’ 15 16 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / N/A 12.715 Surface 115' 0.157 9-5/8" Surface 36 / K-55 / BTC 8.921 Surface 5,100’ 0.077 7" Production 29 / L-80 / BTC 6.276 Surface 8,822’ 0.0372 TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / 8rd EUE 2.441 Surface 8,050’ 0.00579 4-1/2” Tubing 12.6 / L-80 / BTC 3.958 8,274’ 8,507’ 0.01521 JEWELRY DETAIL No Depth Item 1 140’ Sta 2: Camco 2 7/8 X1'' Side pocket KBMM GLM (Dummy 11/1/20) 2 7,840’ Sta 1: Camco 2 7/8 X1'' Side pocket KBMM GLM (Open pocket 11/1/2020) 3 7,960’ 2-7/8” XN Nipple – ID= 2.205” 4 7,981’ Discharge Head: GPDIS 5 7,982’ Ported Discharge Head: 513/538 6 7,983’ Pump 1: PMSXD 20GINPSHH 7 8,000’ Pump 2: PMSXD 119P23 8 8,010’ Gas Separator: GRSFTX 9 8,015’ Upper Tandem Seal: GSB3DB H6 SB/AB PFSA 10 8,022’ Lower Tandem Seal: GSB3DB H6 SB/AB PFSA 11 8,029’ Motor: XP 250Hp/ 2,505V / 61A 12 8,046’ Motor Guage: ZenithW/ Centralizer – Bottom @ 8,050’ 13 8,274’ 7” 23# - 29# Versatrieve Packer 14 8,322’ 4-1/2” 12.75# N-80 LLP .20 Ga. Screen – Bottom @ 8,346’ 15 8,431’ 4-1/2” 12.75# N-80 LLP .20 Ga. Screen – Bottom @ 8,461’ 16 8,503’ 7” 23# - 32# BWD Sump Packer –Bottom @ 8,507’ PERFORATION DETAIL, REF LOG: 5/17/85 DIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1 8,327’ 8,344’ 6,931’ 6,943’ 7’ 8/9/1995 Open 8,327’ 8,344’ 6,931’ 6,943’ 7’ 5/20/1985 Open B6 8,452’ 8,457’ 7,024’ 7,028’ 5’ 5/20/1985 Open 8,481’ 8,487’ 7,046’ 7,050’ 6’ 5/20/1985 Open 8,452’ 8,487’ 7,024’ 7,050’ 5’ 8/9/1995 Open A3 8,576’ 8,596’ 7,116’ 7,131’ 34’ 8/9/1995 Open A3 8,576’ 8,610’ 7,116’ 7,142’ 40’ 5/20/1985 Open A2 8,610’ 8,650’ 7,142’ 7,171’ 40’ 8/9/1995 Open A2 8,610’ 8,650’ 7,142’ 7,171’ 40’ Reperf Open PERFS ORIGINALLY SHOT AT 12 SPF. REPERFED AT 6 SPF 8/94 WELL INCLINATION DETAIL KOP @ 1,400’ Max Hole Angle = 46 deg. @ 6,400’ TREE & WELLHEAD Tree 2-9/16” 5M CIW Wellhead 11” X11” 5M Adapter 2-7/8” T&B threads 2.5” CIW H Profile GENERAL WELL INFO API: 50-029-21344-00-00 Drilled, Cased and Completed by Alaska United #3 - 5/21/1985 Pull GLM and Install ESP – 5/23/1990 Pull ESP and Install GLM by EWS Rig #4– 6/6/1990 Pull GLM and Install ESP by EWS #1 – 7/9/1990 Remove and Replace ESP – 8/22/1994 Remove and Replace ESP & Upper Screen – 10/27/1994 Remove ESP and Screens. Replace ESP w/ Nabors 4ES – 5/23/1995 ESP Change-out & Wellbore Clean-out w/ Nabors 4ES – 7/9/1996 Remove and Replace ESP Instal Prod Screens w/ Nabors 5S – 5/5/1998 ESP Change-out w/ Nabors 4ES – 1/20/2000, 10/15/2000 & 8/28/2006 ESP Change-out w/ Doyon 16 – 4/12/2013 ESP Change-out w/ ASR 1 – 12/16/2015 & 11/27/2019 Coil Tubing, Tubing Clean-out to Top of ESP - OPEN HOLE / CEMENT DETAIL 9-5/8”1,375sx Permafrost E/ 250sx Class G in a 12-1/2” Hole 7” 273 sx Class G in a 8-1/2” Hole STIMULATION SUMMARY Frac 8/9/94 88.1 M#, 8,327’ – 8,344’ _____________________________________________________________________________________ Revised By: TDF 10/3/2023 PROPOSED Milne Point Unit Well: MPU C-14 Last Completed: 11/27/19 PTD: 185-088 TD =8,833 (MD) / TD = 7,306’(TVD) 13-3/8” Last Tag @ 8,720’ w/ Pipe on 7/7/97 Orig. KB Elev.: 52’/ GL Elev.: 12’ 7” 2 3 4 5 1 8 7 Est. TOC @ ±7,650’ 9-5/8” PBTD =8,742’ (MD) / PBTD = 7,239’(TVD) Upper ECP @ 8,519’ Lower ECP @ 8,539’ 9 10 6 1 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48 / H-40 / N/A 12.715 Surface 115' 0.157 9-5/8" Surface 36 / K-55 / BTC 8.921 Surface 5,100’ 0.077 7" Production 29 / L-80 / BTC 6.276 Surface 8,822’ 0.0372 TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / 8rd EUE 2.992 Surface ~8,252’ 0.0087 4-1/2” Tubing 12.6 / L-80 / BTC 3.958 8,274’ 8,507’ 0.01521 JEWELRY DETAIL No Depth Item 1 ~2,500’ 3.5” X Nipple 2 ~7,940’ 3.5” Sliding Sleeve 3 ~8,190’ Gauge Carrier 4 ~8,210’ 7” x 3.5” Packer 5 ~8,230’ 3.5” X Nipple 6 ~8,250’ 3.5” WLEG – Bottom @ ~8,252’ 7 8,274’ 7” 23# - 29# Versatrieve Packer 8 8,322’ 4-1/2” 12.75# N-80 LLP .20 Ga. Screen – Bottom @ 8,346’ 9 8,431’ 4-1/2” 12.75# N-80 LLP .20 Ga. Screen – Bottom @ 8,461’ 10 8,503’ 7” 23# - 32# BWD Sump Packer –Bottom @ 8,507’ PERFORATION DETAIL, REF LOG: 5/17/85 DIL Kuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C1 8,327’ 8,344’ 6,931’ 6,943’ 7’ 8/9/1995 Open 8,327’ 8,344’ 6,931’ 6,943’ 7’ 5/20/1985 Open B6 8,452’ 8,457’ 7,024’ 7,028’ 5’ 5/20/1985 Open 8,481’ 8,487’ 7,046’ 7,050’ 6’ 5/20/1985 Open 8,452’ 8,487’ 7,024’ 7,050’ 5’ 8/9/1995 Open A3 8,576’ 8,596’ 7,116’ 7,131’ 34’ 8/9/1995 Open A3 8,576’ 8,610’ 7,116’ 7,142’ 40’ 5/20/1985 Open A2 8,610’ 8,650’ 7,142’ 7,171’ 40’ 8/9/1995 Open A2 8,610’ 8,650’ 7,142’ 7,171’ 40’ Reperf Open PERFS ORIGINALLY SHOT AT 12 SPF. REPERFED AT 6 SPF 8/94 WELL INCLINATION DETAIL KOP @ 1,400’ Max Hole Angle = 46 deg. @ 6,400’ TREE & WELLHEAD Tree 2-9/16” 5M CIW Wellhead 11” X11” 5M Adapter 2-7/8” T&B threads 2.5” CIW H Profile GENERAL WELL INFO API: 50-029-21344-00-00 Drilled, Cased and Completed by Alaska United #3 - 5/21/1985 Pull GLM and Install ESP – 5/23/1990 Pull ESP and Install GLM by EWS Rig #4– 6/6/1990 Pull GLM and Install ESP by EWS #1 – 7/9/1990 Remove and Replace ESP – 8/22/1994 Remove and Replace ESP & Upper Screen – 10/27/1994 Remove ESP and Screens. Replace ESP w/ Nabors 4ES – 5/23/1995 ESP Change-out & Wellbore Clean-out w/ Nabors 4ES – 7/9/1996 Remove and Replace ESP Instal Prod Screens w/ Nabors 5S – 5/5/1998 ESP Change-out w/ Nabors 4ES – 1/20/2000, 10/15/2000 & 8/28/2006 ESP Change-out w/ Doyon 16 – 4/12/2013 ESP Change-out w/ ASR 1 – 12/16/2015 & 11/27/2019 Coil Tubing, Tubing Clean-out to Top of ESP - OPEN HOLE / CEMENT DETAIL 9-5/8”1,375sx Permafrost E/ 250sx Class G in a 12-1/2” Hole 7” 273 sx Class G in a 8-1/2” Hole STIMULATION SUMMARY Frac 8/9/94 88.1 M#, 8,327’ – 8,344’ Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Blind Ram 2-7/8" x 5" VBRs PT D A P I W E L L S T A T U S T o p o f Z o n e ( M D ) T o p o f Z o n e ( T V D ) T o p o f C e m e n t ( M D ) T o p o f C e m e n t ( T V D ) K u p a r u k S t a t u s Z o n a l I s o l a t i o n 20 1 - 1 9 4 5 0 - 0 2 9 - 2 3 0 2 0 - 0 0 - 0 0 M P C - 2 4 M o t h e r b o r e 7 8 3 4 6 7 1 3 7 4 9 4 6 4 2 0 A b a n d o n e d P e r f o r a t i o n s i s o l a t e d b y s q u e e z e . 20 9 - 1 3 4 50 - 0 2 9 - 2 3 0 2 0 - 0 1 - 0 0 M P C - 2 4 A P r o d u c e r 7 8 3 4 6 7 1 3 7 4 9 4 6 4 2 0 O p e n Es t i m a t e d T O C i n m o t h e r b o r e i s 3 4 0 ' a b o v e fo r m a t i o n t o p . C T l i n e r f u l l y c e m e n t e d w i t h 1 : 1 re t u r n s . 20 9 - 1 3 4 5 0 - 0 2 9 - 2 3 0 2 0 - 0 1 - 0 0 M P C - 2 4 A P B 1 P l u g b a c k 7 8 3 4 6 7 1 3 7 4 9 4 6 4 2 0 A b a n d o n e d P e r f o r a t i o n s i s o l a t e d b y s q u e e z e . Ar e a o f R e v i e w M P U C - 1 4 K U P C-24APB1: Abandoned well bore section lies within the reservoir and is isolated by cement in the C-24A well bore. SFD Kuparuk and Schrader Bluff reservoirs are cement isolated in MPU C-14 and C-18. SFD 201- 094 SFD 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: CTD Mill, Cleanout w/ N2 Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,833 feet N/A feet true vertical 7,306 feet N/A feet Effective Depth measured 8,720 feet 8,247 & 8,742 feet true vertical 7,223 feet 6,891 & 7,239 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 2-7/8"6.5 / L-80 / 8rd EUE 8,050' 6,722' Tubing (size, grade, measured and true vertical depth)4-1/2"12.6 / L-80 / BTC 8,507' 7,065' 7" Versatriev & Packers and SSSV (type, measured and true vertical depth)7" BWD Sump N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: WINJ WAG 0 Water-Bbl MD 115' 5,100' 8,822' TVD 115' 0 Oil-Bbl measured true vertical Packer 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-088 50-029-21344-00-00 Plugs ADL004734 / ADL0047437 5. Permit to Drill Number: MILNE POINT / KUPARUK RIVER OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-429 0 Authorized Signature with date: Authorized Name: Travis Semmens Travis.Semmens@hilcorp.com 460 MILNE PT UNIT C-14 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 700 Casing Pressure Tubing Pressure 0 N/A measured N/A Casing Conductor Size Junk measured Length 115' 5,100' 8,822' Surface Production Burst N/A 3,520psi 7,240psi 13-3/8" 9-5/8" 7" 4,533' 7,297' 2. Operator Name:Hilcorp Alaska LLC 777-8490 Senior Engineer: Senior Res. Engineer: Collapse N/A 2,020psi 5,410psi Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Chad A Helgeson 2020.11.13 12:23:54 -09'00' By Samantha Carlisle at 2:35 pm, Nov 13, 2020 SFD 11/17/2020 RBMDS HEW 11/16/2020 ADL047434 MGR05JAN2021 SFD 11/17/2020DSR-11/13/2020 Well Name Rig API Number Well Permit Number Start Date End Date MP C-14 CTU #6 50-029-21344-00-00 185-088 10/28/2020 10/30/2020 No operations to report. No operations to report. 10/31/2020 - Saturday No operations to report. 11/3/2020 - Tuesday 11/1/2020 - Sunday No operations to report. 11/2/2020 - Monday 10/30/2020 - Friday RDMO Coil Unit. 10/28/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Summary: CTU #6 1.75" CT .156" wall. Move CTU to C-14 and MIRU. MU BOT CTC, MHA and PT 250 / 3,500. Good PT, shut down OPS to start up at 06:00 10/29/2020 - Thursday CTU #6 1.75" CT .156" wall. MU BOT Milling BHA and RIH to tag, small WT changes at 290'. RIH to 2,560' clean, call OE and discuss POOH for Nozzle, POOH and MU a Nozzle BHA. RIH with Nozzle BHA, tag at 7,983', PU and retag, try starting ESP, no go. Online with pump and cleaned out ~12’ of fill on top of the ESP. Tagged the pump a few times and the pump started working. Pumped 25 bbls of 7.5% HCl to clean up the scale in the tubing. Pumped 10 bbls out 2x and let it soak for 15 min each, pumped last 5 bbls out while Pad OP was bumping the pump to make sure it was still free, all good. Displace coil & well to diesel then POOH without pumping to lighten up the Hydrostatic on the well to KO well. OOH one pick the BOP's, install night cap and test. Turn well over to Pad Op to POP. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS DEC 11 2019 fTTiM" 1. Operations Abandon Ll Plug Perforations LJ Fracture StimulatLi Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulat❑ Alter Casin g ❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair We❑� Re-enter Susp Well ❑ Other: ESP Change -out ❑� 2. Operator Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑� Stmtigraphic❑ Exploratory ❑ Service ❑ 185-088 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-21344-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0047437 MILNE PT UNIT C-14 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / KUPARUK RIVER OIL 11. Present Well Condition Summary: Total Depth measured 8,833 feet Plugs measured N/A feet true vertical 7,306 feet Junk measured N/A feet Effective Depth measured 8,720 feet Packer measured 8,247 & 8,742 feet true vertical 7,223 feet true vertical 6,891 & 7,239 feet Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' 1,730psi 740psi Surface 5,100' 9-5/8" 5,100' 4,533' 3,520psi 2,020psi Production 8,822' 7" 8,822' 7,297' 7,240psi 5,410psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 2-7/8" 6.5 / L-80 / and EUE 8,050' 6,722' Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6/ L-80/ BTC 8,507' 7,065' 7" Versatriev & Packers and SSSV (type, measured and true vertical depth) 7" BWD Sump N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 1 60 117 415 1 200 1 206 14. Attachments (required per 20 AAc 25.020, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory❑ Development p ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil El Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-498 Authorized Name: Chad Helgeson L� Contact Name: Stan Porhola 6T - Authorized Title: Operations Manager Contact Email: sp0rhola@hilcorp.com / Authorizetl Signature: Date: 12/9/2019 Contact Phone: 777-8412 M Form 10-404 Revised 4/2017 /z -fv- I l ///'/� RDDMS'f6'DEC 1 12019 Submit Original Only 4 8,: Lo 81! K III]. u Alaska, LLC Orig. KB Elw.: 52'/ GL Elea.: 12' TD=8,833 (1VD)/TD=7,306'(M) PBTD= 8,742' (MD) / PBTD= 7,239'(TW) SCHEMATIC TREE & WELLHEAD Tree 2-9/16"5M CIW Wellhead 11" X11" 5M Adapter 2-7/8" T&B threads 2.5" CIW H Profile Milne Point Unit Well: MPU C-14 Last Completed: 11/27/19 PTD: 185-088 OPEN HOLE / CEMENT DETAIL 9-5/8" 1,375sx Permafrost E/ 250sx Wt/Grade/Conn Class G in 812-1/2" Ho a 7" 1 273 sx Class G in a 8-1/2" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/N/A 12.715 Surface 115' 0.157 9-5/8" Surface 36/K-55/BTC 8.921 Surface 5,100' 0.077 7" Production 29/L-80/BTC 6.276 Surface 8,822' 0.0372 TUBING DETAIL STIMULATION SUMMARY WELL INCLINATION DETAIL Frac 8/9/94KOP @ 1,400' 88.1 M#, 8,327'-8,344' Max Hole Angle =46 deg. @ 6,400' JEWELRY DETAIL No Depth Item 1 140' Sta 2: Camco27/8%1"Side packet KBMM GLM 2 7,840' Sta 1: Ca--- 27/8 Xi" Side pocket KBMM GLM 3 7,960' 2-7/8"XN NMMp - In- 2.205" 4 7,981' Discharge Head: GPDIS 5 7,982' Ported Discharge Head: 5-5- 6 7,983' Pump 1: PMSXD 20GINPSHH 7 8,000' Pump 2: PMSXD 119P23 8 81010' Gas Separator: GRSFTX 98,015' Up or Tandem Seal: GSB3DB H6 SB/AB PFSA 30 8,022' Lower Tandem Seal: GSB3D8 H65B/AB PFSA 11 8,029' Motor: XP 250Hp/ 2,505V / 61A. 12 8,046' Motor Guage: ZenithW/Centralizer- Bottom@8,050' 13 8,274' 7" 23#- 29# Versatrieve Packer 14 8,322' 4-1/2" 12.75# N-80 LLP .20 Ga. Screen -Bottom @ 8,346' 15 8,431' 4-1/2" 12.75# N-80 LLP .20 Ga. Screen -Bottom @ 8,461' 16 8,503' 7"23#-32#BWDSump PackerBottom@8,507' PERFORATION DETAIL, REF LOG: 5/17/85 DIL :uparuk5ands Top (MD) D) Top (TVW7,17V D) FT Date Status C1 8,327' 6,931'' 7' 8/9/1995 Open 81327' 6,931'' 7' 5/20/1985 Open 8;452' 7,024'' 5' 5/20/1985 Open B6 8,481' M8,650'7,142' 7,046'' 6' 5/20/1985 Open 8,452' 7,024'' S' 8/9/1995 Open A3 8,576' 7,116'' 34' 8/9/1995 _5 Open A3 8,576' 7,116'' 40' / Open A2 8,610' 7,142'' 40' 8/9/1995 Open A2 8,610' 7,142'' 40' Report Open PERFS ORIGINALLY SHOT AT 12 SPF. REPERFEDAT6SPF8/94 GENERAL WELL INFO [Pull Mand 1344-00-00 and Completed by Alaska United #3- 5/21/1985 Install ESP-=10/27/1994 nstall GLM b#4-6/6/1990 Install ESP b7/9/1990Replace ESP 4 Remove and Replace ESP reen-10/27/1994 Remove ESP and Screens. P w/ Nabors 4ES -5/23/1995ESP Change-out&Wellbout w/Nabors 4ES-7/9/1996 Remove and Replace ESP Instal Prod Screens w/ Nabors 5S -5/5/1998 ESP Change -out w/ Nabors 4ES -1/20/2000, 10/15/2000 & 8/28/2006 ESPChan e-outw/Doyonl6-4/12/2013 ESP Change -out w/ ASR 1-12/16/2015 & 11/27/2019 Revised By: TDF In Progress Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP C-14 ASR #1 MILNE PT UNIT C-14 185-088 11/24/2019 11/27/2019 11/20/2019- Wednesday No operations to report. 11/21/2019 -Thursday No operations to report. 11/22/2019 - Friday No operations to report. 11/23/2019 -Saturday ,7 No operations to report. 11/24/2019 -Sunday Crane operations. ND wellhead, Inspected Hanger and 2-2/8" EUE Lifting threads, Set Test PLG NU BOPS, Spot Well Hut and Rig, Spot in the jet heaters behind the well hut. Raised Rig and secured Rack Pins, Spot Rig Floor, Set Stairs to Pits and run HCR Kill and Choke, Spot in Mud pump, Torque up BOPE, Run Flow lines through heater tube, Lay out BOPE hoses, Spot in the jet heaters behind the well hut. Spot in DSA's and flow cross. Took on 30bbls of freshwater in pits for BOPE Testing. Held PJSM, Sundry Meeting crew change and fluid checks. Continue Rig Up. Spot Eq. Lay out Secondary Containment & Spot Pipe Handler. Winterize Flow Lines and Eq. Rig Up Certek Unit. Prep For BOPE Test. Test BOPE as per Hilcorp and AOGCC. 250 Low / 2,500 High. Annular & VBR Rams 2-7/8" Test Joint. Witness Waived by AOGCC Inspector Matt Herrera. Blow Lines Dry, Rig Down 2-7/8" Test Joint and Test Eq. Run Rope through Containment Hose and Sheave for ESP Cable. 11/25/2019 - Monday PJSM, Serviced equipment and checked fluids. BOLDS and pulled hanger to rig floor. Hanger off -seat (al 58k. -De -completed hanger and L/D. Threaded cable thru sheave to spooler. POH L/D 2-7/8"" 6.5# L-80 EUE 8rd tbg and ESP Completion. f/surface t/2,000' Observed several blowouts on the ESP Cable and some slack on top the cannon clamps. This caused a slower trip time having to workout the kinks in the cable so it could go through the sheave. Avg trip time 500 fph. Double Displacing every 15jts with produced water. Cont POH with 2-7/8"" ESP completion f/2,000' ave trip time 700 fph. Displacing every 15 jts with produced water. PJSM, Serviced equipment and checked fluids. Cont POH with 2-7/8"" ESP completion. Displacing every 15 jts with produced water. Transfer TBG to Pipe Tub. Total TBG 253 Joints. De complete and LD ESP Assembly. Send assembly to Baker's shop and final inspection report will be sent out. Load out Failed ESP Assembly onto Baker Trailer. Clear off Rig Floor. Swap out ESP Spool. Gather New ESP Assembly and GLM's. Run Rope Through Sheave for ESP Cable. Rack & Tally 260 Joint of 2-7/8" EUE TBG. Pick Up ESP Assembly 11/26/2019 -Tuesday PJSM, Checked fluid and serviced equipment. PU/MU and serviced New ESP assembly. Checked Cable connection. TIH with New ESP assembly on New 2-7/8"" 6.5# L-80 EUE 8rd Tbg, P/U and RIH w/ XN nipple and 2 jts tbg. SO Ops for crew changeout. Monitoring well. crews swapped out, held sundry and safety meeting. Check well to be dead, start RIH w/ 2- 7/8"' rnd EUE tbg - clamping everyjoint for first 10joints and then every otherjoint. Test ESP cable every 1000',. Crew change. PJSM, Checked fluid and serviced equipment. Continue to RIH w/ 2-7/8"" EUE 6.5# Tubing while clamping every otherjoint. Continue to test cable every 1,000'. 130 joints @ 24:00. Continue to RIH w/ 2-7/8"" EUE 6.5# Tubing while clamping every otherjoint. Continue to test cable every 1,000'. Pumping double displacement+10 bbls dowhole every 15 minutes starting at 04:00. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP C-14 ASR #1 MILNE PT UNIT C-14 185-088 11/24/2019 1 11/27/2019 11/27/2019- Wednesday Crew change out and morning safety meeting, fluid checks on equipment. Continue to RIH w/ 2-7/8" EUE 8rd tbg and ESP power cable clamping every otherjoint. Currently on joint 235 of 255 @ 06:30. pump displacement and blow down all lines. Continue Rlh while troubleshooting blocks/carriage encoder issue with ProStar online Resulting in slower RIH time. P/U Hanger and begin to make hanger splice. Complete and test splice. Land Hanger, RILDS, INSTALLED BPV - Down Weight on hanger = 38K 11/28/2019 -Thursday No operations to report. 11/29/2019 - Friday No operations to report. 11/30/2019 -Saturday. No operations to report. 12/1/2019 -Sunday No operations to report. 12/2/2019 - Monday No operations to report. 12/3/2019 -Tuesday No operations to report. THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU C-14 Permit to Drill Number: 185-088 Sundry Number: 319-498 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaskci.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Were . Price a DATED this S day of November, 2019. MMS' Nov 0 6 2019 RECEIVED NOV 01 2019 STATE OF ALASKA AOGCC ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS On AA( nig OCn 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑✓ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change g Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change -out ❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ Stratigraphic ❑ Service ❑ 185-088 ' 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-21344-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432C Will planned perforations require a spacing exception? Yes ❑ No 0 MILNE PT UNIT C-14 9. Property Designation (Lease Number): 10. FielcUPool(s): ADL0047437 MILNE POINT / KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8,833 7,306 8,720 7,223 1,410 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' 1,730psi 740psi Surface 5,100' 9-5/8" 5,100' 4,533' 3,520psi 2,020psi Production 8,822' 7" 8,822' 7,297' 7,240psi 5,410psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 2-7/8" 6.5#/ L-80/ 8rd EUE 8,080' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7" Versatrieve & 7" BWD Sump and N/A 8,274 MD/ 6,891 TVD & 8,742 MD/ 7,239 TVD and N/A 12. Attachments: Proposal Summary ✓ Wellbore schematic ✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Strati ra hic g p ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/17/2018 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. S� Authorized Name: Chad Helgeson Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: S orhola hilcor .Com Contact Phone: 777-8412 Authorized Signature: Date: 11/1/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ Test M/ Mechanical Integrity Test ❑ Location Clearance ❑ 7 C�BOP Other: 4- LJ"W �$;, ,fd V, ` le fW iBDMS NOV 0 6 2019 Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No V Subsequent Form Required: © "' Y OL( APPROVED BY 1 1519 Approved by: COMMISSIONER THE COMMISSION Date: ��UI ORIGINAL "/�/ Submit Form and F ' 10-403 Revised 4/zon Approved application is valid for 12 months from the date of approval. Attachments in Duplicate �K rr if.t1.I. n ff Ililcura Alaska, LG Well Prognosis Well: MPU C-14 Date:11/01/2019 Well Name: MPU C-14 API Number: 50-029-21344-00 Current Status: SI Oil Well [ESP] Pad: C -Pad Estimated Start Date: November 17`^, 2019 Rig: ASR #1 Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 185-088 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) AFE Number: Job Type: ESP Repair Current Bottom Hole Pressure: 2,110 psi @ 7,000' TVD (Last BHP measured 11/01/2019, 5.8 ppg EMW) Maximum Expected BHP: 2,110 psi @ 7,000' TVD (No new perfs being added) MPSP: 1,410 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU C-14 was drilled in 1985 using Alaska United #3 as a grassroots well and completed in the Kuparuk sands. The well was originally completed as a gaslift well and converted to ESP in 1990. The well has had multiple ESPs changed out since 1990. Screens were installed in 1998. The last ESP change was done with ASR#1 on December 2015. Notes Regarding Wellbore Condition Casing last tested to 2,000 psi for 30 min down to 8,255' MD on 12/14/2015. C�— Max angle 46.0° @ 6,500' MD. Deviation at perfs is 42.00 . Obiective• • The purpose of this work is to pull the failed ESP and run a new ESP. Pre -Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with 8.4 ppg water down tubing, taking returns up casing to 500 bbl returns tank. I 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. Brief RWO Procedure: 0 Hikorn Alaska, LG Well Prognosis Well: MPU C-14 Date: 11/01/2019 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 8.4 ppg water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8" test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment \ and list items, pressures and rates. 14. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/ 8.4 ppg water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2015 ESP running was 59K lbs. b. If needed, circulate (long or reverse) pill with lubricant and/or BaraKlean pill prior to laying down the tubing hanger. 16. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8" tubing. Take all tubing to G&I for washing and disposal. Lay down ESP. Note any sand or scale inside or on the outside of the ESP on the morning report. b. Look for over -torqued connections from previous tubing runs. c. The completion has the following amount of clamps/guards: L 5 Protectolizers ii. 2 Flat Guards iii. 133 Crosscollar Clamps Well Prognosis Well: MPU C-14 Hikom ALA., tU Date: 11/01/2019 18. Contingency - Inspect ESP pumps and motor. If pumps and/or motor show any indication of fill/corrosion damage or any other issue that would warrant further review and not running the ESP, contact OE and run 2-7/8" kill string to 3,000' MD. Proceed with step 20. 19. PU ESP (new motor & new pump sections w/ new seals) and RIH on new 2-7/8" tubing. Set base of ESP assembly at ± 8,050' MD. a. Upper GLM @ ± 140' MD w/SO b. 2-7/8" tubing (New) c. Lower GLM w/ DGLV d. 3 joints of 2-7/8" tubing (New) e. 2-7/8" XN (2.205" No -Go) f. 1 joint of 2-7/8" tubing (New) g. ESP Assembly w/ Phoenix XT -150 gauge h. Base of ESP centralizer @ ± 8,050' MD 20. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 21. Set BPV. Post -Ria Procedure: 22. RD mud boat. RD BOPE house. Move to next well location. 23. RU crane. ND BOPE. 24. NU existing 2-9/16" 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 25. RD crane. Move 500 bbl returns tank and rig mats to next well location. 26. Replace gauge(s) if removed. 27. Turn well over to production. RU well house and flowlines. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Blank RWO MOC Form n can, Alaska. LLC Orifi. KB Elev.: 52'/ GL Elev.: 12' TD = 8,833 (MD) / TO = 7,306'(TVD) PBTD = 8,742' (MD) / PBTD = 7,23Y (TVD) SCHEMATIC TREE & WELLHEAD Tree 2-9/16" 5M CIW Wellhead 11"X11"5M Adapter 2-7/8" 7" T&B threads 2.5" CIW H Profile Milne Point Unit Well: MPU C-14 Last Completed: 12/16/15 PTD: 185-088 OPEN HOLE / CEMENT DETAIL 9-5/81, 1,375sx Permafrost E/ 250sx Wt/Grade/ Conn Class G in a 12-1/2" Hole 7" 273 sx Class G in a 8-1/2" Hole CASING DETAIL Size Type Wt/Grade/ Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/N/A 12.715 Surface 115' 0.157 9-5/8" Surface 36/K-55/BTC 8.921 Surface 5,100' 0.077 7" Production 29/L-80/BTC 6.276 Surtace 8,822' 0.0372 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/Brd EUE 2.441 Surf 8,080' 0.00579 STIMULATION SUMMARY Frac 8/9/94 88.1 M#, 8327'-8344' WELL INCLINATION DETAIL KOP @ 1,400' Max Hole Angle =46 deg. @6,400' JEWELRY DETAIL No Depth Item 1 125' GLM: 2-7/8" x 1" Camco KBMM w/Dummy 4-7-19 2 7,869' GLM: 2-7/8" x 1" Camco KBMM w/ Dummy Valve 3 7,976' 2-7/8"XN Nipple - ID= 2.250" 4 8,019' Discharge Head GPDIS 5 8,020' Pump: 119-P23, SXD 6 8,037' Gas Separator GRSFEFNAR 7 8,040' Upper Tandem Sea[ -GSD3DBUT SB/SB PFSA 8 8,047' Lower Tandem Sea[ -GSD3DBLT SB/SB PFSA 9 8,054' Motor CL5- MSPi, 210HP, 2145 Volt, 59 amp 30 8,076' Phoenix XT -150 W/Centralizer - Bottom @8,080' 11 8,274' T7_23#29# Versatrieve Packer 12 8,322' 4-1/2" 12.75# N-80 LLP .20 Ga. Screen - Bottom @ 8,346' 13 8,431' 4-1/2" 12.75# N-80 LLP .20 -Ga. - Bottom @ 8,461' 14 8,503' 7"23#- 32# BWD Sump Packer - Bottom @8,507' PERFORATION DETAIL, REF LOG: 5/17/85 DIL ,uparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TV140' Status C1 8,327' 8,344' 6,931' 6,943'5 Open 8,327' 8,344' 6,931' 6,943'85 Open 8,452' 8,457' 7,024' 7,028'85 C5/20/1985Open Open B6 8,481' 8,487' 7,046' 7,050'5 Open 8,452' 8,487' 7,024' 7,050'5 Open A3 8,576' 8,596' 7,116' 7,131'5 Open A3 8,576' 8,610' 7,116' 71142'5 Open A2 8,610' 8,650' 7,142' 7,171' 1 40' 8/9/1995 Open A2 8,610' 1 8,650' 1 7,142' 7,171'40' Reperf Open PERFS ORIGINALLY SHOT AT 12 SPF. REPERFEDAT6SPF8/94 GENERAL WELL INFO API: 50-029-21344-00-00 Drilled, Cased and Completed by Alaska United #3- 5/21/1985 Pull GLM and Install ESP -5/23/1990 Pull ESP and Install GLM by EWS Rig #4- 6/6/1990 Pull GLM and Install ESP by EWS #1-7/9/1990 Remove and Replace ESP -8/22/1994 Remove and Replace ESP & Upper Screen -10/27/1994 Remove ESP and Screens. Replace ESP w/ Nabors 4ES-5/23/1995 ESP Change -out & Wellbore Clean-out w/ Nabors 4ES 7/9/1996 Remove and Replace ESP Instal Prod Screens w/ Nabors SS - 5/5/1998 ESP Change -out w/ Nabors 4ES -1/20/2000, 10/15/2000 & 8/28/2006 ESP Change -out w/ Doyon 16 - 4/12/2013 ESP Change -out w/ ASR 1-12/16/2015 Revised By: TDF 8/7/2019 n IIileom Alaska, LLC Orifi KB Elev.: 52'/ GL Elev.: 12' TD = 8,833 (MD) / TD= 7,306'M) PBTD = 8,742' (MD) / PBTD = 7,239'(TVD) PROPOSED TREE & WELLHEAD Tree 2-9/16" 5M CIW Wellhead 11" X11" 5M Adapter 2-7/8" 7" T&e threads 2.5" CIW H Profile Milne Point Unit Well: MPU C-14 Last Completed: 12/16/15 PTD: 185-088 OPEN HOLE / CEMENT DETAIL 9-51K 1,375sx Permafrost E/ 250sx Wt/Grade/Conn Class G in a 12-1/2" Hole 7" 273 sx Class G in a 8-1/2" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/N/A 12.715 Surface 1 115' 0.157 9-5/8" Surface 36/K-55/BTC8.921 Pump Surface 5,100' 0.077 7" Production 29/L-80/BTC 6.276 Surface 8,822' 0.0372 TUBING DETAIL Tubing 6.5/L-80/8rd EUE 2.441 Surf 8,050' 0.00579 STIMULATION SUMMARY Frac 8/9/94 -71 88.1 M#, 8327' - 8344' WELL INCLINATION DETAIL KOP @ 1,400' Max Hole Angle = 46 deg. @ 6,400' JEWELRY DETAIL PERFORATION DETAIL, REF LOG: 5/17/85 DIL Cuparuk Sands h Item Top (TVD) 0' GLM: 2-7/8" x 1" Camco KBMM w/ DPSOV Date 39' GLM:2-7/8"x1" Camco KBMM w'Dummy Valve 8,327' 6' W8007' 2-7/8"XN Nipple-ID=2.250" 6,943' 89' Discharge Head Open 90' Pump 8,344' 7' Gas Separator10' 7' 5/20/1985 Upper Tandem Seal 8 +/-8,017' Lower Tandem Seal 9 +/-8,024' ESP Motor 10 +/-8,046' Phoenix XT -150 W/Centralizer- Bottom @8,050' 11 8,274' 7" 23# - 29# Versatrieve Packer 12 8,322' 4-1/2" 12.75# N-80 LLP .20 Ga. Screen - Bottom @ 8,346' 13 8,431' 4-1/2" 12.754 N-80 LLP .20 Ga. Screen - Bottom @ 8,461' 14 8,503' 7"23#-32# BWD Sump Packer - Bottom @ 8,507' PERFORATION DETAIL, REF LOG: 5/17/85 DIL Cuparuk Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status C3 8,327' 8,344' 6,931' 6,943' 7' 8/9/1995 Open 8,327' 8,344' 6,931' 6,943' 7' 5/20/1985 Open 8,452' 8,457' 7,024' 7,028' S' 5/20/1985 Open 86 8,481' 8,487' 7,046' 7,050' 6' 5/20/1985 Open 81452' 8,487' 7,024' 7,050' 5' 8/9/1995 Open A3 8,576' 8,596' 7,116' 7,131' 34' 8/9/1995 Open A3 8,576' 8,610' 7,116' 7,142' 40' 5/20/1985 Open A2 8,610' 8,650' 7,142' 7,171' 40' 8/9/1995 Open A2 8,610' 8,650' 7,142' 7,171' 40' Reperf Open PERFSORIWNALLYSHOT AT125PF. REPERFEDAT6SPF8/94 GENERAL WELL INFO =50 -029 -21344 -00 -00 -21344 -00 -ODed and Completed by Alaska United #3 - 5/21/1985 d Install ESP -5/23/1990 d Install GLM by EWS Rig#4-6/6/1990 nd Install ESP by EWS #1-7/9/1990 d Replace ESP - 8/22/1994 Remove and Replace ESP & Upper Screen -10/27/1994 Remove ESP and Screens. Replace ESP w/ Nabors 4ES - 5/23/1995 ESP Change -out & Wellbore Clean-out w/ Nabors 4ES-7/9/1996 Remove and Replace ESP Instal Prod Screens w/ Nabors SS -5/5/1998 ESP Change -out W/ Nabors 4ES -1/20/2000, 10/15/2000 & 8/28/2006 ESP Change -out w/ Doyon 16 - 4/12/2013 ESP Change -out w/ A511 1-12/16/2015 Revised By: STP 11/01/2019 Milne Point ASR Rig 1 BOPE 2019 11" BOPE Updated 11/01/2019 7/8" x 5" VBR es Tt Fw WE i a m 0 N 0 d a E 0 0 v m a ❑ N t EN Y R ❑ 3 -o m CL CL C N y d > R �+ V ❑ K C Uc C92N C i 0 CL 0 Q Q Qa 'O N N p Y > - 0.- CL CL a aM> N R a S Qm N m m L U v m v O IL m ❑ d rn R a c :3 c -T- I EN Y R ❑ 3 -o m CL CL STATE OF ALASKA • ALIIL OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ID Re-enter Susp Well ❑ Other: ESP Change-out 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory ❑ 185-088 3.Address: Stratigraphic❑ Service❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,Ak 99503 50-029-21344-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIV ED ADL0047437 MILNE PT UNIT KR C-14 Rei 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): J A,, 15 2016 N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: CC; AOG Total Depth measured 8,833 feet Plugs measured N/A feet true vertical 7,306 feet Junk measured N/A feet 8,274 Effective Depth measured 8,742 feet Packer measured 8,503 feet 6,891 true vertical 7,239 feet true vertical 7,062 feet Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' 1,730psi 740psi Surface 5,100' 9-5/8" 5,100' 4,533' 3,520psi 2,020psi Production 8,822' 7" 8,822' 7,297' 7,240psi 5,410psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/8rd EUE 8,080' 6,745' 7"Versatrieve 8,274 MD/6,891 TVD Packers and SSSV(type,measured and true vertical depth) 7"BWD N/A 8,503 MD/7,062 TVD N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 760 0 Subsequent to operation: 158 44 977 260 183 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas U WDSPL❑ Printed and Electronic Fracture Stimulation Data LI GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 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: 315-689 Contact Paul Chan Email pchan(a�hilcorp.com Printed Name Bo Y rk Title Operations Engineer � Signature a �(]2 Yoke—C- Phone 777-8345 Date 1/15/2016 v-ri z1/9 iil Ll )N 5 21 2016 Form 10-404 Revised 5/2015 f RBDMS i�'l/ �Q� Submit Original Only • • Milne Well: Point MPU C-14Unit ,lit SCHEMATIC Last Completed: 12/16/15 Hamra Alaska,LLC PTD: 185-088 TREE&WELLHEAD Orig.KB Elev.:52'/GL Elev.:12' Tree 2-9/16"SM CIW �* Wellhead 11"X11"5M Adapter 2-7/8"T&B threads 2.5"CIW H Profile 2a" krl OPEN HOLE/CEMENT DETAIL 1 9-5/8" 1,375sx Permafrost E/250sx Class G in a 12-1/2"Hole el 't 7" 273 sx Class G in a 8-1/2"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/N/A 12.715 Surface 115' 0.157 n, 4; 9-5/8" Surface 36/K-55/BTC 8.921 Surface 5,100' 0.077 M''' 7" Production 29/L-80/BTC 6.276 Surface 8,822' 0.0372 t TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surf 8,080' 0.00579 :! STIMULATION SUMMARY WELL INCLINATION DETAIL Frac 8/9/94 KOP @ 1,400' t. 88.1 M#, 8327'-8344' Max Hole Angle=46 deg. @ 6,400' 9-5/8" a lit JEWELRY DETAIL No Depth Item 1 125' GLM:2-7/8"x 1"Camco KBMM w/DSOV 2 7,869' GLM:2-7/8"x 1"Camco KBMM w/Dummy Valve 3 7,976' 2-7/8"XN Nipple-ID=2.250" 4 8,019' Discharge Head GPDIS 5 8,020' Pump:119-P23,SXD 6 8,037' Gas Separator GRSFEFNAR 7 8,040' Upper Tandem Seal-GSD3DBUT SB/SB PFSA 8 8,047' Lower Tandem Seal-GSD3DBLT SB/SB PFSA EstTOC @° 9 8,054' Motor CLS-MSP1,210HP,2145 Volt,59 amp ±7,65e 10 8,076' Phoenix XT-150 W/Centralizer-Bottom @ 8,080' 11 8,274' 7"23#-29#Versatrieve Packer 12 8,322' 4-1/2"12.75#N-80 LLP.20 Ga.Screen-Bottom @ 8,346' 13 8,431' 4-1/2"12.75#N-80 LLP.20 Ga.Screen-Bottom @ 8,461' 14 8,503' 7"23#-32#BWD Sump Packer-Bottom @ 8,507' 3 1 4 PERFORATION DETAIL,REF LOG: 5/17/85 DIL Kuparuk Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 5 8,327' 8,344' 6,931' 6,943' 7' 8/9/1995 Open C Sands 8,32T 8,344' 6,931' 6,943' 7' 5/20/1985 Open -- 8,452' 8,457' 7,024' 7,028' 5' 5/20/1985 Open r f 7&8 B Sands 8,481' 8,487' 7,046' 7,050' 6' 5/20/1985 Open 8,452' 8,487' 7,024' 7,050' 5' 8/9/1995 Open 8,576' 8,596' 7,116' 7,131' 34' 8/9/1995 Open . 9 A Sands 8,576' 8,610' 7,116' 7,142' 40' 5/20/1985 Open 8,610' 8,650' 7,142' 7,171' 40' 8/9/1995 Open ti 8,610' 8,650' 7,142' 7,171' 40' Reperf Open 10 PERFS ORIGINALLY SHOT AT 12 SPF. REPERFED AT 6 SPF 8/94 . 11 GENERAL WELL INFO 12 API:50-029-21344-00-00 r'` Drilled,Cased and Completed by Alaska United#3- 5/21/1985 Pull GLM and Install ESP-5/23/1990 13 Pull ESP and Install GLM by EWS Rig#4-6/6/1990 Upper ECP @ '=' '_ 14 Last Tag @ Pull GLM and Install ESP by EWS#1-7/9/1990 8,51g ►I$ El 8,720'w/Pipe Remove and Replace ESP-8/22/1994 Lover ECP @ R on 7/7/97 Remove and Replace ESP &Upper Screen-10/27/1994 8,539'��'"' Remove ESP and Screens.Replace ESP w/Nabors 4ES-5/23/1995 ESP Change-out&Wellbore Clean-out w/Nabors 4E5-7/9/1996 Remove and Replace ESP Instal Prod Screens w/Nabors 5S-5/5/1998 TD=8,833(MD)/TD=7,306'(TVD) ESP Change-out w/Nabors 4ES-1/20/2000 PBTD=8,742'(MD)/PBTD=7,239'(TVD) ESP Change-out w/Nabors 4ES-10/15/2000 ESP Change-out w/Nabors 4E5-8/28/2006 ESP Change-out w/Doyon 16-4/12/2013 ESP Change-out w/ASR 1-12/16/2015 Revised By:TDF 1/14/2016 • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP C-14 ASR#1 50-029-21344-00-00 185-088 12/2/15 12/16/15 Daily Operations: 12/2/2015-Wednesday Rigging up ASR#1. 12/3/2015-Thursday Continue rigging up ASR#1. 12/4/2015- Friday Continue rigging up ASR#1. 12/5/2015-Saturday Continue rigging up ASR#1, and trouble shoot rig engine. 12/6/2015-Sunday Continue rigging up ASR#1, waiting on exhaust filter for rig engine. 12/7/2015- Monday Continue rigging up ASR#1, still waiting on exhaust filter for rig engine. 12/8/2015 -Tuesday Continue rigging up ASR#1, still waiting on exhaust filter for rig engine. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP C-14 ASR#1 50-029-21344-00-00 185-088 12/3/15 12/16/15 Daily'Operations s., It 12/9/2015-Wednesday Continue rigging up ASR#1, install exhaust filter for rig engine. Replacing engine EGR temperature sensor. 12/10/2015-Thursday EGR temperature sensor replaced. Start engine and begin warming rig for operations. 12/11/2015-Friday Grease Rack on Derrick, Work on Hydraulic system for Link Tilt. Rig up for BOP Test. Test BOPs as per AOGCC requirements, Test all Rams and valves to 250 psi low pressure and 3,000 psi high pressure.Test H2s & Methane gas alarms.Test was witnessed by AOGCC, Bob Noble &Johnnie Hill. Rep working on Link Tilt on top Drive. Well Rep Pulled TWC Valve from Tbg Hanger. Circulated down tubing with 20 bbls of 110 Degree Seawater, 1 bpm @ 100 psi. Picked up 2-7/8" Landing JT installed TIW Valve. RIH Make up in Tbg Hnager BOLDS. Verify 0 Pressure on IA. Pulled Tbg Hanger at 63k to Rig Floor, Free Pull 60k. Break out Landing Jt and laid Down,Tie ESP Cable on Rope to Spooling unit.Tripped out of the hole Laid Down 23 Jts Looking for over Torqued or Damaged Tbg While Pulling out of the hole, Rig Engine Shut Down Light Come on, Lowered Top Drive Latched onto Tbg Stump installed TIW Valve into Tbg Stump Pull 45k to Center Tbg in Bop Stack. Secure and Monitor Well Bore. Mechanic From VMS Shop was called out. Mechanic installed Computer to Rig Motor. Computer is saying Particulate filter is Plugged. Rig Motor is not regening on its own to Clear Filter as Needed and Mechanic is unable to do it Manual (Blake Roger CH2MHill Mechanic was Called to help Fix Motor Problem. (Mechanic is now able to Regen Motor Manually) Engine will not Regen on its own at this Time. 12/12/2015-Saturday Continue to Trouble shoot issues with Rig Engine. Found Pressure sensor tubes had ice up, cleared ice and rerouted sensor tubes to allow for drainage of moisture. Functioned hydraulics to verify everything working properly. Continue to Trip out of the hole laying down 2.875"Tubing.Total joint (252). Drain Pump Break Down and layed down on Rack. Rep Working on Hydraulic Leak on Top Drive. Rig Crew Strap Tally BHA and 2.875" Tbg on Rack. Pick up Make up 7' Casing Scraper& Bit Trip in the hole on 2.875"Tbg to 4,362'. 12/13/2015-Sunday Service Rig, Check all fluids on equipment. Continue to Trip in the hole picking up 2.875" tubing to 8,261'.Scrape through test packer setting depth at 8,250' with 5 passes. Reverse Circulate 1 Tubing volume to flow back tank.Trip out of the hole laying down 2-7/8"tubing. Repair hydraulic leak on swivel carrier. Continue to Trip out of the hole laying down 2-7/8" Tubing and 7' Casing Scraper. Pick up 7" Champ IV Packer and 2.875"Tbg Trip in the hole to 8,255'. 12/14/2015- Monday Set Champ Packer at 8,255' Center of Element,fill backside with 38 bbl of seawater.Test 7"Casing to 2,000psi charted for 30 min. Good Test.TOOH, laying down 2.875" Tubing to 2,475'.Troubleshoot rig Engine, had fault codes on rig Engine, Cleaned sensor tubes of moisture, installed heat on sensor tube, cleared codes. Continue to TOOH laying down 2.875" Tubing, Lay down Test packer. Service Rig, Checking Fluids in Equipment and Fuel Levels. Pick up and Make up and Service New ESP Assembly, Install ESP Cable and Test.Tripping in the hole with ESP Completion Pump to 2,400'.Testing Cable every 2,000'. • • •F Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP C-14 ASR#1 50-029-21344-00-00 185-088 12/3/15 12/16/15 D•POperations: 12/15/2015-Tuesday Continue to Trip in the hole with ESP Completion,test cable every 2,000' (Held BOP Drill, Tripping Drill). Make up Tubing hanger. Make up Field connector to ESP cable and install on Tubing Hanger Penetrator. Landed Tbg Hanger @ 19:00 hrs. Set at 8,080.21' (PU=59k) (DN =40K) (Cannon Clamps 2'-133) (Protectolizers=5) (FlatGuards=2) Well Head Rep ( Greg) Verfied Hanger is Landed in Tbg Spool. RILDS. Backed out Landing Joint and layed Down. Install BPV into Tbg Hanger. Roads & Pads Assisted with Crane to Remove Power Tongs and X-Box from Rig Floor. R/D ESP Sheave from Derrick. Remove Hydraulic Hoses From Bop-HCR Choke and Nipple down BOP Stack Flanges to Four Bolts. Break Over and Lower Derrick. • OF TSF • • %%isv THE STATE Alaska Oil and Gas of Conservation Commission _ - T iAsKA _ _ _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®�ALASY'P Fax: 907.276.7542 www.aogcc.alaska.gov Bo York SCA" jN 2-0.1 Operations Manager O S6 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR C-14 Sundry Number: 315-689 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this (Zday of November, 2015 Encl. RBDM IN 13 2015 • • RECEIVEL ' NOV 062015 STATE OF ALASKA PTS itia,/IS ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate [11 Repair Well El ' Fill Clean-out ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing E] • Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ESP Change Out 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska LLC Exploratory ❑ Development 0. 185-088 3.Address: 3800 Centerpoint Dr,Suite 1400El6.API Number. Stratigraphic ❑ Service Anchorage,AK,99503 50-029-21344-00-00 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 432C Will planned perforations require a spacing exception? Yes ❑ No ❑✓ / MILNE PT UNIT KR C-14 ' 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0047437 - MILNE POINT/KUPARUK RIVER OIL. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,833 7,306 8,742 . 7,239 . 175 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 115' 13-3/8" 115' 115' 1,730psi 740p si Surface 5,100' 9-5/8" 5,100' 4,533' 3,520psi 2,020psi Production 8,822 7" 8,822' 7,297' 7,240psi 5,410psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 8,061 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"Versatrieve&7"BWD Sump and N/A 8,274 MD/6,891 TVD&8,742 MD/7,239 TVD and N/A 12.Attachments: Proposal Summary E Wellbore schematic D '13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic ❑ Development ❑✓ . Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 12/1/2015 Commencing Operations: OIL ❑✓ • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola Email sporhola(cthilcorp.com Printed Name Bo York Title Operations Manager Signature "2- _ Phone 777-8345 Date 11/6/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315- C S9 Plug Integrity ❑ BOP Test ri Mechanical Integrity Test ❑ Location Clearance ❑ Other: -i 2 S©D p:.:_ 81'147 f- ( ivtASP= 1 3°5 !'s`.i\ Post Initial Injection MIT Req'd? Yes ❑ No ❑ �� Ci29--- Spacing Exception Required? Yes ❑ No L✓J Subsequent Form Required: to - Y v y 1 „+C �(-(2-i, p ` `1 (1 l u 1J p / APPROVED BY I��D� U Approved by: / u COMMISSIONER THE COMMISSION Date: '(-12 - / S� j /i q.is fl(fl(6 IllibY- /#-(1 //J / 0 R4G4NtAl� Submn Form ane Form 10-403 Revised 11/2015 valid for 12 months from the date of approval. Attachments it Duplicate • • Well Prognosis Well: MPU C-14 fiilcorp Alaska,LL, Date: 11/06/2015 Well Name: MPU C-14 API Number: 50-029-21344-00 Current Status: SI Oil Well [ESP] Pad: C-Pad Estimated Start Date: December 1st, 2015 Rig: ASR#1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 185-088 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: �,41 C Current Bottom Hole Pressure: 2,005 psi @ 7,000' TVD (Last BHP measured 11/01/2015) • f� � Maximum Expected BHP: 2,005 psi @ 7,000' TVD (No new perfs being added) s Current Shut-In Tbg Pressure: 250 psi 4-re (Based on current SITP w/existing fluid column) Max. Predicted Surf Pressure: 1,305 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU C-14 was drilled in 1985 using Alaska United #3 as a grassroots well and completed in the Kuparuk sands. The well was originally completed as a gaslift well and converted to ESP in 1990. The well has had multiple ESPs changed out since 1990. Screens were installed in 1998. The last ESP change was done with Doyon#16 in 2013. Notes Regarding Wellbore Condition • Casing last tested to 3,000 psi for 30 min down to an unknown depth on 6/05/1990,.. Objective: The purpose of this work is to pull the failed ESP, and run a new ESP. / Brief Procedure: Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services Pump. Setup reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Reverse circulate at least one wellbore volume with 8.5 ppg sea water down casing, taking returns up tubing to 500 bbl returns tank. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH or diesel. 7. RD Little Red Services Pump and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU 11" BOPE. RD crane. 9. NU BOPE house. Spot mud boat. • WO Rig Procedure: 10. MIRU Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. 11. Pull BPV. Bleed any pressure off tubing and casing. • ,o-u- • , ll 5 pf Well Prognosis s' Well: MPU C-14 Ililcorp Alaska,LLV— Date: 11/06/2015 12. Kill well w/8.5 ppg seawater as needed. Set TWC. 13. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8" test joint. 14. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path, test choke manifold per standard procedure V) c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor (° < the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking k`/4 anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 15. Pull TWC. Bleed any pressure off tubing and casing to 500 bbl returns tank. Kill well w/8.5 ppg seawater as needed. 16. MU 2-7/8" landing joint (EUE) and BOLDS. 17. Pull over string weight (approx. 55k PU) on tubing hanger to confirm free. LD tubing hanger. a. Contingency: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 18. POOH. Lay 2-7/8" tubing on the pipe rack (plan to re-run tubing). Lay down ESP. a. Replace bad joints of tubing as necessary. b. Look for over-torqued connections from previous Doyon#16 tubing runs. • 19. MU 6" mill/bit and casing scraper and RIH w/2-7/8" tubing (existing tubing or workstring). 20. Scrape 7" 29#casing down to+/-8,274' MD (Versatrieve Packer). 21. Reverse circulate at least one tubing volume (48 bbl)taking return to 500 bbl returns tank. 22. POOH. Lay 2-7/8 tubing on the pipe rack. LD bit and casing scraper. I .) ( ,., . , 23. PU RTTS and RIH w/2-7 8"tubingr I. / (existing tubing or workstring). 24. Set RTTS at+/-8,250' MD. Fill annulus w/8.5 ppg sea water. GASi.: 25. Test casing to 2,000 psi for 30 min and chart. /�3c 26. Bleed off casing pressure to pits. Release RTTS. POOH. Lay down 2-7/8" tubing. LD RTTS. 27. PU new 513/538 series ESP and RIH with existing 2-7/8" 8RD EUE L-80 tubing. DD a. Run 2-7/8" XN profile, 2 ea GLMS, and no heat trace. 1` 5P 28. Set base of ESP at+/-8,080' (Pump intake around +/-8,045'). 29. Land tubing hanger. RILDS. Lay down landing joint. a. Note PU (Pick Up) and SO (Slack Off) weights on tally. 30. Set BPV.Test tubing hanger to 250/5,000 psi thru test port. 31. RD Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500 bbl returns tank. • • Well Prognosis Well: MPU C-14 11110011)a<<„ka.I.L Date: 11/06/2015 Post-Rig Procedure: 32. RD mud boat. RD BOPE house. Move to next well location. 33. RU crane. Pull BPV. Set TWC. ND BOPE. 34. NU existing 2-9/16" 5,000#tree.Test tree to 250/5,000 psi. Pull TWC. RD crane. 35. Move 500 bbl returns tank and rig mats to next well location. 36. Replace IA&OA pressure gauges if removed (7" &9-5/8"). 37. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic 5. Existing Tree/Wellhead 6. FWD Circ to Kill Tank Flow Diagram 7. REV Circ to Kill Tank Flow Diagram 8. Bleed to Pits Flow Diagram 9. Blank RWO Changes Form H . . Milne Point Unit Well: MPU C-14 SCHEMATIC Last Completed: 4/12/2013 Hilcorp Alaska,LLC PTD: 185-088 CASING DETAIL Orig.KB Elev.:52'/GL Elev.:12' Size Type Wt/Grade/Conn ID Top Btm 4 it ,i 13-3/8" Conductor 48/H-40/N/A 12.715 Surface 115' 20' #« 9-5/8" Surface 36/K-55/BTC 8.921 Surface 5,100' 4: 1 7" Production 29/L-80/BTC 6.276 Surface 8,822' L, TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.241 Surf 8,061' r JEWELRY DETAIL s No Depth Item ' 1 132' GLM:2-7/8"x 1"Camco KBMM w/DSOV 2 7,817' GLM:2-7/8"x 1"Camco KBMM w/Dummy Valve 0 r 3 7,959' 2-7/8"XN Nipple-ID=2.250" 4 8,003.7' Discharge Head GPDIS ti 5 8,004' Pump:119-P23,PMSDX 6 8,022' Gas Separator GRSFTXARH6 ` `': 7 8,027' Upper Tandem Seal-GSD3DBUT SB/SB PFSA " 8 8,033' Lower Tandem Seal-GSD3DBLT SB/SB PFSA 1.44 9 8,040' Motor CL5-MSP1,210HP,2380 Volt,53 amp 9-5/8"%j , jj 10 8,057' Phoenix XT-0 W/Centralizer-Bottom @ 8,061' 11 8,274' 7"23#-29#Versatrieve Packer 12 8,322' 4-1/2"12.75#N-80 LLP.20 Ga.Screen-Bottom @ 8,346' 13 8,431' 4-1/2"12.75#N-80 LLP.20 Ga.Screen-Bottom @ 8,461' 14 8,503' 7"23#-32#BWD Sump Packer-Bottom @ 8,507' ` PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status C Sands 8,327' 8,344' 6,931' 6,943' 7' 8/9/1995 Open 8,327' 8,344' 6,931' 6,943' 7' 5/20/1985 Open Est.TOC@ I 8,452' 8,457' 7,024' 7,028' 5' 5/20/1985 Open ±7,650' B Sands 8,481' 8,487' 7,046' 7,050' 6' 5/20/1985 Open I 8,452' 8,487' 7,024' 7,050' 5' 8/9/1995 Open "`r4,, A Sands 8,576' 8,610' 7,116' 7,142' 34' 8/9/1995 Open 4i i. 2 t* 8,610' 8,650' 7,142' 7,171' 40' 5/20/1985 Open '+�� 8,610' 8,650' 7,142' 7,171' 40' 8/9/1995 Open y 6 : 3 Iv 4 OPEN HOLE/CEMENT DETAIL .' 1,4 9-5/8" 1,1375sx Permafrost E/250sx Class G in a 12-1/2"Hole yc #., K i 5 7" 273 sx Class G in a 8-1/2"Hole WELL INCLINATION DETAIL ^1 d" KOP @ 1,400' %I an 7&8 Max Hole Angle=46 deg. @ 6,400' 41 ant TREE&WELLHEAD ++gg 9 Tree 2-9/16"SM CIW x Wellhead 11"X11"5M Adapter 2-7/8"T&B threads 2.5"CIW H Profile 4 .r t i t', GENERAL WELL INFO 10 API:50-029-213-00-00 't >:4+ '„1 11 Drilled,Cased and Completed by Alaska United#3- 5/21/1985 12 Pull GLM and Install ESP-5/23/1990 Pull ESP and Install GLM by EWS Rig#4-6/6/1990 r Pull GLM and Install ESP by EWS#1-7/9/1990 .`; 13ilt Remove and Replace ESP-8/22/1994 Remove and Replace ESP &Upper Screen-10/27/1994 1♦ -1 Upper ECP @ P , r- 4 Lit Tag @ 8,515 8,720 W Pipe Remove ESP and Screens.Replace ES w/Nabors 4ES-5/23/1995 Lour ECP @ on 7/7/9781 ESP Change-out&Wellbore Clean-out w/Nabors 4ES-7/9/1996 8,535 ! 7„ �,, Remove and Replace ESP Instal Prod Screens w/Nabors 5S-5/5/1998 "1 ' ESP Change-out w/Nabors 4ES-1/20/2000 ESP Change-out w/Nabors 4ES-10/15/2000 TD=8,833(MD)/TD=7,306'(TVD) ESP Change-out w/Nabors 4ES-8/28/2006 PBTD=8,742'(MD)/PBTD=7,239'(1VD) ESP Change-out w/Doyon 16-4/12/2013 Revised By:STP 11/05/2015 H . PROPOSED SCHEMATTC Milne Point Unit Well: MPU C-14 Last Completed: Proposed Hilcorp Alaska,LLC PTD: 185-088 CASING DETAIL Orig.KB Elev.:52'/GL Elev.:12' Size Type Wt/Grade/Conn ID Top Btm L 13-3/8" Conductor 48/H-40/N/A 12.715 Surface 115' 20'b ±;� �: 9-5/8" Surface 36/K-55/BTC 8.921 Surface 5,100' 7" Production 29/L-80/BTC 6.276 Surface 8,822' TUBING DETAIL `•; t. 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surf ±8,080' c JEWELRY DETAIL No Depth Item I ' 1 ±130' GLM:2-7/8"x 1"Camco KBMM w/DSOV :t A 2 ±7,900' GLM:2-7/8"x 1"Camco KBMM w/Dummy Valve t; 0 3 ±7,960' 2-7/8"XN Nipple-ID=2.250" 4 ±8,026' Discharge Head GPDIS 'A 5 ±8,027' Pump:119-P23,PMSDX 6 ±8,045' Gas Separator GRSFTXARH6 41, 7 ±8,050' Upper Tandem Seal-GSD3DBUT SB/SB PFSA r " 8 ±8,056' Lower Tandem Seal-GSD3DBLT SB/SB PFSA x 9 ±8,063' Motor CL5-MSP1,210H P,2380 Volt,53 amp 9-5/8",' dg 10 ±8,080' Phoenix XT-0 W/Centralizer-Bottom @ 8,080' 11 8,274' 7"23#-29#Versatrieve Packer 12 8,322' 4-1/2"12.75#N-80 LLP.20 Ga.Screen-Bottom @ 8,346' 13 8,431' 4-1/2"12.75#N-80 LLP.20 Ga.Screen-Bottom @ 8,461' 14 8,503' 7"23#-32#BWD Sump Packer-Bottom @ 8,507' PERFORATION DETAIL Kuparuk Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status C Sands 8,327' 8,344' 6,931' 6,943' 7' 8/9/1995 Open 8,327' 8,344' 6,931' 6,943' 7' 5/20/1985 Open Est.TOC@ 8,452' 8,457' 7,024' 7,028' 5' 5/20/1985 Open ±7,650' B Sands 8,481' 8,487' 7,046' 7,050' 6' 5/20/1985 Open `a 8,452' 8,487' 7,024' 7,050' 5' 8/9/1995 Open +« }A Sands 8,576' 8,610' 7,116' 7,142' 34' 8/9/1995 Open t* 2 3 8,610' 8,650' 7,142' 7,171' 40' 5/20/1985 Open 8,610' 8,650' 7,142' 7,171' 40' 8/9/1995 Open 3 "? i 4 OPEN HOLE/CEMENT DETAIL lett 9-5/8" 1,1375sx Permafrost E/250sx Class G in a 12-1 2"Hole 5 7" 273 sx Class G in a 8-1/2"Hole ') ijji i 6 WELL INCLINATION DETAIL KOP @ 1,400' k7 7&8 Max Hole Angle=46 deg. @ 6,400' 11 P TREE&WELLHEAD I9 Tree 2-9/16"5M CIW :,rt ift 41 Wellhead 11"X11"5M Adapter 2-7/8"T&B threads 2.5"CIW H Profile to: tat?` t ?i GENERAL WELL INFO o 10 " API:50-029-213-00-00 ',`'-" '='1 11 Drilled,Cased and Completed by Alaska United#3- 5/21/1985 12 Pull GLM and Install ESP-5/23/1990 '�, t;', Pull ESP and Install GLM by EWS Rig#4-6/6/1990 }' }' Pull GLM and Install ESP by EWS#1-7/9/1990 5« 13 Remove and Replace ESP-8/22/1994 upper�P@ ,-+1'�."' 14 TH@ Remove and Replace ESP &Upper Screen-10/27/1994 8,515 8,720'1A/130e Remove ESP and Screens.Replace ES w/Nabors 4ES-5/23/1995 Lo�nerECP @ on 7/7/97 ESP Change-out&Wellbore Clean-out w/Nabors 4ES-7/9/1996 8,53g ki .� Remove and Replace ESP Instal Prod Screens w/Nabors SS-5/5/1998 7i'v r ESP Change-out w/Nabors 4ES-1/20/2000 ESP Change-out w/Nabors 4ES-10/15/2000 TD=8,833(MD)/TD=7,306'(TVD) ESP Change-out w/Nabors 4ES-8/28/2006 PBTD=8,742'(MD)/PBTD=7,239'(TVD) ESP Change-out w/Doyon 16-4/12/2013 Revised By:STP 11/05/2015 • • ‘ H Milne Point 2015 ASR Rig 1 Knight Oil Tools BOP »korp �ia*4. .1.11iinvilM Stripping Head ink Shaffer' 11 5000 til tri rciifit 1 V p / I h 1 ) 64 H �2 11" 000 H Blind ei , IID 2" Kill Line 2" Choke Line Gam — : : : d -6, II11101 C Manual Manual Manual HCR Updated 11/03/15 s • Choke Manifold ASR#1 Ifil.r.,rp %looks,lit. 11/01/2015 Digital Reverse line back to Kill Manifold Pressure Readout II El C2 �® illit C3 Digital 1,, Pressure Transmitter - - From Choke Line Manual Choke �� 011, . B "' Remote A C4 C5 C6 C7 Choke v z r I�.� •� I I tot ° i c00 • M ' - Iif _ ' II 0 UOQ 4 o o il .. __ ': N1. III '% 4 III III NI_ .lel 'fir, ;_ iaiIta i vinow.. C9 I0�1 ,:, I ,, 411"0 All Valves 2" „; Piper Series PB Ball Valves 6,170 psi Working x' 10,000 psi Tested C8 -111114%. _ 'r.,4��7 - � 1 Ovi C11 X01 1., C10 X08' ate; 1.1 C13 �,. C15 ill 0 0 ; :-,IMIN Ell t a; 11.110MMON 01k, O IImilli of ' Int 1 III /11111 �� C12 - 1i"tali C14 i - C16 Ii„w o�O.a „. I�` '� To Panic Line ;. 1502 Union Outside End Capped To Gas Buster • i EXISTING TRMPU C-14 EE/WELLHEAD Wellhead/Tree Hilcorp Alaska,LLC Milne Point Unit jo_t Tree Cap :(;)0 :r per Tree Valve 2-9/16"5M ©0 Itl •I Tree Cross 2-9/16"5M 110@(:0)0'41 Tree Valve 2-9/16"5M �_� .. 1 1•V- '1.1 SSV 2-9/16" 5M (0 1.1. r.-.° � �o Tree Valve 2-9/16"5M r o�4) 0p® •I IIINO r H ESP Cable 1•, LI Heat Trace Tubing Adapter = Tubing Head i,i I :mu 11"5M Top x 11" 5M Bt all I I� 1ill`� 111: �. ! ui 110 III Casing Head 411 11"5M Top x 11" 5M Btm J •1111 411 11 (,,,..:: . • 0 ^ E r c.a.1..- .,:4 A 7; 9 0 I X Z 1:1-213 0 cri d 1 a *6' •_ w E u a 1r, 2 • 7,',, 1) 5 g' 6 a 2 = -a Z w Z3 Ln 6) 'LTD VT3 . 2 o co co _. co 0 8 co 8 a 83 L., '2 . . 2 w .. o ..c A v -ii o - co a It g .0 ., A a a _ c, za -M....MTE111_MEI c cc ., V a I. a > ..-.2 = z: 00 <4 a. 0." le---- 2 • ,,, : .., • , t.... — Z r- -g ';1' v, • :-., .. a. F U 2 a % .S -1 co co cc D : v., El o ...• —1— . .. I'---. ••:;....: cc .- .6. 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E _ co k o - § f _ /a—C H R LA Y \ §] w 2 =l I \ 4011— ] hi! 9N�j —i R 2 I 3 ] R Lel L —1 E ] G —1*w H I—— (— }tea § +$ $\ 0 0 0 / \ k tl 22 c $ » o a) ; ca .g P5O E0E k � 2 oo c � � � » E ' o f %§ .§ < � f \ � 2 u) \ \ 2 CL - 1 00 < RI 2 § / 2 a) a) as co • � ml- a) « C3 Ci CO 2 \ / W ¥ 0TU w _a B LI / Ga) U. E la as \ _ & \ -0 / G $ C < E a) a)§ § 01- G ® " O 2/ ' 8 2 \ . a. b \ 0 E a) \ 0 § 7 (" a m c \ 2 \ o u) @ 2 2 t o 0_ � 47. ƒ/ ca. cao. 2 .2 x � 8 2 0 / c0 & 9 o $ d a E q .2 $ 0 ( 0 0 >, 2 it O 0 ., k \ _ .. a f ° 0 &co ƒ e j \ c/ a \ 0 o < < < 2 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Cf6c6 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPC -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPC -Pad 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 • 1 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPC -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO # API # cement pumped cement date inhibitor sealant date , ft bbls ft gal MPC-01 1811430 50029206630000 Sealed conductor NA NA NA NA NA MPC-02 1821940 50029208660000 Sealed conductor NA NA NA NA NA MPC-03 1820500 50029207860000 Sealed conductor NA NA NA NA NA MPC-04 1821260 50029208010000 Sealed conductor NA NA NA NA NA MPC -05A 1842430 50029212440100 Tanko conductor NA NA NA NA NA MPC-06 1842410 50029212570000 Tanko conductor NA NA NA NA NA MPC-07 1850020 50029212660000 Tanko conductor NA NA NA NA NA MPC-08 1850140 50029212770000 Tanko w/o top NA NA NA 3.4 10/9/2011 MPC -09 1850360 50029212990000 Tanko conductor NA NA NA NA NA MPC -10 1850150 50029212780000 Tanko conductor NA NA NA NA NA MPC-11 1850590 50029213210000 Tanko conductor NA NA NA NA NA MPC -12A 1990910 50029213730100 Tanko conductor NA NA NA NA NA MPC -13 1850670 50029213280000 Tanko conductor NA NA NA NA NA ----l► MPC -14 1850880 50029213440000 1.8 NA 1.8 NA 5.1 8/31/2011 MPC-15 1851030 50029213580000 Sealed conductor NA NA NA NA NA MPC-16 1851100 50029213640000 Sealed conductor NA NA NA NA NA MPC-17 1852630 50029214730000 Tanko conductor NA NA NA NA NA MPC-18 1852690 50029214790000 Abandoned NA NA NA NA NA MPC-19 1852960 50029215040000 Tanko conductor NA NA NA NA NA MPC-20 1890150 50029219140000 Tanko conductor NA NA NA NA NA MPC -21 1940800 50029224860000 4.6 NA 4.6 NA 8.5 8/29/2011 MPC -22A 1951980 50029224890100 38 NA Need top job MPC -23 1960160 50029226430000 1.9 NA 1.9 NA 17.0 8/28/2011 MPC-24 2010940 50029230200000 1.6 NA 1.6 NA 20.4 8/28/2011 MPC -25A 1960210 50029226380100 1.7 NA 1.7 NA 17.0 8/28/2011 MPC-26 1952060 50029226340000 1.8 NA 1.8 NA 17.0 8/28/2011 MPC -28A 2051630 50029226480100 1.6 NA 1.6 NA 10.2 8/29/2011 MPC-36 1980010 50029228530000 4.5 NA 4.5 NA 45.9 8/29/2011 MPC-39 1972480 50029228490000 5.5 NA 5.5 NA 49.3 8/29/2011 MPC-40 2002130 50029228710000 0.75 NA 0.75 NA 5.1 8/29/2011 MPC-41 2010780 50029230140000 0.5 NA 0.5 NA 8.5 8/31/2011 MPC-42 2040280 50029231960000 1.5 NA 1.5 NA 13.6 8/30/2011 MPC-43 2040390 50029232000000 3.3 NA 3.3 NA 30.6 8/30/2011 .. I STATE OF ALASKA . ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WEll OPERATIONS RECEIVED SEP 2 7 2006 Alaska Oil & Gas Cons. Commissio 1. Operations Performed: Ancnorage o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver 181 Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 185-088 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21344-00-00 7. KB Elevation (ft): 52' 9. Well Name and Number: MPC-14 8. Property Designation: 10. Field / Pool(s): ADL 047437 Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 8833 feet true vertical 7305 feet Plugs (measured) None Effective depth: measured 8742 feet Junk (measured) None true vertical 7239 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 115' 115' Surface 5100' 9-5/8" 5100' 4533' 3520 2020 Intermediate Production 8822' 7" 8822' 7297' 7240 5410 Liner -,,'t't.NN';;::î' c··, Perforation Depth MD (ft): 8327' - 8650' ,/ '<t'-", '; ',4..'- Perforation Depth TVD (ft): 6931' -7171' 2-718",6.5# L-80 8153' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7",23# - 29#, HES Versatrive Packer 8724' 7" BWD Sump Packer .* 8503' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Ft 0 C1 0 3 2006 13. Recresentative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinç¡ Pressure Tubina Pressure Prior to well operation: 412 635 1404 240 168 Subsequent to operation: 233 313 2901 260 162 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG DGINJ DWINJ o 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: Contact David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant Si~~~(~~-- Prepared By Name/Number: Phone 564-4750 DatE(.}+ Z;-:)' CUSondra Stewman, 564-4750 " - . . Form 1 0-4õ4~evlsed 04/2006 RIGrN- Ai " ,--, J I ..l_ Submit Onglnal Only TREE: 2-9/16- 5M CIW . WELLHEAD: 11"x 11" 5M Adapter 2-7/8" T&B Threads 2.5" CIW H-profile KOP @ 1400' Max Hole Angle: 46" @ 6400' 9 5/8", 36#/ft, K-55 Buttress I 5100' I - Tubing data: 2 7/8" 6.5 ppf, L-80 8rd EUE tbg. (drift = 2.347", cap. = (.0058bpf) Stimulation Summary Frac - 8/9/94, 88.1 M# 8327' - 8344' PERFORATION SUMMARY REF LOG: 5/17/85 DIL SIZE SPF INTERVAL (TVD - RKB) 5" 12DP 8327'-8344' (6930' - 6943') C 3-3/8 6BH 5" 12 DP 8452'-8457' (7024' - 7027') B 5" 12DP 8481'-8487' (7045' - 7050') B 3-3/8 6BH 8452'-8487' (7024' - 7050') B 5" 12DP 8576'-8596' (7115' - 7130') A 3-3/8 6BH 8576'-8610' (7115' -7141') A 5" 12 DP 8610'-8650' (7141' - 7170') A 33/8 6BH PERFS ORIGINALLY SHOT AT 12 SPF REPERFED AT 6 SPF 8/94 DATE 5/21/85 OS/21/95 05/08/98 10/15/00 12/10/00 8131106 MP C-14 8<B Elevation = 52.00' ~L Elevation = 12.00' 2-7/8" X 1" Camco GLM (KBMM w/ DSOV) 2-7/8" X 1" Camco GLM (KBMM w/ dummy valve) 2-7/8" X 1" Camco GLM (KBMM w/dummy valve) 2-7/8" XN nipple 2.205" id Phoenix XT-1 Pressure Head Discharge Head Tandem Pumps 513 & 538 series 112GC2900, Model GPMTAR1:1 18P75, Model SXD Gas Separator 513 series, GRSTXBARH6 Tandem Seal Section 513 series GSB3DB UTIL T FERHLSSCVH6 Motor (Re-rated) 562 series, KMH 195 hp 23415 v./69 amp Phoenix XT-1 w/6-fin centralizer 7" 23#-29# HES Versatrieve pkr. L-80, 12.6# blank pipe (ID = 3.958") 4.5 "N-80. 24' .20" Ga. screen L-80, 12.6# blank pipe (ID = 3.958") 4,5 "N-80, 60' .20" Ga. screen 7" BWD Sump Packer CURRENT PBTD 7" 29#, L-80, BTRS EV.BY DBR JBF K Walker MDO MDO L. Hulme COMMENTS DRILLED 110/26/94 WORKOVER WORKOVER RWO Nabors 4-ES I 01/20/00 ESP RWO ESP RWO Tandem 4-ES RWO Nabors 4ES ESP Change out Nabors 4ES MILNE POINT UNIT WELL C-14 API NO: 50-029-21344 BP EXPLORATION (AK) I 138' I I 1013' I I 7,913' I I 8,056,1 I 8,073' I I 8,074'1 I 8,075' I I 8,105' I I 8,110' I I 8,124' I I 8,146' I I 8274'1 I 8,322'1 I 8,431' I 8503' 8742' 8822' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-14 MPC-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/27/2006 Rig Release: 8/31/2006 Rig Number: Spud Date: 10/14/2000 End: 8/31/2006 8/28/2006 00:00 - 12:00 12.00 MOB P PRE Move Rig and components to MPC-14 from GPB A-02. 12:00 - 16:00 4.00 RIGU P PRE Spot Rig over well slot MPC-14. Spot Camp, Tiger Tank and Pits. Raise and scope Derrick. Begin taking on 140 degree 2% KCL into Pits. Accept Rig at 16:00 hrs on 8/28/2006. 16:00 - 20:00 4.00 KILL P DECOMP RU lines to kill well. Test surface lines to 3500 psi. Hold ATP (Authorization to Proceed) HSE Meeting with Milne Pt. personnel and both rig crews. Welcomed back to Milne pt. and discussed HSE protocol/ policies. 20:00 - 21 :00 1.00 KILL P DECOMP PJSM. Started kill procedure by checking the well pressures Annulus = 1240 psi, TBG = 490 psi. Bleed gas off Annulus to 190 psi and TBG pressure to 170 psi. Both Annulus and TBG full of Well Bore Fluids. Shut in and allow to stabilize at 350 psi. 21 :00 - 21 :30 0.50 KILL P DECOMP Pump 50 bbls of 2% KCI brine down TBG at 2-4 BPM wI 380-720 psi TBG pressure. Maintaining 350 CSG pressure wI choke. 21 :30 - 22:00 0.50 KILL P DECOMP Bullhead 50 bbls down TBG at 3 BPM w/ 300 psi TBG pressure and 500 psi CSG pressure. 22:00 - 23:00 1.00 KILL P DECOMP Kill well by pumping down TBG at 4 BPM and maintain TBG pressure from 480 to 600 psi. Start circulation w/ 350 CSG pressure, came down to 70 psi as brine came to surface. 23:00 - 00:00 1.00 KILL P DECOMP Shut in well and allow to stabilize w/ 20 psi on both TBG and CSG pressure. Bleed off TBG pressure and Annulus pressure. Monitor well dead. 8/29/2006 00:00 - 02:30 2.50 DHB DECOMP Set TWC valve and test by pumping down Annulus to test from below. Pumped 4 BPM wI 200 psi, could not get a pressure test due to injection rate, visibly TWC was holding. Pressure test TWC from above wI 3500 psi for 10 minutes, charted results. 02:30 - 03:30 1.00 WHSUR DECOMP ND production tree and adapter flange. 03:30 - 06:00 2.50 BOPSU DECOMP NU BOPE. Begin RU Sheave to handle ESP cable. 06:00 - 06:30 0.50 BOPSU DECOMP Pre-tour safety meeting and rig checks. 06:30 - 07:30 1.00 BOPSU DECOMP Continue NU BOPE. Change out Pipe Rams from 3" x 6" VBRs to 2 7/8" x 5" VBRs. 07:30 - 12:00 4.50 BOPSU DECOMP PJSM. Test BOPE per BP / AOGCC Regulations to 250 psi low / 3,500 psi high with the IA open. The state's right to witness the test was waived by Chuck Scheve on 8/28/2006. Blow down lines and close IA. 12:00 - 13:00 1.00 WHSUR DECOMP RU Lubricator and Extension to pull TWC with Well Support and FMC. Tubing was on a vac. 13:00 - 14:00 1.00 PULL DECOMP RD Lubricator and RU 2 7/8" 8 Round Landing Joint to pull Tubing Hanger. Prior to BOLDS, open up IA to ensure well is still dead. The well is breathing. SI and pressure built up to 20 psi. RU to circulate well. 14:00 - 17:30 3.50 PULL DECOMP Break circulation at 5 bpm I 900 psi down the tubing up the IA. After 2.5 bbls, we caught fluid (410'). Began getting crude returns after 21 bbls away. Pressure increased to 1100 psi. Pumped a total of 325 bbls and shut-in. Surface to surface is 278 bbls but we lost 147 bbls during the circulation into the formation. Monitor well and tubing is still on a vac but the IA has 20 psi on it. Discuss with Anchorage Engineering and continue to circulate until getting clean KCL returns. Finished cleaning up Well bore. Pumped a total of 437 bbls. Lost -206 Printed: 9/5/2006 11 :08:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-14 MPC-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/27/2006 Rig Release: 8/31/2006 Rig Number: Spud Date: 10/14/2000 End: 8/31/2006 8/29/2006 14:00 - 17:30 3.50 PULL DECOMP bbls during circulation. Monitor Well dead with fluid level slowely dropping out of sight. 17:30 - 18:00 0.50 PULL DECOMP Rig down circulation equipment. BOLDS. Pulled Tubing Hanger to floor with no problems at 75K. Hanger broke free at 77K. 18:00 - 18:30 0.50 PULL DECOMP Lay down Landing Joint and Tubing Hanger. 18:30 - 19:00 0.50 PULL DECOMP Pull ESP Cable over Sheave and attach to Spooling Unit. 19:00 - 00:00 5.00 PULL DECOMP POH with existing 2 7/8" EUE 8 Round Tubing ESP Completion standing back in the Derrick. Visually inspect all joints and GLMs. Pipe is covered with crude and pretty warm coming out of the hole. No scale seen on the pipe. Will need to replace one joint (Joint #190 out of the hole) with a new one. Bad joint length = 31.61' , New joint = 31.64'. Double displacing well with hot 2% KCL as POH. 8/30/2006 00:00 - 00:30 0.50 PULL P DECOMP Continue POH with existing 2 7/8" ESP Completion. 00:30 - 03:00 2.50 PULL P DECOMP PJSM. Break down and lay down ESP Pump. Put components into boxes and prepare to PU new ESP Pump. Motor Adaptor bad and Cable burnt. 03:00 - 06:00 3.00 PULL P DECOMP Load new ESP components into Pipe Shed. Change out spools in the Spooling Unit. Remove elephant trunk. Slickline came out and changed out both dummy valves in bottom GLMs and inserted a screened orifice valve in the upper GLM. Clear and clean Rig Floor in preparation for running new completion. 06:00 - 07:00 1.00 RUNCO RUNCMP Make-up and service new ESP Assembly. 07:00 - 07:30 0.50 RUNCO RUNCMP Perform final ESP checks. While waiting for Centrilift to complete checks the Derrick was inspected and the PVT Alarms were checked. 07:30 - 09:00 1.50 RUNCO RUNCMP Connect Phoenix Senser. Pull new ESP Cable over sheave snd connect to Motor. 09:00 - 15:00 6.00 RUNCO RUNCMP TIH with 2 718" ESP Completion from Derrick. Stopping every 1,700' to make checks and flush the pump with hot 2% KCL. 15:00 - 18:00 3.00 RUNCO RUNCMP Stop to make a reel to reel splice. Still have upper GLM Assembly and 1 stand (3 joints) of 2 7/8" Tubing to run. Clear and clean Rig Floor. Pre-tour safety meerting with night crew. 18:00 - 18:30 0.50 RUNCO RUNCMP Continue TIH with upper GLM Assembly and final 3 joints of 2 7/8" Tubing. Ran a total of 253 joints of 2 7/8" 6.5# L-80 8rd EUE Tubing. Note: The previous tally had 254 joints but with the longer ESP Assmebly, one joint was not re-ran. This puts the bottom of the ESP Assembly at 8153'. The 3 GLMs were re-ran with dummy valves in the bottom 2 and a screened orifice in the upper GLM. Ran 136 laSalle Clamps, 6 Protectolizers and 3 Flat Guards. 18:30 - 19:00 0.50 RUNCO RUNCMP MU Tubing Hanger and Landing Joint. Install the Penetrator. Get weights prior to landing: UW = 72K , DW = 52K. 19:00 - 22:00 3.00 RUNCO RUNCMP Make up Motor Lead Extension Connector. Pumped 10 bbls to flush out Tubing at a rate of 1.3 bpm 1800 psi. Continue to fill hole with 2% KCL. New Centrilift crew and didn't have all equipment on location. 22:00 - 22:30 0.50 RUNCO RUNCMP Land Tubing Hanger gently 20'+ in on the Landing Joint. Lay down Landing Joint and RILDS. 22:30 - 23:00 0.50 WHSUR P RUNCMP PU T-bar and set TWC with FMC representative. Count 51/2 turns to confirm set. Attempt to test from below by pumping down the IA at a rate of 3 bpm 1150 psi - charted. Pumped 15 Printed: 9/5/2006 11 :08:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8/31/2006 22:30 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 03:00 03:00 - 04:00 04:00 - 06:00 MPC-14 MPC-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/27/2006 Rig Release: 8/31/2006 Rig Number: Spud Date: 10/14/2000 End: 8/31/2006 1.00 WHSUR P bbls. Test TWC from above to 1000 psi for 10 mins - charted. Break off Headpin and lay down Landing Joint. PJSM. ND BOPE. Continue ND BOPE. PJSM. NU Adapter Flange and 2 9/16" 5M Tree. Note: The original Tree had faulty master valve and SSV. The Tree put on is a condition B Tree that has been refurbished. RUNCMP Pressure test Adapter Flange and Hanger seals to 5,000 psi for 30 minutes - good. Make final checks on ESP with Centrilíft representatives- good. Test Tree to 5,000 psi - good. RUNCMP RU Lubricator and pull TWC with Well Support reps. Set BPV. Attempt to test from below by pumping 20 bbls of hot 2% KCL at a rate of 3 bpm 1150 psi. Secure Tree and Cellar. Rig released at 06:00 hrs 8/31/2006. 2.00 WHSUR P Printed: 9/5/2006 11 :08:47 AM ' ' / MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, ~~0~ Commissioner Tom Maunder, P. I. Supervisor~"~ DATE: May 19, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Miine point Unit C Pad May 19,2001: I traveled to BP's Milne Point Field to witness Safety Valve System tests. Lee Hulme was BP Rep. in charge of SVS tests. Testing was conducted in a safe & efficient manner. This Pad is on 3 month test cycle due to failure rate above 9.9%. I reviewed the 8/12/98 supplement to the 3/30/94 SVS policy to discuss BP's options for keeping the wells with leaking Surface Safety Valves producing & injecting. Lee Hulme stated that servicing & repair of the valves could not be accomplished immediately. After review of the AOGCC Policy Supplement, I told Lee that the wells could stay on line if someone trained in Drill Site Operations manned the Pad. I requested the Pad be manned immediately & until the valves were repaired & re-tested. The ^OGCC test report is attached for reference. Wells #7,8 & 25 were serviced & re-tested OK 5-20-01. Wells ~t4,6 & 14 were shut in for repairs. .SUMMARY: I witnessed SVS testing in Milne Point Field. 12 wells, 24 components tested. 6'failures witnessed. 25% failure rate. 20 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc cc; NON-CONFIDENTIAL SVS MPU C Pad 5-19-01jc Ala'~" Oil and Gas Conservation Commis~,~n Safety Valve System Test Report Operator: BPX Operator Rep: Lee Huime ,t AOGCC Rep: John Crisp Submitted By: .Jo.lap... Crisp Date: Field/Unit/Pad: Milne Point Unit C Pad Separator psi: LPS 140 HPS 5/19/01 i i i i i . i i ~ r~=?~.~_~.~_.~-~.-:_..~?~ I I I I I I I ! Well Permit Separ Set L/P Test Test Test Date on, WAG, Gm J, Number Number PSI PSI ,Trip ,Code Code. Code Passed GAS or CYCLE iC-01' ' i'8114~0 140 "100 110 P P OiL C-02 1821940 C-03 ' '1820500 140 100 " 95 P P ' OIL C-04 1821'260 140 100 '110 P ' 4 ...... [C-'(~5A 1842430 140 " 100 100 P P ..... OIL C-06 1842410 4300 2000 1950 P 4 WAG C-07 1850020 .... i40 ' i00 ' OS P 4 ' oiL! c-'08 1850140 '4300 2006 1900 p 3, ' wAG ~c-09" 1'850360 ' 140 " i'00 '" 105 P' ' P OiL C-13 i850670~ C-14 1850880 140 100 100 P 4 ' oIL C-15 1851030! C-17 1852630 C-20 1890150 C-21 1940800 C'22A'' 1951980 140 100~ 95 e P ' ' ' 0IL C-23 1960160' C72, 5A 1960210! ,,43001 2000 1900 P ' 4 ....... w)~G' 'C-26 1952060 C-28 1960290 C-36 1980010 C-39 1972480 C-40 2002130 C-10 " 1850150 4300 2000 1850 'P P ..... wAG Wells: 12 Components: 24 Failures: 6 Failure Rate: 25.00o~1~]00 Day Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU C Pad 5-19-01jc STATE OF ALASKA ALASK/','~'=,,t- AND GAS CONSERVATION COMM',,~. 'ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate Iiil Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out, ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 52' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 839' NSL, 2134' WEL, Sec. 10, T13N, R10E, UM ~ ~¢~~ ~ MPC-14 1'~~" V ~ 9. Permit Number / Approval No. - At top of productive interval 185-088 378' SNL, 1641' EWL, Sec. 14, T13N, R10E, UM 10. APl Number At effective depth F E B 0 '~ 2 0 0 ! 50-029-21344-00 440, SNL, 1910' EWL, Sec. 14, T13N, R10E, UM 11. Field and Pool At total depth Alaska 0il & Gas Cons. Commission Kuparuk River 454' SNL, 1970' EWL, Sec. 14, R13N, R10E, UM Anchorage 12. Present well condition summary Total depth: measured 8833 feet Plugs (measured) true vertical 7305 feet Effective depth: measured 8742 feet Junk (measured) true vertical 7239 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 16" To surface 115' 115' Surface 5064' 9 5/8" 1375 sx PF 'E', 250 sx Class 'G' 5100' 4533' Intermediate Production 8788' 7" 273 sx Class 'G' 8822' 7297' Liner Perforation depth: measured 8327' - 8344', 8452' - 8457', 8481' - 8487', 8452' - 8487', 8576' - 8596', 8576' - 8610', 8610' - 8650' true vertical 6931' - 6943', 7024' - 7028', 7046' - 7050', 7024' - 7050', 7116' - 7131', 7116' - 7142', 7142' - 7171' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 8163' Packers and SSSV (type and measured depth) 7" HES Versatrive packer at 8724'; 7" BWD Sump packer at 8503' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubb,e.~j~ {J~,~ Title TechnicalAssistant Date 0~:~'0~"'¢/ ¢ Prepared By Name/Number: Terde Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Legal Well Name: MPC-14 Common Well Name: MPC-14 Spud Date: 1011412000 Event Name: WORKOVER Start: 10/12~2000 End: Contractor Name: NABORS Rig Release: 12/10~2000 Group: RIG Rig Name: NABORS 4ES Rig Number: : : :::: : . : : ::::: ::::::::::::::::::::: :: ;: : ::::::: :::: ::::::::::: :~:~ :::: :::::~: : ::: Date From To Hours TaSk cSoUdbe phase 10/12/2000 18:00 - 00:00 6.00 MOB DECOMP RIG DOWN RIG ON MPU F-45 LOCATION 10/13/2000 00:00 - 03:00 3.00 RIGU DECOMP SPOT SUB, RAISE AND SCOPE OUT DERRICK, SPOT AND BERM PITS, CONNECT ALL LINES 03:00 - 05:00 2.00 RIGU DECOMP SPOT AND BERM TIGER TANK, CONNECT ALL HARD LINES TO THE TREE, HCR VALVE TO THE ANNULUS 05:00 - 06:00 1.00 RIGU DECOMP TAKE ON 500 BBLS OF SEAWATER TO THE PITS 06:00 - 07:30 1.50 PULL DECOMP WEIGHT UP SEA WATER TO 8.7 + PPG WITH SALT 07:30 - 09:30 2.00 PULL DECOMP CIRCULATED HOLE WITH 8.7+PPG BRINE AT 600 PSI @3 BPM. PUMPED A TOTAL OF 400 BBLS. SHUT WELL IN FOR PRESSURE BUILD UP SlTP 240 PSI SlCP 360 PSI. 09:30 - 13:30 4.00 PULL DECOMP WEIGHT UP TO 8.9 + PPG AND CIRCULATE WELL WITH 8.9 + GOING IN AND 8.9+ GOING OUT. SHUT WELL IN AND SlTP 170 PSI SlCP 220 PSI. 13:30- 18:00 4.50 PULL DECOMP WEIGHT UP TO 9.6+ PPGAND CIRCULATED ALL THE WAY AROUND WITH 9.6+ GOING IN AND 9.6+ COMING OUT. WELL DEAD 18:00 - 19:00 1.00 PULL DECOMP MONITORED WELL AND SET TWCV. TESTED TO 2500 PSI. 19:00-20:30 1.50 PULL DECOMP NIPPLE DOWN HCR&TREE 20:30 - 23:30 3.00 PULL DECOMP NIPPLE UP DSA,CUT OFF TOP OF PENATRATOR, NIPPLE UP BOPE. 23:30 - 00:00 0.50 PULL DECOMP TEST BOPE 250~3500 PSI. BODY TEST WITNESS WAIVED BY JOHN SPAULDING OF AOGCC 10/14/2000 00:00 - 01:00 1.00 PULL DECOMP TEST BOPE 250~3500 PSI. BODY TEST WITNESS WAIVED BY JOHN SPAULDING OF AOGCC 01:00 - 02:30 1.50 PULL DECOMP PU LUB AND PULL TWC & LD LUB 02:30 - 04:30 2.00 PULL DECOMP 02:30-03:30 PU LANDING JT./MU IN HANGER/BO LD SCREWS. PULL HNAGER TO THE FLOOR, TEST ESP CABLE. lAY DOWN HANGER. FILLED HOLE WITH 25 BBLS TO FILL HOLE. 04:30 - 11:30 7.00 PULL DECOMP TRIP OUT OF THE HOLE WITH 2 7~8" TUBING, CABLE AND ESP. PUMP DOUBLE DISPLACEMENT WHILE PULLING OUT OF THE HOLE. SHOT FLUID LEVELS WITH FLUID AT 650' TO 500' FROM SURFACE. 11:30 - 13:00 1.50 PULL DECOMP CHECK AND LAY DOWN ESP 13:00 - 14:00 1.00 PULL DECOMP CLEAR AND CLEAN RIG FLOOR. PREP TO RUN NEW ESP 14:00 - 18:00 4.00 RUNCOI~I COMP INSTALL NEW REEL IN SPOOLER, PICK UP AND SERVICE ESP, TEST CABLE 18:00 - 21:00 3.00 RUNCOI~I COMP TRIP IN THE HOLE WITH 2 7~8" TUBING AND ESP WITH ESP TO 2,800'. PHD WOULD NOT TEST 21:00 - 00:00 3.00 PULL COMP PULL OUT OF THE HOLE WITH 2 7~8" TUBING AND ESP TO 800' 10/15/2000 00:00 - 01:00 1.00 PULL COMP 00:00-01:00 PULL OUT OF THE HOLE WITH 2 7/8" TUBING AND ESP 01:00 - 03:00 2.00 PULL COMP TEST ESP AND LAYDOWN PUMP. CHNAGE PHD ON PUMP 03:00 - 08:30 5.50 RUNCOI~I COMP CHANGE LEAD ON MLE CABLE DUE TO KINK, PICK UP AND SERVICE ESP. TIE CABLE IN AND TEST 08:30 - 13:30 5.00 RUNCOI~I COMP RIH WITH ESP TO 8,187'. 13:30 - 15:30 2.00 RUNCOI~I COMP MAKE UP HANGER. MEASURE AND CUT CABLE, SPLICE FIELD CONNECTOR, TIE INTO HANGER AND TEST 15:30 - 16:00 0.50 RUNCOr~ COMP LAND AND LOCK DOWN HANGER, SET AND TEST TWCV TO 2,500 PSI. 16:00 - 19:30 3.50 WHSUR COMP DRAIN STACK, BLOW DOWN LINES, REMOVE BELL NIPPLE, REMOVE ANNULAR, ND BOPE AND DOUBLE STUD ADAPTER Printed: 12/20/2000 7:41:41 PM : Operafi°hS ifilmmh :R P :: Legal Well Name: MPC-14 Common Well Name: MPC-14 Spud Date: 10/14/2000 Event Name: WORKOVER Start: 10/12/2000 End: Contractor Name: NABORS Rig Release: 12/10/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: Date From-T° Hours Task COde:l 10/15/2000 16:00 - 19:30 3.50 WHSUR COMP FLANGE. 19:30 o 22:30 3.00 WHSUR COMP NU TREE AND TEST VOID AND TREE TO 5000 PSI 22:30 - 23:00 0.50 WHSUR COMP PICK UP LUBRICATOR AND PULL TWCV/SET BPV AND LAYDOWN LUBRICATOR 23:00 - 23:59 0.98 WHSUR COMP SECURE WELL AND RIG DOWN CELLER. RIG RELEASED AT 23:59 HRS 10-15-2000 "tChorage' ¢°~ission Printed: 12/20/2000 7:41:41 PM l MEMORANDUM State of Alaska Alaska Oil and Gas Conservation C°mmission TO' Julie Heusser, Commissioner DATE: NOvember 18, 2000 THRU: Blair Wondzell, P. I. Supervisor FROM: Lou Grima~, ~ ~- SUBJECT: Petroleum Inspector SVS tests ~ BPX C-pad Milne Point Unit Kuparuk River Field Saturday, November 18, 2000; I witneSsed the SVS tests on BPX C pad in the Milne Point of the Kuparuk River Field , This was the three-month test for this ~pad due to a 26% fail rate witnessed by Inspector Jeff Jones on 7/9/00. The wells did somewhat better this time although the fail rate of 13.6% was still above the 10% exPectable limit. Again, the gas injectors gave us the most trouble with two SSV's leaking. One Oil producer also had a leaking SSV. The pilots all tripped within limits. Well C-03 had a slight gas leak on the Tubing spoOl adapter, Larry Niles (MPU OI advisor) will pursue this with the wellhead manufacturer as to proper repair and report back to me. The wellhouses were all very clean' and it appears to be a high priority in the Milne facility. ~ SUMMARY: I witnessed the SVS test on Bpx C pad in the Milne Point Unit. 1 pad, 11 wells, 22 components, 3 failures. Wellhouse Inspections; 14 wellhouses, 1 failure (leaking T.s.A') Attachments: SVS MPU C pad 11-18-00 LG.XLS cc;, Niles/Shipley (MPU OI advisers) NON-CONFIDENTIAL SVS MPU C pad 11-t8-00 LG.doc Alaska Oil and Gas Conservation CommisSiOn Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Lou Grimaldi Submitted By: Lou Grimaldi Date: Field/Unit/Pad: K.R.F,/M.P.U./C pad Separator psi: LPS 140 HPS 11 / 18/00 Well Permit Separ Set L/P Test Test Test 'Date Oil, WAG, GINJ, Number Number PSI pSI Trip Code Code Code Passed GAS or CYCLE C-01 1811430 140 100 120 P P OIL C-02 1821940 C-03 1820500 140 100 105 P P OIL C-04 1821260 140 100 105 P 4 OIL C-05A 1842430 140 100 105 P P C-06 1842410 - C-07 1850020 140 100 110 P P OIL C-08 1850140 C-09 1850360 140 100 80! P P OIL I, C-13 1850670 · C-14 1850880 140 100 105 P P OIL C-15 1851030 C-17 1852630 ,c-2o 89o so . ,C-21 1940800 C-22A 1951980 140 100! t10 P e : OIL C-23 1960160 · C-25A 1960210 4000' 2000 2000 e 4 WAG C-26 1952060 C-28 1960290 4000~ 2000 2000 P P WAG C-36 1980010 C-39 1972480 C-19i 1852960 4000 2000 2000 P 4 WAG, ,,, Wells: 11 Components: 22 Failures: 3 FailUre Rate: 13.6%[] 9o Day Remarks: C-03 has gas leak on TUbing SpOol adapter, DeVelop plan for repair and report back. 11/20/00 Page 1 of 1 VOkltrl6.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation CommiSsion TO: THRU: DATE: July 12, 2000 Dan Seamount, Commissioner Blair Wondzell, P. I. Supervisor · Petroleum Ihsp~ct~r FROM: SUBJECT: ;Safety'Valve Tests Milne Point Unit .-B & C Pads July 9, 2000' I traveled to BP's Milne Point Field to witness safety Valve System tests on MPU B & C Pads. Testing was accomplished in a Safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hOld DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested,-~-I failure. 5,5% failure rate. MPU C Pad, 12 wells, 23 Components tested,-6 failures. 26% failure rate. ,- 21 well houses were inspected, no failures. Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc Alaska Oil and Gas Conservation C-ommission Safety Valve System Test Report Operator: BPX Operator Rep' Larry Niles AOGCC Rep: Jeff Jones Submitted By: Date: Field/Unit/Pad: Kuparuk River/MPU/C-Pad Separator psi: LPS 140 HPS 7/9/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE C-01 1811430 140 100 95 P P OIL C-03 '1820500 140 100 95 P P OIL C-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 P P OIL C-08 1850140 C-09 1850360 140 100 120 P 4 OIL C-13 1850670 '~i~-.': 1850880 140 100 100 P P OIL: C-15 1851030 . C-17 1852630 C-20 1890150 C-21 1940800i C-22A 1951980 140 100 95 P P OIL C-23 1960160 C-25~ 1960210 4000 2000 2000: P 4 WAG C-26 1952060 - C-28 1960290 4000 2000 2000! P 43 WAG C-36 1980010 C-39 1972480 C-02 1821940 4000 1900 P P WAG C-06 1842410 4000 1900 P 4 WAG Wells: 12 Components: 23 Failures: 6 Failure Rate: 26.0%~] 90 ~>ev Remarks: Wells # C-02 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap o-ring leaked. The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these items corrected. STATE OF ALASKA ALASKA,. .AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATION~-~' 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate I~ Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 52' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 839' NSL, 2134' WEL, Sec. 10, T13N, R10E, UM MPC-14 At top of productive interval 9. Permit Number / Approval No. 378' SNL, 1641' EWL, Sec. 14, T13N, R10E, UM ORI~I~ 10. APl Number At effective depth 50- 029-21344-00 440' SNL, 1910' EWL, Sec. 14, T13N, R10E, UM 11. Field and Pool At total depth Kuparuk River 454' SNL, 1970' EWL, Sec. 14, R13N, R10E, UM 12. Present well condition summary Total depth: measured 8833 feet Plugs (measured) true vertical 7305 feet ~:~0 ~! 0 2.~'~.~)"'"'" Effective depth: measured 8742 feet Junk (measured) true vertical 7239 feet .:&!~,~:~a Oil & G~s Co~qs, Casing Length Size Cemented ~"'~ch °r~t~e---- TVD Structural Conductor 80' 16" To surface 115' 115' Surface 5064' 9 5/8" 1375 sx PF 'E', 250 sx Class 'G' 5100' 4533' Intermediate Production 8788' 7" 273 sx Class 'G' 8822' 7297' Liner Perforation depth: measured 8327' - 8344', 8452' - 8457', 8481' - 8487', 8452' - 8487', 8576' - 8596', 8576' - 8610', 8610'- 8650' true vertical 6931' - 6943', 7024' - 7028', 7046' - 7050', 7024' - 7050', 7116' - 7131', 7116' - 7142', 7142' - 7171' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 8187' Packers and SSSV (type and measured depth) 7" HES Versatrive packer at 8724'; 7" BWD Sump packer at 8503' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 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: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerdeHubble-~.~/~. ~ Title TechnicalAssistantlll Date Prepared By Name/Number: Terrie Hubble, 564-4628 Submit In Duplicate~ Form 10-404 Rev. 06/15/88 Legal Well Name: MPC-14 Common Well Name: MPC-14~ Date: 10/14/2000 Event Name: WORKOVER Sta~: 10/12/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 4ES Rig Number: :Sub:'-: .':': -' -'. Date From - To Hours Task · Phase .... Code . .-....... . ;_ ; ;.- :_--- : _ 10/12/2000 18:00 - 00:00 6.00 MOB DECOMP RIG DOWN RIG ON MPU F~5 LOCATION 10/13/2000 00:00 - 03:00 3.00 RIGU DECOMP SPOT SUB, ~ISE AND SCOPE OUT DERRICK, SPOT AND BERM PITS, CONNECT ALL LINES 03:00 - 05:00 2.00 RIGU DECOMP SPOT AND BERM TIGER TANK, CONNECT ALL HARD LINES TO THE TREE, HCR VALVE TO THE ANNULUS 05:00 - 06:00 1.00 RIGU DECOMP TAKE ON 500 BBLS OF S~WATER TO THE PITS 06:00 - 07:30 1.50 PULL DECOMP WEIGHT UP S~ WATER TO 8.7 + PPG WITH SALT 07:30 - 09:30 2.00 PULL DECOMP CIRCUITED HOLE WITH 8.7+PPG BRINE AT 600 PSI ~3 BPM. PUMPED A TOTAL OF 400 BBLS. SHUT WELL IN FOR PRESSURE BUILD UP SITP 240 PSI SICP 360 PSI. 09:30 - 13:30 4.00 PULL DECOMP WEIGHT UP TO 8.9 + PPG AND CIRCU~TE WELL WITH 8.9 + GOING IN AND 8.9+ GOING OUT. SHUT WELL IN AND SITP 170 PSI SICP 220 PSI. 13:30 - 18:00 4.50 PULL DECOMP WEIGHT UP TO 9.6+ PPG AND CIRCUITED ALL THE WAY AROUND WITH 9.6+ GOING IN AND 9.6+ COMING OUT. WELL D~D 18:00 - 19:00 1.00 PULL DECOMP MONITORED WELL AND SET ~CV. TESTED TO 2500 PSI. 19:00 - 20:30 1.50 PULL DECOMP NIPPLE DOWN HCR & TREE 20:30 - 23:30 3.00 PULL DECOMP NIPPLE UP DSA,CUT OFF TOP OF PENAT~TOR, NIPPLE UP BOPE. 23:30 - 00:00 0.50 PULL DECOMP TEST BOPE 250/3500 PSI. BODY TEST WITNESS WAIVED BY JOHN SPAULDING OF AOGCC 10/14/2000 00:00 - 01:00 1.00 PULL DECOMP TEST BOPE 250/3500 PSI. BODY TEST WITNESS WAIVED BY JOHN SPAULDING OF AOGCC 01:00 - 02:30 1.50 PULL DECOMP PU LUB AND PULL ~C & LD LUB 02:30 - 04:30 2.00 PULL DECOMP 02:30-03:30 PU ~NDING JT./MU IN HANGE~BO LD SCREWS. PULL HNAGER TO THE FLOOR, TEST ESP CABLE. ~Y DOWN HANGER. FILLED HOLE WITH 25 BBLS TO FILL HOLE. 04:30 - 11:30 7.00 PULL DECOMP TRIP OUT OF THE HOLE WITH 2 7/8" TUBING, CABLE AND ESP. PUMP DOUBLE DISP~CEMENT WHILE PULLING OUT OF THE HOLE. SHOT FLUID LEVELS WITH FLUID AT 650' TO 500' FROM SURFACE. 11:30 - 13:00 1.50 PULL DECOMP CHECKAND ~Y DOWN ESP 13:00 - 14:00 1.00 PULL DECOMP CL~R AND CLaN RIG FLOOR. PREP TO RUN NEW ESP 14:00 - 18:00 4.00 RUNCO~I COMP INSTALL NEW REEL IN SPOOLER, PICK UP AND SERVICE ESP, TEST CABLE 18:00 - 21:00 3.00 RUNCO~I COMP TRIP IN THE HOLE WITH 2 7/8" TUBING AND ESP WITH ESP TO 2,800'. PHD WOULD NOT TEST 21:00 - 00:00 3.00 PULL COMP PULL OUT OF THE HOLE WITH 2 7/8" TUBING AND ESP TO 800' 10/15/2000 00:00 - 01:00 1.00 PULL COMP 00:00-01:00 PULL OUT OF THE HOLE WITH 2 7/8" TUBING AND ESP 01:00 - 03:00 2.00 PULL COMP TEST ESP AND ~YDOWN PUMP. CHNAGE PHD ON PUMP 03:00 - 08:30 5.50 RUNCO~! COMP CHANGE L~D ON MLE CABLE DUE TO KINK, PICK UP AND SERVICE ESP. TIE CABLE IN AND TEST 08:30 - 13:30 5.00 RUNCO~I COMP RIH WITH ESP TO 8,187'. 13:30 - 15:30 2.00 RUNCO~ COMP ~KE UP HANGER. M~SURE AND CUT CABLE, SPLICE FIELD CONNECTOR, TIE INTO HANGER AND TEST 15:30 - 16:00 0.50 RUNCO~I COMP ~ND AND LOCK DOWN HANGER, SET AND TEST ~CV TO 2,500 PSI. 16:00 - 19:30 3.50 WHSUR COMP D~IN STACK, BLOW DOWN LINES, REMOVE BELL NIPPLE, REMOVE ANNU~R, ND BOPE AND DOUBLE STUD ADAPTER Printed: 11/1/2000 1:01:05 PM Legal Well Name: MPC-14 Common Well Name: MPC-14 Spud Date: 10/14/2000 Event Name: WORKOVER Start: 10/12/2000 End: Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 4ES Rig Number: Date From-To Hours ~Task ~°Udbe ~a~ /.: ii~!J ':iiiil ~.~: ~.~es~ripti~°f0P~iati~J::~ ~::i?.'::::J'J:~i~i!:~ 10/15/2000 16:00 - 19:30 3.50 WHSUR COMP FLANGE. 19:30 - 22:30 3.00 WHSUR COMP NU TREE AND TEST VOID AND TREE TO 5000 PSI 22:30 - 23:00 0.50 WHSUR COMP PICK UP LUBRICATOR AND PULL TWCV/SET BPV AND LAYDOWN LUBRICATOR 23:00 - 23:59 0.98 WHSUR COMP SECURE WELL AND RIG DOWN CELLER. RIG RELEASED AT 23:59 HRS 10-15-2000 RECEIVED r:iO'"' ~'P """~ ¢ (j ,_ "'vt. ;J /"~.:,:ska Oil & ~s Cons. Co,~mi~sior~ Printed: 11/1/2000 1:01:05 PM STATE OF ALASKA ALASKA ~-,~.. AND GAS CONSERVATION CO,,_.,/IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well []Other Change Out ESP 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 839' NSL, 2134' WEL, Sec. 10, T13N, R10E, UM At top of productive interval 378' SNL, 1641' EWL, Sec. 14, T13N, R10E, UM At effective depth 440' SNL, 1910' EWL, Sec. 14, T13N, R10E, UM At total depth 454' SNL, 1970' EWL, Sec. 14, R13N, R10E, UM 12. Present well condition summary Total depth: measured 8833 feet true vertical 7305 feet Effective depth: measured 8742 feet true vertical 7239 feet 5. Type of well: 17(] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 52' 7. Unit or Property Name Milne Point Unit 8. Well Number Plugs (measured) Junk (measured) MPC-14 9. Permit Number / Approval No. 185-088 10. APl Number 50- 029-21344-00 11. Field and Pool Kuparuk River Casing Length Size Cemented MD Structural Conductor 80' 16" To surface 115' Surface 5064' 9 5/8" 1375 sx PF 'E', 250 sx Class 'G' 5100' Intermediate Production 8788' 7" 273 sx Class 'G' 8822' Liner TVD 115' 4533' 7297' Perforation depth: measured 8327' - 8344', 8452' - 8457', 8481' - 8487', 8452' - 8487', 8576' - 8596', 8576' - 8610', 8610' - 8650' true vertical 6931' - 6943', 7024' - 7028', 7046' - 7050', 7024' - 7050', 7116' - 7131', 7116' - 7142', 7142' - 7171' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 8206' Packers and SSSV (type and measured depth) 7" HES Versatrive packer at 8724'; 7" BWD Sump packer at 8503' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final Pressure R CEjVED FEB 03 2.000 Alaska 0il & Gas Cons. Comm~ Anchorage 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations J16. Status of well classifications as: [] Oil [] Gas [] Suspended Casing Pressure Tubing Pressure Service 7. I hereby certify that the foregoing i,s true and correct to the best of my knowledge Signed /[/~~ ~ Terrie Rubble_ Title Technical Assistant III Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Facility Date/Time 18 Jan 00 19 Jan 00 Progress Report M Pt C Pad Well MPC- 14 Page 1 Rig Nabors 4ES Date 24 January 00 08:00-16:00 08:00-16:00 16:00 16:00-20:00 16:00-20:00 20:00 20:00-21:00 20:00-21:00 21:00 21:00-06:00 21:00-00:30 00:30 00:30-04:00 04:00 04:00-06:00 06:00 06:00-08:00 06:00-08:00 08:00 08:00-09:00 08:00-09:00 09:00 09:00-11:00 09:00-11:00 11:00 11:00-14:00 11:00-14:00 14:00 14:00-17:30 14:00-17:30 Duration 8 hr 8 hr 4 hr 4 hr 1 hr 1 hr 9 hr 3-1/2 hr 3-1/2 hr 2 hr 2 hr 2 hr 1 hr 1 hr 2 hr 2 hr 3 hr 3 hr 3-1/2 hr 3-1/2 hr Activity Move rig Rig moved 100.00 % move rig from MPE-04 & raise & scope derrick & level & safe out equipment. At well location - Slot Derrick management Rigged up High pressure lines Set Tiger tank & rig lines to tree & rig hcr valve toannulus. Equipment work completed Wellhead work Retrieved Hanger plug Rig lubricator & pull bpv & Tbg. 430 psi. & Annulus 800 psi. & test lines to 3000 psi. Equipment work completed Well control Circulated closed in well at 8030.0 ft circ well bore with 9.0 ppg. brine & monitor same for 10 min well ont. to flow on both sides Inital sitp=70 psi. & annulus 130 psi. before monitoring flow back. Hole displaced with Brine - 125.00 % displaced Circulated closed in well at 8083.0 ft Mix & pump 9.2 PPG> brine. & monitor well for 1/ hour & well flowed back 23-bbl. & tbg. & annulus O & well quit flowing at floor height & when attempt to set twc well flowing through tbg. & decision to raise wt to 9.4 ppg. Well always taking fluid due to Hole displaced with Brine - 125.00 % displaced well takes fluid due to ecd. Circulated closed in well at 8131.0 ft circ. well bore with 9.4 ppg. fluid at reduced pump rate to minimize ecd while displacing 9.2 ppg. with 9.4 (Well is taking fluid while pumping and when shut in with 2400 strokes into killing tbg. 10-psi. & annulus 30 psi. Stopped: To hold safety meeting crew change. Well control (cont...) Circulated closed in well at 8131.0 ft 9.4 brine to surface sut down & monitor well static. Hole displaced with Brine - 100.00 % displaced Wellhead work Installed Hanger plug Equipment work completed Wellhead work Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack F[.S 63 000 Nas~ OH & Gas Cons. C0mmissh Anchorage Facility M Pt C Pad Progress Report Well MPC-14 Page 2 Rig Nabors 4ES Date 24 January 00 Date/Time 20 Jan 00 17:30 17:30-18:30 17:30-18:30 18:30 18:30-04:30 18:30-19:30 19:30 19:30-04:30 04:30 04:30-06:00 04:30-06:00 06:00 06:00-16:00 06:00-13:00 13:00 13:00-16:00 16:00 16:00-16:30 16:00-16:30 16:30 16:30-18:00 16:30-18:00 18:00 18:00-19:00 18:00-19:00 19:00 19:00-20:00 19:00-20:00 20:00 20:00-20:30 20:00-20:30 20:30 20:30-06:00 20:30-22:00 22:00 Duration 1 hr 1 hr lOhr 1 hr 9 hr 1-1/2 hr 1-1/2 hr lOhr 7 hr 3 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 1 hr 1 hr 1 hr 1/2 hr 1/2 hr 9-1/2 hr 1-1/2 hr Activity Pressure test completed successfully - 3500.000 psi Wellhead work Removed Hanger plug Equipment work completed Pull Single completion, 2-7/8in O.D. Removed Tubing hanger Equipment work completed Pulled Tubing in stands to 0.0 ft poh & lay dn esp assy Completed operations Run Single completion, 2-7/8in O.D. Ran Tubing in stands to 500.0 ft Mu esp assy & dh with same. Stopped: To hold safety meeting Run Single completion, 2-7/8in O.D. (cont...) Ran Tubing in stands to 8205.0 ft Completed run with ESP to 8205.0 ft Rigged up Tubing hanger Install hanger & landing jt. & make esp connector to hanger. & land hanger & rilds. Equipment work completed Wellhead work Installed Hanger plug Equipment work completed Nipple down BOP stack Rigged down BOP stack Equipment work completed Wellhead work Installed Xmas tree Equipment work completed Test well control equipment Tested Xmas tree Pressure test completed successfully - 5000.000 psi Wellhead work Installed Hanger plug Equipment work completed Fluid system Freeze protect well - 80.000 bbl of Diesel Completed operations RECEIVED FEB 6,'.3 ?..000 0il & Gas Cons. C0mmi~ql0n Anchorage STATE OF ALASKA ALASK~:)IL AND GAS CONSERVATION c~MMISSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate []Plugging []Perforate []Pull Tubing [--] Alter Casing [] Repair Well []Other ESP Changeout 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 839' NSL, 2134' WEL, Sec. 10, T13N, R10E, UM At top of productive interval 378' SNL, 3639' WEL, Sec. 14, T13N, R10E, UM At effective depth 440' SNL, 898' WEL, Sec. 14, T13N, R10E, UM At total depth 454' SNL, 3306' WEL, Sec. 14, R13N, R10E, UM 12. Present well condition summary Total depth: measured 8833' feet Plugs (measured) true vertical 7305' feet Effective depth: measured 8742' feet Junk (measured) true vertical 7234' feet 5. Type of well: I~ Development [] Exploratory [] Stratigraphic [] Service !6. Datum Elevation (DF or KBE) KBE = 59' 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-14 9. Permit Number / Approval No. 85-88 10. APl Number 50- 029-21344 11. Field and Pool Kuparuk River uu;,i 08 t99, Alaska 0il & Gas Cons. C0r Anchorage Casing Length Size Cemented MD 'r'VD Structural Conductor 80' 16" To surface 115' 115' Surface 5064' 9 5/8" 1375 sx PF 'E' & 250 sx 'G' 5100' 4533' Intermediate Production 8788' 7" 273 sx Class 'G' 8822' 7296' Liner Perforation depth: measured 8327'-8344', 8452'-8457', 8481'-8487', 8452'-8487', 8576'-8596', 8576'-8610', 8610'-8650' true vertical 6930'-6943', 7024'-7027', 7045'-7050', 7024'-7050', 7115'-7130', 7115'-7141', 7141'-7170' Tubing (size, grade, and measured depth) 3 1/2" 6.8# L-80 to 8131' Packers and SSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15, Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 06/15/88 D missie ' '-"~ ~ ' ~ Date Submit In Duplica~ Facility Date/Time 29 Apr 98 30 Apr 98 01 May 98 02 May 98 03 May 98 04 May 98 05 May 98 Progress Report M Pt C Pad Well MPC-14 Page 1 Rig Nabors 5S Date 11 May 98 06:00-12:00 12:00-18:00 18:00-21:00 21:00-23:45 23:45-03:00 03:00-06:00 06:00-09:00 09:00-09:30 09:30-10:00 10:00-11:30 11:30-14:00 14:00-15:00 15:00-18:00 18:00-01:00 01:00-02:00 02:00-04:30 04:30-06:00 06:00-12:00 12:00-13:00 13:00-17:00 17:00-18:00 18:00-23:45 23:45-06:00 06:00-07:30 07:30-11:00 11:00-18:00 18:00-02:00 02:00-06:00 06:00-18:00 18:00-22:00 22:00-23:30 23:30-02:00 02:00-06:00 06:00-08:30 08:30-15:00 15:00-15:30 15:30-17:00 17:00-18:00 18:00-19:00 19:00-19:30 19:30-21:00 21:00-22:00 22:00-23:00 23:00-00:00 00:00-00:30 00:30-03:00 03:00-06:00 Duration 6hr 6hr 3hr 2-3/4 hr 3-1/4 hr 3hr 3hr 1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr lhr 3hr 7hr lhr 2-1/2 hr 1-1/2 hr 6hr lhr 4hr lhr 5-3/4 hr 6-1/4 hr 1-1/2 hr 3-1/2 hr 7hr 8hr 4hr 12hr 4hr 1-1/2 hr 2-1/2 hr 4hr 2-1/2 hr 6-1/2 hr 1/2 hr 1-1/2 hr lhr lhr 1/2 hr 1-1/2 hr lhr lhr lhr 1/2 hr 2-1/2 hr 3hr Activity Rig moved 100.00 % Rigged up Draw works Rigged up Draw works Removed Hanger plug Fill pits with Brine Circulated at 8116.0 ft Circulated at 8116.0 ft Rigged up Hanger plug Removed Xmas tree Rigged up All rams Tested All rams Removed Hanger plug Pulled Tubing in stands to 1550.0 fi Pulled Tubing in stands to 8179.0 ft Laid down 0.0 ft of Tubing Conducted slickline operations on Slickline equipment - Tool run Ran Tubing in stands to 1000.0 fi Ran Tubing in stands to 8175.0 ft Ran Tubing to 8634.0 ft (2-7/8in OD) Ran Tubing to 8730.0 ft (2-7/8in OD) Pulled Tubing in stands to 8490.0 ft Laid down 7980.0 ft of Tubing Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Installed Production packer Installed Production packer Rigged up sub-surface equipment - Production packer Ran Tubing in stands to 4650.0 ft Ran Tubing in stands to 8503.0 ft Space out tubulars Circulated at 8200.0 ft Pulled Tubing in stands to 0.0 ft Ran Tubing in stands to 0.0 ft Ran Tubing in stands to 8145.0 ft Installed Tubing hanger Ran Tubing in stands to 8145.0 ft Installed Tubing hanger Installed Hanger plug Installed All tree valves Rigged down All rams Installed Xmas tree Installed All tree annulus valves Installed Xmas tree Installed Hanger plug Freeze protect well - 10.000 bbl of Diesel Rig moved 0.00 % STATE OF ALASKA ALAsKA'OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate []Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other ESP Changeout 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 839' NSL, 2134' WEL, Sec. 10, T13N, R10E, UM At top of productive interval 378' SNL, 1641' EWL, Sec. 14, T13N, R10E, UM At effective depth 440' SNL, 1910' EWL, Sec. 14, T13N, R10E, UM At total depth 454' SNL, 1970' EWL, Sec. 14, R13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 59' 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-14 9. Permit Number / Approval No. 85-88 94-289 10. APl Number 50-029-21344 11. Field and Pool Kuparuk River 12. Present well condition summary Total depth: measured 8833' feet true vertical 7305' feet Effective depth: measured 8742' feet true vertical 7234' feet Casing Length Structural Conductor Surface Intermediate Production Liner Plugs(measured) ORIGINAL Junk (measured) Size Cemented MD TVD 80' 16" To surface 115' 115' 5064' 9 5/8" 1375 sx PF 'E'& 250 sx 'G' 5100' 4533' 8788' 7" 273 sx Class 'G' 8822' 7296' Perforation depth: measured 8327'~8344'~8452'~8457'~8481'~8487'~8452~~8487'~8576'~8596'~8576~~861~'~861~~~865~~ true vertical 693~'~6943~~7~24'~7~27`~7~45'~7~5~~~7~24~~7~5~'~7115'~713~'~7115'~7141'~7141'~717~' Tubing (size, grade, and measured depth) 3 1/2" 6.8# L-80 to 8179' Packers and SSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure - /~,PR 2 0 )998 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil- Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord ,~,_ ~' ~ Title Engineering Supervisor Date Prepared By Name/Number: Mary Youngers 564-5242 Form 10-404 Rev. 06/15/88 Submit In Duplicate~ SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPC-14 Rig Name: N-4ES AFE# 339016 Accept Date: 7/02/96 Spud Date: - Release Date: 7/08/96 JULY 02, 1996 RIG ACCEPTED @ 0200 HRS. SPOT, BERM RIG RAISE & SCOPE DERRICK REPAIR 3" FLANGE ON PUMP DISCHARGE LINE. RU HARD LINES TO COMP TREE & FLOWLINE PULL BPV 3250 PSI ON TUBING TEST HARD LINES TO 3500 PSI LOAD PITS W/11.5 PPG BRINE. JULY 03, 1996 ATTEMPTED TO BLEED DOWN WELL TO PANT UNABLE TO HANDLE PRESSURE OR VOLUME BLED PRESSURE THROUGH GAS BUSTER FOR AN HOUR BLED TUBING PRESSURE FROM 3290-3130 PSI & CASING PRESSURE FROM 3270-3060 PSI SHUT IN & MONITOR PRESSURE. BULLHEADED 95 BBLS OF 11.6 BRINE DOWN TUBING @ 5 BPM FINAL INJECTION PRESSURE 680 PSI SHUT IN WELL & MONITOR PRESSURE. TUBING PRESSURE 0 & CASING PRESSURE 3260 PSI CIRC OUT THROUGH CAS BUSTER @ 3.5 BPM W/INITIAL TBG PRESSURE OF 350 PSI SHIT IN AFTER PUMPING 120 BBLS TUBING ON VACCUM & 2450 PSI ON CASING BLEED OFF CASING PRESSURE IN 100 PSI STAGES FROM 2450 TO 1940 PSI MONITOR PRESSURE WHILE WAITING ON MORE BRINE SPOT & PUMP 43 BBLS LIQUID CASING PILL IN PERFS CONTINUED KILLING WELL WI11.6 PPG BRINE & VENTING GAS TO TIGER TANK HAD FLUID RETURNS TO SURFACE, SHUT WELL IN & MONITOR FOR 30 MINUTES TUBING 0 PSI CASING 760 PSI JUKK WELL CIRC BACK TO PITS THROUGH GAS BUSTER @ 67 SPM 650#11.6 PPG BRINE RETURNS W/OIL & PRODUCED WATER SHUT WELL IN TUBING PRESSURE 80 PSI CASING 20 PSI CIRC & CONDITION FLUID TO MAINTAIN 11.6 PPG FLUID WEIGHT @ 66 SPM @ 650 PSI MONTIOR WELL; FLUID LOSS IN 30 MINUTES 1 BBL FLUID LOSS WHILE CIRCLUATING - 16 BBLS INSTALL.TWC ND COMPLETION TREE & NU BOP'S. JULY O4, 1996 FINISHED NU BOPE CHANGED RAMS TO 3 ~,~" TEST ALL RAMS & VALVES TO 250/5000 PSI TEST ANNULAR TO 250/3000 PSI WITNESS TO TEST WAS WAIVED BY AOGCC-BOBBY FOSTER. PULL TWC RU LANDING JOINT BACK OUT LOCK DOWN SCREWS UNSEAT HANGER CIRCULATED BU @ 4BPM @ 500 PSI SPOTTED LUQUID CASING PILL OUTSIDE TUBING LOST 16 BBLS DURING CIRCULATING OPERATION. LD 2 7/8" TUBING APPROXIMATELY 115" OF TUBING LD ESP LEFT 7 FLAT BANDS IN HOLE, HOLE TOOK 36 BBLS BRINE ON TOOH. RU CAMCO RIH W/3.5" MAGNET TO 8575' TAGGED FILL POOH W/MAGNET NO RECOVERY. STRAP & MU CLEAN OUT ASSEMBLY. Page JULY O5, 1996 RIG SERVICE SET WEAR RING MU BHA #1 SPACE OUT CASING SCRAPPER & TIH W/3.5" TUBING TAG FILL @ 8573' REVERSE & WASH F/8573'-8595' PUMPING 3-4 BPM @ 500-700 PSI HAD FLUID LOSSES OF 4-18 BBL/HR WHILE REVERSING UNABLE TO WASH PAST 8595'. PULLED 5 STANDS TO 8120 SLIP 42' DRILL LINE POOH LD 3.5" TUBING & CASING SCRAPPER. CLEAN OUT BOOT BASKETS & RIG UP FLOOR TO RUN 3.5 DRILL PIPE RECOVERED ONE METAL BAND STUCK IN BOTTOM OF MILL LOAD 3.5" DRILL PIPE SHED RIH W/BHA #2 PICKING UP 3.5" DRILL PIPE, DRIFT AND SLM. JULY 06, 1996 RIG SERVICE CONTINUED RIH PICKING UP 3.5" DRILL PIPE, DRIFT & SLM TAGGED FILL @ 8595' WASH & REAM W/KELLY FROM 8595' TO KD @ 8619'. TIGHT SPOT IN CASING @ 8595' WORKED THROUGH TIGHT SPOT, SET BACK KELLY & A'I'TEMPED TO REVERSE DOWN TO 8619' UNABLE TO GET PAST 8595' PU KELLY & ROTATED THROUGH TIGHT SPOT @ 8595' & CONTINUED IN HOLE TO 8619' REVERSE CIRC DRILL PIPE VOLUME UP WITH KELLY PIPE STUCK W/KELLY DOWN. WORK STUCK PIPE @ 8619' CIRCULATED AROUND HIGH VIS SWEEP UNABLE TO WORK PIPE FREE PUT 2 WRAPS LEFT HAND TORQUE IN STRING & WORK DOWN HOLE WORKING PIPE TO UP WEIGHT 190K SLACK OFF 95K PUT TOTAL OF 16 ROUNDS IN STRING BEFORE PIPE BACKED OFF PU WEIGHT 53k POOH CHECKING EACH CONNECTION FOR TORQUE BACKED OF 3196' TIH W/3.5" DRILL PIPE SPACE OUT & TAG FISH @ 3196' SCREWED INTO FISH & PUT WORKED TORQUE DOWN TO TOP OF FISH. PICKED UP TO ROTATING STRING WEIGHT OF 108K & WORK 8RD OF TORQUE DOWN STRING PU ATLAS WIRELINE, RIH W/400 GRAIN/FT STRING SHOT & CCL PUT 8RD OF TORQUE TO LEFT & WORKED TORQUE DOWNHOLE, FIRED STRING SHOT & BACKED OFF @ 8561' POOH W/WIRELINE & RIGGED DOWN ATLAS WIRELINE. TOOH CHECKING EACH CONNECTION. JULY 07, 1997 CONTINUED TOOH, RECOVERED 90 STANDS & DOUBLE, LD BO'I'TOM SHOT COLLAR. RIG SERVICE STRAP & MU FTA #3 (SCEW IN SUB, 1 DP, BJ, OJ, 8DCS, A J) TIH TAG TOP OF FISH @ 8575' ROTATE TO RIGHT & SCREWED INTO FISH, WORKED 8 TURNS INTO DRILL PIPE, JARRED DOWN ON FISH FOR 15 MINUTES W/NO SUCCESS JSAR UP W/63K OVER & 88K OVER & FISH CAME FREE. POOH W/FISH 100% RECOVERY CLEAR FLOOR & LD BOOT BASKETS. MU CLEAN UP ASSEMBLY LD 5 DRILL COLLARS, START IN HOLE WI3.5" DRILL PIPE CUT DRILL INE FINISHED RUNNING IN HOLE W/3.5 DRILL PIPE TAGGED FILL @ 8613' REVERSE CIRCULATED && WASHED F/8613'-8720' PBTD (4ES KB) REVERSED OUT FORMATION SAND & CARBOLITE @ 3.5 BPM @ 500 PSI LOSS RATES OF 12- 30 BBL PER HOUR LOSS RATE. LD 17 JOINTS OF 3.5" DRILL PIPE TO 8213' PUMPED 25 BBLS XANVIS PILL SPACER FOLLOWED BY CLEAN FILTERED 11.6 PPG BRINE @ 6 BPM @ 1600 PSI JET OUT & CLEAN OUT CARBOLITE & FORMATION SAND FROM FLOWLINE & MUD TROUGHS. Page 2 JULY 08, 1996 RIG SERVICE CIRCULATED TO BALACE WELL POOH LD 3.5" DRILL PIPE & BHA. RD FLOOR, FU & FLUSHED BOP STACK. PULLED WEAR RING SET TEST PLUG INSTALLED 2 7/8" TUBING RU CENTRALIFT & ESP CABLE MU & SERGVICE ESP. CENTRALIFT PUMP COUPLING DAMAGED IN SHIPMENT, WAITING ON REPLACEMENT FINIFHED SERVICE & MU OF ESP. RIH W/2 7/8"ESP COMPLETION @ 7080'. JULY 09, 1996 RIG SERVICE CONTINUED TIH W/2 7/8" COMPLETION ASSY MU HANGER & LANDING JOINT MAKE PIGTAIL SPLICE LAND TUBING HANGER PU WT 68K SO WT 50K RUN IN LOCK DOWN SCREWS LD LANDING JOINT SET TWC. ND BOPS CLEAN PITS NU ADAPTER FLANGE & TREE TEST HANGER SEALS & TREE @ 5000 PSI CHECKED ESP -OK RU HARDLINE TO TREE PULL TWC TEST LINES TO 2000 PSI TAKE ON SOURCE WATER NTO RIG TANKS. MIX 20 BBL XANVIS PILL PUMPED 20 BBL XANVIS PILL AHEAD & DISPLACED 11.6 PPG BRINE FROM WELL W/CLEAN SOURCE WATER DISPLACED WELL DOWN TUBING @ MAXIMUM RATE OF 1 BPM @ 2500 PSI RECOVERED APPROXIMATELY 275 BBLS OF 11.6 PPG BRINE SET BPV FREEZE PROTECTED ANNULUS W/70 BBLS DIESEL & TUBING W/15 BBLS DIESEL SECURE TREE & CELLAR. RELEASE RIG @ 2400 HRS. Page BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MPU C-14 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 05/18/95 01:00 SPUD: RELEASE: 05/22/95 03:00 OPERATION: DRLG RIG: WO/C RIG: NABORS 4ES 05/18/95 ( 1) TD: 8822 PB: 8742 PREPARE TO KILL WELL MW: 0.0 MOVE RIG FROM C-02 TO C-14 AND RIG UP SAME. BERM UP. TAKE ON SOURCE H20 AND HEAT SAME RIGGING LINES TO TREE AND TEST. 05/19/95 (2) TD: 8833 PB: 8742 05/20/95 (3) TD: 8833 PB: 8742 05/21/95 ( 4) TD: 8833 PB: 8742 05/22/95 (5) TD: 8833 PB: 8742 05/23/95 (6) TD: 8833 PB: 8742 PULLING COMPLETION MW: 0.0 TEST SURFACE LINES AND HEAT SOURCE WATER. KILL WELL W/ 8.3 PPG SOURCE WATER. MONITOR WELL. NIPPLE DOWN TREE AND NIPPLE UP BOPS. PULL TWO WAY CHECK. PULL HGR TO FLOOR AND CK ESP CABLE AND LAY DOWN SAME. CIRC BOTTOMS UP. RIH W/ FTA #1 MW: 0.0 SPT 40 BBL XANVIS PILL. POH W/ ESP COMPLETION LAY DOWN SSSV AND 3-GLM + 7" OTIS DHR PKR. STRAP AND DRIFT TBG. REC 536 PREFORMED BANDS + 44 FLAT BANDS + 8 FLAT GUARDS. CLEAN FLOOR AND RIG UP TO PICK UP FTA #1 AND 3 1/2" DRILL PIPE TO PKR. PUMPING XANVIS SWEEP MW: 0.0 TAG PKR AT 8190' 4ES KB BREAK CIRC MILL ON PKR. FELL FREE. CBU. SHASE PKR TO 8596'. MONITOR WELL AND POH. CLEAN BOOT BASKETS AND MU FTA $2 AND RIH. CUT DRLG LINE. CONTINUE RIH TO 8596'. CREAK CIRC AND WASH OVER PKR AND LATCH. CIRC BOTTOMS UP. POH. LAY DOWN FTA $2 AND BAKER PKR AND SCREEN ASSY. MAKE UP BHA $3 AND RIH TO 8624'. WASH FILL F/ 8624 - 8722' SPLICE CABLE AT HANGER MW: 0.0 CIRC HI-VIS SWEEP @ 8722' POH LAYING DOWN 3 1/2" DRILL PIPE. PULL WEAR RINGS AND RIG UP TO RUN ESP COMPLETION. MU ESP AND CHECK OUT AND RIH W/ SAME ON 6 JTS 2 7/8" 6.55 L-80 8RD EUE TBG + 251 JTS 3 1/2" 9.25 L-80 BUTT TBG. MU FMC HANGER AND INSTALL ESP PENETRATOR AND SPLICE CABLE. RELEASE RIG MW: 0.0 CONTINUE TO SPLICE ESP CABLE AT HANGER AND CHECK OUT SAME. LAND TBG. RILDS. NIPPLE DOWN BOPS. NIPPLE UP ADAPT. FLG AND TREE, TEST SAME. RIG LUBRICATOR AND PULL TWC AND FREEZE PROTECT WELL WITH 65 BBL DIESEL IN ANNULUS AND 20 BBL DIESEL IN TBG. SET BPV AND SECURE TREE AND CELLAR AREA. SIGNATURE: (drilling superintendent) DATE: -. '~ STATE OF ALASKA '-,.. A~ OIL AND GAS CONSERVATION COMMISo--~oN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing, x Alter casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 839' NSL, 2134' WEL, SEC. 10, T13N, RIOE At top of productive interval 378' SNL, 3639' WEL, SEC. 14, T13N, RIOE At effective depth At total depth 454' SNL, 3306' WEL, SEC. 14, T13N, RIOE Repair well Other 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 59' feet 7. Unit or Property name Milne Point Unit 8. Well number MPC-14 9. Permit number/approval number 85-88/94-289 10. APl number 50- O29-21344 11. Field/Pool Kuparuk River 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 5064' Intermediate Production 8788' Liner Perforation depth: 8833 feet 7305 feet 8742 feet 7234 feet Size Plugs (measured) Junk (measured) ORIGINAL Cemented Measured depth True vertical depth 16" To surface 115' 115' 9-5/8" 1375 sx PF "E" & 5100' 4533' 250 sx "G" 7" 273 sx Class "G" 8822' 7296' measured 8327'-8344', 8452'-8487', 8576'-8610', 8610'-8650' true vertical 6930'-6943', 7020'-7050', 7115'-7140; 7141'-7170' Tubing (size, grade, and measured depth) 2- 7/8" L-80 tubing to 8153' MD w/ ESP at bottom; 3-1/2", L-80 tubing tail to 8227' MD Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary HES TRSV @ 593' MD; HES 'DHR' Packer @ 616' MD; Baker model "FB-I' Packer w/screen assembly @ 8199' MD R£C£iV D Intervals treated (measured) Treatment description including volumes used and final pressure NOV 1 7 1994 0ii & Oas Cons. Commission 14. Prior to well operation Subsequent to operation Re.Dresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of~ell Operations x Oil x Gas Suspended 17. I hereby ce~_~h/at~h~oing is tr~ and correct to the best of my knowledge. Signed /~ (~' ~. TitleDrillin~En~inoerSupervisOr Service SUBMIT IN DUPLIO'ATE ~ Form 10-404 Rev 06/15/88 MP C-14 W/O #2 10/17/94 8,742' (PBD) MOVE RIG FROM C-09 TO C-14 AND SPOT OVER WELL. RAISING DERRICK. 10/18/94 8,742' (PBD) RIG HARD LINE TO TRASH TANK FROM ANNULUS. RIG LUBRICATOR PULL BPV AND SET TWO WAY CK. RIG HARD LINE TO WING VALVES AND TREE. UNABLE TO READ TBG DUE TO X PLUG SET IN NIPPLE AT 595'. BLEED ANNULUS THROUGH CHOKE TO TRASH TANK. RETURNS DIESEL- BLEED A TOTAL OF 34 BBL SHUT DOWN AND READ STATIC PRESSURE. ANNULAR VENT APPEARS TO BE OPEN. DECISION MADE TO PULL TWO WAY CHECK AND SHEAR PLUG AND ATTEMPT TO CIRC WELL CONVENTIONALLY TO KILL. WAIT ON LUBRICATOR AND ADAPTER FLANGE FOR TREE TO PULL TWO WAY CHECK. RIG TO ANNULUS AND BULL HEAD 220 BBL OF 10.1 PPG BRINE TO PERFS. OBSERVE WELL AND PRESSURE DECREASE TO FORMATION. NIPPLE DOWN TREE AND NIPPLE UP BOP. TEST BLIND RAMS AND ALL FLANGES AND CHOKE MANIFOLD. WOULD NOT BLEED BACK PAST 900# 2 WAY CHECK LEAKING. BLEED 5 BBL FROM TBG DIESEL. SHUT IN 900 PSI ALLOW TBG TO FLOW TO TRASH TANK WHILE PUMPING DOWN ANNULUS.. GAS AND CRUDE OIL RETURNS. CRUDE THROUGH TUBING. SHUT DOWN AND OBSERVE WELL. STILL FLOWING GAS. A'I-rEMPT TO PUMP DOWN TBG. FLUID PUMPED. FLOW INFLUX FROM TBG WHILE PUMPING DOWN ANNULUS. TAKING GAS AND OIL RETURNS TO TRASH TANK. 10/19/94 8,742' (PBD) PUMP DOWN ANNULUS W/10.1 PPG BRINE 1/2 BPM ATTEMPT TO FLUID PACK TBG W/SAME TAKING OIL AND GAS INFLUX TO THRASH TANK THROUGH CK VALVE WITH LEAK. PUMP 142 BBL BRINE TOOK 26 BBL CRUDE. PUMP 40 BBL XANVIS PILL DOWN ANNULUS TAKING RETURNS TO THRASH TANK. REC TOTAL 6 BBL CRUDE. PSI ON 'TWC TO 4000 PSI AND HOLD INCREASE TO 5000 PSI, HOLD. BLEED OFF THE THRASH TANK. CONTINUE BLEED OIL AND GAS FROM TBG. CONTINUE TO PSI TBG AND BLEED BACK ATTEMPT TO LUBRICATE TO PULL TWC AND REPLACE WITH NEW. PU AND RIG UP LUBRICATOR TO PULL TWC. 10/20/94 8,822' RU LUBRICATOR TO HANGER. TEST. PULL TWC. SHEAR WL PLUG. BULLHEAD 81 BBL'S 10.1# BRINE DOWN TBG. MONITOR WELL. XO TWC. BREAK LUBRICATOR AND PULL BACK. TEST BOPE, ANNULAR. MU LUBRICATOR, TEST. OK. PULL TWC. RD LUBRICATOR. BLED GAS OFF ANNULUS. MU LANDING JT. BOLDS. LOAD TBG AND ANNULUS. UNSEAT PKR W/49K OVER STRING WT. CIRC WELL TO 10.1 NACL BRINE, DOWN TBG. MONITOR WELL. PULL HANGER TO FLOOR. LD SAME. POH W/3.4" TBG STANDING BACK. DRIFT AND SLM. LD PKR, SSSV, AND GLM. 10/21/94 8,822' SERVICE RIG. FINISH POH W/ESP COMPLETION. DART VALVE TO PUMP FULL OF FRAC SAND. APPEARED PUMP SHAFT WAS PARTED. LD ESP. RECOVERED 547 BANDS AND 9 FLAT GUARDS. SET WEAR RING. CLEAR RIG FLOOR. MU MULE SHOE AND 1 JT 1.25" CS HYDRIL ON 3.5" TBG. PU 16 JTS 3.5". WASH LAST 3 JTS DOWN. TAG UP @8304'. UNABLE TO MAINTAIN OVER 2.5 BPM RETURNS. REVERSED XANVIS SWEEP AROUND. STILL HAD MINIMAL SAND W/PARTIAL RETURNS. POH. SLM. 10/22/94 8,822' SERVICE RIG. FINISH POH W/1.25" MULE SHOE. SHOE HAD CUT SHOWING SET DOWN ON TOP OF PACKER. A FEW PIECES OF SS BAND INSIDE SHOE. EVALUATE OPTIONS W/TOWN. RIH W/5 STDS 3.5" DP. LD SAME. LOAD PIPE SHED W/3.5" 15.5# DP AND 4.75" DC. SLM. MU FTA #1. JET BASKET, ETC. RIH PICKING UP 3.5" DP TO 8262'. CBU. ESTABLISH RATE W/52 SPM @ 700 PSI. DROP BALL F/JET BASKET. BALL SEATED. CIRC DOWN. TAG PACKER @ 8275' DPM. MONITOR WELL, OK. POH. 10/23/94 8,822' SERVICE RIG. FINISH POH W/FTA #1. RECOVERED 5 BANDS. LD BASKET. MU FTA #2. START RIH. SLIP 42' DRLG LINE. FINISH RIH. BURN OVER PACKER F/8276 - 8278.5' DPM. PACKER DROPPED. PU SINGLES. PUSH PACKER TO 8496'. CBU. POH. RECOVERED PKR AND SCREEN, WEDGED IN BURN SHOE. SCREEN HAD 1.25" X .75" HOLE 10" UP F/BOTTOM OF SCREEN. SCREEN OVAL IN SEVERAL PLACES. LD FISH AND FTA #2. MU FTA #3. RIH. TAG FILL @ 8522'. REVERSE CIRC FILL F/8522 - 8566'. PUMP XANVIS SWEEP WHILE REVERSING. REVERSE CBU TO CLEAR DP. 10/24/94 8,822' CONTINUE REVERSE FILL F/8566 - 8628'. GRADUALLY LOST RETURNS LAST 1/2 HOUR. WASH UP TO 8581'. REVERSE XANVIS SWEEPS. UNABLE TO REGAIN RETURNS'. BREAK CIRC DOWN DP. WASH F/8581 - 8717'. HARD SET DOWN. REVERSING XANVIS SWEEPS. STARTED GETTING FULL RETURNS. INCREASE RATE TO 4.5 BPM W/1400 PSI. PUMPED 2 ADDITIONAL 40 BBL SWEEPS WHILE RECIPROCATING PIPE. WELL UNLOADED LARGE AMOUNT OF SAND ON 1ST SWEEP. SEEMED TO CLEAN UP GOOD AFTER 2ND SWEEP. MONITOR WELL. SLIGHT FLOW FP AND ANNULUS. DIED AFTER 20 MIN. LD 3.5" DP. 10/25/94 8,822' FINISH LD DP, DC, & BHA. PULL WEAR RING. ND FLOW LINE AND RISER. NU SHOOTING FLANGE. RU ATLAS WIRELINE. WO LUBRICATOR PUMP IN SUB. RU LUBRICATOR AND PUMP IN SUB. TEST, OK. MADE 4 JB/GR RUNS TO 8300'. FIRST 2 RUNS RECOVERED SMALL AMOUNTS OF METAL AND SS BAND PIECES. LAST 2 RUNS WERE CLEAN. MU BAKER 'FB-I' PKR, 12 GAUGE SCREEN, 'X'-NIPPLE W/PXN PLUG, & WLEG. RIH W/SAME. TIE IN TO SOS DIL/SFL/GR DATED 5/18/85. SET PKR @ 8202'. POH. RD ATLAS. ND SHOOTING FLANGE. NU RISER AND FLOWLINE. RU CENTRILIFT SPOOLING UNIT AND CLEAR FLOOR. MU CENTRILIFT EST, SERVICE, AND TEST. START RIH W/ESP COMPLETION. 10/26/94 8,822' SERVICE RIG. RUNNING ESP COMPLETION. PU HES PKR W/'X' NIPPLE & RHC PLUG. MAKE ESP SPLICE @ PACKER. PU TRSV & CONTROL LINE. TEST, OK. FINISH RIH W/TBG. MAKE UP HANGER AND LANDING JOINT. MAKE PIG-TAIL SPLICE @ HANGER. MU CONTROL LINE TO HANGER. TEST, OK. LAND TBG. RILDS. CLOSE TRSV. LD LANDING JOINT. ND BOP. NU TREE. 10/27/94 8,822' NU ADAPTER FLANGE. TEST HANGER, OK. NU TREE. PULL BPV. SET TWC. TEST TREE, OK. PULL TWC. PUMP OPEN SSSV. FREEZE PROTECT ANNULUS TO 2000' W/58 BBL'S 60/40 METHANOL. FREEZE PROTECT TBG TO 2000' W/19 BBL'S DIESEL. DROP BALL. SET PACKER. TEST. RHC PLUG LEAKING. TEST TRSV TO 1000 PSI DIFFERENTIAL. TEST ANNULUS, OK. SET BPV AND SECURE WELLHEAD. CLEAN PITS. RELEASE RIG @ 1700 H R'S ON 10/26/94. STATE OF ALASKA A~ OIL AND GAS CONSERVATION COMMIS~I~,~,:~I REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing X Alter casing Repair well Perforate Other x Replace ESP 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 839' NSL, 2134' WEL, SEC. 10, T13N, RIOE At top of productive interval 378' SNL, 3639' WEL, SEC. 14, T13N, RIOE At effective depth At total depth 454' SNL, 3306' WEL, SEC. 14, T13N, RIOE 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 5064' Intermediate Production 8788' Liner Perforation depth: 8833 feet 7305 feet 8742 feet 7234 feet Size Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) KBE = 59' feet 7. Unit or Property name Mi/ne Point Unit 8. Well number MPC-14 9. Permit number/approval number 85-88/94-200 10. APl number 50- 029-21344 11. Field/Pool Kuparuk River Cemented Measured depth True vertical depth 16" To surface 115' 115' 9-5/8" 1375 sx PF "E" & 5100' 4533' 250 sx "G" 7" 273 sx Class "G" 8822' 7296' measured 8327'-8344', 8452'-8487', 8576'-8610', 8610'-8650' true vertical 6930'-6943', 7020'-7050', 7115'-7140', 7141'-7170' Tubing (size, grade, and measured depth) 3-1/2", L-80 tubing to 8027'MD w/ ESP at bottom Packers and SSSV (type and measured depth) Camco 'TRDP-4A SSSV @ 554' MD; HES DHR Packer @ 583' MD; Baker model "FB- 1' Packer w/screen assembly @ 8292' MD I't I" ~ ~. ! ~ I r.. r~ 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) NOV - 4 1994 Treatment description including volumes used and final pressure A_i~,S~',~ Oil & Gas Cons. Commission Anchor~ Reoresentative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well O/l~erations x 17.1 hereby certify th~.~tl~g/.,~/~s-'~ tru,e an/~'correct Si,ned F°rm 10-404 Rev 06/15/88 16. Status of well classification as: Oil x Gas Suspended to the best of my knowledge. Title Dr/fling Engineer Supervisor Service Date SUBMIT IN DU~LI~ATI~ MP C-14 08/06/94 8,822' MOVE RIG F/MP C-03 TO C-14. SPOT RIG ON HERCULITE. RU PITS AND PIPE SHED. TAKE ON 450 BBL'S 9.7# NACL BRINE. SITP-300 PSI, SICP- 250. RIG UP TO BLEED ANNULUS PRESSURE. BLEED GAS AND CRUDE. RU AND BLEED OFF TBG PRESSURE. RU LUBRICATOR ON TREE AND PULL BPV. UNABLE TO START MUD PUMP. SCR'S KICKING OUT. TROUBLESHOOT PROBLEM. START PUMPING TO KILL WELL. ACCEPT RIG @1630 HR'S ON 08/05/94. 08/07/94 8,822' ATTEMPT TO KILL WELL. BULL HAD 90 BBL'S 9.7# NACL DOWN TBG AND 225 BBL'S DOWN ANNULUS. MONITOR WELL FOR PRESSURE DECLINE. STABILIZED @ 300 TUBING AND 275 CASING. TRY TO BLEED PRESSURE OFF TBG AND ANN. GAS AND OIL AT SURFACE ALMOST IMMEDIATELY. REVERSE ClRC 45 BBL'S BRINE. RECOVERED MOSTLY CRUDE OIL W/ SOME BRINE. RU CAMCO SL. RIH AND PULL PUMP OPEN PLUG @515' WLM. RD CAMCO. DROPPED 3 7/8" FRAC BALLS DOWN TUBING. PUMPED 50 BBL'S DOWN TUBING. TOOK 30 BBL'S TO LOAD HOLE. SHUT DOWN AND DROP 3 ADDITIONAL FRAC BALLS. PUMPED CALCULATED VOLUME TO TBG PERF AND PRESS INCREASED. CIRCULATED WELL TO BRINE. MADE I COMPLETE CIRCULATION AFTER WELL CLEANED UP. MONITOR WELL. OPEN UP. WELL DEAD. SET TWC. NIPPLE DOWN TREE. PRESS UP SSSV. NU BOPE. TESTING BOPE. 08/08/94 8,822' FINISH TESTING BOPE. TESTED BOPE AND ANNULAR. PULL TWC. FILL HOLE. DROP 2 FRACBALLS AND CIRC ONE FULL CIRC. BOLDS. PULL HANGER TO FLOOR. PKR RELEASED. LD HANGER. PRESS CONTROL LINE. POH W/TBG. LD PACKER, SSSV, AND CONTROL LINE. PUMP 30 BBL XANVIS PILL. FINISH POH. DRIFT AND SLM TBG. INSPECT AND CUT BAD CABLE. LD PERF'D JT TBG. INSPECT AND LD ESP. CLEAN FLOOR. ND FLOW NIPPLE. NU SHOOTING FLANGE. 08/09/94 8,822' FINISH NU SHOOTING FLANGE. RU ATLAS WL. TEST LUBRICATOR. RIH W/GR/CCL. TIE IN TO SOS DIL/SFL/GR. TAG UP @8699'. LOG F/8698- 7500'. POH. RD ATLAS. ND SHOOTING FLANGE. NU FLOW NIPPLE AND FLOW LINE. SET WEAR RING. PU 3.5" BTC MULESHOE. RIH ON 3.5" BTC TUBING. PU 26 JTS 3.5" DP. TAG BOTTOM @8687'. CIRC, PREP TO SPOT SAND PLUG. 08/10/94 8,822' RECEIVED NOV - 4 1994 Alaska Oil & Gas Cons. Commission Anchor~.. ,~ CIRCULATE. PULL UP TO 8490'. RU BJ. TEST LINES. PUMP AND DISPLACE 22 BBL'S SAND SLURRY. PULL UP TO 8303' AND REPEAT. PULL UP TO 8209'. LET SAND SETTLE. RIH AND CONFIRM SAND PLUG @8462'. PULL UP TO 8391'. PUMP AND DISPLACE 12 BBL'S SLURRY. PULL UP TO 8297'. RIH AND CONFIRM PLUG @8407'. RD BJ. TOTAL SAND SPOTTED: 7900#. POH. LD 11 JTS DP. PU BAKER MODEL 'C' FULLBORE PACKER. RIH ON 3.5" DP AND SET @509'. TEST ANNULUS. RU BJ TO FRAC. TEST LINES. RD BJ. WO GET TO BREAK. 08/11/94 8,822' BLEED AND MONITOR FRAC. BLEED TO 500 PSI NOT GOING DOWN. BULL- HEAD 2 BBL. BLEED OFF WENT TO ZERO. THEN STARTED TO FLOW. SHUT WELL IN. RIG UP NOWSCAM COIL UNIT TO KILL AND CLEAN OUT WELL. 08/12/94 8,822' CONTINUE TO RIG UP NOWSOAM COIL UNIT TO CLEAN OUT FRAC SAND. FILL LINES AND TEST COIL BOP'S. OPEN TIW VALVE ON WELL, RIH W/ COIL. TAG SAND @7875', REVERSE OUT SAND F/7875-8452'. PICKING AND CLEARING COIL A COUPLE OF TIMES AND WORKED SAND PLUG OUT OF COIL. HAVE LOST APP. 200 BBL OF SEA WATER FORMATION. 08/13/94 8,822' CONTINUE TO REVERSE OUT FRAC SAND TO 8420' UNABLE TO MAKE ANY FORWARD PROGRESS. DISPLACE 8.6 PPG SEA WATER WITH 9.7 PPG BRINE. MONITOR WELL. BLEED WELL TO ZERO. BUILD BRINE IN PITS TO 9.9 PPG FOR TRIP AND SURGE MARGIN. CIRCULATE. MONITOR WELL. PULL COIL OUT OF HOLE. RIGGING DOWN COIL TBG UNIT. 08/14/94 8,822' CONTINUE TO RIG DOWN COIL UNIT. RELEASE BAKER TENSION PKR AT 500' AND POH AND LAY DOWN. SERVICE RIG SET IN PIPE SHED. MU MULE SHOE ON 3 1/2" TBG AND RIH TO 8418'. REVERSE OUT FRAC SAND F/8418-8717'. REVERSE CIRC. TO CLEAN OUT FOR BAKER MODEL "D" PKR AND SCREEN. POH. RIG ATLAS AND RIH 2 RUNS TO 8315' TO CLEAN JUNK AND GAUGE FOR PKR. REC. METAL DEBRIS FROM BASKET ON BOTH RUNS. WILL RUN #3. 08/15/94 8,822' CONTINUE RUNNING 6.0" GR/JB. FOR TOTAL OF FIVE RUNS RECOVERING GUN DEBRIS ETC. LAST RUN WAS CLEAN. RIH WITH BAKER F-1 PKR AND TIE IN TO DIL. SET PKR AT 8822' TOP OF PKR TAIL PIPE AT 8322'. POH RIG DOWN ATLAS. SERVICE RIG. MU CAMCO LLC. VALVE AND RIH ON TBG RECEIVED NOV - 4 !994 Alaska 0il & Gas Cons. Commission AND TAG PKR AT 8820'. SET VALVE AND SHEAR OFF. ATTEMPT TO TEST LLC. NO TEST. POH WITH TBG. CUT AND SLIP DRLG LINE. CONT. POH WITH SE'FI'lNG TOOL. LAY DOWN SETTING TOOL. MU AND RIH WITH LLC RETRIEVING TOOL. LATCH LLC AND RELEASE SAME. CIRC BOTTOMS UP BEFORE PULLING OUT OF HOLE. 08/16/94 8,822' CIRCULATE GAS CUT BRINE AND MONITOR WELL. POH. INSPECT LLC VALVE SEAT WASHED BY DEBRIS. RIH W/LLC VALVE TAG PKR @8280'. SET AND SHEAR OFF. TEST LLC VALVE. WOULD NOT TEST. POH TO 110' OF SURFACE. CIRC AND WORK GAS OF ANNULUS AND TBG. NO RECORDABLE PRESSURES. POH WITH LLC VALVE SETTING TOOL AND PICK UP RET. TOOL. RIH WITH 32 STD TBG. CIRC OUT CONT. GAS AND OIL INFLUX. RIH WITH RET TOOL TO 8271'. REVERSE CIRC TO CLEAN WELL BORE FLUIDS. NO NOTICEABLE DEBRIS. LATCH LLC VALVE AND RELEASE ANCHOR. CIRC BOTTOMS UP. 08/17/94 8,822' CONT. CIRC BO'I-rOMS UP. POH WITH LLCV. INSPECT LLCV AND SEAL ASSY. SEAT BLEW ON LLCV CHANGE OUT VALVE. RIH WITH LLCV. CIRC AND COND MUD @8264'. POH W! TBG. LAY DOWN 12 JTS DP. RIG UP TO COMP STRING. PICK UP THE ESP AND TEST OILS IN MTR. HOOK UP ELECTRIC LINE AND TEST CABLE RESISTANCE. RIH WITH COMPLETION STRING TO 299.87. CIRC AND WORK GAS AND OIL INFLUX THAT MIGRATED TO SURFACE. 08/18/94 8,822' CIRC AND WORK OIL AND GAS. CUT ESP CABLE AND STRIP IN HOLE THROUGH HYDRIL TO 2274'. CIRC MIGRATING GAS AND OIL THROUGH CHOKE. RIH W/HYDRIL OPEN FILLING EVERY 10 STDS. HOLE TRYING TO UNLOAD INFLUX. CIRC INFLUX OUT OF WELL BORE THROUGH CHOKE. BOTTOMS UP BRINE. WEIGHT UP BRINE IN PITS. CIRC. BRINE TO WELL BORE HOLE NOT STABLE LOTS OF OIL AND GAS BREAKING OUT AT SURFACE. MONITOR WELL. WELL BORE STABLE WITH SMALL LOSS. CIRC BOTTOMS UP AND MONITOR WELL BORE STABLE. SMALL LOSS. POH. CALCULATED HOLE FILL = 28 BBL, ACTUAL = 69 BBL. SERVICE ESP. 08/19/94 8,822' RIH WITH ESP COMPLETION. MAKE UP OTIS PKR + MAKE ESP. CABLE SPLICE + PICK UP OTIS TRSV AND HOOK CONTROL LINE AND TEST. CONT. RIH WITH COMP STRING. PICK UP SPACE OUT PUPS + FMC HGR + HOOK PENETRATOR TO HGR + CONTROL LINE AND TEST. TEST ESP CABLE. LAND TBG HGR. HAD TROUBLE GETTING HANGER INTO TBG SPOOL DUE TO THE POSITION OF THE PENETRATOR AND CABLE. PULL HGR TO FLOOR TO CHECK. FOUND CABLE CUT. RE-CONNEOT_E.S_P__ ...__ RECEIVED NOV - 4 1994 Alaska 0il & Gas Cons. Commission Anchor~,.,~ CABLE TO HGR AND TEST. RE-LAND TBG HGR AND RILDS. INJECT 20 BBL'S DIESEL DOWN ANNULUS AND 5 BBL DOWN TBG FOR FREEZE PROTECTION. DROP 1" BALL TO SET PKR. ATFEMPT TO TEST ANNULUS. ALIGNMENT PIN ON TBG HEAD LEAKING. UNABLE TO BACK OUT ALIGNMENT PIN OR TIGHTEN TO STOP LEAK. 08/20/94 8,822' RU SLICK LINE AND PULL MODIFIED XX PLUG AND PKR SETTING BALL. TAP AND PLUG LEAKING ALIGNMENT PIN RECESS TO OBTAIN PRESSURE INTEGRITY BELOW THE BOPS. ATTEMPT TO SHEAR ANNULAR VENT BY PUMPING INTO ANNULUS, BUT FLUID BEGAN LEAKING AROUND TBG HGR. PUMP DOWN TBG, NO RETURNS INDICATING VENT NOT SHEARED. CLOSE BAG AND PULL RELEASE DHR PKR. CIRC DOWN. PUMP DOWN ANNULUS. SWITCH BACK TO TUBING AND CIRCULATE WELL. PULL HGR TO FLOOR. SEALS PARTIALLY MISSING AND CUT AT LOCK DOWN SCREWS. SOME MARKS AT TOP LEFT OF ALIGNMENT SLOT. BUT NOT READILY APPARENT WHY PIN WOULD NOT TURN. PULL COMPLETION TO JUST BELOW X NIPPLE. PU BAKER STORM PACKER. RIH AND SET AT 607'. 08/21/94 8,822' RIH W/BAKER STORM PACKER AND SET @607'. RELEASE AND POH LAY DOWN SETTING TOOL. TEST STORM PKR. MU BAKER 7" BRIDGE PLUG AND RIH AND SET @545'. RELEASE AND POH AND TEST. ND BOPS AND TBG SPOOL. TOP SEAL ON 7" PACKOFF BAD. REPLACE SAME. ATTEMPT TO NU NEW TBG SPOOL NOT BORED FOR 7" PACKOFF. REPLACE ALIGNMENT PIN IN OLD TBG SPOOL. NU REPAIRED TBG SPOOL. NU NEW TBG SPOOL. TEST PACKOFF. NU BOP. SHORTEN FLOW NIPPLE TEST BOPS AND TBG SPOOL. RIH AND RETRIEVE AND LAY DOWN BRIDGE PLUG. RIH AND LATCH ONTO AND RELEASE BAKER STORM PACKER. PUMP DN TBG. FLOW RESTRICTED VALVE IN PKR SEEMS TO BE PARTIALLY CLOSED. PUMP DOWN ANNULUS INTO FORMATION. WAIT ON CAMCO TO PULL PRONG FROM BAKER PKR VALVE TO REGAIN CIRC IN TBG. RU CAMCO AND RIH W/OVERSHOT AND PULL EQUALIZING PRONG FROM VALVE. RECOVERED VALVE PRONG AND O-RING DEBRIS. 08/22/94 8,822' NIPPLE UP AND TEST TREE. PULL TWO WAY CHECK AND SET BPV. RELEASE RIG @0800 HR'S ON 08/22/94. RECEIVED NOV - 4 1994 Naska Oil & Gas Cons. Commission Anchor[ _~ . LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 27 October 1994 Transmittal of Data ECC #: 6253.02 Sent by: U.S. MAIL Data: PFC/PERF Dear Sir/Madam, Reference: BP MPC-14 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PFC/PACKER FINAL BL Run # 1 1 PFC/PACKER RF SEPIA Run # 1 l~_~.~~3~d return to: Atlas Wireline Services 5600 B street Suite 201 Anchorage, AK 99518 /._Attn. Rodney D. Paulson ~ ~ _O~ FAX~(907)563-7803 Received by: .~--/~~~ //-~//~.~ ~'-- Date NOV 03 1994 Alaska Oil & Gas Cons, Cemmiss!gn Anchorage 1. Type of Request: STATE OF ALASKA A~ OIL AND GAS CONSERVATION COMMIS~N APPLICATION FOR SUNDRY APPROVALS Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing x Variance__ Perforate__ O~er x __ Replace ESP 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 839' NSL, 2134' WEL, SEC. 10, T13N, R10E At top of productive interval 378' SNL, 3639' WEL, SEC. 14, T13N, RIOE 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service RECEIVED 6. Datum elevation (DF or KB) KBE = 59' 7. Unit or Property name Mi/ne Point Unit 8. Well number MPC-14 9. Permit number 85-88 10. APl number 50- 029-21344 11. Field/Pool Kuparuk River At effective depth At total depth 454' SNL, 3306' WEL, SEC. 14, T13N, RIOE 12. Present well condition summary Total depth: measured true vertical OCT 1 2 1994 Alaska Oil & Gas Cons. Commission AflGhorao 8833 feet Plugs (measured) 7305 feet Effective depth: measured 8742 feet Junk (measured) true vertical 7234 feet Casing Length Size Cemented Measured depth Structural Conductor 80' 16" To surface 115' Surface 5064' 9-5/8" 1375 sx PF "E" & 5100' Intermediate 250 sx "G" Production 8788' 7" 273 sx Class "G" 8822' Liner Perforation depth: measured 8327'-8344', 8452'-8457', 8481'-8487', 8576'-8596', 8610'-8650' True vertical depth 115' 4533' 7296' feet true vertical 6930'-6943', 7024'-7027', 7045'-7050', 7115'-7130', 7141'-7170' Tubing (size, grade, and measured depth) 3-1/2", L-80 tubing to 8027'MD '~, bj , Packers and SSSV (type and measured depth) HES DHR Packer @ 583' MD; Baker model "D' Packer @ 8292' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation 812/94 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil x Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~//~ .~.~--~'~ Title Drilling Engineer Supervisor~~,v~'~ ~/ ' - f FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Subsequent form required 10- ~: o4 Original Signed By D~virf W ...... ~ 1.~i i J Approval No.~ ~7/.._~ Commissioner Date Approved Copy Returned SUBMIT IN TRIPLICATE RWO SUNDRY INFORMATIC.._.. Objective' Pull failed electrical submersible pump from well, inspect the integrety of packer/screen assembly, and recomplete with a new ESP and existing tubing. Scope' , Pre- rig: Run TD tag, retrieve bottom GLM dummy valve, abtain a static bottom hole pressure survey, shear open the annular packer vent valve, circulate well with kill weight brine, freeze protect top 2000'TVD of tubing and tubing annulus with diesel, set a pump open valve in X nipple below the packer, and install BPV. . MIRU Nabors 4ES workover rig. Pull BPV and pressure shear open the plug in X nipple. Circulate tubing if necessary to ensure the well is killed. Pull existing 3- 1/2" tubing and ESP assembly. , Tag the packer/screen assembly with slickline to confirm the existance of blank plug in the tailpipe. Set a newscreen blank plug if the odginal plug is not set in the XN nipple of tailpipe. , RIH with 3-1/2" drillpipe to top of packer/screen assembly and perform wellbore cleanout. . Re-run existing 3-1/2" tubing and new ESP. Freeze protect tubing and annulus to 2000'TVD. 6. RDMO Nabors 4ES. 7. Place well on production. This work is expected to begin 10/14/94, immediately following the C-09 completion. A RWO was performed on well C-14 during August 1994 to frac the Kuparuk C sand and convert the well from GL to ESP production. However, due to excessive sand production and erratic ESP performance, a parted pump shaft is suspencted. The C-14 pump replacement is expected to take 6 days rig time assuming a wellbore cleanout and a new packer / screen assembly are required. DH, October 12, 1994, 10:53 AM OCT 1 2 1994 0il & Gas Cons. Commission Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 18 August 1994 RE: Transmittal of Data ECC #: 6253.01 Sent by: ANCHORAGE EXPRS Data: PL Dear Sir/Madam, Reference: BP NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PFC/PACKER FINAL BL Run # 1 1 PFC/PACKER FS SEPIA Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~/~~n- Rodney D- Paulson~/~ Received - ~.- Date: Please sign and return to: Petroteehnical Data Center BP Exploration (Alaska) Ine 900 East Benson Boulevard Anchorage, Alaska 99508 Received by ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 11 August 1994 RE: Transmittal of Data ECC #: 6253.00 Sent by: ATLAS WIRELINE Data: PL Dear Sir/Madam, Reference: MPC-14 MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Prints/Films: 1 GR/CCL FINAL BL Run # 1 1 CCL/PERF FINAL BL Run # 1 1 GR/CCL RF SEPIA Run # 1 1 CCL/PERF RF SEPIA Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~Cf/~fD ~ y~odney D. Paulson~ - ~UG ? 7 Received by// /~.W'/~ ///~ .~____ D~ Oll, /~ Aochorago Corr~i~S/o° Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) 900 East Benson Boulevard Anchorage, Alaska 99.508 I I I .Il I I Received by Date ........... MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David John~, DATE: Chairma~~ THRU: Blair Wondzell,~ ,J.~ P. I. Supervisor FROM' ~'~u Grimaldi, SUBJECT: Petroleum Inspector August 7, 1994 FILE NO: QW9JHGBD.DOC Rig BOPE inspection Nabors 4-ES BPX well # C-14 Milne Point Unit PTD # 94-299- ,,o.r--c~ Sunday, August 7, 1994: I traveled to BPX C pad in the Milne Point Unit to make a Rig BOPE inspection on Nabors rig 4-ES. The rig was pulling tubing when I arrived. Gene Sweatt (Nabors Toolpusher) accompanied me on my tour of the rig. I found all BOPE equipment to be in place with the exception of the methane detection system. The equipment was on location but had not been installed as of yet. I spoke with Tom Anglin (Company Rep.) and I was assured that this would receive immediate attention. Access to the rig was fair considering the small size of the pad. The location surrounding the rig was clean and orderly. SUMMARY: I made a Rig/BOPE inspection on Nabors 4-ES. One non- compliance noted, No methane detection system. Attachments: QW9JHGBD.XLS _ __p, cc: Sam Lynch (Prudhoe Bay drilling) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RIG I BPS INSPECTION REPORT OPERATION: Drig Contr: Operator: Location: Drilling Workover X Cmpl. UIC Well Name C-14 Nabors Rig No. 4ES Rep. BPX Rep. Tom An~llin Section 10 T. 13N R. 10E M. U DATE: 8/7/94 PTD# 94-200 Gene Sweatt Rig Ph.# 659-2233 INSPECTION ITEMS (A.) B.O.P. STACK Wellhead fig wkg press Stack wkg press preventer Pipe rams Blind rams Stack anchored Chke/kill line size All turns targeted ( chke & kill Ln.) HCR valves (chke & kill Ln.) Manual valves (chke & kill Ln.) Connections (Flgd, Whd, Clamped Drilling spool Flow Nipple Flow monitor Control lines fire protected INSPECTION ITEMS (B.) CLOSING UNIT Working pressure Fluid level Operating pressure Pressure gauges Sufficient valves Regulator bypass 4-way valves (actuators) Blind rams handle cover Driller control panel Remote control panel Firewall Nitrogen power source (backup) Condition (leaks, hoses, ect.) REMARKS: IN COMPLIANCE IN COMPLIANCE INSPECTION ITEMS MUD SYSTEM Pit level floats installed Flow rate sensor Mud gas separator Degasser Separator bypass Gas sensors Choke line connections Trip tank INSPECTION ITEMS (D.) RIG FLOOR iKelly cocks (upper, lower, IBOP) Floor valves (dart, ball, ect.) Kelly & floor valve wrenches Drillers console (flow monitor, flow rate indicator, pit level indicators, gauges) Kill sheet up-to-date Gas detection monitors H2S & methane) Hydraulic choke panel Choke manifold INSPECTION ITEMS Rig housekeeping Methane detectors not installed. IN IN COMPLIANCE IN RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date CorrectionS Will Be Completed: BOP Test & Results Properly Entered On Daily Record? OK 8~7~94 Flange leaks Kill Sheet Current? Distribution: odg - Well File c - Oper./Rig c- Database c - Tdp Rpt File c- Inspector AOGCC REP: OPERATOR REP: FI-022 (Rev. 3/93) Louis R Grimaldi QW9JHGBD.XLS STATE OF ALASKA A[~"'i~,,A OIL AND GAS CONSERVATION COMMIS"~' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well Alter casing __ Repair well__ Plugging Time extension __ Stimulate __ Change approved program Pull tubing x Variance__ Perforate __ Other x __ Replace ESP 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 839' NSL, 2134' WEL, SEC. 10, T13N, RIOE 5. Type of Well: Development x Exploratory __ Sl~atigraphic __ Service 6. Datum elevation (DF or KB) KBE = 59' 7. Unit or Property name Miine Point Unit 8. Well number MPC-14 At top of productive interval 9. Permit number 378' SNL, 3639' WEL, SEC. 14, T13N, RlOE O ~ I G1N A L 85-88 At effective depth 10. APl number 50- 029-21344 At total depth 11. Field/Pool 454' SNL, 3306' WEL, SEC. 14, T13N, RIOE Kuparuk River feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8833 feet Plugs (measured) 7305 feet 8742 feet Junk (measured) 7234 feet Casing Length Size Cemented Measured depth Structural Conductor 80' 16" To surface 115' Surface 5064' 9-5/8" 1375 sx PF "E" & 5100' Intermediate 250 sx "G" Production 8788' 7" 273 sx Class "G" 8822' Liner Perforation depth: measured 8327'-8344', 8452'-8457', 8481'-8487', 8576'-8596', 8610'-8650' true vertical 6930'-6943', 7024'-7027', 7045'-7050', 7115'-7130', 7141'-7170' Tubing (size, grade, and measured depth) 3-1/2", _L-80 tubing to 8051'MD Packers and SSSV (type and measured depth) 7"Otis "RDH"Packer@ 541' True vertical depth 115' 4533' 7296' RECEIVED JUL 2 6 1994 Aiaska 0il & Gas Cons. C0mmissi Anchorage 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation 8/2/94 16. If proposal was verbally approved Oil x Gas ~ Name of approv/er Date approved Service 17. I hereby certif,~tha~.t the, foregoing is,true and correct to the best of my knowledge. Sic~ned Title Ddlling Engineer Supervisor FOR COMMISSION USE ONLY 15. Status of well classification as: Suspended Conditions of approval: Notify Commission so representative may witness Approval No. ? ¥ _ 2 c, c~ Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev 06/15/88 Original SJgnee ~ David '"' '"'"'"'"+"" Commissioner Approved Copy Returned Date '7/-~ ~'/~ ~ SUBMIT IN TRIPLICATE~ ~ MP C-14 R~/~_._..AND FRAC SUNDRY INFORh,-,~.~ION Ob!ective: The objective of this workover is to pull a failed ESP from the well, add additional perforations, perform a fracture treatment on the Kuparuk interval, and recomplete the well with the existing 3.5" tubing and an ESP. Scope: 1. Pre- rig: Shift sleeve or punch hole in tubing immediately above ESP. Bullhead kill well and circulate with source water. Install BPV. Remove wellhouse and flowline. 2. MIRU Nabors 4ES workover rig. Circulate as necessary. Pull existing 3.5" BTC tubing. Perform wireline conveyed perforations. Perform data frac and frac. Cleanout to below perforations. Run Model D electric line set packer/tailpipe assembly and set immediately above perfs. Install liquid level control valve. Pressure test casing. Rerun 3.5" tubing with an electrical submersible pump. RDMO Nabors 4ES. Put well on production. , . , , , , Tlminq: Rig Nabors 4ES is expected to move on this well 8/2/94. The workover is expected to take 8 days. RECEIVED JUL 2 6 1994 AlasJ(a 0jj & Gas Cons. Commission Anchorage DBR, July 25, 1994, 2:42 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C(~MMISSION 3001 porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Receip f the following m'~iterial which was transmitted via ~+. ,~. '~ P~~ ~70BI~ is hereby acknowledged: QUANTITY DESCR! PT I ON Copy sent to sender YES NO · STATE OF ALASKA AI~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing X Alter casing Repair woll Pedorate Other 2. Name of Operator CONOCO INC. 3. Address P,0, BOX 340045, PRUDHOE BAY, AK 9973~ 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 839' FSL, 2134'FEL, SECTION 10, T13N, RIOE, UM At top of productive interval 380' FNL, 4652'FEL, SECTION 14, T13N, R10E, UM At effective depth 438' FNL, 3369'FEL, SECTION 14, T13N, R10E, UM At total depth 454' FNL, 3305'FEL, SECTION 14, T13N, R10E, UN 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8822 ' feet Plugs (measured) NONE 7300' feet 8742 ' feet Junk (measured) NONE 7241 ' feet 6. Datum elevation (DF or KB) 52' KDB MSL 7. Unit or Prooertv name M I LNE PO I'NT UN IT feet 8. Well number 6-14 9. Permit number/approval number 90-513 10. APl number 50-- 029-21344 11. Field/Pool KUPARUK RIVER Casing Length Structural Conductor 80 ' Surface Intermediate 5060' Production Liner 8785' Perforation depth: measured 8327 ' -8344', 8452' -8457', true vertical 6930'-6943', 7024'-7027', Tubing (size. grade, and measured depth) Size Cemented Measured depth 13-3/8" TO SURFACE 115' 9-5/8" 1125 SKS PERM E 5100' 250 SKS CLASS G 7" 250 SKS CLASS G 8822' 180 SKS PERM E 60 BBLS ARCTIC PACK 8481'-8487', 8610'-8650' 7045'-7050', 7141 '-7170' 3-1/2", 9.2#/FT, L-80, BTRS, TO 8021' True vertical depth 115' 4535' 7300' Packers and SSSV (type and measured depth) OTIS "FMX" TRSV 1~ 520' OTIS "RDH" 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 571 413 1091 1201 691 324 1171 0 207 192 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16, Status of well classification as: Oil ~ Gas_ Suspended __ Service 17. I hereby certify that,~regoing is true and correct to the best of my knowledge. Signed ....' Title SENIOR Form 10-404 Rev 06/15/88 PRODUCTION FOREMAN SUBMIT IN DUPLIC^TE / JUNE 26, 1990 RU BPV'LUBRICATOR. SET TWO WAY CHECK VALVE - PRESSURE UP FROM WING VALVE TO TBG HNGR WITH 4000 PSI - OPEN TEST PORT ON ADAPTOR FLANGE TO CHECK FOR PRESSURE COMMUNICATION - NO COMMUNICATION NOTED - TBG INTEGRITY GOOD FROM PKR TO WING VALVE - LEAVE TWO WAY CHECK IN TREE - BLEED OFF PRESSURE ABOVE - 300 PSI GAS PRESSURE UNDER TWO WAY CHECK. RDMO. JUNE 27, 1990 MOVE RIG TO C-14 WELL LOCATION. AND FILTER. DILUTE 10.3 NaCl/NaBr BACK TO 9.9 PPG JUNE 28, 1990 CONTINUE DILUTING 10.3 PPG NaCl/NaBr BACK TO 9.9 PPG AND FILTER. LUBRICATE OUT THE BPV. BULLHEAD 85 BBLS OF 9.9 PPG NaCl/NaBr DOWN TBG. R/U SLICKLINE UNIT. RIH WITH 3-1/2" JDC AND RETRIEVE THE B-7 LOCK AND SPACER PIPE (ACROSS FLAPPER) FROM TRDP SCSSV @543'. R/D SUCKLINE UNIT. R/U SCHLUMBERGER E-LINE UNIT. RIH WITH 1-11/16" OD TUBING PUNCH GUN. PERFORATE TUBING @7984-86RKB POOH. R/D E-LINE. R/U SLICKLINE UNIT. RIH W/FLAPPER SLEEVE AND SET ACROSS SCSSV FLAPPER POOH R/D SLICKLINE. 'CONTINUE TO WEIGHT UP BRINE TO 10.25 PPG. CIRCULATE BRINE DOWN THE TUBING TAKING RETURNS UP THE BACKSIDE. JUNE 29, 1990 CONTINE CIRCULATING DOWN TBG. & UP ANNULUS W/10.25 PPG NaCl/NaBr BRINE. CIRCULATE UNTIL RETURNS ARE CLEAN. PUMPED A TOTAL OF 520 BBLS. INSTALL BPV. N/D PRODUCTION TREE, N/U BOPES. TEST BOPE. INSTALL LANDING JOINT. ATTEMPT TO RELEASE PACKER. PACKER WONT RELEASE. WAIT FOR ARRIVAL OF TRISTATE FISHNG SPECIALIST. R/U SLICKLINE. RIH AND RETRIEVE FLAPPER SLEEVE FROM SCSSV. RD SUCKLINE. R/U SCHLUMBERGER E-LINE UNIT. START RIH W/2.75"OD JET CUTTER STARTED PULLING WEIGHT I ^=ow =,= =,o, ow. ^ ow GEM ~5. ~ r ~~ ~~--~ ~V ~ U CONTINUE POOH W/SPENT TBG. CUTTER UNABLE TOrGE~I~~PENT CUTTER HEAD UP THROUGH THE SCSSV. CUT LOGGING LINE THREAD THROUGH FLAPPER SLEEVE ON SURFACE. DROP FLAPPER SLEEVE TO SCSSV NO GO STILL UNABLE TO GET WlRELINE TOOLS UP THROUGH THE SCSSV. START POOH TO SURFACE W/3-1/2" TBG. L/D GLMs & SHOT OFF JT. OF TBG. M/U BHA CONSISTING OF: 5-3/4" OVERSHOT, 4-3/4" BUMPER SUB, 4-3/4" HYDRAULIC JARS, SlX 4-3/4" DCs & R3/4" ACCELERATOR. RIH W/BHA ON 4", 14#/FT D.P. TO APPROX 4545'. P.U. 7" RTTS PACKER AND STORM VALVE. RIH. SET PKR. APPROX 30' BELOW THE WELLHEAD. BACKOFF THE TOP 2 JTS ABOVE THE STORM VALVE & POOH. START NIPPLING DOWN BOP AND TUBING SPOOL. JULY 1, 1990 N/D BOPS AND TBG SPOOL. REMOVE TUBING SPOOL AND REPLACE WITH A TUBING SPOOL W/ALIGNMENT PIN. N/U TBG. SPOOL AND BOPS. TESTED BOPS (AND TBG SPOOL) TO 2500 PSI - OK. TESTED FLANGE & SEALS TO 5000 PSI-OK. RIH W/STORM VALVE STINGER ON 2 JTS OF D.P. RELEASE PKR. POOH TO PKR/STORM VALVE, L/D SAME. CONTINUE TO RIH W/OVERSHOT ASSEMBLY., TAG TOP OF FISH @ APPROX. 7540'. P.U. LAY DOWN ONE JOINT. P/U POWER SWIVEL. POOH 6 STANDS - HAVING TO JAR THROUGH SEVERAL CASING COLLARS. L/D POWER SWIVEL. CONTINUE POOH W/FISH TO OVERSHOT. LAY DOWN FISHING TOOLS & GLM//5 POOH W/REMAINDER OF 3-1/2" BTRS TBG AND RTTS PACKER. L/D SAME. M.U. 5-3/4" PBR OVERSHOT W/GRAPPLE & KICKOVER SHOE ON BUMPER SUB, HYDRAULIC JARS, 6,4-3/4"X2-3/16" DCS, & ACCELERATOR JARS. START RUNNING BHA IN HOLE ON 4" D.P. JULY 2, 1990 CONTINUE RIH. WITH 259 JTS IN THE HOLE R/U POWER SWIVEL. RIH W/2 MORE JOINTS - TAG TOP OF FISH @8137'. ENGAGE PBR W/GRAPPLE. ROTATE POOH. R/D POWER SWIVEL. CIRCULATE 10.3 PPG BRINE DOWN THE D.P. NO RETURNS SEEN W/34 BBLS AWAY. PUMP PRESSURE = 125 PSI. SHUT DOWN PUMP & SHUT IN WELL. MONITOR PRESSURES. SlPP & SlCP STABILIZED @ 75 TO 100 PSI WHICH BLED OFF QUICKLY. NO FLOW. CONTINUE POOH. BREAK DOWN PACKER ASSEMBLY AND LAY DOWN. WAIT ON SLICKLINE UNIT. JULY 3, 1990. R.U. SLICKLINE UNIT. RIN W/GRC EMS 700 PRESSURE/TEMP GAUGE TO 8370' RKB. RECORD BHP FOR 30 MIN. POOH. RIH W/4.0" OD BLIND BOX TO DETERMINE FLUID LIVEL @545' RKB. SBHP--3366 PSlA+ R/D SLICKLINE UNIT. SLIP & CUT DRILLING LINE. P/U BAKER MODEL CK' MILLING TOOL, MODEL I~' JUNK BASKET AND RIH ON JARS, SHOCK SUB, DSs, ACCELERATORS, AND DP. REPAIR HYDROMATIC. P/U POWER SWIVEL. RIH TAG PKR @8522' RKB. LATCH INTO SEAL BORE. MILL ON TOP OF PKR. CIRCULATING FRESH WATER AT APPROX I BPM. +__ 1' OF DEPTH SINCE START. JULY 4, 1990 CONTINUE TO CIRCULATE AT +_ 1BPM, MILL W/+__ 3000 TO 5000 LBS WOB, & ROTATING. HAVE LOST MOST OF ROTARY TORQUE WHILE MILLING. SET OFF JARS SEVERAL TIME-PKR NOT MOVING. RELEASE GRAPPLE. CONTINUE TO CIRCULATE TO GET CONSlSTANT BRINE WEIGHT. S/I WELL & MONITOR PRESSURE: SlDPP+100 PSI, SlCP--0. WEIGHT UP SURFACE SYSTEM TO 9.7 PPG AND CIRCULATE. WELL NOT DEAD. CONTINUE TO WEIGHT UP SYSTEM. RETURNING BRINE WEIGHTS FLUCTUATING FROM 9.1 TO 9.8. WEIGHT UP SURFACE BRINE SYSTEM TO 9.9 PPG. CIRCULATE OUT WELL. CIRCULATE 327 BBLS. WELL DEAD. ATTEMPT LATCH BACK INTO PKR - CANNOT LATCH RESUME MILLING W/O CIRCULATION - GAINING SOME TORQUE - PU & SET BACK DOWN - NOT GAINING ANY DEPTH - PU & CIRCULATE 20 BBLS - LD SWIVEL POOH TO CHANGE MILL SHOE, GRAPPLE LD JUNK BASKET, "CK" MILLING TOOL. CHANGE OUT JUNK BASKET & MILLING SHOE. JULY 5, 1990 MU "CK" MILLING TOOL, JUNK BASKET - RH W/JARS, BUMPER SUB, DC~, ACCELERATOR ON DP MU POWER SWIVEL. RIH TO LATCH INTO PKR - WHEN PKR WAS TAGGED, MOVED DOWNHOLE- PKR LATCHED & FREE LD POWER SWIVEL. POOH W/PKR. MU 6"BIT & 7" CSG SCRAPER W/JARS, BUMPER SUB DC~. RIH ON DP TAG FILL @8586' RKB. REVERSE CIRCULATE TO WASH OUT FILL. BEGAN GETTING SAND RETURNS AFTER PUMPING BOTTOMS UP. JULY 6, 1990 CONTINUE CIRCULATING BRINE DOWN ANNULUS TAKING RETURNS FROM DP- MU POWER SWIVEL - ALTERNATE RECIPROCATING AND ROTATING DP - RETURNS ARE PLUGGING FILTERS AFTER 5 BBLS - SAND & RUBBER IN RETURNS. WORK DOWN TO 8680' RKB FROM 8580' RKB PBTD = 8742'- PICK UP OFF BOTTOM. CONDITION FLUID, RESUME CIRCULATION & ROTATION WORKING DOWN TO 8700'. CONTINUE ROTATION/CIRCULATION. CONDITION FLUIDS WAIT ON BRINE, PU OFF BOTTOM MIX CHEMICAL SWEEP IN SOURCE WATER AS FOLLOWS: 3.5~ HEC/BBL-25BBL, I DRUM SAFE-KLEEN/50BBL, 3.5#HEC/BBL - 25BBL. RE-ESTABLISH CIRCULATION W/10# BRINE. PUMP CHEMICAL SWEEP & CIRCULATE BOTTOMS UP TO BRING CHEMICAL SWEEP AROUND. JULY 7, 1990 CONTINUE CIRCULATING UNTIL CLEAN RETURNS W/NO SAND/SOLIDS - CIRCULATED ADDITIONAL 50 BBLS AFTER RETURNS CLEANED UP RD POWER SWIVEL. POOH W/DP & LD DP, DC~, ACCELERATOR, BUMPER SUB, JARS, CSG SCRAPER, BIT - PULL WEAR BUSHING, CHANGE PIPE RAMS FROM 4" TO 3-1/2" PU, ASSEMBLE/SERVICE ESP EQUIPMENT. RIH W/3-1/2" TBG BANDING CABLE W/PRE-FORMED HEAVY DUTY BANDS ABOVE & BELOW EACH COLLAR 2 BANDS/JT. JULY 8, 1990 CONTINUE RIH W/3-1/2" TBG. SPLICE CABLE 6 STDS BELOW PKR. MU OTIS SCSSV & RDH PKR. MAKE VERTICAL SPLICE @PKR MU CONTROL LINE TO ANNULAR VENT VALVE & SCSSV. RIH W/PKR, SCSSV, 16 JTS LD I JT TBG. MU TBG HGR, SPLICE IN PIG TAIL TO BOTTOM OF H. LAND HGR. RU TRANS TECH S/L. SET "XX" PLUG IN "X" NIPPLE BELOW PKR @548'- POOH & STANDBY. PUMP 30 BBLS DIESEL DOWN ANNULUS FOR FREEZE PROTECTION. PRESSURE UP TBG TO 2750PSl - PKR SET @2200PSI. RIH & RETRIEVE XX PLUG. RD TRANS TECH. BLEED PRESSURE OFF CONTROL LINE TO CLOSE ANNULAR VENT- PRESSURE UP TO 500 PSI TO TEST PKR/VENT - GOOD TEST - OPEN ANNULAR VENT & PUMP ADDITIONAL 20 BBLS DIESEL DOWN ANNULUS FOR FREEZE PROTECTION. 50 BBLS DIESEL TOTAL FREEZE PROTECTION - ANNULUS. JULY 9, 1990 SET BPV. ND BOPE, NU TREE, PULL BPV & SET 2-WAY CHECK- TEST TREE TO 5000 PSI - GOOD TEST PULL CHECK & SET BPV. RD EWS & MOVE TO C-16. SCHLUMBERGER WELL SERVICES A Ol¥1.~tON OF ~.,HLUMB£RGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77~..51-2 ! 75 'JUL- 3 lggO CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 AHention' Marc Shannon ~ RElY TO aCHLUMBERGER WELL ~I"I~ICE$Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed are3__RL_prints of the Tubing Puncher Rec, Run 1, 6/28/90 Company CONOCO, Inc. Well Hilne Point Unit C-14 Field MJlne Poin: Additionol prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 A~n: Georg~ Lamb - OF 2018 PER County Nnrth Slope State Alaska _l_B2,__prints, I RF Sepia CONOCO. Tnt_ 1000 South Pine Ponca City, OK 74603 Attn: Log Library 1BL prints, 1RF Sepia OXY U.S.A., Inc. 6 Desta Drive Midland, TX 79710 At,n: John Carrol *(915/685-5600) ~rints, 1RF Sepia Chevron U.S.A. 6001Bollinger Canyon Road San Ramon, CA 94583-0943 Attn: Priscilla MacLeroy *(415/842-1000) 1 BL r~rin,ts%> I RF S ~.~-a .... :~..~-: ~- . ~ ~-. ~-~ -~_-..~. ~. Ala. s-k:i~ 0~1 & ..Gas Conservation f.?3001 Porcupine Dr~ve ~[~r Anchorage, AK 99501 tn.: John Boyle ~*-- The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints prints prints Date: d U L - 9 ~990 Alas~ 0il .& Gas Cons. Commission Very truly yours, SCHLUMBERGER WELL tSP. RVICES 13274' _David H. Saalwaechter DI JTR iCT JaANAG£R SCHLUMBERGER WELL SER¥1CES DIVISION OF GCHLUMBE:RGER TECHNOLOGY CORPORATION HOUSTON. TE:XAS 77251-2175 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 A~ention: Marc Shannon iq. EASE RElY TO ICHL'L~KImH3~IMELLI~RVIC, ESPouch 340069 Prudhoe Bay, ~ 99734-0069 Attn: Bernie/Shelle~ Gentlemen: Enclosed ore_2__BL_prints of the Tubing Cutter, Run 1, 6/29/90 Compony CONOCO. Inc,_ Well Milne Point Unit C-14 Field Milne Point '. County Nnrth $~ope State. Additionol prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 At,n: George Lamb - OF 2018 PER Alaska ~rints, 1RF Sepia CON~CO~ Thc: 1000 South Pine Ponca City. OK 74603 Attn: Log Library 1BL prints, 1RF Sepia OXY U.S.A., Inc. 6 Desta Drive Midland, TX 79710 Atg~: John Carro] *(915/685-5600) _lJ~d~prints, 1RF Sepia Chevron U.S.A. . 6001Bollinger Canyon Road San Ramon, CA 94583-0943 Attn; Priscilla MacLeroy .*(415/842-1000) 1 BL nrinr ts,-"'~. -I~F Sepia ~.. Alaska~0ii & Gas Conservation .¢6mmi s si on / ,8'001 Porcupine Drive ,, ~ Anchorage, AK 99501..? ~ Attn: John Boyle/~ The film is returned to Conoco, Log Library. We oppreciate the privilege of serving you. prints prints prints Date: .... Alas~ Oil & Ve~ truly yours, Anchorage SCHLUMBERGER ~LL SERVICES ~David M, Saalwaechter I:) I STA itt MANAGER SW~-- 1327-F TO: THRU: MEMORAhOUM Slate of Alaska ALASKA OIL AND GAS CONSERVATION CO~R~IISSION Lonnie C. Commi s s ioner DATE: FILE NO: July 5, 1990 JT.HH. 75.4 TELEPHONE NO: SUBJECT: RIG/BOPE Inspections Permit No. 85-88 Kuparuk Rv Field FROM: Harold R. Hawkins Petroleum Inspector Thursday June 28, 1990: I went t~ Conoco's Milne Point DS C-14 to inspect the 'BOP equipment on rig EWS #1. This rig is doing a workover and completion or remedial work for Conoco at different times and schedules. There is no gas monitors or detector. There was no flow monitor or any kind of trip tank alarm. The motorman or stabber was supposed to be the pit watcher also but a cover was on the pit tank. I asked them how they could tell in advance whether there was a voluntary flow. Their answer~ "That is a good question." In summary, I was told that they would see to it to put a float in the tank with a marker inside rig so as to see level of mud taD~s at all times on the floor. Wayne Olheiser was the toolpusher. Jim Fox was the company man or operator for Conoco. 02-001A (Rev. 6/89) 20/11/MEMO1.PM3 .~._...~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coM~-'~SlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation sytdown __ Stimulate ~ Plugging __ Pull tubing __ Alter casing __ Repair well __ 2. N~6r~e0o~ ~ p ~ ~ ~ 3. Aj~d.~.ss BOX 340045, PRUDHOE BAY, AK 9973' Perforate __ 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 839' FSL, 2134'FEL,SEC10,T13N,R10E,UM At top of productive interval 380' FNL, 4652'FEL,SEC14,T13N,R10E,UM. At effective depth 438' FNL, 3369'FEL,SEC14,T13N,R10E,UM. Att°ta~dse~? FNL, 3305'FEL,SEC14,T13N,R10E,UM. 12. Present well condition summary Total depth: measured true vertical Other __ 6' I~LCn ~Ii~at¢~LDF or K B) 7. C~Ero~t~n[~l iT 8. Well number C-14 9. Permit number/approval number 85-88 10. APl nur~l~e(j so- 02-21344 11. F~iL~cj~/jK R!VER feet .E Effec!ive depth: measured true vertical 8822 ' feet Plugs (measUred) NONE 7300' feet 8742 ' feet Junk (measured) NONE 7241' feet Casing Length Structural Conductor 80 ' Surface Intermediate 5060' Production Liner 8785' Size Cemented Measured depth 13-3/8" TO SURFACE 115' 9-5/8" 1125 SKS PERM E 5100' 250 SKS CLASS G 7" 250 SKS CLASS G 8822' 180 SKS PERM E 60 BBLS ARCT!C PACK True vertical depth 115' 4535' 7300' RECEIVE Perforation depth: measured 8327' -8344' 8452'-8457' ,8481'-8487' ,8610'-8650' true vertical 6930'-6943' 7024'-7027',7045'-7050' 7141'-7170' Tubing (size, grade, and measured depth) 3-1/2" ,9.2#/FT,L-80,BTRS, TO 7976"~i~-;Oil& Gas Cons. Commissio~ "'~*.'-,~ Anch'0rag~ Packers and SSSV (type and measured depth) CAMCO TRDP- lA SSA SCSSV e543' HALL ! BURTON CHAMP ! ! ! RETR! EVAE g8016'RKB BOT'HB' PKR. g8153'RKB BOT ' 2B' PERMAMENT PKR e8522'RKB' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations RepresentativeDailyAveragePmdu¢onorlnjectionD~a OiI-Bbl Gas-Md Water-Bbl CasingPressure 1430 1050 580 1220 571 413 1091 1201 16. Status of well classification as: Oil X Gas__ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Tubing Pressure 235 207 Signed //~~)¢'~ Title Form 10-4~)411~ev ~)6/15/88 Service Date (o i ~/ifo SUBMIT IN DUPLICATE JUNE 2, 1990 1200-2400 INSTALL BPV. MIRU EWS RIG #4. DILUTE 10.3 NaCI/NaBr BRINE TO 9.4 PPG. AND FILTER. JUNE 3, 1990 DROP BALL DOWN TUBING FOR CIRCULATING SUB. PRESSURE UP ON TUBING TO 1200 PSIG TO SHEAR OPEN CIRCULATING SUB. BULLHEAD 70 BBLS OF 9.4 NaCI/NaBr BRINE DOWN TUBING. CIRCULATE 250 BBLS BRINE DOWN TUBING PRESSURE=730 PSI FINAL PRESSURE=(Z). PUMP 70 BBL OF DIESEL DOWN THE BACKSIDE TAKING RETURNS OUT TUBING. PUMP 10 BBLS 10.5 NaCI/NaBr DOWN BACKSIDE. BACKSIDE STILL FLOWING. (RECOVERED 42 BBL DIESEL) CIRCULATE 15 BBL OF 10.5 BRINE DOWN BACKSIDE & BULLHEAD 5 BBL DOWN THE TBG. WELL DEAD. N.D. PRODUCTION TREE/N.U. BOPE. PRESSURE TEST - OK. BOP TEST WITNESSING BY AOGCC WAS WAIVED BY DOUG AMOS. UNLAND TBG. AND START POOH W/TUBING STRING & POWER CABLE. JUNE 4, 1990 0000-1030 CONTINUE POOH W/ESP COMPLETION. L/D ESP ASSEMBLY. CURSORY CHECK INDICATES: THE PUMP DRIVE SHAFT IS LOCKED UP. R.U. HRS E-LINE UNIT. RIH w/JUNK BASKET & 5.90" OD GAUGE RING. TAG PBR/JUNK @8138' RKB. POOH. RECOVERED APPROX. 6 CABLE BANDS AND 3 SADDLES. MADE A SECOND JUNK BASKET RUN WITH A 5.95" OD GAUGE RING TO THE SAME DEPTH. RECOVERED ONE BAND & ENCOUNTERED NO RESTRICTIONS. R.D. S/L UNIT. RIH w/4.4" OD LIB. TAG PBR/JUNK @8138" WLM. POOH. SHOW IMPRESSION OF JUNK (CABLE BANDS) ONLY. PREPARE TO RUN TAPERED SWEDGE (2.43"OD) ON S/L. WELL STARTED TO FLOW SLIGHTLY AND BLOW GAS. R/U S/L LUBRICATOR. JUNE 5, 1990 SHUT-IN ADJACENT WIW (C-15). R.U. S/L LUBRICATOR. RIH w/2.43" OD TAPERED SWEDGE ON S/L TO 8688' WLM (THROUGH THE TBG. TAIL). POOH. WELL FLUIDS SURGING SLIGHTLY DUE TO GAS BREAKOUT. PUMP 15 BBLS OF 9.4 PPG BRINE DOWN THE WELLBORE - WELL IS DEAD RIH w/HALLIBURTON CHAMP III RETRIEVABLE PACKER, GLMS. M.U. TBG HNG, LAND TBG, P.U. REPLACE HNG O RING, SET PKR, LAND TBG, LOCK DOWN. PRESSURE TEST ANNULUS TO 3000 PSlG - OK. NIPPLE DOWN OF BOPS. JUNE 6, 1990 CONTINUE N/D OF BOP & N/U OF PRODUCTION TREE. CLEANING RIG. RD RIG AND MOVE TO CFP-I. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS OR 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator CONOCO [tiC. 3. Address Operation shutdown ~ Re-enter suspended well __ Plugging · Time extension __ Stimulate __ Pull tubing _jr,. Variance ~ Perforate ~ Other 5. Type of Well: Development -X- Exploratory ~ Stratigraphic ~ _~ 9 7 ~ A_ Service ~ 4. Location of well at surface 839 ' FSL~ 2 134 ' FEL~ SEC10 · T13N~ R10E~ Uti At top of productive interval N/A At effective depth ti/A At total depth 3305'FEL SEC14 UM 12. Present well condition summary Total depth: measured feet Plugs (measured) true vertical 8822" feet 7300' Effective depth: measured 8 7 4 2 ' feet Junk (measured) true vertical feet 7241' Casing Length Size Cemented Structural Conductor 13 - 3 / 8' Surface 9 -5 / 8" Intermediate Production 7' Liner Perforation depth: measured 8327 '-8344·8452 '-8457 ' ·8481'-8487 ' ·8610-8650' true vertical 6930'-6943 ' , 7024 ~-8027' · 7045'-7050', 7141'-7050 Tubing (size, grade, and measured depth) 3-1/2" 9.2# L-80 BTRS 6. Datum elevation (DF or KB) 52 "KDB MSL 7. Unit or Property name MTLNI~ POTNT ~N'rT $. Well number C-14 9. Permit number 85-88 10. APl number 50-- 029-21344 11. Field/Pool KUP~UK RTVER FTELD feet TO SURFACE 115' 115' iitli 5 00, 45a5, Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal 7976' Ci~ICO TRDP-1A SSA SCSSV @543' 153'RKB. BOT '2B' PERM. PKR. @ 8522'RKB Detailed operations program __ BOP sketch __ 15. Status of well classification as: Gas __ Suspended __ R~NTOR FOR COMMISSION USE ONLY 14. Estimated date for commencing operation 16. If proposal ! approved Oil -X- Name of approver Date approved Service 17. I h~ertify that,the foregoing is true and correct to the best of my knowledge. S, g n 6d.¢.__./~...~ 2.~ /~/,~~1 Title Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10- ORIGINAL SIGNED BY LONNIE C. SMITH Date ~'//'~//~ Approved by order of the Commission Appr°val N°' Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MILNE POINT UN~,_~C-14 ACTUAL COMPLETION SKETCH COMPLETED ON 5-21-85 #O?E~: FMC TUBING HANGER i/ $ ~'~' 'H' BP¥ PROFILE KDB - GL ' 4. Mil. I~lll 4&-Ie~ &400' I. KOP~ ~4~' IS4S'(~.TS"~D) 10. APl Ne. ~.0~9-~1~ 11. ~Bi~I~n Ib~ 10.2 ~ PERFORA?tO~S I~ SPIt, I~:)° 14o~fq, DII. log ef l$27'. 8}44' ur, 6930' 6J4:' TVD L-I ?024'. ?02?' TqgD L-$ 848I'- 8481' id: 704~' - 7OSO' TVI:) LK-2 8610'. 8650' MD ?t4l'- ?l?O' 4SPF, 180el~t,al. 2 ~' ll~l (AJ~ del)tlr ~ DIt le~ S.17.8~} LK -I 85?6' - 1596' YD ?liS'. 7i30' TVD FRACTuR[ STIMULATION 8-29-8~. Lo-e, K-I) (2) 72000 II)s I&-20 ISP fB,q, Soel Asaoeslk] (3.00' ID) lOT 'HB' PecMw (289'iO) 0202' C~¢0 '~' S~e~s,vo #il~ (~IE' ~)- -- 02}5' CAMCO 'MMG-2' O el I~' GLH esi4' BJott jl~t (29.52'loM1 leah, 0444' Bletl Joint {S 78' t~i ~em~g~h, 4.25'0D, ~.00' ID) 8470' Blest domt [ i9~73' tMol le~th, 4.25'OD, 3.00"ID) , 1~):)2' BOT '2-8' I'~rm,o,w~i Petter (S.STS'OI:).4.0C,'iD) vlpm'lo~ eUMu.,o~ ( 5.~62"0D, ,i.M:)e"ID) CAMCO ' D' l$54' Tubing TMt ,r OINT C-iq(P) OPERATOR: CONOCO INC. SURFACE LOCATION: 839' FSL, 2134' FEL, Section 10, T13N, R10E BOTTOM HOLE LOCATION: 454' FNL, 3306' FEL, Section 14, T13~, RIOE SPUD DATE: 05/09/85 13 3/8" 48~ H-60 at 115' 9 5/8" 36# K-55 Btrs. at 5100' Est. TOC at 7650'~~ NOTES: 1. All measurements from KDB of Alaska United ~3 2. KDB - SL ' 52' 3. KDB - GL ' 35' 4. Max. angle = 46.1' @ 6400' M.D. 5. KOP at 1400' 6. Slant Type Hole - YES · 9 5/8" Surface Casing 1. Pumped 40 Bbls of 11 ppg Sepiolite spacer for pre-flush. 2. Pumped 482 Bbls (1375 sx) of 12.3 ppg Permafrost "E" cement with 5 lbs/gilsonite per sk. 3. Pumped 51Bbls (250 sx) of 15.8 ppg Class "G" cement with 31 NaC1 and 11 CFR-2. Displaced with 388 Bbls 9.1 ppg mud. NOTE: Full returns with cement td surface. 7" Production Casin~ 1. Pumped 35 Bbls of 12 ppg Sepiolite spacer for preflush. 2. Pumped 56 Bbls (273 sx) of 15.8 ppg Class "G" cement with 1I CFR-! and 0.31 Halad-24. 3, D!splaced with 334 Bbls of 10.2 ppg NaCI-NaBr. Centralizers: 1 per 40' 7680' - 8821' 1 per 120' O' - 3000' 7" x 9 5/8" Annulus I. Pumped 30 Bbls of 15.6 ppg Permafrost "C" followed by 60 Bbls Arctic Pack. PBTD 8742' ECP 8518' ECP 8539' 7I, 26~ L-80 Btrs. Based on 100% excess in 8%" hole. NPU KUPARUK RESERVOIR PROGEDURE FOR GONV£RS[ON OF O&9 LIFT MELLS TO ELEGTRIG SUBMERSIBLE PU~P I. STABILIZED WELL TESTS WERE OBTAINED FOR EACH WELL. 2. PRESSURE GAUGES WERE RUN ON WIRELINE AND FLOWING BOTTOM HOLE PRESSURES WERE MEASURED FOR EACH WELL, WELLS WERE THEN SHUT IN AT SURFACE AND 12 HOUR PRESSURE BUILDUP SURVEYS WERE PERFORMED TO DETERMINE RESERVOIR PRESSURES. 3. KILL FLUID DENSITIES WERE THEN DESIGNED BASED ON THIS PRESSURE DATA FOR EACH WELL TO PROVIDE FOR BALANCED CONDITIONS DURING THE WORKOVER OPERATIONS. FOLLOWING ARE THE RESULTING KILL FLUID DENSITIES: WELL DEPTH SBHP FBHP KILL FLUID (TVD-FT) (PSIG) (PSIG) (PPG) C-2 7151 2732 1194 7.85 C-3 7017 2570 1548 7.54 C-7 7192 2370 1240 6.84 C-14 7050 3580 1432 10.3 C-16 7050 3600 1225 10.5 (NOTE: KILL FLUIDS ARE A HALF POUND OVER-BALANCED TO THE SBHP, 8.33 PPG SOURCE WATER WILL BE USED AS KILL FLUID FOR C-2~ C-3, AND C-7. C-14 AND C-16 WILL BE KILLED WITH 10.3 AND 10.5 PPG NABR BRINES, RESPECTIVELY, CURRENTLY, 450 BBLS OF 10.3 PPG AND 450 BBLS OF 10.5 PPG NABR BRINE ARE BEING STORED IN TWO 500 BBL TIGER TANKS ON C PAD. THERE IS ENOUGH DRY BULK BEING STORED AT MILNE POINT ON C PAD TO MIX AN ADDITIONAL 600 BBLS OF 10,3 PPG AND 600 BBLS OF 10.5 PPG NABR IN THE EVENT THAT WE ARE WORKING ON EITHER C-14 OR C-16 DURING BREAKUP. 4. ALL KILL FLUIDS WILL BE FILTERED TO 2 MICRON AND STORED IN CLEAN TANKS. 5. SHUT IN OFFSET INJECTORS PRIOR TO RIGGING UP WORKOVER RIG ON WELL, BULLHEAD KILL FLUID DOWN TUBING TO KILL THE WELL. (SEE ATTACHED WELL BORE DIAGRAMS.) NIPPLE DOWN WELLHEAD AND NIPPLE UP BOPs. PRESSURE TEST BOPs TO 3000 PSIG. 6. P/U TUBING AND SHEAR THE PBR ASSEMBLY (SEE ATTACHED WELL BORE DIAGRAMS). CIRCULATE KILL FLUID AROUND AND MAINTAIN HOLE FULL OF KILL FLUID. POOH WITH TUBING AND LAY DOWN SBR. RIH W/ 4" D.P, AND RETREIVE THE TEMPORARY PACKER. RIH WITH PACKER PLUCKER AND BURNING SHOE AND MILL THE SLIPS AND POOH WITH THE PERMANENT PACKER. PERFORM A CLEAN-OUT TRIP AND CIRCULATE FILL OUT OF HOLE WHILE CIRCULATING CASING WASH PROGRAM, 7. M/U THE ELECTRIC SUBMERSIBLE PUMP ASSEMBLY AS ILLUSTRATED IN THE ATTACHED OTIS COMPLETION GUIDE. STRAP AND RECORD THE LENGTH OF EACH COMPONENT. RUN A STANDARD CENTRALIFT MOTOR CENTRALIZER FOR THE 562 SERIES MOTORS AND 7" 26# CASING ON THE BOTTOM OF THE MOTOR. 8. RIH WITH THE ELECTRIC SUBMERSIBLE PUMP NO FASTER THAN 30~ PER MINUTE. MAINTAIN SUFFICIENT HYDRAULIC PRESSURE WHILE RIH TO MAINTAIN VALVES IN THE OPEN POSITION. ATTACH 2 CABLE BANDS PER JOINT. ATTACH ADDITIONAL BANDS ABOVE AND BELOW EACH CABLE SPLICE. SET THE BOTTOM OF THE MOTOR AT DEPTHS SPECIFIED IN THE ATTACHED E.S.P. DATA TABLE. 9. LOCATE PACKER AND CONTROL VALVES NOT LESS THAN 500 FT MD. PIN PACKERS TO BEGIN SETTING AT APPROXIMATELY 1100 PSIG. (IMPORTANT NOTE: THE COMBINED MEASUREMENT OF THE DIAMETERS OF THE #2 ROUND CABLE DIAMETER AND THE SCSSV IS 6.07 INCHES -- THE DRIFT OF THE 7" CASING IS 6.059" (TO0 LARGE TO FIT). IT WILL THEREFORE BE NECESSARY TO SPLICE APPROX. 20 FT OF #2 FLAT CABLE TO EXTEND ACROSS THE SCSSV.) 10. RIH WITH "X" PLUG ON WIRELINE AND SET IN THE "X" NIPPLE LOCATED BELOW THE PACKER AND PRESSURE UP TO 1000 PSIG. SET PACKER BY GRADUALLY PRESSURING UP THE TUBING FROM 1000 PSIG TO 2500 PSIG. 11. BLEED OFF THE CONTROL LINE PRESSURE TO CLOSE THE ANNULAR VENT VALVE AND TRSCSSV. PRESSURE THE ANNULUS TO 500 PSIG FOR 10 MINUTES TO TEST THE PACKER AND ANNULAR VENT VALVE. RETRIEVE THE X PLUG ON W/L. IF PRESSURE HOLDS, PROCEED TO STEP 12. IF PRESSURE DOES NOT HOLD, RETRIEVE THE PACKER/TRSCSSV SYSTEM, REPAIR OR REPLACE IT, RIH, RESET, AND RETEST IT. 12. NIPPLE DOWN BOPs, N/U AND TEST WELLHEAD TREE, RIG DOWN WORKOVER RIG, MOVE TO NEXT WELL. THIS PROCEDURE IS IN ACCORDANCE WITH AN EARLIER PROCEDURE WHICH WAS: PREPARED BY STEVE ROSSBERG, SENIOR PRODUCTION ENGINEER (3/23/90) REVIEWED BY MARC SHANNON, SUPV. PRODUCTION ENGINEER (3/27/90) APPROVED BY GARY FLOWERS FOR JACK COPELAND, PRODUCTION SUPT. (4/3/90) J.D. POLYA DRILLING FOREMAN 1. Operations performed: '-.~.~----- ' STATE OF ALASKA ...,_.. "~'~" 0 ,t~ / ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT 'OF SUNDRY WELL OPERATIONS Operation shutdown ' Stimulate__ Plugging m Perforatem Pull tubing X Alter casing ~ Repair well g Other 2. Name of Operator CONOCO INC. 3. Address P.O. BOX 340045, PRUDHOE BAY, AK 99734 Location of well at surface 839' FSL, 2134'FEL,SEClO,T13N,RlOE'UH At top of productive interval N/A At effective depth N/A At total depth 454' FNL, 3305'FEL,SEC14,T13N,R10E,UH. 5. Type of Well: Development Exploratory Stratigraphic Service 6. ~t~un~at~L(DF or KB) 8. Well number C-14 9. Permit number/approval number 85-88//~71 10. APl number 50- 029-21344 11. ~'~K RIVER feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8822' 7300! 8742' 7241' Casing Structural Conductor Surface Intermediate Production Liner feet feet feet feet Plugs (measured) :'.': NONE, · . Junk (measured) NONE Length Size Cemented 13-3/8" TO SURFACE '. g-5/8" 7" 180 SKS 1125 SKS PERH E 250 SKS CLASS G Pedoration depth: measured 8327'-8344' ,8452'-8457', 8481 '-8487' ,8610'-8650' 250 SKS CLASS G PERH E 60 BBLS ARCTIC Measured depth true vertical 6930'-6943' 7024'-7027' 7045'-7050' 7141'-7170' 115' 5100' ~. 8822' PACK .- :: ~ · · ~ue vertical depth 115' 4535' 7300' Tubing (size, grade, and measured depth) 3-1/2",9.2#/FT,L-80,BTRS, TO= 7976': · , Packers and SSSV (type and measured dePth) 7" 0TIS RDH DuAL STRING !PKR @572' 'RKB, :0TIS 2-7/8" . FHX TRSV SCCSSV g552'RKB, ANNULAR VENT VALVE g570'. RKB D'; ~ ~ j [~I ~-~- 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treafment description including volumes used and final pressure ~[&~ .0JJ .& Gas Cons. C0mm·issi0~ .... ' ~:~ ~ch'0ra~ 14. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 1430 1050 580 1220 Tubing Pressure 235 Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys runx._ Daily Report of Well Operations __ Oil X Gas SusPended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Signed ~ {[~')"-~_~ Title Form lO-4~',~ev~0~/15/88- FOREMAN Date SUBMIT IN DUPLICATE Kuparuk River- North Slope Borough, Alaska Milne Point C No. 14 CONFIDENTIAL (6115'-Kuparuk Oil Sands) AFE 10-61-1205 MAY 20, 1990 MOVE RIG FROM C-2 TO C-14. RIG UP. RETRIEVE BPV. OPEN SCSSV. INITIAL WHP = ±100 PSI. PUMP 35 BBL OF 10.3PPG NaCl/NaBr BRINE DOWN THE WELL - WELL IS ON A VACUUM. PUMP AN ADDITIONAL 30 BBLS OF BRINE TO CLEAR THE TBG. R.U. SLICKLINE UNIT. RIH TO 8098' RKB AND RETRIEVE THE GAS LIFT VALVE. POOH. R/D SLICKLINE UNIT. START PUMPING SOURCE WATER DOWN ANNULUS. MAY 21, 1990 CONTINUE PUMPING SOURCE WATER DOWN THEANNULUS. TOTAL SOURCE WATER PUMPED = 120 BBLS. FOLLOWED BY 73 BBLS OF 10.3 NaCl/NaBr BRINE. PUMP 30 BBL BRINE DOWN THE TBG. WHP=30 MONITOR WHP - OK. INSTALL BPV. N/D PRODUCTION TREE N/U BOPE. PRESSURE TEST BOPE - OK. BOP INSPECTION BY AOGCC WAS WAIVED BY HAROLD HAWKINS. POOH SLM & LAYING DOWN SCSSV & GLMS. MAY 22, 1990 CONTINUE POOH W/GAS LIFT STRING. LAY DOWN GAS LIFT MANDRELS & PBR OVERSHOT. CLEAR FLOOR AND PREPARE TO RUN ESP. P/U ASSEMBLE, AND SERVICE ESP ATTACH POWER CABLE RIH W/ESP ON 3 1/2" L-80 9.2#/FT. BTRS TBG BAND CABLE ± ABOVE & BELOW EACH CONNECTION· RIH ON 3 1/2"~ 9.2#/FT-L-80, BTRS TUBING. WITH 112 JTS IN THE HOLE PICK UP AND INSTALL PACKER/SCSSV. SPLICE PIGTAIL BELOW PACKER. MAY 23, 1990 CONTINUE SPLICES ABOVE AND BELOW THE PACKER. CONTINUE RIH W/ESP. M/U TBG HNG. SPLICE CONNECTOR AT TBG HNG. LAND TBG. PUMP 1.6 BBLS DIESEL DOWN TBG & 45 BBLS DIESEL DOWN ANNULUS FOR FREEZE PROTECTION RU S/L TO SET XX PLUG. RIH W/1.875" XX PLUG & SET IN X NIPPLE BELOW PKR @566' WLM SET PKR W/2500 PSI ON TBG PUMP DIESEL DOWN ANNULUS TO FILL UP & TEST PKR. TEST PKR TO 500 PSI FOR 15 MIN. - GOOD TEST RU S/L & RIH PULL XX PLUG, POOH & RD SET 2-WAY CHK VALVE, ND BOPE, NU TREE TEST TREE TO 3000 PSI - GOOD TEST - RETRIEVE CHK SET BPV - RIG TEST PUMP RELIEF VALVE. RD AND MOVE RIG TO C-7. ,,,_~, i STATE OF ALASKA '~"/¢ 0 R! ALASK~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator CONOCO INC. Abandon __ Suspend __. Operation shutdown __ Re-enter suspended well __ . Alter casing __ Repair well ~L_ Plugging __ Time extension __ Stimulate__ Change approved program __ Pull tubing -X- Variance __ Perforate __ Other __ 3. Address P.O. aOX 340045, PP, UDHOE BAY, AK 4. Location of well at surface 839'FSL,2134 ' FEL, SEC10,T13N, R10E,UH At top of productive interval N/A At effective depth N/A At total depth 454' FNL, 3305' FEL, SEC 14, T 13N, R 10E, UN · 8822 t, . 'feet 7300' feet 12. Present well condition summary Total depth: measured true Vertical Effective depth: measured 8742 ' feet true vertical 7241 ' feet- Casing Length Size Cemented Structural 5. Type of Well: Development _X_ Exploratory __ Stratigraphic __ 9973 Service __ 6. Datum elevation (DF or KB) 52'KDB HSL 7. Unit or Property name HILNE 8. Well number C-14 9. Permit number 85-88 10. APl number 5o-- 029-21344 11. Field/Pool KUPARUK RIVER FIELD Plugs (measured) .:~ ,,NONE~ ~ ~ ':~ ' Junk (measured) NONE - ' ii: Measured depth · True vertical depth Conductor 13-3/8" TO sUP'FACE- Sudace 9-5/8" 1~c~ ~]~ ~E~sEG Intermediate Production 7" ;~8 ~ ~i~i~SEG& Liner Perforation depth: measured 8327'-8344,8452'-8457', 8481 ' -8487', 8610-8650' true vertical 6930'-6943' ,7024'-8027' ,7045'-7050', 7141 '-7050' . Tubing (size, grade, and measured depth) 3.1/2'' 9 2# L'80 BTRS'$ 7976' ' : . · 7" OTIS RDH DUAL STRING PKR $ 572'RKB, Packers and SSSV (type and measured depth) OTIS 2-7/8" FNX TRSV SCSSV ~ 552'RKB, ANNULAR VENT VALVE ~ 570' RKB 13. Attachments Description summary of proposalX__ Detailed operations program __ BOP sketch 115, 115' 5100, '" 4535' ~82t~LS:AR~e'PACK . .. feet RECEIVE Oil & Gas Cons, Anchora~ 14. Estimated date for commencing operation APRIL 1. 1990 16. If proposal was verbally approved Name of approver Date approved 17. I hereby certify that the foregoing is true and correct to the best of m, Signed ~_~/~(~?~ 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service ~ knowledge. TitteSENIOR FOREHAN FOR COMMISSION USE ONLY Date ~ )9-? lifo Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH NO. Approved Copy Retprn~d Commissioner Date ~Ob/O~ Form 10-403Rev06/15/88 . . SUBMIT IN TRIPLICATE Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 MR. LONNIE SMITH STATE OF ALASKA OIL AND GAS COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 DEAR MR. SMITH, CONOCO IS REQUESTING TO CONDUCT WORKOVER OPERATIONS TO PULL THE ELECTRIC SUBMERSIBLE PUMP ON THE C-14 WELL. WE WERE UNABLE TO START THE ESP AFTER INSTALLATION. WE HAVE EXPERIENCED WHAT APPEARS TO BE SIMILAIR PUMP PROBLEMS ON THE C-2 WELL. DEPENDING ON WHAT WE FIND WHEN WE PULL THE C-2 PUMP, WE WILL EITHER PROCEDE WITH THE FOLLOWING OPERATIONS PLAN, CALL YOU TO SUBMIT ALTERNATE PLANS, OR CANCEL THIS REQUEST ALTOGETHER. FOLLOWING IS THE OPERATIONS PROGRAM WE ARE SUBMITTING FOR YOUR REVIEW AND APPROVAL: I · LOCK OPEN THE SCSSV AND SSV (FUSE CAP) AND INSTALL A BPV IN THE WELLHEAD. 2. MIRU WORKOVER RIG. m N/D WELLHEAD TREE AND N/U AND PRESSURE TEST BOP's TO 3000 PSIG. UNSEAT PACKER AND KILL WELL WITH 10.3 PPG SOURCE WATER (CALCULATED KILL FLUID DENSITY IS 10.3 PPG). 5. POOH WITH ELECTRIC SUBMERSIBLE PUMP AND INSPECT. m THE PROCEDURE AT THIS POINT WILL BE DETERMINED BY WHAT WE FIND TO BE THE CAUSE OF THE PUMP FAILURE; HOWEVER, CONOCO WILL NOTIFY AOGCC OF ANY DEVIATION FROM THE FOLLOWING OPERATIONS. m RIH W/ ELECTRIC SUBMERSIBLE PUMP, PACKER, AND SCSSV -- TEST SCSSV TO 5000 PSIG. Bm N/D BOP's, INSTALL A DOUBLE CHECK VALVE, N/U AND TEST WELLHEAD TREE TO 5000 PSIG, AND MOVE RIG OFF WELL. 9. RETURN WELL TO PRODUCTION. EOR RESPECTFULLY, J.D. POLYA DRILLING FOREMAN Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 MR. MIKE MINDER STATE OF ALASKA OIL AND GAS COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 DEAR MR. MINDER, ATTACHED IS THE REQUEST FOR SUNDRY APPROVAL TO CONDUCT WORKOVER OPERATIONS ON THE C-14 WELL. THESE OPERATIONS WILL BE NECESSARY TO CONVERT THE PRODUCTION TECHNIQUE ON THE C-14 WELL FROM THE CURRENT GAS LIFT DESIGN TO ELECTRIC SUBMERSIBLE PUMP DESIGN. RESPECTFULLY, J.D. I~OLYA DRILLING FOREMAN ,.i~ska.Oii & Gas Cons. Commissio~;!: -:,~-gnchorag~ · ,,_~,---.~ ' STATE O F ALAS KA ALASKA OIL AND GAS CONSERVATION COM MISSION 0 APPLICATION FOR SUNDRY APPROVALS NA 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdown ~ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing -X--- Variance __ Perforate __ Other -X-- 2. Name of Operator CONOCO INC. 3. Address Location of well at surface 839' FSL, 2134' FEL, Sec 10, T13N, RIOE At top of productive interval N/A At effective depth N/A At total depth 454' FNL, 3305'FEL, Sec 14, T13N, RIOE 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KB 52 7. Unit or Property name MILNE POINT UNIT 8. Well number C-14 9. Permit number 85-88 10. APl number 5o- 029-21344 11. Field/Pool Kuparuk River feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8822 ' feet N/A feet 8,742' feet N/A feet Casing Length Size Structural 13-3/8" Conductor Surface 9-5/8" Intermediate Production 7" Liner Perforation depth: measured MID KUP 8327'-8344'; L-8 L-9 8481'-8487'; LK-2 8610'-8650' Plugs (measured) Junk (measured) Cemented 8742' NONE Measured depth 115' 5100' 8822' 8452' -8457'; True vertical depth trueverticalvlID KUP 6930'-6943'; L-8 7024'-7027' L-9 7045'-7050'; LK-2 7Z41'-7170' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 BUTTRESS, 8556' MD Packers and SSSV (type and measured depthBOT ' HB' RETRIEVABLE PACKER e 8153'; @ 8522'; CAMCO TRDP-1A SSA SSSV e 1862' 13. Attachments Description summary of propos~ Detailed operations programL BOT '2-B' PERM BOP sketc~j PACKER 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 17. I hereby certify that the foregoing is true and correct to the best of m, 15. Status of well classification as: Oil)(__ Gas __ Suspended __ Service ¢ knowledge. Title SENIOR PRODUCTION FOREMAN FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- . ~ ~L ORIGINAL SIGNED BY LONNIE C. SM)TH Approved by order of the Commission Form 10-403 Rev 06/15/88 IAppr°val N°' Approved Copy ~.~.,~%turned L;ommissioner Date SUBMIT IN TRIPLICATE MILNE POINT UN!l'rC---~ 14 ACTUAL COMPLETION SKETCH COMPLETED ON 6-21-85 NOTEI: FMC TUBING HANGER ./ 3 I/z" 'H' BPV PROFILE 1. AN mellMemente ire from KDB of I. KDB - GL = 4. Mit. ingle 46.1°~ 6400' S. KOP~ ~4~' ~. 8lint t~pe hole Yes ?. Ml~. ingle 41° ~ 8200' I. FMC 8 1/8' APl SOO0~ tree ~h · 1~2' 8 rd. treetop connection. e. Min. restriction ii CAMCO 'D' N~pple ~ 8546'(Z.75"iD) t I. Ce~t~ f~tO IO.Z ppg NaCI-NaBr Cil~ led cimenl ~formet~h o~ ciilnO end Cement eketch. 3 I/2", 9.2a~,L-80 B~tmss tubieq (2.992" ID,Z.867'Mift) - 1862' CAMCO TROP-IA SSA SSSV (2.812" ID) GLM Z~86' GLM $64~' GLM 4395' GLM GLM 6375' GLM 7065' GLM ' 6LM GLM PERFORATIONS BOT 'liB' Poc:~m' (2.89" ID) 12 SPF, 120° phosin~, 5 "g~s (All 681:~hs ftO~ DIL log of 5-17-85) " 8202' CAMCO 'W-I' Selective Nipple (2.812' ID) MIDDLE KUP 8327'~ 8344' MD 69~,0' - 694.~' TVD CAMCO 'MMG-;Z' G4~ Lif~ Meneei (GLM) 2.92"zI.D.,I.S'velves GLM L-8 8452'- 8457' MD 7024'- 7027' TVD e314' Blest Joint (29_52't0~1 Ite, qth, 4.25"00,.~.00"ID) L-9 8481'- 8487' I~D 7045' - 7050' TVD LK-2 8610' - 8650' MD 7141'- 7170' TVD 8444' B,I, ost do~t (9.78' toMI leeg~h, 4.25"0D, ~00" ID) 8470' BLast Joint ( t9.7~,' total length, 4.25"0D, BOT '2-8' Permo~,e~t Pecker (5.$75" OD,4.00"ID) w/miUc~t extermoe ( 5.562 "OD, 4 SPF, 180° I:hh~mg, 2 ~" ~uqi (All depths from DIL LK -I 8576'° 8596' MD 7115'- 7150' TVD CAMCO ' D' Nipple {2.';~'ID) 0554' Tubing T~! FRACTURE STI~ULATION Lower Kup (2) 72000 It)s 16-20 ISP 8708' Top of fill (Wireline 9- 18 - 85) 8742' PBTO 8822' 7" 26~ L-80 BTR$ (8.276' ID, 6.151' Ik|ft) MILNE POINT C-14 (P) OPERATOR: CONOCO INC. SURFACE LOCATION: 839' FSL, 2134' FEL, Section 10, T13N, RIOE BOTTOM HOLE LOCATION: 454' FNL, 3306' FEL, Section 14, T13N, RIOE SPUD DATE: 05/09/85 13 3/8" 48# H-40 at 115' 9 5/8" 36# K-55 Btrs. at 5100' Est. TOC at 7650'!~ NOTES: 1. Ail measurements from KDB of Alaska United #3 2. KDB - SL = 52' 3. KDB - GL = 35' 4. Max. angle = 46.1° @ 6400' M.D. 5. KOP at 1400' 6. Slant Type Hole - YES .. 9 5/8" Surface Casing 1. Pumped 40 Bbls of 11 ppg Sepiolite spacer for pre-flush. 2. Pumped 482 Bbls (1375 sx) of 12.3 ppg Permafrost "E" cement with 5 lbs/gilsonite per sk. 3. Pumped 51Bbls (250 sx) of 15.8 pp~ Class "G" cement with 3% NaC1 and 1% CFR-2. 4. Displaced with 388 Bbls 9.1 ppg mud. NOTE: Full returns with cement to surface. 7" Production Casing 1. Pumped 35 Bbls of 12 ppg Sepiolite spacer for preflush. 2. Pumped 56 Bbls (273 sx) of 15.8 ppg Class "G" cement with 1% CYR-] and 0.3Z Halad-24. 3. Displaced with 334 Bbls of 10.2 ppg NaC]-NaBr. Centralizers: 1 per 40' 7680' - 8821' 1 per 120' 0' - 3000' 7" x 9 5/8" Annulus 1. Pumped 30 Bbls of 15.6 ppg Permafrost "C" followed by 60 Bbls Arctic Pack. ECP 8518' * Based on 100% excess in 8~" hole. PBTD ECP 8539' 7l! 26# L-80 Btrs. HPU KUPARUK RESERVOIR PROCEDURE FOR CONVERSION OF GAS LIFT HELLS TO ELECTRIC SUBMERSIBLE PUNP 1. STABILIZED WELL TESTS WERE OBTAINED FOR EACH WELL. 2. PRESSURE GAUGES WERE RUN ON WIRELINE AND FLOWING BOTTOM HOLE PRESSURES WERE MEASURED FOR EACH WELL. WELLS WERE THEN SHUT IN AT SURFACE AND 12 HOUR PRESSURE BUILDUP SURVEYS WERE PERFORMED TO DETERMINE RESERVOIR PRESSURES. 3. KILL FLUID DENSITIES WERE THEN DESIGNED BASED ON THIS PRESSURE DATA FOR EACH WELL TO PROVIDE FOR BALANCED CONDITIONS DURING THE WORKOVER OPERATIONS. FOLLOWING ARE THE RESULTING KILL FLUID DENSITIES: WELL DEPTH SBHP FBHP KILL FLUID (TVD-FT) (PSIG) (PSIG) (PPG) C-2 7151 2732 1194 7.85 C-3 7017 2570 1548 7.54 C-7 7192 2370 1240 6.84 C-14 7050 3580 1432 10.3 C-16 7050 3600 1225 10.5 (NOTE: KILL FLUIDS ARE A HALF POUND OVER-BALANCED TO THE SBHP. 8.33 PPG SOURCE WATER WILL BE USED AS KILL FLUID FOR C-2, AND C-7. C-14 AND C-16 WILL BE KILLED WITH 10.3 AND 10.5 PPG NABR BRINES, RESPECTIVELY. CURRENTLY, 450 BBLS OF 10.3 PPG AND- 450 BBLS OF 10.5 PPG NABR BRINE ARE BEING STORED IN TWO 500 BBL TIGER TANKS ON C PAD. THERE IS ENOUGH DRY BULK BEING STORED AT MILNE POINT ON C PAD TO MIX AN ADDITIONAL 600 BBLS OF 10.3 PPG AND 600 BBLS OF 10.5 PPG NABR IN THE EVENT THAT WE ARE WORKING ON EITHER C-14 OR C-16 DURING BREAKUP. 4. ALL KILL FLUIDS WILL BE FILTERED TO 2 MICRON AND STORED IN CLEAN TANKS. 5. SHUT IN OFFSET INJECTORS PRIOR TO RIGGING UP WORKOVER RIG ON WELL. BULLHEAD KILL FLUID DOWN TUBING TO KILL THE WELL. (SEE ATTACHED WELL BORE DIAGRAMS.) NIPPLE DOWN WELLHEAD AND NIPPLE UP BOPs. PRESSURE TEST BOPs TO 3000 PSIG. 6. P/U TUBING AND SHEAR THE PBR ASSEMBLY (SEE ATTACHED WELL BORE DIAGRAMS). CIRCULATE KILL FLUID AROUND AND MAINTAIN HOLE FULL OF KILL FLUID. POOH WITH TUBING AND LAY DOWN SBR. 7. M/U THE ELECTRIC SUBMERSIBLE PUMP ASSEMBLY AS ILLUSTRATED IN THE ATTACHED OTIS COMPLETION GUIDE. STRAP AND RECORD THE LENGTH OF EACH COMPONENT. RUN A STANDARD CENTRALIFT MOTOR CENTRALIZER FOR THE 562 SERIES MOTORS AND 7" 26# CASING ON THE BOTTOM OF THE MOTOR. 8. RIH WITH THE ELECTRIC SUBMERSIBLE PUMP NO FASTER THAN 30' PER MINUTE. MAINTAIN SUFFICIENT HYDRAULIC PRESSURE WHILE RIH TO MAINTAIN VALVES IN THE OPEN POSITION. ATTACH 2 CABLE BANDS PER JOINT. ATTACH ADDITIONAL BANDS ABOVE AND BELOW EACH CABLE SPLICE. SET THE BOTTOM OF THE MOTOR AT DEPTHS SPECIFIED IN THE ATTACHED E.S.P. DATA TABLE. 9. LOCATE PACKER AND CONTROL VALVES NOT LESS THAN 500 FT MD. PIN PACKERS TO BEGIN SETTING AT APPROXIMATELY 1100 PSIG. (IMPORTANT NOTE: THE COMBINED MEASUREMENT OF THE DIAMETERS OF THE #2 ROUND CABLE DIAMETER AND THE SCSSV IS 6.07 INCHES -- THE DRIFT OF THE ?" CASING IS 6.059" (TO0 LARGE TO FIT). IT WILL THEREFORE BE NECESSARY TO SPLICE APPROX. 20 FT OF #2 FLAT CABLE TO EXTEND ACROSS THE SCSSV.) 10. RIH WITH "X" PLUG ON WIRELINE AND SET IN THE "X" NIPPLE LOCATED BELOW THE PACKER AND PRESSURE UP TO 1000 PSIG. SET PACKER BY GRADUALLY PRESSURING UP THE TUBING FROM 1000 PSIG TO 2500 PSIG. 11. BLEED OFF THE CONTROL LINE PRESSURE TO CLOSE THE ANNULAR VENT VALVE AND TRSCSSV. PRESSURE THE ANNULUS TO 500 PSIG FOR 10 MINUTES TO TEST THE PACKER AND ANNULAR VENT VALVE. RETRIEVE THE X PLUG ON W/L. IF PRESSURE HOLDS, PROCEED TO STEP 12. IF PRESSURE DOES NOT HOLD, RETRIEVE THE PACKER/TRSCSSV SYSTEM, REPAIR OR REPLACE IT, RIH, RESET, AND RETEST IT. 12. NIPPLE DOWN BOPs, N/U AND TEST WELLHEAD TREE, RIG DOWN WORKOVER RIG, MOVE TO NEXT WELL. THIS PROCEDURE IS IN ACCORDANCE WITH AN EARLIER PROCEDURE WHICH WAS: PREPARED BY STEVE ROSSBERG, SENIOR PRODUCTION ENGINEER (3/23/90) REVIEWED BY MARC SHANNON, SUPV. PRODUCTION ENGINEER (3/2?/90) APPROVED BY GARY FLOWERS FOR JACK COPELAND, PRODUCTION SUPT. (4/3/90) J.D. POLYA DRILLING FOREMAN Conoco Inc. 3201 C Street Suite 200 Anchorage, AK: 99503 (907) 564-76O0 May 29, 1987 Ms. Fran Jones Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Ms. Jones: Enclosed please find the drilling "well histories" from Conoco's Milne Point Unit wells No. C-13, C-14, C-15 and B-13. If you require additional information concerning this well history, please contact Don Girdler at 564-7637. Yours ve r~L~ E. D. Wilson Sr. Administrative Coordinator DRG/vv C-13, C-14, C-15, B-13 I ECEIVED Alaska Oil & Gas Cons. linchora.qe Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.14- CONFIDENTIAL (7,305'-Kuparuk River) AFE 10-61-1113 API No. 50-029-21344. Ak. Permit No. 85-88. Elevation: 59' KB. Location: 839' FSL, 2134' FEL, Sec. 10, T13N, R10E, Umiat Meridian 5-9-85: NU 20" hydrill & diverter. Mix spud mud and RU to spud. PU BHA & test hydril & diverter system to 50 psi. ACCEPT RIG. 5-10: Drlg from 115' to 511'. Run wireline survey. Drlg from 511' to 863'. Survey, POOH, change bits, RIH/broken nozzle on bit. Drlg from 863' to 1400'. POOH from 1400', lay down BHA, PU MWD & Navidrill. Service MWD & orient, test MWD & Navidrill. RIH to 1400'. Drill from 1400' to 2170'. 5-11: Drlg from 2170' to 2987'. POOH from 2987', lay down BHA, PU new BHA, service MWD, orient and test MWD, RIH to 2875'. Wash & ream 2875' to 2987'. Circ and cond hole. Work pipe & condition hole (to remove gravel). Drill from 2987' to 3935'. 5-12: Drlg from 3935' to 4667'. POOH from 4667' to 4050'. Pump singles out of tite hole from 4050' to 2043'. POOH, wet from 2043' to surface. LD BHA, PU new bit and BHA. RIH. 5-13: RIH to 4231', hit bridge. Circ. and condition hole. Wash from 4231' to 4667'. Drlg from 4667' to 5125'. Survey, pump pill, short trip to 2515', hole tite 5025' to 3000' coming out. Tight @ 3893' and 4444' going in. Circ. and pump high visc. pill. POOH from 5125' to surface laying down BHA. Prepare to run csg. 5-14: Run 129 jts of 9 5/8", 36#, K-55 BTRC csg., breaking circ. @ its 50 & 95. Circ., RD circ. head, install cmt head. Pumped 40 bbls 11 ppg Sepiolite spacer, 1375 sks Permafrost w/5# Gilsonite and 250 sks Class "G" w/3% salt & 1% CFR-2, displaced w/388 bbls of mud, bumped plug to 2500#. Floats held. RD cementers, back out landing jt, clear floor of csg. tools, ND 20" stack & diverter lines, install trash ring & speed head, NU BOP's. RU to test BOP's, test BOP's and choke manifold to 500# & 5000#. Annular to 350# & 3500#, witnessed by Bobby Foster, AOGCC. RD BOP test tools, set wear ring. PU BHA, service MWD, orient mud motor, RIH to 5018 for plugs. Test csg to 1500# for 15 mins. OK. Drlg float equip. 5-15: Drlg float equipment & cmt from 5018 to 5100. Drlg from 5125 to 5150. Circ. & run leak-off test to 12 ppg equivalent. Drlg from 5150 to 6310. 5-16: Drlg from 6310 to 6336. POH from 6336, change bit, service MWD. RIH to 2580'. Cut drlg line & fill drill pipe. RIH to 6234'. Ream from 6234' to 6336' & break in new bit. Drlg from 6336' to 6868'. Survey, pump pill & POH from 6868'. Change Navidrill motors, BHA ,re-orient, test MWD & Navidrill. RIH to 6868'. Drlg w/directional control from 6868'. -1- Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.14- CONFIDENTIAL (7,305'-Kuparuk River) AFE 10-61-1113 API No. 50-029-21344. Ak. Permit No. 85-88. Elevation: 59' KB. Location: 839' FSL, 2134' FEL, Sec. 10, T13N, R10E, Umiat Meridian 5-17: Drlg from 6890' to 8660' w/directional control. 5-18: Drlg from 8660' to 8833' w/surveys. Circ. & mix pill for short trip. Short trip from 8833' to 5100' (9 5/8" shoe) tight @ 7877'. Circ. hole clean. POH for logs & SIAM. Service MWD & Navidrill & lay down same. RU Schlumberger & prepare logging tools. Run logs DIL/LDT/CNL/GR. Wireline depth 8831'. RD Schlumberger. Change BRA & make up bit. RIH to 4722'. Cut drlg line. RIH to 8833' (no tight spots). Circ. & cond. mud for 7" csg. 5-19: POH laying down pipe & BHA. Pull wear ring & change rams to 7" & RU csg crew. Run 7" csg 223 jts 7" 26# L-80 Buttress. Float shoe @ 8822'; float collar @ 8742'. Btm ECP @ 8538'; top ECP @ 8518'. Machine joint @ 8217'. 25 ea. rigid centralizers & 37 bow type centralizers. Broke circ. @ 5100' & 8100'. Partial loss of returns. Circ. and reciprocated csg, attempting to get full returns. Attempt to land csg & energize packing; pulled hanger to rig floor & inspected. Relanded OK. Energized pack off test to 5000 psi. Pump 35 bbls 12 ppg Sepiolite spacer followed by 5 bbls H_O, test lines to 4000 psi; pumped 56 bbls of 15.8 ppg Class "G" cmt w~l% CFR-2, 3% Hal-24; followed by 334 bbls of NaC1/NaBr 10.2 ppg brine. Used top & btm plugs. Bumped top plug to 2800 psi, floats held. 5-20: Transfer NaC1/NaBr to pits, RD Halliburton cementers. RU Dresser Atlas & prepare to run Gyro & top job w/Halliburton. Run #1 - Gyro/GR/CCL, tool malfunction @ surface; Run #1 Gyro/GR/CCL, surface to 8716'; prepare to run perf guns (Dresser Atlas 10' short on lubricator); Run #2 - perf w/5" csg guns 12 SPF, 8650' to 8630'; Run #3 - misfire on 20' gun @ 8630' to 8610'; Run #3 - perforate 5" csg guns 1% SPF, 8452' tO 8457'; Run #4 - perf w/5" csg guns 12 SPF, 8481' - 8487', 8327' to 8344'; Run #5 - misfire @ 8630' to 8610'; Run #6 - perf w/5" csg guns 12 SPF, 8630' to 8610'; Run #7 - junk basket, gage ring, CCL, surface to 8600'; Run #8 - RIH w/BOT '28' packer, packer set @ 8527'. 5-21: RD Dresser Atlas, change rams to 3½", test 32" rams 500 & 5000. RU csg crew & CAMCO tools for tbg run. Run 265 its 32" 9.2# L-80 BTRS tbg: space out and set 'HB' packer @ 8138'; BOT '28' packer set @ 8522' drillers depths; 'HB' packer set w/2400 psi shear out. Displace tbg to diesel + 20 bbls. Final circ. press 1175 psi. Drain stack & back flow & final press shut in 1075 psi. Land tbg & energize hanger packoffs - test back side to 1500 psi & operational test SSSV; test good. LD landing joint & install BPV. k~ BOPE & change rams back to 5". NU tree & test packoffs, adaptor flange, control l~e~'!5000Ps~ -2- ~uparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.14- CONFIDENTIAL (7,305'-Kuparuk River) AFE 10-61-1113 API No. 50-029-21344. Ak. Permit No. 85-88. Elevation: 59' KB. Location: 839' FSL, 2134' FEL, Sec. 10, T13N, R10E, Umiat Meridian 5-22: Clean pits, blow down lines to tree, secure tree, install BPV. RIG RELEASED. -3- Tom Painter Division Manager Conocoln¢. 3201C Street Suite 200 Anchorage, AK 99503 March 5, 1987 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99510 Dear Mr. Chatterton: Production Profile Logs for Wells B-10; B-ii; C-9; C-13; C-14; C-15; C-16 Included with this cover letter are the logs and related pressure data for production profile work completed at Milne Point prior to shutdown. This information is submitted to the State as per Rule 9 of the Kuparuk River Field Rules. If you should have any questions or comments, please contact Mr. Don Girdler at 564-7637. Division Manager DRG/vv Tom Painter Division Manager Conoco inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Poin.t Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Miine Point Unit. There are 19 active and 5 inactive production wells at Mi!ne Point. ACTIVE: B-3, B-4A, B-6, B-9, B--10, B-ii, B-13, B-15, B-16, C-l, C-2, C-3, C-4, C-5A, C-7, C-9, C-13, C-i4, C-16 STATIC: B-20, B-2!, B-22 C-17, C-18 Ail active production wells will be freeze protected by displacing the top 3000' of the tubing with a 1:3 diesel:oil mixture. The annular fluid levels will be monitored for leaking gas lift valves. If necessary the production casing annulus will be displaced with a diesel:oil m~:ture to at least 3000'. Once the shut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SCSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive water injection wells in the Milne Point Unit. r~. ~_L.~'-' ! '~/ ~L~'~ ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-ii, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. %hough only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-i; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the-glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. The wellbore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix will be used to carry the inhibitor. if you have any questions on the shutdo~ procedure please contact Don Girdler at 564-7637. Yours very truly, Painter ~ ~~i. sion Manager STATE OF ALASKA ALAS[ 3IL AND GAS CONSERVATION COMI~..--.$1ON APPLICA'riON FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown Re-enter suspended well © Alter casing ~ Time extension 72 Change approved program [~ Plugging ~ Stimulate ,~ Pull tubing .,~ Amend order ~ Perforate ~ Other)~ 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Ste. 200, Anchorage, Alaska 99503 4. Location of well at surface 839' FSL, 2134' FEL, Sec. At top of productive interval 378' FNL, 3639' FEL, Sec. At effective depth N/A At total depth 454' FNL, 3306' FEL, Sec. 10, T13N, R10E, U.M. 14, T13N, R10E, U.M. 14, T13N, R10E, U.M. 5. Datum elevation (DF or KB) 59' KB 6. Unit or ProPerty name Milne Point Unit 7. Well number C-14 8. Permit number 85-88 9. APl number 50-- 029-21344 10. Pool Kuparuk River feet 11. Present well condition summary Total depth: measured 8833 feet true vertical 7305 feet Plugs (measured) Effective depth: measured N/A feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth Structural Conductor 80' 16" To Surface 115' Surface 5064' 9 5/8" 1625 Sxs 5100' I n termed late Production 8788 ' 7" 273 Sxs 8822' Liner Perforation depth: measured 8610'-50' ;8576'-96' ;8481'-87' ;8452'-57' ;8327'-44' true vertical 7141'-70' ;8576'-96' ;7045'-50' ;7024'-27' ;6930'-43' ~ue Verticaldepth 115' 4533' 7296' Tubing (size, grade and measured depth) 32" L-80 8546' ; Packers and SSSV (type and measured ~e~'h)SCSSV @ 1862' @ 8522' ; Ret. Pkr. @ 8153'; Perm. Pkr. 12.Attachments Description summary of proposal~ Detailed operations prog(am [] B©R.Sketcln ~ 13. Estimated date for commencing operation January 19 87 14. If proposal was verbally approved Name of approver Date approved 15. I hereb c}L_q.~tify that tOe foregoing is true and correct to the best of my knowledge Signed ~,__~--~ ~.& x__ ~£. ~£ut~ucclon Ettg.I. Ite~r Commission Use Only Date ) 2. ".,~,.~, "g/-~ Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity ~ BOP Test .,~ Location clearance OltlGINAL SIGI~[il Approved by BY 1611111[ · tMl'l'g Form 10-403 Rev 1~71-8~' ........... " Commissioner by order of the commission Date.~~ ~ Submit in triplicate ~- ~ STATE OF ALASKA ALASKA 0~L AND GAS CONSERVATION Co~r~M ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Suite 200, Anchorage, Alaska 99503 4. Location of Well 839' FSL, 2134' FEL, Sec. 10, T13N, RiOE, U.M. 7. Permit No. 85-88 8. APl Number 50- 029-21344 9. Unit or Lease Name Milne Point Unit 10. Well Number C-14 11. Field and Pool Kuparuk River I 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. 52' KB I 47437 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as an oil producing well on 12-11-85, and its suspended status should be removed. Conditions or~pproval, if any: the best of my knowled.~e. ' / Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate LOCATION IN SECTION STATE PLANE CO-ORDS. SCALE IN MtLES · FROM S. LINE FRO~ E. UNE 190RTHINGS FASTINGS 1068' 2205' 6 , 029 ,:551.58 558, ~'55.76 70~29' 26.894" CONOCO MILNE P0!H'T UNIT EXISTING DE;TELOPMENT STATE PLANE CO-ORDINATES ARE ZONE 4. ALL GEODETIC POSITIONS ARE BASED ON N A.D. 1927. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF TI~E SECTION CORNER POSITIONS. LOCATED WITHIN SE:CT. 10, T 13 N, Ri0E, U.M.,AK. GEODETIC POSITION ] LATITUDE LONGITUDE J DATE CHECt< EI~ FIELD BOOK 496' 2027' 6, 0PS, ~>80.21 558, 4:58.90 70°29'21.260" C -13 J 954' 2169' 6 ,029,2:57.39 558, 292.56 ?O°29' 25.768" 839' 21:54' 1 C-16 I --1 724' 2098' 6 ,029 , 007.58 610' 2063' 1287 ' 2273' 4:57' 2219' C-19 ] 1468' 2329' .j, 028, 894.48 6, 029,569.69 55 8';~29.0 6' 558 , 566.14 558, 402.27' 558, 185.84 558~ 248. 260 558, 128.09 ' * N. 149°:Sl'ZS'543"W' I 6.1 , 85 N 149°:51'20'280"W I II -!-85 N. 149°31'24'486"W* I 6.1, 85 '-'70° 29' 24.639" N. 70° 29' 2:5.502" N. 70° 29'2Z.587"N 70° 29'29. 044" 70° 29' 20.680" 70° 29' :50.821" 149°:51' 22' 374"W' I 149° 3l'21.357" W. 149° :51' 27. 550" W, 149° :51' 25. 909" 149° :51' 29. 208" JII - I - 85 II - 9 -85 III- 10-85 J. B.$. J.H. J. B.S. L.O. 22 - 85 22 - 85 22 - 85 46 - 85 46 - 85 CERTIFICATE OF SURVEYOR : .I HERF'BY CERTIFY THAT I AM P~OPERI_Y R[GIST£RED AND LICENSED TO PRACTICE LAND SURVEYING I~ THC STATE OF ALASKA 'C' PA D AS- BUILT WELL LOCATION CONOCO - SCALE : j SHEET : I' · 400' J 2 OF. -.-- CO~kJENTS ; John R. Kemp Manager of Alaskan Operations conoc_ Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (9071 564-76O0 August 19, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed please find the "Well Completion" forms #10-407 from Conoco's Milne Point Unit wells No. C-7, C-9, C-Ii, C-12, C-13, C-14, C-15, and C-16. If you require additional information concerning these completion forms, please contact Kent Stolz at 564-7641. Very truly yours, J R Kemp~ ~laskan Operations KJS 5/vv RECEIVED AUG 2 0 ]98§ Alaska 0{! & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA~..~ AND GAS CONSERVATION C~._MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Conoco Inc. 85-88 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, Alaska 99503 50-029-21344 4. Location of well at surface 9. Unit or Lease Name 839' FSL, 2134' FEL, Sec. 10, T13N, R10E, U.M. Milne Point Unit At Top Producing Interval 10. Well Number 378' FNL, 3639' FEL, Sec. 14, T13N, R10E, U.M. C No. 14 At Total Depth 11. Field and Pool 454' FNL, 3306' FEL, Sec. 14, T13N, R10E, U.M. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etC.) I 6. Lease Designation and Serial No. Kuparuk River 52' KB! ADL 47437 . 12' Date Spudded5-9-85 13, Date T.D. Reached5_18_85 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns5--21--85 N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8833' (7305'TVD) 8742' (7234'TVD) YES]~ NO [] 1862' feetMDI 1800+ 22. Type Electric or Other Logs Run gZL-GR-Open hole LDT-CNL- Cased hole GR-CNL-Gyro-CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 9 5/8" 36# K-55 0' 5100' 12¼" 1375 sx Permafrost 250 sx Class G " .~: 7" 26# L-80 0' 8822' 8~" 273 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number} SIZE DEPTH SET (MD) PACKER SET (MD) 8327'-8344' (Middle Kup) 12spf, 120°phasinf 3¼",9.2#,L-~t0 8546' 8153' (top) 8522' (bottom) 8452' -8457' (L-8) 12spf, 120°phasin~ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8481 '-8487' (L-9) 12spf, 120°phasin¢ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED . 8610'-8650' (LK-2) 12spf, 120°phasin~ 27. PRODUCTION TEST Date First Production I Method of OperatiOn (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. _ Nas~a 0i~ & Gas Go~s. t. mchomcje Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE _ _. · : .. . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH .GOR, and time of.each phase. KA 4,056' 3,712' MA 4,421' 3,994' NA 4,692' 4,208' - OA 4,868 ' 4,34 7' T/Kup. Interval 8,137' 6,787' Middle Kuparuk 8,324 ' 6,928' Laminated Zone 8,346 ' 6,944 ' Lower Kuparuk 8,575' 7,115'- .. _ -- 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · Signed /'~-~ J. ~ Title /J~/'o~- ~'~¢-'¢J' Date Alx~. '~. 'q~- ,~ ' . INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement. lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Directional Services Pressure Services Chemical Transmission Systems July 29, 1~85 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak 99501 Att: William Van Alen CONFiDENTiAl. Re: Our Boss Gyroscopic Survey Job No: AK-BO-50051 Wel 1: C-14 Milne Pt., Alaska Survey Date: May 1~, 1~85 Operator: J. Samec William Van Alen: Please ~ind enclosed the copy o~ our Boss Oyroscopic Survey on the above well. Thank you ~or giving us this opportunity to be o~ service. Si ncerel y, NL SPERRY-SUN~ INC. Ken Broussard District Manager Enclosure (2 copies of survey are enclosed) cc: According to distribution list CONFIDENTIAL NL Sperry-Sun/NL Industries, Inc. P.O. Box 6207, Anchorage, AK 99502-0207 (907) 563-3430 ( I" PAAE ANr':HORAGE ALASKA F:ONOE:O, INC. DATE. OF '.=;URVEY_MAY~ 1..9, .... 1':*'-'= C:- 14 COMPLITAT I ON DATE BOS:=; GYROSCOF'I C: :=;I_IRVEY MILNE F'OINT MAY 20 1'="-'= .. .-. c,._, ,_lOB NLIMBER AK-BO-50051 ALASKA KELLY BLI.'=-;HING ELEV, = _.52 00 FT ...................................................................................................................... mm. - · OPERATOR-,_I. '.=-;AMEC: VERTICAL :_=;ECTION CALCLILATED ALONG CLOt=;LIRE TRUE SUB-.'_:;EA -'F ,,-' _ L. J U R .=, E C 0 I_1R '.=-; E D 0 R- L E G T 0 T A L MEASLIRED VERT I CAE VERT I 6:AL I NCL I NAT I ON D I RECT I lIN '..:.;EVER I I'Y REF:TANGLILAR COCIRD I NATE:E; VERT I C:AL DEF'TH DEF'TH DEF'TH DEG M I N __DEG.RE__E.L=_; ....... I::IEj3/._ 1?'LC_) ...... __N. CjR__T~. H../_.L_=!_C!!~j_T_H .......... E _A.'-:;__.T_~_W. E_.~_E!.]'. ............. L=;ECT I ON 0 (_3.00 -5'2.00 0 0 N O. (') E O. O0 0. O0 0. O0 0. O0 100 100.00 48.00 0 11 S 33.60 W 0.1 ':' ' ' ' 0 '-' '""71 ' '-, ' ,- ,-. '. 200 '2(j'~F~(~ 14 .... O0 (.~ ,-, N 4.:,..:, ~ W O. ~6 O. 1 ~ o 0.27 W -0 :'::OC) '-' ]' - o(.(.) O0 24:::.00 (') 31 S 1 6'P W 0 64 0.5F, '=' 0.37 W -0.18 400 39'P. 99 347.99 0 '-":' '-' ':":' == o 10 W 0 29 ':' . . .:,(.) C) 56 W ..... ................................................. - .-' · :,00 ~ Y ? · Y ;/ 447. 600 599.99 ~47. 0 1:3 N ~/- 0 W 0 54 ':' 17 ':' ........ =, ~, 1.10 W -0.40 70C~ a':¢'~' 99 647. ';'~? 0 7 '-' '-'= 60 W 0 15 2 07 .S 1.38 W -0.70 · _ ,, ,,¢ ~ .. . . . .... ';~0(') '"":~':, 99 '-' . - ,:,;~ .... :,47.':~':~ 0 6 N 10 10 E 0 2('} '=' 15 '~ 1 55 W -0.':":' . . .:,,:, .:, · · · ~ ~ ~ .~I 140 (] 1 '-"- '- '~'" ........· :, ;~ ;~ .. ,:, 1347 9::: 0 29 S 16 ,:,'-'"'::~ E 4J~':' ~'i ..... .=,.'" 44 '".:, o' · -,='='~ ~ O. 5:3 1={-- 3 ':'32 :::9 E 9, ~--, ~, .} 0 14 'F~'P 9 c} 1447 'F/0 '-' ,:, · .... 6:30 S 16AA 1 ~'~'2 F '" 5 :,~ i ._ 47 A'2 5 ':' ':~':/ ':'{' "~ '~' ' '-' ,-' = - . ._ 17 .............. ~ E ~. ~U 1 ,:. 16 .:, ~,. 54 : ......... ?~'.,. - - m -. ~ ~, ; ._, ':~7~' 1/-,'~,'~.. .. u~"'-' 1647 , I '"{' ' '-' ,:.}0 17'P7,.AT_ 1745, ,:,7 10 ._, .=, 47 6';~ E ~' '~ '" . . J. t~;(")('} 1 "'c;~ ,-, .-, - .:~ .:, ,:.. ~..~, .:, - · ~, ~ .-, ,-,,- ,-. .-,,. .-,.~ _ ~. 20C) C} 1992 51 194 C} 51 15 19 'S ~':; 10 E ':' '-' =~ =' ':' . . . . , . m . . m · -.. 2100 ,~':' c'}':":' .4 9. 20:36 .4 '~ ]. 7 19. ._,':' 6 ._~. 19. E ~,':' 62 70.74 .:,"' ,:'] 4 . 9./-,_ _- 102. ~"',:,'-' 220 C} c, 1 ,-,.:, .:,.':, ':' ':' '~"~' 84 '=' ,= .... == .= 1 1 20 0 '-' · =, 65 :::9 E '" 6'~> 11 114 ('}:? = '~'~ ..... == 134, :::'3ClC~ ':":'~/- 43 o.:,.:, ,-. /~ .-,,:,~=- .-., ~,-, ,:/,-, =, ,-. - .... ==-_,. ~.~=4 4.3 ":'"' '-"-' . =4 ~.:, .=, o-, .-,; = z .... ,., = ,-, ,, ,,=, .-, 147. 1 ,=,"'_ ~ 69. ';/. :=:_ 24. (') 0 .-,.-, ~ ,-, .:,-:, - ~.:, =,,=, 20 Z 6 '-" - zL) '24 67 E I '-'" ,:,.) ll':' 67 '-' =-, Yo . o , 209 ~3.' . . m ~ . ,:,..~ 87 = 250 ('} ') 45 :::, ~9/-, 24 ('}/-,. 5/-, 2/-, 19 ':; 7 ('} 1 ':; Er 2, 2 F) ] .:, o, ~,:: ,:; .-:,.:,.:: ,:,.:: : o ~.=, .-,.-, .-, - (. .], ~ ~ ~ .':,.:, . .~,,:,.-,,-, ,-. ~60 .~ '"~'-'= '-"-' ':' 4:3 '"~ '-":--' ~ ~ ;-.-,..:,.:, ~ .... ~,:, .:, 7 ..... 10 E '-'._~4 1 42 S z :,7.5(] : ':,-:, ~ "-- / ~ I ,_m 2700 2634 '::2 c,~,:,.:, '::2 "" ) '-' '? ~ 5/-, ~ ' ':' '- ..:, · 'l m--m (' ' ~,:, JU 2719 A~ 2667. A~ '-'"' .- .:,.:, 30 'S ~ 4. :30 E "~ 0:3 170 1 = - . .., S :::/-,/-, ':' '-~ 400 5 2 ~? 0 0 ~ '" o '-' C'., j.~. ~.' ._, = ~ '-' / ~ ~ ~ '-':,. · :, 4~ .;.:, _ 4~7. ='-' m · :,F ERRY-.:,L N WELL .:,L. RVEY I NG F:nMF'ANY F AI,E ANCHORAGE ALASKA F:ONOC:O, INE: DATE nF "" I ' - _ . .:,I_RVEY MAY 19, 1785 C- 14 F:FiMF'I ............ ITAT I ON DATE BF~F; GYRF'I'.gF:FIP I C '-'1:, JRVEY' MILNE POINT MAY 20, 19:::~ ,JOB NLIMBER AK-BCl-50051 ALASKA KELLY BUSHING ELEV - ~'~' (~(') FT ..................................................................................................................................................... OF'ERATCIR-,J, oAME_. VERTICAL SECTION C:ALC:ULATED ALONG C:LOSURE .......................................... 'I=R'i. JE ............... E:LiB-i=;EA .... i-:F'HjR:E;E F:GURsE .... DFuz'/:i" EG-" TQTAL ME~'.=;LIREI] VERT I E:~L VERT T E:~L I NCL T NAT Z ON Ii I RECT _T ON .'_=;EVER I TY REL.'I ~1',1 _.,LIL AR CF'u-iRr'i _T NATE:=; VERT I F':~I_ DEPTH DEF'TH DEPTH f]EG M T N DEGREES REG/10(') NORTH/SOLITH E ~'.=;T /WEST SECT ;[ nN 3100 2960. · =, -" .) .) :'=:(') 4 ("). 3'3 C)O :2:119. :=:400 :31 'F,'2. ..=,.., (.) (.) 3600 :..--.:7C) 0 47:E:. 40 E 517.55 ~.-, .=;7o :'~i · _.:,7 16 E · _; ._,, ._ (.) E 6 :=::=:. ,=, 652, 42: E /=,'F/'2.. 1';,' 711.60 E 759.66 ::,._":, c,,:-']4 - o,=,.':, :':.:4 '-'""'".._,6 "': 'F~44.21 ,-~ m-! - - .-m I~_ . l- .-! .-i i'# .-! ~,-m .-! o,=, (.) L) .:,.., 14. 1 ~' .:, 4. A ~, 1 ;' .-,,-,.-,,-, .-,7 ~,/-,( ) E ,."), .,~":',=,'-' .:,'-' ~ ~,.,''' . ~n,~"" .=,'-' 948. (') 1_~ i t)(.)o' ~ ' 48 ::: 9 (') 0 ':'~'~ ]. ts' 6 '-' ='-''' ':' ~':' 91S ' (' '" .:,._, o ? 9/-, :::9 16 S 7:3.19 EE C) 7:3 1 1 1 ~ . ~ ~l._ .. m i .~ ._ i.w . 40C)0 '-' o6A9 ]'-' '-' - ' C ~ .:, & 17 ')'-' 29 ':' (.~ 54 72. 10 E 0 ~._, :377 1 .E; 1C) 68 '23 = 11 08 -- . i ._l I 4 ]. O0 o 74..,'-' =. d~ ._, = o6'-' ;~;; .:,a; ...... 6,_,~ .................... 4L)= ............. ..... = =. ..... _. .. z .~ S 71 .60 E 0 .7.5 417 .66 .=,'"' 11 '20 .7:3 E 1 ~_, 1 . 19. '-' '" J ~ .:,,=, 4,=, ]'-' ':: 9 324 4.:, t~ u 3900 c '~ ¢"-' '" ¢ .,~ 10 '-' · =, 71 6 ,:..,. 7'~ E 1 46 .......................44 (J =' L) ................... .:, :=; ':~ ~ ....... 77. ;=' c, ,:, '~' .................. .:, :=, ~6 s ~ '-; ._, ~ '~'"', ';=;;'~; o ,:, ..................... .:, :~' c, '~'' .:, .~, ~ 1 0:~ E 1449 ')'-' 45c)(') 4 C) 56 4.:3 4 C) O 4 43 37 ._ 4 S 71 ':"o E (') 66, 476 97 ':' '-'F ':* (. ,:, 4 d, 00 41.:,'-' ~, = , 36_4 ('}. ,_,o ._,.:,..:,'-' ~:, :37 5 4700 4~14'¢ ......... ..... .E;:¥ ................ 41_=2-2:fi= ......... ::'~= ........ '~: ...... 7 44 ~-~" ' 0 ~ :~ " .-¢ ' .-c 4,:,OL~ 4= .....40 4=4~. 4~ ~7 ..,~ · ~, 71. ~ .. E (J. 44 ._,.:,7.47 .:, t..,4z. 77 E ~ A..,~. ~. · ~ .-, .-,.-,(-) - 4900 4._ 7 ~. 72 4.:, ~., 7:2 :37 9 '" 69 3 (') E 1 ':' =; '~ Pi':' 04 S 1600 ' '" . ......................... '='="="o (.) (.)(.) ............ 44 ._,='~'~. ''''~o ..................... 6 4 ~'"$ ( ='=)( }. ~=.-, ............................ Z-, o:=; ......../., .,. 5100 a ~ ':,'s, ,:,,:, 44 :R (') ...... 1 '-' ..... 52C~C) 46~3 ~ ~6~ 62 :36 4 S ~4(')C) 4773 66 4721 66 37 ~'=: "" .=, E 1 1 '~'~ 6~ i ':":' '~ 1 '-"-' ' .-,o ,=, ,:, ~:~('~('~ ,~ '"~i"' 9 '-' ' " 4,=, L)(.) 19 """ .... o,:, .:, 6 '-' 70.19 '""-' ....... ~, . E 0.71 6,:, z .20 ~:, 1 ':~.. ~, '~'..,° . 64 E 2054 . ('.) ~'-' '~ ' '-'Pi - .-, · .. 700 Pi (~) (') /-, 26 40 c. 4~.._4 26 :~:~ 67 60 E 1 10 7~, C) 2 S '-' ~,-,"" ~r),-, · _,,:,UL) 1 ._ 7 ~(')29 ._ 7 41 1 06 ':' ':' '-' ') '-"~ · _,.,=,.~ _. . .~ ._,_, .=,'"' 70.:30 E . 74 ..... 57 ._, 2 .,. ~::~9(~ 0 ~ t = = :37 70 50 E 1. ' '" · _,.., 74 r410:3 74 4.2 '" ~) .=, 7" " '-' ............. =, . 7 '"'J'" ' .................................................. SF'ERRY-:3UN WELL SLIRVEYING F':OMF'ANY F'AGE ANCHORAGE ALASKA F:FINC,"':O, I NF:. DATE OE :=,L R.gEY. MAY. 1.':.-,'., lC"'"'".=, C- 1. 4 C:CIMF'LITA T I ON DATE BOS:-; C~YRI]ISC:I_]F' I C: L=;URVEY A I..'. - B U- ._, t) .)._, 1 I"1I LNE F'O I NT MAY 20, 1 ':,"-'='..: c,.J ,_lOB NUMBER " - =" (' =' ,--o ALA.=,I'...A ........................................................ VERTICAL SECTION CALCLILATE1] ALONG CLO'.=;URE ........................ KELL~..._BLIS.HING _ELEV_ =._ ._=,2. c)C) FT. CIF'ERATOR-,J. RAHEF: MEASLIRED VERT I CAL VERT I CAL I NCL I NAT I ON D I RECT I ON SEVER I TY REL. TAN_,I_ILAR COORD I NATE:_=; VERT I C:AL DEPTH DEF'TH DEPTH DEG M I N DEG._R'.E'-_E;'_-=_; ........ D_E_G/__l ¢_.'~!)_ ....... ..N]Z!.F..'_T_H_/j;,;]--]I_-!_TH __ E_A:-:.iT_/___W~L--_L'F_ ......... SE.C(T I ON ...... · ....,=.,:.,_, :.5.:'.-.: .17 6 '""'-":' 43 '-" o ,=, :, 79:3 43 '-' .=, 2247 7._'5 E . . · %.! · . . · ,..'-, 1 (] 0~'-"q, 01,04 ~i 24 ¢.'. c) 4 44 :1 ,Z-, ::; 7 o./'-, 'T.,, E 0 · 'P'.-.-., :--: :! 6. () 2 S 2:31 .'.5--: · 19 E ..... ~ ....... ]-._'.-..,'_ .%_ ................. 2-_ ....... f ..... ' ............................ '_ .-.. .......... 't ....... ". _.. -----' ................. -%- "- ................... '- '2:;~iSi~F" ' 5:372.42 5:_:,'2(:). 42 44 :37 S 71. :39 E 0./:,C) 8:38.77 S 2379.43 E 6.z, UL /_',400 .,f.-,500 6600 ./:,700 6800 /_-900 7000 · ¢. ~- '-- -'- m "' --' 2~21. , ..' ._l :: .-'· F.]ztn.=, :_=:7 5390 87 45 4/:. '-' · c., 71 .~io E 1 15 ,=,'-'/':, 1 .z,'-'4c,'-' 244/:, 70 E '-'='-?'-' 4:2: ._,._='.~ z" .."-'· 40 .~,4/.,0_ _. · 4(.')46 7 ._,':' 72 .:,'-'¢j I= . (3 · 67 ,.,':"=:'q,_ ._. 67 ':' '='F, l .'5 · ¢)2 E 2~/:,4-· :30 5/:, '"' .=, 277:6 2..':=: .=, 5':' 9 :=: 1 45 905./:, 8 c; '-' = A '-' ' ' ?]='--" '='1 .... .-.. · · .=, 72 10 E 0 ':":' ...-.., .-'~,,_o ~6 E ._ ,_1 ,--m .L ~-' · · ' - '- · d,_ E 5/,51 70 MS'P'P 7(.') 45 '-"'"' '-' ,... ,_,o · ...,.. .=, 72 :R'~ E C) 61 ,:a-_':, v 4 '=' '=' 2651 .., q =.-., ~_,..,r-)_v o- -- -- -- . ._ _ . . · m .. ~2. z # '--' ~..! · · ~'i -~ ''~ .m 76 ~.-* l c; 519 ' "' '-' · joo; 7/:, 4~ S 72 ~','P E' O. '--'~ Pg,:, '-":' · ,: ..... :, 271'P 74 E 2879 1 ... [ .. j.. . _ . . _ . . 5 7 !¢¢ TTi .... -' ...... 4 i5-: 'Fi' ............. - 74- ...... B ............... :._si -'-? 2 :: g 6'-E .................. i5': ................ ?;¢i:i';"'6 .......... i5":'2 · .' .=,._ 4 O :--: E ::~ O 1 7 3 ~=,-,/..:: ,.-¢ c,~ ,-, ,p ::: 9 'P O 2 9 '-'"'.=i ._,,:, 1 1 47: 10 '-' · . _ .=, 7:3 /:,0 E 1 '"'--' ,: .... :--; ._l,~.m ~", ._ m .. '-! m · · · - - · · - - .' · ='- '-- ':: 29 '-'C'" 3 U'(.),=, ()6 '-' -'="=;'-"-' '=- '"=' .=; ::: :=:/-, 55 4 O' ":":' ':' 7..,..=; (] E '" ,05 1 ' ' '" .:, '.."'.':" 1 ,_ E ._", J',:, 6 1 -- -- -- -- · - . .-'.! · · · ._! .': ....~ ,=, · ..!..! .~..., ._, , . .=, ..; ,:,1· ..-,:, E,:.'-'151 . :2:4 · ":'~ 'S 7/:, 0 E (] 66 1040 56 '=; :3045.10 E :3217· 0:=: · -' /-,o':"-') 74 /:,0:37.74 41' ~... 7z:O0 .......... ..... ..~.. ~_ .-, ?,.-, ,-. (') - ~.. ~.-_,-, ,-. .-, . ~ , 7 o L) t) /:, 164.4..., · 611 .-'-. 45 4.1 :, .=,76.1. E 0.46, 10 o 6.._,,:, ¢, .=, 10 .. ·/:, 1 E '"'-"-"" .:, -.- ,:,.:,. :2:7 '2-400"-' ..... ' ...... /-, ..'-.-,o:~;:;;";"'"~. ·, / ................... /-, 1 7-7,_,A ........~-':,7 ................... 4...~;;---'-:4z/:, ............ -F.:.:, ...... 7e,'" ......, J'(;:, .) ............................... E O: ............ ·/:,._,~ ................ 107=: ..... .E; ........, 4..-:5-';-5 ....... .................... :~; ............ 174 ...... ,¥;~-T, E ................ .:, ..:, ._, ,.,':; ::"~-';=:-· .:,::;"/"-, .......... 75(30 7600 7700 7o 79 0 0 ,-'R, '-: r, A A'P (')'P /:, 8 ,:= ..% %.; %. .... · , ,--1 ":'~(')") 6, ?o4 7...=,, c.,,.,O0 7059 · 3::,' '='/- C)C) 71,,'='._,'='. 42 70 :_=: 1 42 42 ' 1 ._, = t_! _! m ::~7 C)C)_ 7207.12 71 ,_,._, .='= 1~'=' 4.2 4'=',_, '"'-" ') ':'""':'. 42 ,=,,=,0(. 72:=:C~. 49 7~.~.,_, 4'.'.'; 48 .... 7.:, .)4 70 .~.._ .,. . .-, :q~-:3, ~ '"c . v.-., 5'-.' 70 42 48 '=' · --, . .', m~ '=' 76 2 9 E 0. C) 7 1 181 '=;'=' S o 6, z. / 6,.'2: E :3 :=: 17 C) 4 , · ..._1 · · · -,, - . .-f ,.~ ._") ,=. .-, . ,- .-, .-, ,-, ,=,.-., '='.., 7/:,. o .-.'7 E (.). (.).~ 1 1 .. 7.4...- .., ._-6, ~..,./_-6 E .= ....... ... 7/_', ;=,'-' 7,5.,. ,::,0'"' E 0..,.,.,'":"=' 1 '-' 1,~'-" ..... 70 !=~ 7:757 79 E .-,o,,,-, 52 ~:. ..~ .. ~t,=, '" 7 6, '-" .... -,,:,'7, ,=,(J E C). 11 1227 .79 '.=, .= .... ..: ...'-. 10 E 4 C) 14 ..",'""" 0 · ,-' '-,,v ' - o c, .-, - '=' '" '--'"'=' ' '" ¢ '=' 7'.P · =, 77...:, .'. E 0. ,=,4 1 ..4~ · 6..,.=, ..,b,_,7. Oo E 4 .),=,0. '.--; 7/:, '-'c 1 6!5 '-' ,=,J E 0 42 '='Fi"?' '-":';='"':" 50 E 4147 75 · · ..... ~ · ._--, ..~, ..._1 .. m m. '='77 '-"-? ..:,; E 0 6, 8 1272.74 ".d; 4 C) 1 :'q '-"=; ,_ o; E 4215 1'=' ,-. · .-,, .... .-,,., ~_,-. - ,-, . ,.'! .-., -).-., ,-,....-, ..,77..=,? E (.). O0 1.',=,7.._,6 .=, 4(.),=,4.6; E ......... _.4_~.~,.o~. ......... 77 '='o E 0 C) C) 1 '""= '=' =' ,, "' ? ~. · 4 %.1 '~" ~ 41C)6.57 E 4:'~C)~ 16 · _! .. n HORIZONTAL DISF'LACEMENT 4:::(').=,. 1,"-, FEET AT .=,UI_TH 7.a DE'..,. .:,1 MIN. EA.=] AT MD._= ..... .......................................................................................... :' .-__.__-_ .......... '% ...................................................................................... THE CALCULATIF/N FRUL. EDLRE.=,' '--' ! ' '-' ARE BASED ON 'THE LISE OF THREE EfIMENSIONAI_ RADIL.:,' I'-' OF C:LIRVATLIRE METHOD. '.:-'F'ERRY-::'_N WELL S_r~VEYIN3 COMF'ANY ' ~;'~E. 4 ANCFIORAGE ALASKA C 0 N 0 C I_'1.~ I N C. D A T E El F '._-': I_i R V E Y M A Y 1 '-.':;. , 1 '--~.-. ,_-,.J'-' '= C- 14 CF~MF'UTAT I ON [lATE MILNE F'OINT MAY 20, 1':"-'= . _ :.,:,._, ,JFIB NUMBER AK-BO-500Ml ALAL::KA KELLY BLISHING ELEV. = 52,00 FT. INTERPOLATED VALUE:S; FOR EVEN 1000 FEET OF MEASURED DEPTH T R U E S LI B- S E A T 0 T A L MEA'SURED VERT I F:AL VERT I CAL RECTANGLILAR C.'OORD I NATES MD-TVD VERT I CAL =. DEF'TH DEF'TH DEPTH NORTH/SOLITH EAST/WEST D I FFERENCE CC~RRECT I ON 0 0.00 - 52.00 O. 0(:) 0.00 0.00 .............. :i. i.~i~iCi ................... ~, ;:~,:, ................" .:..~; ........... ¢'4 ?,";~,,~ ................................ '~' ~"Ci~'''''''~: ...... ~., ~ ~' '-W ................ o. ~:i'i d20- ~ ............... 2 C) 00 1 ': ': ':' . .. ~ ~ ':' · 22.~.51 194(') ._1 ._7.71 60. I0 E 7.4'2 7 47 '~' :::000 ~ ...... 1 15 1 ~ 2(') 2 'F~4 ':' .:,:,~. ._ 478.40 E 11,_. ~,~, 111 .... .................................................................................................................................................................................................................................... 4000 2 ~-, 69 ' '-' '-' '~ i S 1 (') Z-, ::: ':~':' E 212.13 L) ~ .:, 617. r) 2 ._. 77 .9 . .:,.:,'" '-' ¢.~ '~.. ,:, ''~' 547 44 '"" 6 46 ~6 ~,7 ~ . '-"-' 16._,6 44 E ~ 1 44~ ~. 4400 ~/-, '-' 5000 ~'-' - ' ' ~.-,.-,,-, ,-,,:/ ~ o,:] ,D.=, .-, ,:. .~,.-~ ~= .':,.o.=, ~, 7 6L)L)L) ._,zz,:,. o; . ..,17~ ....... 7 ...... 4.: .... ==47.7.., E 771. 11 7000 ~':/'-"-' ~= ~'"'-'/ P]~ 2'F¢ 1 '-. 2'2 · _, ~ o,: ...... , ._,,:,o,: ...... 1008.06 S ,:: E 1061.45 290. :34 ,-, ' ' ') .-, 66oz.04 1166 49 '" oL)L)L /-,6:::4 04 '-"-' ..... =, .:, ._ . _ .:,. . -- ~ ~, ~ m .- o,:,.:,.:, 7 2 (') 4 7 0 ' '-' ='-' 410 ~ ....7 E 1 ~..: ...... ,: ........... / ~.., ~. 7 0 12 9 2 4 5 ':' ~ ~":":' :::(') 212.3 4 THE C~LCI_IL~T~CIN PROCEDURES ~RE B~.:,EB ON THE IJSE OF THREE D~MEN.:,~CIkI~L R~D~I_IS Off I::I_IRM~TI. IRE METHOD. ANCFIORAGE ALAF;KA _].--_!.!?.N~H--:.E!.L ._! N.E!._, I]ATE_._I]~F_:.~;LIRVEY._ HP~_Y_..1..I.-T?.~.. 1785 .. I_-:- 14 CF~HF'I_IT~T I F~N DATE MILNE F'F~INT MAY 20, 1'.-.-;85 ,_IF~B NLIMBER AK-BI'Z~-50051 ALA'.--;KA kELLY B_I.:,HINI] ELEV = 5'7' (')o FT _.- .............. m. ......... -,.~..m . _.. ~m OF'ERATOR-,_I. SAMEC I NTERF'OLATED VALI_IES FOR EVEN lOO FEET OF SI_IB-'.--;EA DEF'TH ................................. TRLIE SLIB-SEA MEA'.--;LIRED VERT I CAL VERT I CAL DEPTH DEPTH TOTAL REL. TAhluLILAR .... ~ ' L. UL RD I NATES fiEF'TH Iq_IRTH/.-..,uUTH EAST/WEST MD- T_ ~.[! .............. WES_I-_lC;_A L D I FFERENCE CORRECT I ON 0. O0 0.00 0.00 0. O0 652 752 :--:52 1052 652.00 600.00 2, 07 S 1.27 W 0.01 0.00 752.00 700.00 2.07 S 1.49 W 0.01 0.00 852.00 800.00 2.22 S 1.56 W 0.01 0.00 952.00 900.00 2.08 S 1.52 W 0.01 0.00 1052.00 1000.00 2.13 S 1.31 W 0.01 0.00 :.':;F'ERRY-L=;UN WELL SURVEYING CF~MF'ANY .......... iSsUE; ANF:HORAGE ALA.=,k.A C:ONOCO, ]:NC: ..... r:!AT.E PF_..!:!qR..V_EX_ r~..A.Y_, l_;..-?.:. .... f'!':"J'-4 C:0i,iP'iJT~-9 J:Z]ki '"riAg~: .......... I'IILNE F'OINT MAY ':.'0, 1985 , ,JOB NUMBER AK-BO-5C)051 ALASKA KELLY BU'.:;HING ELEV. = 52.0C) FT. INTERPOLATED VALUE'.--; FOR EVEN 100 FEET 01-- L=;UB-SEA DEF'TH MEASLIRED DEF'TH TRUE SUB-SEA TOTAL VERT I C:AL VERT I CAL RECTANGULAR COORD I NATES MD-TVD I I--' VERTI _.AL . C 0 R R E C T I Fi N 2273 2252. O0 2200. O0 94./_-,'Fy S 137.89 E 21.58 6.7C) 2382 :2352. O0 2300.00 110. 'PO S `177 · OR E 3¢). 22 :::. 64 2492 2452.00 ' 2400..00 127.88 '....; 220.7:=: E 40.68 10.46 , 2720 2/_-,52.00 2600. O0 15'2.11 S :::25. :31 E 6:::. 61 15.28 2839 2752. O0 2700. O0 176.36 .'=; :::87.6'2 E 87.75 19.14 :372(:) '-'"="-' r':ON OCO, I NC. F:- 14 MILNE POINT ALA:Z:KA SPERRY-SUN WELL SLIRVEYING COMF'ANY PAGE ANCHORAGE ALASKA .............................................................................. DATE_CIE jz;IJR~/EY_MAY _1~."..-,', ..... 1 '.-7/L.::5 .. COMPUTATION DATE MAY 20, 19R5 dOB NLIMBER AK-BO-50051 .......................................................... _KELLV._...BUL=;HINF,_'_.ELE?_ ...... _=_ 52,.00 ET. OF'ERATOR-,_I. SAMEC INTERPOLATED VALLIES ..~!._'.!.R_.'.....E_.WE_N.._!OC.~' . FEET..OF .F;_I:IB]SEA__ DEF'T_H ]'RUE MEASLIRED VERT I CAL DEPTH DEF'TH ::; I_1B - ,.z; E A T 0 T A L VERT I CAL RECTAN_d_ILAR C:C"]RD I NATER MD-TVD VERT I C:AL NURTH..=,ULIff H EA'.-Z;T/WEE:T DEPTH D I FFERENF:E C:CIRREE.'T I ON 41 C '-' '" ~ ='-' 0 (:) .:, 7 t) } 00 .) ,_~ *-, ' "( -'-,,.%, ..:,/._, ...-. . . ....... :':l 7 ............... ............ hi1 .............. ...................... 4 :'4/-,A '-'"' ="-' ...........· :, ;/._, .*' 0 (') :-*:'-.'~ (9 ('). 00 4 .=i, ('). '-'z,~.."" S 4494 4052.00 400C). 00 475· :s:7 :$; Z[6 ... 1 415~ 00 4100.00 4.747 ~._... ,/'.'-"F,':' 00 420C).. 00 4 8 7 4 '~--,- ._q._. ~ .,-'-'. 0 0 , 4:3 0 0 .0 0 4¢/'~:) 4452.00 4400. O0 5123 4552. O0 4500, O0 · '.:1247 4652.00 4600.00 5:::72--- .... zFT~.. ;-f~.9 4700· 00 F'~499 4852. O0 4800. O0 ' .:,.., 6 · .:, C) :'.-] (9 4'"::' ( .:,..,. 1:3 E .......................................................................... :---2-.~: .. ?- ...... ~'. ..................................... '-' /-,0 E '.-.'9 7:_3 1 .' 1 :z: · .*:,,z,/. 0':' -- o_1 ~_! _l. 1 '-"':'/r~ 7 6,E 414. '.'? C) ":"=' 8 7 ,a:... -.- · · . ,a~ '--' · :1.":'/*~ 76 E 442.'-"-' · .:,,:, 27 4L--: · _, _! ._ · .............................. 501.26, S 1439.28 527· 06 S 1512,34 552.49 S 1585.38 604.85 S 1725.41 630.06 S 1793. '.'70 E 4 6 9. C) 7 2 6,. 6 9 E "=' ~ 2'6,. 5(:) 4 ...¢'._,.._ 7 E 5..-.,.:. u 4.3 .... E 54 7 '-' ~ '::'=i :30 E 571. '7(:) 24., 4.0 E ._ .=, '-' ~,..., =· 5 1 .,--'-:' ...,':' . ,_,':' ('). ........................................................................................................................ E E,..': (.) rq-=' '": .... ', z._, .04 · -%, .'~ E 647.76 .~7. ~1 · =,FERRY-.=,_IN WELL I · =,_RVEY NG C:nMF'ANY ANCHORAGE ALASKA C 0 N I"IC I-I :, ~. N C:. I-:-- i 4 I-:1-1M F' I_1T A T I lEI N FI A T E MILNE F'OINT HAY 2('), i '-? '--' F,.. ,_,._ ,_lnB NUMBER AK-BO-.S")'''=._ ,. ,.,._, 1 ALA'.--:KA KELLY BLI'.-':HING ELEV. = i-,~;~'R'Ai'OR-'-I-,' i~;~H~L=: F, AGE DATE AF F.;LIRVEY MAY 1'--'.. , 1'-? '-' :.-. ,:,._, ="-' 0(') FT ._I .-' · . . INTERPOLATED VALLIEF; FOR EVEN 1Cx) FEET OF.:,L""IB-.:,EA'-' lIEF'TH TRLIE MEA.:,L RE[ VERT I I]:AL DEPTH DEPTH SLIB-L=.:EA TOTAL VERT I F:AL RECTANC4LILAR CI31]IRD I NATES MD-TVD VERT I CAL DEF'TH Ni-IRTH/SOLITH EAST/WEST DIFFERENCE CCiRREI-:TIOr, I 7957 6652. O0 6600. O0 1159.93 S 3538.24 E 1:,::05.39 33.55 80'.-.?0 6752.00 6700.00 :1. 180.44 S 3623.4/_-, E 1:.'-:38.37 32. '.-.78 ,:,.":,..':,.:, z ,-,,=.-, 0 0 '-' ' ' 6 ,:, o u. 0 0 1 "' ') ':' '" ';'")'" =/' ':'":' ,::.~. 1 0:'-: E 1 :-::71 ':":' '? 1 .=,/',.. ,=~, · .,I :..~ ._, .~. ,_, .,:.." ._, (D ,-,.-I d~,, . .-' . ~ '..' · '-"-' '-"-' C)/:, ,-"-' =" /- '-?.=,'.'::' ,rE) () /.:,'-.-.' (') C). (') 0 1 ~ ..' 1 1 '-T., '=':':: 7'F.-' 4. C) 0 E 14 c:, 4 :q 4 . .... ii . . · ."e ..~1 · ,=, ..=, ._1 ~, _, ..._ .,_ · .., L=:490 7052.00 7000.00 1241 · 21 S :38:=:0.56 E ]. 4:_'-::,::. 1 1 :3:3.77 ,-,/..-, ~ r~.-., .-',,- ,-, . · .:, :.,'/:,,:, · '? ::: '.q ,:, :,,:. ,. 71 0 0 710 0 0 0 12 61 ''=-- c ':' .::, .) ._, E 147:3 10 ._ 4 99 · ,,.l,* · , -- · il . . :-::761 -"-":'-'/z ...,-'. C) 0 7 :T_., 00.00 1281 . :_--: 0 ._,':' 4 nr-~:::. _ _. '-?'-.-..:, E ' 1 !'"-;. .... 0,."..> . 1 '7 !J'~'.7,"~'-6~'--~ '=":":":' 7 :q 04.70 -,--, F, "' 70 1 ":' ':~ o 45 ':; 41 C) 6 57 E 1 F,".":' '-' ') · :,L 19:1.2: ,__ll__I ~,.1%..I . . / ,~. 'm "' ii .l:~ ,' "I ,__ · ,. & I..I It . THE CALC:I_ILATII-fN FRI_IL.E[LIREo IJ'.--;E A L IN[AR I N1 I=RFI_ILA FI CIN BETWEEN . .. '"~ ' * ' "l" THE NEAREF;T 20 FOOT MD (FROM RADILIS F',F L._IRVATLIRE) F-JINT.:, SFE'RRY-.S..N WELL F-';_,H:VE~ i'N;_-.i '~ii~;MF,'A'~-(F F'AGE. 9 ANCHORAGE ALASKA · _ ?DNCJL-_:.O_ ..... ! NFl, DATE nF ..,: ....RVE_Y_.hIA¥ ..1.?_, 1 '?:::5. C- 14 C:nMPLITAT I F~N DATE..' MILNE F'L]INT MAY 2F) 1'--~'-'= ., ;,:,._, ,_li]B NUMBER AK-BO-50051 ALASKA KELLY BLIRHING ELE_V_ = ~'-' OF) FT ...................................................................................................................................... · .............. ?...' # .... · OPERATOR-,_!. SAMEC: ............. ! N _T._ERF'I,-'J,.LA.,T, EEL VALL!E:::; F0~._. F:PEC I nL __SLIRVE¥ .F'.01N._T..:=L ................................................................... TRUE '.::;LIB-F;EA TOTAL MEASLIRED VER T I CAL VERT I CAL RECTANGLILAR COORD I NATES DEF'TH DEF'TH DEF'TH NORTH/SOLITH EA.=.T/WE.=. F MARKER 4201 3823.36 3771.36 417·86 S 1191.33 4264 3872·11 3820.11 430.44 S 1229.20 4307 "3?05.45 385:3.45 438.97 S 1254. ?8 4348 3?37.24 2:885.24 447, 10 S 1279.57 4515 4068.27 4.016.27 477.9I .S I377.77 4581 4120.36 4068.36 4?3.09 8 1416.09 4642 4168.53 4116.53 505.52 $ 1451.4.0 KB E KC E KD E LA E LB _g ................... E MB E !'11]: E MKR 46?2 '-" '" 4,.u,=,, 06 41~/-, 06 .~1~' :$,=, J E NA ........ ,. 7:3 8 1 - '"¢' '-'/ 4715 '-"-'" '-.'~ ":-' ~ ' 4~,-6 4174 ,._._ ~2¢) 4.7-: o 1473 ~-'E NB · ,1~ ,~ · ~ . · ,_1 # ,_ ,.i 4745 4249 97 4~97 ?7 ~-'"/' ~/- '" ..... ,-' =,..:, ~- 1._~ .1.0 "',=, 4 E N C ........ ;_'~-' .........'.~F '"-,~;-Nfl:=; .................. .~; ........... 'T-7~-; .................... £%~,- ........ ;-T ..... 7~. ................. '~ '.-n7 ................ - ~Y/:, ;, 4..'6,:,..-yz 4..' 16I"..~.~1 .,, ...'.:I 1..:,4 .=, 1 ._,z4.76 E I.q[I / ,:,._, 4 ..' ,:, · _,.. 4.~.~ ./ ...'.,4 ~_1 L--; · · .-- ._ # i--m i--m 4,~/_',o 4347j~.'-'"' 4295 '-':'2 ._._iHS ":' 1 '-' ..... _-, · _ ,=, 1 E 0 A '~7,.: ...... 78/:,7 c,._,,=,--, ..,~.=,..,.:,..- ..,-..- 1.145 5M '=' .:,4,=,o ]"" . (. ,-, E LINOONF. . · · · ,.i 7 ? 44 6641 '- :" ' ~'''''-'~ '-~ '-~ ~ "-' "''- '--' '-', / ~'' · :.~.-, ,--,,-,,:, :. ..... ! 1 ,:,7, 84 8 ..... ,~=..,. :,.:, E HKR 1 ? ........................................................................................................................................SF'ERRY-SLIN WELL '-'l.=7"~jRV'~'~'~'l~'l'~"'i':ii:'i~;~N~'' ........................................................ F'Ai-.~E' 1(:) ANr':HORAGE ALASKA r':f]NF~CO., I. NE: · DATE IZIF SLIRVEY MAY 1 ,...9, 1 '.~:--:5 ---2"...%.. % .............. ' C:- 14 CC~MF'I_rTAT I ON DATE M I LNE PO I NT MAY '.-"¢), 1 ':'/'-'=' I ' ..,... :: ,:,._, ,JOB NL MBER AI<-BC~-50¢')51 ALA?--;I<A KELLY BU".:;HING ELEV, = 5'.'2.00 FT. OF'ERATEIR-,_I. SAM~..C% ..................... · :,F E_. I Al_ ._-,1_ RVEY F'O I NT8 INTERF'OLATED VALLIES FCIR '-'" ;" '-'1' TRLIE .=,L B-.=,EA MEASURED VERT I CAL VERT I RAL TOTAL RECTANGLILAR I]:OI]IR[I I NATES DEPTH DEF'I'H DEF'TH NORTH/~::OLITH EAST/WE::;T MARKER 67.",.: 11:--:7 67 S T/I-:,LF INT :-9137 6787, 08 '-'.-q ")'"" "-'/- ~":' ":'":' E "I ' ,_-,..:,...4 6 ~,,~7.7_~ /= .... 7._,. 71 ~'~-i72_-:2~272---~i · /. o,.--¢.7., 2 4 121 '-.-,,/- '.':' S :3 7:5: 7, :2; 4 E ]9 / M K- 1 8:'::46 6?44 24 _,,_ .............. '"-~ ='- "~ 7023 74 /.:,'.~7 _1,74 1, ..... ,=, ~.~,,.. · ':'":' ~ .6:3 S .-,'-',=,'-'._, =._, ='' 6 C) E L - 7 8456 7026.70 6?74.70 1236.21 S 3:::58.22 E B/I_-7 8458 7028.1'2 6'~76.1'? 1236.51 S 3859.53 E L-8 8468 70:--:5.60 ~ 6?83.60 1237.97 S 3866.08 E B/L-8 ............,=,4,=,u ;=-T-';=-;' ~ ................. 7(.)44 ~ ...............-,0 =--" ..................... 6 ';=;.., ;.~:'5--Ze.:---.. ,~.. ,.,0 ................... 1 ~ .'~; '.5~' ...... --='-5--;=: 7 .... ~ .............. ~;;=;-~ ._.,,=, ,,:,.--~';'"'";.~-a --b_'. ... -,. ~ ................. ~-,.._ ...... ,5> ...................................... -~ 8487 7049.69 69?7.69 1240· 75 S 3878.52 E B/L-'.:.~ :_-:575 7114. ? 1 7062. '..;' 1 1253.81 S :3'.-.'~36.14 E LK- 1 861 C) CJ _ ._~ .L 8700 871..:,'-' 7131. '?¢4 707'2. ?4 1257.34 S 3951 · 19 E B/LI'.'.'.'- 1 7140.82 7088.82 125'~. 18 S 3'?,57.05 E L.K-2 7171.16 711'2.16 1265.47 8 :3'~85.'~0 E B/LK-2 7 2 C) 7 ~'-i'~' ............. Y'i]~.'i'~"~---i' ~ .................... ]i-~7'-'~"~"~-2$--"]~i 2[ij"~[']~' ~'-.'~i"~'"'-i':Z- ................. i~iLi F~'~ ?-""~i ~.]p"-r-~ 7216.66 7164.66 1274.66 :=; 4027·01 E B/KLIF'. INT. 7237. '..;'3 7185. '23 1278· :;% S 4046.24 E P.B.T.D. 7 :--:_ ('). 4 .7 C) _ .._._ ~ .'7-':.,.-=i.-., 7 0 12 9 2 · 4.5 S 41 (') .4,.. ~... 7 E T.O. SCALE :- ~ INCH ]'8 500.00 / 500. N~LNE POINT CSNOCO. INC. C-14 NAT 19. 1985 . TRUE -50~.00 AK-BO-50051 qORTH , -1000.00 , ' ' ', . ' " " 8833. 1500. O0 ' HOR I ZONTiqL. PROJECTION 0.00 5CRLE :- 1 INCH TO 2000.00 / 2000.0 HILNE POINT CONOCO. 1NC. C-14 MR~ 19. 1985 RK-BO-50051 2000.00 4000.00 6000.00 8000.00 VI ~ 7so4. 'm 8833 VERT I CGL PROJECT I ON 20bo. oo 4oko oo _, [ t . Suggested form tob'é inserted in~ch "Active" well folder to check for timely compliancèwith our regulations. (!- /'1 . Reports and Materials to be received by: þ - ;¿.~- ?~ Date Required Completion Report ~ Mud Log Core Chips Core Description Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Log Run Digitized Data e&: _.".~..."_."~".."._...,,..-.. ~..,,-_..~~_'- . Date Received Remarks ~ u cJ - ð t I-I -~¡ ""'ql:1ølWl. us - ~ s 7-3/-KS .,,.1:'J~ m - -'~I '7~ð 5--r~ h - 1~8:~ 0 CONOCO, INC. ~ 3201 "C" STREET, SUITE 200 SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. T~'XAS 77001 POUCH 340069 3UNE 30, 1985 PRUDHOE BAY, AK 99734 ATTN: HOLLY BURGAN ANCHORAGE, ALASKA 99503 Attention' MIKE BRADSHAW Gentlemen: Enclosed are2 BLprints of the 2" & 5" DIL, L~DT~CNL, CASED HOLE CNL/GR & CYBERI6~.C)K. Company CONOCO INC. ,Weil ~EL~~~:,~::~:/ , Field MILNE POINT , County~N ~'~~?~?'-~O~:~~' ALASKA Additional prints are being sent to: 1 BLprints & 1RF ~FEST COAST & ALASKA DIVISION, 290 MAPLE COURT, SUITE 284 VENTU~.A, CA 93003 ATTN~ PHiL SALVADOR 1 BL prints & 2RF CHE~v-RON U. S.A. ,- I.NC. P.O. BOX 107839 A~NCHORAGE: AK 99510 ATTN: J _ L ~- WEA'v-ER 1 BLprints & 1RF CONOCO, INC. P.E.S. RESERVOIR SECTION OFFS.HC]iE BgiLDiNG ~.0. BOX 2197 HOUSTON, TX 77252 ATTN: GERALD KIEL c/o GEORGE LAMB 1 BLprints CONOCO, INC. P.O. BOX 1267 PONCA CITY, OK 74603 ATTN: H.E. GILLILAND/6356RW 1 BLprints & iRF ALASKA OIL &'GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ATTN: WILLIAM VAN ALEN l~rin~ &'i RF CHEVRON U.S.A., INC. P.O, BOX 8200 CONCORD, CA 94524 'ATTN: DAV~ ENGSTROM c/o LOUIS KLONSKY 1 BL prints & 1 RF CHAMPLIN PETROLEUM COMPANY P.O. BOX 1257 ENGLEWOOD, CO 80150 ATTN: DALE BOSSERT c/o BILL KIRSCHNqER 1 BL prints & !RF READING & BATES PETROLEUM CO. 3200 MID- CONTINENT TOWER TULSA, OK 74103 ATTN: C.E. SEERY, JR. The film is RETURNED TO CONOCO We appreciate the privilege, of serving you. RECEIVED BY: Very truly yours, ...... SCHLUMBERGER OFFSHORE SERVICES CATHERI~ G~0~KI rlI~TR ICT MANAGEI~ CONOCO, INC. 320i "C" STREET SCHLUMBERGER OFFSHORE SERVICES ANCHORAGE, ALASKA 99503 Attention: MIKE BRADSHAW A Division of Schlumberger Limited HOUSTON. TEXAS 77001 PAGE 2 OF 2 3UNE 30, 1985 PLEASE R~-PL¥ TO SCHLUMBERGER OFFSHORE SE:I:WICES POUCH 3400 69 PRUDHOE BAY, AK 99734 ATTN: HOLLY BURGAN Gentlemen: Enclosed ore r~rints of the 2" & 5" DIL LDT/CNL, CASED HOLE CNL & CYBERLOOK. · - ' .on: Company CONOCO, INC. , Well MILNE POINT UNIT C-14 Field MILNE POINT , County NORTH SLOPE Stot~- ALASKA Additional prints ore being sent to: i BL prints & 1RF CITIES SERVICE OIL & GAS CORP. P.O. BOX 939 BAKERSFIELD, CA 93302 ATTN! NEIL BUTTRAM JIM QUINN prints prints prints prints prints prints prints The film is RETURNED TO CONOCO We appreciate the privilege of serving you. RECEIVED BY: -~ ..... DC?ri DATE: ~ j/? . ~\L%..E I. Ve~ truly yours, Alaska 0~ & Gas Cons. Commission SCHLUMBERGER OFFSHORE SERVICE5 Anchorage CATHERINE GADOMSKI STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO~_~vllSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~] OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 85-88 ddrp.~ $. APl Number 3'A3-201 "C" Street, Suite 200, Anchorage, Alaska 99503 50029-21344 4. Location of Well SURFACE: 839' FSL, 2134' FEL, Sec. 10, T13N, R10E 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 6. Lease Designation and Serial No. ADL 47437 12. 9. Unit or Lease Name Milne Point Unit 10. Well Number C-14 11. Field and Pool Kuparuk River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe' Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The C-14 well was originally completed as a single selective with the Lower Kuparuk (2) (the bottom lobe of the Lower Kuparuk Formation) as the primary sand and the Middle Kuparuk as the selective. We now propose to finalize our completion program by fracture stimulating the Lower Kuparuk (2) then wireline perforate the Lower Kuparuk (1) through tubing. Our objective is to improve the productivity of the Lower Kuparuk (2) so that it will deplete consistantly with the L.K. (1) (on the average the permeability of L.K. (1) is approximately twice that seen in L.K. (2)). On a number of the "C" pad wells the post completion flow test left significant fill in the casing. Prior to the fracture treatment each well is to be checked for fill. If the C-14 well has insufficient rat hole remaining (minimum of 35') a coiled tubing unit will be used to clean-out to PBTD. RECEIVED J U N 2 0 1985 Alaska 0ii & Gas Cons. Commission 14.1 here yl~C'~c-~r~t'tfy that the fo,regoing is truefahd correct to the best of my knowledge. Signed ~--_~//~,,,,~ - .~k Title The space below for Commission use Anchorage Date 6-17-85 Conditions of Approval, if any: O~I~i. tiAL SIGNED BY Ll)~lE C. ShtlTI~i By Order of Approved by COMMISSIONER the Commission Approved .R~turned Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ADDITIONAL TAPES TO: = * ' CITIES SERVICE : BAKERSFIELD, READING & BATES : TULSA, OK CHAMPLIN : ENGLEWOOD, CO CHEVRON USA : ANCH, AK ALASKA OIL & GAS: ANCRORAGE SCHLUMBERGER OFFSHORE SERVICES CONOCO AK : ANCHORAGE 500 W. INTERNATIONAL AIRPORT ROAD CONOCO : PONCA CITY, OK ANCHORAGE, ALASKA 99502 · LOCATION ' ~, ~_/.z/ s~.~v~c~.s - /--~//zx:: s~.~v~c~s - 000085, COMPUTING CENTER PRINT CENTER NO. OF BOXES' JOB NO. ' ADD'L TAPES ' NO. OF BOXES' JOB NO. ' ADD'L TAPES ' WELL NAME SERVICES J 0 B NO. · ~O~/f,~7 ADD'L TAPES ' ~ WELL NAME ' SERVICES ' NO. ~~XES: ADD'L TA~pfP WELL NAME SERVICES NO. OF BOXES' JOB NO. ' ADD'L TAPES ' SCHLUMBERGER COURIER NO. OF BOXES' JOB ~,u. : /~ '/ ,f~.yVr' m .Alaska 0ii & Gas Cons. Commissio~ Anchorage DATE DELIVERED RECEIVED BY ~1 AI I- UP ALASKA .~ ALASKA '.AND GAS CONSERVATION C~, MISSION u~'- MO ITHLY REPORT I= DRILLING AFID WOI:tI(OVER OPERAT,oNS · Drilling well ]~ Workover operation [] 2. Name of operator Conoco Inc. 7. Permit No. 85-88 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 50- 029-21344 9. Unit or Lease Name Milne Point Unit Section 10, T13N, RiOE, U.M. 4. Location of Well at surface 839' FSL, 2134' FEL, 6. Lease Designation and Serial No. ADL 47434 For the Month of. May ,19 85 5. Elevation in feet (indicate KB, DF, etc.) 52 'KB 10. Well No. CNo. 14 11. Field and Pool Kuparuk River Field Kuparuk River 12. D~th at end of month, f~ta~e driile~, fi~ing jobs, directional drilling problems, spud date, remarks Spud Date: 5-9-85 Drilled surface to 8833' MD during the month Depth at end of month: 8833' 13. Casi~ ~ ~in~ mn a~ quanfiti~ of c~ent, ~ults of pressure tests Run 129 jts. of 9 5/8", 36#, K-55 BTRC csg. Pumped 40 bbls of 11 ppg Sepiolite space~. 1375 sks. of Permafrost E w/5# gilsonite and 250 sks Class "G" w/ 3% salt & 1% CFR-2 Run 223 jts. 7" 26# L-80 BTRC csg. Pump 35 bbls. 12 ppg Sepiolite spacer. Pumped 56 bbls of 15.8 ppg Class "G" cmt. w/l% CFR-2, .3% Halad-24 followed by 334 bbls. of NaC1-NaBr 10.2 ppg brine. 14. Cori~j re~,~r.e a~ml b~r~ef description None 15. Lc~ run a~ d~h where run DIL-GR 8823' - 5100' 4000'. Open hole LDT-CNL 8797' - 7800'. Cased hole GR-CNL 5100' - RECEIVED 16. DST data. perforating data, shows of H2S, miscellaneous data None JUN 0 985 A, laska 0i# & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 i4, MEMORANDUM State¢of-A'f'as ka TO: THRU: FROM: ALASKA OIL AND GAS CONSERVATION CO~4ISSION C. V ~t~erton Chai~ Lonnie C. Smith Commissioner Bobby Foster'y;;~' Petroleum Inspector DATE: FILE NO: TELEPHONE NO: ~" 1985 May 20, D.BDF.37 SUBJECT: Witness BOPE Test on Conoco' s C- 14, Sec 10, T13N,R10E,UI~, 'Permit No. 85-88. Monday, May 13, 1985: The BOPE test began at 9:30 pm and was ~clUded at11 :00 pm. As the attached BOPE test report shows there were no failures. in summary, I witnessed the BOPE test on Conoco's C-14. Attachment 02-001AfRev. 10/79) Q&G /14 5/84 () ç STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Location: Sec Drillin Contractor Well Operator Well Test Results: Failures 0 ACCUMULATOR SYSTEM Full Charge Pressure 3 1 0 0 psig Pressure After Closure' / 700 psig Pump incr. clos. pres. 200 psig mi~sec. Full Charge Pressure Attained: ~ min~~sec. N2 Stfd /9.50 /~/8s;o psig Controls: Master Ljé:...-.5 Remote Ljt!:..:S Blinds switch cover Lje.~ Kelly and Floor Safety Valves Upper Kelly / Test Pressure ..5~()D Lower Kelly I Test Pressure S'lYfJo Ball Type) Test Pressure 50ðó Inside BOP I Test Pressure f tTlT-O 'Choke Manifold~Test Pressure,",",:~ 110 No. Valves 9 No. flanges ;Z ~ Adjustable Çhokes ~ Hvdrauicall 0 erated choke / Test Time ~hrs. . ~Iud S stems Trip Tank Pit Gauge Visual Audio ¡,~ Flow Monitor Gas Detectors v' Kill Line Valves Check Valve :BOPESEåèk Annular Preventer Pipe Rams Blind Rams Choke Line Valves . H.C.R. Valve Repair or Replacement of failed equipment to be made withiIb...--, Commission office notified. days and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspect~1 ¡¡¡. ~¿ t. .. :. '!'A""''¡.'' - May 3, 1985 Mr. Don Girdler Engineer Conoco Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 Re: Milne Point Unit No. C-14 Conoco Inc. Permit No. 85-88 Sur. Loc. 839'FSL, 2134'FEL, Sec. 10, T!3N, R10E, UM. Btmhole Loc. 452'FS~L, 3382'FEL, Sec. 14, T!3M, R10E, L~M. Dear Mr. Girdler: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter survey~ S. Many rivers in Alaska and their-drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and.the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. 'Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Don Girdler _r Milne Point Unit C-14 -2- .... 'May 3, ]985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter syste~m is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or .abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yo~,urs, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug Tjx. Lowerv~ John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 April 29, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Permit to Drill application for Milne Point C-14. A $100 check is being submitted with the permit application to fulfill the permitting fee requirement. If you have any questions, please call Don Girdler at 564-7637. Very truly yours, ~askan Operations DGH/vv cc: MP C-14 Correpondence File RECEIVED MAY 0 1 1985 Naska 0~ & Sas C~.s, ~ STATE OF ALASKA ALASKA ~I/,L AND GAS CONSERVATION COI~-rMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL:~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Conoco Inc. 3. Address 3201 "C" Street, Suite 200, Anchorage, AK. 99503 "" -t/VEo 4. Location of well at surface MA 839. Fsi., 213~. ~E~., Sec 10, n3., mOE, U.M. ¥ 0 ] At tOp of proposed producing interval A~ 0il & Gas Coni,,851Ct 350' FNL, 3700'FEL, Sec 1~, T13N,RIOE, U.M. ArlCJ;Ol.~g;'"' Corl'lrllj At total depth 452' FNL, 3382' FEL, Sec 14, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF etc.) KB 52' Pad 17' 6. Lease designation and serial no. ~L 47437 9. Unit or lease name Milne Point Unit 10. Well number C No. 14 '~¥.//Field and pool Kuparuk River 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-54 Amount $200,000.00 15. Distance to nearest drilling or completed C-13 120 well feet 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 33 mi NW of Deadhorse 3256' at surf - miles feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease '8,768' MD 7300'TVD fec. t 2,560 19. If deviated (see 20 AAC 25.050) [20. Anticipated pressures KICK OFF POINT 1400 feet. MAXIMUM HOLE ANGLE 39' gl(see 20 AAC 25.035 (c) (2) 21 18. Approximate spud date 5/07/85 3230 80nP psig@~ Surface 3800 psig@ 7300 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole I Casing Weight 12k". 9 5/8'~ 36 B~"I 7- 2~, I 22. Describe proposed program: CASING AND LINER Grade I C°uplingl Length H-40 k'~;bF { 80 ~ [ U 71~6' SETTING DEPTH MD BOTTOM TVD ltd~ I lA5i 5250, I 4600' I UTb~' i 7300~ MD TOP TVD 35' I ~b' 33' I 33' [ . . 3z' i ~z' I QUANTITY OF CEMENT (include stage data) ±i00 cf Cmt .. · 2500 c~ Cmt ±290 cf C~ Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River field. The mud system will be low solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T.D. will be 10.2 ppg. A 20", 2000 psi diverter will be installed on the 13 3/8" conductor for drilling surface hole. A 13 3/8", 5000 psi RSRRA BOPE stack will be used on the surface, casing. Pressure tests will be performed as per State Regulations. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is C No. 13 which is 120' northwest of C-14 on the surface. Arctic pack will be placed in the 7" X 9 5/8" annulus after disposing to test oil and excess drilling fluids. The well will ~e perforated and completed before releasing the drilling rig. .It will be flow tested after the rig is released. 23. I hereb~ify that the foregoing is true and correct to the best of my knowledge TITLE Engineer DATE April 29, 1985 The space below for Commission use Samples required '~--YES ~.N 0 Perm,! number APPROVED BY Form 10-401 CONDITIONS OF APPROVAL Mud log required Directional Survey required I APl number []YES ,~O ';~-..Y ES [--INO I 50- d 7_ ~- %. ) ~ ~- z?/ Approval date / ,/~ ~ Y ~~~'~~COMMISSIONER DATE 1V~y 3' 1985 ~~~ by order of the Commission Submit in triplicate SUPPLEMENTAL DATA SHEET~- APPLICATION FOR PERMIT TO DRILL Conoco et al- Milne Point NojfB~14 Conoco Inc. 3201 "C" Street, Ste 200 Anchorage, Alaska 99503 CEMENTING PROGRAM Ae The 13-3/8" conductor will be set at 80' below the surface (115' K.B.), then cemented to the surface with permafrost cement. Bo The 9-5/8" surface casing will be cemented with ±1125 sacks of Permafrost "E" cement followed by ±250 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The first stage will consist of ±250 sacks of Class "G" cement pumped around the casing shoe (estimated ±1400' of annular cement, based on 100% excess over gauge hole). The secondary cement job will consist of ±180 sacks of permafrost type 'C' cement followed by 60± barrels 'of Arctic Pack pumped down the 7" x 9 5/8" annulus. II. ANTICIPATED GEOLOGY 0' - 4500' Surface conglomerates, clay, silt and sand sequences. Estimated base of permafrost at ±1700'. 4500' - TD Predominately shale until the Kuparuk Sands - expected at ±6700' subsea TVD. III. FORMATION EVALUATION Ae Wireline logs for the 8~" hole (from T.D. to ±1000'above the Kuparuk interval) will include: Dual Induction log; Spherically Focused log; Litho Density log; Compensated Neutron log - Gamma Ray. IV. DRILLING FLUIDS A high viscosity fresh water gel (non-dispersed) mud system will be used from 0'-1000'. RECEIVED MAY 0 I 1985 AJa, sKa Oil & Gas Cons. ColiltlliSsiorl Anchorage VJ A low solids non-dispersed gel/water mud system will be used from 1000'-Surf. Csg. Pt. Low solids lightly dispersed mud system 5250'-T.D. DIRECTIONAL PROGRAM The C-14 well will be drilled to a proposed KOP of 1400', then build angle in a south 72.25° east direction. The closest that the C-14 will come to another wellbore is from surface to KOP, where the proposed C-14 will be 120' southeast of the existing C-13 well. An MWD tool is to be run while drilling for surveying purposes. Final hole angle will be 39.9°. The proposed depth is an estimate only. If actual depth exceeds the permit depth by over 30~T, a Sundry Notice will be submitted. RECEIVED MAY 0 l t985 Alaska Oil & Gas Cons. Commission Anchorage M-ii NI~-PT~-NO~TH- SLOPing' ALASKA EASTMAN ~/FJIPSTOCK. INC. 0 . SURFACE 1 000 _ 2000. 3000 _ 4000 _ $000. 6000 _ 7'000 _ 8000 _ KOP 10 15 20 25 30 35 TVD=I 400 TMD-I 400 DEP=O _ . . BUILD 2 I/2 DEO PER i O0 FT EOB TVD=2869 TMD-2995 DEP=533 g 5/8' CSO PT TVD=4600 TMD-5250 DEP=I 97'9 AVERAGE ANGLE :39 DE(; 52 TARGET TVD=6900 TMD=8247 DEP=3900 'TENTAT[VE' TD TVD=?300 TMD=87,68 DEP=4234 RECEIVED MAy 0 1 1985 i i I 1 000 2000 :3000 VERTI C^L SECTION i I 4000 5000 HORIZONTAL PROJECTION SCALE 1 IN. - 1000 FEET CONOCO, PAD C, WELL NOt 14 PROPOSED M[LNE PT.. NORTH SLOPE, ALASKA EASTMAN WHIPSTOCK, [NC. o 1000 _ 1000 _ 2000 _ :3000 . 1000 0 . I, WEST-EAST 1000 · 2000 SURFACE LOCAT ! ON ~ 839' FSI., 2134' FEL SEC. 10. T13#. RIOE TARGET LOCATIO#t 350' FNL, 3?00' FEL SEC. 14, TI3#. RIOE S 72 DE~ 15 MI N E 3900' (TO TARGET) 3000 I, TARGET TVD-6900 TMD-8247 DEP-3900 SOUTH 1189 EAST 3714 4000 I 'TENTATIVE' TD 5000 I 6000 I NORTH ~00 :)00 _ 100 _ 100 _ 200 _ 300 _ 400 2OO I O0 6692 100 200 300 400 500 , ,. I I I t L CONOCO. INC. PAD C. WELL NO, 14 PROPOSED MILNE PT.. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. NOTE, I/ELL PATHS EXTEND BEYOND THIS VIEWING WINDOW 22?6 L., 2+51' 41 o? ~ 2630 .4280 2?94 CONOCO INC. MILNE POINT UNIT 20" DIVERTER STACK ~ Flow Line Fill-up Line ~ i'~o" 2000 psi) ] Annular | _ Preventer | Valve · . · ~ Valve 6" * .... Drilling ~~ ~ ~ ~~ ~poo~ ~~ ~" ~.~ VaZve -- 120,,x20,,[ ~ ~ , I 2000 psi ¢ . ~ '~ Connect Assembl~ -.::i ~ s~or S~b [__~ ~. I ~ ~} Assembly 1~~ I'... ..,:1 ' ~[ / ' I r Starting ]_ ] · " ' ~ ' ~ ~ Head ~ ''[ % J f.'., H ~ / t ',',' ',:.: ~4ro ~.~_ 1. RelSef l~nes .from the drilling spool w~ll be routed for do~wSnd d~vers~on. 2. Hydraulic control system will be in accordance with API specifications and AOGCC regulations. 3. Both HCR valves will open when the preventer closes, then either one may be closed. Depending on rig contracted, the two 6" lines may be replaced by a single 10" line with a downstream tee. DRG 7-17-84 CONOCO INC. MILNE POINT UNIT BOP STACK Fill-up Lile~__~ Flow Line [Preventer ~'' ~M ' )~ ~"- ~000 ~f II I1 / ,~ ~rOOLk- - 11" - 5000 ~"- ~000 ,bcso C_ Side Outlets ~)iSPO0~p~'~''''! · - 3 3/8 .. o o (1) B.O.P. stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. (2) BOPE to be operated on each trip & pressure tested weekly. (3) Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. (4) Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. (5) Choke and kill manifolds shown seperately to meet API RP 53 class 5M requirements. RECEIVED Ataska Oil & (~as Cons. Commission Anchorage ALASKA. UNITED DRILLING RIG NO. 3 CHOKE MANIFOLD' LIQUID MUD SYSTEM Active pits Solids removal function 4 each: 6 "x 6"centrifugal pumps, 75 hp Reserve pits 16 each: Lightnin' mixers, 5 hp Working Pressure Choke (1) Type Choke (2) Type 10,000 psi w/ (2) Manual ( 1 ) Automat i c CAPACITIES ACTIVE SYSTEM I Sand trap I Degasser tank I Desander suction I Desilter suction I DesiRer discharge SUBTOTAL Mud Tank NO. I I Common 2 Suction Mud Tank NO. 2 Receiving Discharge Mud Tank No. 3 SUBTOTAL ACTIVE SYSTEM TOTAL TRIP TANK 6 bbl 56 bbl 5q bbl SS bbl 66 bbl 237 bbl 38 bbl 122 bbl I B~ bbl I B4 bbl 2'~0 bbl 768 bbl IOOS bbl t 50 bbl SURFACE VOLUME GRAND TOTAL I 155 bbl JCalculated 4' below tank t0pJ (2) HCR valves ALASKA UNITED DRILLING RIG NO. 3 CLOSED DES~RND£R SUCTION CLOSED Flow path Solids removal DEGASSING FLOW PATH 1 Flowline (in) & pass shaker screens 2 Shaker discharge into sand trap (ditch to pit room closed) 3 Sand trap overflow into degasser suction (desander suction closed) 4 Degasser discharge into ditch 5 Overflow returns to degasser suction (underflow butterfly closed) 6 Switch desander suction out of degasser t~nk 7 Desiltersuction (Normal) 8 Cleaned mud to treatment pit 9 Underflow from treatment to suction pit 10 Gravity-flooded suction CHECK LIST FOR NEW WELL P.~RM.LTS Company Lease & Well No. ITEM APPROVE DATE <1) Fee (2) Lo.9 ~ 5-~'/"'~5 ..... : thru 8) (3) Admin . "" '!:~? 9. ~(b thru ~ ]0. (10 and 12) 1.2. (4) Cas~ ~ ~-Z- (13 thru 21) 1. Is the permit fee attached ................... , .................. .... 2. Is well to be located in a defined pool ............... 3. Is well located proper distance from property line .. . 4. Is well located proper distance from other wells .. 5. Is sufficient undedicated acreage available in this pool . 6. Is well to be deviated and is wellbore plat included ............... 7. Is operator the only affected party ......................: ' 8. Can permit be approved before ten-day wait .i i .. . !~4. :15. :~ 6. ~7. :'8. Z, 9. :~ O. YES NO REMARKS Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed '.... ..... Is the lease number appropriate ...... '' ' ' Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface. ........ Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ (5) sOPE '-~ 5-z-~v- (22 thru 26) ':'.3. ,:4. ,:5. Is a diverter system required ....................................... ~ Are necessary diagrams of diverte~ and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~'bo~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. .D Additional requirements ............................................. Additional Remarks: Geology: Eng~erin~: WVA~ MTM HJH JAL~.. -- -- rev: 03/13/85 ~ 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * * ****************************** . ............................ * ....... SCHLUFiBERGER ....... * ............................ * ****************************** COMPANY NAME : BP EXPLORATION (ALASKA) WELL NAME : MPC-14 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : AK API NUIVi~ER : 500292134400 REFERENCE NO : 98225 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/05/14 ORIGIN : FLIC REEL NAME : 98225 CONTINUATION # : PREVIOUS REEL COM~F2TT : BP EXPLORATION, MPC-14, MILNE POINT, API# 50-029-21344-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/05/14 ORIGIN : FLIC TAPE NAM~ : 98225 CONTINUATION # : 1 PREVIOUS TAPE : COMFIENT : BP EXPLORATION, MPC-14, MILNE POINT, API# 50-029-21344-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NAME: MPC-14 API NUMBER: 500292134400 OPERATOR: BP EXPLORATION (ALASKA) LOGGING COMPANY: WESTERN ATLAS TAPE CREATION DATE: 14-MAY-98 JOB NUMBER: 98225 LOGGING ENGINEER: R. ECK OPERATOR WITNESS: L. HINKEL SURFACE LOCATION SECTION: 10 TOWNSHIP: 13N RANGE: 10E FNL : FSL : 839 FEL: 2134 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 52. O0 DERRICK FLOOR: GROUND LEVEL: 12. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 675 5100.0 36. O0 2ND STRING 7. 000 8822.0 26. O0 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 88888.0 8632.0 8629.0 8619.0 8616.5 8615.0 8613.5 8611.0 8610 5 8608 0 8601 5 8601 0 8597 0 8594 5 8594 0 8592.5 8590.0 8587.5 8585.0 8582.5 8578.5 8574.0 8572.0 8568.5 8568.0 8563.5 8563.0 8559.0 8554.5 8554.0 8551.5 8550.0 8549.5 8548.0 8546.5 8541.0 8538.0 8533.5 8528.0 8520.0 8515.0 8513.5 8508.5 8500.0 8497.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88888.0 88887.5 8632.0 8618.5 8617.0 8614.5 8612.5 861 O. 5 8606.0 8600.0 8593.5 8592.5 8590.5 8587.0 8583.0 8579.0 8574.0 8568.0 8563.0 8560.5 8556.5 8554.0 8550.0 8547.5 8546.0 8540.5 8518.5 8514.5 8507.5 8500.0 8497.5 8628.5 8617.0 8610.5 8608.5 8600.0 8593.5 8584.5 8574.0 8571.5 8568.0 8563.0 8556.5 8550.0 8540.5 8533.5 8526.5 8518.5 8514.5 8507.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 8493.5 8491.5 8488.0 8488.0 8485.0 8483.5 8482.5 8481.0 8478.0 8477.5 8473.0 8473.5 8466.5 8466.0 8466.0 8466.0 8464 . 5 8464.0 8456.5 8457.0 8456.0 8457.0 8453.5 8453.5 8448.5 8448.0 8444.5 8444.5 8431 . 5 8433.0 8424.0 8425.0 8422.0 8422.5 8418.5 8419.5 8420 . 0 8413.0 8413.0 8403.5 8403.5 8403.5 8399.5 8400.0 8397.5 8398.0 8397.0 8398.0 8391.5 8392.5 8388.0 8389.0 8384.5 8384.5 8382.0 8382.5 8373.0 8373.0 8369.5 8370.0 8367.0 8367.5 8365.0 8364.5 83 64.0 83 64.5 83 60.0 8358.5 8357.5 8358.5 8357.0 8356.5 8355.0 8357.0 8352.5 8353.0 8345.5 8344.0 8342.0 8344.0 8340.0 8341.0 8338.5 8337.0 8337.0 8337.0 8336.5 8335.0 8328.0 8331 . 0 8327.0 8324.5 8324.5 8323.5 8324.5 8317.0 8317.0 8316.5 8317 . 0 8306.5 8307.5 8301.0 8303.5 8295.5 8297.0 8293.0 8297.0 8288.0 8289.5 8288.0 8286.5 8288.0 8284.5 8285.5 8283.0 8283.5 14-MAY-1998 13:58 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 8282.0 8283.5 8279.5 8280.0 8277.0 8277.0 8270.5 8271.0 8268.5 8267.5 8268.0 8267.5 8264.5 82 63.5 8264.0 8265.5 8262.5 8264.0 8254.5 8254.0 8250.5 8252.0 8250.0 8252.0 8248.0 8249.0 8244.5 8245.5 8243.5 8245.5 8235.5 8237.5 8234.0 8236.0 8229.5 8230.5 8228.5 8230.5 8225.5 8227.5 8223.0 8224.0 8220.5 8222.5 8220.0 8224.0 8211.0 8213.0 8208.5 8211.5 8203.5 8206.0 8203.0 8206.0 8200.0 8203.5 8194.5 8197.5 8189.0 8191.0 8188.0 8191.0 8186.0 8189.5 8183.5 8185.5 8165.0 8167.0 8163.5 8166.5 8161.5 8163.5 8156.5 8159.0 8154.0 8156.0 8149.5 8152.0 8147.5 8150.5 8147.0 8148.5 8146.0 8148.5 100.0 102.5 101.5 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA AQUIRED ON BP'S MPC-14 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BCS GAMFiA RAY, ALSO BASE PASS #1 SIGMA AND THE BCS GAMFiA RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. THIS DATA WAS LOGGED BY WESTERN ATLAS AND PROCESSED BY SCHLUMBERGER. $ $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/14 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 SUF~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8634.0 8146.5 TDTP 8633.5 8145.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. REMARKS: THIS FILE CONTAINS CASED HOLE TDTP 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 56 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NA~E SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 194602 O0 000 O0 0 1 1 1 4 68 0000000000 SGMA PDK CU 194602 O0 000 O0 0 1 1 1 4 68 0000000000 RATO PDK 194602 O0 000 O0 0 1 1 1 4 68 0000000000 MSD PDK CU 194602 O0 000 O0 0 1 1 1 4 68 0000000000 BKS PDK CPS 194602 O0 000 O0 0 1 1 1 4 68 0000000000 BKL PDK CPS 194602 O0 000 O0 0 1 1 1 4 68 0000000000 SS PDK CPS 194602 O0 000 O0 0 1 1 1 4 68 0000000000 LS PDK CPS 194602 O0 000 O0 0 1 1 1 4 68 0000000000 RICS PDK DIM 194602 O0 000 O0 0 1 1 1 4 68 0000000000 RIN PDK DIM 194602 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH PDK GAPI 194602 O0 000 O0 0 1 1 1 4 68 0000000000 TENS PDK LB 194602 O0 000 O0 0 1 1 1 4 68 0000000000 CCL PDK V 194602 O0 000 O0 0 1 1 1 4 68 0000000000 RBOR PDK 194602 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 8634.000 SGMA.PDK -999.250 RATO. PDK -999.250 MSD. PDK BKS.PDK -999.250 BKL.PDK -999.250 SS. PDK -999.250 LS.PDK RICS.PDK -999.250 RIN. PDK -999.250 GRCH. PDK 29.474 TENS.PDK CCL.PDK -999.250 RBOR.PDK -999.250 DEPT. 8145.500 SGMA.PDK 48.469 RATO.PDK 30.220 MSD.PDK BKS.PDK 266.575 BKL.PDK 159.432 SS. PDK 8813.512 LS.PDK RICS.PDK 30.504 RIN. PDK 11.781 GRCH. PDK -999.250 TENS.PDK CCL.PDK 0.000 RBOR.PDK 2.319 -999.250 -999.250 -999.250 1. 002 289.167 4. 953 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE . FLIC VERSION : O01CO1 DATE : 98/05/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION . O01CO1 DATE : 98/05/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 2 DEPTH INCREMENT: 0.5000 FILE SUFk~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8637.0 8142.5 TDTP 8633.5 8140.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP ............................ 88888.0 88891 . 0 88887.5 8629.0 8628.5 8627.5 8626.5 8626.0 8624.5 8624.0 8627.0 8617.0 8622.0 8616.5 8617.0 8611.0 8617.0 8608.0 8608.5 8604.0 8602.0 8603.5 8608.5 3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 8594.5 8590.5 8589.0 8585.5 8577.5 8571.0 8567.5 8566.0 8563.5 8563.0 8560.0 8557.5 8556.5 8553.5 8550.5 8548.5 8546.0 8542.5 8540.0 8539.5 8538.0 8535.5 8535.0 8534.5 8532.5 8530. 0 8527.5 8524.0 8522.0 8520.5 8520.0 8515.0 8513.0 8511.5 8509.0 8505.5 8497.0 8494.0 8492.0 8489.0 8487.5 8484 5 848O 0 8477 0 8475 0 8473 5 8471 5 8469 0 8467.0 8460.5 8458.0 8455.5 8443.0 8440.5 8439.0 8593.5 8583.0 8574.0 8571.5 8568.0 8563.5 8560.5 8551.0 8550.0 8546.0 8544.5 8540.5 8536.5 8533.5 8525.0 8522.5 8518.5 8514.0 8497.5 8492.5 8476.0 8473.5 8472.0 8458.5 8441.5 8594.0 8590.O 8586.5 8584.5 8571.5 8563.0 8559.0 8556.5 8553.5 8550.0 8545.0 8539.0 8535.0 8533.5 8529.0 8523.0 8520.5 8518.5 8514.5 8511.0 8507.5 8503.5 8491.5 8488.0 8485.5 8483.5 8479.0 8474.5 8471.5 8469.0 8465.5 8461.0 8457.0 8444.5 8439.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 8437.5 8439.5 8435.5 8437.5 8431.0 8433.0 8429.0 8429.0 8425.5 8425.0 8424.5 8427.5 8421.5 8422.5 8421.0 8422.5 8418.5 8419.5 8420.0 8414.0 8416.5 8411.5 8412.5 8411.0 8413.0 8407. $ 8407.0 8405.0 8408.5 8403.5 8403.5 8398. $ 8403.5 8396.5 8399.5 8393.0 8398.0 8393.5 8389.0 8392.5 8388.0 8389.5 8384.0 8384.5 8379.0 8379.0 8378.5 8381 . $ 8374 . 0 8373.0 8370.5 8370.0 8368.5 8369.5 8367.5 8367.5 8365.0 8364.5 8361 . 5 8364.5 8362.0 8359.5 8359.0 8358.0 8356.0 8357.5 8358.5 8350.0 8348.0 8349.0 8350.0 8346.5 8348.5 8342 . 5 8340.0 8340.0 8341.0 8338.5 8337.0 8328.0 8327.0 8327.0 8331.0 8323. $ 8324.5 8319.5 8319.5 8316.0 8317.0 8309 . 5 8312.0 8307.5 8309.5 8304.0 8305.5 8300.5 8303.5 8296.0 8298.5 8294.5 8297.0 8287.5 8288.0 8286.5 8288.0 8285.0 8285.5 8282.0 8283.5 8281 . 5 8283.0 8280.5 8280.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 10 8272.0 8271.0 8266.5 8265.5 8265.0 8267.5 8261.5 8260.5 8265.5 8259.0 8258.0 8251 . 0 8252.0 8250.0 8252.0 8246.5 8248.5 8243 . 5 8245.0 8242.5 8242.0 8235.5 8238.0 8234.0 8236.0 8229.0 8229.0 8227.5 8230.5 8226.5 8227.0 8222.0 8225.5 8220.5 8220.5 8220.0 8224.0 8215.0 8218.5 8209.5 8211.0 8209.0 8211.5 8206.0 8206.0 8204.0 8206.0 8194.0 8198.0 8192.0 8196.5 8191.5 8191.0 8190.0 8193.0 8188.0 8191 . 0 8184.5 8185.5 8182.0 8182.5 8176.0 8178.0 8172.5 8175.0 8169.0 8171.5 8168.0 8167.0 8165.0 8167.0 8162.0 8163.5 8159.0 8159.5 8158.0 8160.0 8151 . 5 8152.0 8149.5 8152.0 8148.0 8148.0 8147.5 8150.0 100.0 102.5 100.0 REM~LRKS: THIS FILE CONTAINS CASED HOLE TDTP DOWN PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH DOWN PASS #1 AND GRCH BASE PASS #1, ALSO SIGMA DOWN PASS #1 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 194602 O0 000 O0 0 2 1 1 4 68 0000000000 SGMA PDK CU 194602 O0 000 O0 0 2 1 1 4 68 0000000000 RATO PDK 194602 O0 000 O0 0 2 1 1 4 68 0000000000 MSD PDK CU 194602 O0 000 O0 0 2 1 1 4 68 0000000000 BKS PDK CPS 194602 O0 000 O0 0 2 1 1 4 68 0000000000 BKL PDK CPS 194602 O0 000 O0 0 2 1 1 4 68 0000000000 SS PDK CPS 194602 O0 000 O0 0 2 1 1 4 68 0000000000 LS PDK CPS 194602 O0 000 O0 0 2 1 1 4 68 0000000000 RICS PDK DIM 194602 O0 000 O0 0 2 1 1 4 68 0000000000 RIN PDK DIM 194602 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH PDK GAPI 194602 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PDK LB 194602 O0 000 O0 0 2 1 1 4 68 0000000000 CCL PDK V 194602 O0 000 O0 0 2 1 1 4 68 0000000000 RBOR PDK 194602 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 8637.000 SGMA.PDK -999.250 RATO. PDK -999.250 MSD. PDK BKS. PDK -999.250 BKL.PDK -999.250 SS.PDK -999.250 LS. PDK RICS. PDK -999.250 RIN. PDK -999.250 GRCH. PDK 80.490 TENS. PDK CCL.PDK -999.250 RBOR.PDK -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 12 DEPT. 8140.000 SGMA.PDK BKS. PDK 5709.215 BKL.PDK RICS.PDK 29.666 RIN. PDK CCL.PDK 0.000 RBOR.PDK 43.614 RATO.PDK 5201.855 SS.PDK 11.737 GRCH. PDK 2.311 26.027 9466.422 -999.250 MSD. PDK LS. PDK TENS. PDK 1. 754 363. 846 -91. 308 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE -FLIC VERSION .O01CO1 DATE : 98/05/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE . 98/05/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SO?4FIARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8631 . 0 8128.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS AU]FiBER: 1 BASELINE DEPTH .............. 88888.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH ....... 88885.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 8630.5 8622.5 8619.5 8617.0 8614.0 8611.5 8609.0 8606.5 8594.5 8587.0 8584.5 8582.0 8574.5 8571.5 8566.0 8557.5 8549.0 8546.0 8538.5 8535.0 8533.5 8526.0 8523.5 8520.0 8512.5 8509.0 8498.0 8483 0 8475 0 8465 5 8453 5 8445 0 8437 5 8431.5 8428.5 8419.0 8406.5 8404.0 8399.5 8397.5 8393.5 8384.0 8369.5 8357.5 8345.5 8340.0 8331.0 8321.0 8317.5 831 O. 5 8301.5 8295.5 8290.0 8287.0 8278.0 8627.5 8621.5 8619.5 8617 0 8613 0 8610 5 8608 5 8605 5 8593 5 8587 0 8584 5 8583 0 8574 0 8571 0 8563 5 8556 5 8550 5 8546.0 8540. 5 8536.5 8533.5 8525.0 8522.5 8518.5 8514.0 8507.5 8497.5 8481.5 8474.5 8466.0 8453.5 8444.5 8439.5 8433.0 8429.0 8419.5 8405.5 8403.5 8400.0 8398.0 8392 5 8384 5 8369 5 8358 5 8345 0 8341 0 8331 0 8320 5 8317 0 8312.0 8303.5 8297.0 8289.5 8288.0 8277.0 14-MAY-1998 13:58 PAGE: 13 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 14 8273.5 8271.0 8269.0 8267.5 8266.5 8263.5 8262.0 8260.0 8254.5 8254.5 8251.5 8252.0 8248.5 8249.5 8244.0 8245.0 8236.0 8237.5 8227.5 8230.5 8222.5 8225.5 8220.5 8224.0 8217.5 8220.0 8209.0 8211.5 8207.5 8209.0 8203.5 8206.0 8202.0 8203.5 8199.0 8198.0 8195.0 8194.0 8189.0 8191.5 8182.0 8183.0 8175.0 8175.0 8169.5 8171.5 8165.5 8167.0 8162.5 8162.5 8156.5 8158.5 8150.0 8152.0 100.0 102.0 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP TIE-IN PASS #1. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH TIE-IN PASS #1 AND GRCH BASE PASS #1. THE SOURCE WAS INACTIVE ON THIS PASS, SO GRCH IS THE ONLY CURVE EDITED o $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 15 TYPE REPR CODE VALUE 8 68 O. 5 9 65 FT 11 66 128 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 194602 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH PDK GAPI 194602 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 8631 . 000 GRCH. PDK 34. 353 DEPT. 8128. 000 GRCH. PDK 68. 877 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~IE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 16 FILE HEADER FILE NUBIBER: 4 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 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NTJM~ERS TDTP 1, $ REMARKS: THIS FILE CONTAINS EDITED BASE PASS #1. NO AVERAGE WAS CALCULATED BECAUSE THIS IS THE ONLY BASE PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 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 NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 194602 O0 000 O0 0 4 1 1 4 68 0000000000 SGMA PNAV CU 194602 O0 000 O0 0 4 1 1 4 68 0000000000 RATO PNAV 194602 O0 000 O0 0 4 1 1 4 68 0000000000 MSD PNAV CU 194602 O0 000 O0 0 4 1 1 4 68 0000000000 BKS PDK CPS 194602 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 17 NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BKL PDK CPS 194602 O0 000 O0 0 4 1 1 4 68 0000000000 SS PNAV CPS 194602 O0 000 O0 0 4 1 1 4 68 0000000000 LS PNAV CPS 194602 O0 000 O0 0 4 1 1 4 68 0000000000 RICS PNAV DIM 194602 O0 000 O0 0 4 1 1 4 68 0000000000 RIN PNAV DIM 194602 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH PDK GAPI 194602 O0 000 O0 0 4 1 1 4 68 0000000000 RBOR PNAV 194602 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 8634.000 SGMA.PNAV -999.250 RATO.PNAV -999.250 MSD.PNAV -999.250 BKS.PDK -999.250 BKL.PDK -999.250 SS.PNAV -999.250 LS.PNAV -999.250 RICS.PNAV -999.250 RIN. PNAV -999.250 GRCH. PDK 29.474 RBOR.PNAV -999.250 DEPT. BKS. PDK RICS. PNAV 8145.500 SGMA.PNAV 266.575 BKL.PDK 30.504 RIN. PNAV 48.469 RATO.PNAV 30.220 MSD.PNAV 1.002 159. 432 SS. PNAV 8813. 512 LS. PNAV 289. 167 11 . 781 GRCH. PDK -999. 250 RBOR. PNAV 2. 319 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE . 98/05/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE . FLIC VERSION · O01CO1 DATE : 98/05/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 18 PASS NUFIBER : 1 DEPTH INCREF~_~TT: 0.5000 FILE SUF~IARY VENDOR TOOL CODE START DEPTH PDK 8658.0 $ 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 PDK THERMAL DECAY $ 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 STOP DEPTH 8114.5 02-MAY-98 JO01 1.1 839 27-APR-98 8742.0 8647.0 8140.0 8634.0 900.0 TOOL NUMBER ........... 2725XA 2725XA 8822.0 BRINE 9.80 TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELIATE COUNT RATE SCALES SET BY FIELD ENGINEER LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 18 PASS NUMBER: 1 DEPTH INCREME1F~: 0.5000 FILE SUB~b%RY VENDOR TOOL CODE START DEPTH ........................... PDK 8658.0 $ LOG HEADER DATA STOP DEPTH .......... 8114.5 DATE LOGGED: SOFTWARE VERSION: TIFiE 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): 02 -MAY- 98 JO01 1.1 839 27-APR-98 8742.0 8647.0 8140.0 8634.0 900.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY PDK THERMAL DECAY $ TOOL NUMBER 2725XA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8822.0 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) : BRINE 9.80 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL)'. MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 19 FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): REMARKS: LOG TIED TO GR/CCL DATED 08-AUG-94 DOWN PASS WAS LOGGED AT 10 FPM UP PASS WAS LOGGED AT 15 FPM MAX. DEV. = 46 DEG AT 6400' LOG WAS RTUN TO DETERMINE WHERE SAND WAS ENTERING BOREHOLE JUNK BASKET AND 5.944' GAUGE RING WERE RUN IN COMBINATION WITH THE PDK. 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 80 4 66 1 5 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** NAFZE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 194602 O0 000 O0 0 5 1 1 4 68 0000000000 SGMA PS1 SU 194602 O0 000 O0 0 5 1 1 4 68 0000000000 RATO PS1 194602 O0 000 O0 0 5 1 1 4 68 0000000000 MSD PS1 SU 194602 O0 000 O0 0 5 1 1 4 68 0000000000 BKS PS1 CPS 194602 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 20 ___ NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BKL PS1 CPS 194602 O0 000 O0 0 5 1 1 4 SS PS1 CPS 194602 O0 000 O0 0 5 1 1 4 LS PS1 CPS 194602 O0 000 O0 0 5 1 1 4 RICS PS1 DIM 194602 O0 000 O0 0 5 1 1 4 RIN PS1 DIM 194602 O0 000 O0 0 5 1 1 4 GR PS1 API 194602 O0 000 O0 0 5 1 1 4 TEN PS1 LBF 194602 O0 000 O0 0 5 1 1 4 CCL PS1 V 194602 O0 000 O0 0 5 1 1 4 SPD PS1 FPM 194602 O0 000 O0 0 5 1 1 4 G2 PS1 CPS 194602 O0 000 O0 0 5 1 1 4 G1 PS1 CPS 194602 O0 000 O0 0 5 1 1 4 MON PS1 CPS 194602 O0 000 O0 0 5 1 1 4 CSS PS1 API 194602 O0 000 O0 0 5 1 1 4 ISS PS1 CPS 194602 O0 000 O0 0 5 1 1 4 RBOR PS1 194602 O0 000 O0 0 5 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. BKS.PS1 RICS.PS1 CCL.PS1 MON. PS1 DEPT. BKS.PS1 RICS.PS1 CCL.PS1 MON. PS1 8650.000 SGMA.PS1 20.076 RATO.PS1 19.086 MSD.PS1 855.997 BKL.PS1 206.891 SS.PSi 22485.484 LS.PS1 18.287 RIN. PS1 11.079 GR.PS1 0.000 TEN. PSi 300.000 SPD.PS1 1019.898 G2.PS1 1607.396 Gl.PS1 1991.472 CSS.PS1 16956.949 ISS. PS1 310093.688 RBOR.PS1 8120.000 SGMA.PS1 0.000 RATO. PS1 0.000 MSD.PS1 0.000 BKL.PS1 0.000 SS. PSi 0.000 LS.PS1 0.000 RIN. PS1 5.000 GR.PS1 0.000 TEN. PSi 0.000 SPD.PS1 0.000 G2.PS1 0.000 G1.PSl 0.000 CSS.PS1 0.000 ISS.PS1 0.000 RBOR.PS1 O. 275 1179.361 89. 688 6119. 883 1. 844 0.000 0.000 -500.000 0.000 -1.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 21 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/05/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREFIENT: 0.5000 FILE SUMbL~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 8113.0 8656.5 PDK $ LOG HEADER DATA DATE LOGGED: 02 -MAY- 98 SOFTWARE VERSION: JO01 1.1 TIM~ LOGGER ON BOTTOM: 839 27-APR-98 TD DRILLER (FT) : 8742.0 TD LOGGER (FT) : 8647.0 TOP LOG INTERVAL (FT) : 8140. 0 BOTTOM LOG INTERVAL (FT) : 8634.0 LOGGING SPEED (FPHR) : 900.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY PDK THERMAL DECAY $ 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) : TOOL NUMBER 2725XA 2725XA 8822.0 BRINE 9.80 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 22 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): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): ~S: LOG TIED TO GR/CCL DATED 08-AUG-94 DOWN PASS WAS LOGGED AT 10 FPM UP PASS WAS LOGGED AT 15 FPM MAX. DEV. = 46 DEG AT 6400' LOG WAS RTUN TO DETERMINE WHERE SAND WAS ENTERING BOREHOLE JUNK BASKET AND 5.944' GAUGE RING WERE RUN IN CO~INATION WITH THE PDK. THIS FILE CONTAINS _THE RAW DATA FOR DOWN PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 2 3 TYPE REPR CODE VALUE 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 NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 194602 O0 000 O0 0 6 1 1 4 SGMADWN SU 194602 O0 000 O0 0 6 1 1 4 RATO DWN 194602 O0 000 O0 0 6 1 1 4 MSD DWN SU 194602 O0 000 O0 0 6 1 1 4 BKS DWN CPS 194602 O0 000 O0 0 6 1 1 4 BKL DWN CPS 194602 O0 000 O0 0 6 1 1 4 SS DWN CPS 194602 O0 000 O0 0 6 1 1 4 LS DWN CPS 194602 O0 000 O0 0 6 1 1 4 RICS DWN DIM 194602 O0 000 O0 0 6 1 1 4 RIN DWN DIM 194602 O0 000 O0 0 6 1 1 4 GR DWN API 194602 O0 000 O0 0 6 1 1 4 TEN DWN LBF 194602 O0 000 O0 0 6 1 1 4 CCL DWN V 194602 O0 000 O0 0 6 1 1 4 SPD DWN FPM 194602 O0 000 O0 0 6 1 1 4 G2 DWN CPS 194602 O0 000 O0 0 6 1 1 4 G1 DWN CPS 194602 O0 000 O0 0 6 1 1 4 MON DWN CPS 194602 O0 000 O0 0 6 1 1 4 CSS DWN API 194602 O0 000 O0 0 6 1 1 4 ISS DWN CPS 194602 O0 000 O0 0 6 1 1 4 RBOR DWN 194602 O0 000 O0 0 6 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 8120.000 SGMA.DWN 0.000 RATO.DWN BKS.DWN 0.000 BKL.DWN 0.000 SS.DWN RICS.DWN 0.000 RIN. DWN 5.000 GR.DWN CCL.DWN 0.000 SPD.DWN 599.940 G2.DWN MON. DWN 0.000 CSS.DWN 0.000 ISS.DWN DEPT. BKS. DWN R I CS . DWN CCL . DWN MON. DWN 0.000 MSD.DWN 0.000 0.000 LS.DWN 0.000 0.000 TEN. DWN -331.376 0.000 G1.DWN 0.000 0.000 RBOR.DWN -1.000 8650.000 SGMA.DWN 19.965 RATO.DWN 19.829 MSD.DWN 0.172 923.169 BKL.DWN 371.824 SS.DWN 21608.055 LS.DWN 1093.566 16.930 RIN.DWN 10.977 GR.DWN 0.000 TEN. DWN -500.000 300.000 SPD.DWN 0.000 G2.DWN 1573.504 G1.DWN 5884.449 2002.035 CSS.DWN 15875.543 ISS.DWN 268779.813 RBOR.DWN 1.836 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE '. 24 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/05/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~I~ : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREFIENT: 0. 5000 FILE SU~4MARY VENDOR TOOL CODE START DEPTH PDK 8661.0 $ 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 GAM~A RAY PDK THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): STOP DEPTH .......... 8109.5 02-MAY-98 JO01 1.1 839 27-APR-98 8742.0 8647.0 8140.0 8634.0 900.0 TOOL NUMBER ........... 2725XA 2725XA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-MAY-1998 13:58 PAGE: 25 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8822.0 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) : BRINE 9.80 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): REMARKS: LOG TIED TO GR/CCL DATED 08-AUG-94 DOWN PASS WAS LOGGED AT 10 FPM UP PASS WAS LOGGED AT 15 FPM MAX. DEV. = 46 DEG AT 6400' LOG WAS RTUN TO DETERMINE WHERE SAND WAS ENTERING BOREHOLE JUNK BASKET AND 5.944' GAUGE RING WERE RUN IN COMBINATION WITH THE PDK. 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