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Home My WebLink About187-0321. 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 Injection 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): 12,180 NA Casing Collapse Conductor N/A Surface 2,260psi Intermediate 4,760psi Intermediate 5,090psi Liner 7,020psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng NA 9-5/8" x 4-1/2" TIW HB-BP-T Packer and HES 4.5" HXO SVLN 10,662 MD / 9,355 TVD and 1,515 MD / 1,515 TVD 11,738' 12,020 11,024 1,269 See Schematic 907-564-4763 aras.worthington@hilcorp.com Operations Manager October 7, 2025 4-1/2" Perforation Depth MD (ft): See Schematic 10,4437" 131 30" 13-3/8" 9-5/8" 2,474 9-5/8"1,833 9,191 5,020psi 6,870psi 2,474 8,287 9,619 2,474 9,191 131 131 12.6# / L-80 / BTC TVD Burst 10,762 8,160psi MD N/A 8,150psi Hilcorp Alaska, LLC Length Size Proposed Pools: 10,583 11,738 10,195 3,060 ENDICOTT OIL Same STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312828 187-032 DUCK IS UNIT MPI 1-41 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21713-00-00 ENDICOTT PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Aras Worthington 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: 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 2:06 pm, Sep 22, 2025 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.09.22 13:54:20 -08'00' Justus Hinks (3691) 325-573 SFD JJL 9/23/25 ADL0034633, DSR-9/24/25 CDW 09/23/2025 10-404 SFD 10/16/2025JLC 10/20/2025 10/20/25 Cement Squeeze, Recomplete to K2A, Convert to WAG Injection Well: END 1-41 PTD: 187-032 Well Name:END 1-41 API Number: 50-029-21713-00 Current Status:Operable PWI Rig:SL, CT, EL Estimated Start Date:Oct 1, 2025 Estimated Duration:One week Reg.Approval Reqstd?N/A Date Reg. Approval Recvd: Regulatory Contact:Darci Horner Permit to Drill Number:187-032 First Call Engineer:Aras Worthington (907) 564-4763 (O) (907) 440-7692 (M) Reservoir Engineer:Gavin Dittman (907) 564-5246 (O) (907) 903-1903 (M) Geologist:Brock Rust (907) 777-8394 (O) (615) 306-9509 (M) Current Bottom Hole Pressure:4,068 psi @ 10,000 ssTVD (Based on offset END1-33B on 09/24) 7.9 ppge Max. Anticipated Surface Pressure:3,060 psi (Gas gradient/0.1psi/ft) Max. Deviation 46 deg @ 10,371 MD Last Tag 11,681 MD w/ 1.75 Bailer; Sandy Schmoo recvd (11/18/2017) SBHT 170 deg F IPROF 7/24/2007 Brief Well Summary: Endicott well 1-41 was originally drilled and completed in July 1987 as a production well. In December 1995 the well was converted to a water injector. Injection rate is ~3000 bwpd @ ~600 psi. A tubing caliper was run 3/13/25 and showed the tubing was in fair condition (see attached caliper snapshot). Subsequently a CMIT-TxIA was performed and passed to 4,761 psi, validating that the casing/packer envelope (secondary barrier) has integrity to gas injection pressures. The tubing was then purged with gas, a TTP set, and the tubing pressured up to 4,500 psi with gas for one week to test the tubing integrity to gas. The IA did not re-pressurize validating that the tubing envelope (primary barrier) will hold gas injection pressure. Objective: CT cement squeeze of the K2B perforations. Underream cement and FCO sand covering the K2A perforations. Convert the well to Water-Alternating-Gas (WAG) Injection in the K2A. AOR information requested from operator was supplied separately via email dated 10/7/2025 that is appended to this Sundry Application. All wells in AOR are adequately isolated. SFD 10/16/2025 q p Convert the well to Water-Alternating-Gas (WAG) Injection in the K2A Cement Squeeze, Recomplete to K2A, Convert to WAG Injection Well: END 1-41 PTD: 187-032 Procedure: Slickline 1. PT PCE to 250 psi low, 3500 psi high. 2. Pull SSSV. 3. Drift and Tag PBTD w/ TEL. Obtain corrected depth to MD for PBTD. 4. Set DSSSV. Coiled Tubing (1.75 or 2) 1. PT PCE to 250 psi low, 3500 psi high. 2. MU ~2 JSN or DJN (WSS discretion). 3. Tag TD, correct depth to MD and flag pipe for depth control. 4. FCO to 11,700 MD. 5. POOH and MU ~2.0 cementing nozzle (WSS discretion). Tag TD, pick up and flag pipe for depth control. 6. Liquid pack well with diesel (if needed to get positive wellhead pressure) by pumping down the coil tubing and up the backside or bullhead (WSS discretion). a. Volume to top perf is 163 bbls (tbg volume) + 25 bbls (7 liner to top perfs) = 188 bbls. 7. Perform pre-cement injectivity test. 8. Lay 40 bbls 15.8 ppg Class G cement @ 1:1 from flag depth. a. Minimum thickening time = 10 hours. i. 1 hour mixing at surface. ii. 1.5 hours pump down coil assuming 1 bbl / minute iii. 1 hour cement placement assuming 0.5 bbl / minute iv. 2 hour squeeze time v. 2 hour contingency b. Expected bottom hole temperature 170 degF (IPROF of 7/24/2007). c. 11,700 10,760 = 940 x 0.0372 bbls/ft = 35 bbls from PBTD to the tubing tail. 9. Pump pipe displacement while pulling coil tubing up above cement to keep hydrostatics stable and hold cement in place. 10. Hesitation squeeze for ~2 hours targeting 2500 psi squeeze in 250 psi increments. Hold each pressure for 5-15 minutes. d. Hold max squeeze pressure for target of 45-60 minutes. 11. If hesitation squeeze is successful cleanout cement with frequent gel sweeps. e. First contamination pass should be no later than 2/3 of thickening time. 12.Contingent If well is unable to build squeeze pressure, over displace cement by 2-3 bbls and prepare to repeat squeeze attempt once cement has reached compressive strength. Or consider leaving cement to set up and under-reaming cement with Hailey Under reamer & mill. 13. After cement has reached 1000 psi compressive strength perform post cement PT to 500 psi for five minutes. 14. FCO with JSN, DJN, or Mill and Hailly Underreamer (WSS discretion). Target depth is 11,830 MD. Note:The DSSSV will need to be pulled to run the UR and Mill. Note: IF CT pulls the DSSSV; try straight pulls to open the lock before jarring and jar gently (if at all) to to avoid splitting the FN. Cement Squeeze, Recomplete to K2A, Convert to WAG Injection Well: END 1-41 PTD: 187-032 Note:Mill/Underream cement and FCO sand down to a target depth of 11,830 MD to open up K2A perforations from 11,765 11,695 MD. Cleaning out to 11,830 MD leaves some rat hole for EL if re-perforating is necessary. Note: there is a 59 OAL Fish: 3.25 Centralizer, TEL, and Sample Bailer LIH around 11,800 MD on 7/20/2007. Note: The CT cement job on 9/13/2013 (1.2 bbls of cement pumped on top of sand plug @ 11,770 MD) appeared to be strung out in the 7 liner; SL tagged it after the cement job @ 11,292 MD (and got a sample of cement in the bailer) 9/17/13. SL tagged later @ 11,690 MD on 9/9/2014. 15. Perform injectivity test into perfs to establish if re-perforating will be necessary. 16.Contingent: Re-perforate the K2A from 11,760 11,795 MD. Slickline 17. Pull DSSSV (if CT did not pull it already). 18. Set SSSV. Attachments 19. Current Schematic 20. Proposed Schematic 21. UR BHA Proposal 22. Caliper snapshot Cement Squeeze, Recomplete to K2A, Convert to WAG Injection Well: END 1-41 PTD: 187-032 Current Schematic Cement Squeeze, Recomplete to K2A, Convert to WAG Injection Well: END 1-41 PTD: 187-032 Proposed Schematic All Perfs above 11,700 MD squeezed off K2A Perfs open to injection Cement Squeeze, Recomplete to K2A, Convert to WAG Injection Well: END 1-41 PTD: 187-032 Cement Squeeze, Recomplete to K2A, Convert to WAG Injection Well: END 1-41 PTD: 187-032 2025 Caliper 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:Aras Worthington To:Davies, Stephen F (OGC); justus.hinks@hilcorp.com Cc:Dewhurst, Andrew D (OGC); Starns, Ted C (OGC); Brock Rust Subject:RE: [EXTERNAL] RE: DIU MPU 1-41 (PTD 187-032, Sundry 325-573) - Request Date:Tuesday, October 7, 2025 8:57:15 AM Attachments:image001.png image002.png Good Morning Steve, Please see below AOR map and the mechanical condition table of each subject well below. Thanks and Best Regards, Isolated: Int csg cmt calc top ~9,650' MD, Int csg shoe 11,024' MD, Liner CBL TOC 11,032' MD (SFD's pick). SFD Isolated: Int csg cmt calc top ~10,350' MD, Int csg shoe 11,728' MD, Liner CBL TOC 11,746' MD (SFD's pick). SFD Isolated: Int csg cmt calc top ~7,050' MD, Int csg shoe 11,865' MD, Liner CBL TOC 11,908' MD. SFD Isolated: Surface csg set at 4,737' MD and cmtd to surface. No additional casing set. Openhole plug 10,888' to 12,090' MD. Reservoir top at 11,161' MD (SFD's pick). SFD CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Aras Worthington Sr. Operations Engineer, Islands Team Hilcorp Alaska Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Saturday, October 4, 2025 7:58 AM To: Aras Worthington <aras.worthington@hilcorp.com>; justus.hinks@hilcorp.com Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov> Subject: [EXTERNAL] RE: DIU MPU 1-41 (PTD 187-032, Sundry 325-573) - Request Aras and Justus: I'd like to confirm that you received my email below. I'd like to keep this Sundry Application moving through the AOGCC's review process. The estimated date for commencing operations is listed on the 403 form as October 7th. Let me know if this date has changed. Thanks Again and Be Well, Steve Davies Senior Petroleum Geologist AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov From: Davies, Stephen F (OGC) Sent: Wednesday, October 1, 2025 1:54 PM To: Aras Worthington <aras.worthington@hilcorp.com>; 'justus.hinks@hilcorp.com' <justus.hinks@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Starns, Ted C (OGC) <ted.starns@alaska.gov> Subject: DIU MPU 1-41 (PTD 187-032, Sundry 325-573) - Request Aras and Justus, I'm reviewing Hilcorp Alaska, LLC's Sundry Application for DIU MPI 1-41 and I have a request. This is an older well that has injected only water to date. Hilcorp's application is to change from water to WAG injection but does not contain a report on the mechanical condition of each well that has penetrated the injection zone within a one-quarter mile radius of this proposed injection well, which is required under 20 AAC 25.402(c)(15). It is important to demonstrate that injected gas will be confined to the approved injection zone(s). (See also 20 AAC 25.402(b).) Could Hilcorp please provide this mechanical condition report to AOGCC? Please include cement tops for the casing strings within each well within that radius along with the top and base of the target reservoir interval(s) as measured and true vertical depths. Please include how each cement top was determined and Hilcorp's interpretation of whether the target injection zone(s) is/(are) isolated in each well. Since this is an older development area, please also provide brief updated descriptions, depths, and thicknesses for the upper and lower confining intervals for the injection zone(s) per 20 AAC 25.402(c)(6). As you know, the estimated date for commencing operations is listed on the 403 form as October 7th. Let me know if this date has changed. Thanks and Be Well, Steve Davies Senior Petroleum Geologist AOGCC 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 Steve Davies at 907-793-1224 or steve.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. 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: 4/10/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#2025010 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 211-26 50283201280000 208112 1/27/2025 AK E-LINE PPROF T40287 END 1-41 50029217130000 187032 3/13/2025 HALLIBURTON MFC40 T40288 END 2-14 50029216390000 186149 3/12/2025 HALLIBURTON MFC40 T40289 END 3-33A 50029216680100 203215 3/23/2025 HALLIBURTON COILFLAG T40290 GP AN-17A 50733203110100 213049 12/29/2024 AK E-LINE Perf T40291 KALOTSA 3 50133206610000 217028 3/3/2025 AK E-LINE PPROF T40292 KU 12-17 50133205770000 208089 1/28/2025 AK E-LINE Perf T40293 MPI 2-14 50029216390000 186149 2/17/2025 AK E-LINE Plug/Cement T40294 NCIU A-21 50883201990000 224086 3/28/2025 AK E-LINE Plug-Perf T40295 ODSN-25 50703206560000 212030 3/7/2025 HALLIBURTON CORRELATION T40296 PBU 02-08B 50029201550200 198095 3/17/2025 HALLIBURTON RBT T40297 PBU D-08B 50029203720200 225007 3/22/2025 HALLIBURTON RBT T40298 PBU J-25B 50029217410200 224134 3/10/2025 HALLIBURTON RBT T40299 PBU K-12D 50029217590400 224099 3/18/2025 HALLIBURTON RBT T40300 PBU K-19B 50029225310200 215182 3/27/2025 HALLIBURTON RBT T40301 PBU L1-15A 50029219950100 203120 3/27/2025 HALLIBURTON PPROF T40302 PBU M-207 50029238070000 224141 3/18/2025 HALLIBURTON IPROF T40303 PBU P1-04 50029223660000 193063 3/28/2025 HALLIBURTON PPROF T40304 PBU W-220A 50029234320100 224161 3/11/2025 HALLIBURTON RBT T40305 Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40288END 1-41 50029217130000 187032 3/13/2025 HALLIBURTON MFC40 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.10 13:48:56 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 29, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 1-41 DUCK IS UNIT MPI 1-41 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2024 1-41 50-029-21713-00-00 187-032-0 W SPT 9356 1870320 2339 525 529 527 529 200 360 360 360 4YRTST P Josh Hunt 7/17/2024 Packer TVD is 9,356' with a MD of 10,662' They chose to use the measured depth to get the test pressure because that’s what was used on the last few tests I guess. I didn't see a problem with this as it was deeper with a higher test pressure. Excellent test. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:DUCK IS UNIT MPI 1-41 Inspection Date: Tubing OA Packer Depth 1236 2900 2881 2875IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240717111412 BBL Pumped:3.8 BBL Returned:3.8 Thursday, August 29, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.29 15:56:37 -08'00' MEMORANDUM TO: Jim Regg �I\nq ) P.I. Supervisor - ll %I ?j31 SCZ-p FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 14, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC 14I DUCK IS UNIT MPI 141 See: Inspector Reviewed By: -56. P.L Supry Comm Well Name DUCK IS UNIT MPI 141 API Well Number 50-029-21713-00-00 Inspector Name: Guy Cook Permit Number: 187-032-0 Inspection Date: 7/10/2020 ' I¢sp Num; mitGDC200710130124 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 e Inj TVD 93se � Tubing zzoa - zzol - 2zoo - zzol- PTD 20 Fpeld e Test t SPT Test psi 2339 IA 491 2874 - 2851 2841BBL Pu BBL Returned: 5.1 - OA 150 380 380. 380 - IntervalT PAF P Notes: Testing performed with a triplex, bleed trailer and calibrated gauge. v Tuesday, July 14, 2020 Page 1 of 1 STATE OF ALASKA ALL OIL AND GAS CONSERVATION CO SIONECEIVE® REPORT OF SUNDRY WELL OPERATIONS DEC 1 5 2017 1.Operations Abandon LI Plug Perforations U Fracture Stimulate LJ Pull Tubing Performed: Suspend ❑ Perforate LJ Operations shutdown U p Q Other Stimulate ❑ Alter Casing ❑ Cha I 1 -00r m CIv�o Plug for Redrill ❑ erforate New Pool ❑ Repair Well Cl Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑ Exploratory ❑ 187-032 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service 0 6.API Number: AK 99503 50-029-21713-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312828 DUCK IS UNIT MPI 1-41 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A ENDICOTT/ENDICOTT OIL 11.Present Well Condition Summary: Total Depth measured 12,180 feet Plugs measured 11,738 feet true vertical 10,585 feet Junk measured 11,681 (Fill) feet Effective Depth measured 11,681 feet Packer measured 10,662 feet true vertical 10,146 feet true vertical 9,356 feet Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' N/A N/A Surface 2,474' 13-3/8" 2,474' 2,474' 5,020psi 2,260psi Production 9,191' 9-5/8" 9,191' 8,287' 6,870psi 4,760psi Production 1,833' 9-5/8" 11,024' 9,620' 8,150psi 5,090psi Liner 12,020' 7" 12,020' 10,444' 8,160psi 7,020psi Perforation depth Measured depth See Schematic feet SCANNED ', P• 2 9 _01k True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6/L-80/BTC 10,762' 9,428' 9-5/8"x 4-1/2" 1,515 MD Packers and SSSV(type,measured and true vertical depth) TIW HB-BP-T HES 4.5"HXO SVLN See Above 1,515 TVD 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 14,947 350 2,242 Subsequent to operation: 0 0 17,146 300 2,200 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory Development El Service ❑✓ Stratigraphic ❑ Copies of Logs and Surveys Run Li 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q 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: 317-497 Authorized Name: Bo York Contact Name: Taylor Wellman'MI Authorized Title: Operations Manager Contact Email: twellman hilcorp.com Authorized Signature: p._ — Data 12/12/2017 Contact Phone: 777-8449 Form 10-404 Revised 4/2017 , Submit Original Only ,`2 RBDPJS L C1_,, i ' 2017 111 . Ill Duck Island Unit Well: END 1-41 SCHEMATIC Last Completed: 2/27/1996 Hitearp Alaska,LLC PTD: 187-032 SAFETY NOTES TREE&WELLHEAD KB Elev.:55.25'/BF Elev.:15.8' COMPOSITE WRAP REPAIR SH LEAK-DO NOT PUMP Tree 4-1/16"5M 30 J L METH/METH BLEND INTO OA DUE TO CHEM Wellhead 13-5/8"SM INCOMPATIBILITY w/EPDXY RESIN IN WRAP. Well Requires a SSSV. 4-1/2"CHROME NIPPLES. 1 OPEN HOLE/CEMENT DETAIL 13-3/8" 3,440 cu/ft Permafrost in 17.5"Hole 1.3 3/8 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole 7" 446 cu/ft Class"G"in 8-1/2"Hole z CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 131' N/A 13-3/8" Surface 68/L-80/BTC 12.415 Surface 2,474' 0.1497 9-5/8" Intermediate 47/NT8OS/NSCC 8.681 Surface 9,191' 0.0732 9-5/8" Intermediate 47/NT95H/NSCC 8.681 9,191' 11,024' 0.0732 7" Liner 29/L-80/Btrs 6.184 10,751' 12,020' 0.0371 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/BTC 3.958 Surface 10,762' 0.0152 WELL INCLINATION DETAIL Max Hole Angle=46 deg.@ 10,279' Angle at Top Perf=35 Deg.@ 11,417' 1 ' , JEWELRY DETAIL No Depth Item 1 1,515' 4-1/2"HES HXO SVLN 9Cr Assy-ID=3.813" GLM DETAIL:HES 4.S"x 1.5"9Cr TB Round w/RA Latch 2 3,415' STA 2:Dev=1,VLV=DMY,Port=0,TVD=3,415',Date=2/27/96 3 10,571' STA 1:Dev=45,VLV=DMY,Port=0,ND=9,291',Date=2/27/96 4 10,641' 4-1/2"OTIS X Nipple,9Cr-ID=3.813" 5 10,662' 9-5/8"x 4-1/2"TIW HB-BP-T Packer-ID=3.910" 6 10,728' 4-1/2"OTIS X Nipple,9 Cr-ID=3.813" * = 4 7 10,749' 4-1/2"OTIS XN Nipple,9Cr-ID=3.725" 8 10,760' 4-1/2"WLEG-ID=3.958"-Btm @ 10,762' ) "`^"'1 5 PERFORATION DETAIL M;n11: 3.7zs' 6 END Top(MD) Btm Top Btm(ND) FT Date Status Size @10.745 Sands (MD) (NDj 11,417' 11,437 9,924' 9,941' 20 9/11/2014 Open 2-7/8" 11,448' 11,463' 9,983' 9,962' 15 9/11/2014 Open 2-7/8" 8 11,524' 11,544' 10,013' 10,029' 20 11/21/2017 Open Future 11,564' 11,594' 10,046' 10,072' 30 4/26/1995 Leaking 2-7/8" NI11,590' 11,600' 10,068' 10,077' 10 4/4/1996 Open 3-3/8" END Sands 11,610' 11,634' 10,085' 10,106' 24 4/26/1995 Squeezed 3-3/8" 11,625' 11,635' 10,098' 10,107' 10 5/22/1998 Open 3-3/8" 11,640' 11,694' 10,111' 10,157' 54 4/26/1995 Leaking 3-3/8" 9-5/8" a rill 11,690' 11,700' 10,154' 10,163' 10 4/4/1996 Open 3-3/8" 11,760' 11,770' 10,215' 10,224' 10 4/26/1995 Covered 3-3/8" Top of Cement@ 11,765' 11,795' 10219 10,246' 30 3/19/1996 Covered 3-3/8" 11,738'-8'13"13 Reference Perf Log:CBT/GR on 5/1/1987 R Top ofSand @ °' ` GENERAL WELL INFO 11,770-9/13/13 _ r bz API:50-029-21713-00-00 Initial Completion by Doyon 15 -7/22/1987 FISH-Male QC ;` RWO w/Doyon 15-2/27/1996 3-1/4"Cent Tel Sand Plug w/Cmt Cap-9/13/2013 @ 11,824'SLM " ,," 7" TD=12,180'(MD)/TD=10,585'(TVD) PBTD=11,938'(MD)/PBTD=10,371'(ND) Revised By:TDF 12/11/2017 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 1-41 E-Line 50-029-21713-00-00 187-032 11/17/17 11/24/17 Daily Operations: 11/15/2017-Wednesday No activity to report. 11/16/2017 -Thursday No activity to report. 11/17/2017 - Friday PT PCE 250psi LOW/2,000psi HIGH. TAG 4-1/2" MCX AT 1,481' SLM (1,515' MD). HAVE WELL BROUGHT BACK ON OVERNIGHT. 11/18/2017-Saturday PT PCE 250psi LOW/2,000psi HIGH. PULL 4-1/2" MCX FROM HXO NIPPLE AT 1,481' SLM (1,515' MD) SER# BPX-470 LOCATE WLEG AT 10,739' SLM (10,762' MD), TAG BTM. AT 11,658' SLM (11,681' MD) +23'. RAN 20' 3-1/8" DMY. GUNS TO TARGET DEPTH OF 11,577' SLM (11,600' MD). 11/19/2017-Sunday No activity to report. 11/20/2017- Monday No activity to report. 11/21/2017-Tuesday WELL ON INJECTION UPON ARRIVAL. INITIAL WHP 1,900PSI. PT PCE TO 250L/2,000H. RIH WITH 20'X3.13", 60 DEG, 6 SPF, EHC. SHOOT HOLES FROM 11,524' RKB TO 11,544' RKB. POOH. OOH. SECURE WELL. RD.JOB COMPLETE. TURN WELL OVER TO DSO. • 4110 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 1-41 E-Line 50-029-21713-00-00 187-032 11/17/17 11/24/17 Daily Operations: 11/22/2017-Wednesday No activity to report. 11/23/2017-Thursday No activity to report. 11/24/2017 - Friday WELL ON INJECTION UPON ARRIVAL. PT PCE 250#-LOW/2,200#-HIGH. BRUSH TBG WI 4-1/2" BRUSH &3.80" G. RING TO HXO SVLN AT 1,515' MD. SET 4-1/2" MCX SSSV(BPX-470) IN HXO SVLN AT 1,515' MD w/X eq. dev& 1.30" bean 1 SET OF STD PKG W/0-RING. PERFORMED SUCCESFUL DRAWDOWN TEST ON SSSV. WELL LEFT SHUT-IN ON DEPARTURE, DSO NOTIFIED. 11/25/2017 -Saturday No activity to report. 11/26/2017-Sunday No activity to report. 11/27/2017- Monday No activity to report. •F T�� • • i0P* y�_s,, THE STATE Alaska Oiland Gas �w �' ��-9vii ®f Conservation Commission LAsKA�,toti = == 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 P Main: 907.279.1433 ALAS* Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager Hilcorp Alaska, LLC , NOV 0 92017 3800 Centerpoint Drive, Suite 1400 ��® Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU MPI 1-41 Permit to Drill Number: 187-032 Sundry Number: 317-497 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, LD3T-1-- Hollis S. French Chair DATED this 2day of October, 2017. REG:J5 '/L {av19 2 Z6l7 • • RECEIVED STATE OF ALASKA OCT 1 7/2 017 ALASKA OIL AND GAS CONSERVATION COMMISSION /4-l6 / Z /3'4 APPLICATION FOR SUNDRY APPROVALS AUUce 20 AAC 25.280 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: ESP Change-out ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 187-032' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service Q. 6.API Number: Anchorage Alaska 99503 50029-21713-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462.007 Will planned perforations require a spacing exception? Yes ❑ No ❑., DUCK IS UNIT MPI 1-41 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312828 - ENDICOTT/ENDICOTT 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): 12,180' - 10,585' - 11,738' 10,196' 1,200 11,738' N/A Casing Length Size MD TVD Burst Collapse Conductor 131' 30" 131' 131' N/A N/A Surface 2,474' 13-3/8" 2,474' 2,474' 5,020psi 2,260psi Production 919' 9-5/8" 9,191' 8,287' 6,870psi 4,760psi Production 1,833' 9-5/8" 11,024' 9,620' 8,150psi 5,090psi Liner 12,020' 7" 12,020' 10,444' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" 12.6/L-80/BTC 10,762' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"x 4-1/2"TIW HB-BP-T Packer and HES 4.5"HXO SVLN 10,662 MD/9,356 TVD and 1,515 MD /1,515 TVD 12.Attachments: Proposal Summary Q Wellbore schematic Q 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: 11/3/2017 Commencing Operations: OIL El WINJ ❑., WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Taylor Wellman -r-4J Authorized Title: Operations Manager Contact Email: twellmanhilcorp.com Authorized Signature: ��,j7%� . go Y04-k Date: 10/17tf 7 Contact Phone: 777-8449 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 /Atri Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test El Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes No r Ey 231 SpacingException Required? ❑ ❑ \� ��iV�i� �� E'ev� — 1 Ltf i P q Yes ❑ No Subsequent Form Required: /0 .- 'JG APPROVED BY i Approved by: t-OCZ: COMMISSIONER THE COMMISSION Date: 1 L l Z6 It 44�� /v • -;:,,,i-i7 n RIG[UAL Submit Form and Q� Form 10-403 Revised 4/2017 Approved application is vali r approval. Attachments in°uplicate .13 • • Add Perf Well: END 1-41 PTD: 187-032 I3ilcorn Alaska,LLQ API: 50-029-21713-00 Well Name: END 1-41 API Number: 50-029-21713-00 Current Status: On Injection Rig: SL& E-Line Estimated Start Date: November 3, 2017 Estimated Duration: 2 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 187-032 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907)947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) AFE Number: Sundry/WeIIEZ Input Req'd: Yes Current Bottom Hole Pressure: 4,820psi (Based on offset well END4-08 on 03/27/17) Maximum Expected BHP: 4,820psi (Based on offset well END4-08 on 03/27/17) Max. Anticipated Surface Pressure: 1,200psi (Max recorded S/I pressure) Brief Well Summary: Endicott well 1-41 was originally drilled and completed in July 1987 as a production well. In December 1995 the well was converted to a water injector. During the conversion attempts to cement squeeze and reperforate the liner were done. In 2013 a sandback and cement cap were placed in the well to isolate the well to inject into the K2A. The well is currently open to the S3A4, S3A3,S3A1 and the K2B sands. • Objective: Perforate the following intervals in the table below. Run# Perf Top Perf Bottom Perf Length Formation Carrier/Charge/Note 1 11,524' 11,544' 20' S3A2 2-7/8"-3-1/8", 60 deg phasing, 6spf Total 20' Table 1: END 1-41 Proposed Perf Gun Runs Note: Final depths to be confirmed in "Final Approved Perf Sheet" Area of Review—Endicott DIU 1-41 (187-032) This AOR found two other wells (1-37 & 5-02) within 1/4 mile of 1-41's entry point into the S3A2 Formation. Table 2:Wells within AOR Well Name PTD Distance, Ft. Annulus Integrity 1-41 187-032 0' MIT-IA on 7/10/16 passed to 2764 psi 1-37 187-090 1,380' LTSI—Secured w/CIBP in tbg. CMIT-TxIA on 5/28/07 passed to 3360psi 5-02 181-118 1,120' CMIT-TxIA(lower)on 7/24/17 to 3022psi MIT-IA(upper) on 7/24/17 to 2963 psi MIT-T on 8/5/17 to 2920psi Table 3:Completion Detail API Well No Permit Well Current Status Zonal isolation (method) 50-029-21713-00-00 187-032 1-41 Online Produced Cement Bond Log run on 5/1/1987 Water Injector indicates TOC at 11,024'MD (top of 9-5/8" . 13 • S Add Perf Well: END 1-41 PTD: 187-032 Iiilcorn Alaska,LLI API: 50-029-21713-00 Endicott Oil Pool liner). S/I Producer- Cement Bond Log run on 11/23/1987 50-029-21748-00-00 187-090 1-37 Endicott Oil Pool indicates TOC at 11,728 MD (bottom of the 9-5/8" liner lap). Online Produced Cement Bond Log run on 4/18/1987 50-029-20646-00-00 181-118 5-02 Water Injector- indicates TOC at 11,865'MD (bottom of the Endicott Oil Pool 9-5/8" liner lap). Procedure: Slickline 1. RU SL unit and pressure test to 250psi low/2000psi high. 2. Pull SSSV from 1,515' md. 3. MU 3-1/8" drift and drift to TOC. 4. MU 3-1/8" dummy gun and drift. a. Target depth to achieve is 11,600' md. 5. RD SL unit. E-Line 1. RU EL unit and pressure test to 250psi low/2000psi. 2. MU perforating tool string with 2-7/8"-3-1/8",6spf, 60 deg phased, deep penetrating guns. 3. RIH and correlate 15t gun run to Tie-In Log:SLB Cement Evaluation Log dated 01May1987.Contact OE " prior to perforating for final approval of tie in. a. Note any tubing pressure change in WSR. 4. RD Eline. Slickline 1. RU SL unit and pressure test to 250psi low/2000psi high. 2. Set SSSV from 1,515' md. a. Description of previous SSSV set on 09/12/14: 4-1/2" MCX W/SECONDARY LOCK DOWN, (SER# BPX-470, OAL=40", BEAN=1.30", 8 x 1/8" PORTS). 3. RD SL unit. . • N� 44 �o r coZei v. N In M rn to r , zo- in cn r M r. :i. fs9 co r .s o0 r M co rM r, ', LO _ Q) T rN ,II IM T- 7 CD CM CD CO in cr) at: ;1r� o o iiile o) %- ) N coN co I r M 7/ IIPIN II .47 11111111.1r "Ail 2 `P .II / ao ' o r i, i '011441 ; .I /I g lvr N :, fir %i� l '�O�i/�i'r, 0 / J O. ! !: ¢ I \lki ; I: L-5 ig\ O a _.W3J J - ° WNmiJ_> 5 ¢ m 5 5 docg,, F W 1� Y a • 0)•.k < 0 Mil 0 • Duckll:IslanENDd1-41 Unit . 14We SCHEMATIC Last Completed: 2/27/1996 PTD: 187-032 Hilcorp Alaska,LLC SAFETY NOTES TREE&WELLHEAD KB Elev.:55.25'/BF Elev.:15.8' COMPOSITE WRAP REPAIR SH LEAK-DO NOT PUMP Tree 4-1/16"5M METH/METH BLEND INTO OA DUE TO CHEM Wellhead 13-5/8"5M INCOMPATIBILITY w/EPDXY RESIN IN WRAP. 30 Well Requires a SSS/. 4-1/2"CHROME NIPPLES. AIV 1 OPEN HOLE/CEMENT DETAIL 13-3/8" 3,440 cu/ft Permafrost in 17.5"Hole 13-3/8 9-5/8" 575 cu/ft Class`G'in a 12-1/4"Hole 7" 446 cu/ft Class"G"in 8-1/2"Hole 2 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 131' N/A 13-3/8" Surface 68/L-80/BTC 12.415 Surface 2,474' 0.1497 9-5/8" Intermediate 47/NT8OS/NSCC 8.681 Surface 9,191' 0.0732 9-5/8" Intermediate 47/NT95H/NSCC 8.681 9,191' 11,024' 0.0732 7" Liner 29/L-80/Btrs 6.184 10,751' 12,020' 0.0371 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/BTC 3.958 Surface 10,762' 0.0152 WELL INCLINATION DETAIL Max Hole Angle=46 deg.@ 10,279' Angle at Top Perf=35 Deg.@ 11,417' 3 JEWELRY DETAIL No Depth Item 1 1,515' 4-1/2"HES HXO SVLN 9Cr Assy-ID=3.813" GLM DETAIL:HES 4.5"x 1.5"9Cr TB Round w/RA Latch 2 3,415' STA 2:Dev=1,VLV=DMY,Port=0,TVD=3,415',Date=2/27/96 3 10,571' STA 1:Dev=45,VLV=DMY,Port=0,TVD=9,291',Date=2/27/96 4 10,641' 4-1/2"OTIS X Nipple,9Cr-ID=3.813" 5 10,662' 9-5/8"x 4-1/2"TIW HB-BP-T Packer-ID=3.910" 6 10,728' 4-1/2"OTIS X Nipple,9Cr-ID=3.813" 6 it t. 4 4 7 10,749' 4-1/2"OTIS XN Nipple,9Cr-ID=3.725" 8 10,760' 4-1/2"WLEG-ID=3.958"-Btm @ 10,762' v' - 5 PERFORATION DETAIL Mn1r3.725" ;`tea 6 END Btm Top @10,745 111Sands Top(MD) (MD) (TVD) Btm(TVD) FT Date Status Size If 7 11,417' 11,437' 9,924' 9,941' 20 9/11/2014 Open 2-7/8" 11,448' 11,463' 9,983' 9,962' 15 9/11/2014 Open 2-7/8" 8 11,564' 11,594' 10,046' 10,072' 30 4/26/1995 Leaking 2-7/8" 11,590' 11,600' 10,068' 10,077' 10 4/4/1996 Open 3-3/8" I:Er tiZi 11,610' 11,634' 10,085' 10,106' 24 4/26/1995 Squeezed 3-3/8" END Sands 11,625' 11,635' 10,098' 10,107' 10 5/22/1998 Open 3-3/8" 11,640' 11,694' 10,111' 10,157' 54 4/26/1995 Leaking 3-3/8" 11,690' 11,700' 10,154' 10,163' 10 4/4/1996 Open 3-3/8" 9-5/8" a & 11,760' 11,770' 10,215' 10,224' 10 4/26/1995 Covered 3-3/8" 11,765' 11,795' 10219 10,246' 30 3/19/1996 Covered 3-3/8" TopdCerr t@ _ Reference Perf Log:CBT/GR on 5/1/1987 11,738'-9/13/13 Top otSaid @3 GENERAL WELL INFO 11,770-9/13/13 API:50-029-21713-00-00 V Initial Completion by Doyon 15 -7/22/1987 FISH-Male QC, RWO w/Doyon 15-2/27/1996 3-1/4"Cent Tel.........-41 T Sand Plug w/Cmt Cap-9/13/2013 @11,824'SLM 7" a `.1 TD=12,180'(MD)/TD=10,58511VD) PBTD=11,938'(MD)/PBTD=10,371'(ND) Revised By:DH 10/17/2017 • • Duck Island Unit Well: END 1-41 • liPROPOSED Last Completed: 2/27/1996 [lileorp Alaska,LLC PTD: 187-032 SAFETY NOTES TREE&WELLHEAD KB Elev.:55.2576F Elev.:15.8' COMPOSITE WRAP REPAIR SH LEAK-DO NOT PUMP Tree 4-1/16"5M METH/METH BLEND INTO OA DUE TO CHEM Wellhead 13-5/8"5M INCOMPATIBILITY w/EPDXY RESIN IN WRAP. 30 Well Requires a SSSV. 4-1/2"CHROME NIPPLES. ll 1 OPEN HOLE/CEMENT DETAIL 13-3/8" 3,440 cu/ft Permafrost in 17.5"Hole 13-3/8" 9-5/8" 575 cu/ft Class'G'in a 12-1/4"Hole 7" 446 cu/ft Class"G"in 8-1/2"Hole 2 CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 30" Conductor N/A/N/A/N/A N/A Surface 131' N/A 13-3/8" Surface 68/L-80/BTC 12.415 Surface 2,474' 0.1497 9-5/8" Intermediate 47/NT8OS/NSCC 8.681 Surface 9,191' 0.0732 9-5/8" Intermediate 47/NT95H/NSCC 8.681 9,191' 11,024' 0.0732 7" Liner 29/L-80/Btrs 6.184 10,751' 12,020' 0.0371 TUBING DETAIL 4-1/2" Tubing 12.6/L-80/BTC 3.958 Surface 10,762' 0.0152 WELL INCLINATION DETAIL Max Hole Angle=46 deg.@ 10,279' Angle at Top Perf=35 Deg.@ 11,417' 3 JEWELRY DETAIL No Depth Item 1 1,515' 4-1/2"HES HXO SVLN 9Cr Assy-ID=3.813" GLM DETAIL: HES 4.5"x 1.5"9Cr TB Round w/RA Latch 2 3,415' _ STA 2:Dev=1,VLV=DMY,Port=0,TVD=3,415',Date=2/27/96 3 10,571' STA 1:Dev=45,VLV=DMY,Port=0,TVD=9,291',Date=2/27/96 4 10,641' 4-1/2"OTIS X Nipple,9Cr-ID=3.813" 5 10,662' 9-5/8"x 4-1/2"TIW HB-BP-T Packer-ID=3.910" 6 10,728' 4-1/2"OTIS X Nipple,9Cr-ID=3.813" ' 4 7 10,749' 4-1/2"OTIS XN Nipple,9Cr-ID=3.725" 8 10,760' 4-1/2"WLEG-ID=3.958"-Btm @ 10,762' 5 PERFORATION DETAIL Mn ID 3.725" ^ 6 END Btm Top @10,745 Sands Top(MD) (MD) (TVD) Btm(TVD) FT Date Status Size IV 7 11,417' 11,437' 9,924' 9,941' 20 9/11/2014 Open 2-7/8" 11,448' 11,463' 9,983' 9,962' 15 9/11/2014 Open 2-7/8" 8 11,524' 11,544' 10,013' 10,029' 20 Future Future Future • 11,564' 11,594' 10,046' 10,072' 30 4/26/1995 Leaking 2-7/8" Er MI 11,590' 11,600' 10,068' 10,077' 10 4/4/1996 Open 3-3/8" END Sands 11,610' 11,634' 10,085' 10,106' 24 4/26/1995 Squeezed 3-3/8" 11,625' 11,635' 10,098' 10,107' 10 5/22/1998 Open 3-3/8" 11,640' 11,694' 10,111' 10,157' 54 4/26/1995 Leaking 3-3/8" 9-5/8" • =II 11,690' 11,700' 10,154' 10,163' 10 4/4/1996 Open 3-3/8" 11,760' 11,770' 10,215' 10,224' 10 4/26/1995 Covered 3-3/8" Tap of Cement@ 11,765' 11,795' 10219 10,246' 30 3/19/1996 Covered 3-3/8" 11,738'-9/13/13 714 Reference Perf Log:CBT/GR on 5/1/1987 T of Sand @ ,« �*`Y Top R GENERAL WELL INFO 11,770-9/13/13' ° i a API:50-029-21713-00-00 ''7 « Initial Completion by Doyon 15 -7/22/1987 FISH-Male QC 5°r t RWO w/Doyon 15-2/27/1996 34/4"Cent Tel ;. ,, , , Sand Plug w/Cmt Cap-9/13/2013 @ 11,824'SLM 44,41 r `« sA TD=12,180'(MD)/TD=10,585'(TVD) PBTD=11,938'(MD)/PBTD=10,371'(TVD) Revised By:DH 10/17/2017 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,July 13,2016 Jim Regg P.I.Supervisor Teti 1114'I i 4' SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 1-41 FROM: Bob Noble DUCK IS UNIT MPI 1-41 Petroleum Inspector Src: Inspector Reviewed By:i� P.I.Supry NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT MPI 1-41 API Well Number 50-029-21713-00-00 Inspector Name: Bob Noble Permit Number: 187-032-0 Inspection Date: 7/10/2016 Insp Num: mitRCN160710133315 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 141 ' Type Inj W'TVD 9356 ' Tubing 2241 2215 2232 - 2199 - PTD1 1870320 , Type Test SPT Test psi 2339 - IA 1340 2806 - 2782 2764 - Interval 4YRTST 1P/F P / OA 220 390 . 390 _ 390 Notes: SCANS® NOV 2 22016 Wednesday,July 13,2016 Page 1 of 1 • • R - .. F V Post Office Box 244027 3 Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JULV 0 2O1 3800 Centerpoint Drive Suite 100 AOGCCAnchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 S`NItt4 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ( 07 - 0 3 dcc�� " Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I"followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/134" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp Orig • New API_WellNo PermitNumber WellName WellNumber WeIlNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/119 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/118 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 'DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/117 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/Q26 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/021 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/Q20 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/Q20 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/122 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/016 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/L16 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 50029219310000 1890340 DUCK IS UNIT MPI 2-22/L14 2-22 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. / ~ ¢- ~,.~ _~ Well History File Identifier " RESCAN DIGITAL DATA OVERSIZED (Scannable) [3 Color items: [3 Diskettes, No. [3 Maps: [3 Grayscale items: D Other. No/Type ~" Other items scannable by large scanner [3 Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds ~' ~ Other TOTAL PAGES: /~1'-~ NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Scanned (done) IIIIIIIIIIIIIIIIIII PAGES: Iq¢ (at the time of scanning) SCANNED BY; ~BREN VINCENT SHERYL MARIA LOWELL RESCANNEDBY; BEVERLY BREN VINCENT SHERY~ MARIA ~C~WELL General Notes or Comments about this file .~ PAGES: DATE fSI Quality Checked (done) RevlNOTScanned.w¢ UNSCANNED, OVERSIZED MATERIALS AVAILABLE: 1 ~1- 03;< FILE # L P 4d IYltf To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission J 333 W. 7th Ave., Ste. 100 J Anchorage, Alaska 99501 Voice (907) 279-1433 tFax (907) 276-7542 STATE OF ALASKA RECEIVED • AOKA OIL AND GAS CONSERVATION COMMON OCT 1 1 2013 REPORT OF SUNDRY WELL OPERATIONS ��°�o ,�� 1.Operations Abandon U Repair Well U Plug Perforations Lj Perforate U Other U a'° ° Performed: Alter Casing ❑ Pull Tubing0 Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Na me: BP Exploration(Alaska),Inc Developments Exploratory ❑ 187-032-0 • 3.Address: P.O.Box 196612 StratigraphiC Service © 6.API Number: Anchorage,AK 99519-6612 50-029-21713-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312828 • EPA 1-41/0-23 ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): ENDICOTT,ENDICOTT OIL ' 11.Present Well Condition Summary: Total Depth measured 12178 feet Plugs measured 11738 feet true vertical 10581.77 feet Junk measured 11824 feet Effective Depth measured 11738 feet Packer measured 10661.74 feet true vertical 10194.58 feet true vertical 9354.67 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 30"CONDUCTOR 39.45-119.45 39.45-119.45 Surface 2433.81 13-3/8"68#L-80 40.53-2474.34 40.53-2474.31 5020 2260 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 1268.92 7"29#L-80 10751.08-12020 9418.75-10442.7 8160 7020 Perforation depth Measured depth See Attachment feet 14 ti' .� t-�i �� True Vertical depth See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 36.9-10761.66 36.9-9426.38 Packers and SSSV(type,measured and true vertical depth) 4-1/2"TIW HBBP-T Packer 10661.74 9354.67 Packer 4-1/2"MCX I-SSV 1515 1514.99 SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 14769 2063 Subsequent to operation: 10224 2307 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service p • Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U Gas U WDSPLU GSTOR ❑ WINJ 0• 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: N/A Contact Garry Catron Email Gar .Catron • BP.Com Printed Name Garry Catron Title PDC PE Signature _RIA , vr Phone 564-4424 Date 10/11/2013 1/L r: /0I BB['NIS OCT 14 Form 10-404 Revised 10/2012 Submit Original Only Casing / Tubing Attachment ADLO312828 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 30" CONDUCTOR 39 - 119 39.45 - 119.45 LINER 1269 7"29# L-80 10751 - 12020 9418.75 - 10442.7 8160 7020 PRODUCTION 9152 9-5/8"47#NT80S 39 - 9191 38.99 - 8286.14 6870 4760 PRODUCTION 1833 9-5/8"47# NT95HS 9191 - 11024 8286.14 - 9619.33 8150 5080 SURFACE 2434 13-3/8"68# L-80 41 - 2474 40.53 - 2474.31 5020 2260 TUBING 10725 4-1/2" 12.6# L-80 37 - 10762 36.9 - 9426.38 8430 7500 Ill • Perforation Attachment ADL0312828 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 1-41/0-23 4/4/1996 SQZ 11564 11590 10045.07 10067.15 1-41/0-23 4/4/1996 APF 11590 11594 10067.15 10070.55 1-41/0-23 4/4/1996 APF 11594 11600 10070.55 10075.67 _ 1-41/0-23 5/22/1998 SQF 11610 11625 10084.2 10097.03 1-41/0-23 5/22/1998 SQF 11625 11634 10097.03 10104.74 1-41/0-23 4/4/1996 APF 11634 11635 10104.74 10105.6 1-41/0-23 2/19/1996 SQZ 11640 11690 10109.88 10152.9 • 1-41/0-23 4/4/1996 APF 11690 11694 10152.9 10156.35 1-41/0-23 4/4/1996 APF 11694 11700 10156.35 10161.54 1-41/0-23 9/14/2013 SPS 11760 11765 10213.85 10218.23 1-41/0-23 9/14/2013 SPS 11765 11770 10218.23 10222.63 1-41/0-23 9/14/2013 SPS 11770 11795 10222.63 10244.63 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • • m .Q 0 L ,a o o ° � � p a) D. a) = E o M c -a CO 10 •-- co C N 0_ c O - co - . E Oct O p �' C co c co 0 ° o f -a °) o cc a) .0 C C 7 a a U E N .�U > Y Q3 O a) U= c = y aria °—�i O > O CZ •- Q> a - o (LEI (f) aa) a� a 0 o0 •1- n o .- c _ o Ci) a) �� a ° � UfY r = ° o o * � o - 73 aNi _ to p C an. ca a) a) OY a) Eoo c ° � a. aL _ca -c L .. N L (V In (0 ✓m- -o N r O) a U co a-5 N U O co OC U C 4- r M U in - (A 2 O o O (N N C QI� O ° +. N D co o 0 D a) O 7 L (o C (\j O M H as Z (0 is Q O E a p M "O E U C_) =a)C 3 = Q E °' 0 co = co c O =m °) '� 3 = N *k c as .3 c 2 aa)) CO Co ° = O c 4- r C C).o r °'co (6 N C) E .N o _ a) N m E o co C a) — n -° O = w E �i � co QQLO >,N p Q U - 0 3 06 0 0 -a v- _0 C C as u) 0 02 -v U Ear - c o o -a >,'E a) p0° ,_ . .� L N Z 7 ° - CD C C co 0 0 (a CO ° L cr)CD 0 —) . co 0 (0 (n & c as co C (/) M Q a) L a) O N N 2 ill O N ca a) O La Z "r r a) Op +3 U N a N 2� ) .0 r 0 IT t (A J - 0 c3aC) cQ- ) '0 C * o 4-6 co 0 L co L k C ° ca c :.--q O cL1 O Q E13 •0� C N � aw u) a) _c _c � a3 v) ON CH o CD E � oo E ° cO � Q � (na. o- - N n N Ecn .0 Ce V J c U C ,-- CS) -'-' CL NO M N U U a) w U to U N _ ;.= Daily Report of Well Operations ADL0312828 ***WELL SHUT IN UPON ARRIVAL***(E-LINE PERFORATING) INITIAL T/I/0=1650/200/0 PSI RIH W/6'x2-1/8"WEIGHT BAR (x3)/JARS SET AT 500#/GR/CCL/BULLNOSE TOOLS FALL SLOWLY AT 11600', TAG SOFT/STICKY TD AT 11657' PULLED 600#OVER PICK UP WEIGHT BEFORE TENSION LEVELED OUT RIH W/20'x2-7/8" 2906 HMX PJ OMEGA PERF GUNS (14' LOADED) INTERVAL 11444'-11458', CCL TO TOP SHOT=9.3', CCL STOP DEPTH=11434.7' ATTEMPTED TO MITIGATE OVERBALANCED CONDITIONS STARTED TAGGING SCHMOO AT SHALLOWER DEPTH DECISION MADE TO POOH, NO PERFORATIONS SHOT WELL SHUT IN ON DEPARTURE, DSO NOTIFIED FINAL T/I/0=1100/200/0 PSI 9/16/2013 ***JOB CANCELED*** ***CONT FROM WSR 9/16/13*** RAN 3.25" CENT, TEL, SAMPLE BAILER LOCATED TUBING TAIL @10728' slm(10762'md)(+34' correction) SD @11258' SLM (11292'MD) RECOVERED SAMPLE OF SCHOOM/SOME CEMENT 9/17/2013 ***WELL S/I ON DEPARTURE*** ****WELL S/I UPON ARRIVAL**** (profile modification) DRIFTED W/ 3.25" CENTRALIZER, TEL, 3" SAMPLE BAILER, S/D @ 11,371' MD (sticky) (sample of schmoo) BRUSH SVLN W/3.85" CENTRALIZER, 4-1/2" BRUSH, 3.805" GAUGE RING SET 4-1/2" MCX-SSSV(serial# M-15, 1.30" bean) IN SVLN @ 1481' SLM / 1515' MD 9/26/2013 ****CONT. JOB ON 9/27/13**** ****CONT. JOB FROM 9/26/13****(profile modification) RAN 4-1/2" CHECK SET TO MCX @ 1515' MD (indicated good set) PERFORMED PASSING DRAW DOWN /CLOSURE TEST 9/27/2013 ****WELL LEFT S/I &WELL TENDER NOTIFIED OF STATUS UPON DEPARTURE**** `Tim= C]VV E: "'WELL REQUIRES A SSSV'"' WB LF EAD= C3W END 1 -41 SA NOT COMPOSITE WRAP REPAIR SH LEAK-DO NOT PUPA ACTUATOR= OTIS ( I M EDAM ETH BLEND INTO OA DUE TO CI-EM OKB.ENV= ENINCOMPATIBILITY w/EPDXY RESIN IN WRAP"' BF.E EV= 15.8' "'4-112"CHROME NIPPLES'" Max Angle= 46'@ 10279' 1615' H4-1/2"HXO SV LN(9-CR),D=3-813' Datum MD= 11571' Datum TVD= 10000 SS GAS LIFT MANDRELS 13-3/8"CSG,68#,L-80 BTC,D=12.415" H 2474' ST MD TVD DEV TYPE VLV LATCH PORT DATE I ' I 2 3415 3415 1 ITS DIM' RA 0 02/27/96 1 10571 9290 45 I-ES DMY RA 0 02/27/96 9-5/8'CSG,47#,NTSOS NSCC x0 —I 9191' —X X NT95HS NiSCC 10641' --I4-112"OTIS X NP(9-CR),D=3.813" 10667 —19-5/8"X 4-1/2"TIW HBBRT PKR,D=3.910" Minimum ID =3.725" @ 10749' 4-1/2" OTIS XN NIPPLE ' , 10728' —14-1/2'OTIS X NP(9-CR),D=3.813' ' 10749' --I4-1/2'OTIS XN NP(9-CR),D=3.725" TOP OF 7"LNR H 10751' 4-1/2'LW., 12.6#,L-80 BTC, -j 10762' —/ ` 10762' — 4.1/2'VVLEG,D=3.958' .0152 bpf,D=3.958" 9-5/8"CSG,47#,NT95S NSCC,ID=8.681" — 11024' J • , PERFORATION SUPAAARY REF LOG:CBT/GRon 05/01/87 ANGLE AT TOP FERF:32°@ 11590' Note:Refer to Production DB for historical pert data SCE SPF INTERVAL Opn/Sqz SHOT SQZ 11564-11590 S 04/04/96 11564-11594 S 02/19/96 3-3/8" 6 11590-11600 0 04/04/96 11610-11625 0 07/20/87 11610 11634 S 02/19/96 �.�.�...�.�.�.� 11738' H TOP OF CEMENT(09/13/13) 3-3/8" 6 11625 11635 0 04/04/96 ••••••v•v�••# 11640 11690 S 02/19/96 11770' SAND PLUG(09/13/13) 11640-11694 S 05/19/95 3-3/8" 6 11690-11700 0 04/04/96 11760-11765 S 03/19/96 11760-11770 S 02/19/96 3-38" 6 11765-11795 C 03/19/96 11824'SLM HFISH:MALE QC,3.25"CENT TEL(07/21/07) FBTD 11885' •T•vvvvv• (7'Lt,29#,L-80 BUTT,.0371 bpi,D=6,184" 12020' I'�'�'�'�'�'�'�'�' DATE REV BY CX)PJt fTS DATE REV BY COMMENTS ENDICOTT UNIT 07/23/87 D15 IMTIAL COMPLETION 11/10/10 JM) FORMAT REVISION WELL: 1-41/0-23 06/29/96 D15 RWO 09/17/13 TRRJJMD SET SAND PLUG&CMT(09/13/13) PERMT No: 1870320 07/19/07 SPF/PJC SSSV CORRECTION AR No: 50-029-21713-00-00 07/21/07 JCM'PJC FISH @ 11824'SLM SEC 36,T12N,R16E,2120'FNL&2153'FEL 03/18/10 JLW/SV CSG COTTON 09/23/10' PJC SAFETY NOTE UPGRA OE BP Exploration(Alaska) • • • • �AV OF • /Tye THE STATE y,��l//i�, Alaska Oil and Gas - - Conservation Commission ALASKA owl ,,, GOVERNOR SEAN PARNELL 333 West Seventh Avenue o� OFALAS� Anchorage, Alaska 99501-3572 Main: 907.279.1433 f r Fax: 907.276.7542 ,�a Michael Hibbert O* Well Interventions Engineer 2. BP Exploration (Alaska), Inc. 7 3 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Endicott Field, Endicott Oil Pool, EPA 1-41/0-23 Sundry Number: 313-408 Dear Mr. Hibbert: 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 P. Foerster / Chair DATED this /(o day of August, 2013. End. 4 • STATE OF ALASKA $,k JUL. 2 9 ALASKA OIL AND GAS CONSERVATION COMMISSION 07-5 41/S'/ /e...3 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations 0 ' Perforate Q • Pull Tubing[] Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Development ❑ Exploratory ❑ 187-032-0 • 3.Address: 6.API Number. Stratigraphic ❑ Service 12 - P.O.Box 196612,Anchorage,AK 99519-6612 50-029-21713-00-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 462 EPA 1-41/0-23 - Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312828 • ENDICOTT, ENDICOTT OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12178 • 10582. 11885 10324 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 92 30"CONDUCTOR 39-131 39-131 Surface 2436 13-3/8"68#L-80 38-2474 38-2473.97 5020 2260 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 1269 7"29#L-80 10751 -12020 9418.69-10442.7 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 35-10762 Packers and SSSV Type: 4-1/2"TIW HBBP-T Packer Packers and SSSV MD(ft)and TVD(ft): 10662,9354.86 4-1/2"HES HXO SSV 1515',9354.86' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program ® BOP Sketch ❑ Exploratory ❑ Development ❑ Service 5 - 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9/1/13 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 5 • GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Michael Hibbert Email Michael,Hibbert a( �BP.com Printed Name Michael Hibb rt Title Well Interventions Engineer Signature V hone Date r 564-4351 7/25/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 15•- 1/01 \J1� Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RBDMS OCT 1 0 2013 Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 10// APPROVED BY Approved by: / COMMISSIONER THE COMMISSION Date: g-/ - /3 V P 811571 77 ///'''�� kbhs Form 10-403 Revised 1/2010 �Cpprove. . tIli from the date of approval. ,,,,Syibgiit in Duplicate j.7. .,j7 1 I • • .. <> PERFORATING PROCEDURE Ver 1.2,Rev 10/21/01 Well: End1-41 API#:50029217130000 Date: 05/17/2013 Prod Engr Steve Cinelli Office Ph: 907 564 5919 H2S Level: Home Ph: Injector N/A Cell/Pager: 907 240 0713 .......................................................................................................... WBL Entries IOR Type Work Desciption • 100................i..............._E................Add 20 ft of perforations 1.00................[..............._E................Add 14 ft of perforations Well Objectives and Perforating Notes: Perforate Zone FIV. Given the depths below.Perfs are annotated on the Reference and Tie In Logs. Attachment: Reference log with proposed perfs annotated,5"/100'scale Reference Log Tie in Log Add _........._N/A................... feet Log: Cement Evaluation Log Same as Reference to the tie-in log to be on /198.................................. g Date: 5/1/1987 depth with the reference log. Company: SLB Depths(from-to) Depths(from-to) Feet SPF Orient. Phasing Zone Add/Re-pert 11,412'.... 11,432'................. 11,412'........... 11,432''.... ..._20'..... 6 N/A 60° S3A4 Add 11,444' 11,458'................. 11,444'........... -....11,458''.... ...._14'..... 6 N/A 60° S3A3 Add Requested Gun Size: 2.875" Charge: PowerJet Omega HMX Is Drawdown Necessary/Desired/Unnecessary During Perforating NA .. .............................................................................................................................................................. Preferred Amount of Drawdown/Suggestions to Achieve Drawdown .. .............................................................................................................................................................. Last Tag:°°wL 11,791....................ft ELMD on 6/12/2010 Est Res.Pres.x..................11,576 MD is ................................4,600 psi Perforation Summary Summary Dist Well: End1-41 Town: Date: API#: 50029217130000 Prod Engr: Anch Prod Engr P.D.Center PBTD ........._............................................................. General Comments: Depths Balance Based on Ref Log Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf 0/B/U - 0/B/U - 0/B/U - 0/B/U - 0/B/U - 0/B/U - 0/B/U - • • To: Jerry Middendorf/Rob Liddelow (Wireline Operations Team Leader) Len Seymour/Tyler Norene(Operations Team Leader) Date: 7/22/2013 From: Ricardo Saldana Well Interventions Engineer AFE: AENNRWOS Contacts: (Cell) Ricardo Saldana: 907-564-4670 (office) 832-758-4564 (Cell) Well: END1-41 IOR: 350 Subject: Sand Plug and Addperf Summary: Step Unit Operation 1 S Pull SSSV and Drift& Tag 2 C Sandback Plug w/ 1 bbl of Cement Cap 3 E AddPerfs 4 S Set SSSV Well Detail: Current Status: Operable PWI Max Deviation: 46° @ 10279' Minimum ID: 3.725" @ 10749', OTIS XN nipple Last Representative 7/07/2013 1987 psi WHIP, 6049 psi BHP, 13618 BBLs Well Test: Injection Vol. Last Downhole Op: 6/12/2010 Drift to 11744' SLM (after SBG) Last Drift/Tag: 6/12/2010 Drift to 11744' SLM (after SBG) Latest H2S Value: None None Injection Pressure 7/07/2013 1987 psi WHIP Objective: The objective of this procedure is to sandback the K2A subzone to inject more water into the K2B. Additionally, S3A3 and S3A4 will be perforated. Discussion: End1-41 is a Kekituk K2A and K2B injector in the MPI fault block. The well is currently injecting to 14000 BWPD equally into the K2B and K2A subzone with a VRR of .06 and 1.3 respectively, indicating over injection into the K2A. The K2A and K2B are separated by the K2M subzone; there are no plans to inject to the K2M subzone. The well will also be perforated in another part of the kekituk formation, S3A3 and S3A4. The well's tubing has been treated with SBG. The well has a SH • • leak which was repaired with a furmanite composite wrap. Pumping methanol in the OA should be avoided as well as pressuring it above 1200 psi. f r�Y'� -L '� t "'r &` yq� S`��`fi7 1 es�" as d 2's, t w � y, , 1. Remove MCX @ 1515'MD. 2. RBIH and D &T with TEL. Coiled Tubmq- Place Sand Plug With,4 E BE **e*t 1. RU 1.75" CT. 2. MU CT flag logging tools. RIH and tag TD. Paint flag at 11,720'MD. POOH. 3. MU BHA w/ cementing nozzle (minimum '/z" main hole and 4-6 small down-jets of about 1/4"), stingers, disco, and CTC. (No DFCV). 4. Pump 280 bbls of 1% KCI down CTBS followed by 36 bbls of diesel. This will underbalance the well and allow for better monitoring of well conditions while laying in sand plug. 5. RIH and dry tag. Tie into Coil Flag. 6. PUH 5'-10' and batch up sand slurry. a. Mix 6 bbls of FW with 10 lbs of HEC for gel spacers and .5 lb of HEC breaker. b. Mix 1.9 bbls of FW with 632 lbs of 20/40 river sand, 3.2 lbs of HEC and .1 lb of HEC breaker. Product Volume Weight Sand—20/40 river sand 1.2 bbls bulk 632 lbs Sand Slurry Gel 1.9 bbls of FW 3.2 lbs HEC HEC Breaker 0.1 lb Total Slurry 2.6 bbls Clean HEC Gel 6 bbls of FW 10 lbs HEC SLB currently stocks Badger River sand which has a bulk density of 531.4 lb/bbl and an absolute density of 928.2 lbs/bbl. • • 7. Pump the following down the CT max rate: a. 3 bbls gel spear b. 2.6 bbls of sand slurry c. 3 bbls gel pill slurry with 60/40 d. Displace san d ry 8. When sand slurry arrives at nozzle then slow down to 1 bpm and lay in 1:1. 9. When end of sand slurry exits nozzle then pump 1 additional bbl of 60/40 and then shut down pumps and PUH to safety. 10.Wait for gel to break and sand to settle for 1 hour. 11. RIH and dry tag sand plug. PUH 25'. Wait 30 min and retag. Repeat until tag is repeatable. Once sand tags is stable then determine if additional sand is needed or if plug is within the acceptable range (11750' +/- 5'). a. If additional sand is needed then use Table 1 and Appendix 1 in the `Laying Sand Plugs with Coiled Tubing' RP in the PE manual to determine quantities of sand and fresh water for slurry mixture. Use sacked sand for fine tuning the sand top. b. If sand is found to be too high then fluff sand and try to remove any possible bridges. 12. POOH 13. MU pig shear cement nozzle and RIH and tag sand top. 14. Batch 1 bbl of pumpable cement. Cement Specs: Well END1-41 Date 7/10/2013 Well Properties MD(ft) 11,782' TVD(ft) 10,223' BHST(degF) 214 BHCT(degF) 200 BHP(psi) 4400 Cement Requirements • • Density(ppg) 15.8 System (UniSLURRY, GASBLOK, LARC, etc.) Class-G Batch Mix or on the Fly Batch Thickening Time(hr:mn) Min:4:0 Max:6:0 Free Fluid (ml) Trace Fluid Loss,API (ml) Min:30 Max:80 Compressive Strength (psi) 2500 psi Filter Cake(in) Min:.5" Max:1" Pre or post job UCA No Job Volume(bbl) 1 bbls 15. Launch pigs and ball according to PE Manual `Small Cement Plugs with Coiled Tubing'. Pump 3-5 bbls fresh water spacer before and after cement. 16.Adjust nozzle 5-10' above sand top. 17. Displace cement to nozzle at 1-2 bpm. Slow down to .5 bpm when cement is within 2 bbls of the nozzle. 18. Continue to pump until the ball lands on seat. Do not shear! 19. PUH 25' above WCTOC wait 5 min for cement to settle and then shear nozzle. 20. POOH circulating at min rate. E-fine: Perforate 1. Ensure well is SI. 2. RIH with 14' of 2 7/8" Power Jet Omega HMX a. Tie into the SLB Cement Evaluation Log dated 5/01/1987. 3. Perforate 11444' MD to 11458'MD. 4. RBIH with 20' of 2 7/8" Power Jet Omega HMX 5. Perforate 11412' MD to 11432'MD. 6. POOH Slickhne: 1. RIH and Set SSSV @ 1515' MD, 4'/2" HXO. • Appendix 1: WBS TRH SAFETY EP 'lM.LHEAD= OW END 1 -41 O SI � DO OT PUN P ACTUATOR -CITE 1 f METNMETNBLf31DINTOOA WETOGF93N KB.B EV= 15.8' I NGOM PATIBILfTY w/EPDXY RESIN IN WRAP" BF ELEV= 15.8' '•"4-1/2"CNRDME NIPPLES*" KOP= _ atom MD 11577' I 1 1515' N4.1/7 WO SV LN(3-014,m:3-813" mtum TVD• .__ 10000 55 I 1 GAS UFT MANDRELS 113-31E1 G80,611,1-80 eTe D•1?,418' 2474' Mo DEV ligM LATCH PORT DATE 2 3415 3415 1 HES DUI El 0 02177/96 1 10571 9290 45 FES UK 0 02/27196 3518'CSC:47*.NT806 NSCC X0 1-H 9191' 1 NT96HS NSOC j I 10641' H4112.(715 X NIP$.Clq,D 3,813` I oar H'518"X 4-1/2"TYYNBSATWM,o•;.91ar H —I Minimum ID=3.725" 10749' 4-112"OTIS XN NIPPLE 10728' H4-1/7 OTIS X NIP(9-CRL D=3.813' I 1o70/ H4.1/7 OTIS XNNP(f-cRi,IO=372'5" I TOP OFTLNR —I 10751' I • 4 117 LN!12 OP L-80 B7C, —I 10767 (- 1 I 107!2' ,4.1/7"WEED,C•3-958' .0152 Of,0=3988' 9.51P3 CSG,415 NT95S MCC,0=8.681" H 11024' 1 P6i:ORATION SUMMARY Rff LOG:CBT/GR an 0601/87 ANGLE AT TOP FERF 32' 11590* 1.411c Rsfar to Producron CB for historical parr data SEE SFF 1'REiVAL Opr/Sqz DATE 11564-11590 S 0404/96 11564-11594 S 0219/96 3-318" 6 11580-11600 0 04/04/96 11610.11625 0 0712087 11610 11634 S 07/19/96 3-3m"" 6 11625-11635 0 04/04/996 11640-11890 S 02/19/96 11640-11694 S 05/19/95 3318' 6 11690-11700 0 04/04/96 ' 11760-11765 S 03/19/96 _ 11760-11770 S 02119196 3-316" 8 11766.11795 0 03/19/96 1 11624'SLM H}'ISH MALE QC,3.25'CENT TEL(07/21)07) Inn)H .44+414444444+4 9 r•4•4•4•4•4�4•/•4∎ rLNR 29/,L.-00 sun, 0371 hpf,D+6.184' H 12020' DATE REV BY COMMENTS DATE Fe/BY COb/1C TS ENCICOTT UNIT r0'1f2167 DI5..._ INITIAL COMPLETION 11/10110 JM7 FORMATRVVISION WELL 1-41/0-23 95129/96 015 IMO 02/24411 WNW ADDED SSSV SAFETY NOTE P86Mff No. "870320 07/19/07 SFf1PJC SSSV COmBCTTON 08/12/11 C1,413MI:) ADDED FES SAFE I Y NOTE API No 50.029-21713-00-00 07/21107 JCM IFJC FISH 0 11824'SLM _02193/12 PJC LEGEND CORRECT1ONS SEC 36,Tim,RI 6E,2120'FM.&2153 FEL 03118/10 JLNISV C8G CORRECTION 04193112 ?MC P6 F UFDATES 0923110 PJC SAFETY NOTE UPGRADE BP Exploration(Alaska) . • Appendix 2: Cement Evaluation Log dated 05/01/1987 CEMENT EVALUATION LOG herger COMPANY STANDARD ALASKA PRODUCTION CO. WELL 1-41/0-23 MPt 2 FIELD ENDICOTT BOROUGH NORTH SLOPE STATE ALASKA 2121' FM. • 2153' FEL 1d218-T133' aw�+r�+..� ciT { acTSCYR01 AT SURFACE' API SERIAL Nt? SECT. TWP. RANGE * t , g e _5002921713 36 12 N 16 E Permanent Deti m MSL Elev. 0.0 F ENV.i(..G, 65.3 F Log Measured Fiore KB 66.3 F above Perim. Datum Q.F. 66.3 F O,Mng Measured From KB G.L. 14.6 F Dote 1-MAY-87 Run No. ONE Depth Oilier 11932.0 F Depth Logger (Sena.) 11818.0 F stm Lob Interval 11812.0 F Top Log Interval 10700.0 F — Type Fluid in Nell ERNE sai lilty Density '9 60 L8/G Field Level Msi. Rae. Terra. Deviation 42 DEG Legge/ on Bottom 1600 1-MAY-87 Equip 1 Looatioe 8345 I PRUDI+OE BAY RReeocwrded Sy S. J. SALAZAR Wilimesed By DAN CARTER BOREHOLE RECORD 1M Rte 17.0 • 12 25 • 860 - Dw+h CASING 8 T1JBHHG RECORD She 13.375 9.625 7.0 ' Weight 72-0004 LB/F 47.0000 LB/F -29.0000 LB/F • • Appendix 3: Estimated Sand and Cement placement - = JOINfiB MOW _ - f COU!R s V • � 4..--°s ;..t,. I tf __.,. 11•11 4 ' . —.�. — Cement as t + it r0 -gessrvt .._..-4-.5-, 1 AIKI ti - :t __TM At_ a�! r ?+� Sand t MB . taz a A -. _...:._.. 4 w ,� �_,_ _ _ 3 .rN ,. I • • Appendix 4: Perforations vr��rr 1 130 0 .---: , • - AMIN 111111M11111111 1 •� y :ii. ■-. . c s� -I ..i ... i ` : R x -a to. ^ �6rnrra�rrmrn.—^a -•MIMI _ I=Mil 11111111111111 Q t ~ was rrrrsr∎ ,1 _ } , �� _- �, - ` _ 1. a r r! ra _i_ 1: ram < --J_ illt 1;1.1 r .4... < t *a i 1.r i m�s _. J ifir•+ . - II - illialill NM= r t+ 1 - r _ - rrBr��rrr� r♦ '.`Y QQQQ1l '7�� --- - --- ' • , '.._:•,`. .,,^. . I 1 it !'.wi rr ice- _f---t . '-. • •- t F t ______ .r .- I , —f n -- ' j Q r• = 11400 Mil ■. .I.. - '.I II I Perforate 11412'-11432'MD = ' r ,a KIE --t,----fr-L Perforate ' 11444'-11458'MD _ 1 r� — I s1. . ■Q t — � aillidiriUMMINsia.._ i''' ____ x 6 .dr N. 4*--- Nil In r= 40 �, s ■ r� I FM ri= moisIN • • Perforation Attachment ADL0312828 Well Date Perf Code MD Top MD Base TVD Top TVD Base 1-41/0-23 4/4/96 SQZ 11564 11590 10045 10067 1-41/0-23 4/4/96 APF - 11590 11594 10067 10071 1-41/0-23 4/4/96 APF 11594 11600 10071 10076 1 1-41/0-23 5/22/98 SQF 11610 1 11625 10084 10097 4 1-41/0-23 5/22/98 SQF 11625 11634 10097 10105 1-41/0-23 4/4/96 APF 11634 11635 10105 10106 1-41/0-23 2/19/96 SQZ 11640 11690 10110 10153 1-41/0-23 4/4/96 APF • 11690 11694 10153 10156 1-41/0-23 4/4/96 APF 11694 11700 10156 10162 1-41/0-23 3/19/96 SQZ 11760 11765 10214 10218 1-41/0-23 3/19/96 RPF 11765 11770 10218 10223 1-41/0-23 3/19/96 RPF 11770 _ 11795 10223 10245 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF . ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF • REPERF • Casing Summary ADL0312828 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade LINER 1269 7"29# L-80 10751 12020 9419 10443 8160 7020 L-80 PRODUCTION 9154 9-5/8"47# NT80S 37 9191 37 8286 6870 4760 NT80S PRODUCTION 1833 9-5/8"47# NT95HS 9191 11024 8286 9619 8150 5080 NT95HS SURFACE 2436 13-3/8"68# L-80 38 2474 38 2474 5020 2260 L-80 TUBING 10727 4-1/2" 12.6# L-80 35 10762 35 9427 8430 7500 L-80 CONDUCTOR 92 30" CONDUCTOR 39 131 39 131 • • • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 840F: Mr. Jim Regg Alaska Oil and Gas Conservation Commission 1 7 _ D 39-- 333 West 7 Avenue �3 Anchorage, Alaska 99501 Et r .. 41/0 Subject: Corrosion Inhibitor Treatments of Endicott Row 1 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 1 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 - 5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Endicott Row 1 Date: 09/24/2010' Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal END1 -01 /J -19 1880370 50029218010000 1.5 0.3 0.5 9/2/2010 0.85 9/23/2010 END1 -03 / P -16 1951500 50029226018000 4.0 3.5 0.5 9/2/2010 5.10 9/23/2010 END1 -05 / 0 -20 1861060 50029216050000 0.3 NA 0.3 NA 1.70 9/23/2010 END1 -09 / L -21 1970290 50029217430100 6.0 5.0 0.5 8/28/2010 3.40 9/23/2010 END1 -15 / P -25 1930560 50029223610000 4.0 3.0 0.5 9/2/2010 6.80 9/23/2010 END1 -17 /1-17 1961990 50029221000100 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -19 /1-18 1950930 50029225690000 7.0 9.3 0.5 9/2/2010 4.25 9/23/2010 END1 -21 / K -25 1900020 50029220050000 2.5 1.5 0.5 9/2/2010 1.70 9/23/2010 END1 -23 / 0 -15 1941280 50029225100000 12.0 12.5 0.5 9/2/2010 1.70 9/23/2010 END1 -25 / K -22 1970750 50029217220100 5.0 1.5 0.5 9/2/2010 5.10 9/23/2010 END1 -27 / P -20 1870090 50029216930000 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -29 / M -25 1861810 50029216690000 2.0 1.3 0.5 9/2/2010 1.70 9/23/2010 END1 -31 / M -21 1950720 50029225620000 5.0 1.8 0.5 9/2/2010 13.60 9/23/2010 END1 -33 / L -24 1982550 50029225770200 1.5 0.3 0.5 9/2/2010 3.40 9/23/2010 END1 -35 / 0 -25 1861840 50029216720000 8.0 4.8 0.5 9/2/2010 3.40 9/23/2010 END1 -37 / P -24 1870900 50029217480000 0.5 NA 0.5 _ NA 4.25 9/23/2010 END1 -39A / N -16 2061870 50029218270100 0.5 NA 0.5 NA 6.80 9/23/2010 /� END1-41 / 0-23 1870320 50029217130000 8.0 5.2 0.5 9/2/2010 4.25 9/23/2010 END1 -43 / P -26 1881050 50029218640000 2.0 0.5 0.5 9/2/2010 3.40 9/23/2010 END1 -45 / Q -26 1891240 50029219910000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -47A / M -20 1972030 50029216250100 1.0 0.1 0.5 9/2/2010 3.40 9/24/2010 END1 -49 / P -21 1880780 50029218410000 1.0 0.8 0.5 9/2/2010 3.40 9/24/2010 END1 -51 / V -20 1921190 50029223040000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -53 / Q-20 1941120 50029225010000 9.0 4.2 0.5 9/2/2010 1.70 9/24/2010 END1 -55 / R -25 1880210 50029217880000 1.3 0.1 0.5 9/2/2010 1.70 9/24/2010 END1 -57 / R -23 1881140 50029218730000 3.0 1.3 0.5 9/2/2010 5.10 9/24/2010 END1 -59 / 0 -24 1960220 50029226440000 3.0 1.3 0.5 9/2/2010 0.85 9/24/2010 END1 -61 /0-20 1941420 50029225200000 8.0 6.8 0.5 9/2/2010 2.55 9/24/2010 END1 -63 / T -22 1890060 50029219050000 8.0 4.1 0.5 9/2/2010 2.55 9/24/2010 END1 -65A / N -27 2032120 50029226270100 8.0 5.8 0.5 9/2/2010 3.40 9/24/2010 END1 -67 / T -20 1891140 50029219850000 0.5 NA 0.5 NA 1.70 9/24/2010 END1 -69 / V -19 1900290 50029220200000 15.0 10.3 0.5 9/2/2010 0.85 9/24/2010 STATE OF ALASKA ALASKA ~ND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other Q FURMANITE Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ WRAp Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 187-0320 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ API Number: Anchorage, AK 99519-6612 50-029-21713-00-00 8. Property Designation (Lease Number) : Well Name and Number: ~ECEIVED ADLO-312828 1-41/0-23 10. Field/Pool(s): ~ ENDI COTT FIELD / ENDICOTT OIL POOL ~EB 1 ~ zd~ 11. Present Well Condition Summary: Alaska 0~ g! ~$$ C~g~ ~p~j ~ Total Depth measured ~ 12178 feet Plugs (measured) None feet An~hurg~a true vertical 10581.77 feet Junk (measured) 11824' 7/21/07 feet Effective Depth measured 11885 feet Packer (measured) 1515 10662 true vertical 10323.86 feet (true vertical) 1515 9355 Casing Length Size MD TVD Burst Collapse Structural Conductor 92 30" 39 - 131 39 - 131 Surtace 2436 13-3/8"68# L-80 38 - 2474 38 - 2474 5020 2270 Intermediate 9154 9-5/8" 47# NT80S 37 - 9191 37 - 8286 6870 4760 Production 1833 9-5/8" 47# NT95HS 9191 - 11024 8286 - 9619 8150 5080 Liner 1269 7" 29# SM-110 10751 - 12020 9419 - 10443 11220 8510 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ - = True Vertical depth: _ - = = Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# LL-8p 35 - 10762 35 - 9427 Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES HXO SSV ,, , ~ .: 1515 1515 . _. ._ ,.. T Packer 10662 ~ fdl° 9355 1/2" TIW HBBP 4 - - pac /1- 12. Stimulation or cement squeeze summary: Intervals treated (measured): F ~;~V~r~i~~ ~°~~ ~ ~~~ ' Treatment descriptions including volumes used and final pressu re: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 6943 2004 Subsequent to operation: 14605 2197 14. Attachments: .Well C-ass after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ Daily Report of Well Operations X Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^Q 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: N/A Contact Gary Preble Printed Name Gary Pr ~ e Title Data Management Engineer Signature Phone 564-4944 Date 2/15/2010 It3n I Form 10-404 ReGised 7/2009 ~BDMS ~g 1 g 1010 G~~ ~~/ Z-~. ~~Submit,'Original Only -~~,~/~~ 1-4110-23 187-032 ... r.IT • • Sw Name Operation Date Perf Operation Code r~r~r r+~ ~ rw~ nna,.~ Meas Depth Top . ~ Meas Depth Base Tvd Depth Top Tvd Depth Base 1-41/0-23 7/20/87 PER 11,564. 11,594. 10,045.07 10,070.55 1-41/0-23 7/20/87 PER 11,610. 11,634. 10,084.2 10,104.74 1-41/0-23 7/20/87 PER 11,640. 11,694. 10,109.88 10,156.35 1-41 /0-23 10/15193 APF 11,760. 11,770. 10,213.85 10,222.63 1-4110-23 4/26/95 SQZ 11,564. 11,594. 10,045.07 10,070.55 1-41/0-23 4126/95 SQZ 11,610. 11,634. 10,084.2 10,104.74 1-41/0-23 4/26/95 SQZ 11,640. 11,694. 10,109.88 10,156.35 1-41/0-23 4/26195 SQZ 11,760. 11,770. 10,213.85 10,222.63 1-41/0-23 5119/95 SQZ 11,760. 11,770. 10,213.85 10,222.63 1-41/0-23 5/19/95 SQZ 11,640. 11,694. 10,109.88 10,156.35 1-41/0-23 5/19/95 SQZ 11,564. 11,594. 10,045.07 10,070.55 1-41/0-23 5119/95 SQZ 11,610. 11,634. 10,084.2 10,104.74 1-41/0-23 5/22/95 SQF 11,564. 11,594. 10,045.07 10,070.55 1-41/0-23 2/19196 SQZ 11,690. 11,694. 10,152.9 10,156.35 1-41/0-23 2119/96 SQZ 11,564. 11,594. 10,045.07 10,070.55 1-41/0-23 2/19/96 SQZ 11,610. 11,634. 10,084.2 10,104.74 1-41/0-23 2/19196 SQZ 11,760. 11,770. 10,213.85 10,222.63 1-41/0-23 3/19/96 RPF 11,765. 11,795. 10,218.23 10,244.63 1-41/0-23 4/4196 APF 11,625. 11,635. 10,097.03 10,105.6 1-41/0-23 4/4/96 APF 11,690. 11,700. 10,152.9 10,161.54 1-41/0-23 4/4196 APF 11,590. 11,600. 10,067.15 10,075.67 1-4110-23 5/22/98 SQF 11,610. 11,634. 10,084.2 10,104.74 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1-41/0-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY SUMMARY ACTIVITYDATE 1 /21 /2010; T/I/0=1400/290/Vac. Temp=S1. Clean SH & prep cellar; bleed IA & UH to u psi; put 25 psi N2 cap on OA (Furmanite wrap). No AL. IA has integral installed. Bled IAP to 50 psi in 5 hr (fluid gas mix). Placed 25 psi N2 cap on OA. Monitor 30 min, IAP unchanged. Final WHPs=1400/50/25. *"*Job incomplete*"" SV, WV=Closed. SSV, MV=Open. IA&OA=OTG. NOVP. 1/22/2010jT/I/0=1400/63/25. Temp-=S1. Assist w/ Furmanite wrap; oven oieea on UH Furmanite wrap). No AL. tAP increased 13 psi overnight. Bled IAP to 40 psi in 60 :min. Maintain open OA bleed to assist Furmanite. CCI sandblasted SH. `Furmanite Techs applied E-Glass layer to composite wrap. Wrap incomplete. Turn over to night crew. ***Job incomplete*"* w .. _ _~.._.._ 1/23/2010 T/i/0= SSV/40/0. Temp= SI. Assist w/Furmanite wrap; open bleed on OA (Furmanite wrap). Hold open bleed on OA. Heaters working properly. Final WHPs= SSV/50/0. SSV, WV, SSV= Closed. MV=Open. IA, OA= OTG. NOVP. ~.®e ~.. .. ~ m ~®a ~. 1/23/2010 T/I/0= 1400/50/0. Temp= SI. Assist w/ Furmanite wrap, open bleed on OA (Furmanite wrap). No AL (Inj). C/O w/night crew. Maintained open bleed on OA while Furmanite applied 1st set of carbon fiber layers to composite wrap. ;Continued monitor of open OA bleed until C/O w/ night crew. ***See log for details, ;job incomplete*** FWHPs= 1400/58/0. Night crew has control of wellhead. 1/24/2010;T/I/O-SSV/55/0. Temp=S1. Assist w/ Furmanite: open bleed on OA (Furmanite wrap). No AL. Assist Furmanite, Maintain open bleed on OA. Furmanite Techs applied 2nd set of carbon fiber layers to composite wrap. Wrap incomplete. `***Turned over to night crew*** • 1/24/2010~TI0 ssv/60/0. SI. Maintain open bleed on OA (Furmanite Wrap). No AL, Integral installed on IA. Maintained continuous bleed on OA for 12 hours, no fluid returns. Job in progress. Final WHPs=ssv/60/0. DHD day crew in control of the well. 1 /25/2010 1 /25/2010 TIO ssv/70/0. SI. Maintain open bleed on OA (Furmanite Wrap). No AL, Integral installed on IA. Maintained continuous bleed on OA for 12 hours, no fluid returns. Job in progress. Final WHPs=ssv/70/0. DHD day crew in control of the well. _____ ____w.a ~ _ _ ..~~~_ ~_.__.__ T/I/O =SSV/60/0. Temp = SI. Assist w/ Furmanite wrap, hold open bleed on OA (Furmanite wrap). PWI. C/O w/ night shift. Assist Furmanite. Hold open bleed on OA through day (no returns). Furmanite applied Final wraps @ 10:00. Composite wrap complete. Begin cure phase. FWHP's SSV/60/0. ,SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 1/26/2010~T/I/O= SSV/60/0. Temp SI. Hold open bleed on OA (Furmanite). Hold open =bleed on OA and monitor heater. Final WHPs= SSV/60/0. Change out with day crew. SV, WV, SSV= Closed. MV= Open. IA, OA= OTG. NOVP. .._a~ ~. e®.~... _.~__~ , ~...~ .~__ 1/26/2010 T/I/0= SSV/65/0. Temp= SI. Maintain open bleed on OA (Furmanite). Hold open ;bleed on OA and monitor heater. Final WHPs= SSV/65/0. ~SV, WV, SSV= Closed. MV= Open. IA, OA= OTG. NOVP. • 1 /26/2010 T/I/O=SSV/60/0. Temp=S1. Assist w/ Furmanite wrap, hold open bleed on OA (Furmanite wrap). No AL. Maintain open bleed on OA. **"turned over to night crew*** 1/27/2010'T/I/O=SSV/60/0. Temp=S1. Open bleed on OA (Furmanite Wrap). No AL. Bled IAP @ 10 am to 0 psi in 4 hr. SI IA bleed @ 1400 pm for BUR. IAP & OAP did not .increase in 5 hr. ***Turned over to night crew*"'' 1/28/2010T/I/O =SSV/0+/0+ Temp = SI. WHPs (post Furmanite wrap). No AL line. increased to 0+, OAP unchanged overnight. Heater working properly. WV, SV, SSV =closed. MV =open. IA, OA = OTG. IAP 10T/I/0= SSV/2/9. Temp= SI. Hold open bleed on OA (Furmanite). Monitor BUR on BOA till 2 am. Bled IAP from 2 psi to 0 psi. Bled OAP from 1 psi to 0 psi. Monitor .for 30 min. WHPs unchanged. Heater is working properly. Final WHPs= SSV/0/0. SV, WV, SSV= Closed. MV= Open. IA, OA= OTG. NOVP. 1 /30/2010 t i i ~._~...~.n. ~._......~® e~a,.. W~~. ~~_.~_ T/I/O =SSV/15/0+. Temp = SI. WHPs (Eval Furmanite wrap) make sure heater is working & bleed if OA > 5 psi. No AL. Heater is working properly. IAP increased 15 psi & OAP unchanged from 01-28-10 monitor. SV, WV, SSV =Closed. MV =Open. IA & OA = OTG. NOVP. • 2/1/2010 ~.~ . ~.._ _._m _._ ~ ~~ _ ~ .______~ T/I/O =SSV/20/0+. Temp = SI WHPs (Eval Furmanite wrap) make sure heater is ~ working & bleed if OA > 5 psi. No AL. Heater is working properly. Furmanite wrap j curing well, no signs of leaks of fluid saturation. IAP increased 5 psi & OAP ~ unchanged from 01-30-10 monitor. SV, WV, SSV =Closed. MV =Open. IA & OA = OTG. NOVP. 2/5/2010T/I/O SSV/0+0+. Temp SI. WHPs (eval Furmanite wrap). No visible signs of leaking on composite wrap. SV,SSV,WV=C. MV=O. IA,OA=OTG. NOVP. 2/7/2010 AL SI @ casing valve. __ _ w _ ~._..,_ _ _ ___... T/I/O=SSV/20/Vac. Temp=Si. MIT-OA "*Passed"* to 1200 psi with diesel (eval Furmanite repair). No AL. Increased IAP from a Vac to 1200 psi with 2.6 bbls of diesel. IAP lost 30 psi the 1st 15 mins & 10 psi the 2nd 15 mins for a total loss of 30 psi. There were no audible or visible signs of Furmanite wrap leaking,. Bled OAP to 0 psi. Job complete. Final WHPs=SSV/20 0. SV, WV, SSV=Closed. MV=Open. IA & OA=OTG. NOVP. RT ELEV = 55. 2' ~ TREE: 4-1/ 16" I 5000 PSI BF ELEV = 15. 8' VIELLHEAD: 13- 5l 8" / 5000 PSI / q W MAX. DEV. = 46: 00 MD 10300' • ~- 4 1/2" HXO SVLN SSSV 1,515' (MIN I.D. 3.813") ~'- 13-3/8" CSG SHOE 2,474' 4- 1 / 2" , 12. 6#/ FT, L- 80, BTC TBG G4S L I FT M~DREL FiES TB RCUf~D 1- 1/ 2' }fVDSS MD-BRT #2 3360' 3,415' #1 9234' 10,570' Ufl S 4-1/ 2" " X" NI PPLE ( 3. 813" I D) ~- TIW HB-BP-T PACKER OTIS 4-1/2" "X" NIPPLE ((3.813" ID) ~- TOP 7" LINER OTIS 4-1/2" "XN"NIPPLE (3.725" ID) WIRE LINE ENTRY ~'- 9-5/8", 47#/FT CSG PERFORATION SUMMARY REF LOG: CBTi GR ON 05/01/87 ANGLE AT TOP PERF: 32° @ 11590 Note: Refer to Production DB for historical perf data SQE SPF MITERVAL '" DATE 5" 5 11546 - 11594 S 3-318" 6 11590 - 11600 O 5" 5 11610 - 11634 S 3-318" 6 11625 - 11635 O 5" 5 11640 - 11694 S 3-318" 6 **11690 - 11700 O 2-118" 4 **11760 - 11770 S 3-3/$" 6 **11765 - 11795 O "GUKKCLHICU I V mYYV Vl~v+r«wr 1824' SLM FISH - MALE OC, 3.25" CENT TEL 10, 641 10,662' "~ 10,728' 10,751' 10,749' 10,762' ELM 10, 756 11,024' /07} ~' PBTD "-• 7" - 29#/FT CSG SHOE 11,885' 12,020' DATE REV BY COMMENTS DATE REV BY COMMENTS ENDKATT UNIT INITIAL COMPLETION 04/13/96 RAC ADDPERFS WELL: 1-41 /0-23 03/26186 JTP POST F2UVt0 07!19107 SPF/PJC SSSV CORRECTION PERMff No: 05!01/95 JTP SQZ 07!21!07 JCfvVPJC FISH @ 11824' SLM API No: 50-029-21713-00 05126!95 GAM FISH IN HOLE SEC T N R E 04!13/96 RAC ADD PERFS BP Expbratwn (Alaska) NOT OPERABLE: Endicott 1-4~ 23 (PTD #1870320) Confirmed Start head Leak Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ I ~, 9 jZ- Sent: Friday, December 18, 2009 6:56 PM `~ C ~ ~ ~ ~ I To: Maunder, Thomas E (DOA); Regg, James 6 (DOA); END/BAD Area Manager; END, O&M TL; END, Operations Lead Tech; END, Production Coordinator; END, Board Operator; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; McLeod, Jennifer D; Soto, Jose A; Garing, John D; Anderson, Robert L; Dahl, Norm; Grimes, Jeremy; Hernandez, Rogelio (ASRC ENERGY SERVICES); Houser, John (ASRC); Hume, Ky A; Hyland, Wilf (ASRC ENERGY SERVICES); McBride, Larry D. Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: Endicott 1-41/0-23 (PTD #1870320) Confirmed Startinghead Leak Attachments: 1-41.pdf AI I, ~` Endicott well 1-41/0-23 (PTD 1870320) has been confirmed to have a startinghead leak. Therefore, the well has been reclassified as Not Operable until repaired. Please shut-in and freeze rotect the well as soon as safely possible. The well will be added to the quarterly report for Not perable injectors until repaired. A wellbore schematic has been included for reference. «1-41.pdf» Please let us know if you have any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Caordinator GPB Wells Group Phane: (907) 659-5102 Pager: (907) 659-5100 x1154 12/21 /2009 RT ELEV = 55. 2' ! TREE: 4- 1/ 16" I 5000 PSI ~W BF ELEV = 15. 8' VIELLI-EAD: 13- 5/ 8" / 5000 PSI / q W M4X. DEV. = 46:00 MD 10300' • ~- 4 1/2" HXO SVLN SSSV 1,515' (MIN I.D. 3.813") ~- 13-3/8" CSG SHOE 2,474' 4- 1 / 2" , 12. 6#/ FT, L- 80, BTC TBG S L I FT M4NDREL S HES TB ROUND 1- 1/ 2" )1-VDSS MD-BRT #2 3360' 3,415' #1 9234' 10,570' OTI S 4- 1 / 2" " X" NI PPLE ( 3. 813" I D) ~- TIW HB-BP-T PACKER OTIS 4-1/2" "X" NIPPLE ((3.813" ID) ~- TOP 7" LINER OTIS 4-1/2" "XN" NIPPLE (3.725" ID) WIRE LINE ENTRY ~- 9-5/8", 47#/FT CSG PERFORATION SUMMARY REF LOG: CBT! GR ON 05/01/87 ANGLE AT TOP PERF: 32° @ 11590 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL *' DATE 5" 5 11546 - 11594 S 3-318" 6 11590 - 11600 O 5" 5 11610 - 11634 S 3-3/8" 6 11625 - 11635 O 5" 5 11640 - 11694 S 3-318" 6 `"11690 - 11700 O 2-118" 4 '"11760 - 11770 S 3-318" 6 **11765 - 11795 O -- C:VKKtLA 1 tlJ 1 U mvvu vn vwr~cror 1$24' SLM FISH-MALEOC, 3.25" CENT TEL {07(21/07) PBTD 11,885' 7" - 29#/FT CSG SHOE 12,020' DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT INITIAL COMPLEf10N 04/13/96 RAC ADD PERF5 WELL: 1-41 lO-23 03126(96 JTP POST RWO 07119/07 SPF/PJC SSSV CORRECTION PERMfT No: 05101/95 JTP SOZ 07/21!07 JCM/PJC FISH @ 11824' SLM API No: 50-029-21713-00 05/26/95 GAM FISH NV HOLE SEC T N R E 04/13/96 RAC ADD PERFS BP Exploration {Alaska) 10, 641 10,662' 10,728' 10,751' 10,749' 10,762' ELM 10, 756 11,024' OPERABLE: Endicott well 1-41 /0-23 (PTD # 1870320) No current evidence of a starting head le... Page 1 of 2 • • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ ~G(~E{ j~~ Sent: Sunday, November 23, 2008 3:52 PM ~~ I To: END/BAD Area Manager; END, O&M TL; END, Operations Lead Tech; END, Production Coordinator; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Holt, Ryan P (ASRC); Gering, John D; Lau, John, Jack; Soto, Jose A; Rockafellow, Joseph D; Anderson, Robert L; Hernandez, Rogelio (ASRC ENERGY SERVICES); Houser, John (ASRC); Whitney, William A; Dahl, Norm; NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: OPERABLE: Endicott well 1-41/0-23 (PTD #1870320) No current evidence of a starting head leak All, / Endicott well 1-41/0-23 {PTD 1870320) has been evaluated for a possible starting head leak. The well passed a MITOA to 500 psi with nitrogen with no evidence of an leak to atmosphere. The well has been reclassified as Operable. ff in e future the well exhibits signs of a starting head leak, it will be treated with Seal-Tits. Please let me know if you have any questions. Thank you, Anna tDu6e, ~P. E. Well Integrity Coordinator GPB Wells Group Phone: {907) 659-5102 Pager: {907) 659-5100 x1154 ~~~~ N~~? ~ ~ 200 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, November 12, 2008 10:55 AM To: END/BAD Area Manager; END, O&M TL; END, Operations Lead Tech; END, Production Coordinator; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)' Ce: Winslow, Jack L.; Garing, John D; Lau, John, Jack; Soto, Jose A; Rockafellow, Joseph D; Anderson, Robert L; Hernandez, Rogelio (ASRC ENERGY SERVICES); Houser, John (ASRC); Whitney, William A; Dahl, Norm; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: Endicott well 1-41/0-23 (PTD #1870320) POI to Evai Starting Head Leak All, END1-41/0-23 (PTD #1870320) passed an MITOA with nitrogen on 11f10/08. In addition, no leak from the starting head was observed just prior to or during the test. The previously suspected Beak was reported around the time that a Schmoo- B-Gone treatment was performed. This treatment could have heated the starting head threads above the normal operating temperature and paused some seeping. We would like to put the well back on praduction to determine if seeping does in fact occur at normal operating temperature. The wail has been reclassified as Under Evaluation and the 28-day clock will start when the well is put on injection. ~ The plan forward far the well is as follows: 1. Operator: Put well on PWl 2. D: Re-MITOA w/N2 and monitor starting head for leaks far up to 2 weeks ~ 3. WIC: Reclassify as Not Operable and secure well if leak is observed 11 /24/2008 OPERABLE: Endicott well 1-41/0-23 (PTD #1870320) No current evidence of a starting head le... Page 2 of 2 • • Please Gail with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, October 29, 2008 10:34 AM To: END/BAD Area Manager; END, O&M TL; END, Operations Lead Tech; END, Production Coordinator; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)' Cc: Townsend, S. Eliot; Garing, John D; Lau, John, Jack; Soto, Jose A; Rockafellow, Joseph D; Anderson, Robert L; Hernandez, Rogelio (ASRC ENERGY SERVICES); Houser, John (ASRC); Whitney, William A; NSU, ADW Well Integrity Engineer; Dahl, Norm Subject: NOT OPERABLE: Endicott well 1-41/0-23 (PTD #1870320) Not Operable due to Starting Head Leak Hi all, Endicott well 1-41/0-23 (PTD #1870320) is a water injector found to have a very small starting head leak. Per BP's Well Integrity Management System, wells with leaks to atmosphere are not allowed for continued operations. The well has been classified as Not Operable. Please shut-in and freeze protect the well as soon as safely possible. Actions to evaluate the small starting head leak for repair will continue. A wellbore schematic and TIO plot have been included for reference. ~ Please let us know if you have any questions. Thank you, Anna 1~u6e, ~? 2. Well Integri#y Coordinator GPB Wells Group Phone; {907) 659-5102 Pager: {907) 659-5100 x1154 11 /24/2008 M i N ~ ~ ~F c ~~ i ~1' d o °o °a 0 0 0 Cri V/ a~ a °o °o a o N r RT ELEV = 55. BF ELEV = 15. M4X. DEV. = 46:00 MD 10300' u TREE: 4-11 16" / 5000 q W VIELLHEAD: 13- 5/ 8" / 5000 / q W ~- 4 1/2" HXO SVLN SSSV (MIN I.D. 3.813") ~- 13-3/8" CSG SHOE 4- 1 / 2" , 12. 6#/ FT, L- 80, BTC TBG G4S LI FT M41~DRELS HES TB RGUND 1- 1 / 2" )fVDSS MD-BRT #2 3360' 3,415' #1 9234' 10,570' OTI S 4- 1 / 2" " X" NI PPLE ( 3. 813" I D) ~-- TIW HB-BP-T PACKER OTIS 4-1/2" "X" NIPPLE ((3.813" ID) ~ TOP 7" LINER 1,515' 2,474' 10, 641 10, 662' 10,728' 10, 751' 10,749' OTIS 4-1/2" "XN" NIPPLE (3.725" ID) WIRE LINE ENTRY 10,762' ELM 10, 756 11,024' ~- 9-5/8", 47#/FT CSG PERFORATION SUMMARY REF LOG: CBT( GR ON 05/01187 ANGLE AT TOP PERF: 32° @ 11590 Note: Refer ko Production DB for historical perf data SIZE SPF INTERVAL DATE 5" 5 11546 - 11594 S 3-318" 6 11590 - 11600 O 5" 5 11610 - 11634 S 3-318" 6 11625 - 11635 O 5" 5 11640 - 11694 S 3-3/8" 6 `"11690- 11700 O 2-118" 4 `'11760 - 11770 S 3-318" 6 "11765 - 11795 O "` t:VKKtLA 1 tU 1 V M WU VN U4l"LLJtfI 1824' SLM FISH-MALEOC, 3.25" CENT TEL ("07121;07) PBTD 11, 885' ~ 7" - 29#/FT CSG SHOE 12,020' MEMORANDUM . To: Jim Regg ~'"7 ~~/ P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commi~ DATE: Wednesday, July 30, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 1-41/023 DUCK IS UNIT MPI 1-41/023 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~,~" Comm Well Name: DUCK IS UNIT MPI 1-41/023 Insp Num: mitLG080728160329 Rel Insp Num: API Well Number: 50-029-2 1 7 1 3-00-00 Permit Number: 187-032-0 Inspector Name: ~u Grimaldi Inspection Date: 7/27/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Ial/o23 Type Inj. w TVD 9355 IA ago z76o J z7zo z72o p.T. Ia7o3zo TypeTest SPT Test psi 2338.75 ' QA 40 190 Igo Igo Interval 4YRTST p~F P Tubing 2350 2375 2375 2375 Notes: Observed pretest conditions for thirty minutes to satisfy 500 psi minimum Differential Tubing->IA, "OK". ~~ANNf~ SEP :~ ~? 2000 Wednesday, July 30, 2008 Page 1 of 1 07/27/07 ScblumbllPD8P ~, ' "-," I'VE,"~,' '~"," ; , '" I } ' -.-" RECE u¡:<£: 1(5"1~6~- JUL 3 0 zom NO. 4346 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Alaska on & Gas Cons. CommissiQn Anchorage SCI>.Nt-ISP þ..UG Q 1 2001 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Well Job og escrlptlon ate BL Color 3-25/L-27 11686762 STATIC PRESSURE SURVEY 07/09/07 1 4-18/S-30 11813062 STATIC PRESSURE SURVEY 07/10/07 1 2-50/U-08 11676953 LDL 07/13/07 1 1-61/Q-20 11695066 SBHP SURVEY 07/13/07 1 3-41/K-39 11846795 WFL & PRESS GRADIENT 07/17/07 1 1-41/0-23 11695068 INJECTION PROFILE 07/24/07 1 3-41/K-39 11846795 IPROF & JEWELRY 07/16/07 1 L 1-09 11626109 LDL 06/27/07 1 02-30B 11626108 LDL 06/25/07 1 H-07A 11637346 LDL 06/30/07 1 12-05A 11638649 FPIT 07/04/07 1 12-12A 11661162 MEM STATIC TEMP/JEWELRY 07/05/07 1 P2-08 11686761 STATIC PRESSURE SURVEY 07/05/07 1 17-02 11745227 MEM GLS 07/10/07 1 09-11 11686765 STATIC PRESSURE SURVEY 07/11/07 1 X-19B 11801075 LDL 06/19/07 1 MPK-30 11676952 FPIT 07/12/07 1 11-08 11813061 STATIC PRESSURE SURVEY 07/07/07 1 03-14A 11849926 BHP SURVEY 07/25/07 1 01-16 11630486 PROD PROFILE 06/28/07 1 MPH-17 11813063 CBL & IMAGE LOG 07/21/07 1 01-15A 11849924 USIT 07/20/07 1 02-30B 11813058 USIT 07/04/07 1 MPJ-24 11638647 USIT 06/29/07 1 E-101 11630488 PRODUCTION PROFILE 06/30/07 1 G-18A 11209612 MCNL 07/19/06 1 1 # L D D CD . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: d(¡) It (~\~'~j (";": ::"-::1 .¡'-:;::;:J .1" :\~I! ¡ /\ \111 L "\ '\ :1: / :1: \ ·1'1 1:-:1 .,..,,\ 1 ' ! :. .~. ì ·:!I ~¿J LJ !~/ ~j ,j L.= lm~ /""0:: r" .\: (\~ i !J,~ Lf'.~ ,:;j) !" /t~\ /.þ! '\ l.J '.:-; FRANK H. MURKOWSKI, GOVERNOR AIIASKA.OILAND GAS CONSERVAnONCO~SSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 ,FAX (907) 276-7542 John McMullen Senior Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 .~(~l.àíMNt:[. In p 2· Ð. 20U5 ';¡JI\;¡oJ~~1: c ¡¡... ... L L Re: Endicott 1-41/0-23 Sundry Number: 305-202 :r ~ ~O'~ ~,. , Dear Mr. McMullen: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision tou rior Court unless rehearing has been requested~ Si'~ ' J n . No hair DATED this2day of July, 2005 Encl. ( if ò BP Exploration (Alaska) Inc. Post Office Box 196612 900 East Benson Blvd Anchorage, Alaska 99519-6612 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 RECEIVED JUL 2 1 2005 Alaska Oil & Gas Cons. Commissi Anchorage July 20, 2005 Subject: Endicott Well 1-41/0-23 Application for Sundry Approval ~/ Dear Winton: Attached is Application for Sundry Approval form 10-403 for Endicott water injection well 1-41 /0-23. BP proposes additional perforations in the K2A sand of this water /' injector to improve waterflood support in this area of the reservoir. The scope of work is as follows: · Perform tubing wash to clean-up produced water deposits. · Pull SSSV. · Add perfs in the K2A sand: 11800' - 11835' MD (ref 5/1/87 CBl). r · Re-install and test SSSV. ,,/' · Return well to water injection service. If you require any additional information or clarification, please contact me at 564-4711. Sincerely, P c IJ! l{Þ // / John McMullen, P.E. ii/ II Sr. Petroleum Engineer V Endicott lr'~ ~~( i (':; Î N' , A L )li\l~ ,j~' 1. Type of Request: Abandon D D D Alter Casing Change Approved Program 2. Operator Name: 3. Address: r.Jir 1" z,-) ~ D 5 V-I. G A 7 / '2 S I ù"o ç Suspend D D D Operation Shutdown Plug Perforations Perforate New Pool D D D t ALAS~ OIL AND ~~;~g~S~~;A~ON CO~MISSION RECEIVED APPLICATION FOR SUNDRY APPROVAL JUL 21 2005 20 AAC 25.280 Alaska Oil R, r,as Cons C . ,/ . on1flltsslon Perforate [X] waAQ~rBge OtherD StimulateD Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 187-0320 / Repair Well Pull Tubing 4. Current Well Class: BP Exploration (Alaska), Inc. Development D Exploratory D 7. KB Elevation (ft): P.O. Box 196612 Anchorage, Ak 99519-6612 56.00 KB 8. Property Designation: ADL-312828 11. Presen1 Total Depth MD (ft): 12178 Casing Stratigraphic D Service Œ] 9. Well Name and Number: 1-41/0-23 ,,/ 10. Field/Pool(s): Endicott Field / Endicott Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11885 10267.9 Size MD TVD Total Depth TVD (ft): 10581.8 Length / 6. API Number / 50-029-21713-00-00 Plugs (md): None Burst Junk (md): None Collapse CONDUCTOR SURFACE PRODUCTION PRODUCTION LINER top bottom top bottom 92 30" Conductor 39 131 39.0 131.0 2436 13-3/8" 68# L-80 38 2474 38.0 2474.0 5020 2270 9154 9-5/8" 47# NT80S 37 9191 37.0 8286.1 6870 4760 1833 9-5/8" 47# NT95HS 9191 11024 8286.1 9619.0 8150 5080 1269 7" 29# SM-11 0 10751 12020 9418.7 10442.7 11220 8510 Description Summary of Proposal Œ] Detailed Operations Proqram D BOP Sketch D 14. Estimated Date for Commencing Operation: Perforation Depth MD (ft): 11590 - 11600 11610-11635 11690 - 11700 11765 - 11795 / Packers and SSSV Type: 4-112" TIW HBBP-T Packer 4-112" HES HXO SSV 12. Attachments: Perforation Depth TVD (ft): 10067 - 10076 10084 -10106 10153 - 1 0162 10218 -10245 Tubing Size: 4-1/2 " 12.6 # Packers and SSSV MD (ft): 13. Well Class after proposed work: Tubing Grade: Tubing MD (ft): L-80 35 10762 r 10662 1515 Service ŒJ / August 4, 2005 Exploratory D DevelopmentD 15. Well Status after proposed work: Oil D GasD Date: WAGD GINJD 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ~, ' ' lC~7A' . Signature ylr \ I '/1 jY l.A- Contact Title Phone Plugged D Abandoned D WINJ ŒJ / WDSPLD Prepared by DeWayne R. Schnorr 564-5174. John McMullen Sr Production Engineer 564-4711 7/21/05 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Form 10-403 Revised 11/2004 Sundry Number: 3or- ~ 0.;1... BOP TestO Mechanciallntegrity Test D RBDM8iBf€l~~J@1tc~Œ] 2005 RBDMS BFL JUL 2 8 2005 ~ Ç/ BY ORDER OF ~ THE COMMISSION Date: t~\~AL \0 -- 4'04. SUBMIT IN DUPLICATE ~,i \ RT ELEV = 55. 2' a= ELEV = 15. 8' 1'vroC. œv. = 46: 00 MD 10300' . A ~ .. (' TREE: 4-1/16" / 5000 PSI I a w V\ELLHEAD: 13- 5/8" / 5000 PSI / CI W / ~ 4 1/2" HXO SVLN SSSV (MIN 1.0. 3.813") .... ~ WITH SSSV MIN 1.0. 2.0" ... --......-- 13-3/8" CSG SHOE 11,515' I 12,474' I ( 4-1/2", 12.6#1 FT, L- 80, BTC TOO 8M3 LI FT fVW\JDRR S (HFS TB FU.JND 1- 1/2" ¡rVDSS MD-BRT #2 3360' 3,415' #1 9234' 10,570' z ~ on S 4-1/2" " 'X' NI PPLE (3.813" I D) Z.....-- TIW HB-BP-T PACKER 11 0, 6411 110,662' I ] ..... OTIS 4-1/2" "x" NIPPLE ((3.813" 10) ....-- TOP 7" LINER ... OTIS 4-1/2" "XN" NIPPLE (3.725" 10) I \.... WIRE LINE ENTRY A .. ~ 9-5/8", 47#/FT CSG COMMENTS SOl SEE "FI SH I N HCl.E" DATE REV. BY 5/1/95 JTP 5/26/95 ~M 3/2196 JTP 4/13/ 96 RAC POST RWO ADD PERFS 110,728' I 110,751' I 110,749' I 10,762' EUv 10, 756 11 ,024' / PERFORA TIONS: REF: CBT-GR (5/01/87) SOS 5" 5SPF 11,564' TO 11,594' SOZ 11,610' TO 11,634' -ser- öPE AI 11,640' TO 11,694' SOZ AWS 2-1/8" 4 SP 11,760' TO 11,770' SOZ AW3 3- 3/ 8 6 SPF 11, 765' TO 11, 795' œEN :: AW3 3 3/8 6 SPF 11590' TO 11600' œEN :: AW3 3 3/8 6 SPF 11625' TO 11635' œEN :: AW3 3 3/8 6 SPF 11690' TO 11700' œEN I :f¡ C~LATED TO MIlD LOOS DATED 22 APR L 87 ~ ..... 111,885' I 112,020' I / PBTD 7" - 29#/FT CSG SHOE .. BP EXPLœATI (J\J, I NC COI\IPLETION DI AGRAM ENDI CaTT V\ELL 1- 41 I (). 23 API NQ 50- 029- 21713 MEMORl\NDUM State of Alaska Alaska Oil and Gas Consen'ation Commission TO: Jim Regg P.I. Supenisor ~ I \'--(/f¡ 1/ 7<iktJ DA TE: \\'edne:;day. July 28. ~OO-t SliBJECT: t\1echanicallntegTlt) Tests BP EXPLORA TlON IALA51,...AI fNC FROI\t: Jeff Jones Petroleum Inspector 1-11'O~3 DUCK IS UNIT MPI I-.H 'Œ3 Src: Inspector Re\'iewed By: ~--,......I' P.I. Supn ..j D ~ Comm NON-CONFIDENTIAL Well Name: DUCK IS UNIT MPI 1-411023 Insp Num: m1lJJ04072810ù244 Rellnsp Num: API \Vell Number: 50-029-21713-00-00 Permit Number: I 87-032-fJ Inspector Name: JeffJone:; Inspection Date: 7/27/200-t Packer Depth Pretest Initial ]5 Min. 30 Min. ..&5 Min. 60 Min. 1-41'023 Type Inj. 5 I IA 2660 Well TVD 10583 380 270(1 2660 P.T. 1870320 TypeTest I 5PT Test psi 2338.75 OA 200 200 200 200 Interval "¡YRTST P/F P Tu bing 2250 2300 2300 2300 Notes: 8.2 BBLS 50/50 methanol pumped. Wednesday, July 28. 200-t Page I of I MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MA TERIAL UNDER THIS PAGE STATE OF/~LA,.~KA ALAS~-'~.OIL AND GAS CONSERVATION COMMISS~ REPORT C. SUNDRY WELL OPL JATIONS 1. Operations performed: Operation shutdown Stimulate Plugging__ Pull tubing__ Alter casing .__ Repair well __ Perforate Other X 2. Name of Operator BP Exl~loration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora_cle, Alaska 99519-6612 4. Location of well at surface 2121' SNL, 2153' WEL, Sec. 36, T12N, R16E At top of productive interval 4460' SNL, 3616' WEL, Sec. 31, T12N, R17E At effective depth 4567' SNL, 3528' WEL, Sec. 31, T12N, R17E At total depth 4648'SNL, 3421' WEL, Sec. 31, T12N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE - 55 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-41/0-23 MPI 9. Permit number/approval number 87-32/(see attached letter) 10. APl number 50- 029-21713 11. Field/Pool ' Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12180 feet 10583 BKB feet Plugs (measured) 11932 feet Junk (measured) 10366 BKB feet 12021 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 131' 2435' 13 3/8" 3440 c.f. Permafrost 2474' 2473' 10985' 9 5/8" 575 c.f. Class G 11024' 9618' 1269' 7" 446c. f. Class G 10751'- 12020' 9418'- 10442' measured 11564'- 11594', 11610'- 11634', 11640'- 11694', 11760'- 11770'(AIIsqueezed) 11590'-11600', 11625'-11635', 11690'-11700'; 11765'-11795' (open) true vertical (Subsea) 9989'- 10015', 10028'- 10049', 10054'- 10100, 10158'- 10167'(AII squeezed) 10011'-10015', 11041'-10050', 10097'-10106'; 10163'-10189' (open) Tubing (size, grade, and measured depth) 4 1/2" 12.6 #, L-80 to 10762' Packers and SSSV (type and measured depth) HES 4-1/2" HXO SVLN 12.6# CR at 1515'; 9-5/8" TIW HB-BP-T Packer at 10662' 13. Stimulation or cement squeeze summary Intervals treated (measured) 14. ORI61NAL RECEIVED /.PR 19 2000 Treatment description including volumes used and final pressure ~Jaska 0il & Gas Cons. Commissior~ Representative Daily Average Production or Injection Data All~0rage Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15743 0 6123 15772 0 6153 15. Attachments MIT Report 3/21/00 Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil Gas__ Suspended 17. I hereby certify that the foregoing is truce and correct to the best of my knowledge. Signed '~%(~J,,.~i/~ I~,i'L-~'~(~¢--~(~/ Titlesenior TechnicalAssistantlV Form 10-404 Rev 06/1(;~8 Service W~ter !_niector Date 04/19/00 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department MIT with AOGCC Witness DATE: 3-21-00 WELL N-°: 1-41/O-23 BP EXPLORATION REP: Sauve SERVICE COMPANY: HB&R DATE/TIME OPERATIONS SUMMARY WHP= 2200 IA = 800 OA = 0 0900 MIRU TO IA PT HARDLINE TO 3000 PSI. START PUMPING 60/40 MEOH 4 BBLS AWAY. lAP= 2700 PSI. START TEST. GAUGE IS BUILDING PRESSURE. MOVE ON TO ROW FIVE. CHANGE OUT GAUGE ON ANNULUS. TEST IS GOOD. RDMO. WHP=2250 IA=1000 OA=0 Summary: MIT with the state AOGCC witness (Lou Grimaldi) Pump Summary: BBLSI FLUID 4 60/40 meth. RECEIVED /,PR 1 9 2000 A~aska 0il & Gas Co~s. Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 5, 1996 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. B. Wondzell Dear Mr. Wondzell Attached, please find three Reportsof Sundry Well Operations for Endicott Wells 1-41/O-23, 2-70/U-15 and 1-51N-20 (in duplicate). These three wells are water injection wells that have had perforations added, without prior approval. We apologize for this mishap, due to a change in personnel within the Endicott group. Please feel free to contact myself at 564-5734 if you require further information. S i.~ce,re ly,~.~. //,4, ~ndicott Development attachments (3) JAM cc: File 06.10 STATE OF ALASKA ALASI<~ OIL AND GAS CONSERVATION COMMISSIO~',~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate ~ Plugging__ Pull tubing __ Alter casing __ Repair well ~ Perforate X Other ~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2121'SNL, 2153' WEL, Sec. 36, T12N, R16E At top of productive interval 4460' SNL, 3616' WEL, Sec. 31, T12N, R17E At effective depth 4567' SNL, 3528' WEL, Sec. 31, T12N, R17E At total depth 4648' SNL, 3421' WEL, Sec. 31, T12N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service ORIGINAL 6. Datum elevation (DF or KB) KBE- 55 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-41/0-23 MPI 9. Permit number/approval number 87-32/(see attached letter) 10. APl number 50- 029-21713 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 12180 feet Plugs (measured) 10583 BKB feet 11932 feet Junk (measured) 10366 BKB feet 12021 Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 131' 2435' 13 3/8" 3440 c.f. Permafrost 2474' 2473' 10985' 9 5/8" 575 c.f. Class G 11024' 9618' 1269' 7" 446c. f. Class G 10751'- 12020' 9418'- 10442' measured 11564'- 11594', 11610'- 11634', 11640'- 11694', 11760'- 11770' (AII squeezed) 11590'-11600', 11625'-11635', 11690'-11700'; 11765'-11795' (open) true vertical (Subsea) 9989'- 10015', 10028'- 10049', 10054'- 10100, 10158'- 10167'(AII squeezed) 10011'- 10015', 11041'-10050', 10097'-10106'; 10163'- 10189' (open) Tubing (size, grade, and measured depth) 4 1/2" 12.6 #, L-80 to 10762' Packers and SSSV (type and measured depth) HES 4-1/2" HXO SVLN 12.6# CR at 1515'; 9-5/8" Tl~,.,.-.~:~__ p~K~ker azN10662' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1O982 0 11000 0 Tubing Pressure 2109 2007 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X ~ Oil~ Gas Suspended 17. I hereby certify th~at the/~J/~.,egoing is~ru~and correct to the best of my knowledge. Slgned~._:L~;:b(',j'jC,~' ~ Title Senior Technlc., Assistant IV Form 10-~4' Rev 06/15/88 Service water In!ector Date 9/5/96r~ SUBMIT IN DUPLICATE Endicott Production Engineering Department ADD-PERF DATE: 4~4~96 WELL N-°: 1-41/O-23 BP EXPLORATION REP: SERVICE COMPANY: R. Clump AWS (D. CAIN, B. ESARY) DATE/TIME OPERATIONS SUMMARY 0800 MIRU ATLAS IWHP= 2150 lAP= 1350 OAP--0 0930 HOLD TGSM, SHUT-IN WELL. 1015 RIH w/ GR/CCL/GUN # 1 (Select fire - 28' from CCL to Bull Plug). Length btw MP to top shots is 2'& 15'. 1100 Log tie-in strip from 11775' to 11645' (+4'). Tied in to MWD dated 22-April-87. Log confirmation pass. (+4') Add 1', take out 1'. Log into CCL position 11775' MWD depth. 1210 Shoot Gun F1 11690'to 11700'. Log into position @ 11623'. Need to-l'. Drop back down to 11741'. Log into position @ 11623' into CCL position. Shoot gun F2 from 11625-11635' MWD depth. No indications. Lo[~ off. Fla[t line @ 11577. 1 345 OOH. F2 did not fire. Load up select fire gun. Bad Cap. 1435 Rih w/Gun #2 (select fire). 1525 Cut flag. Log tie-in strip from 11790' to 11610' (on depth). Shoot F1 11625'-11635' MWD depth. Log into position @ 11588' CCL depth. Shoot F2 11590'-11600' MWD depth. Log off. Pooh. 1630 OOH. Confirm all shots fired. RDMO ATLAS. Put well back on injection. PERFORATION SUMMARY: GUN SUBZONE MWD DEPTH CBLDEPTH INTERVAL lA 2B 11690' - 11700' 11686' - 11696' 10 2A 2B 11625'- 11635' 11621'- 11631' 10 2B 2B 11590' - 11600' 11586' - 11596' 10 ALL PERFORATIONS WERE SHOT USING 3 3/8" ALPHA JETS, 21.0 gm, 6 SPF, 60° PHASING & RANDOM ORIENTATION. EH= 0.48" & TTP= 22.8". ALL DEPTHS WERE CORRELATED TO MWD LOG DATED 22-APR-87. i Endicott Production Engineering Department ,, RE- PERF DATE: 3-19-96 WELL Ne: 1-41/O-23 BP EXPLORATION REP: SERVICE COMPANY: VARBLE AWS (ESARY) I ,D,ATE/TIME, , OPERATIONS SUMMARY ' ' ' 3'~/19 1730 MIR0 ATLAS " SIP=0 lAP--0 OAP=0 ' 1 900 HOLD ~GSM ' ' , 1930 RIH WITH GR/CCL/GUN # 1 (10') 2045 LOG JEWELRY FROM 1'0900 MD' TO 10500' MD 2105 RIH & TAG TD @ 11878' MD ......... ' ' '2115 LOG TIE IN PASS FROM 11880' MD TO 11650'MD. TAKE OUT 1' ..... 2135 LOG INTO PLACE. ON DEPTH. HANGCCL @ 11783' (2' FROM TOP SHoT) & SHOOT GUN #1 FORM 11785 MD- 11795' MD. DID NOT SEE CAP BREAK OR WEIGHT CHANGE. LOG OFF. '2150 POOH ..... 1035 OOH 1041 GUN DID NOT FIRE. EBW PACKAGE BAD. RE- ARM GUN " 111 5 'RIH WITH SAME TOOL STRING. ' ...... :~/20 001 5 ON BTM. LOG TIE PASS FROM 11880' MD TO 11650' MD. ADD 1' ' .... 0030 LOG INTO PLACE, CCL @ 11783. ON DEPTH. SHOOT GUN FROM 11785' MD - 11795' MD. NO CAP BREAK, LOST ABOUT 30 LBS. WEIGHT. LOG OFF ,, , ,, ,, 0O45 POOH 0130 OOH. ALL SHOTS FIRED. PUT WELL ON INJECTION. 0230 RiG'DOWN EQUIPMENT FOR NIGHT. " ' ' , , , , ,,, , , , ,, , ,, 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 2. Name of Operator 5. Type of well: 6. BP Exploration (Alaska) Inc. [] Development [] Exploratory 7. 3. Address [] Stratigraphic P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Datum Elevation (DF or KB) KBE = 55' Unit or Property Name Duck Island Unit/Endicott Well Number 1-41/O-23 2121' SNL, 2152' WEL, Sec. 36, T12N, R16E At top of productive interval 4460' SNL, 3616' WEL, Sec. 31, T12N, R17E At effective depth 4567' SNL, 3528' WEL, Sec. 31, T12N, R17E At total depth 4648' SNI_, 3421' WEL, Sec. 31, T12N, R17E 9. Permit Number / Approval No. 87-32 96-033, 96-034 10. APl Number : 50-029-21713 11. Field and Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured 12180 feet true vertical 10583 BKB feet Effective depth: measured 11932 feet true vertical 10366 BKB feet Casing Length Structural Conductor 92' Surface 2435' Intermediate 10985' Production Liner 1269' Plugs (measured) Junk (measured) Size Cemented MD TVD 30" Driven 131' 131' 13-3/8" 3440 c.f. Permafrost 2474' 2473' 9-5/8" 575 c.f. Class 'G' 11024' 9618' 7" 446 c.f. Class 'G' 10751'-12020' 9418'-10442' Perforation depth: measured true vertical 11564'-11294', 11610'-11634', 11640'-11694', 11760'-11770' (All squeezed) (Subsea) 9989'-10015', 10028'-10049', 10054'-10100', 10158'-10167' (All squeezed) Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 10762' Packers and SSSV (type and measured depth) HES 4-1/2" HXO SVLN 12.6# CR at 1515'; 9-5/8" TIW HB-BP-T Packer at 10662' 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 RECEIVED AUG 1 6 19,,96 Prior to well operation: Subsequent to operation: 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 Water. Injection !17. I hereby certify that the~~s try~to the best of my knowledge Signed SteveShultz Title Senior Drilling Engineer - ~g Prepared By Name/Number: Date ~//~'//~ o Kathy Carr~poan~or, 564-5122 Form 10-404 Rev. 06/15/88 Submit In Duplicat~ Well: 1-410-23 RWO Rig: Doyon 15 AFE: 176260 Days (from morning cost reports): 8 Cum Cost: 530,958.00 Planned Cost: 657,000.00 Feb 22 1996 (1) Held safety meeting. Rig moved 100 %. Fill pits with Brine. Rigged up Lubricator. Removed Hanger plug. Rigged down Lubricator. Rigged up High pressure lines. Circulated at 10505 ft. Feb 23 1996 (2) Held safety meeting. Circulated at 10669 ft. Installed Hanger plug. Rigged down Surface tree. Rigged up BOP stack. Tested BOP stack. Held safety meeting. Removed Hanger plug. Removed Tubing hanger. Circulated at 10669 ft. Laid down Tubing of 60 ft. Set packer at 42 ft with 0 psi. Tested BOP stack. Removed Seal assembly. Installed Seal assembly. Tested Seal assembly. Feb 24 1996 (3) Held safety meeting. Tested Seal assembly. Installed Wellhead integral components. Packer worked at 42 ft. Laid down Tubing of 10659 ft. Rigged down Tubing handling equipment. Held safety meeting. Installed Wear bushing. Made up BHA no. 1 . R.I.H. to 3500 ft. Serviced Block line. R.I.H. to 10669 ft. Fished at 10669 ft. Feb 25 1996 (4) Held safety meeting. Pulled out of hole to 736 ft. Pulled BHA. Laid down fish. Made up BHA no. 2 . Serviced Iron roughneck. R.I.H. to 10684 ft. Milled Permanent packer at 10684 ft. Held safety meeting. Circulated at 10748 ft. Pulled out of hole to 1086 ft. Pulled BHA. Laid down fish. Made up BHA no. 3 . Feb 26 1996 (5) I Held safety meeting. R.I.H. to 5000 ft. Serviced Block line. R.I.H. to 11654 ft. Washed to 11885 ft. Circulated at 11885 ft. Pulled out of hole to 1030 ft. Pulled BHA. Held safety meeting. Ran Drillpipe in stands to 5 ft. Circulated at 11885 ft. Injectivity test - 5 bbl injected at 650 psi. Tested High pressure lines. Mixed and pumped slurry - 26 bbl. Displaced slurry - 181 bbl. Pulled Drillpipe in stands to 10528 ft. Circulated at 10528 ft. Held 1100 psi pressure on 5 bbl squeezed cement. Circulated at 10528 ft. Pulled Drillpipe in stands to 9500 ft. Feb 27 1996 (6) Held safety meeting. Pulled Drillpipe in stands to 0 ft. Repaired Iron roughneck. Serviced Top drive. Pulled Drillpipe in stands to 0 ft. Made up BHA no. 4 R.I.H. to 10750 ft. Tested Casing. Held safety meeting. Serviced Lines / Cables. R.I.H. to 11280 ft. Drilled cement to 11885 ft. Circulated at 11885 ft. Tested Casing. Circulated at 11885 ft. Feb 28 1996 (7) Held safety meeting. Circulated at 11885 ft. Pulled out of hole to 4285 ft. Laid down 2090 ft of 5 in OD drill pipe. Laid down 930 ft of 3.5 in OD drill pipe. Pulled BHA. Removed Wear bushing. Rigged up Completion string handling equipment. Ran Tubing to 5600 ft (4.5 in OD). Held safety meeting. Ran Tubing to 9243 ft (4.5 in OD). Rig waited : Equipment. Feb 29 1996 (8) Rig waited : Equipment. Held safety meeting. Rigged up sub- surface equipment - SCSSSV. Tested Dual control line. Ran Tubing to 10761 ft (4.5 in OD). Installed Tubing hanger. Rigged up sub-surface equipment - SCSSSV control line. Circulated at 10761 ft. Installed Hanger plug. Rigged down All functions. Held safety meeting. Installed Adapter spool. Rigged up Surface tree. Tested All tree valves. Removed Hanger plug. Set packer at 10661 ft with 3500 psi. Tested Tubing. Tested Permanent packer. Freeze protect well - 35 bbl of Diesel. Installed Hanger plug. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 12 April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 41/O-23 (MPI) ~-" 7~-26/O-34 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 HYDROLOG FINAL BL+RF ECC No. Run # 1 6004.08 Run # 1 6355.06 Run # 1 Run # 1 Run # 1 6607.01 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 D at e: Please s i~n and ~e~-1~ 'iii;; Petrotechnieal Data Oen~ BP E×ploration (Alaska) ~$ 900 hast Benson B~leva~ Anchorage, Ala~k~ 99908 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP 1-41/O-23 (MPI) ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Date: RE: 26 March 1996 Transmittal of Data ECC #: 6004.07 Sent by: HAND CARRY Data: PFC/PERF Prints/Films: 1 GR/CCL FINAL BL+RF Run # 1 1 PFC/PERF FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 ~CEIVED Anchorage, AK 99518 to (907) 583-7803 ARR 09 ]99S Received by: An~o~ge MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh. j:l~w~, DATE: Chairman THRU: FILE NO: Blair Wondzell, P. I. Supervisor FROM' Bobby F os te r,~~~'- S U BJ ECT: Petroleum Inspector February 23, 1996 AKNIBWDD.doc BOPE Test - Doyen 15 BPX- DIU - 1-41/O-23 Endicott Field ~:~ - oo ~ z.. Thursday, February 22, 1996: I received a call at 3:00PM from James Carlile, BPX drilling rep., on Doyen 15 working over DIU MP! 1-41/O-23 requesting permission to only test the BOPE to 3,000 psig due to either the tu~.,~anger leaking or the TVVCV leaking. I told James that i would not give a ~ on the required test pressure. He agreed and said he would hang the tubing off on a "storm packer" and he would be ready to test in approximately 3 hours. ! traveled to the location and arrived at 5:30PM where i stoodby for the test to start. Friday, February 23, 1996: The test began after removeing the tubing hanger and hanging the tubing off. As the attached AOGCC BOPE Test Report shows the were 3 non-compliance items - a flange on the choke line leaked - this was tightened and retested. There was not a safety chain on the upstream side of choke line hose. The upper and lower control valves for the pipe rams were out of adjustment on the accumulator unit - they leaked when they were operated from the floor control station, i gave the rig 24 hours to correct these problems. The rig was clean and all equipment seemed to be in good working order. The location was clean and there was access to all areas of the rig. Summaw: ! witnessed the BOPE test on Doyen rig 15 working over BPX's DIU - MPi 1-41/O-23 - test time 3.5 hours - 3 noncompliance items. NOTE: i was notified by Allen Sinclair, Doyen toolpusher, that the valves on the accumulator had'~djusted and worked properly and that the safety chains had been installed on the choke line. Attachment: AKNIBWDD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg:,j . Workover: . . X Drig Contractor: .... DOYON , .. Rig No....15 . PTD # Operator: BP, X , Rep.: Well Name: 1-4 fl 0.23 Rig Rep,: Casing Size: 'g~625"X'7" .' ' set {~ .......... f'~,g32,..~ *' Location: Sec. Test: lanai 'x Weekly Other 87.0032 ,, 36 T. DATE: 2/23~6 R~g Ph.# e59-e5 ~o / ~ ~ JAMES CAR'L'IL'E ....... ALLEN SlNC'I. AIR ................. ./2N R. "16E I~eridian'' ' Urn, MISC. INSPECTIONS: Location Gen.: OK Housekeeping: '/_0K (Gen) PTD On Location ~ Standing Order Post~' _. yES. Well Sign OK Drl. Rig "0K"' Hazard Sec. YES' BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Test Press. P/F t, i ,~oo/~,°o° !, ,, ' "./ .... !',~0~,oooi i '~ ! ~,oo0.. ! ..... '~ ! ~,,~1 ' '2'1 5~5~1 ' ._ ,," ..... [ ,, Quan. Pressure P/F I I 500/5,000 ! P .... ./-' "~oo/5,oo~' ' P" ....I' MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YEs Flow Indicator ~ YEs' 'YES' Meth Gas Detector 'YES- YES H2S Gas Detector YES' .YEs' Test CHOKE MANIFOLD: Pressure P/F No. Valves 'i'/7' !, l~tS, 000 i PP No. Flanges 500/5, 000 . ' : Manual Chokes Fun~ne'd " P Hydraulic Chokes . Functioned ]i P' ACCUMULATOR SYSTEM: System Pressure 3,000 ! . P _ Pressure After Closure ./,350 J P 200 psi Attained After Closure 0 .... minutes 3f' .... sec. System Pressure Attained .... 3. 'i_ minutes , ~5,, ..'" sec. Blind Switch Covers: Master: YES Remote: ,.YES Nitgn. Btl's: ,4 @ 2500 ..... Psig. Number of Failures: 3 ,Test Time: 3.5 Hours. Number of valves tested 23. Repair or Replacement of Failed Equipment will be made within' ' , , ./ ............ days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 .... I~ ri I I III. I _1 I III I I III IIIII I I . I IIIII I ~ I I j. IIl.II II , IIII IIII I1 REMARKS: FAILURES: A flan~e., I.~aked on the choke Ii.n?. -., ti~lht .~, . and tested OK No safe~ chains.on ,choke hose. The man'ual contr~ va'~es on the u~. r and iowe~ pi~e ~am's "leaked :out ~f adj. ustmen't, ........ ,,~ . ,,~ ,, ,,,~,,, , ,~ , ,,, , ~,~k~,~ ,~,,~ ............ ~' "- ' "- ' ' ' ~' ' ,' -"""' ~ safety cha,'ns .On, choke hose - These 2 items are to be corrected and the inspector noUfled . ,ti ., , i i~ i i i ~ , ,,. , ,,., i , i i t, , J f , , within 24 hours. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector , , sTA'I;E WITNESS RE~UIRED~.'~" YES X NO Waived By: VV'Rnessed By: 24 HOUR NOTICE GIVEN YES X NO ,i , ,,~ ,, ij, ,, ,, , ,~ : : ' ,, ,1 , i L BOBBY O. FOSTER FI-021L (Rev. 12/94) AKNIBWDD.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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 __ 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 X 4. Location of well at surface 2121' SNL, 2153' WEL, Sec. 36, T12N, R16E At top of productive interval 4460' SNL, 3616' WEL, Sec. 31, T12N, R17E At effective depth 4567' SNL, 3528' WEL, Sec. 31, T12N, R17E At total depth 4648' SNL, 3421' WEL, Sec. 31, T12N, R17E ORIGINAL 6. Datum elevation (DF or KB) KBE- 55 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-41/0-23 MPI 9. Permit number 87-32 10. APl number 50- 029-21713 11. Field/Pool Endicott Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12180 feet 10583 BKB feet Plugs (measured) 11932 feet Junk (measured) 2 DC's, 2 stabs, 3 x/o's and I mill 10366 BKB feet 12021 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured cl~ True vertical depth BKB 92' 30" Driven 131' 131' 2435' 13 3/8" 3440 c.f. Permafrost 2474' 2473' 10985' 9 5/8" 575 c.f. Class G 11024' 9618' 1269' 7" 446 c.f. Class G 10751'- 9418'- measured 11564'-11594', 11610'-11634', 11640'-11694', 11760'-11770'(AIIsqueezed) true vertical (Subsea) 9989'- 10015', 10028'- 10049', 10054'- 10100, 10158'- 10167'~ll s. queez~cO~. " Tubing (size, grade, and measured depth) 4 1/2" 12.75 #AB DSS tubing with 3 1/2" tailpipe to 10794' FEB 20 1996 Packers and SSSV (type and measured depth) 9 5/8" Packer at 10684'; SSSV at 1572' 13. Attachments Description summaw of proposal__ Detailed operations program X BOP sk~'~ 14. Estimated date for commencing operation February 20, 1996 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Service Water Injector Suspended__ 17. I hereby certify that the foregoirjg isltrue axed correct to the best of my knowledge. Signed ,~~,~..,.....~ --z._~ Title ~¢,,1, ,-- ~,--///,.~.~-,_-,_-,_-,_-,~ ~',,.,..) FOR COMMISSION USE ONLY U Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test ~ Location clearance__ Mechanical Integrity Test Subseaue~t form,reouired 10- /~ ~ ~ -- 0dginal u~gnea ~y David W. Johnston Approved by order of the Commission Form 10-403 Rev 06/15/88 Date Approved Cot~¢ppr°val NO. ~'~ - (2 .~ 4.//' Returned. Commissioner Date SUBMIT IN TRIPLICATE PRE-RIG OPERATIONS I . . . Pull the WL SSSV. Confirm annulus is fluid packed and freeze protected. Kill well with Seawater. Spot 30 bbl sized salt pill across the perforations. Displace with freeze protection diesel and brine. Set BPV. Dig out the cellar and level the pad. Inspect the wellhead and tree. Test the 9-5/8" packoff and function test the LDS's. RIG OPERATIONS (SUMMARY) . . . , , . . . , 10. 11. 12. 13. 14. 15. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. Check that the well is dead. ND the tree and NU the BOPE. Test the BOPE. FEB _2.0 '19'36 Alaska Oi! & ,G,~s Cons. Commission Screw in the landing joint. Shear SBR pinned at 72,500 # over stri~¢h°ra~''~ weight. LD tubing and SBR. P/U overshot to fish the latch. (Optional hang off BHA on storm packer. Replace the 9-5/8 mandrel packoff If testing proves it is necessary. Test Packoff). Install bowl protector. Continue to RIH with overshot and fish the latch. P/U mill and PRT for 9-5/8" packer. Fish 9-5/8" Baker packer and tailpipe. PU bit and tandem 7" & 9-5/8" scrapers and clean out to PBTD 11,932'. RIH open ended and lay 26 bbl balanced plug across the perforations. POH 15 stands and squeeze to 2500 psi or 5 bbl loss. POH. RIH to cleanout liner. Test casing to 3500 psi for 30 minutes. Cleanout to PBTD test squeeze to 1500 psi. Change over to clean brine. RIH w/9-5/8" x 4-1/2" packer, 4-1/2" L-80 tubing to expected setting depth. Set the 9-5/8" packer. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. Set the BPV. ND the BOPE and NU the tree. Shear the RP valve and freeze protect the well. 16. Turn the well over to ProdUction. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 7, 1996 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. B. Wondzell Dear Mr. Wondzell, Attached, please find an Application for Sundry Approval for Endicott MPI water injection Well 1-41/O-23. The well is diagnosed as having a leaking production packer causing tubing - IA communication. BP requests that the well be allowed to remain on injection, pending a decision of available options to remedy the problem. Please feel free to contact myself at 564-4613 if you require further information or discussion regarding the proposed course of action. Sincerely, Bob Metzger Endicott Development attachments (3) rrm FEB 1 5 1996 Oil & Gas ConS. Comr~lission Anchoracje ec: Haas, J. Laule, B. ~ Suttles, D. Wood, D. Endicott Production Coordinator Endicott PE Supervisor cc: File 06.10 1-41 Well File STATE OF ALASKA ALA,_. ,A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend__ Alter casing __ Repair well Plugging __ Change approved program .__ Pull tubing __ Operation Shutdown __ Re-enter suspended well __ Time extension __ Stimulate __ Variance X Perforate__ Other__ 5. Type of Well: 6. Datum elevation (DF or KB) Development__ KBE- 55 Exploratory __ Stratigraphic__ 7. Unit or Property name Service X Duck Island Unit/Endicott 8. Well number 1-41/0-23 MPI 9. Permit number 87-32 10. APl number 50- 029-21713 11. Field/Pool Endicott Pool 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2121' SNL, 2153' WEL, Sec. 36, T12N, R16E At top of productive interval 4460' SNL, 3616' WEL, Sec. 31, T12N, R17E At effective depth 4567' SNL, 3528' WEL, Sec. 31, T12N, R17E At total depth 4648' SNL, 3421' WEL, Sec. 31, T12N, R17E ORIGINAL 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12180 feet Plugs (measured) 10583 BKB feet 11932 feet Junk (measured) 10366 BKB feet 12021 2 DC's, 2 stabs, 3 x/o's and 1 mill feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured cl~ True vertical depth BKB 92' 30" Driven 131' 131' 2435' 13 3/8" 3440 c.f. Permafrost 2474' 2473' 10985' 9 5/8" 575 c.f. Class G 11024' 9618' 1269' 7" 446 c.f. Class G 10751'- 9418'- measured 11564'- 11594', 11610'-11634', 11640'- 11694', 11760'- 11770' (Afl squeezed) true vertical (Subsea) 9989'- 10015', 10028'- 10049', 10054'- 10100, 10158'- 10167'(Afl squeezed) Tubing (size, grade, and measured depth) 4 1/2" 12.75 # AB DSS tubing with 3 1/2" tailpipe to 10794' ~'~ ~ ~.~..i V ~ D Packers and SSSV (type and measured depth) 9 5/8" Packerat 10684'; SSSVat 1572' FEB 15 1996 13. Attachments Description summary of proposal X Detailed operations program __ 14. Estimated date for commencing operation February 15, 1996 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Service Water Injector Suspended__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S igne~ ~:.~J, /~__.,~--~ T itle,,~,J. ~~.,, ~ ~ ./7 - co .,ss,o, o..¥ Conditrons of approval: Notify Commission so representative may witness I Approval No. Plug integrity BOP Test __ Location clearance __ Mechanical Integrity Test Subsequent form required 10--~//G~ ¢Jr ~j;~roved Copy /w.o,,,'4,=,r ,~~ p~,~.~ r_).,,t4 :fo_s. ' 'Return.ed 0ng~nar~gned By ~//4.//'~(.,, __ Approved by order of the Commission David W. Johnston -~ommissioner' Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SUNDRY APPLICATION FOR VARIANCE ENDICOTT POOL WELL 1-41/O-23 February 7, 1996 Background Well 1-41/O-23 was originally drilled and completed in May, 1987 as an MPI area subzone 2B producer. Prior to conversion to water injection service in December of 1995, the well had a cumulative production of 5.7 mm barrels of oil. Conversion to water injection service was warranted since the well was determined to have no further utility as a producer, and was positioned within the reservoir to provide additional water injection support for lower MPI 2B and 2A subzones. /.~ ,~ ¢/~ ,,.,~,~ ,~4- Tubing to inner annulus communication was suspected in late December, 1995. On January 28, 1996, a plug was placed in the tubing tail at the 'XN' profile and the tubing pressure tested to 1900 psi. IA pressure was stableat 300 psi during this test. Tubing pressure wa§~h~en bled to 500 psi and the IA,~.C~-S-u-~-~d to 1500 psi. The tubing pressure remained constant, while IA pressure fell-off 300 psi in 30 minutes. IA pressure continued to drop to 900 psi over an additional 60 minutes. Remedial Actions The pressure data tend to point to a failed 9 5/8" production packer as the source of the tubing-inner annulus communication. Currently, both rig and non-rig options are under consideration to remedy the IA communication. At the same time, the well is being evaluated with respect to its' future utility within the overall reservoir development plan for the MPI lower subzones. Recommendation We request that 1-41/O-23 be allowed to remain on injection until May 1, 1996, pending resolution of available workover options and final disposition of the well. The well will remain on injection at a reduced rate, such that average wellhead pressure no greater than 2000 psig will be experienced. Annular pressures will be routinely monitored during this period. We believe the well may be utilized in this manner without compromising safety. Your concurrence.- is sought. FEd '1 7L 1996 .Alaska Oil & Gas Cons. Gommission Anchorage ' ( MPI WELL x-41/O-23 RT ELEV = 55.2' BF ELEV = 15.8' . MAX. DEV. = 46:00 10300' WELL NAME 1-41/O-23 TREE: 4-1116" 15000 PSI I ClW WELLHEAD: 13-518" / 5000 PSI / ClW MD DEPTH 4 1/2' SSSV 01572' (MIN I.D. 3.813') WITH SSSV MIN I.D. 2.0' 13-3/8' CSG SHOE 2,474' 4-1/2", 12.75#/FT, L-80, DSS TBG GAS LIFT MANDRELS (HUGHES) TVDSS MD-BRT #6 4141' 4,197" #5 6310' 6,553' tut 7772' 8,559' #3 8683' 9,789' #2 9085' 10,360' #1 9187' 10,505' OTIS 'XA' SLIDING SLEEVE 10,611' (3.813' MIN ID) BAKER 'EB-I' TBG SEAL ASSY 10,669' BAKER 9-5/8' PACKER 10,684' 3-1/2', 9.2#/FT, TAILPIPE OTIS 3-1/2' 'X' NIPPLE 10,728' (2.750' ID) TOP 7' LINER 10,751' OTIS 3-1/2' 'XN" NIPPLE 10,760' (2.635" ID) WIRE LINE ENTRY GUIDE 10,794' 9-5/8', 47#/FT CSG SHOE 11,024' COMMENTS SQZ SEE 'FISH IN HOLE' PERFORATIONS: REF: CBT-GR (5/01/87) SOS 5' 5SPF 11,564' TO 11,594' SQZ 11,610' TO 11,634' SQZ 11,640' TO 11,694' SQZ 2-1/8' 4 SPF 11,760' TO 11,770' SQZ FISH IN HOLE: 1.5" GLV PBTD 11,932' 7' - 29#/FT CSG SHOE 12,020' TOP OF FISH 12,021' OPEN HOLE T:D. 12,180' BP EXPLORATION, INC. COMPLETION DIAGRAM ENDlCO1-F WELL 1-41 ! 0-23 APl NO: 50-029-21713 REVISED BY: MDM DATE: 10/I5/93 LOG/DATE 5/1/87 ZONE TOP M.D. BOT M.D. H 285 11564 11594 283/282 11610 11634 281 11640 11694 2A 11760 11770 ~T~ROJ£CT _4 ::L/0- 2 5 IST LOG: 05/~1/87 ENDTCOTT LOGS - xPIz ~-93 ~!/25/95 12=55.'18 DEPTH UNIT - FEET COt{NENTz '1'VD EXTI; ACTUAL MD OIL $HO~3 se NPH! INELU~O OR CO~8 t~ '?'?T'.""VT'T':"? - ~ "i'! :'! =--'? ?~:~..'"..'! W::.=. "'?'?'T'?"V'.""!"?' ~~ Lt') --: - L~- -' -: ~ ;'"'-'- -*'-; -' '~-' i;.;-.: -&*-' --:--:--;--~-- ~,..- ~ ~ ..i.i~..LL~iS~....:.i .:.:~ ~._~..L.i..i...:. ...21--i-'~'-- ~ · -.:-+'6q .... ',~ .-i-H~i~ -:=.-'-:~i.--i---.'--+--.:-.! -.:---.'-- ::::::: 7~S~- ::::::": :: : : : : : : : , .'?'?':."F'-u~ - ~ "!'[E.... '"7."~7.:"i'i.~..'.'~ "~"'."'T': . ""~":"' ~-E-~-?-~ - o -~.~,! ,--~-'.~.~F,'.-'.--¢--:-F. .--~-F,- ' ' .:..L. _O~ -- ~ ..L[:"_..;-::J'~:::..Li:::i~ ..i...:..;. ' .... L.i..".. . : .;.a.;.;. i .... - ~ ..i.[:;?'" .... 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".'-'v'?'.."7'7'..-':"-cq ,~ ".. ----":T..'~".."'...~.:: ":"'..":'T: · : : TOP TVD BOT TVD SPINNER SPINNER SPINNER SPINNER 6/5/94 4/9/95 4/28/95 30 9989 10015 0.22 0.13 0.00 SCXJI=F-/F~ 24 10028 10049 0.30 0.05 0.00 SQU~ 54 10054 10100 0.46 0.82 1.00 SQUF:F-/F~ 10 10158 10167 0.00 0.00 SC;)JFFTFF) STATE OF ALASKA ALAb,,~-~ OIL AND GAS CONSERVATION COMMISSIuN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate ~ Plugging__ Pull tubing __ Alter casing __ Repair well __ Perforate,__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2121' SNL, 2153' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE- 55 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-41/0-23 MPI At top of productive interval 4460' SNL, 3616' WEL, Sec. 31, T12N, R17E At effective depth 4567' SNL, 3528' WEL, Sec. 31, T12N, R17E At total depth 4648' SNL, 3421' WEL, Sec. 31, T12N, R 17E ORIGINAL 9. Permit number/approval number 8 7-32/95-199 10. APl number 50- 029-21713 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12180 feet 10583 BKB feet Plugs (measured) 11932 feet Junk (measured) 10366 BKB feet 12021 2 DC's, 2stabs, 3x/o's and I mill Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 131' 2435' 13 3/8" 3440 c.f. Permafrost 2474' 2473' 10985' 9 5/8" 575 c.f. Class G 11024' 9618' 1269' 7" 446 c.f. Class G 10751'- 12020' 9418'- 10442' measured 11564'- 11594', 11610'- 11634', 11640'- 11694', 11760'- 11770'(AIIsqueezed) true vertical (Subsea) 9989'- 10015', 10028'- 10049', 10054'- 10100, 10158'- 10167'(AII squeezed) Tubing (size, grade, and measured depth) 4 1/2" 12. 75 # AB DSS tubing with 3 1/2" tailpipe to 10794' Packers and SSSV (type and measured depth) 9 5/8" Packer at 10684'; SSSV at 1572' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 201 140 6487 0 19180 0 Tubing Pressure 413 2189 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil __ Gas__ Suspended Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ined~,~*~/'J/~/.~q~/-~ E~/. /~~~ Title SeniorTechnicalAssistantll Form10-~0-_,4/~/// ~t Rev 06/15/88 Date SUBMIT IN DUPLICATE Endicott Production Engineering Department INITIAL MIT FOR CONV TO WATER INJ. DATE: 10/8/95 WELL N-°: 1-41/O-23 BP EXPLORATION REP: R. CLUMP SERVICE COMPANY: HB & R / AOGCC REP: J. HERRING DATE/TIME OPERATIONS SUMMARY 1100 MIRU HB & R TO IA. SIP= 1600 PSI, lAP= 375 PSI. PT LINE TO 3500 PSI. 1106 START PUMPING DIESEL. 1115 PUMPED 4 BBLS DIESEL. lAP= 2475 PSI. RDMO HB & R. START TEST. 1145 lAP= 2475 PSI. TEST IS GOOD. BLEED IA DOWN TO 300 PSI LATER WELL BEING CONV TO WATER INJ. PASSES INITIAL MIT. J. HERRING (AOGCC) WIT. STATE OF ALASKA ALA,.,,,A OIL AND GAS CONSERVATION COMMISSI'~N 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 __ Variance __ Perforate __ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2121' SNL, 2153' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development x Exploratory __ Stratigraphic Service 6. Datum elevation (DF or KB) KBE - 55 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-41/0-23 MPI At top of productive interval 4460' SNL, 3616' WEL, Sec. 31, T12N, R17E At effective depth 4567' SNL, 3528' WEL, Sec. 31, T12N, R17E At total depth 4648' SNL, 3421' WEL, Sec. 31, T12N, R17E ORIGINAL 9. Permit number 87-32 10. APl number 50- 029-21713 11. Field/Pool Endicott Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12180 feet Plugs (measured) 10583 BKB feet 11932 feet Junk (measured) 10366 BKB feet 12021 2 DC's, 2 stabs, 3 x/o's and I mill Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured cl~ 92' 30" Driven 131' 2435' 13 3/8" 3440 c.f. Permafrost 2474' 10985' 9 5/8" 575 c.f. Class G 11024' 1269' 7" 446 c.f. Class G 10751' measured 11564'- 11594', 11610'- 11634', 11640'- 11694', 11760'- 11770' True vertical depth BKB 131' 2473' 9618' true vertical (Subsea) 9989'- 10015', 10028'- 10049', 10054'- 10100, 10158'- 10167' Tubing (size, grade, and measured depth) 4 1/2" 12.75 #AB DSS tubing with 3 1/2" tailpipe to 10794' Packers and SSSV (type and measured depth) 9 5/8" Packer at 10684'; SSSV at 1572' 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation December 1995 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. FOR COMMISSION USE ONLY Conditi~6s of approval: Notify Commission so representative may witness Plug integrity_ BOP Test __ Location clearance __ Mechanical Integrity Test ,X, Subsequent form required 10- ,Y~,-/ ' ' Jr~ginal Signed By ~)avid W, Johnston Approved by order of the Commission Date / ~!/,,~/~/'~)- / / I Approval NO.?~-./~::~,~ ~Dproved Copy Returned. ~ / , z Cd~issiO~er Date X/~ '~~~ SUBMIT ¢ Th .bCA Form 10-403 Rev 06/15/88 Endicott Well 1-41/O-23 : Change of Service to Water Injection Conversion of well 1-41/O-23 to water injection duty is recommended. This conversion will support offtake of remaining reserves in Subzone 2B at well 1-61/Q-20, and in Subzone 2A at wells 1-31/M21, 1-33/M-23 and high GOR well 1-27/P-20. This well is a shut-in non-competitive producer with watercuts in excess of 95%. In April 1995, both the oil-water contact and the localised gas-oil contact were logged at 10,050'tvdss. Two non-rig water shut-off cement squeezes were performed in April and May of 1995, both failing to reduce water production. No further potential exists for additional oil recovery at this location. Cumulative oil production to date stands at 5.7mmbbls. STATE OF ALASKA ALA~.,,~ OIL AND GAS CONSERVATION COMMISSI~ J REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2121' SNL, 2153' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE- 55 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-41/0-23 MPI At top of productive interval 4460' SNL, 3616' WEL, Sec. 31, T12N, R 17E At effective depth 4567' SNL, 3528' WEL, Sec. 31, T12N, R17E At total depth 4648'SNL, 3421' WEL, Sec. 31, T12N, R17E ORIGINAL 9. Permit number/approval number 87-32/Not Required 10. APl number 50- 029-21713 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 12180 feet 10583 BKB feet Plugs (measured) 11932 feet Junk (measured) 10366 BKB feet 12021 2 DC's, 2 stabs, 3 x/o's and I mill Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 131' 2435' 13 3/8" 3440 c.f Permafrost 2474' 2473' 10985' 9 5/8" 575 c.f. Class G 11024' 9618' 1269' 7" 446 c.f. Class G 10751'- 12020' measured 11564'- 11594', 11610'- 11634', 11640'- 11694', 11760'- 11770' 9418'-10442' true vertical (Subsea) 9989'- 10015', 10028'- 10049', 10054'- 10100, 10158'- 10167' Tubing (size, grade, and measured depth) 4 1/2" 12. 75 # AB DSS tubing with 3 1/2" tailpipe to 10794' Packers and SSSV (type and measured depth) 9 5/8" Packer at 10684'; SSSV at 1572' 13. Stimulation or cement squeeze summary Water shut off cement squeeze #1 (4/26/95) and Water shut off cement squeeze #2 (5/19/95) Intervals treated (measured) 11564'- 11594', 11610'- 11634', 11640'- 11694', 11760'- 11770' Treatment description including volumes used and final pressure #1:970 Bbls Fresh seawater, 19 Bbls 15% HCl../Xylene, 28 Bbls EW, 21 Bbls cement, & 40 BBLs methanol; FSlWHP = 2450; #2:550 Bbls. fresh seawater, 31 Bbls mud acid, 278 Bbls seawater, 24 Bbls ew and 19 Bbls cement; FSlWHP = 2250 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 465 71 7283 0 201 140 6487 0 Tubing Pressure 327 413 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby certify that the foregoing is true_/a~ correct to the best of my knowledge. Signed ~~¢'~..,~,..(_~ ~, ,~~~' Title Senior Tech.ica/Assistant II Form lO-4~ev 06/15/88 Date SUBMIT IN DUPLICATE LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 2 May 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: ~ELL ~./~2-40/S-22 ~_7~4-26/°-34 DESCRIPTION 1 PFC/PERF FINAL BL+RF 1PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 PLS FINAL BL+RF ECC No. Run # 1 3842.04 Run # 1 5724.04 Run # 1 6004.05 Run # 1 6351.06 Run '# 1 6355.04 Run # 1 Run #'1 6419.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and r~eturn Petrotechntcal Data Cente: BP Exploration (Alaska) InS 900 East Benson Boulevard Nask~ Oil & Gas ~s. AnChOrage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE. ANCHORAGE AK, 99501. Date: 13 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below.' WELL DESCRIPTION PLS FINAL BL+RF PLS FINAL BL+RF ECC No. Run # 1 4205.03 Run ~ 1 6004.04 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: ~_ /~d~~~. . Date: Please sign end~etur~.~ol Petrotechmical Data center UP E×ploration (Alaska) inO 900 East Benson Boulevard Anchorage, Alaska 99508 Received bY ..... - - ~-~-- ' ------~'- ~- ... ..... . .. APR O 1995 Naska 011 & Gas Cons. Commission Anchorage STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COM, .... ;SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well 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 2121'SNL, 2153' WEL, Sec. 36, T12N, R16E At top of productive interval 4460'SNL, 3616' WEL, Sec. 31, T12N, R17E At effective depth 4567' SNL, 3528' WEL, Sec. 31, T12N, R17E Perforate Other X 6. Datum elevation (DF or KB) KBE- 55 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-41/0-23 MPI 9. Permit number/approval number 87-32/Not Required 10. APl number 50- 029-21713 At total depth 4648'SNL, 3421' WEL, Sec. 31, T12N, R17E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12180 feet 10583 BKB feet 11. Field/Pool Endicott Pool Plugs (measured) 11932 feet Junk (measured) 2 DC's, 2 stabs, 3 x/o's and 1 mill 10366 BKB feet 12021 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True v~rt~l depth BKB 92' 30" Driven 131' 131' 2435' 13 3/8" 3440 c.f. Permafrost 2474' 2473' 10985' 9 5/8" 575 c.f. Class G 11024' 9618' 1269' 7" 446 c.f. Class G 10751' - 12020' measured 11564'- 11594', 11610'- 11634', 11640'- 11694', 11760'- 11770' 9418'- 10442' true vertical (Subsea) 9989'- 10015', 10028'- 10049', 10054'- 10100, 10158'- 10167' Tubing (size, grade, and measured depth) 4 1/2" 12.75# AB DSS tubing with31/2" tailpipe to 10794' Packers and SSSV (type and measured depth) 9 5/8" Packer at 10684'; SSSV at 1572' 13. Stimulation or cement squeeze summary Scale Inhibitor Treatment (10/6/94) Intervals treated (measured) 11564'- 11594', 11610'- 11634', 11640'- 11694', 11760'- 11770' 62 Bble diesel/mutual solvent mix and 653 Bbls ~eawater with scale Treatment description including volumes used and final pressure inhibitor and surfactant mixes. FSIWHP = 200 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!action Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 723 173 2242 0 819 183 2644 0 Tubing Pressure 553 343 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ~_~,~E., ~>~' ~--~~-'-~' Title senior Technical Assistant II Form 10..41~ Rev 06/15/88 Date /~//~/~ ~ SUBMIT IN DL4PL4OAYE ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 9 June 1994 RE: Transmittal of Data ECC #: 6004.03 Sent by: ANCHORAGE XPRES Data: PL Dear Sir/Madam,. · Reference: BP 1-41/O-23 (MPI) ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Prints/Films: ,~PLS FINAL BLUELINE PLS FINAL RF SEPIA Run # 1 Please sign an~ return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: Please s i~n and return to: Petrotechnical Data Center BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99508 Received by Da%e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,.. _,'N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate × Pull tubing Alter casing Repair well 6. Datum elevation (DF or KB) '~/~'~"'1 KBE- 55 f~et I 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2121' SNL, 2153' WEL, Sec. 36, T12N, R16E At top of productive interval 4460'SNL, 3616' WEL, Sec. 31, T12N, R17E At effective depth 4567' SNL, 3528' WEL, Sec. 31, T12N, R17E At total depth 4648' SNL, 3421' WEL, Sec. 31, T12N, R17E 5. Type of Well: Development .. Exploratory Stratigraphic Service 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-41/0-23 MPI 9. Permit number/approval number 87-32/Not Required 10. APl number 50- 029-21713 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12180 feet 10583 BKB feet 11932 feet 10366 BKB feet Plugs (measured) Junk (measured) 2 DC's, 2 stabs, 3 x/o's and I mill at 12021' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 92' 30" Driven 2435' 13 3/8" 3440 c.f. Permafrost 10985' 9 5/8" 575 c.f. Class G Measured depth True ve~l depth BKB 131' 131' 2474' 2473' 11024' 9618' 1269' 7" 446 c.f. Class G 10751'- 12020' measured 11564'- 11594; 11610'- 11634; 11640'- 11694', 11760'- 11770' 9418'-10442' true vertical (Subsea) 9989'- 10015; 10028'- 10049; 10054'- 10104 10158'- 10167' Tubing (size, grade, and measured depth) 4 1/2" 12.75#AB DSS tubing with 3 1/2" tailpipe to 10794' Packers and SSSV (type and measured depth) 9 5/8" Packerat 10684'; SSSVat 1572' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1463 10085 586 0 / 1517// 12334 564 0 Tubing Pressure 2699 2682 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X' Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~.~ TitleSeniorTechnicalAsslstantll Form 10-4~,l~ev 06/15/88 SUBMIT IN DUPLI~AI I= ~ Endicott Production Engineering Department DATE: 10/15/93 WELL N-°: 1-41/O-23 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: ADD PERFORATIONS MARTIN _ ATLAS WIRELINE ,, DATE TIME OPERATIONS SUMMARY 10/14/93' 1430 ATLAS'"0N' LOCATION. RIG UP AND'PRESSURE TEST. WELL WAS SHUT IN. RIH WITH 10', 2-1/8" JUMBO JET, 6.5gm CHARGE, 4 SHOTS PER FT, 180° PHASED, 90° ORIENTATION GUN. TIE IN TO CET/GR (DTD 5/1/87) SHOOT @ 11,760' TO 11,770'. POH. ALL SHOTS FIRED. 1930' RIG DowIq. POP WELL AND RETURN TO PROI~UCTION'. ..... ,., ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Dear Sir/Madam, Reference~: BP 1-41/O-23 (MPI) ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Date: 21 October 1993 RE: Transmittal of Data ECC #: 6004.01 Data: PDK-PORO Tapes/Diskettes: 1 C~--PDK LDWG TAPE+LISTER Run # 1 Sent by ANCHORAGE XPRES ~ ~qZ I~ 050 --l~ 5 Received by: Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Date: This is to acknowledge receipt of the followin9 prints and negatives. COMPANY: STATE OF ALASKA - ALASKA OIL & GAS COMMISSION ATTENTION: LARRY GRANT FIELD: ENDICOTT WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA 2-36/0-14 PFC/GR~PERFJlcca 5': [{OTO 1__ [~O 0 1 3-25/M-27 gCL~CHEM C~ 5" ~%%~O k 15~S9 0 1 1-41/O-23 PFC/GR ~ERF~/~ 5" [~5~ {{~ZO 0 1 ...... Please return one copy of si~ned transmittal to each of the following: Atlas Wireline Services Pouch 340013 Prudhoe Bay, AK 99734 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 FT\RTN~I BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 11, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, JLH Enclosures xc: File 06.10 WELL NAME ~-/'-~, I --1-09/J-18 ~7-- "~ 2.-1-41/O-23 ~c/--! lq--1-67/T-20 ~T~-~Z,---2-04/M-19 ~ 0.-- q ~-'2-18/L-16 ~O-- 7.4/-2.36/O.14 ~2 -~J 7_ I- 3-03/J-33 DATE 9/17/93 9/2O/93 9/25/93 9/21/93 9/21/93 9/22/93 9/24/93 INTERVALS LOG NAME RUN NO COMPANY NAME 11500'-11951' 11050'-11875' 11300'-11800' 10300'-10750' 10800'-11150' 10550'-11350' 13425'-13725' Production Logging Services PDK-100 Production Logging Services Production Logging Services Production Logging Services PDK-100 Production Logging Services ATLAS WI RELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WlRELINE ATLAS WlRELINE ATLAS WI RELINE INTERVALS 11973'-12150' LOG NAME ~PFC/GR/CCL RUN NO COMPANY NAME ATLAS WIRELINE WELL NAME DATE ~'/'-1-01/J-19 8/2/93 -1~)~3.33/K.37 8/2/93 -~_F~.. 2-04/M-19 7/24/93 ~ 3-27/M-33 7/28/93 - 3-01/N-29 7/26/93 ~al!l~lll~. 1-41/0-23 7/29/93 -'1-35/0-25 7/31/93 -'1-15/P-25 8/5/93 /~4-06/Q-32 7/25/93 ~'?.-~ ~4-06/Q-32 7/25/93 ~-06/Q-32 8/5/93 .,,,.,2-52/S-14 8/11/93 12630'- 13200' 10460'- 10748' 10980'-11950' 11600'- 12850' 11350'-11892' 12750'- 13100' 12430°-12800' 11000'- 11250' 10953'-11250' 8850'- 11350' 11503'- 12072' PRODUCTION LOGGING SERVICES PFC/GR/COL PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES PFC/GR/CCL PFC/GR/CCL PRODUCTION LOGGING SERVICES PFC GAMMA RAY ~PRODUCTION LOGGING SERVICES ~PFC GAMMA RAY ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WI RELINE ATLAS WI RELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 20, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, J_~nne L. Haas · ~'enior Technical Assistant Ii JLH Enclosures xc: File 06.10 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 20, 1991 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the 'well logs run on the following Endicott wells: WELL 1-27.P-20 ,/ 9930'-10700' CNL SCHLUMBERGER 7/4/91 RUN ONE WELL 1-39/P-17 ,/ 10100'-10400' PUMP-IN-TEMPERATURE SURVEY 7/1/91 RUN ONE WELL 1-41/O-23v' 11 350'- 11 880' PRODUCTION LOG SCHLUMBERGER 7/4/91 RUNONE WELL 1-45/Q-26 v/ 13250'-13760' PRODUC'flON LOG SCHLUMBERGER 8/1/91 RUNONE 2142/J LH/clt BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 13, 1991 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the well logs run on the following Endicott wells' WELL 1-27/P-20 ~q'" PRODUCTION PROFILE SURVEY./ 10350'-10900' 5/23/91 RUN CNE WELL 1-41/O-23 PRODUCTION PROFILE SURVEY ~J 11350'-11900' WELL 1-47/Q-21 TEMPERATURE SURVEY ./ 10650'-11290' HRS TUBING COLLAR LOG W/JEWELRY -/ 9800'-10900' HRS 5/22/91 RUN ONE 5/1 2/91 RUN ONE 5/12/91 RUN ONE RECEIVED JUN 1 7 1991 Alaska (ill & Oas Cons. ~ 2013/JLH/clt BP EXPLORATION BP Exploration (Alaska)Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 4, 1990 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells' WELL 1-01/J-19 *TEMPERATURE SURVEY 11790' - 12264' Run No. 1 HRS WELL 1-09/J-18 *PRODUCTION PROFILE SURVEY 11428' - 12146' Run No. 1 thru 4 CAMCO WELL 1-37/P-24 *INJECTION PROFILE SURVEY 11700' - 13000' Run No. 1 CAMCO WELL 1-41/O-23 *STATIC TEMPERATURE SURVEY 11000' - 11901' Run No. 1 CAMCO RE¢£1V D APR - 91990 Alaska 0il & Gas Cons. comm'tss'tot~ Anchorage BP EXPLORATION March 14, 1990 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Reports Dear Sirs' Enclosed are Bottom Hole Pressure Reports for the following wells Well Name Date 1-09J-18 2-12-90 1-41/O-23 2-18-90 1-491P-21 3-1-90 1-67/T-20 2-3-90 2-26/N- 14 2-7-90 2-28/P-19 2-24-90 2-52/S-14 1-2-90 3-17/J-30 2-27-90 4-04/T-26 12-30-89 4-42/P-38 2-13-90 4-46/N-39 12-29-89 5-03/SG09 2-20-90 If there are any questions regarding this data, please contact Jeanne Haas at 5.64-5225. Sincerely, 'eanne L. Haas JLH Enclosures BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 December 4, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells: WELL 4-04/T-26 *PFC LOG 12950'-14016' Run No. 1 ATLAS WIRELINE SERVICES WELL :~-11/M-30 *PRODUCTION PROFILE LOG 12800'-13200' Run No. 1 CAMCO WELL 3-4,,5/M-39 SDI *INJECTION PROFILE TEMPERATURE SURVEY 11880'-12700' Run No. 1 CAMCO WELL 1-41/0-23 *PRODUCTION PROFILE 11400' - 11900' CAMCO Run No. 1 RECEIVED c - l glt9 Alaska 0il & Gas Cons. CommissiQl! Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 23, 1989 Mr. J. Boyle AOGCC 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Mr. Boyle: Accompanying this letter are reprocessed TDT-P data, including bluelines, sepias, and tapes, for the following wells' Sag Delta 7 ~ N-29 Sag Delta 10 ~ 0-23 J-18 ~ ~O-25 J-19 ~O-29 K-33 '~ ~' P-17 ~, M-19 "P-20 M-25 ~ ~ ~' P-24 M-30 '~,, Q-32 N-22 In January of this year, Schlumberger modified their TDT-P software. Previously processed logs then 'became unsuitable as baselines for fluid monitoring with newly processed logs. Consequently, Schlumberger agreed to reprocess previous TDT-P data with the new software, and we now have a full set of standard format, consistently processed logs for monitoring fluid movements. If any further questions arise over the reprocessing of TDT-P logs in Endicott please contact J.H. Dupree (907) 564-4797 G.W. Geehan Manager Endicott Geoscience GWG/GD/Ims Standard Alaska ~- Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 January 25, 1989 STANDARD ALASKA PRODUCTION Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Reports Dear Sirs' Enclosed are Bottom Hole Pressure Reports for the following wells in the Endicott Reservoir: Well Name Date ! -" 1-41/O-23 j."l 43/P-26 t -'2-04/M-19 ~ ~3-21/L-34 I,," ~,, /.~ 3-35/L-36 ~ 12-06-88 12-16-88 01-02-89 01-02-89 01-15-89 If there are any questions regarding this data, please contact Loren Twyford at 564-4401. Sincerely, JLH Jeanne L. Haas Anchorage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Standard Alaska ~' Production Company 900 East Benson Boulevura P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-.5111 STANDARD ALASKA PRODUCTION January 3, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Endicott Well Log Information Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the cased hole well logs mn in the following Endicott well: WELL 2-08/K- 16 *PRODUCTION PROFILE 11700'-12050' Run No. 1 CAMCO WELL 2-28/P.- 19 *PRODUCTION PROFILE 9900'- 10250' Run'No. 1 CA/rICO WELL 1-41/O-23 *PRODUCTION PROFILE 11350'-11800' Run No. 1 CAMCO WELL 3-1 l/M-30 *PRODUCTION PROFILE 12700'-13200' Run No. 1 CAMCO ~: gncl~oraqe Date Sincerely, ~llard A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Standard Alaska .... Production Company 900 East Benson Boulev~,~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 MAR 21, 1988 STANDARD ALASKA PRODUCTION John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: The following log information for wells is enclosed: 1 sepia and blueline print for; 1-41~~ Run 1 Mar. 3, 1988 * TDT-P Sincerely, ~ ~ ~,~. ~.~II~ ~ Bruce St Pierre e '' A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Standard Ala~,' .... Production Co.n, , 900 Eost Benson Boutevord P.O, Box 196612 Anchorage, Alaska 99519-66t2 (907) 561-5111 JUL 28, 1987 STANDARD ALASKA PRODUCTION William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells is enclosed: 1 sepia print and 1 blueline print for: 0-23 Run 1 July 20, 1987 * TCP GR Positioning Log Sincerely, Bruce St. Pierre ~, umt of the or,gmoi StC. r~dord Fou,~ded m Cle~eiond Oh;o ,n 1870 ~ STATE OF ALASKA (~I:SSION ~' ALASK~i~ AND GAS CONSERVATION WELL COMPLETION OR RECOMPLETIONi EPOFIT AND LOCi 1. Status of Well Classification of Service Well OIL [~ GAS r-] SUSPENDED [2] ABANDONED [] SERVICE [~] 2. Name of Operator 7. Permi~ Number ' standard Alaska Production Company 87,32 3. Address 8. APl Number P. O. Box 196612 Anchorage Alaska 99519-6612 50-029-21713 4. Location of well at surface 9. Unit or Lease Name 2121' SNL, 2153' WEL, Sec. 36, T12N, R16E Duck Island Unit/ Endicot~ At Top Producing Interval ' ' 10. Well Number 4460' SNL, 3616' 'WEL, Sec. 31, T12N, R17E 1-41/ 0-23 MPI At Total Depth 11. Field and Pool 4648' SNL, 3421' WEL, Sec 31, T12N, R17E Endicott Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Endicott Pool 55.25' = KBEJ ADL 312828 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 4-2-87 4-23-87 7-22-87I N/A feet MSLI Qne 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 12180'MD 10583'TV)l1932'MD 10366'TV)YESS~ NOI'-II BYN @ 1575faetUD ~466' 22. Type Electric or Other Logs Run submitted TCp GR' Positioning Log CBT/CET/~C? ' · May 1987 10-403 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" St~'uctural )rive Pipe;Surface 131' 13-3/8' 68# L-80 Surface 2474' 17%" 3440' cu.ft. Permafrost 9-5/8" 47# NT80S Surface 9191' 12%" 9-5/8" 47# NT95HS 9191" 11024' 12¼" 575 cu.ft. Class G 0 17% HR-7, i%CFR-; 7" 29# ~SMll0 10751 .12020' 8%" 446 cu.ft, class G.5~ Halad 344, .16% 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. ~'TUBING RECORD ' . 2% CFR-2 interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4~" AB DSS 10684'MD 10697'Mp 12.75#/ft. 11564 ' -11594 'MD (9989 ' -10015 ' TVDss) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11610'-11634'MD (1002~'-10049' TVDSs) DEPTH iNTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11640'-11694'MD (1005.~'-1010D' TVDss) q_q~3/8"× 9-5/8" Downsoueeze 13-3/8" x 9-5/8" annulus with 345 sx. Permafro.. Ifollowed bv 115 bbls dry crud( 27. PRODUCTION TEST Date First Production i Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PER~OO 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 lithotogy, porosity, fractures, ~apparent dips and presence of oil, gas or water. Submit core chips. RECEIVEO AUG ~ Naska 011 & gas Oons. C°mmlss[on ~ch0rage Form 10.407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ ~ GEOLOGic MARKi:RS ..... ~ . . ..... :' ': ~::, '~ ' . FORMATION T~STS : , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Hrz 10716' 9338' LCU 11048 ' 9581 ' Top Kekiktuk 11048 ' 9581' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Division ~ Drilling Signed ~),-%- ~ Title Enc3ineer Date .., INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift,' Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" SAPC Daily Drilling Report -- ENDICOTT July 20, 1987 at 0600 hours Rig: Doyon #15 Well: 1-41/0-23 (MPI) AFE # 717520 APl: 50-029-21713 Current Operation: 0600 Depth: 11932' Day: 30 48-Hour Ftg: ' Accept rig at 2130 hfs on 7-18-87. Install BPV. N/D tree. N/U BOPE and test same. Pull tubing hanger. RIH to 1000 ft and displace diesel from well. RIH to 11932 ft and displace well to 9.6 ppg brine. Filter brine. RIH with perforating guns on drill pipe. MUD TYPE-NaC1 Brine WT:9.6 VIS: PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1897D: Rig: Doyon #15 Well: 1-41/0-23 (MPI) SAPC Daily Drilling Report -- ENDICOTT July 21, 1987 at 0600 hours AFE ~ 717520 APl: 50-029-21713 Current Operation: 0600 Depth: 11932' Day: 31 24-Hour Ftg: RIH with perforating guns and space out. Set packer and flow head. Pressure up and fire guns. Flow oil to surface. Shut well in. Unseat packer. Kill well with 9.6 ppg brine. Lost circulation. Well taking 60 bbl/hr. M/U kill pill. ~gJD TYPE-NaC1 Brine WT:9.6 VIS: PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD ~ECTION COORDINATES DLS 1897D: Rig: Doyon #15 Well: 1--41/0-23 (MPI) SAPC Daily Drilling Report -- ENDICOTT July 22, 1987 at 0600 hours AFE # 717520 API: 50-029-21713 Current Operation: 0600 Depth: 11932' Day: 32 24-Hour Ftg: ' R/D control head. perforating guns. N/D BOPE. Circulate hole clean. POH and L/D Run 4-1/2" completion and land in wellhead. MUD TYPE-NaC1 Brine WT:9.6 VIS: PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1897D: SAPC Daily Drilling Report -- ENDICOTT July 23, 1987 at 0600 hours Rig: Doyon #15 Well: 1-41/0-23 (MPI) AFE # 717520 API: 50-029-21713 Current Operation: 0600 Depth: 11932' Day: 33 24-Hour Ftg: ' N/D BOPE. N/U tree and test. Pull dummy SSSV. Set plug in 'XN' nipple. Set packer with 3000 psi and test annulus to 2500 psi - O.K. Open S.S. Displace tubing to diesel. Close S.S. Install BPV. Release rig at 1830 hfs on 7-22-87. MUD TYPE-NaC1 Brine WT:9.6 VIS: PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD .ANGLE DIRECTIQN TVD SECTIQN COORDINATES DL$ 1897D: GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY STANDARD OIL PRODUCTION CORPANY C 0 M F:' A N Y MPI WELL NO. 0-23 W E I... L.. N A f~ I!!i ENDICOTT I,.. (:) C h 'T' I 0 iN 291 FT 11039 FT D El I::' ]"1"t I IN T E R g A L,. F:' Fi: [) M T 0 4-2-87 4-18-87 D A 'l" I!!i S I,.l I:~ V E Y '1' A t'( t!il N F' I:~ t:)I'1 '1' (] THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO OESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT LAND DIRECTIONAL ORILLING~INC 4-22.-87 Client .............. : STANDARD ALASKA PRODUCTION CO. Well - ENDICOTT MPI WELL 0-23 Closure Direction - S 54.30 E Magnetic Declination- 31 deg 30 min E Data file name - B-023.DAT RECORD OF SURVEY (Well assumed vertical to Computotton: RADIUS OF CURVATURE Survey date: 4-22-87 Method ..... : GYRO S.S. & MWD READINGS RKB Height.: 56.0 ft 0.0! MEAS DR I FT TRUVERT SUBSEA SECT I ON DEPTH DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD CLOSURE DOG LEG DISTANCE DG MN S d~ BOO 0 O 0 0.00 -58.00 291 0 15 291.00 235.00 801 0 30 800.99 544.99 982 0 30 981.98 905.98 1233 0 15 1232.97 1176.97 0.00 N 0.00 E -0.34 S 88.00 W -0.99 S 41.00 W -0.05 S 5.00 E -0.13 S 82.00 W 0.00 N 0.00 E 0.24 S 0.59 W 1.41 S 2.23 W 4.32 S 3.17 W 5.58 S 4.17 W 0.00 N 0 0 0 E O. 83 S 88 0 0 W 2.83 S 57 43 42 W 5.38 S 36 17 8 W 8.97 S 38 47 47 W. 0.000 O. 088 O. 08l 0.001 O] 092 1503 1882 2495 2817 0 15 1502.97 1448_97 0 15 I881.97 1825.97 0 15 o~- .. ~ol 98 2205.98 0 45 2494.95 2438.95 0 42 2818.94 2560.94 -1.19 N 57.00 W o58 N = O0 E -2.22 S 88.00 E -1.88 N 11.00 E -2.14 N 26.00 E 5.33 S 5.30 W 3.92 S 5.99 W 2.94 S 4.85 W 1.81 S 3.38 W 0.35 S 2.89 W 7.52 S 44 SO 3 W 7.'18 S S8 49 37 W 5.88 S 58 45 14 W 3.83 S 81 47 8 W 2.91 S 83 3 27 W 0.000 0.000 0.000 0.215 0.041 2899 3184 3467 3752 4038 1 38 2898.88 2842.88 1 12 3183.80 3127.80 1 24 3486.72 3410.72 1 12 3751.85 3695.85 0 42 4037.61 3981.81 0.97 S 58.00 E 7.47 S 18.00 E 13.32 S 47.00 E 19.61 S 38.00 E 24.25 S 49.00 E 1.03 N 1.94 E 4.41 S 8.04 E 9.81 S 9.35 E .14.85 S 13.83 E 18.14 S 18.82 E o 20 N 81 57 47 E 7.47 S S3 S2 33 E 13.55 S 43 38 52 E 20.0i S 42 55 58 E 24.74 S 42 SO S? E O_ 320 O. 140 O ~7'1 0 432.1 4808 4788 488'1 4979 0 48 4320.S? 4284.59 0 42 4805.58 4549.58 0 42 4787_55 4731.55 2 0 4880.52 4824.52 4 18 4978.37 4922.37 27.94 SSl. O0 E 31.67 S 80.00 E 33.89 S S3.00 E 38.08 S 68.00 E 41.28 S 71.00 E °0 52 S 19 68 E aa 83 S 22 73 E 23.88 S 24.59 E 24.98 S 26.47 E 26.94 S 31.48 E 28.42 S 43 48 48 E 32.08 S 45 7 54 E 34.26 S 45 S1 52 E 38.39 S 48 40 34 E 41.43 S 49 28 40 E O. OBE O. 035 0.00] 1. 398 2. 347 5089 8 54 5087.93 5011.93 S184 9 48 S181.91 S105.91 5297 12 S4 5292.30 5238.30 5502 18 6 5489.77 5433.77 5880 22 54 5837.72 SS81.72 49.81 S 65.00 E 83.28 S 89_00 E 88.89 S 87.00 E 142.11 S 87.00 E 198.28 S 85.00 E 30.23 S 39.82 E 35.81 S 52.31 E 45.42 S 78.58 E 86.82 S 128.99 E 89.31S 177.52 E 49.83 S 52 39 29 E 83.28 S SS 45 9 E 89.03 S 59 19 39 E 143.49 S 82 14 54 E 198.72 S 83 17 Bl E 2. 896 3. OSE o 332 o 537 3. 044 ENDICOTT MPI WELL 0-23 4-22-87 RECORD OF SURVEY MEAS DRIFT TRUVERT SUBSEA SECTION DEPTH DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD S847 26 42 S807.45 S751.45 6037 32 42 5972.41 S916.41 6227 38 30 8126.83 8070.83 8322 42 0 6199.33 6143.33 6509 44 18 6335.75 6279.75 273.58 S 63.00 E 366.82 S 61.00 E 476.73 S 60.00 E S37.85 S S9.00 E 665.30 S S9.00 E 123.69 S 248.00 E 167.86 S 331.08 E 222.30 S 427.30 E 253.45 S 480.18 E 319.32 S S89.80 E 6700 44 0 8472.79 6416.79 798.05 S S7.00 E 6890 43 36 8809.93 6553.93 929.35 S S8.00 E 7069 43 30 6739.68 6683.66 1052.42 S 58.00 E 7267 43 12 6883.84 6827.64 1188.06 S 58.00 E 7459 43 0 7023.83 8967.83 1318.89 S S9.00 E 389.81 S 702.61 E 460.47 S 813.52 E S25.82 S 918.11 E S97.85 S 1033.38 E 666.39 S 1145.23 E 7845 42 36 7160.31 7104.31 1444.84 S S9.00 E 731.48 S 1253.56 E 7835 41 42 7301.17 7245.17 1572.00 S S8.00 E 798.10 S I362_27 E 8022 41 24 7441.12 7385.12 1695.78 S S8.00 E 863.83 S 1467.46 E 8217 43 24 7585.11 7529_11 1826.98 S S8.00 E 933.50 S 1578.96 E 8402 45 0 77:17_73 7661.73 1955.75 S 57.00 E 1002.80 S 1887.73 E 8598 44 S4 7856.45 7800.45 2094.07 S S7.00 E 1078.22 S 1803.86 E 8788 44 12 7991.85 7935_85 2227.26 S S6.0O E 1151.78 S 1915.01E 897? 43 12 8129.93 8073.93 2359.16 S S6.00 E 1225_57 S 2024.41E 9166 42 0 8267.58 8211.58 2485.70 S SS.O0 E 1297.26 S 2128.72 E 9358 41 18 8411.05 8355.05 2613.29 S SS.O0 E 1370.45 S 2233.24 E 9545 39 S4 8553.03 8497.03 2734.98 S S4.00 E 1441.12 S 2332.31E 9742 40 S4 8703.05 8847.05 2862.66 S S4.00 E IS16.I6 S 2435.61 E 9927 44 42 8838.76 8782.76 2988.32 S 56.00 E 1588.24 S 2538.55 E 10117 45 42 8972.64 8916_64 3123.10 S 55.00 E 1664.60 S 2649_65 E 10299 45 54 9099.52 9043.52 3253.57 S 55.00 E 1739.44 S 2756.53 E 10489 44 54 9232.93 9176.93 3388.85 S 54.00 E 1818.00 S 2866.67 E 10683 44 24 9370.95 9314.95 3525.19 S S~.O0 E 1898.14 S 2976.97 E 10868 43 6 950~.58 9448_58 3653_I0 S S3.00 E 1974.23 S 3079.80 E 10969 ~2 24 9578.75 ~ PP ...... .5__ 75 3721 62 S 52 O0 E 2015 q7 S 3134 17 E ~11039 42 0 ¢630.60 9574.~0 3768.61 S 52.00 E 2044.92 S 3171.24 E ffINTERPOLATED FRO~ LAST SURVEY STATION CLOSURE DISTANCE DG MN S DOG LEG deg/lO0 277.14 S 63 29 32 E 371.20 S 63 ~; 51 E 481.67 S ~62 30 S1 E 542.96 S 62 I0 25 E 670.69 S 61 34 8 E 2. 044 3. 173 803.51 S 60 58 42 E 0.529 934.80 S 60 29 22 E 0.327 1058.03 S 60 11 S7 E 0.058 1193.86 S S9 S6 S6 E : 0.IS2 1325.01 S S9 48 20 E 0.2~4 1451.37 S S9 44 7 E iS78_84 S S9 38 8 E 1702.83 S S9 30 S9 E :[834.27 S S9 24 28 E 1963.17 S 59 16 57 E 0.215 O. S28 O. 160 I. 026 0.906 2101.54 S S9 7 S6 E 223~.70 S 58 58 31 E 2366.49 S 58 48 34 E 2492_86 S S8 38 29 E 2620.21 S 58 27 51E O. 524 0. 685 0. 365 2741.62 S S8 17 18 E 2868.96 S 58 S 52 E 2994.45 S S7 58 4 E 3129.15 S S7 S1 41 E 3259.47 S 57 44 49 E 0. 780 0. 508 C~.. O. 591 0.110 3394.54 S S7 37 4 E 3530.62 S S7 28 41 E 3658_25 S S7 20 21E 3726.56 S S7 1S I E 3773.39 S 57:11 S E 0. 588 O. 2.58 0. 747 0.82d O. 571 ENDICOTT MP! WELL 0-23 DATA INTERPOLATED FOR EVEN lO0 FEET OF SUBSEA DEPTH 4-22-87 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 58 58 0 0 0 1S6 158 lO0 0 0 256 258 200 0 0 356 358. 300 0 0 466 458 400 0 0 SS8 SS8 SOO 0 0 658 858 600 0 0 758 758 700 0 0 858 858 800 0 0 958 958 900 0 0 1058 iOS8 lO00 0 0 liS8 llS8 llO0 0 0 1256 1258 1200 0 0 1458 1458 1400 0 0 ISS8 1SS8 ISO0 0 0 1658 ISS8 1600 0 0 1758 1758 1700 0 0 1858 1858 1800 0 0 1958 195~ 1900 0 0 2056 2058 2000 0 0 2158 2iS8 2100 0 0 2256 2258 2200 0 0 2358 2358 2300 0 0 2456 245~ 2400 0 0 2558 2558 2500 0 0 -2656 2858 2600 0 0 2756 2756 2700 0 0 2856 2858 2800 0 0 2958 2958 2900 0 0 RELATIVE COORDINATES FROM WELL-HEAD 0.02 N O.O1 W 0.09 N O. 18 W O. 07 S 0.49 W 0.37 S 0.87 W 0.68 S 1.38 W 1.14 S 1.96 W 1.79 S 2.52 W 2.58 S 2.92 W 3.40 S 3.14 W 4.27 S 3.18 W S.02 S 2.92 W S.39 S 2.39 W S.80 S 4.27 W S.74 S 4.~8 W S.98 S 5.04 W S.22 S S.SO W S.IO S S.92 W S.iO S 8.35 W S_22 S 6.77 W 3.59 S 8.01 W 3.20 S 8.19 W o 91 S 8 SI W ~.- . . 2.76 S 6.92 W °825 4 30 W c... 2.20 S 3.60 W 1.03 S 3.28 W O. 14 N 2.72 W 1.82 N 2_80 W 3.66 N 3.94 W 0.31 N 3.31 E ENDICOTT MPI WELL 0-23 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 4-22-87 MEAS. DEPTH 30S6 3156 32S6 33S6 34S8 3SS6 36S6 3756 38S6 39S6 40S6 41S6 42S6 43S6 44S6 4SS6 4~S6 48S5 49S7 SOS7 SIS8 S260 S363 S467 SS73 S790 S~03 6018 TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DIFF. CORRECT 30S5 3000 0 0 31S6 3100 0 0 32S6 3200 0 0 33S6 33OO 0 0 34S6 3400 0 0 3SS6 3S00 0 0 36S6 3600 0 0 37S6 3700 0 0 38S6 3800 0 0 39S5 3900 '0 0 40S~ 4000 0 0 41S6 4100 0 0 42S6 4200 0 0 43S5 4300 0 0 44S6 4400 0 0 4SS6 4S00 46S6 4600 47S6 4700 48S6 4800 49S6 4900 SOS6 SO00 1 0 SiS6 SIOO 2 1 S2S6 S200 4 2 S3S6 S300 7 3 54S6 S400 11 4 SSS6 SSO0 17 6 S6S5 S600 24 7 S7S5 S700 34 10 S8S6 S800 47 13 S9S6 S900 62 1S RELATIVE COORDINATES FROM WELL-HEAD 0.38 S S.74 E 0.38 S 8.03 E S.86 S 6.S6 E 7.8l S 7.55 E 9.63 S .g. I6 E 11.22 S 10.9S E 12.60 S 12.7S E 14.72 S ' 13.68 E 16.23 S 14.88 E 17.41 S 16.00 E 18.28 S 16.99 E 19.11S 17.96 E 19.9S S 18.97 E 20.82 S ~°O.OS E °1 62 S 21 13 E ~ . 22.32 S 22_20 E 22.93 S 23.27 E 23_47 S 24.37 E 24.60 S 2S.78 E 26.40 S 30.00 E 29.02 S 38.SS E 3S.2S S S1.37 E 41.91S 69.36 E SI.SS S 91.03 E 62.46 S 117.20 E 7S.73 S 148.44 E 92.64 S 184.69 E 111.32 S 225.2S E 13S.33 S 271.33 E 1~0.~3 S 323.40 E ENDICOTT MPI WELL 0-23 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 4-22-87 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 6140 6400 6337 7091 7229 7366 7503 7639 777~ 7908 8042 8178 8316 8456 8597 8738 8877 9014 9284 9417 9814 10093 6056 6000 84 22 6156 6100 109 25 6256 6200 144 35 6356 6300 181 37 6456 6400 221 40 6556 6500 259 38 66S6 6600 298 39 6756 6700 335 37 6856 6800 373 38 6956 6900 410 37 7056 7000 447 37 7156 7100 483 36 7258 7200 518 35 7356 7300 SS2 34 7456 7400 586 34 7556 7500 622 36 7656 7600 660 38 7756 7700 700 40 7856 7800 741 41 7956 7900 782 41 8056 8000 821 39 8156 8100 858 37 8256 8800 894 36 8356 8300 928 34 8456 8400 961 33 8556 8500 993 32 8656 8600 1024 31 8756 8700 1058 34 8856 8800 1095 37 8956 8900 1137 42 RELATIVE COORDINATES FROM WELL-HEAD 195.70 S 381.86 E 234.31S 448.26 E 280.47 S 525.15 E 329.42 S 606.71 E 377.92 S 690.80 E 432.98 S 769.86 E 483.69 S 850.69 E S34.02 S 931.22 E S84.05 S 1011.30 E 633.50 S 1091.0I E 681.78 S 729.44 S 775.78 S 823.90 S 870.91S 1170.84 E 1250.15 E 1328.87 E 1403.55 E 1478.78 E 919.20 S 969. S2 S 1023.62 S 1077_ 97 S 1131. IS S 1556.08 E 1637.20 E 1719.79 E 1803.49 E 1886.53 E 1186.23 S 1239.07 S 1289.69 S 1342.49 S 1392.68 S 1966.08 E 2044.49 E 2121.12 E 2193.31 E 2265_ 17 E 1442.59 S 1492.46 S 1544.09 S 1597.86 S 1653.44 S 2334.34 E 2402.98 E 2474.60 E 2552.84 E 2636.82 E ENDICOTT MPI WELL 0-23 DATA INTERPOLATED FOR EVEN I00 FEET OF SUBSEA DEPTH 4-22-87 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 10237 10379 10521 10562 10801 9056 9000 1181 44 9156 9100 1223 42 9256 9200 1265 42 9356 9300 1306 41 9456 9400 1345 39 RELATIVE COORDINATES FROM WELL-HEAD 1713.74 S 1772.28 S 1831.45 S 1889.50 S 1945.84 S 2719.83 E 2803.80 E 2885.17 E 29~5.07 E 3043.39 E 10938 9558 9500 1382 37 2002.~ S 3118.01 E ENDICOTT NPI WELL 0-23 DATA INTERPOLATED FOR EVEN 1000 FEET OF MEASURED DEPTH 4'22-87 MEAS. TRU VERT' SUB SEA DEPTH DEPTH DEPTH RELATIVE COORDINATES FROM WELL-HEAD 1000 1000 944 4.83 S 3.11 W 2000 2000 1944 3.41S 6.07 W 3000 3000 2944 0.08 S 4.38 E 4000 4000 3944 17.82 S 18.45 E 5000 4999 4943 27.47 S 33.08 E 8000 S941 S885 158.54 S 314.78 E 7000 8690 6634 SO0.&S S 877.82 E 8000 7425 7389 858.12 S 1455.11E 9000 8145 8089 1233.59 S 2038.32 E 10000 8890 8834 1818.91 S 2581.38 E 11000 9602 9548 2028.81 S 3150.83 E ~0 ~0 t800 2700 ~000 R~k~ I~e~tlflcatlo~ ~ ~ Last Survey Recomie~ 10969 9b'79 HORIZONTAL VIE~ STANDARD ALASKA PRODUCTION CO. ENDICOTT HPI WELL 0-23 CLOSURE: 3773 fi: S 57.2 E DECLINATION: 3i.50 deg E SCALE: ! inch - 600 feel: DRAWN: 4-22-87 300 0 300 600 900 i200 i500 i800 2i00 2400 ~700 3000 3300 iiO0 t650 330O 385O 4400 D 4~0 5ffO0 6O9O 6600 7i50 7700 88OO 99OO -~-~0 VERTICAL SECTION A ._ STANDARD ALASKA PRODUCTION CO. ENDICOTT HPI NELL 0-23 , , ,,, ,, SECTION AT S 54.30 E TVD SCALE: i inch = tt00 feet ,, ,, ,, DEP SCALE' t inch = tt00 feet DRAWN ' 4-;22-87 , I#~ke~ I~enttficmtt~n 14D ~ I]8:RT ~J trot survey Recoe~ed ?.9t ~gt -0 ....... B{ Last Sm, vey RecoP~eO t0961{ 9579 3722 , ,,, , , ,, , ,, ...... ......... , ....... ,, , , , , , ,, .... ,,, 0 550 !!00 !650 2200 2750 3300 3850 4400 4950 5500 60§0 Departure $ UB-$ URFA CE DIRECTIONAL SURVEY I'~'i UIDANCE r~-! ONTINUOUS ~-~ OOL' Company STANDARD ALASKA PRODUCTION COMPANY Well Name 1-41/0-23 MPI(2121' SNL,2153' WEL,SEC 36~T12N~R16E) Field/Location ENDICOTT, NORTH SLOPEr ALASKA , Job Reference No. 72293 Log{3ed IByj, SALAZAR Date 1 -MAY-87 Computed By: KRUWELL GCT DIRECTIONAL SURVEY CDSTOMER LISTING FOR STANDARD ALASK~ PRODUCTION CO. ~-41/0-23 MPI ENDIC6TT NORTH SL£PE~ALASKA · SURVEY DATE: 01-MAY-87 ENGINEER: SALAZAR METHODS OF COMPUTATION TOOL LOC~TION: I'ANGENTZAL- AVEkAGED DEVIATION ~hO AZIMUTH iNTERPOLATION: LINEAR VERTICAL SECTION: HORIZo DI~T. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 5~ DEG ~0 MIN EAST COMPUTATION DATE: 6-MA¥-87 PAGE STANDARD ALASKA PRODUCTION CO. 1-41/0-23 MPI ENDICOTT NORTH SLOPEsALASKA DATE DF SURVEY: OI-MAY-87 KELLY BUSHING ELEVATION: 55.25 FT ENGINEER: SALAZAR INTERPOLATED VALUES'FOR EVEN lO0 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPIH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR CDORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/S~UTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -55.25 0 0 N 0 0 E 100.00 100.00 44.75 0 28 S 11 55 E 200.00 200.00 144.75 0 13 S 21 41 W 300.00 300.00 244.75 0 12 S 9 59 E ~400,00 400,00 344.75 0 8 S 24 43 W ~-~00,00 500.00 444,75 0 13 S 25 29 W ~00,00 599,99 ~44,'74 0 16 S 3 32 W 700.00 699.99 644.74 0 8 S 14 12 E aO0.O0 799.99 744.74 0 10 S 33 41 W ~00.00 899.99 844.74 0 18 S 0 21 E 0.00 0,00 0.00 N 0.00 E 0.24 0.10 0.31 S 0.07 E 0.57 0,19 0,81 S 0'12 E 0.78 0,15 1.25 S 0,07 E 0,94 0,13 1,53 S 0,06 E 0,97 0,08 1,80 S 0,09 W 1,10 0.22 2,22 S 0,23 W 1.38 0,27 2,60 S 0,16 W 1.42 0,28 2.80 S 0.25 W 1.58 0.29 3.25 S 0.38 W 0.00 N 0 0 E 0.32 S 12 37 E 0.82 S 8 41 E 1.25 S 3 8 E 1.53 S 2 22 E 1.80 S 2 52 W 2.23 S 5 54 W 2.60 S 3 30 ~ 2,81 S 5 0 W 3.28 S 6 35 W 1000.00 999.99 944.74 1100.00 1099.95 1044.74 1ZO0.O0 1199.99 1144.74 1300.00 1299.99 1244.74 1400.00 1399.99 13~4.74 1500,00 1499.99 1444.74 1600,00 1599.99 1544.74 1700.00 1699.98 1644.73 1800~00 1799.98 17~4.73 1900.00 1899.98 1844.73 0 8 S 25 52 E 0 8 S 30 16 W 0 14 S 33 13 W 0 19 S 20 54 W 0 20 S 12 4 W 015 S 6 39 W 0 8 S 1 10 E 0 6 S 22 28 W 0 8 S 76 1t~ w 0 10 N 89 49 W 1.92 0.36 3,68 S 0.26 W 2.02 0.09 3,8'7 S 0,28 W 2,04 0,17 4,17 S 0.47 W 2,13 0,14 4,65 S 0,70 W 2.34 0.10 5.22 S 0.85 W 2.56 0,16 5.75 S 0,95 W 2.74 0.06 6.10 S 0,99 W 2.86 0.22 6.30 S 0.99 W 2.80 0,15 6,40 S 1,13 W 2..60 0,34 6.43 S 1.39 W 3,69 S 4 6 W 3,88 S 4 7 N 4,20 .S 6 27 W 4,70 S 8 30 W 5,29 S 9 13 W 5.83 S 9 24 ~ 6.18 S 9, 10 W 6.38 S 8 54 W 6.50 S 10 0 W 6.58 S 12 13 N' 2000.00 1999.98 1944.7~ 2100,00 2099,9~ 2044,73 2200.00 2199.98 2144.7~ 2300.00 2299.98 2244.7~ 2400.002399.982344.73 013 N 71 6 W 0 7 N 37 37 W 0 13 N 22 19 E 0 29 N 54 5 E 0 42 N 55 37 E 0 37 N 52 13 E 0 38 N 56 18 E 1 4 N 74 18 E 1 20 S 82 55 E 1 31 S 68 29 E 2.22 0,08 6,33 S 1,79 W 1,92 0,22 6,16 S 2,04 W 1,77 0,29 5,91 S 2,04 W 1,90 0,32 5,53 S 1.61 W 2.29 0.31 4.91 S 0.69 W 2.66 0.39 4.17 S 0.28 E 2.98 0,21 3,45 S 1,20 f 3.72 0.58 2.83 S 2.55 E 5.37 0.34 2.72 S 4.65 E 7.74 0.72 3.38 S 7.09 E 6.58 S 15 47 W 6.49 S 18 17 W 6.25 S 19 0 W 5.76 S 16 13 N 4.96 S 7 59 W 4'18 S 3 54 E 3.65 S 19 9 E 3.81 S 4! 56 E 5.39 S 59 42 E 7.85 S 64 28 E 3000.00 2999.B7 2944.62 3100.00 3099.84 3044.59 3200.00 3199.82 3144.57 3300.00 3299.80 3244.55 3400.00 3399.77 3344.52 3500.00 3499.74 3444.49 3600.00 3599.71 3544.46 3700.00 3699.6~ 3644.43 3800.00 3799.66 3744.41 3900.00 3899.64 3844.39 1 17 S 56 20 E 1 I0 S 48 3 E 1 8 S 42 33 E 1 15 S 45 46 E I 25 S 40 38 E 1 29 S 40 10 E 1 19 S 44 6 E 1 24 S 44 25 r- i 14 S 35 34 E 0 57 S 43 52 E 10.13 0.75 4.58 S 9.18 12.32 0.75 5.86 S 10.95 14.31 0.58 7.28 S 12.38 16,29 0.09 8.74 S 13.77 18.55 0.26 10.41 S 15.~6 21.06 0.17 12,38 S 17,05 23.53 0.23 14.32 S 18.69 25.82 0.78 15.93 S 20.36 28.06 0.34 17.75 S 21.80 29.86 0.18 19.21 S 22.98 10.26 S 63 29 E 12.42 S 61 50 E 14.36 S 59 3~ E 16.31 S 57 35 E 18.56 S 55 52 E 21.07 S 54 I E 23.54 S 52 32 E 25.85 S 51 57 E 28.11 S 50 50 E 29.95 S 50 6 E STANDARD ALASKA PRODUCTION CO. 1-41/0-23 MPI ENDICOTT NORTH SLOPE~ALASKA COMPUTATION O~TE: 6-MA¥-87 PAGE 2 DATE OF SURVEY: OI-MAY-87 KELLY BUSHING ELEVATION: 55.25 FT ENGINEER: SALAZAR INTERPOLATED VALUES FOR EVEN 100 FEET GF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUIH DEPTH DEPTH DEPTH DEG MIN DEG MiN VER~TICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTICN SEVERITY NORTH/SOUTH EAST/WEST CIST. AZIMUTH FkET DEG/iO0 FEET FEET FEET DEG MIN 4000.00 3999,62 3944.37 4100,00 4099,61 4044,36 4200,00 4199,60 4144,35 4300,00 4299,60 4244,35 _~00.00 ~399.5~ 4344.33 00.00 4499.58 4444.33 00.00 4599,57 4544.32 4700.00 4699.56 4644.31 4800,00 4799,55 4744,30 4900,00 4899,51 4844,26 0 56 S 41 7 E 0 49 S 40 15 E 0 41 S 51 19 E 0 46 S 57 36 E 0 45 S 43 35 E 0 47 S 46 19 E 0 35 S 50 5i E 0 48 S 51 59 E 0 56 S 51 32 E 2 19 S 63 5 E 31.43 0.08 20.33 S 24.11 E 32.90 0.09 21.49 S 25.08 E 34.22 0,56 22.52 S 25.97 E 35.~3 0.72 23.20 S 26.97 E 36.85 0.40 24.17 S 28.02 E 38.23 0.36 25.17 S 29.01 E 39.37 0.28 25.92 S 29.88 E 40.60 0.24 26.59 S 30.91 E 42.02 0.69 27.53 S 31.97 E 44.57 3.11 28.95 S 34.09 E 31.54 S 49 51 E 33.03 S 49 24 E 34.37 S 49 3 E 35.58 S 49 18 E 37.0,1 S 49 13 E 38.41 S 49 3 E 39.55 S 49 3 E 40.77 S 49 17 E 42.19 S 49 15 E 44.73 S 49 39 E 5000,00 4999,31 4944,06 5 0 5100,00 . 5098,65 5043,40 7 59 5200.00 5197.31 5142.06 10 42 5300.00 5295.15 5239.90 12 58 5400.00 5392.13 5336.88 15 17 5500.00 5487.89 5432.64 18 7 5600.00 5582.17 5526.92 20 42 5700.00 5674,94 5619.69 23 7 5800;00 5765.96 5710.71 25 45 5900.00 5854.99 5799.74 28 25 S 72 15 E 50.71 3.23 S 69 14 E 61.57 3.19 S 69 48 E 77.25 2.71 S 67 1 E 97.26 2.43 S 66 37 E 121.12 2.69 S 66 24 E 149.27 2.75 S 65 18 E 181.92 2.49 S 64 4 E 218.62 2.55 S 62 46 E 259.50 2.51 S 61 35 E 304.61 2.69 31.10 S 40.11 E 50.75 S 52 13 E 34.80 S 50.80 E 61.58 S 55 35 E 40.51 S 65.99 E 77.43 S 58 27. E 48.03 S 85.22 E 97.82 S 60 35 E 57.83 S 107.53 E 122.09 S 61 43 E 69.23 S 133.96 E 150.80 S 62 40 E 82.82 S 164.38 E 184.07 S 63 15 E 98.77 S 198.08 E 221'34 S 63 29 E 117.30 S 235.08 E 2'62.72 S 63 28 E 138.57 S 275.33 E 308.23 S 63 17 E 6000.00 5941.67 5886.42 31 32 S 60 52 E 6100.00 6025.28 5970.03 34 53 S 60 2 E 6200.00 6105.84 6050.59 37 48 S 59 0 E 6300.00 6183.04 6127.79 41 14 S 58 6 ~ 6400. O0 6256.35 62 O1 . 10 44 4 S 57 37 E · 00.00 6327.90 6272.65 44 12' S 57 35 E ~~00.00 6399.63 6344.38 44 3 S 57 33 E 0.00 6471.49 6416.24 43 57 S 57 17 E 6800.00 6543.54 6488.29 43 53 S 57 17 E 6900.00 6615.76 6560.51 43 37 S 57 10 E 354.11 3.40 408.63 2.88 467.62 3.17 531.00 3.69 59~.88 1.74 668.64 0.14 738.21 0.34 807.66 0.63 876.92 0.45 946.02 0.51 162.59 S 318.99 E 358.04 S 62'59 E 189.58 S 366.71 E 412.81 S 62 39 E 219.62 S 417.74 E 471,95 S 62 16 E 252.82 S 471.91 E 535.36 S 61 49 E 289.03 S 529.46 E 603.21 S 61 22 E 326.48 S 588.42 E 6'72.9'3 S 60 58 E 363.84 S 647.25 E 742.50 S 60 39 E 401.23 S 705.88 E 811.94 S 60 23 E ~38.78 S 764.17 E 881.18 S 60 8 E 476.19 S 822.35 E 950.27 S 59 55 E 7000.00 6688.20 6632.95 43 40 7100.00 b760.64 6705.39 43 27 7200.00 6833.40 6778.15 43 14 7300.00 6906.i9 6850.94 4.3 13 7400.00 6979.19 6923.94 42 57 7500.00 7052.2~ 6997.0~ 42 58 7600.00 7125.73 7070.48 42 33 7700.00 7199.66 7144.41 42 16 7800.00 7273.61 7218.36 41 56 7900.00 7348.64 7293.39 41 7 S 57 12 E 1014.87 S 57 8 E 1083.74 S 57 5 E 1152.26 S 57 22 ~ 1220.76 S 57 31 ~ 1289.01 S 57 25 E 1357.16 S 57 19 E 1424.95 S 57 9 f 1492.20 S 57 1Z E I559.44 S 57 2 E 1625.48 0.52 0.52 0.21 0.56 0.38 0.99 0.94 0.16 1.47 0.70 513.58 S 880.26 E 1019.13 S 59 44 E 550.93 S 938.22 E 1088.01 S 59 34 E 588.16 S 995.82 E 1156.55 S 59 25 E 625.35 S 1053.44 E 1225.07 S 59 18 E 662.08 S 1111.06 E 1293.37 S 59 12 E 698.76 S 1168.61 E 1361.59 S 59 7 E 735.34 S 1225.79 i 1429.43 S 59 2 E 771.78 S 1282.41 E 1-496.73 ~ 58 57 E 808.25 S 1338.99 E 1564.02 S 58 53 E 844.16 S 1394.49 E 1630.10 S 58 48 E STANDARD ALASKA PRODUCTION CO. 1-41/0-23 MPI ENOICOTT NORTH SLOPE,ALASKA COMPUTATION DATE: 6-MAY-87 PAGE 3 DATE OF SURVEY: 01-NAY-8? KELLY BUSHING ELEVATION: 55.25 FT ENGINEER: SALAZAR INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTM DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL ~OGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG'MIN 8000.00 7423.80 7368.55 41 21 8100.00 7498.66 7443.41 42 0 8200.00 7572.31 7517.06 43 2 8300.001644.647589.394358 ~00.00 7716.01 7660.76 44 5, .00.00 7786.43 7731.18 45 11 00.00 7857.13 7801.88 44 51 8700.00 7928.12 7872.87 44 25 8800.00 7999.81 7944.56 44 7 ~900.00 8071.77 8016.52 43 33 9000.00 8144.62 8089.37 43 2 9100.00 8218.16 6162.91 42 19 9200.00 8292.29 8237.04 41 54 9300.00 8367.01 8311.76 41 27 9400.00 8442.25 8387.00 40 53 9500.00 8518.07 8462.82 40 19 9600.00 8594.84 8539.59 39 32 9700.00 8671.62 8616.37 40 38 9800.00 8746.29 8691.04 42 42 9900.00 8618.70 $763.45 44 27 10000.008889.288834.034534 10100.008959.138903.88'*545 10200.00 '~028.97 8973.72 45 32 10300.009098.719043.46460 10400.00 9168.40 9113.15 45 31 11000.00 9600.54 9545.29 41 59 11100.00 9675.19 9619.$4 41 7 11200.00 9751.49 9696.24 39 36 11300.00 9829.26 9774.01 38 8 11400.00 9908.87 9853.62 36 26 11500.00 9990.54 9935.29 33. 36 11600.00 10074.94 10019.69 31 28 11700.00 10160.82 10105.57 30 5 11800.00 10248.32 10193.07 28 11 11900.00 10336.35 10281.10 28 20 S 57 10 E 1691.38 S 57 10 E 1757.60 S 56 33 E 1825.18 S 56 4 E '1894.20 S 5~ 44 E 1964.22 S 55 45 E 2035.20 5 55 42 ~ 2105.91 S 55 40 E 2176.32 S b5 11 E 2246.03 S 55 6 E 2315.46 S 54 37 E 2383.98 S 54 18 E 2451.73 S 54 15 E 2518.85 S 54 2 E 2585.31 S 53 52 E 265.1.18 S 53 42 E 2716.36 S 53 50 E 2780.44 S 54 1 E 2844.51 S 54 22 E 2911.00 S 54 32 E 2979.96 $ 54 15 E 3050.82 S 53 50 E 31'22.38 S 53 14 E 3193.92 S 52 52 E 3265.57 S 52 34 E 3337.26 S 52 11 E 3408.12 S 52 10 E 3478.38 S 52 15 E 3548.29 S 51 27 E 3617.49 S 50 55 ~ 3685~65 S 50 22 E 3752.86 S 48 43 E 3819.13 S 48 32 E 3883.44 S 48 36 E 3945.98 S 47 43 E 4006.12 S 4b 26 E 4063.34 S 45 30 E 4116.32 S 45 29 E 4166.92 S 45 48 E 4214.78 S 45 53 E 4261.67 0.76 1.92 1.63 0.80 1.15 0.33 0.39 1.10 0.42 1.23 0.69 0.53 0.56 0.52 0.63 1.07 0.38 2.04 1.84 1.10 0.71 0.47 0.58 0.41 0.75 0.30 0.64 2.95 1.22 1.24 1.13 1.89 1.28 1.98 1.59 3.11 1.72 2.41 1.41 0.00 879.94 S 1449.91 E 1696.04 S 58 44 E 915.78 S 1505.69 E 1762.31 S 58 41 E 952.79 S 1562.31 E 1829.92 5 58 37 E 991,06 S 1619.77 E 1898.91 S 58 32 E 1030.34 S 1677.77 E 1968.89 $ 58 26 E 1070.32 S 1736.44 E 2039.81 $ 58 21 E 1110.07 S 1794.94 E 2110.46 S 58 15 E 1149.77 S 1853.12 E 2180,83 S 58 10 E 1189.30 S. 1910.53 E 2250.46 S 58 5 E 1229.04 S 1967.48 E 2319.81 S 58 0 E 1268.48 S 2023.51E 2388.22 S 57 55 E 1307.81 S 2078.68 E 2455.87 S 57 49 E 1347.10 S 2133.09 E 2522.85 S 57 43 E 1385.92 S 2187.04 E 2589-19 S 57 38 E 1424.71 S 2240.28 E 2654.93 S 57 32 E 1463.30 S 2292.82 E 2719.98 S 57 27 E 1501.19 S 2344.51 E 2783'93 S 57 22 E 1538.87 S 2396.31E 2847.89 S 57 17 E 1577.77 S 2450.25 E 2914.29 S 57 13 E 1617.81 S 2506.39 E 2983.17 S 57 9 E 1658.95 S 2564.08 E 3053.96 S 57 5 E 1700.93 S 2622.04 E 3125.42 S 57 1 E 1743.45 S 2679.59 E 3196.85 S 56 57 E 1786.53 S 2736.86 E 3268.35 S 56 51 E 1829.95 S 2793.96 E 3339.90 S 56 46 E 1873.21 S 2850.13 E 3410.60 S 56 41 E 1916.30 S 2905.70 E 3480.70 S 56 35 E 1959.19 S 2960.98 E 3550.47 S 56 30 E 2002.05 S 3015.41 E 3619.51 S 56 25 E 2044.88 S 3068.58 E 3687.51 S 56 19 E 2087.61 S 3120.66 E 3754.55 S 56 13 E 2130.70 S 3171.33 E 3820.63 S 56 6 E 2173.47 S 3219.82 E 3884.74 S 55 58 E 2215.01 S 3267.00 E 3947.09 S 55 51 E 2255.34 S 3312.10 E 4007.07 S 55 44 E 2294.51 S 3354.44 E 4064.12 S 55 37 E 2331.85 S 3392.90 E 4116.95 S 55 30 E 2367.78 S 3429.43 E 4167.41 S 55 22 E 2401.60 S 3464.09 E 4215.16 S 55 16 E 2434.62 S 3498.13 E 4261.96 S 55 9 E STANDARD ALASKA PRODUCTION CO. 1-41/0-23 MPI ENDICOTT NORTH SLOPE~ALASKA COMPUTATION DATE: 6-MAY-87 PAGE 4 DATE DF SURVEY: 01-MAY-87 KELLY BUSHING ELEVATION: 55.25 FT ENGINEER: SALAZAR INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SU6-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL ~OGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTI£N SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 12000.00 10424.36 10369.11 28 20 12100.00 10512.37 10457.12 28 20 12180.00 10582.79 10527.54 28 20 S 45 53 E 430~.61 S 45 53 E 4355.55 S 45 53 E 4393.10 0.00 0.00 0.00 2467.66 S 3532.21 E 4308.82 S 55 3 E 2500.71 S 3566.30 E 4355.69 S 54 57 E 2527.14 S 3593.57 E 4393.20 S 54 53 E COMPUTATION DATE: 6-MAY-87 PAGE 5 STANDARD ALASKA PRODUCTION C0. 1-41/0-23 MPI ENDICOTT NORTH SLOPE~ALASKA DATE OF SURVEY: 01-MAY-87 KELLY BUSHING ELEVATION: 55.25 FT ENGINEER: SALAZAR INTERPOLATED VALUES FOR EVEN 1000 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE MEASUREO VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH BEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NDRTH/SQOTH E~ST/WEST DIST. AZIMUTH F~ET CEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -55.25 0 0 1000,00 999.99 944.74 0 8 2000.00 1999.98 1944.73 0 13 3000.00 2999.87 2944.62 1 17 )00 O0 3~99.62 3944.37 0 56 00:00 4999.31 4944.06 5 0 00.00 5941.67 5886.42 31 32 7000.00 6688.20 6632.95 43 40 8000.00 '7423.~0 7368.55 41 21 9000.00 8144.62 8089.37 43 2 N 0 0 E 0.00 S 25 52 E 1.92 N 71 6 W 2.22 S 56 20 E 10.13 S 41 7 E 31.43 S 72 15 E 50,71 S 60 52 E 354.11 S 57 12 E 1014.87 S 57 10 E ~691.36 S 54 37 E 2383.98 0.00 0.36 0.08 0.75 0.08 3.23 3.40 0.52 0.76 0.69 0.00 N 0.00 E 0.00 N 0 0 E 3.68 S 0.26 ~ 3.69 S 4 6 W 6.33 S 1.79 W 6.58 S 15 47 W 4.58 S 9.18 E 10,26 S 63 29 E 20.33 S 24.11 E 31.54 S 49 51E 31.10 S 40.11E 50.75 S 52 13 E 162.59 S 318.99 E 358.04 S 62 59 E 513.58 S 880.26 E 1019.13 S 59 44 E 879.94 S 1449.91 E 1696.04 S 58 44 E 1268.48 S 2023.51 E 2388.22 S 57 55 E 10000.00 8889.28 8834.03 45 34 11000.00 9600.54 9545.29 41 59 1ZO00.O0 10424.36 10369.11 28 20 12180.00 10582.79 10527.54 28 20 S 54 15 E 3050.82 S 50 22 E 3752.86 S 45 53 E 4308.61 S 45 53 E 4393.10 0.71 1.13 0.00 0.00 1658.95 S 2564.08 E 3053.96 S 57 5 E 2087.61 S' 3120.66 E 3754.55 S 56 13 E 2467.66 S 3532.21 E 4308.82 S 55. 3 E 2527.14 S 3593.57 E 4393.20 S 54 53 E STANDARD ALASKA PRODUCTION CC. 1-41/0-23 MPI ENDICOTT NORTH SLOPE,ALASKA COMPUTATION DATE: 6-MA¥-87 PAGE 6 DATE OF SURVEY: 01-MAY-87 KELLY BUSHING ELEVATION: 55,25 FT ENGINEER: SALAZAR INTERPOLATED VALUES, FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN 0,00 O,OO -55,25 '0 0 N 0 0 E 55,25 55,25 0,00 0 14 S 24 44 E 155,25 155,25 100,00 0 13 S ~ 34 E 255,25 255,25 200,00 0 17 S 4 13 W 355.2~ 355.25 300.00 0 9 S 1 56 W .~55.25 455.25 qO0.O0 0 11 S 30 48 W 55,~6 555,25 500.00 0 15 S 19 46 W 655,26 655,25 600,00 0 12 S 14 57 e 755.20 755.25 700.00 0 7 S 31 48 W 855.26 855.25 ~00.00 0 17 S 14 45 W 955.26 955.25 900.00 1055.26 · 1055.25 1000.00 1155.26 1155.25 1100.00 1255.26 1255.25 1200.00 1355.26 1355.25 1300.00 1455.26 1455.25 1400.00 1555.26 1555.25 1500.OO 1655.26 lb55,25 1600.00 1755',27 1755,25 I700,00 1855,27 1855,25 1800,00 0 15 S 16 49 E 0 6 S 5 41W 0 13 S 33 41 W 0 18 S 22 7 W 0 20 S 13~ 32 W 0 19 S 12 28 W 0 11 S 6 41 W 0 6 S 6 25 E 0 5 S 60 2 W 0 9 S 87 21 W 1955.27 1955.25 1900.C0 2055.2? 2055.25 2000.00 2155,27 2155,25 2100,00 2255,27 2255,25 2200,00 2355,27 2355,25 2300,00 ~!5.28 2455,25 2400.00 5,29 2555,25 2500,00 5.302655.252600.00 2755.31 2755.Z5 2700.00 2855.34 2855.25 2800.00 2955.37 2955.25 2900.00 3055.40 3055.25 3000.00 3155.42 3155.25 3100.00 3255,4~ 3255,25 3200.00 3355.45 3355.25 3300.00 3455.49 3455.25 3400.00 3555.53 3555.25 3500.00 3655.56 3655.25 3600.00 3755.58 3755.25 3700.00 3855.61 3855.25 3800.00 0 15 N 72 57 W 0 9 N 47 21 k 0 9 N 4345 0 20 N 51 39 E 0 259 N 57 46 E 0 43 N 52 33 E 041 N 51 1E 0 54 N 64 44 E 1 13 N 87 30 E i 27 S 73 42 E 1 23 .S 5? 36 h 1 16 S 55 27 E 1 9 S 45 35 E 1 6 S 43 26 E 1 19 S 43 45 E 1 29 S 40 17 E 1 28 S 39 7 E 1 20 S 46 16 E I I9 S 37 6 E 1 2 S 41 26[- VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, OEPARTURE SECTICN SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET CEG/iO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 0.01 1.08 0.01 S 0.01 0.50 0.30 0.66 S 0.14 0,65 0,2b 1,05 S 0,05 0,90 0,18 1,42 S 0,09 0,95 0,09 1,66 S 0,01 1,02 0,10 2,02 S 0,18 1,26 0,09 2,45 .S 0,20 1.42 0.08 2.70 S 0.18 1.47 0.16 3.02 S 0.34 0.00 N 0 0 E 0.01 S 30 15 E 0.67 S 12 .1.6 E 1.05 S 2 57 E 1.42 S 3 36 E 1.66 S 0 29 N 2,03 S 5 7 W 2,46 S 4 42 W 2.71 S 3 52 W 3.04 S 6 27 N 1.78 0.16 3.52 S 0.33 W 2.01 0.25 3.78 S 0.24 W 2.03 0.18 4.02 S 0.37 W 2.08 0.14 4.42 $ 0.60 W 2.25 0.06 4.96 S 0.78 W 2.47 0.14 5.54 S 0.91 W 2.67 0.19 5.97 S 0.98 W 2,82 0.09 6.23 S 0.98 W 2.85 0.20 6.37 S 1.05 W 2.69 0.11 6.42 S 1.28 W 3.54 S 5 16 W 3.79 S 3 33 W 4.04 S 5 17 W 4.46 S 7 41 N 5.02 S 8 56 W 5'61 S 9 Z1 W 6,06 S 9 20 W 6.31 S 8 58 N 6.46 S 9 20 W 6.55 S 11 15 W 2.40 0.14 6.39 S 1.61 W 2.03 0.29 6.24 S 1.97 W 1.83 0.32 6.06 S 2.07 W 1.80 0.35 5.71 S 1.87 W 2.09 0.21 5,22 S 1.15 W 2,50 0,27 4.49 S 0,13 W 2,82 0,22 3,76 S 0,78 E 3.29 0.66 3.11 S 1.82 E 4.51 0.68 2.66 S 3.64 E 6.60 0.38 3.00 S 5.97 E 6.59 S 14 6 W 6.54 S 17 28 W 6.40 S 18 53 W 6.01 S 18 6 W 5.34 S 12 25 W 4.49 S 1 40 N 3.84 S 11 45 E 3.60 S 30 24 E 4.51 S 53 49 E 6.68 S 63 19 E 9.11 0.34 4.03 S 8.32 E 11.36 0.87 5.26 S I0.20 E 13.40 0.47 6.63 S 11.73 E 15,36 0,25 8.08 S 13.11 E 17.50 0.54 9.61 S 14.64 E 19.94 0.27 11.49 S 16.30 E 22.46 0.13 13.49 S 17.97 E 24.81 0.25 15.22 S 19.61 E 27.11 0.06 16.96 S 21.21 E 29.10 0.45 18.64 S 22.45 E 9.24 S 64 8 E 11.48 S 62 42 E 13.48 S 60 30 E 15.40 S 58 ZO E 17.51 S 56 43 E 19.94 S 54 49 E 22.47 S 53 6 E 24.83 S 52 10 E 27.15 S 51 21E 29.18 S 50 17 E STANDARD ALASKA PRODUCTION CO. 1-41/0-23 MPI ENDICOTT NORTH SLOP~sALASKA COMPUTATION DATE: 6-MAY-87 PAGE DATE OF SURVEY: 01-MAY-87 KELLY eUSHING ELEVATION: 55.25 FT ENGINEER: SALAZAR INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUb SUB-SEA COURSE MEASURED VERTICAL ~ERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN 3955.6z 3955.25 39oo.oo 4055.63 4o55.zs 4000.00 4155.64 4155.25 4100.0'0 4255.6~ ~zss.z~ 4200.00 .:!r~55'66 4~55' Z5 4300000 SS'aT 4455'25 44OO'OO 55'6~ 4555'25 450O'OO 4655'69 4655'Z5 46O0'OO 0 53 S 47 14 E 0 51 S 39 39 E 0 48 S 39 52 E 0 41 S 56 17 E 0 50 S 45 24 E 0 49 S 44 18 E 0 38 S 49 37 E 0 45 S 61 ,2 E S 45 58 E S 56 7 E 4755.69 4755.25 4700'00 '0 46 4855.71 4855.25 4800.00 1 31 VERTICAL GOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4955.82 4~55.25 4900.00 3 47 S 71 16 E 5056.24 5055.25 5000.00 6 37 S 70 59 E 5157,27 5155.25 5100.00 9 29 S 69 24 E 5259.12 5255.25 5200.00 12 7 S 68 28 E 5361.86 5355.25 5300.00 14 23 S 66 9 E 5465,75 5455.25 5400.00 17 11 S 66 36 E 5571.2~ 5555.25 5500.00 20 0 S 65 42 E 5678.62 5655.25 5600.00 22 34 S 64 20 E 5788~12 5755.25 5700.00 25 27 S 62 55 E 5900.30 5855.25 5800.00 28 25 S 61 34 E 6015,96 5955.25 5900.00 32 4 S 60 45 E 6136,76 6055.25 6000.00 35 55 S 59 39 E 6263,42 6155,25 6100.00 39 53 S 58 22 E 6398.47 6255.25 6200.00 44 3 S 57 37 E 6538,17 b355,25 ~300.00 ~4 12 S 57 35 E ~77,42 6455.25 6400.00 44 '2 S 57 23 E ~16,26 6555.25 6500.-00 43 48 S 57 17 E ~54.48 b555,25 0600.00 43 33 S 57 8 E 7092,56 6755,25 6700.00 43 28 7229.99 6655.25 6800.00 43 17 30.74 0.37 19.82 S 23.62 E 32.27 0.09 20.99 S 24.66 E 33.65 0.05 22.09 S 25.57 E 34.90 0.04 22.91 S 26.52 E 36,25 0.28 23.73 S 27.60 E 37.62 0.20 24.73 S 28.57 E 38.90 0.74 25.63 S 29.50 E 39,98 0.61 26.24 S 30,39 E 41,37 0,67 27.10 S 31,49 E 43.12 2.11 28,19 S 362,43 429,82 507,26 597.81 695.22 791,99 888.19 953.51 S 57 8 E 1078.62 S 57 6 E 1172.79 -, 7367,26 6955,25 bgo0,o0 43 4 7504,05 7055.25 7000.00 42 55 7639,97 7155,25 7100.00 42 18 7775.26 7255.25 7200.00 42 17 7908.77 7355.25 7300.00 41 7 8041,97 7455.25 7400.00 41 28 8176.74 7555.25 '7500.00 42 46 8314.76 7655.25 7600.00 44 7 8455.70 7755.25 7700.00 45 16 8597,34 7855,25 7~00.00 44 51 S 57 30 E 1266,70 S 57 25 E ' 1359.92 S 57 15 E 1451.86 S 57 15 E 1542,89 S 57 2 E 1631.23 S 57 18 E 1719.13 $ 56 38 E 1809.39 S 56 0 E 1904.47 S 55 45 E 2003.75 S 55 43 E 2104,03 47.52 2.07 56.21 3.08 70.00 2,80 88.65 1,95 111.61 2.19 139,11 2.75 172,08 2.52 210.42 2.74 254.42 2.70 304.75 2.70 3.33 3.01 3.63 1.80 0.26 0.61 0,64 0,15 0,39 0,40 0.43 1.15 0.31 1.61 0,67 0.40 0.85 1.05 0.51 0.39 3'0.83 S 50 0 E 32.39 S 49 35 E 33.80 S 49 10 E 35.05 S 49 11 E 36.40 S 49 18 E 37,79 S 49 6 E 39,08 S 49 0 E 40,15 S 49 Il E 41,55 S 49 17 E 32.85 E 43.29 S 49 22 E 30,05 S 36,94 E 47,61 S 50 52 E 32.91 S 45,57 E 56,21 S 54 10 E 37,90 S 58,95 E 70.09 S 57 15. E 44,67 S 77,02 E 89,04 S 59 53 E 53,94 S 98.62 E 112,41 S 61 19 E 65.09 S 124.44 E 140.43 S 62 23 E 78,66 S 155.27 E 174,05 S 63 7 E 95,16 S 190,59 E 213.02 S 63 28 E 114.96 S 230.51 E 257.58 S 63 29 E 138,63 S 275,45 E 308,37 S 63 17 E 166.67 S 326.30 E 366.40 S 62.56 E 200.27 S 385.11 E 434.07 S 62 31 E 240.29 S 451.68 E 511.62 S 61 59 E 288.46 S 528.55 E 602.14 S 61 22 E 340,75 S ~10,90 ~ 699,51 S 60 50 E 392'76 S 692,67 E 796,28 S 60 26 E 444.87 S 773.66 E 892.45 S 60 6 E 496.56 S 853,88 E 987,77 S 59 49 E 548,15 S 933,91 E 1082,89 S 59 35 E 599,34 S 1013.06 E 1177,07 S 59 23 E 650.09 S 1092.22 E 1271.05 S 59 14 E 700.25 S. I170.95 E 1364.36 S 59 T E ?49.90 S 1248.45 E 1456,36 S 59 0 E 799,28 S 1325,05 E 1547,45 S 58 54 E 847,30 S 1399.32 E 1635,85 S 58 48 E 894.98 S 1473,26 E 1723,80 S 58 43 E 944.09 S 1549.11 E 1814,12 S 58 38 E 996.81 S 1628.29 E 1909.18 S 58 31' E 1052.61 S 1710.44 E 2008.38 S 58 23 E 1109.01 S 1793.39 E 2108.59 S 58 16 E STANDARD ALASKA PRODUCTION CO. 1-41/0-23 MPI ENDICOTT NORTH SLOPE,ALASKA COMPUTATION DATE: 6-MA¥-87 PAGE 8 DaTE OF SURVEY: 01-MAY-87 KELLY BUSHING ELEVATION: 55.25 FT ENGINEER: SALAZAR INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZiNUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET gEG/IO0 FEET FEET FEET DEG MIN 8737.87 7955.25 7900.00 44 13 8877.16 8055.25 8000.00 43 48 9014.55 8155.25 8100.00 42 57 9150.11 8255.25 8200-00 42 11 · 284,31 ~355,25 8300,00 41 30 .::::!i 17,18 8455,25 8400,00 40 50 ~48.60 8555,25 8500,00 39 51 9678,48 8655,25 8600,00 40 13 9812,20 8755,25 8700,00 42 55 9951.51 8855,25 8800,00 45 9 10094,44 8955,25 8900,00 45 45 10237,50 9055,25 9000,00 45 41 10381,22 9155,25 9100,00 45 38 10523,06 9255,25 9200,00 44 48 10663,3~ 9355,25 9300,00 44 30 10802.29 9455,25 9400,00 43 20 10938,84 9555,25 9500,00 42 25 11073,39 9655,25 9600,00 41 30 11204;90 97.55,25 9700,00. 39 32 11332,90 9855.25 9800,00 37 31 11457,53 9955,25 9400,00 35 2 11576.84 10055.25 10000.00 31 52 11693,56 10155,25 10100,00 30 14 11807,87 10255,25 10200,00 28 14 11921.48 10355.25 10300.00 28 ZO 1~35.10 10455.25' 10400.00 28 20 : '~8,71 10555,25 10500,00 2~ 20 1~80 .00 10582.79 10527.54 2E 20 S 55 30 E '2202,75 S 55 6 d 2299,69 S 54 36 E 2393,-91 S 54 7 E 2q85,43 S 5~ 8 ~ 2574.92 S 53 45 E 2662,41 S 53 4~ E 2747,66 S 53 59 ~ 2~30,53 S 54 24 E 2919,28 S 54 32 f 3016,28 S 53 52 E 3118,40 S 53 3 ~ 3220,67 S 52 ~1 E 3323,86 S 52 11E 3424,38 S 52 1~ E 3522.69 S 51 26 E 3519.05 S 50 39 E 3711,84 S 49 9 E 3801,61 S 48 32 E 3886,56 S 48 21 E 3966,04 S 47 9 E 4039,55 S w5 38 E 4104,29 S 45 28 E 4163,74 S 45 50 E 4218,45 S 45 53 E 4271.75 S 45 53 E ~325,08 S 45 53 E 4378,41 S 45 53 k 4393,10 0,35 1,19 0,84 0,40 0,52 0,54 1,09 1,95 1,75 1.40 0.54 1.26 0.82 0.75 1.02 1.22 0.72 1.99 1.29 1.96 3.89 1.78 2.06 2.81 0.00 0.00 0.00 0.00 1164,70 S 1874,92 E 2207,23 S 58 9 E 1220,02 S 1954,54 E 2304,05 S 58 I E 1274.24 S 2031.60 E 2398.14 S 57 54 E 1327.53 S 2106.01 E 2489.50 S 57 46 E 1379.84 S 2178.62 E 2578.82 S 57 39 E 1431.35 S 2249.34 E 2666.14 S 57 31 E 1481,81 S 2318,06 E 2751,21 S 57 24 E 1530,66 S 2385,01 E 2833,94 S 57 18 E 1582.60 S 2456.98 E 2922.56 S 57 12 E 1638.87 S 2535.98 E 3019.45 S 57 7 E 1698.58 S 2618.83 E 3121.45 S 57 1 E 1759.50 S 2701.00 E 3223.54 S 56 55 E' 1821.82 S'2783.29 E 3326.52 S 56 47 E 1883,20 S 2862.99 E 3426,83 S 56 39 E 1943,54 S 2940,71 E 3524.92 S 56 32 E 2003.02 S 3016.64 E 3621.08 S 56 24 E 2061.47 S 3088,92 E 3713.64 S 56 16 E 2119,12 S 3,1,58.07 E 3803.16 S 56 8 E 2175,54 S 3222.17 E 3887,84 S 55 58 E 2228.37 S 3282.11 E 3967,10 S 55 49 E 2278.09 S 3336.94 E 4040.41 S 55 40 E 2323.32 S 3384.20 E 4104.95 S 55 31 E 2365.51 S 3427.13 E 4164.24 S 55 23 E 2404,18 S 3466,75 E 4218,82 S 55 15 E 2441.72 S 3505.45 E 4272.02 S 55 8 E 2479.26 S 35~4.18 E 4325.27 S 55 1 E 2516.81 S 3582.90 E 4378.53 S 54 54 E 2527.14 S 3593.57 E 4393.20 S 54 53 E STANDARD ALASKA PRODUCTION CO. 1-~1/0-23 MPI ENDICOTT NORTH SLOPE,ALASKA MARKER DRILLERS DEPTH COMPUTATIDN DATE: 6-MAY-87 PAGE 9 DATE OF SURYEY: OL-MA¥-87 KELLY BUSHING ELEVATION: 55.25 FT ENGINEER: SALAZAR INTERPOLATED VALUES FGR CHOSEN HORIZONS MEASURED DEPTH ~ BELOW KB SURFACE LOCATION AT ORIGIN: 2121 SNL, 2153 WEL, SEC. 36, T12N, R16E TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH ,~EAST/WEST 12180.00 10582.79 10527.54 2527.14 S 3593.57 E COMPUTATION DATE: 6-MAY-87 PAGE 10 STANDARD ALASKA PRODUCTION CO. 1-41/0-23 MPI ENDICOTT NORTH SLOPE~ALASKA DATE OF SURVEY: 01-MAY-B7 KELLY BUSHING ELEVATION: 55.25 PT ENGINEER: SALAZAR MARKER MEASURED DEPTH BELOW K~ FROF, K~. SURFACE LOCATION AT ORIGIN: 2121 SNL, 2153 WELt SEC. 36~ T12N~ R16E TVD RECTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST DRILLERS DEPTH 121~0.00 10582.79 10527.54 2527.14 S 3593.57 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPlH DEPTH dORiZONTAL DEPARTURE ~iS~ANCE AZIMUTH PEET DEG MIN 12180.0U 10582.79 10527.54 4393.20 S 54 53 E SCHLUMBERGER O ~ REC T l ONAL SURV E Y COMPANY STANOARO ALASKA PROOUCTION WELL 1-41 0-23 MPI F I ELD ENO I COTT COUNTRY USA RUN 1 OATE LOOOEO O1 - MAY - 87 REFERENCE 7 WELL' 1-41/0-23 MPI (212~1' SNL, 2153' WEL, .... EC 36, T12N, R16E) HORIZONTAL PROJECTION NORTH 3000 2OOO 1000 - 1000 -:>000 -3000 -4000 ~OUTH -SOO0 WEST REF '72293 SCALE = 1/!000 IN/FT -2000 - 1000 0 1000 ~000 3000 4000 SO00 6000 EI:~T WELL' (2121' 1-41/0-23 MPI VERTICAL PROJECTION SNL, 2153' WEL,~-SEC 36, T12N, R16E) ~ -2000 - 1000 0 0 1000 2000 3000 4000 5000 6000 125. ?"?"?'i ..... 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SCALE = 1/ 1000 IN/FT Standard Alaska Production Company ...... 900 East Benson Boule' P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALASKA PRODUCTION MAY 28, 1987 William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells is enclosed: 1 sepia print and i blueline print for: 0-23 Run 1 May 1, 1987 * CBT * CET Bruce St. Pierre Received by Date A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. '' STATE OF ALASKA ALAt , OIL AND GAS CONSERVATION CON .... SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well UJ Alter casing [_il Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator Standard Ala.~a Prnr~.~n~ CnmDany 3. Address P. O. Box 196612, Anchoraqe, Alaska 99519-6612 4. Location of well at surface 2121' SNL, 2153' WEL, Sec. 36, T12N, R16E At top of productive interval 4460' SNL, 3616' WEL, Sec. 31, T12N, R17E At effective depth At total depth 4648' SNL, 3839' WEL, Sec. 31, T12N, R17E 5. Datum elevation (DF or KB) feet KB_F. - 55,25 6. Unit or Property name Duck Island Unit/Endicott 7. Well number 1-41/0-23 MPI 8. Permit number 87-32 9. APl number 50-029-21713 10. Pool E~dicott Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length 131' 2474' 11024' 1259' Perforation depth: measured 12180 feet 10583 feet Size 30" 13-3/8" 9-5/8" true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Plugs (measured) feet Junk (measured) feet Cemented Measured depth True Vertical depth Structural Drive Pipe 131' 3440 cu.ft. Permafrost 2474' 575 cu.ft. Class G 11024' 131' 2474' 9621' 7" 446 cu.ft. Class G 12020 ' 10422 ' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation July 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~~ ~~_ Division Drilling Engineer Signed , _. Title Commission Use Only Date Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner IApproval No. by order of the commission Date,Sr"-¢2 Form 10-403 Rev 12-1-85 /_/,.~,~..%,.) Submit in triplicate WELL 1-41/0-23 (~PI) Permit lqumber: 87-32 Approval Date: 3-20-87 OPERATIONS Well operations will be shutdown after clean out to 7" float collar. Test 7" liner and lap to 3000 psi. Change over to NaC1 packer fluid. Nipple down BOPE. Install master valve with blind flange on wellhead and release rig. Run GCT, CBT, CET, in 7" liner and gyroscopic survey from PBTD to surface and downsqueeze the 13-3/8" x 9-5/8" annulus with a non-freezing fluid once rig is off location. The well will be completed by moving a rig on location in mid-1987 and perforate well under balanced utilizing drill pipe conveyed guns. Flow well for simple clean-up. Kill well and complete with packer tailpipe configuration using 9-5/8" and 7" packers with 3-1/2" tailpipe run on 4-1/2" 12.6#/ft., L-80 TDS tubing with GLM's. A sub surface safety valve will be installed below base of permafrost. Install and test tree. Release rig. JGV/MAW/kb/1782D Rig: Doyon #15 Well: 1-41/0-23 IMPI) SAPC Daily Drilling Report -- ENDICOTT April l, 1987 at 0600 hours AFE # 717520 API 50-029-21713 0600 Depth: ' Day: -1 24-Hour Ftg: ' Current Operation: R/U top drive. Move rig. Accept rig at OlO0 hrs. on 4/1/87. Install top drive. Prepare to spud. MUD TYPE- WT: VIS: PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1565h: Rig' Doyon #15 Well' 1-41/0-23 ~MPI) SAPC Daily Drilling Report -- ENDICOTT April 2, 1987 at 0600 hours AFE # 717520 API 50-029-21713 0600 Depth- 300' Day: 0 24-Hour Ftg' 300' Current Operation' Drilling. Spud well at 0300 hrs. on 4/2/87. Drill 17-1/2# hole to 300 ft. MUD TYPE-Spud Mud WT:8.8 VIS:280 PV-11 YP:46 FL'20.6 SOLIDS'3 TEMP:48°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES , ,, 1565h' DLS SAPC r)aily Drilling Report -- ENDICOTT April 3, 1987 at 0600 hours Rig: Doyon #15 Well: 1-41/0-23 (MPI) AFE # 717520 API 50-029-21713 0600 Depth: 1635' Day: 1 24-Hour Ftg: 1335' Current Operation' Drilling. Drill 17-1/2" hole to 1083 ft. Trip bit. Drill 17-1/2" hole. Plugged bit. Trip bit. Drill to 1635 ft. MUD TYPE-Spud Mud WT:9.1 VIS'ISO PV'17 YP'24 FL'22.5 SOLIDS'5 TEMp'47°F SURVEY PE) ANGLE DIRECTION TVD SECTION COORDINATES DLS 1565h: SAPC Daily Drilling Report -- _FNF~ICOTT April 4, 1987 at 0600 hours Rig: Doyon #15 Well: 1-41/0-23 /~.~PI) AFE # 717520 API 50-029-21713 0600 Depth: 2495' Day: 2 24-Hour Ftg: 860' Current Operation: Tripping. Drill 17-1/2" hole to 2495 ft. CBU. POH. Run 13-3/8" casing; shoe at 2474 ft. RIH w/stab-in. CBU. Mix and pump cement. POH. MUD TYPE-Spud Mud WT:9.3 VIS:ISO PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1565h: SAPC Daily Drilling Report -- ENDICOTT April 5, 1987 at 0600 hours Rig: Doyon #15 Well: 1-41/0-23 (MPI) AFE # 717520 API 50-029-21713 0600 Depth: 3488' Day: 3 24-Hour Ftg: 994' Current Operation' Drilling. N/U BOPE. Test BOP's. RIH. Test casing to 3000 psi. Drill float equipment and lO ft. new hole. Perform FIT to 13.8 ppg. Drill 12-1/4" hole to 3489 ft. MUD l~/PE-Polymer WT:9.2 VIS:38 PV:5 YP:9 FL:22.8 SOLIDS: TEMP:46°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1565h: Rig: Doyon #15 Well: 1-41/0-23 (MPI) SAPC Daily Drilling Report -- ENDICOTT April 6. 1987 at 0600 hours AF£ # 717520 API 50-029-21713 0600 Depth: 4850' Day: 4 24-Hour Ftg: 1361' Current Operation: Tripping. Drill 12-1/4" hole to 4160 ft, Trip bit. Drill to 4850 ft. Change mud to Newdrill. POH. RIH w/dynadrtll. MUD TYPE-New Drill WT:9.3 VIS:60 PV:8 YP:30 FL:lg.8 SOLIDS:4 TEMP:49°F SURVEY ~ ANGLE DIRECTION TVD SECTION COORDINATES 1565h: DLS Rig' noyon #1.5 ',.,/el I: i -~.l/0-23 SAPC Daily Drilling Report -- ENPICrlTT April 7, 1987 at 0600 hours AFE # 717520 ,APT qfl-ne9 ?171 * .... ,,.~ ~.. ~ ,~ ..~ Current Operation' MUD TYPE-New Drill 3rilling. RIP,. .r)ynadri 11 hole. 0600 ge~ ,th-, .. .5~79'., Day: 5 24-Hour Ft9: 529' to 5379 Ft. POH. P, IH w/bit, r)rill 12-I/4" WT'9.3 VIS' 64 PV'8 YP'32 FI_'ll .2 SOLIDS:4 TEMP:50 °F SURVEY HD ANGLE DIRECTION 19 4979 4.3 S71E 21 51 54 9.8 S69E TVO SECTION 4978 5162 42 64 COORDINATES g' 28 c~ 33 1565h: DLS 2.4 3.1 SAPC Daily Drilling Report -- END. ICOTT April 8, 1987 at 0600 hours Rig' Doyon #15 Well' 1-41/0-23 IMPI.) AFE # 717520 API 50-029-21713 0600 Depth' 6,600' Day: 6 24-Hour Ftg' 1221' Current Operation' Drilling. Drill and survey 12-1/4" hole to 6411 ft. Trip bit. Drill to 6600 ft. MUD TYPE-New Drill WT-9.4 VIS:46 PV-9 YP'18 FL:8.6 SOLIDS'6 TEMP'68°F SURVEY ~ ANGLE DIRECTION TVD SECTION COORDINATES DLS 24 5660 22.9 S65E 5638 197 91 179 3.1 26 6037 32.7 S61E 5973 368 170 332 3.2 28 6322 42 S59E 6200 539 256 481 3.5 1565h- SAPC Daily Drilling Report -- ENDICOTT April 9, 1987 at 0600 hours Rig' Doyon #15 Well' 1-41/0-23 (MPI) AF£ # 717520 API 50-029-21713 0600 Depth' 7610' Day' 7 24-Hour Ftg' 1010' Current Operation' Drilling. Drill and survey 12-1/4" hole to 7159 ft. Trip bit. Drill to 7610 ft. MUD TYPE-Polymer WT:9.6 VIS'52 PV'IO YP'20 FL'8.2 SOLIDS'7 TEMP'75°F SURVEY MD ANGLE DIRECTION · TVD SECTION COORDINATES 30 6700 44'0 S57E 6473 799 ~ 392 ~ 704 32 7069 43'5 S58E 6740 1054 ~ 528 ~ 919 34 7459 43 S59E 7024 1320 ~ 669 ~1146 1565h' DLS 0.5 0.1 0.5 SAPC Daily Drilling Report -- ENDICOTT April lO, 1987 at 0600 hours Rig' Doyon #15 Well- 1-41/0-23 {MPI) AFE # 717520 API 50-029-21713 0600 Depth' 7991' Day' 8 24-Hour Ftg' 381' Current Operation: Drilling. Drill and survey 12-1/4" hole to 7991 ft. Trip bit. Drilling. MUD TYPE-Pol~qner WT:9.6 VIS'51 PV'IO YP-19 FL:8.5 SOLIDS:7 TEMP'75°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 35 7645 42j6 S59E 7161 1446 $ 734 ~_~ 1255 0.2 36 7838 41 '7 S58E 7304 1575 ~ 801 ~ 1365 O. 5 1565h' Rig: Doyon #15 Well: 1-41/0-23 IMPI) SAPC Daily Drilling Report -- ENDICOTT April ll. 1987 at 0600 hours AFE # 717520 API 50-029-21713 0600 Depth: 8482' Day: 9 24-Hour Ftg: 491' Current Operation: Change BHA. Drill and survey 12-1/4" hole to 8482 ft. Trip bit. MUD TYPE-Polymer WT:9,8 VIS:57 PV:IO YP:20 FL:8.5 SOLIDS:8 TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 37 8022 41 j 4 S58E 7441 1691 s 866 c.~469 1565h: DLS .2 SAPC Daily Drilling Report -- ENDICOTT April 12. 1987 at 0600 hours Rig: Doyon #15 Well: 1-41/0-23 IMPI) AFE # 717520 API 50-029-21713 0600 Depth: 8950' Day: 10 24-Hour Ftg: 468' Current Operation- Drilling. RIH, Drill and survey 12-1/4" hole to 8950 ft. MUD TYPE-Polymer WT:9.8 VIS:60 PV:9 YP:21 FL:8.3 SOLIDS:8 TEMP:86°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 40 8598 44, 9 S57E 7857 2096 41 8788 44~ 2 S56E 7992 2229 Y 1080 ~ 1805 O. 1 ~ 1154 ~1916 0.5 1565h: SAPC Daily Drilling Report -- ENDICOTT April 13, 1987 at 0600 hours Rig: Doyon #15 Well: 1-41/0-23 {MPI) AFE # 717520 API 50-029-21713 0600 Depth: 9425' Day: 11 24-Hour Ftg: 475' Current Operation' Drilling. Drill and survey 12-1/4" hole to 9425 ft. MUD TYPE-Polymer 'WT:gj8 VIS:56 PV:9 YP:23 FL:8.5 SOLIDS:9 TEMP:85°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 42 8979 43 j 2 S56E 8130 2361 S 1228 ~_~2026 . 5 43 9166 42 S55E 8268 2487 ~ 1300 ~2130 .8 1565h: SAPC Daily Drilling Report - ENDICOTT April 14, 1987 at 0600 hours Rig: Doyon #15 Well: 1-41/0-23 (MPI) AFE # 717520 API 50-029-21 71 3 0600 Depth: 9643' Day.' 1 2 24-Hour Ftg'. 218' Current Operation: Repair top drive. Drill and survey 12-1/4" hole to 9643 ft. POH. Test BOP's. Repair top drive. MUD TYPE-Polymer WT:9.8 VIS-54 PV:9 YP-26 FL:8.8 SOLIDS'9 TEMP'88°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 44 9358 41 . 3 S55E 8411 2614 5' 1370 (~ 2231 45 9545 39.9 S54E 8553 2736 X 1440 C~ 2330 0.4 0.9 1565h: SAPC Daily Drilling Report -- ENDICOTT April 15, 1987 at 0600 hours Rig: Doyon #15 Well: 1-41/0-23 /MPI) AFE # 717520 API 50-029-21713 0600 Depth: 9859' Day: 13 24-Hour Ftg: 216' Current Operation: Drilling. Work on top drive. RIH. Drill and survey 12-1/4" hole to 9859 fto MUD TYPE-Polyn~r WT:9~9 VIS:56 PV:8 YP:30 FL:7.8 SOLIDS:8 TEMP:90°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 46' 9742 40'9 S54E 8703 2863 ~1516 J2433 DLS 0.5 1565h: SAPC Daily Drilling Report -- ENDICOTT April 16, 1967 at 0600 -hours Rig: Doyon #15 Well: 1-41/0-23 (MPI) AFE # 71 7520 API 50-029-21713 0600 Depth: 10,285' Day: 14 24-Hour Ftg: 426' Current Operation: Drilling. Drill and survey 12-1/4" hole to 10,285 ft. MUD TYPE-Polymer WT:9.9 VIS:47 PV:8 YP:28 FL:7.0 SOLIDS:8 TEMP:92°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 47 9927 44.7 S56E 8839 2989 s'1588 6 2536 2.1 48 lOll7 45.7 S55E 8973 3124 ~ 1664 ~2647 0.6 1565h: SAPC Daily Drilling Report -- ENDICOTT April 17, 1987 at 0600 hours Rig: Doyon #15 Well: 1-41/0-23 /MPI) AFE # 717520 API 50-029-21713 0600 Depth: 10,688' Day: 15 24-Hour Ftg: 403' Current Operation: Drilling. Drill 12-1/4" hole to 10,290 ft. Trip bit. Drill and survey to 1 0,688 ft. MUD TYPE-Polymer WT:IO.O VIS:56 PV:IO YP:30 FL:6.2 SOLIDS:9 TEMP:88°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 49 10299 46.1 S55E 9099 3255 S 1739 ~ 2754 O. 2 50 1 0489 44.9 S54E 9232 3390 ~ 1817 N~2864 O. 7 1565h: Rig: Doyon #15 Well: 1-41/0-23 (MPI) SAPC Daily llrilling Report --. Et~DIC. OTT April 18, 1987 at 0600 hours AFE # 717520 API 50-029-21713 0600 Depth: 11,039' Day.' 1 6 24-Hour Ftg: 351' Current Operation: Run 9-5/8" casing. Drill and survey 12-1/4" hole to 11,039 ft. Short trip. CBU. POH. Rig up and run 9-5/8" casing. MUD TYPE-Polymer WT:IO VIS:48 PV:ll YP:30 FL:6.2 SOLIDS:9 TEMP:IOO°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 52 10868 43.1 S52E 9505 3654 S1974 ~ 3077 54 11039 42 S52E 9631 3769 ~ 2046 ~3168 1565h: DLS .9 .6 Rig: Doyon #15 Well: 1-41/0-23 (MPI) SAPC Daily Drilling Report -- ENDI£OTT April 19, 1987 at 0600 hours AFE # 717520 API 50-029-21713 0600 Depth: 11,039' Day: 17 24-Hour Ftg: ' Current Operation: Tripping. Run 9-5/8" casing. Shoe at 11,024 ft. CBU. Mix and pump cement. Install and test pack-off to 3000 psi. RIH w/ 8-1/2" BHA. MUD TYPE-Polymer WT:IO VIS:48 PV:ll YP:30 FL:6.2 SOLIDS:9 TEMP:90°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1565h: Rig: Doyon #15 Well' 1-41/0-23 (MPI) SAPC Daily Drilling Repert -- ENDICOTT April 20, 1987 at 0600 hours AFE # 717520 API 50-029-21713 0600 Depth: 11,407' Day: 18 24-Hour Ftg: 368' Current Operation: Drilling. RIH. Test casing to 3000 psi. Drill FS, FC and l0 ft. new hole. Perform FIT to 13.5 ppg EMW. Drill 8-1/2" hole to 11,407 ft. MUD TYPE-Polymer WT:IO VIS:43 PV:14 YP:16 FL:8.8 SOLIDS:9 TEMP: 96°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1565h: Rig' Doyon #15 Well' 1-41/0-23 IMPI) SAPC Daily Drilling Report -- EHDICOTT April 21, 1987 at 0600 hours AFE # 717520 API 50-029-21713 0600 Depth' ll,710' Day: 19 24-Hour Ftg' 303' Current Operation' Reaming. Drill 8-1/2" hole to ll,710 ft. Trip bit. Ream tight spots. MUD TYPE-Polyn~r WT:IO VIS'44 PV'12 YP'15 FL'7.2 SOLIDS:9 TEMP'96°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1565h' Rig: Doyon #15 Well: 1-41/0-23 /MPI) SAPC Daily Drilling P. eport -- ENDICOTT April 22, 1987 at 0600 hours AFE # 71 752O API 50-029-21713 0600 Depth: 12,180' Day: 20 24-Hour Ftg: 470' Current Operation: Logging with RLL tool. RIH. Drill 8-1/2" hole to 12,180 ft. logging tool. MUD TYPE-Polymer WT:IO VIS:37 PV:14 YP:17 FL:5.8 POH. SOLIDS:9 Rill with RLL TEMP:92°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 1565h: DLS ,. Rig: Doyon #15 Well: 1-41/0-23 (MPI) SAPC Daily Drilling Report -- ENDICOTT April 23, 1987 at 0600 hours AFE # 717520 API 50-029-21713 0600 Depth: 12,180' Day: 21 24-Hour Ftg: ' Current Operation' RIH for wiper trip~ Logging with Baroid MWD RLL. POH. Rig up Gearhart. RIH with GR-DLI-MSFL, could not [let below 9-5/8" shoe. RIH with bit for wi per trip' MUD TYPE-Polymer WT'IO VIS'37 PV'13 YP:15 FL'5.8 SOLIDS'9 TEMP' °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 1565h~ DLS SAP¢ Daily Drilling Report -- EHPICOTT April 24, 1987 at 0600 hours Rig: Doyon #15 Well: 1-41/0-23 /MPI) AFE # 71 7520 API 50-029-21713 0600 Depth.' 12,180' Day: 22 24-Hour Ftg: ' Current Operation: Laying down 7" liner. RIH to bottom, POH and work pipe thru tight spot at ll,120'. RIH to bottom. Condition mud and increase weight to lO.1 ppg. POH. RIH with 7" liner on 5" DP. Unable to get past 9-5/8" shoe at 11,026'. POH laying down liner. MUD TYPE-Polymer WT:IO.2 VIS:38 PV:13 YP:15 FL:5.8 SOLIDS:9 TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDI)~TES DLS 1565h :~ SAPC Daily Drilling Report --, ENDICOTT April 25, 1987 at 0600 hours Rig' Doyon #1 5 Well' 1-41/0-23 (MPI) AFE # 717520 API 50-029-2171 3 0600 Depth' ll,180' Day: 23 24-Hour Ftg: ' Current Operation' Jarring on stuck pipe. POH with liner. RIH with 8-1/2" mill. Ream from 11,026 to 11,074'. RIH. Stuck pipe at 11,725'. Worked pipe free. Ream from 11,775 to 12,105. Stuck pipe at 12,105. Jarring. MUD TYPE-Polymer WT'IO.2 VIS' 38 PV'14 YP'15 FL'5.7 SOLIDS:lO TEMP' °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 1565h.'~ DLS SAPC Daily Drilling Report -- ENDICOTT April 26, 1987 at 0600 hours Rig' Doyon #15 Well' 1-41/0-23 (MPI) AFE # 717520 API 50-029-21713 0600 Depth' 12,180' Day' 24 24-Hour Ftg' ' Current Operation' Circ. and condition mud. Work stuck pipe. Place spotting fluid around stuck pipe. Run free point - 12,092'. Backoff with string shot. Circ. and condition mud. MUD TYPE-Polymer WT'IO.2 VIS'40 PV'14 YP-16 FL'5.6 SOLIDS'lO TEMP' °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 1 565h'~ DLS Rig' Doyon #15 Well' 1-41/0-23 (IIPI) SAPC Dai!y Drilling Report -- ENDICOTT April 27. 1987 at 0600 hours AFE # 71 7520 API 50-029-21713 0600 Depth' 12,180' Day' 25 24-Hour Ftg' ' Current Operation' POH for liner. Circ. and condition mud. POH. Left mill - 3 x XO's - NBS-DC- Stb, - DC, back-off was at 12,026. RIH with bit. Ream from 11,024 to ll,04S. RIH to fish. Circ. and raise mud wt. to 10.4 ppg. POH for liner. MUD TYPE-Polymer WT'IO 4 VIS'45 PV-16 YP:20 FL'5.8 SOLIDS'Il TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 1 565h:~ DLS Rig: Doyon #15 Well: 1-41/0-23 (MPI) SAPC Daily Drilling Report -- ENDICOTT April 28, 1987 at 0600 hours AFE # 717520 API 50-029-21713 0600 Depth: 12,180' Day: 26 24-Hour Ftg: ' Current Operation' RIH with 8-1/2" bit to drill cement. POH. Run and cement 7" liner at 12,026'. POH. RIH with 8-1/2" bit. MUD TYPE-Polymer WT:IOj4 VIS:42 PV:16 YP:12 FL:5.7 Release from liner SOLIDS:Il TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 1 565h-~ DLS Rig: Doyon #15 Well: 1-41/0-23 (MPI) SAPC Daily Drilling Report --o ENDICOTT April 29, 1987 at 0600 hours AFE # 717520 AP! 50-029-21713 0600 Depth: 12,180' Day: 27 24-Hour Ftg: ' Current Operation: POH. RIH. Circulate. POH. RIH w/6" cleanout assy. Test lap to $000 psi. RIH and drill cement to 11,932 ft. CBU. Test liner to 3000 psi. Displace well to 9.6 ppg brine. POH. MUD TYPE-NaC1 WT:9.6 VIS: PV: YP: FL: SOlIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1565h: Rig: Doyon #15 Well: 1-41/0-23 /MPI) SAPC F)aily Drilling Report -- ENDIC6)TT April 30, 1987 at 0600 hours AFE # 71 7520 API 50-029-21713 0600 Depth: 12,180' Day: 28 24-Hour Ftg: ' Current Operation: Rig released. POH. Install tubing hanger. N/D BOP's. Install and test tree to 5000 psi. Release rig at 1430 hrs. on 4/29/87. Move rig to 1-25/N-22. MUD TYPE- WT: VIS: PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1565h: Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 ,. STANDARD Mr. Lonnie Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Duck Island Unit/Endicott Wells Dear Mr. Smith, We are requesting that the AOGCC adopt dual designation for all future well names in the Duck Island/Endicott Unit for operational and safety reasons. Dual designation lists the numeric surface location followed by an alpha-numeric bottom hole location. This will be indicated in future wells on Form 10-401 in Item Number 8. We also ask that wells drilled to date be referenced by this dual designation. For your use is a list of wells drilled to date. WELL NAME PERMIT NUMBER API NUMBER 1-5/0-20 (MPI) 1-27/P-20 (MPI) 1-2g/M-25 (MPI) 1-35/0-25 (MPI) 1-41/0-23 (MPI) 1-47/Q-21 (MPI) 2-2/P-18 (MPI) 2-4/M-19 (MPI) 2-6/J-22 (MPI) 2-14/0-16 (MPI) 2-34/P-14 (MPI) 2-62/Q-17 (MPI) 3-1/N-29 (SDI) 3-5/0-29 (SDI) 3-21/5-34 (SDI) 3-23/N-32 (SDI) 3-27/M-33 (SDI) 3-33/K-37 (SDI) 3-35/L-36 (SDI) 3-47/Q-35 (SDI) 4-8/P-27 (SDI) 4-20/M-35 (SDI) (T-34 Redrill) 4-20/T-34 (SDI) (Abandoned) ' ~n ~ ~.~lbnit of the origino' Standard Oil C .... pony 86-106 50-029-21605 87-9 50-029-21693 86-181 50-029-21669 86-184 50-029-21672 87-32 50-029-21713 86-131 50-029-21625 86-63 50-029-21568 86-82 50-029-21585 87-18 50-029-21699 86-149 50-029-21639 86-172 50-029-21662 86-158 50-029-21648 86-190 50-029-21678 86-130 50-029-21624 87-33 50-029-21714 86-155 50-029-21645 86-83 50-029-21586 86-180 50-029-21668 87-20 50-029-21701 86-64 50-029-21569 87-8 50-029-21692 86-173 50-029-21640-01 86-150 50-029-21640 We thank you for your assistance and should you have any questions, give me a call at 564-5007. Yours very truly, RSA/MAW/pm/1664D cc: R. H. Reiley_ B. L. Ros W J. G. Vidrine I. R. Robertson D. Huxley B. Ross File 16.4 Endicott Development R. S. Allan Division Drilling Engineer l~farch 26, 1987 Mr. R. S. Allan Division Drilling Engineer Standard Alaska Production Company P.O. Box 196612 Anchorage, Alaska 99519-6612 Telecopy: (907) 276-7542 Re: Duck Island Unit 0-23 Standard Alaska-Production Company Permit No. 87-32 Sur. Loc. 212t'SNL, 2153'WEL, Sec. 36, T12N, R16E, UM. Btmhole Loc. 4908'SNL, 3157'WEL, Sec. 31, T12N, R17E, UM. Dear Mr. A1 t am_: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~ t~u!~w~you~_ s, ~ c. v. Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA C.,~. AND GAS CONSERVATION COh't...,SSION PERMIT TO DRILL 20 Amc 25.005 Row 1 Slot 41 la~. Type of work Drill ~ Redrill [~! lb. iype of well. Exploratory i~-; Stratigraphic Test [i] Development Oil Re-Entry ~ Deepen CJI Service ~ Developement Gas ~_] Single Zone ~ Multiple Zone LJ =, 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company 56 feet Endicott Field 3. Address 6. Property Designation Endicott Oil Pool P.O. Box 196612: Anchora~e~ AK 99519-6612 ADL 312828 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 2121 SNL, 2153' WEL, Sec. 36, TI2N, R16E Duck I.~land Unit/Endi.cot.t At top of productive interval 8. Well nurpber Number 4625' SNL, 3525' WEL, Sec. 31, T12N, R17E ~11~'/O-23 (MPI) KOO683449-G-14 At total depth 9. Approximate spud date Amount 4908' SNL, 3157' WEL, Sec. 31, T12N, R17E April 1, :1987 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in pr°pert~ 15. Proposed depth (MD and TVD) property line Surface 12,424' MD ADL 47502 655feet 0-25 MPI 30 feet 2560 10t546' TVD feet 16. To be completed for deviated wells 45.1© 17. Anticipated pressure (see2O^^C25.035(eX2))10,O00, TVDss Kickoff depth 4850 feet Maximum hole angle 0 Maximum surface 3900 psig At lotal depth (-FVD) 4900 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement ,, Hole Casing Weight i Grade Coupling Length MD TVD MD TVD (include stage data) 30" Strtlctural! Driv( Pip~ 75' Surfac, 131' 131' Drive "i7-1/2" 13-3/8" 68# L-80 Butt. 2444' Surfac_~ 2500' 2500' 2700 cu.ff_. 12-1/4" 9-5/8" ~47# NT80S NSCC 9469' Surfac.~ 9525' 8500' 320 cu. ft. Class G 12-1/4". 9-5/8" 47# NT95H: NSCC 1638' 9525' 8500' [1163' 9656' 575 cu. ft. Class G 8-1/2" 7" 29# L-80 Butt. 1511' 10913' 9480' [2424' 10546' 400 cu. ft. Class G 19.To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate ~ ~ C i! IV E D Production Perforation depth: measured true vertical ~'i.';!{3 Oil & t~:~ t;~';:i~}. ,, 20. Attachments Filing fee E~ Property plat E~ BOP Sketch '_~ Diverter Sketoh [-~ Drilling program [_X. Drilling fluid program [] Time vs depth plot ~ Refraction analysis ~ Seabed report EJ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~) ~. ~ Title Division Drilling Engineer Date ~/Z~/~ Commission Use Only Permit ] APl numbe~) [ Approvaldate I See cover letter Numbe-7-32~ 5O-- 29-21713 03/26/87 for other requirements Conditions of approval Samples required ~ Yes '~No Mud Icg required ! ~ Yes ~,~ No Hydrogen sulfide m_..easures i.7} Yes i~ No D. Irectlona~l.survey required ?<..Yes .~; No Required worki~r~ssure~for B~;)C~2MJ ~ 3M; X 5M; ."~ 10M; .'i 15M Other: / ~//4~~',.. ~¢~'~41~ - -- the mission ..... by order of Approved byk,,...~ ,-./,.- ~ /,/¢~ Commissioner corn Dar PROPOSED DRILLING AND COMPLETION PROGRAM WELL 1-41/O-23 (MPD Obj0ctive Well 0-23 will be drilled as an oil production well from zones 2B and 3A. The completion will will consist of a straddle pack assembly. Ooeration Execute a rig move from slot 2-6 to slot 1-41 and rig-up. Vertically drill 17-1/2" hole to 2500 ft. and cement 13-3/8" 68#/ft. L-80 Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4840 psi at 9855 ft. TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Vertically drill 12-1/4" hole to 4850 ft. then directionally drill to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47g/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe and 5 ft. new hole and conduct a formation leak-off test. Drill 8-1/2" hole to TD. Run logs. Run and cement 7" 29#/ft SM-110 buttress liner to TD with approximately 250 ft. of lap in the 9-5/8" casing. Clean out to float collar. Test casing and lap to 3000 psi. Run CET/CBT/VDL/GR/CCL in 7" liner and gyroscopic survey from PBTD to surface. Change over to NaC1 packer fluid. Nipple down BOPE. Install tree. Release rig. Downsqueeze the 13-3/8" x 9-5/8" annulus with Permafrost cement followed by a non-freezing fluid once rig is off location. Move rig on location in mid-1987 and perforate well under balance utilizing drill pipe conveyed guns. Kill well. Run straddle pack assembly. Flow tubing volume. Release rig. ENDICOTT PROPOSED DIAGRAM WELL 1-41/O-23 i'MPI) (DEFERRED COMPLETION TILL MID 1987) TVD (BKB) MD (BKB) 30" DRIVE PIPE 131 FT BASE PERMAFROST 1466 FT SSSV 1516 FT TOP OF [:X::NVN SQUE~ ~ 13-3/8" 68#/FT L-80 BUTT 131 FT 1466 FT 1516 FT (ESTIMATED 2000 FT) 2500 F-I' 250O FT BO~OF[X3WNSQUFFTFCEMENT (ESTIMATED 3000 FT) KOP ( DIR: S 54.5 E; ANGLE: 45.1 DEG ) 4-1/2' 12.6#/FT L-80 TDS TUBING W/3-1/2' TAILPIPE 485O FT 9-5/8' 47#/FT NT80S NSCC TOP OF 9-5/8' CEMENT 8500 FT 9525 FT (ESTIMATED 9483 FT) 9-5/8' TIW PACKER 9444 FT 10863 FT 7" LINER TOP 9512 FT 10913 FT 9-5/8' 47#/FT NT95HS NSCC 9656 FT 11163 FT 7" TIW PACKER W/PBR PLUG BACK 'iD 7' 29#/FT SM-110 BUTT LINER 1O546 FT 12344 FT 12424 FT 15-87 B.O.P. STACK CONFIGURATION 13-5/8 IN. TRIPLE RAM STACK SO00 PSI WP DRILLING ! I ANNULAR PREVENTER 2 IN. KILL LINE GATE GATE ,I I ! ! PIPE RAMS ! i BLIND RArlS DRILLING SPOOL PIPE RAMS , I I,_ 4 IN. CHOKE LINE GATE GATE u I PLAT OF PROPOSED WELL LOCATIONS IdPi ll~ellt Leceted I~ See.$&,T. IZM,l. ll[.,Umilt M. iSOl ll~ldll LeCe~ed Il SA'C. I,T.IIN.,R.I?E'-,Um)~ M ~ , PRE. PAR E.D FOR SOHIO ALASKA PETROLEUM CO. DRW NO. IIG' 15 SHEET I ef t0 REV. 0 PRE. PAR El IY F,R. BELL & A. SSOC. PRUDHOE BAY OFFICE PRUDHOE BAY, ALASKA I~ATE: NOV. 13, 14115 -- _ leAL[: I".1 IdlL[ -biAWld 11': Ri.T. ClI, II:CJCE.O IY' I.E.. ~ ~ ~-- _ IIII I II · I ' III II J I _ III - . 14 0 ~2 0 ~o o I ~.~o ,, I~ 0 icj 1~)1~)© S'l 0 23 0 %%0 $6 $~ 0 575~ 0 NO TE$' CERTIFICATE OF SURVEYOR o I lleerby certify that I em properly registered and licensed to practice land surveying in the State af Alaska emi that this plat represents an proposed location for the 'Well numbers shown above. Ail eerveying was done byme or under my supervis~n, end tMt ell dimn~iont end details ere correct. DRW. 116-85 SHEET 2 et IO REV. 0 Indicates well Indicates Celci~leted Section Cer~er I~sltmn Indicates PerlNndiceler Offset Distance Indicetq Pemndiculer Off,et Distance )endi~ular ~*st~ ' PLAT ~ BPI PROPOSED WELL LOCATIONS LOCATED IN I[C;.li, T. IZ N., R. Ii t. UNIAT Id. PREPARED FOR SOHIO ALASKA PETROLEUM CO. PREPAREO BY F.R. BELL & ASSOC. PRUDHOE BAY OFFICE PRUDHOE BAY, AI,.ASKA i I I I II i DATE ' NOV. I$, ItS $CALEs I'. GO' CHECKED BY' B.E. _ · I . I I I ..... ~1 II III ! ii iii UTI. jif( 6 L~ITZTUBE L~ ,fl( BIIT ASP Z~ I Y- S912482,~7 N' 7105324.S1 7~21'10.0670~ 14~17'~.4~' 1~'20'~ X- 259110.7S E, 464137.36 2 Y- 5982579.88 N- 7805353.52 70~21'10.9814' 147657'24.6257' 113S.43 2160.94 , X' 259041.49 E' 464094,45 3 Y- ~982474.18 ~N- 780~321.98 70~21'09.9846' 147~'20.62~8" ~936.77' X' 259~75.0~ ; E. 464Z35'65 , 4 Y= 59B257~.69 N= 7805~50.99 70~22'~0,8992* 147~57'24.7856· ~B'4~.80 2~74,4~ X= 259035,76 E= 464092,74 5 Y. 4246 .9 7Boss ,46 70 2 '0 . 02s. 47 57'20. e * x. 2 9 6 .27 e64 ss. &" Y= 5982563,50 N= 7B05~48,47 70~21"lO,O16B* 1~7~57'24,9~54*' IB52,17' 2~79~8 X= 259030,02 E= 464091,04 7 Y='" 5982457' e0 N= 7805~16,94 70°21'09,8200* 147~57'2'0,~455* 1953',52 2043,06 X= 259~63,3~ E= 46~132,2~ ~ Y= 59~2555,30 N= 7B05345,94 70~21'1'~,7~44' 147°57'2'5,105~' 11~0'54 21B5',35' X= 259024,29 E= 4~089,33 9' Y= ~9~24~9,&1'' N= 7B0531~.41 70°'2l'09,7~76' 147°~7'21~'10~4* llil,lt 2041,5~ X= 2~9L57,~0 E= ~64130,53 10 Y= 5982547,11 N= 7B05343~'42 70d21'10.6521' 147~5~'25,2651' 116B,91 2190,13 X= 259018,55 E= 464~87,62 'il Y='596244"i'42 N= 7805311,B9 70°21'09,6553* 147°57'21,2653' 1970.26 2054.00 X' 259iS2,07 E' 464128.83 12 Y= 5902538.92 N= 7805340.90' 70~21'10.56~7" 147°57'25.4250* 1077.20 2196.30 X= 2590~2,82 E' 464085.92 13' Y= 5~82'433,2'3 N= 7805309.36 70021'09.573'0* 147°57'21.4251* 1978.63 2~59'.47 / X= 259~46.33 E= 464127, ~2 14 Y= 59825~0.73 N= 7805~8,37 70°21'10.4874* 147°57'~5.~049* 1885.661 220Z.77 X= 259007,08 E= 464084,2~ 15 Y- 5982425.03 N- 780~306.84 70~21'09.4906" 147°57'21.58~0" 1~87.00 2064.~4 X= 259t40.60 E= 464125.42 16 Y= 5982522,54 N= 7605335.65 70621'10,405~= 147°57'25,7447' 1194.03 2207,24 X= 25900 .35 E= 464082.30 17 Y= 5982416.84 N= 780'5304.3~ 70o2i'09.40B~* 147°57'2~,7449* 1t95.38 2070,41 X= 259134,86 E= 464123.71 lB Y= 5982514.35 N- 7805333.32 70~21'10.3227' 147°57'~5.9046' 1902.40 *'2212.7~ x- 25899~.61 E- 464080.80 19' Y= 5982408.65 N= 7805301.79 70c21'09,326'0' 147o57'21.9047* 2003.75 2075.89 X- 259129.13 E- 464122,00 , 20 Y= 5962506,"16 N= 7605330.80' 70c21'10.2404* '~47~57'26.0644' ~910.77 221i'18 X- 256969.87 E= 464079.09 21 Y= 5982400,46'" N= 7805299.27 70~21'09.~4~"6- 147°5'~'22~0646' 2012.12 2081,36 X= 259123,~9. E= 464~20.30 ~ i i i MPI PRO~SED WELL L~ATION LIST : .. ~'~~~ · SOHIO ALASKA PETROLEUM CO. · ~o~,~,~~ F.R. BELL · ASSOC ~ ~F v~ SHE ET 5 of IO · SCALE · N/A ~k%~ss~~~ PRUDHOE BAY OFFICE ~Ev. o PRUDHOE BAY, ALASKA CHECKEO BY~ I.E. i u ii il i i I _ ULII I II II I I ~ - I I I I I III I II · I il --~-~4~ I I I ~11 I I ~L ~ IN I IT i 6 L&TITI LI 'll~ lllT~w' "IIIT~ II1 ~Z ye 1912497,97 N~ 780S321,27 7~Zl'tO, l~i' '14~17'Zi,ZZ43' 1919, tS Z223,61~ I' ~1914,~4 E~ 464077,31 23 Y' 59i2392,27 N' 7B0~296,74 70~21'09',"~6~3' ~ 147057'22'2244' 2020.49 Z016,13 X' 2~9~17,6~ E' 464~i.59 24 ~Y- 5982489.77 N~ 7~'~5325.75 "70c"21'10.07~'~' 147~57'26.3842' 1927.53 2229.13 x- 258978.40 ' E- 464075,68 25 Y- 5982384.08 N- 7805294.22 70~21'09.0790' ~ 147-57'22.3843' 2028.8~ 2092.30 iX- 259~11 92 ~ E' 464116.88 , 26 'Y' Sga248~.S8 "N- ~80S~23.23 '70~ 2~'09.9934'] ~47~'26.S440' ~9~.90 ,X- 2~8972,67,,,~ E' 464073.97 ~ ............ - 27 ~Y- ~982~75.'89 N- 7805291'~'69 '70c21'0B.9966" 147c~7'22.~442' ' 20~7.24 2097.77 X- 2~9106.18 E' 4~411~.18 28 Y' 5982473.~9 N' 7B'05~20.70 70°21'09.9111' 147o57'2&.70~9'' 1944,27 2240.07 X- 258966.93 E' 464072.27 , 29 Y' 5982~67.70 N' 780~289.17 ~70021'08.914I' 147oS7'22,7040' '~045.&i 2105.24 X~ 2~9100.4~ [' 4i411~.47~ , - 30 Y- ~9B2465,20 N- 710531i,11 t70°2i'09,1287· 147°57'2&,l&37" 1952,&4 2245.54 X- 2~89&~.20 E- 4&4070,~6 ~..70o . , 31 Y- 59i2359,~0 N"' 71052iA,E5 21'08,1320" 147c~7 22,1&39" 2053,9l 2tOl 72 X- 259094,71 E- 4641tt,T&~ 32 Y- S9B24~7,01 N- 780~3'15,&~t70c21'09,74&4" J47°57'27,0236" tg&I,OZ X- 2S895~,46 E- 464068,l~ ~ I 33 Y' 59823~l,31 N- 78'05284,12 ~70c21'08,7496" 147057'23,0237" ' 2062,3~ ~2~14, t9 X- 2~9088,98 E' 464110,06t ~ 34 Y' ~982448,82 N- 7805313,13 170c2]'09,&64Z" 1470~7'27,,134" ~'19&9,38 2256,49 X- 258949,73 E' 464067,15 I 35 Y- 5962318.55 N- 7605274.02 "70°21'06,4203" 147°57'23.4&32" ~ '2095.14 2136.07 X- 259066,03 E- 464103.23 I 36 Y- 59824~&,05 N- 780~303.03 70°2~'09,3347' ~47c~7'2~',B229' 2002.17 2278,37 X- 258926.78 E- 464060.32 ~ 37 Y- 59B23~0.36 N- 7805271.50~ 70°21'0B.3379' 147057'23.B230'' 2~04.21 2141,55 X- 259060,30 E' 464101.53l 38 Y- ~982407,B6 N- 7805300.~1 70021'09.2~24' ~47°~7'27,9B27' 2011.24 2283.B4 X- 2~892~,0~ E- 4&40~8,&l 39 Y- ~982302.17 N- 7B0~268.98 7~21'OB,25S&' ~47~7'23.912~' 2~12.SI 2~4~.02 X- 2~90~4.~6 E' 464099.B2 , 40 Y- 5982399.&7 N- 7805297 98 ]70°2~'09.~700' ~47°57'28.~426' 20~9.&2 2289.3~ X- 2~89[~.3~ E- 4640~6~9~ ~' 41 Y' 5982293.97 N- 780~266.4~ ~70°21'08.~733' ~47~57'24.~427' 2120.9~ 2~52.49 X- 2~9048.83 r E' 464098.1~ ~ ' N- 780~295.46 70021'09,0877, 147057'28.3024, 2027.*~ 2294.7*' 42 Y- ~9~2391.48 1 X- 2~8909.58 i E' 4640~5.20 ~T~X~ MP! PR~SED WELL L~ATION LIST ~~~I~~*~~~~ ~ LOCATED IN SEC. 3G, T. 12N., R. I6 E. UMIAT M. ~~~~~~7,, , , SOHIO ALASKA PETROLEUMCO. ~~ff~~~A ~~~~~ DRW. NO. 115-$5 PREPARED BY _DATE'NOV'I~' 1~8~ ~ ~s~~__ ~ F.R BELL & ASSOC. k~~~-- SHEET 4 of IO ' SCALE: N/A ..... PRUOHO[ BAY O~CE .... ' ', REV. O PRUDHOE BAY, ~ASKA :DRAWN BY: · CHECKED BY: B.E. I I III I JI II _ I I I I I I --- II I III , I I I I I loll I UTh .ONf 6 L&TXTUIE LIL ...-~ll Illt(~ lilT(I) 43 ye 19122fl~'71 'N;,"7106263.93 70¢21'0i.0909'' i476117;24,14k~&' ' ~1~,11 x- '2~9043.09 E- 464096.4! 44 Y- $9i2583;29 Id, 760:5292.95 70c 21' 09. 00:54' ~ 1470'S702B.4623· 2036.36 2300.26 X- 2:58905.84 E- 4640:55.150 · 45 jY- 5982277,59 ' N-. 7805261.40 70:21'08,0086' 147c :57 ' 24, 4625' 2i'37.70 i X" 2:59037,36 E' 464094,70 46 Y. 1596237:5.2o ~. ?e0:5290.42 ?0=22,08.92~0-~147~*$7.28.62~2·; X' 2:58898,11 E' 4640:51,79 ' ! 4'7 Y''~982269,40 N' 7805258.88 70¢2~'07,92b~* 247¢~7'24,6223''?' ~'~ 2268.92 X- 2~9061.62 E- 464092.99 I ! 48 Y- $982666.91 N- 7106287.69 [70°21'08.6407'' 147°$7'26.7820i 2055.10! 2311.20 ~ . . . Ia 258892.37 E- 464050.08 49 Y- $962261.21 N- 780:5266.3~ 70021'07.8439' i47°57;24.712.2' 21S4.44'* 2174.3'8 X- 2:5902:5.69 E- 464091.29 $0 Y- ~9B2658.71 t4- 7606285.$6' 70021'08.71564' 14'7°~7'2S.941'1' 2061.47' 2616.&7 X- 258866,63 E- 464048.36 $1 Y- $982253.02 "N- 78062~$.1i$ 70021'07.'7616' 14'7°57'24.9420, 21&~.ll 2179.66 X- 259020.16 E- 464089.$8 $2 Y- $982~50.52 N- 780'$28i'.84 70c21'08.6760' 147°57';29.1017, 2069.1:5 '2322.14 X- 258880.90 E- 464046.67 $$ Y' $982244.'86 N- 780:52~1.31 70021'07.679:5' 147o$7'26.101'9' 2i71.19 216~.$$ · X- 259014.4l E- 464067.66 $4 Y- 5982342.33 N- 760:5200.31 70021 '08.:5957" 147°"57'29.2616" 2078.22| 2327;&2 X- 256875.16 E" 464044.96 55 Y' 5962236,64 N= 760:5246,78 70c21'07,5c~69' 147°57'25',2617' 2179,56 2190,60 X- 259008.68 E- 464086.17 36 Y- $982334.14 'N,, 78015277.79 70o21'08;5113· 147o57'29,4214· J'' 2066.$9I 2333,09 X- 2:58669.43 E- 464043.26 "'~7 Y- 5982228.44 N- 780:5246.26 70o21'07.:5~6" 1470§7'2:5.421&" 2287.93 2196.27 X- 259002,94 E- 464084,46 . . .J $6 Y-159823215.9:5N-7e0:527:5.27 70o21'08,4290' 147°$7:'29.$612" ' 2094.96 233'6.$6 X" 2:58866,&9 E- 464041,.15:5 59 Y- 5982220;'26 N- 780:5243.73 7(i)o21'07'~4323· 147o$7"26.$114· 2156.30 2201'.74 X- 268~97.21 E- 464082,T& 60 Y- $962517.76 N'-' 780:5272.74 70021*08.3467" 147°$7'29.7411" 2103.33"2344.03 X- 2:588157,96 E- 464039.8:5 62 Y- $982212.06 N- 7~0:5~'.21, 70o22'0'7.5499" 147o~7'2:5.7425" 2204.&7 2207.21 X" 2:58991.47 E' 464061.05 /)2 Y' $9132509,157. 14' 7605270.22 70c21'08.2646' 147°~S7'29.~009" 2111.71 2649.:50 X" 2:588:52.22 E' 464058.24 · &3 *y'""$9B2206,67 N, 7805238,/)'9 '70022'07,2"676, 147o~7'215,9011" 2213.0:5 2222,&9 X" 2158985.74 E" 464079.34 .......... _~,~.~,,~,~, , MPI PROPOSED WELL LOCATION LIST ~' .4 .... * * PREPARED FOR ~,...~~ ~.~. SOH ALASKA PETROLEUM CO. J ............... ;t. ,.,,..,,.-,,. · ...//-z ~'~'..;,':d" ~ DRW. NO. 116 - 815 PREPARED BY DATE: NO'/. f5, 4~k,~,'"'*~;SK:Xii'"----'~' SHEET 5of to F.R. BELL & ASSOC. :SCALE' "'~.,~a,,,i,~,~.,~-"' .... PRUDHOE BAY OFFICE DRAWN BY : RG.T _ , REV. 0 PRUDHOE BAY, ALASKA CHEC. KEO~Y' mi i ii Il I I I I II I~LL ~ ZONE I liT, , ,1 6 ~TI~I La K ll~ i4 V- 1912301.~ "k '7105267'.69 7F21"0'1',1120' 147~17'I0.0601' llP.fl i314.97 X- 25ll46.41 E' 464036.43 65 Y' ~982~9~.68 N' 7105236, S6 70~2t'OT,X852' ~47~57'26,06~0' 222:.43 22:1. t6 X- 2~8980.00 E- 464077.&4 66 ~Y' 596229T.~6 N' 7905265. t? '70:2~';08.0997~ ~47'57'~0~2206' 2~26.45 ~2360.4~- i 67 Y~ 59B'~-~'~.49 N= 7805233~64 i70'21'0~-i0~-9~'-'i47-57'26,2208' ,' 2229.80 ~2~2:3~63 :~ X 258974.26' E. 46407~ 93 6B "Y- 5982284,99 N- 7805262.64 i 70:'21'08.0173" ', 147~7'30.3805' 2~36.82" 2365.92 x. 258e35.0t, E. 4640~3.02 i9 'Y- ~982179.~0~ N- 710~2~l.tl 70~21'07.0206'' t47c~7'2~,3B07' 2231.17 2229. t0 x- 2~8968.~3~ E- 4~4074'23 70 Y- $gB227&,I0' N- '71'0~2~0. t2 70°2~'07.9350' t47°~7'3~'.5403' 214~.1~ i i MPI PRO~SEO WE~ L~ATI~ LIST _~ ~ 4~ ~ LOCATED IN SEC. $6,T. 12N.,R. IS[. UMIATH. ~--~~~*" ~ -- SOHIO ALASKA PETROLEUM CO. _ , ,. ~TE' NOV. 13,11a5 'IkD~"--~~ ~ SHEET s of lo F.R. LBELL ~ ASSOC. SC~E: qk~'~ssl~~ ~ PR U DHOE BAY OF FICE ~ ~~~ DRAWN IY' R.G~. e~. O PRUDHOE BAY, ALASKA '~ '1 IIII I I I II I I ENDICOTT DEVELOPMENT WELL 1-41/0-23 (MPI) SLOT 1-41 SURFACE LOCATION X = 259,049 FT ; Y = 5,982,294 FT 2121 FT SNL; 2153 FT WEL SEC, 36, T12N, R16E TRUE NORTH GRID S 52.5 E DEPARTURE TO TARGET: 4298 FT 11770 FT MD 10084 FT TVD BKB DEPARTURE TO BHL: 4762 FT 12424 FT MD 10546 FT TVD BKB J~/3- 12-87 .... Close~z.t Approach Anaigsis ...... Date' i? .... ', 'i ;:, R -. . -~ '.? Time' OB' 36' 41 ........... .2 zt.. - ,_, ] '- ':. 2-- i '7 ] L. c, c a t :;.. o n = W-E S-N TVO ( BBS ) Top '-~5c~('~4g c,,.q ~'~4 Off --D6 O0 · ~,~:.~ ~o ~o~,,~ 7~ 10490 '~ ~'~. 0 't; ~ o m ,=.,_.., ..:~ ~ ,, ~ ... ,.~ ......... ~ ..... . s, ~..., J Closest Approach !,,'~' PROPOSED", /NEARBY\ CLOSEST ~.... L T r3~N''r ' TVD DEPART TVD DEPART D I STANCE A02~-2064000 MISDiO AO~21 ~6800. MI-Pi8 A029-2158500 MI-MI9 A02~-2160500 MI -020 A029-2162500 . :;;; M I - ~21 A029-~ 163900 MI-016 A029-2164800 MI-Gl7 A029-2166200 MI-PI4 AO29-~166900 MI-M~5 A029--2167200 MI-O~5 A029-~169300 MI-P~O 10546. 0 . 3756.0 ~701. I 1600.6 200.9 4400.8 4200.8 18.3 273. 5 191. 7 200... O- ' 30. 0 227, 0 0.0 4199.~ 10.7 187. ! I000.0 0,0 ~800.7 0.0 1073.8 0.0 2900.3 0.0 1000.0 2799.8 1072. B 2899.8 4. 1 13.2 9.7 I8.4 180, 5 84. 6 23. 4 80. 7 TVD Ve~-tical intersec t~on OSED \ .," "'EAR, ,, ~ Y "- DEPART rVD DEPART 7986. 1 2192.4 10169.9 =186. 6 D I ~ TArxIC -.-.' ~L84. 3 SUMMARY The u, el] ~hich comes closest to the 200 proposed is' Closest dl'= OFF f'c,r- this run -= 4850. 0 Ceet ENDICO'I~ l(lI) PROGR~M~I 14AIl~ PRODUCTION ISLAND WELL 1-41/0-2~ (MPI) Interval 0-2,500 Mud Weight 8.8-9.8 viscosity (sec/at) -- 100-200 Fluld Loss ($1/3Omin) 20-15 9.0-9,5 Mud Type/ Co_m~onents feneric Mud #5 Seawater Fresh Water Soda Ash Set 13-3/8" Casing 2,500 - 11,163 9.2-10.2 40-45 10 -12 10.0-10.5 Generic Mud #7 Seawater Fresh Water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite New Drill Set 9-5/8" Casing 11,163 - 12,424 9,6-10.2 40-45 6-8 9.7-10.5 Generic Mud #? Seawater Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite New Drill Hang 7" Liner ]pm/ 1602D DOYON DRILLING, INC. RIG NO. 15 MUD AND SOLIDS CONTROL EQUIPMENT Equipment Manufacturer Nominal Model Capaci ty Shaker Desander Mudcieaners Centrifuge Brandt Damco Trt Flou Dual Double 2-12" cones 1000 9pm 700 9Pm (each) Double 400 9Pm 8 each - 4" (each) cones Pioneer Mark II, 150 gpm Decant i n 9 Vacuum 1000 9pm 8 each - 25 h,p. Desasser Drilco Agitators Brandt Hoppers Geosource Dual Sidewinders 1000 9pm The trip tank and mud tank sections have one vertical pit level float indicator which are connected to the drillin9 recorder system that contains visual and audio warnin9 devices located in the driller's console. DOUBT . . - ASK. II i I _ I~': 6.' T~N~ D~AMD ! )G-~ ' t I O: Iz:o.. I II:D' 1. It!~' i I? 'C ° q~ .. ~. . I II III II I I I I I C) ~r'~£, ~c..- - . VIE h~ -~ TESTING THE B.O.P. STACK WITH THE 13-1/8" x 4½" IF BOX X BOX, (THRU-BORE) , TEST PLUG (FIG. 7) 1.) Make up the 13-1/8" x 4½" IF test plug to a stand of drill pipe. (Illustration 9) NOTE: Sometimes it is helpful to make a stand of heavy wall up to the bottom of the test plug in order to help energize the compression packing. 2.) Lower the ~est plug through the B.O.P. stack until it lands on the lower load shoulder of the. split unihead unit. 3.) Run in at least two of the lower set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. NOTE: All lockdown screws can be run in if need to energize the compression packing on the test plug. 4.) Test the B.O.P. stack. 5.) Back out all lockdown screws which have been run in. 6.) Remove the test plug. 13-1/8" X 4-1/2" IF BOX X BOX (THRU-BORE) TEST PLUG THIS END UP L FMC P.N. 48-261-082 REQ'D PART NO. DESCRIPTION .. 1 48-261-268 Test Plug 1 48-261-083 Body 1 48-261-673 Compression Ring 4 79-040-074 Set Screws 1 48-081-529 Packing 1 51-092-001 2" Ball Check Figure #7 (Part number 48-261-082 continued on next page) FMC P.N. 48-261-082 continued REQ' D. PART NO. DESCRIPTION 1 19-505-663 Coil Spring 1 25-411-356 Retaining Plate , 1 25-411-357 Circ.-O-Lox Ring 2 48-180-027 Pipe Plug 1 52-304-013 Drlg. Pipe Sub. ILLUSTRATION 9 B.O.P. STACK 3-5/8" 5000 NP 3-5/8" 3000 WP TESTING THE B.O.P. STACK WITH THE 13%" X 4%" IF BOX X BOX, (UPPER), TEST PLUG (FIG. 19) 1.) Make up the 13%" x 4%" IF test plug (upper). to a stand of drill pipe. (Illustration 13) NOTE: Sometimes it is helpful to make a stand of heavy wall 6p to the bottom of the test plug in order to help energize the compression packing. 2.) Lower the test plug through the B.O.P. stack until it lands on the upper load shoulder of the split unihead unit. · 3.) Run in at least two of the upper, set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe-can be backed Out in order to test the blind rams. NOTE: All lockdown screws can be run in if you need to · energize the compression packing on the test plug. 4.) Test the B.O.P. stack· 5.) Back out all lockdown screws which have been run in. 6.) Remove the test plug. 13-1/2" X 4-1/2" IF BOX X BOX (UPPER) TEST PLUG FMC P.N. 48-261-068 REQ'D PART NO. DESCRIPTION 1 48-261-067 Body 1 48-261-671 Compression Ring 4 79-040-074 Set Screw 1 82-741-117 Packing 1 51-092-001 2" Ball Check 1 19-505-663 Coil Spring 1 25-411-356 Retaining Plate 1 25-411-357 Circ.-O-Lox Ring 2 48-180-027 Pipe Plug IS END UP Figure #19 ILLUSTRATION ~ 13 :5/8" STACK 5000 WP Z3-5/8" 3000 WP TESTING THE B.O.P. STACK WITH THE 10" X 4-1/2" IF BOX X BOX (COMBINATION) , TEST PLUG (FIG. 22A) 1.) Make up the 10" x 4%" IF test plug (.combination) to a stand of drill pipe. 2.) Lower the test plug through the B.O.P. stack until it lands on the upper load shoulder of the tubing/casing head. 3.) Rin in at least two of the upper set of lockdown screws 180" opposed tO hold the test plug in place. This is so the drill PiPe can be backed out in order to test the blind rams. 4.) Test the B.O.P. stack. 5.) Back out all the lockdown scres which have been run in. 6.) Remove the test plug. 10" COMBINATION TEST PLUG AND BOWL PROTECTOR RUNNING/RETRIEVING TOOL THIS END UP FMC PART NO. 48-261-503 REQ'D. -~--N'~-~-- DESCRIPTION 1 48-261-504 BODY . , 1 48-085-833 BELT PACKING 1 48-180-025 PLUG, 1¼ L.P. , , 1 48-180-025 PLUG, 1¼ L'P. 4 48-180-015 PLUG, ½ L.P. 1 48-010-009 WRENCH .. (Figure #22A) ~ B.O.P. STACK ..... ...... 1" 5000 WP 13-5/8" 3000 ~ B.O.P. STACK - 11" 5O00 wP 11" 5000 WP ! 13-5/8" 3000 WP CHE~ LIST FOR NEW W~.~. PERMITS ITEM APPROVE DATE (1) Fee ~" ~-~/.~ 1. (2) Loc .?.4r7 2. (2 thru 8) ~... 4 · 5 6. 7. 8. (3) Admin ~-~,, ?~'-Y~7 9. ~ (9 ? 13) 10. (10 ~d i3) . 12. 13. (4) Casg ~,~/3-=~-8 ? (14 t~ 22) (5) BOPE (23 thru 28) (6) OTHER (29 thru 31) (6) Add: Company YES Is the permit fee attached .......................................... ~ Is well to be located in a defined pool ............................. .~'~ Is well located proper distance from property line ......... Is well located proper distance from other wells ............. ~ ~~ Is sufficient undedicated acreage available in this pool ~'~""'"' ~ Is well to be deviated and is wellbore plat included ................ ~ Is operator the only affected party ................................. ~ Can permit be approved before fifteen-day wait ...................... ~ Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval-needed ................................... Is the lease number appropriate ................................. ~ Does the well have a unique name and number . [ ....... ~.. ~ .... ~. ~ Lease & Well No. NO 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided .... · · · · ********************************** Will surface easing protect fresh water zones ....................... Is enough cemmnt used to circulate on conductor and surface ......... Will cement tie in surface and intermmdiate or production strings ... Will cement cover all known productive horizons ..................... 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 abandommnt procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required .......................... . ............. Is tb~ drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of ~ ~ BO~ attached. Does BOPE bare sufficient pressure rating - Test to Jooo/~-~o~ psig .. Does the choke manifold comply w/API RP-53 (May 84)....z. ............. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. For 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. Geolo~f: Eng~e~/_n~: wws ACS rev: 01/28/87 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS gEA2US AREA- NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No special'effort has been made to chronologically organize this category of information. -.. · ,. 1 - 41/0 - 23 ENDICOTT Run I' 20 - September - 1~9a PDK-1001GR 1050 1875 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1-41 / 0-23 (MPI) 500292171300 B.P. EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 18-OCT-93 6004.01 R. IORIO M. MARTIN 36 12N 16E 2121 2153 56.30 55.30 14.50 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 11024.0 47.00 7.000 12020.0 29.00 4.500 10684.0 12.75 3.500 10794.0 9.20 BASELINE DEPTH 11037.5 11040.5 11056.0 11056.5 11057.5 11058.0 11063.0 11066.0 11072.5 11083.0 11084.5 11085.5 11086.5 -- EQUIVALENT UNSHIFTED DEPTH SCHLUMBERGER WELL SERVICES TDT GR GRCH 11030.0 11033.5 11048.0 11048.5 11049.0 11049.5 11056.0 11059.0 11065.5 11076.5 11078.0 11078.5 11079.5 11095.5 11097.5 11098.5 11099.5 11112.5 11113.5 11122.0 11133.5 11159.0 11160.5 11161.5 11163.0 11181.0 11187.5 11191.5 11193.5 11200.0 11229.0 11240.5 11250.0 11255.0 11259.0 11270.5 11273.5 11280.5 11285.5 11292.0 11314.5 11326.5 11334.5 11349.0 11365.5 11371.5 11378.0 11394.0 11397.0 11399.0 11408.5 11411.5 11412.5 11414.0 11422.5 11428.0 11429.0 11430.0 11442.0 11457.0 11460.5 11471.5 11484.5 11486.5 11494.5 11498.5 11502.5 11510.0 11523.5 11562.5 11563.5 11564.0 11567.5 11089.5 11091.5 11092.0 11093.0 11107.0 11108.0 11116.5 11129.0 11154.0 11155.5 11156.0 11157.5 11176.0 11182.5 11186.5 11188.5 11195.5 11225.0 11236.0 11246.5 11251.5 11255.5 11266.0 11270.0 11276.5 11281.5 11288.0 11306.5 11320.5 11329.0 11342.0 11358.0 11363.5 11371.0 11386.5 11389.5 11391.5 11401.5 11404.5 11405.0 11406.5 11415.5 11421.0 11422.5 11423.5 11434.0 11450.0 11453.0 11465.0 11477.0 11479.0 11487.0 11493.0 11496.0 11504.5 11516.5 11554.5 11555.5 11556.5 11560.0 11568.5 11590.0 11595.5 11602.0 11609.5 11610.5 116]_4.0 11636.0 11646.0 11705.0 11724.5 11728.0 11736.0 11744.5 11754.5 11762.0 11765.0 11765.5 11766.0 11766.5 11862.5 $ REMARKS: 11560.5 11582.5 11588.0 11595.0 11602.5 11603.5 11607.0 11629.5 11638.0 11697.0 11716.0 11719.5 11727.0 11735.0 11745.0 11753.0 11757.5 11758.5 11759.0 11759.5 11853.5 PDK-100/GR Log. LOG TIED INTO CET RUN 01-MAY-1987. THIS DATA WAS DEPTH MATCHED TO A PREVIOUS TDT GR. THE PREVIOUS TDT WAS FOUND TO BE OFF DEPTH WITH THE OPEN HOLE GR. AT THE CLIENTS REQUEST, THIS DATA WAS LEFT DEPTH MATCHED TO THE TDT. LOGGING PROGRAM ORGANIZATION: 1. LOGGED BASE GR (SOURCE OFF) WITH WELL SHUT-IN. 2. LOGGED FLOWING PASS AT 20 BEAN CHOKE SETTING. 3. PUMPED IN SEAWATER AND MADE 3 PASSES WHILE PUMPING .5 BBLS/MIN SEAWATER. PRODUCTION RATES (30-JUL-93): BOPD = 1315 GOR = 5930 SCF/STB WC = 30% WHFP = 2731 PSIG @ 148 DEGF CHOKE = 40 BEANS CURRENT RATES: WHFP = 2800 PSIG @ 102 DEGF IAP = 50 PSIG CHOKE = 40 BEANS A DIFFUSION CORRECTED SGMA CURVE IS INCLUDED FOR EACH PASS. THE CURVE IS NAMED SGNT AND WAS CORRECTED WITH THE FOLLOWING PARAMETERS: BOREHOLE SIZE = 8" CASING SIZE = 7" SALINITY = 0 PPM - FLOWING PASS SALINITY = 25,000 PPM - PUMP IN PASSES OPEN HOLE GAMMA RAY FOR DEPTH MATCHING SUPPLIED BY BP EXPLORATION (ALASKA) INC. ON 10-0CT-93. SHIFT PROCEDURE AS FOLLOWS: 1. FIRST PASS GAMMA RAY DEPTH MATCHED TO PREVIOUS TDT GAMMA RAY. 2. FIRST PASS SGMA DEPTH MATCHED TO "SHIFTED" FIRST GAMMA RAY. 3. ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4. ALL SUBSEQUENT SGMA (PDK) PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS SGMA. / ??MATCH2. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 11028.0 PDK 11040.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH SGMA 1105S.0 11052.0 11063.0 11056.0 11066.0 11059.0 11072.5 11065.5 11088.5 11081.5 11101.0 11094.5 11112.5 11107.0 11113.5 11108.0 11122.0 11116.5 11128.0 11122.5 11133.0 11128.0 11169.5 11164.5 11187.5 11183.5 11191.0 11186.5 11193.5 11188.5 11195.0 11190.0 11200.0 11195.5 11225.0 11221.5 11229.0 11225.0 11240.5 11236.0 11250.0 11246.5 11255.0 11251.5 11259.0 11255.5 11270.5 11267.0 11273.5 11270.0 11280.5 11276.5 11285.5 11281.5 11292.0 11287.0 11314.5 11306.5 11334.5 11327.5 11349.0 11342.0 11365.5 11358.0 11371.5 11363.5 11378.0 11371.0 11394.0 11386.5 11397.0 11389.5 11399.0 11391.5 114©4.5 11397.0 11411.0 11404.0 for each pass in separate files. STOP DEPTH 11858.0 11870.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH 11422.5 11428.0 11429.0 11430.0 11442.0 11457.0 11460.5 11471.5 11484.5 11486.5 11494.5 11498.5 11502.5 11510.0 11523.5 11562.5 11563.5 11564.0 11567.5 11568.5 11590.0 11595.5 11602.0 11609.5 11610.5 11614.0 11636.0 116~6.0 11663.0 11705.0 11724.5 11728.0 11736.0 11744.5 11754.5 11762.0 11765.0 11765.5 11766.0 11766.5 11862.5 $ REMARKS: 11415.5 11421.0 11422.5 11423.5 11434.0 11450.0 11453.0 11465.0 11477.0 11479.0 11487.0 11493.0 11496.0 11504.5 11516.5 11554.5 11555.5 11556.5 11560.0 11560.5 11582.5 11588.0 11595.0 11602.5 11603.5 11607.0 11627.5 11637.0 11654.0 11697.0 11716.0 11719.5 11727.0 11735.0 11745.0 11753.0 11757.5 11758.5 11759.0 11759.5 11853.5 FLOWING PASS. ALL PDK CURVES WERE SHIFTED WITH SGMA. CN WN FN COUN STAT / ??MATCH3. OUT $ : B.P. EXPLORATION : 1-41 / 0-23 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# ONE DEPTH PER FRAME 64) Tape depth ID: F 15 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS 15 SGNT PDK 68 1 CU 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 4 4 00 201 24 1 60 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 117 Tape File Start Depth = 11885.000000 Tape File End Depth = 11015.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Co~e: 68 27857 datums Tape Subfile: 2 425 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 11030.0 11042.0 BASELINE DEPTH GRCH 11038.0 11030.5 11057.5 11058.5 11048.5 11059.5 11051.5 11060.5 11061.0 11061.5 11054.0 11072.0 11064.5 11073.0 11074.5 11067.0 11075.5 11078.0 11084.0 11076.0 11084.5 11076.5 110~5.0 11077.5 11086.0 11078.5 11086.5 110~7.0 11092.5 11085.0 11094.5 11095.0 11097.0 11089.0 11098.0 11090.0 11099.0 11091.5 11100.5 11093.0 11102.0 11103.5 11111.0 11104.5 11115.5 11109.0 11119.5 11114.0 11120.0 11121.0 11122.0 11123.0 11123.5 11128.5 11129.0 11116.5 STOP DEPTH 11858.0 11870.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 11049.0 11052.0 11053.0 11053.5 11064.5 11067.0 11070.0 11078.5 11079.5 11087.0 11088.0 11095.0 11097.0 11116.5 11117.5 11122.5 11123.5 11113.5 11114.0 11114.5 11130.5 11133.0 11133.5 11138.5 llld3.0 11147.0 11160.5 11162.5 11163.0 11168.0 lllS3.0 11183.5 111~4.0 11192.0 11192.5 11193.5 11194.5 11195.0 11198.0 112]0.0 11210.5 11213.5 11214.0 11215.5 11218.5 11219.5 11222.0 11225.0 11226.0 11228.5 11229.5 11236.0 11240.5 11242.0 11242.5 11245.5 11247.5 112~8.0 11259.5 11260.5 11262.0 11265.5 11267.5 11268.0 11270.5 11279.0 112g0.5 11282.0 11283.0 11295.5 11292.0 11296.5 11314.0 11314.5 11321.5 11322.0 11320.0 11334.5 1133~.0 113~,0 11125.0 11129.0 11154.5 11156.5 11157.5 11177.5 11186.0 11187.0 11188.0 11192.5 11211.0 11217.5 11221.0 11224.5 11235.5 11238.5 11241.5 11255.5 11256.0 11257.5 11262.5 11263.0 11274.5 11277.5 11278.0 11280.5 11291.0 11315.0 11323.5 11332.5 11127.5 11133.0 11137.5 11141.5 11163.0 11178.0 11178.5 11189.0 11190.0 11205.0 11206.0 11209.0 11210.0 11214.5 11215.0 11220.5 11221.0 11225.0 11230.5 11237.0 11238.0 11243.0 11244.0 11255.0 11261.5 11266.5 11275.5 11286.5 11305.5 11306.5 11313.5 11314.5 11327.0 11338.5 113,~0.0 113gl.5 113~,6.5 11370.5 11371.0 l13gO.O 11393.0 11324.0 113~4.5 11393.0 11401.0 11401.5 114n4.o 114.1_1.o 11413.5 114]_5.o 11419.5 1142o.0 11422.5 11425.5 11426.5 11428.5 11431.5 11432.5 11436.5 11441.5 114~3.5 114~4.0 11453.5 11459.0 114~1.5 114~2.0 114~7.0 114~,7.5 11470.0 114'73.0 11475.5 11476.5 114~0.5 114P. 3.5 11485.0 114~6.0 11496.5 114P~7.0 11490.0 11490.5 11493.5 ll~g4.0 115n0.5 11501.5 115~3.0 11503.5 11507.0 11508.0 11509.0 llS]O.O 115~.5 115!l.0 11513.0 11341.0 11361.5 11376.0 11376.5 11385.5 11393.5 11396.0 11406.5 11412.0 11421.5 11435.5 11446.0 11451.5 11454.0 11463.0 11469.5 11476.0 11477.5 11483.0 11495.0 11498.0 11502.0 11503.0 11503.5 11353.0 11358.0 11363.5 11373.0 11375.5 11376.0 11393.0 11394.0 11403.5 11407.5 11412.5 11415.5 11418.5 11419.0 11424.0 11424.5 11428.5 11435.5 11436.5 11454.0 11455.0 11460.0 11461.0 11466.5 11468.5 11469.5 11473.0 11477.5 11478.0 11478.5 11479.5 11482.5 11486.5 11487.5 11494.0 11497.0 11501.0 11501.5 11503.5 11504.0 11504.5 11506.5 11514,0 11514,5 11519.0 11524.5 11531.0 11532.0 11535.5 11536.0 11539.5 11540.5 11547.5 11550.0 11559.0 11563.5 11567.0 l15Ag. O 11568.5 11569.0 11573.5 115R6.5 11597.0 115A9.0 11599.0 11599.5 116~2.5 11603.5 11611.5 116t3.0 11614.0 116~4.5 11615.0 11615.5 11647.5 l16~g.O 11619.0 11622.5 11623.5 11625.0 11631.0 11633.0 11635.5 11636.0 11639.0 11642.0 116~3.0 11646.0 116~8.5 11651.0 11651.5 11652.0 l16AO.O 116A0.5 116~3.5 116A5.5 116~3.0 116~4.0 117~1.5 117~2.5 llanO.5 117o5.5 11517.0 11540.0 11551.0 11559.0 11559.5 11560.5 11565.5 11578.5 11579.5 11591.5 11604.0 11607.0 11608.5 11611.0 11611.5 11615.0 11616.5 11618.0 11624.0 11626.5 11629.0 11632.0 11634.0 11634.5 11640.5 11642.5 11643.0 11643.5 11651.5 11652.5 11657.5 11675.0 11675.5 11694.0 11507.0 11507.5 11511.5 11523.5 11524.0 11527.5 11528.5 11532.0 11532.5 11542.5 11555.5 11560.5 11581.5 11591.5 11592.5 11595.5 11596.0 11605.5 11606.0 11606.5 11607.5 11609.0 11627.5 11637.5 11654.0 11693.5 11694.5 11695.0 11697.0 11711.0 1]72~.5 1172~.5 11735.5 117~2.0 117~4 .0 11749.0 11754 .0 11754.5 11759.0 11762.0 117~.5. 0 117~6.5 llT?g.0 117~3.5 117~7.0 117~7.5 11799.5 ll~nt.5 11~2.0 11~4 5 11~0.0 11~3.5 11~20.5 llR21.0 11822.0 11~25.5 11829.0 11R29.5 11936.0 llg~A.0 llgSg.0 118~0.5 llg~,7.5 118~9.5 11870.0 $ REMAR¥g: 11726.5 11734.5 11745.0 11753.5 11759.5 11775.5 11779.0 11780.0 11792.5 11794.5 11797.0 11806.0 11812.0 11814.0 11817.0 11820.5 11821.0 11827.5 11838.0 11849.0 11851.0 11702.5 11712.0 11720.0 11733.0 11740.5 11744.0 11750.0 11752.5 11757.5 11771.0 11776.0 11794.0 11796.5 11801.5 11812.5 11852.0 11860.0 11862.0 11862.5 PUMP-IN PASS 1. ALL PDK CURVES WERE SHIFTED WITH SGMA. CN ~'~N COUN STAT / ? ?MATCH4 . OUT / ? ?MATCH5. OUT $ : B.P. EXPLORATION : 1-41 / 0-23 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape de~th ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod l GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 ~ LS PDK 68 1 CPS 4 7 MSD PDK 68 1 CU 4 S RATO PDK 68 1 4 9 RBOR PDK 68 1 4 10 RICS PDK 68 1 4 11 RIN PDK 68 1 4 12 SGMA PDK 68 1 CU 4 13 SGMB PDK 68 1 CU 4 14 SS PDK 68 1 CPS 4 15 SGNT PDK 68 1 CU 4 16 PHI PDK 68 1 PU-S 4 4 00 201 24 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 64 * DATA RECORD (TYPE# 0) T©tal Data Records: 125 958 BYTES * Tape File Start Depth = 11885.000000 Tape File End Depth = 11015.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Co~e- 68 29598 datums Tape Subfile: 3 412 records... Minimu~ record length: Maximum record length: 62 bytes 958 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: EDITED CURVES Depth shifted PASS NUMBER: DEPTH I~CREMENT: FILE SU~4MARY PBU TOOL CODE GRCH PD~ $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS ~BU CURVE CODE: GRCH ~ASS NUMBER: 1 3 and clipped curves for each pass 3 0.5000 START DEPTH STOP DEPTH 11028.0 11858.0 11040.0 11870.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 11040.5 11041.0 BASELINE DEPTH GRCH 11o~7.5 11~57.0 11051.0 11058.0 11051.5 11058.5 11050.5 ll0&0.0 11053.5 11~1.0 11054.0 11053.0 ll~S.0 11061.0 110~3.5 11066.0 110S2.5 11075.0 110~7.5 11080.0 11~8.0 11081.0 11091.0 11083.5 11093.5 11086.5 lln~4.0 11087.0 11087.5 11097.0 11090.0 1109R.5 11091.5 11~99.0 11092.5 ll].n0.0 11093.5 11]~2.0 11095.5 111~3.5 11097.5 11]!0.0 11104.0 11110.5 11105.0 11111.5 11105.5 11113.5 11107.5 11120.0 11115.5 11122.5 11118.0 11123.0 11117.5 11]~9.0 11123.5 11129.5 11124.5 11~l.0 11126.0 11~9.5 11133.0 113~2.0 11135.5 11~.5 11137.5 111~.0 11141.0 11~ ~.0 11144.5 11157.5 11152.0 in separate files. 1115R.5 11]59.5 lll~rt.O 11170.0 1112,3.0 ll].g4.0 11]g4.5 111~5.0 112q5.0 112o9.5 11210.0 11213.5 11214.0 112].5.5 11218.5 11219.5 11224.5 11225.5 1122~.0 11229.5 11236.0 11242.0 112,12.5 11253.0 11253.5 11259.5 112~Q.5 112~6.0 l12g?.O 1'1.2 ~,g. 0 11277.0 l12Vg. O 112-~9.0 112~!.5 112~,2.5 l12n~.O 112e5.0 112e~.5 112e7.0 112~2.~ 112~'~.0 11311.5 11312.5 113]~.0 113~7.5 113~.0 11322.0 11322.5 11323.0 11323.5 11330.0 11331.0 11334.0 113-~.5 1135~.5 11357.0 113q7.5 113Fq.5 11~.0 113~.5 11152.5 11153.5 11154.5 11189.0 11211.5 11221.5 11222.5 11256.0 11256.5 11264.0 11274.5 11279.5 11280.0 11282.0 11309.0 11310.5 11311.5 11316.5 11317.5 11324.0 11324.5 11165.0 11178.5 11179.0 11189.5 11190.5 11200.5 11205.0 11206.0 11209.5 11210.5 11215.0 11215.5 11220.5 11221.0 11225.0 11231.0 11237.5 11238.5 11249.0 11250.0 11255.5 11262.5 11263.0 11273.0 11273.5 11277.0 11277.5 11281.5 11287.0 11291.0 11303.5 11305.0 11314.5 11315.5 11327.0 11339.5 11342.5 11349.0 11350.0 11352.0 11355.0 11358.5 1137]_.0 113e2.5 113~3.0 11323.5 11394.5 11391.5 11394.0 11399.5 11401.5 114n2.0 11~,]1.0 11412.0 11412.5 114!6.5 11417.0 11424.5 11425.5 11426.0 11~26.5 11427.5 llamA.5 11~3~.0 11420.5 11~3] .g 11471.5 11~-32.0 11436.5 11~2.0 11~ ~ 7.5 ll~.~g.O 11~51.0 11452.0 11~53.0 11453.5 11~5~ .0 11~1.0 11 .~. ~ 1.5 11~3.5 11~4.0 11~ ~,~ .5 11~?1.5 11~7~.0 11478.0 ll~g.5 ll~?O.O 11~3.5 11~5.0 11~6.5 ll~eg.O 11~90.5 11~03.0 11~7.0 11501.0 115n2.0 115o2.5 1 1 F,~ 5 . 0 1 ]_ ~, !'~7 . 5 1t5'~.5 115~.5 11375.0 11376.5 11384.5 11392.5 11394.0 11404.5 11405.5 11419.0 11420.0 11421.0 11421.5 11422.0 11422.5 11423.0 11423.5 11435.0 11445.0 11445.5 11453.5 11454.5 11456.5 11476.0 11477.5 11479.5 11481.0 11491.0 11496.0 11497.0 11502.0 11502.5 11364.0 11375.5 11376.0 11387.0 11394.0 11395.0 11403.5 11409.5 11410.5 11418.0 11418.5 11424.0 11424.5 11429.0 11440.0 11441.0 11444.0 11444.5 11446.0 11447.0 11457.0 11458.0 11465.0 11468.5 11469.5 11470.0 11470.5 11471.5 11483.0 11486.5 11494.5 11496.5 11499.0 11501.5 11502.0 11504.0 llS~].n 1157i.5 115~2.n 115]_3.0 11514.0 llS1G.O 11527.0 1152~.0 11574.5 115~5.5 11537.0 11538.0 11539.0 11530.5 1155~.5 11556.5 11559.5 115~3.5 11564.0 115~4.5 115~2.5 115~9.5 115c2.5 1~5~3.0 115~].5 llSe~.O 1!5e?.5 ll5CR.O 115e9.0 115e9.5 ll~n2.0 ll~n3.0 11611.5 11~]3.0 11~]~.0 116]~.5 11615.0 11~25.5 11~2~.0 1]~2~.5 11~1.0 116~3.0 11~34.0 11634.5 11635.5 11636.0 ll~n.5 116dl.5 11646.0 11650.5 11651.0 11~3.0 116~.5 11~05.0 117~.5 11~1.5 117~2.5 1]_7~9 .0 11~ .0 11~4.5 11505.0 11505.5 11506.5 11507.0 11527.5 11528.0 11549.0 11551.5 11555.5 11556.0 11556.5 11564.5 11565.5 11574.0 11578.0 11579.5 11581.5 11607.0 11608.0 11618.5 11619.5 11621.0 11624.0 11626.0 11626.5 11627.0 11627.5 11632.5 11633.0 11642.0 11643.0 11655.0 11692.5 11693.0 11694.0 11504.5 11505.0 11507.5 11509.0 11520.0 11520.5 11529.5 11530.0 11531.0 11532.0 11543.0 11556.0 11556.5 11560.5 11563.5 11582.0 11582.5 11595.0 11595.5 11604.5 11605.5 11606.0 11627.5 11636.5 11653.0 11686.0 11687.0 11695.0 11695.5 11706.0 11~'~2 0 11~2~.. 5 11725.5 11742.5 117~'~,~.0 117,~, 9.0 11750.0 11759.5 117~3.0 117~3.5 117~5.0 11765.5 117~7 5 llTSq.0 11709.0 117~0.0 11~nn 5 11°~3 0 11~2~ 5 11836.0 11~2.0 llR~.2.5 $ 11719.5 11719.5 11727.5 11732.5 11734.5 11739.0 11740.5 11745.0 11749.0 11752.0 11755.5 11756.5 11758.0 11758.5 11775.0 11779.5 11780.5 11781.5 11782.0 11793.5 11794.0 11801.0 11804.5 11810.5 11812.0 11827.0 11832.5 11845.0 11851.0 11853.0 11853.5 PUMP IN PASS 2. ALL PDK CURVES WERE SHIFTED WITH SGMA. ~,~ COUN STAT / ? ?MATCH6. OUT / ? ?MATCH7 . OUT $ : B.P. EXPLORATION : 1-41 / 0-23 : ENDICOTT : NORTH SLOPE : ALASKA * FOR;.~AT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape ~cpth ID: F 16 Curves: ~ame Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod ~ GRCH PDK 68 2 BIF PDK 68 1 GAPI 1 4 00 201 24 1 4 00 201 24 1 3 BKL PDK 68 1 CPS ~ BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU ~ RATO PDK 68 1 9 RBOR PDK 68 1 1~ RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS 15 SGNT PDK 68 1 CU 16 PHI PDK 68 1 PU-S * DATA RECORD (TYPE# 0) Total Data Records: 125 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 64 958 BYTES * T~De File Start Depth = 11885.000000 Tape File End Depth = 11015.000000 ?ape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Co~e: 68 57455 datums Tape Subfile: 4 406 records... Minim~m record length: Maxim~m record length: 62 bytes 958 bytes Tape S~bfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS ~,T~_T~.~BER: 4 DEPTH I~,~CREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH ~ASS NUMBER: 1 START DEPTH 11028.0 11040.0 BAS ELIN 11~29.0 lln~O 5 ilO3~.o i1040.5 11044 .0 11057.0 11057.5 11©5~.0 l10a2.0 11064. 5 11072.5 11073.0 11077.5 ll0?g.0 11n°2.5 11oo3.5 lln~9 5 iinon.o linen.5 11093.5 11o96.5 11007.0 I1]nl.0 11]~2.0 ll]n~.5 ii] n~. o lli~.o 11~!.?.0 11] !?. 5 1Il~7 5 11] 3P~. 5 E DEPTH GRCH 11021.0 11022.5 11028.5 11033.0 11036.5 11049.5 11050.5 11052.0 11054.5 11057.0 11064.5 11074.5 11081.0 11081.5 11082.0 11086.0 11089.5 11093.5 11103.0 11110.0 11113.5 11119.5 11128.5 STOP DEPTH 11858.0 11870.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH SGMA 11037.0 11049.5 11065.0 11070.0 11070.5 11071.0 11075.0 11076.0 11082.0 11083.0 11089.5 11094.0 11095,5 11102.0 11103.0 11110.0 11110.5 11111.5 11121.0 11127.5 11133.5 1].!~&.5 11 ] '%%. 5 1115~.0 11]_56.5 11157.5 11158.5 ll]&3.0 ll!&~.O 11]~,7.0 ll].&g.5 11]P2.5 11]~3.0 111~3.5 11192.5 11!~3.0 11!9~5. 0 11].~.0 112~B.5 1] 2 ~ .0 11214.5 112~.5 112[~5.0 1127~.0 112~e.5 112~7.0 112~'e.5 112~9.0 112 '~2.5 112 ,~ 5. 5 11259.0 l12~g.O 112~.0 112~.5 11273 . 5 11~-~.5 11~'~ 5 l127g. 5 112~] .0 112~2.0 ll~g3.0 112~4.0 112~.0 112~2.5 11297.0 11]~.5 117~!.0 1]B?g.5 11~9.0 11~74.5 ll]?g.O 11~9.0 11~5.5 ll?~q.5 1]?=]..0 1] ? :~2 . 0 11147.0 11149.5 11150.5 11157.5 11160.5 11176.5 11177.0 11178.0 11187.5 11189.5 11193.0 11210.0 11215.5 11224.0 11233.5 11239.0 11254.5 11255.0 11263.0 11269.0 11274.0 11278.5 11279.0 11281.0 11291.5 11314.0 11315.0 11322.0 11322.5 11333.0 11141.5 11151.0 11151.5 11152.0 11153.0 11161.5 11163.5 11177.5 11178.0 11187.0 11188.0 11189.5 11198.5 11199.5 11205.0 11220.5 11221.0 11233.5 11234.5 11241.0 11255.0 11266.5 11272.0 11272.5 11276.0 11276.5 11280.5 11286.5 11291.0 11312.5 11313.5 11320.5 11321.0 11322.0 11327.0 11330.5 11338.0 11341.5 11343.0 11343.5 11344.0 11353.n 1] ~7 -~ . o i~3~o.5 1137].0 llD??.5 113e3 .0 113~4 .O 113Q~.5 11391.0 11391.5 11~00.0 llanO.5 ll~nl,O 11,~3.5 11~ ~ . 5 11~ ]_3.5 11~]4.0 11~5.0 ll~]A.O 11~27.0 11~20.5 11,~.5 ll~F2.0 1]~3.0 1]~?R.5 11~.~.5 1 ]..~ ~. 0 ll~A~.O 11,~].0 11~.0 1].~ ~.~. 5 ll~A?.O 11~ ~iQ . 0 11~ ~-~. 0 ll~.P2.0 ll~PS. 0 11~ ~ 5 5 . :~, ll~Pq.5 1].~A.5 1]~ag.0 11~3.0 11~94 .5 ll~f~9.0 115n2.0 llDa? . 5 115~] .5 1].5~.5 llT~g.O 115R1.5 11352.5 11363.0 11375.0 11375.5 11384.0 11393.0 11396.0 11400.5 11407.5 11409.0 11420.0 11420.5 11421.0 11422.0 11443.0 11451.5 11453.0 11459.0 11460.0 11462.5 11474.0 11477.0 11478.0 11480.0 11487.0 11491.0 11492.5 11514.5 11345.0 11358.0 11362.0 11370.0 11382.0 11383.0 11392.0 11393.0 11396.5 11406.0 11407.0 11419.0 11419.5 11424.5 11425.0 11430.0 11431.0 11452.5 11454.0 11459.0 11460.0 11460.5 11461.0 11465.0 11472.5 11480.0 11480.5 11481.5 11485.5 11495.0 11496.0 11500.5 11501.0 11505.0 11505.5 11507.0 11510.5 11522.5 11523.5 115q2.0 11533.0 11523.5 1153~.5 115F~.O 1~5~.5 1157v.5 1157~.5 115~.5 115~5.0 115,~7.5 115,~.5 11553.5 11554.0 1!5=5.0. 115~.0 1155~.5 1]~.0 1].55~.0 115~,2.5 11~3.5 117..<~.5 115'~.5 1156e.0 115~q.5 115-~ .0 115~%.0 1!5~.5 115o].5 1]_5~5.5 115e6.0 llS°S.O l!5~e.O ll~q©.O 11~2.0 1!~,-.2.5 11~iI.5 1!~2.© 1].~ .0 1]~n.5 1].~'~3.0 11~£3.5 11~.0 11~.0 11~79.5 llg~3.0 11~6.5 11~77.5 11~,~5.5 11~9.0 1] ~ - 0 1 ] ~ :~ '~ · 5 1 1~'~ 4.5 11515.5 11516.0 11526.0 11526.5 11531.5 11537.5 11540.0 11540.5 11545.5 11546.5 11547.5 11550.0 11554.5 11555.0 11559.5 11560.5 11566.0 11566.5 11567.0 11577.5 11578.5 11591.5 11595.0 11604.0 11611.0 11615.5 11616.5 11620.0 11622.0 11625.5 11626.0 11628.5 11629.0 11640.5 11656.0 11524.5 11525.0 11528.0 11529.0 11530.0 11530.5 11548.0 11548.5 11549.0 11555.5 11556.0 11559.0 11572.5 11573.5 11580.5 11590.5 11591.5 11592.0 11592.5 11595.5 11604.5 11605.5 11614.5 11615.0 11624.0 11624.5 11636.5 11650.5 11651.5 11652.0 1] G~i6. 5 11~71.0 11671.5 ll~,e4 .5 116~5. 5 11~9~ · 0 11~?~4 .5 li~5.0 11696.0 llTnl. O ll~nt.5 117n2.5 11775.5 11710.0 117~7.5 117~.5 11~ -~ 2 . 0 llV-< ~ . 0 11=~5.5 11v52.0 1]~2.5 llV<!.5 117~2.0 llV.<~3.0 117,<.5. 5 117~0.5 11r~2.5 ll?Pg.O llVPg.0 1!~9.5 11~2.0 llP~2. 5 llQ!7. 5 11o?2.5 11920.5 llPCT.0 11933.0 11~23.5 11~34 .0 11P35.0 11S26.5 11~ ~ 0.5 1 ].P~ 2.0 11~2.5 1].~." 5.5 ~1~ :~9.0 1!°57.5 ii_Poi.5 11~5.5 11657.0 11657.5 11658.0 11662.5 11663.5 11676.5 11677.0 11685.5 11686.5 11687.0 11687.5 11691.5 11692.0 11692.5 11693.0 11719.5 11734.0 11742.5 11749.0 11752.5 11755.5 11758.0 11774.0 11794.0 11807.5 11812.0 11818.0 11824.0 11825.0 11825.5 11826.0 11827.0 11828.0 11830.5 11831.5 11836.0 11843.0 11850.0 11853.5 11697.5 11701.0 11718.5 11719.0 11732.5 11736.0 11749.0 11752.5 11759.0 11759.5 11763.0 11780.5 11781.0 11791.5 11792.0 11794.0 11809.0 11809.5 11833.0 11834.0 11837.0 11840.0 11853.5 11866.5 PUMP-IN PASS 3. ALL PDK CURVES WERE SHIFTED WITH SGMA. COUN ~TAT /??MATCH8. OUT / ? ?MATCH9 . OUT $ : B.P. EXPLORATION : 1-41 / 0-23 : ENDICOTT : NORTH SLOPE : ALASKA * FOR?'hT RECORD (TYPE# 64) ONE DE~TH PER FRAME Tape depth ID: F Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod ]. GRCH PDK 68 2 BIF PDK 68 3 BKL PDK 68 ,n BKS PDK 68 5 CSLS PDK 68 6 LS PDK 68 7 MSD PDK 68 ,,, RATO PDK 68 9 RBOR PDK 68 10 RICS PDK 68 1! RIN PDK 68 12 SGMA PDK 68 13 SGMB PDK 68 1~ SS PDK 68 15 SGNT PDK 68 l& PHI PDK 68 1 GAPI 4 1 4 1 CPS 4 1 CPS 4 1 CU 4 1 CPS 4 1 CU 4 1 4 1 4 1 4 1 4 1 CU 4 1 CU 4 1 CPS 4 1 CU 4 1 PU-S 4 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 '1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 125 ~pe File Start Depth = 11885.000000 Tape File End Depth = 11015.000000 T~pe File Level Spacing = 0.500000 ~ape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Cn~e' 68 59196 datums Tape C,~bFile: 5 435 records... Minimum record length: 62 bytes Maxim~ record length: 958 bytes Tape S~bfile 6 is type: LIS FILE HEAQER FILE ~'.'MBER: 5 AVERAGED CURVES Co~nensated Neutron: Arithmetic average of edited passes for all curves. Pu]ae<~ Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH I~TCREMENT: 0.5000 PASSES IWCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS PDK GRC'~ $ REMAPv~ . 2, 3, 4 1 AVERAGED PASS. PUMP-IN PASSES 1, 2, & 3 WERE AVERAGED. $ : B.P. EXPLORATION : 1-41 / 0-23 : ENDICOTT : NORTH SLOPE : ALASKA * FORU~T RECORD (TYPE# 64) ONE D~H PER FRAME Tape ~.~th ID: F Curves: wame Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod ~ GRCH PNAV 68 1 GAPI 4 2 BKL PNAV 68 1 CPS 4 ? BKS PNAV 68 1 CPS 4 ~ BIF PNAV 68 1 CPS 4 ? CSLS PNAV 68 1 CU 4 m LS PNAV 68 1 CPS 4 ~ MSD PNAV 68 1 CU 4 2 RATO PNAV 68 1 4 9 RBOR PNAV 68 1 4 10 RICS PNAV 68 1 4 11 RIN PNAV 68 1 4 12 SGMA PNAV 68 1 CU 4 17 SGMB PNAV 68 1 CU 4 1~ SS PNAV 68 1 CPS 4 15 SGNT PNAV 68 1 CU 4 1< PHI PNAV 68 1 PU-S 4 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 '5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 64 * ~T% RECOPD (TYPE# 0) 958 BYTES * Total Data Records: 125 Tape File Start Depth = 11885.000000 Tame File End Depth = 11015.000000 Tape File Level Spacing = 0.500000 maDe_, File Depth Units -- Feet ***4 FILE TRAILER **** LIS ro~resentation code decoding summary: Rep C~e- 68 87053 datums Tape c'~bfile: 6 147 records... Minim~ record length: 62 bytes Maxim~ record length: 958 bytes Tape S,~¼file 7 is type: LIS FILE HEADER FILE NUMBER: 6 EDITED C~]RVES Depth shifted and clipped curves for each pass in separate files. PASS ~'~?~PER: 0 DEPTH INCREMENT: 0.5000 FILE SUN~.~ARY PBU TOOL CODE GRC~ PDV $ CURVE ?'~!FT DATA - PASS TO PASS BAS~7~INE CURVE FOR SHIFTS ?BU CURVE CODE: n.nSS NUMBER: START DEPTH 11018.0 11030.0 BASELINE DEPTH GRCH 11e'37.5 11029.5 llr"~©. 5 11032.5 11'~' '! 5.0 11036.0 11 ~ ~-q. 5 11050.5 11e72.5 11065.5 110?.4.0 11067.5 11~"~-~~. 5 11071.0 11~n. 5 11083.0 11a ~,'i . 5 11089.0 110~,7.0 11090.0 lln~g. 5 11091.5 11~9.5 11092.0 11~,~,~.~.0_ 11093.0 11 ~ '~ I . _5 11094.5 11~ ^~.0 11104.0 11~ ~.5 11104.5 11~ ~ !.0 11105.0 1].~.0 11110.0 11] 22.0 11116.5 11~ ~'? . 0 11128.5 11: ~:.~ 11149.5 11~ ~5.0 11150.5 11] ~,o.5 11153.5 1] ~ ~-~,. 5 11161.5 ll~"'! .5 11169.0 11~}"5.g 11169.5 1]~-~.5 11173.5 1].~'-~. ~ 11174.0 11~'''] .O 11185.5 11~'~.5 11190.0 112~ ? . O 11212.5 1]~'~.O 11222.5 1 t'--' '-~ ,--~ . 0 11223.0 1] "'~ :? . 5 11223.5 11? ....-~.~ 11224.5 1] '~' ~<.~ 11231.5 1!~'"-~.,') 11255.5 STOP DEPTH 11863.0 11875.0 (MEASURED DEPTH) - EQUIVALENT UNSHIFTED DEPTH 117°'! . 5 115!?1 ,5 11~]. 5 11722,5 117 q '~, 5 1173~ 11~ ~ 5 11 ? ~' ~-. ~ 11~~ ~ .0 1].<~ ~ ,0 1~~ ~].5 1] ~v.O 11~ ~ ~ .5 11~2.5 1] ~0., 1!~.5 1t~ ~. 5 1]~ ~.0 1]~.~ 1]_'~'~ 1]~ 1!~5.0 11~2.0 11~<~ . 5 11TM . 5 1]~ REMAP ~' =:: ' 11266.0 1].273.5 11277.5 11278.5 11280.0 11287.0 11316.5 11317.0 11317.5 11318.0 11323.5 11328.0 1!S63.5 11370.5 1l]75.5 11387.0 11393.5 11296.5 1]~03.5 1t~07.0 11~07.5 1IA15.0 11~22.5 1]A23.0 11423.5 1!~35.5 11448.5 l].'i 50.0 11475.5 11~87.0 11496.0 11503.0 11522.5 1]_543.5 11555.5 11556.5 112.64.5 11590.0 1!,~04.5 11629.5 11732.0 11735.0 11745.5 1]_753.5 11756.0 11757.0 11~07.5 11~54.0 BASE GR ?ri. SS. NO PDK SOURCE ACTIVATION. GRCH WAS DEPTH MATCHED TO A PREVIOUS TDT GAMMA RAY. BKL & BKS WERE SHIFTED WITH GRCH. / ? ?MATCH t . OUT $ : B.?. EXPLORATION : 1-4] / 0-23 .-,.T : EN?TCOTT "~T!W : NOF. TI{ SLOPE '?r~T : ALASKA * FOP~'~T RECORD (TYPE~ 64) ONE D?'~T~ PER FRAME Tape ~th ID: F 3 Curves: ~3ame Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod ~ GRCH PDK 62 1 GAPI 4 ~ ~KL PDK 68 1 CPS 4 ~ ~KS PDK 6~ 1 CPS 4 4 06 511 09 0 4 39 705 61 6 4 74 169 61 6 * ~.% RECORD (TYPE# 0) 1014 BYTES * ~nt~l Data Records- 28 12 File Start De~h = 11885 000000 ~ '-- . File End Depth = 11015.000000 File Level S?~cing = 0.500000 File Depth Units = Feet ***~ =ILE TRAILER **** LIS rc!~resentation code decoding summary: Rep C~e: 68 66]~I datums Tape S,~Tfile: 7 147 records... Minim~ record length: 62 bytes Maxi~ .... record length: 1014 bytes Tape ~'~f]le 8 is type: LIS FILE HEADER FILE ~"'~!~ER: 7 RAW C~T~'TES Cur~.;e,~ and log header data for each run in separate files; raw background pa?? ~n last file. PASS ~TTH~ER: 1 DEPTH T~'~CREMENT: 0.2500 FILE VE?~%~9 TOOL CODE START DEPTH GR 11022.0 PD¥ 11034 . 0 $ LOG H~ ~nER DATA DA?-:. T ~OGGED: SO ~-'?WARE VERSION: TI~'~ T,©GGER ON BOTTOM: TD "~ILLER (FT): TD L©GGER (FT): TOr~ ~.~G INTERVAL (FT): B~=~~.'~ LOG INTERVAL ~FT): L©a~:~G SPEED (FPHR): DE'~'TH CONTROL USED !VES/NO): TOe~ STRING (TOP TO BOTTOM) ~E~DOR TOOL CODE TOOL TYPE ~-~w PDK-100 "~ SINKER BAR :~:~.R SINKER BAR BO~q~{OLE AND CASING DATA ~'~EN HOLE BIT SIZE(IN): ~"~I~LER'S CASING DEPTH (FT): '.~GER'S CASING DEPTH (FT): BO~?~nLE CONDITIONS ¥~/~ID TYPE: 7/7ID DENSITY (LB/G): ~PFACE TEMPERATURE (DEGF): ~©TTOM HOLE TEMPERATURE (DEGF): T.~ID SALINITY (PPH): ~T.~ID LEVEL (FT): ~[~ID RATE AT WELLHEAD (BPM): "~,~ER CUTS (PCT): /OIL RATIO: '"WmKE (DEG) : TOOL TYPE (EPITHEtiCAL OR THERMAL): "~TPIX: ~'~TPIX DENSITY: CORRECTION r~?): STOP DEPTH 11861.0 11873.0 20-SEP-93 FSYS REV. J001 VER. 1.1 1142 20-SEP-93 11893.0 11893.0 11050.0 11875.0 720.0 YES TOOL NUMBER 2725XA 0.000 12020.0 0.0 PRODUCED / SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 :'''~ELINE COUNT R~.TE NORMALIZATION IN OIL ZONE TOP NORMALIZIWG WINDOW (FT) : 0.0 BASE NORMALIZI~'G WINDOW (FT): 0.0 ~:ELINE COUNT P,~,:~,~ SCALES SET BY FIELD ENGINEER ?AR COUNT RATE LOW SCALE (CPS): 550 TAR COUNT RATE HIGH SCALE (CPS): 3050 NEAR COUNT RATE LOW SCALE (CPS): 0 WEAR COUNT RAT~ HIGH SCALE (CPS): 60000 ~TANDOFF (IN): 0.0 ~WS: FLOWING PASS. : B.P. EXPLO~TION : 1-~ ~ / 0-23 : EN~' T COTT ~'~ : NO~ SLOPE c!~.T : ALASKA * FOP~' RECORD (TYPE.~ 64) ONE D7 .... ?w PER FRAME Tape c~--.~th ID: F Curves: Name Tool Code Samples Units GR PDK 6 ~ ~ 1 GAPI gIF PDK 68 1 BKL PDK 68 1 CPS BKS PDK 6~ 1 CPS CCL PDK 68 1 CSLS PDK 68 1 CU CSS PDK 68 1 CPS G1 PDK 6~ 1 CPS G2 PDK 6,~, ~ 1 CPS GElS PDK 6.o 1 CPS ISS PDK 6~ 1 CPS LS PDK 6~ 1 CPS ?4ON PDK 6~, ~ 1 CPS MSD PDK 6 2 1 CU PATO PDK 6 q 1 RBOR PDK 6 8 1 RICS PDK 6~ 1 ~PIN PDK _~ ,:', 1 SGMA PDK 6 $ 1 CU SGMB PDK 6 ~ 1 CU SPD PDK 6 g 1 F/MN SS PDK 6~ 1 CPS SGNT PDK 6-q 1 CU API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 06 511 09 0 4 4 00 201 24 1 4 4 39 705 61 6 4 4 74 169 61 6 4 4 92 630 79 6 4 4 00 201 24 1 4 4 00 201 24 1 4 4 35 975 96 1 4 4 36 631 32 1 4 4 74 169 61 6 4 4 00 201 24 1 4 4 71 162 89 6 4 4 32 125 68 0 4 4 00 201 24 1 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 23 260 40 0 4 4 96 761 61 6 4 4 00 201 24 1 4 4 52 386 28 5 4 4 05 626 89 6 4 4 00 201 24 1 g2 * ~T,% RECORD (TYPE# 0) 966 BYTES * ~tal Data Records: 349 ~e File Start Popth = 11876.000000 Tape File End Depth = 11004.000000 T~e File Level S~acing = 0.250000 ~e File Depth Units = Feet ***~ FILE TRAILER **** LIS ronresentation code decoding summary: Rep C~qe: 68 170790 datums Tape S~¼file: 8 424 records... Minim,~- record length: 62 bytes Maxi~ ...... ~-ecord length' 966 bytes Tape S,,brile 9 is type: LIS FILE H EA D, ER FILE b~!~BER: 8 RAW C~.~V F,S Curves and log header data for each run in separate files; raw background pas~ fin last file. PASS t"~DER: 2 DEPTH I~'~CREMENT: 0.2500 FILE SUMMARY VE~'~©P TOOL CODE ST~T DEPTH GR 11027.0 PDK 11039.0 $ LOG N=~EP DATA D~~ .... } ,OGGED: S©?'~'?,~E VERSION: TI~ L©GGER ON BOTTO~: TD ~'~ILLER (FT) : TD ,LOGGER (FT): TOO I,~G INTERVAL (PT): BO~?~.-~ LOG INTERVAL f FT): LOq'nI,~?G SPEED (FPHP) · DE~'?}~ CONTROL USED (",.'ES/NO): STOP DEPTH 11859.0 11871.0 20-SEP-93 FSYS REV. J001 VER. 1.1 1400 20-SEP-93 11893.0 11893.0 11050.0 11875.0 900.0 YES STRING (TOP TO BOTTOM) "E~OOR TOOL CODE TOOL TYPE ~-~w PDK-100 ~'~'~ SINKER BAR '-:~ SINKER BAR TOOL NUMBER 2725XA BOn~WOLE AND CASING DATA -'~,~ HOLE BIT SIZE(IN): "OrLLER'S CASING DEPTH (FT): ~OGGER'S CASING DE~TH (FT): 0.000 12020.0 0.0 BO""- ~.~r~!,E CONDITIONS T:~ID TYPE: :'-L~ID DENSITY (LB/G] : 7"~DFACE TEMPERATURE (DEGF): ~-~TOM HOLE TEMPEPATURE (DEGF): ~,~ID SALINITY (PPIS): :~77~ID LEVEL (FT): ?L:~ID RATE AT WELLHEAD (BPM): ~:~TER CUTS (PCT)' !OIL PATIO: --~.~¥E (DEG): PRODUCED / SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NE .... ~mw TOOL ~,'~L TYPE (EPITHE~"~,L OR THERMAL): ~". ~RIX: ' ' ~'. ~PIX DE~SITY: .... ~E CO9PECTION ~!~% : 0.00 0.000 ELINE COUNT P~-~,.: ~ NORMALIZATION IN OIL ZONE TOP NORMALIZI~C ~.~INDOW (FT): 0.0 BASE NORMALIZI"q WINDOW (FT): 0.0 ~'~ELINE~. COUNT ~i~-~., SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 550 FAR COUNT RATE !~,IGH SCALE (CPS) : 3050 NEAR COUNT RATE LOW SCALE (CPS): 0 WEAR COUNT RATE HIGH SCALE (CPS) : 60000 STANDOFF (IN) ' RE .... owS: PUMP IN P~'.S,q 1. $ COtT}~ S T-~.T : B.P. EXPLORATION : 1-~ / 0-23 : ENDICOTT : NONT.U SLOPE : AL~ SKA 0.0 , FOR?~? PECORD (TYPE~ 6~) ONE D?'-~t? PER FRAME Tape ~-:-'~th ID: F Curves: Wame Tool Cod.~.. .-~amples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod ! GR PDK ~ BIF PDK ~ BKL PDK ~ BKS PDK ~- CCL PDK s CSLS PDK i CSS PDK P G1 PDK ~ G2 PDK le GElS PDK 1! ISS PDK 12 LS PDK 17 MON PDK 1' MSD PDK ]7 PATO PDK 1~ NBOR PDK 1~ RICS PDK 1.~ RIN PDK If' SGMA PDK 2~ SGMB PDK 27 SPD PDK 2q SS PDK 22 SGNT PDK 2~ PHI PDK GAPI 4 4 CPS 4 CPS 4 4 CU 4 CPS 4 CPS 4 CPS 4 CPS 4 CPS 4 CPS 4 CPS 4 CU 4 4 4 4 4 CU 4 CU 4 F/MN 4 CPS 4 CU 4 PU-S 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 O0 201 24 1 4 71 162 89 6 4 32 125 68 0 4 O0 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 O0 201 24 1 4 52 386 28 5 4 05 626 89 6 4 00 201 24 1 4 00 201 24 1 96 + ~'~,~n RECePD (~-vPE# 0) 1006 BYTES * Data Recor~m· 346 Tape File Start Depth = 11874.000000 Tape File End Depth = 11010.000000 T~me File Level Spacing = 0.250000 m~mc File Depth l~m[ts = Feet ***'~ ~T!,E TRAILER LIS r~resentation code ~ecoding summary: Rep C~e: 68 1525S7 datums Tape ,~,~'rile: 9 421 records... Minim~-.'~ ~ecord length' 62 bytes Maxim,~ ?ecord length' 1006 bytes Tape F,,%~ile 10 is type: LIS FILE HEADER FILE ~'~T~ER: 9 RAW C'~nVES Cur~'e~ and log header data for each run in separate files; raw background pa?~ ~n last file. PASS [ .... ~ER: 3 DEPTH i'~CREMENT: 0.2500 FILE VE~ ~P TOOL CODE STAPT DEPTH G~ 1]~23.0 PPI< 11035.0 $ LOG H~ '~pER DATA DA~K I,OGGED: SO~*~?>~E VEPSION: TI ..... ~,©GGER ON BOTT~: TD '-'~7~,LER (FT) : TO ~.OGGER (FT) : TOTM ~,~G INTERVAL (FT) : BO ...... ~ LOG INTERVAL (FT): LOqzI~G SPEED (FPHP% : DE~'iH CONTROL USED rVES/NO): TO~L STRING (TOP TO BOTTOM) "~"DOR TOOL CODE TOOL TYPE '~W PDK-100 ~n~ SINKER BAR ~n~ SINKER BAR STOP DEPTH 11859.0 11871.0 20-SEP-93 FSYS REV. J001 VER. 1.1 1506 20-SEP-93 11893.0 11893.0 11050.0 11875.0 900.0 YES TOOL NUMBER 2725XA BO~?r~LE AND CASING ,r>.~'~.TA "~?~ HOLE BIT ST?,E,~IN): '-~-LLER'S CASING ~EPTH (FT): - ~.~GER'S CASING ~E?TH (FT): 0.000 12020.0 0.0 CONDITIONS TYPE: DENSITY (LB/a) : -r~FACE TEMPERATURE (DEGF): ~?OM HOLE TEMPEP..~.TURE (DEGF): SALINITY (PF[~): LEVEL (FT) : RATE AT WEL, r,~'EAD (BPM): CUTS (PCT) : --"'S/OIL PATIO: (DEG): PRODUCED / SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NE .... ~mN TOOL ~,~oL TYPE (EPITHEtiCAL OR THERMAL): "~.T~IX: "~'~IX DE~SITY: "~'~',£ CORRECTION (r"%: 0.00 0.000 ~-~I,INE COUNT Pr. TX NORMALIZATION IN OIL ZONE TOP NOPMALIZI~G WINDOW (FT): 0.0 ~ASE ~,~©P. MALIZT"C WINDOW (FT): 0.0 '-~/~LINE COUNT F;~E SCALES SET BY FIELD ENGINEER FAR COUNT RATE ~©W SCALE (CPS): 550 FAR COUNT RATE ~7GH SCALE (CPS): 3050 ,WEAR COUNT RATE ,~OW SCALE (CPS): 0 WEAR COUNT RATE HIGH SCALE (CPS): 60000 TO~, ?TANDOFF (IN) : 0.0 RE"'~wS' PUHP IN m.~oS 2 $ ~'~?. : B.~ . EXPLORATION ~"~ : 1- ~ ] / 0-23 '~'- : E~;~ ! C"'TT ~'~"? : NO~'iTM SLOPE * FOP~'"T PECORD (TYPE,+' ONE Di~;~ PER FRAME Tape ;~-~t~ ID: F Wame Tool Cod~ ~ples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod ~ GR PDK 6° 1 GAPI 4 " ~IF PDK 61 1 4 ~' ~KL PDK 6e 1 CPS 4 RKS PDK 6~ 1 CPS 4 ~ CCL PPK 6R 1 4 ~ CSLS PDK 6R 1 CU 4 ~ CSS P~K 6~ 1 CPS 4 ~ G1 PDK 6e 1 CPS 4 ? G2 PDK 60 1 CPS 4 1~ GElS PDK ~c 1 CPS 4 11 ISS PDK 6~ 1 CPS 4 12 LS PDK 6~ 1 CPS 4 12 ~.7ON P~K 6~ 1 CPS 4 1~' ~.~SD PDK 6~ 1 CU 4 If ~ATO PDK ~o 1 4 1'~ nBOR PDK 6~ 1 4 1'-~ RICS PDK 62 I 4 1'- RIN PDK 6R 1 4 1~- SGHA PDK 6~ 1 CU 4 2? SGMB PDK 62 1 CU 4 2~ SPD PDK ao 1 F/MN 4 2~ SS PDK 6o 1 CPS 4 23 SGNT PDK 6~ 1 CU 4 2~ PHI PDK 6e ~ PU-S 4 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 32 125 68 0 4 00 201 24 1 4 23 260 40 0 4 23 260 40 .0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 4 00 201 24 1 4 00 201 24 1 96 + ..... ~ NEC~P~ ~:-'-"PE~ 0) 1006 BYTES * Data Recor,'-~, s: 347 Tape File Start Depth = 11876.000000 ~e File End Depth = 11011.000000 Tape File Level Spacing = 0.250000 ~ File Depth ~]t~ = Feet ***~ ~TT,E TRAIl,ER LIS ro:~-esentation co~e ~ocoding summary: Rep C ~ -~. e - 68 25~?~ ~ datums Tape~..~'~file: 10 422 records... Minim, .... ~-ecord length' Maxim ..... record length' 62 bytes 1006 bytes Tape F,,¼ffSle 11 is type: LIS FILE UEa, DER FILE ?!?~:~RER: 10 RAW C~PVES Curves and log header data for each run in separate files; raw background pass 5m last file. PASS ~"?~nER: 4 DEPTH ,~"'~REMENT-. ,_.~ ©.~,~0~., FILE ~'~ARY VE~'nnR TOOL CODE ST~,~T DEPTH GR 1 !_r~21 . 0 PDW 110~3., .0 LOG H~~ DATA DA~E ;OGGED: SO~'~-~WAPE VERSION: TI~ ~ r.~GGER ON BOTTO~: TO .... ~7!,LER (FT) : TC~- ~G INTERVAL (Ui~ ' BQ ..... ~ LOG INTERVAL (?T): L~'c~!~G SPEED (FPH~ : DEr!U CONTROL USED ~YES/NO): STOP DEPTH 11858.0 11870.0 20-SEP-93 FSYS REV. J001 VER. 1.1 1613 20-SEP-93 11893.0 11893.0 11050.0 11875.0 900.0 YES TO~'~, ST9ING (TOP TO PeTTOM) "E~'~OR TOOL CODE TOOL TYPE ~¥ PDK-100 2~P SINKER BAR .~n.nP SINKER BAR TOOL NUMBER 2725XA Bop~'-~rOT,E AND CASING r~TA ~:,~'.~ HOLm ~IT ST!~fTN : ...., TT,T, ~. ,oPPose, ' ~_,C CASING r~EPTH (FT): ' ~nGER'S CASING ~'r-PTI{ (PT): 0.000 12020.0 0.0 BO'~ =t~OLE CONDITIONS -rJ~ID TYPE: '-i,}~TD DENSITY (T,r0~'c% : ":~FACE TEMPERAT~'r'E (DEGF): ~TTOM HOLE TEMFEn?'TI~RE (DEGF): ~,~!U SALINITY (~F~i) : ID LEVEL (FT) : ~'i'?~T~ RATE AT WET,r.,WEAD (BPM): '"~TER CUTS (PCT) : /OIL RATIO: -"~n, WE (DEG) : PRODUCED / SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.O00 0.000 0.0 0.00 0.000 ''FT.: ,Itl~.~ "~'~I!NT,. ....... P'"" :-' NORMALIZATION IN OIL ZONE *op ~?r~W~LIT,?':c: ., ~.,. .. WINDOW (PT): 0.0 WINDOW (FT): 0.0 "~,~TELIN. E COUNT ~,~"E SCALES SET BY FIELD ENGINEER vAR COUNT RATE LOW SCALE (CPS): 550 TAR COUNT RATE ~.~TGH SCALE (CPS): 3050 ,EAR COUNT ~?,~-'E T,OW SCALE (CPS): 0 ~'~EAR COUNT R.:~-?E .~:IGH SCALE (CPS): 60000 TO~ ST~,NDOFF (IN) : 0.0 EXPLORATION I 0-23 SLOPE ..... ' * FOP~'~'' ~qCONO (TY~?' '.~ . '-'~, ONE F~'-"-'~? PER FNAME Tape ~ .... ,.~t!~ ID- F ".' 4 CNFves · Wame Tool Co~e $~mples Units ~ ne enK ~- '~' 1 GAPI 2 R I F PDK ?, u 1 ~ nWL ~w ~, ~ 1 CPS .~ ~KS PDK 6~ 1 CPS '" CCL PDK 6q 1 '..< CSLS PDK 68 1 CU ~ CSS PPK 6 ~ 1 CPS o G! PDK ~.~ 1 CPS ~' ,,~ 2 PDK & 1 CPS 10 GElS PDK 6° 1 CPS 11 ISS PDK 68 1 CPS 12 !,S PDK 6 ~ 1 CPS 1 ~ ~-'~ON PDK ~ '~ 1 CPS 1 ~ ".~SD P~I< ~ o 1 CU 1< ~OR PO!'{ ~'~' 1 1'-' m!CS PDK c<- 1 1 ':' e I N P D K 6. <' 1 1 ~' SGMA POK 6q 1 CU 2 ~' SGMB PDK ~, q 1 CU 2' cuD ~n~,, ~ '~ 1 F/MN 2 c$ p:..: r" 1 CPS 23 SGNT PDK ~e 1 CU 2. ewI P~ K ~. 1 PU-S API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 06 511 09 0 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 74 169 61 6 4 00 201 24 1 4 71 162 89 6 4 32 125 68 0 4 00 201 24 1 4 23 260 40 .0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 4 00 201 24 1 4 00 201 24 1 96 Data Reco~,-~s: 346 Tape File Start Depth = 11873.000000 m~ne File End Denth = 11009.000000 ~'-~ne File l,evel '~'~'.~cing = 0.250000 ~-'~pe File Pepth '"'it~ = Feet **~* ~!T,E TRAILER LIS representation code ~ecoding summary: Rep C .... n- ~g 23~'~3 datums 421 records... Minim,,~ record length' 62 bytes ]006 bytes Tape S,,h£i]e ].2 is typ~: I, IS FILE HEADER FILE U,;wnER,: RAW C? paCs in ].ast file. PASS DEPT~! '~'CPEHENT- FILE VE,"~ TOOL CODE GR PDK $ LOG N~'~E~ DATA D~~ ~' ~ GED: Sor ....~'~n~E VEPSION: TI ..... T,~GGER ON BOTT~: To~ ' ~.c INTERVAL (r ..... ~ : Bo~ ..... ~"~ r,.,OG.. INTE~V~,~., .. , ~} : LO~i'~.iNG SPEED (FP~r~' ' DRr'TU CONTROL USED ~"r~/NO): 11 log hear]er data for each run 0 o.25~0 c?~ DEPTH ]!n]_7.0 11029.0 TOO.% STRING (TOP TO BOTTOM) "lWnOR TOOL CODE TOOL TYPE '-~" PDK-100 . ~ SINKER BAR ~ SINKER BAR in separate files; STOP DEPTH 11882.0 11894.0 20-SEP-93 FSYS REV. J001 VER. 1031 20-SEP-93 11893.0 11893.0 11050.0 11875.0 1500.0 YES TOOL NUMBER 2725XA raw background 1.1 COND!TIO TYPE' DENSITY (T.°./c~. ' -'":PFACE TEMPERATURT~ (DEGF) .' HOLE TEHPED~mURE (DEGF): S~LINITY (.--.r '- , .' t 'e~.~EL (FT~ · PATE . .... ,. iD (BPM): C~TTS (PCT~ · TOOL TYPE (EPIT~!~nr~L OR THERMAL): "'T~IX- ~'~TnlY DE~'SITY' C~n~NCTI~~ ':'!~,T"~E COT?.~:T ~-' : '"%RMALIZATION IN OIL maD, ?,,n T) r"l' 5 T. .'ir . . .,.,T 'ti .... : "'"DOW., (FT): 0.000 12020.0 0.0 PRODUCED / SEAWATER 0.O0 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 ZONE 0.0 0.0 '.'i'~TN5 Co~,q"? ~ ..... ~ SCALES SET BY FIELD ENGINEER FAR COUNT RAq'!i LC)W SCALE (CPS): 0 ~n.p Ce~,',?~T n~m? "zcH SCALE (CPS): 0 ~EAR CO~T ~ .... ~ ~W SCALE (CPS): 0 '~5AR COUNT P ...... '-"IGH SCALE (CPS): 0 0.0 ~SE Gn .... . NO PDK SOURCE ACTIVATION : ~ . ~ qXPLORATION - ~,- '~ ,' 0-23 - ~ ............ ?T ....... z~': 9LOPE · ONE D~'''~-''' PEP FP.-~,,~'~E Tape s~,~t¼ ID: ~ "sme m~ ..... ~,~' ~"'~les Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GAPI 4 1 CPS 4 1 CPS 4 1 4 1 F/MN 4 4 06 511 09 0 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 05 626 89 6 20 , ~ ....m~ ~=~apD r~..,n~- 0) 1014 BYTES * .... ~ Da~ pm ...... ~- 86 m~ne rile Start Depth = 11897.000000 .... ~'c File End Ocu''~ = 11001.000000 ~'?~e File Level ~'-~c~.ng = 0.250000 ~':-'~e File Depth ~'.-~t~ = Feet **** ?ILE TPAILER **-~* LIS r~ ~.¢enea~on c~ S~oding summary: Rep Co'~'~' 6~,-, n~c~? ~atums Tape S'~'fi !.e' 12 160 records... Mini~'"" rncnrcl q cng?~- ' 62 bytes 1014 bytes Tape ***4. RE'-'q-.L TRA!~.JER ' 92 /10/2,0 Tape ~,~bfJ]e: 13 2 records... Minim~-~ record length: 132 bytes Maxim~ record length' 132 bytes End cf e>~ecution: ~.~ed 20 OCT 93 2:15p Elapsc~ ewecution time = 51.41 seconds. SYSTE~'? RETUP,?.I CODE = 0