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Home My WebLink About191-033From:Brooks, Phoebe L (OGC) To:Morales, Tony Cc:Regg, James B (OGC) Subject:FW: Nabors 7ES 11-22-23 Date:Wednesday, January 3, 2024 1:40:07 PM Attachments:Nabors 7ES 11-22-23 Revised.xlsx Tony, I received an error message when I sent this to Kelly, so I hope this revision makes it to you. Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Brooks, Phoebe L (OGC) Sent: Wednesday, January 3, 2024 1:35 PM To: Cozby, Kelly <Kelly.Cozby@nabors.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: RE: Nabors 7ES 11-22-23 Kelly, Attached is a revised report changing the MASP to reflect 2307 per sundry #323-448. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. KRU 2M-15 PTD 1910330 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: Cozby, Kelly <Kelly.Cozby@nabors.com> Sent: Friday, November 24, 2023 6:47 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; NSK RWO CM <nskrwo.cm@conocophillips.com> Cc: White, Bradley <Bradley.White@nabors.com>; Morales, Tony <Tony.Morales@nabors.com>; Medina, Johnny <Johnny.Medina@nabors.com>; Yearout, Paul <Paul.Yearout@nabors.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Kneale, Michael L <michael.l.kneale@conocophillips.com> Subject: Re: Nabors 7ES 11-22-23 Please disregard the previous report as the notification date & time were incorrect. Sending corrected report. Thanks, Kelly Cozby 7ES Rig Manager NABORS ALASKA DRILLING INC. Office 907 670-6132 Mobil 907 715 9055 kelly.cozby@nabors.com From: Cozby, Kelly <Kelly.Cozby@nabors.com> Sent: Wednesday, November 22, 2023 6:50 PM To: Regg, James B (CED) <jim.regg@alaska.gov>; AOGCC.Inspectors@alaska.gov <AOGCC.Inspectors@alaska.gov>; Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov>; NSK RWO CM <nskrwo.cm@conocophillips.com> Cc: White, Bradley <Bradley.White@nabors.com>; Morales, Tony <Tony.Morales@nabors.com>; Medina, Johnny <Johnny.Medina@nabors.com>; Yearout, Paul <Paul.Yearout@nabors.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Kneale, Michael L <michael.l.kneale@conocophillips.com> Subject: Nabors 7ES 11-22-23 Thanks, Kelly Cozby 7ES Rig Manager NABORS ALASKA DRILLING INC. Office 907 670-6132 Mobil 907 715 9055 kelly.cozby@nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:7ES DATE:11/22/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1910330 Sundry #323-448 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2307 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 P Pit Level Indicators P P #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 3 1/2" x 5 1/2"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)3000 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1550 P Check Valve 0 NA 200 psi Attained (sec)18 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)114 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:1000 P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5@ 2025 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 28 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0 NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 11/20/23 10:54 Waived By Test Start Date/Time:11/22/2023 5:30 (date)(time)Witness Test Finish Date/Time:11/22/2023 11:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors Test with 3-1/2" test joint. Kelly Cozby / Johnny Medina ConocoPhillips Ron Phillips / Chase Eardman KRU 2M-15 Test Pressure (psi): kelly.cozby@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2023-1122_BOP_Nabors7ES_KRU_2M-15         J. Regg; 5/3/2024 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: ___________________ 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): 7021'None Casing Collapse Structural Conductor Surface Intermediate Production Liner 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. W ell 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 9/4/2023 3-1/2" Packer: Otis HVT Retrevbl Packer SSSV: Camco TRDP-4A-RO Safety Vlv Perforation Depth MD (ft): J-55 2859' 6606-6626', 6656-6668', 6684-6724' 6956' 6012-6027', 6050-6059', 6071- 6102' 7" Perforation Depth TVD (ft): 123' 2901' 6311'6998' 16" 9-5/8" 81' 6534' MD 123' 2901' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025586 191-033 P.O. Box 100360, Anchorage, AK 99510 50-103-20154-00-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6509' MD and 5939' TVD 1792' MD and 1792' TVD Dusty Ward 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: dusty.ward@conocophillips.com (907) 265-6531 Senior Wells Engineer KRU 2M-15 6329' 6707' 6089' 2307 6524' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:20 pm, Aug 08, 2023 323-448 DSR-8/14/23SFD 8/23/2023VTL 9/20/2023*&:JLC 9/21/2023 09/21/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.09.21 15:39:07 -08'00' RBDMS JSB 092123 2M-15 RWO Procedure Kuparuk Producer PTD #191-033 Page 1 of 3 Remaining Pre-Rig Work 1. Set deep plug for secure and isolation from formation. - Unsuccessful 2. Open lowest GLM at 6440’ RKB in upper completion. Dummy off the rest. 3. Cut the tubing nominally at ~6450 RKB in the middle of the first full joint above the production packer. 4. Prepare well within 48-72 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors N7ES on 2M-15. (No BPV will be installed due to risk assessment done for MIRU/RDMO on N7ES w/o BPV.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3500 psi. Test annular 250/3500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to pre-rig cut (~6450’ RKB). 6. If not all tubing comes due to subsidence, then work additional steps below to clear buckled 7”, then pull remaining completion. a.RU Eline while holding on to tubing. b.RIH with IBP through tubing and set deep in 7” casing, above cut tubing stub. c.Roll well over to lighter KWF above IBP to test in direction of flow with 30 minute NFT. i.Once IBP and fluid are tested with NFT, then dump sand through tubing on top of IBP. d. Set tubing down on sand gently. e. Cut tubing at 3000’. PU tubing again. f. RIH and set IBP near 3000’ RKB in 7” casing between tubing sections. g. PT from above to confirm as barrier. h. Dump sand on IBP through tubing again. i. Set tubing back down on 2nd IBP sand. j. If can get completion out, RU Eline and log 7.0” casing for OA cement from Arctic Pack job. Pull Subsided 7.0” Casing 7. Set storm packer or plug in 7” casing and PT to confirm as barrier. a. Set additional IBPs or RBPs in 7.0” casing and dump sand as necessary. 8.Swap lower ram to 7.0” casing ram and test to BOPE test pressure if not already done so. 9. ND BOPE. ND old tubing spool. NU BOPE and test flange break. a. Grow/stretch and Cut 7” casing at surface as necessary to deal with subsidence in this step. b. Shell test 3000 psi rated flanges on wellhead to 3000 psig when flanges are exposed to test pressure as soon as practical. 10. Pull storm packer or plug. Condition fluid as needed. 11. RU Eline and log 7.0” casing for OA cement from Arctic Pack job. 12. Cut 7.0” casing with cutter above OA cement. a. Circulate out Arctic Pack diesel/slurry as needed. 13. Pull 7.0” casing down to cut (~2000’). a. Make addition cut/pulls/BHA runs as necessary to remove 7”. b. If any 3.5” tubing was left downhole. Pull 3.5” tubing to clear wellbore for tie-back running. 14.*Depending how 7.0” Casing pulls/removed, go to “7.0” Tie-Back Subsidence”, this scope assumes this will now need to be done. 7.0” Tie-Back Subsidence 2M-15 RWO Procedure Kuparuk Producer PTD #191-033 Page 2 of 3 Bore out 9-5/8” and run 7.0” Tie-Back Subsidence Before Running of 5.5” x 3.5” tie-back 15. PU mills and bore out 9-5/8” as necessary to obtain drift for new 7.0” tie-back. a. As drift is regained, pull any additional 7.0” or 3.5” tubing as needed to get 7.0” removed down to cement in OA. 16. Run new 7.0” tie-back casing with overshot. 17. Test casing to 2500 psig. 18. Cement OA to surface. 19. Split stack and land slips, cut excess casing and install IC packoffs. Installed tubing spool and terminate 7.0”. Land stack and MU to casing flange. a. Shell test flange break. 20. Swap lower ram to VBRs for running 3.5” and 5.5” tubing/tie-back. Test same to BOPE pressure. 21. Mill plugs in cementer. 22. Circulate out sand on IBP or any lower plug. Pull all but deepest plug. 23. RIH with test packer to ~5250’. PT 7” casing from test packer to surface to confirm depth of casing leak. POOH. 24. Pull any lower plugs or remaining 3.5”. a. Confirm KWF as needed before pulling deepest plug. 25. If 7” casing passes PT at adequate depth to allow good gas lift per above pressure test, then go to “Install New 3-1/2” Completion” Section of plan to run completion and stack packer above 7” damage. a. If 7” casing damage is higher than expected, then i. Set DP on storm packer or plug and test to confirm as barrier. ii. ND BOP. Swap tubing spool with 5.5” tie-back spool. NU BOP and test break. iii. Pull storm packer or plug. iv. Go to “Run New 3.5” x 5.5” Tie-back Liner” steps. Contingency: Run New 3.5” x 5.5” Tie-back Liner 26. RIH with overshot, nipple profile with pre-test plug installed, 3.5” x 7.0” packer, PBR, seals, and DP to surface. 27. Overshot tubing. Pressure up against plug and set packer. Pull out of PBR with seals and circ well over to lighter brine and do 30 minute NFT to confirm new packer/plug to set. a. Use test packer in BHA of DP to confirm packer set as alternative to test packer form above. 28. Begin to lay down DP and BHA. On TOOH, hang of DP on storm packer and test same. 29. ND BOP and tubing spool. NU 5.5” tie-back spool and BOP. Test same. 30. RIH with 3.5” overshot, Nipple profile, 3.5” x 7.0” packer, 3.5” seals, 3.5” x 5.5” crossover, 5.5” x 7.0” packer, and 5.5” tie-back liner to surface. (Crossover to 7.0” at surface for last joint if needed for wellhead termination.) a. Depending on height and severity of 7” casing damage, 5.5” x 7.0” packer may be omitted. 31. Circulate in CI fluid and freeze protect as needed before stinging into PBR. 32. Engage seals into PBR. Pressure up on tubing to set the 5.5” x 7.0” packer. PT 5.5” x 7.0” annulus to confirm as barrier. 33. RU SL and RIH to pull isolation sleeve across communication ports in top of PBR assembly. a. Communication port allows pressure communication from 3.5” x 5.5” annulus down to 3.5” x 7.0” annulus. Covered up on initial install to allow packer setting. b. Replace Dual Flapper Check Valve (DFCV) in tubing nipple with plug as necessary. c. If SL not available, then finish steps below to terminate 5.5” and get new tubing spool on. Then RIH and pull sleeve with tubing. 34. PT 5.5” liner to 2500 psig for 30 minutes and chart. (This is the new IA envelope.) 35. Set 5.5” RBP near surface. PT to confirm as barrier. 36. ND BOPE. Finish 5.5” termination. NU new tubing spool. NU BOPE. Test flange breaks. 37. Swap lower ram to VBRs for running 3.5” tubing if not already done so. Test same to BOPE pressure.(Swabbed already in earlier step for this updated scope.) 38. Pull 5.5” RBP. Freeze protect new OA at opportune moment. Install in 3-½” Completion and ND BOP, NU Tree 2M-15 RWO Procedure Kuparuk Producer PTD #191-033 Page 3 of 3 39. MU 3 ½” completion with overshot, packers, nipples, and GLMs. RIH with completion. a. Modify completion as needed to run inside 5.5” liner if 5.5” liner contingency is ran. Modify running order, landing completion and final PTs of tubing and IA as necessary. 40. Once on depth, stab in seals overshot and space out as needed. Land hanger and test packoffs. 41. Install BPV. Test. 42. ND BOPE. NU tree. PT tree. 43. Pull BPV. 44. Reverse circulate in CI fluid at opportune time as needed. After CI is in place, set packers. 45. Pressure test tubing to 3000 psi for 30 minutes and chart. 46. Pressure test inner annulus to 2500 psi for 30 minutes on chart. 47. Confirm pressure tests, then shear out SOV with pressure differential. 48. Freeze protect well, and set BPV if necessary. 49. RDMO. Post-Rig Work 50. Pull BPV 51. Pull dual flapper valve or ball/rod and RHC plug. 52. Install GLD. 53. Pull any other plugs and turn over to operations. General Well info: Wellhead type/pressure rating: FMC Gen IV. 7-1/16” 5M psi top flange x 11” 3M psi bottom flange Production Engineer: Natalie Dye Reservoir Development Engineer: Mandy Pogany Estimated Start Date: 9/4/2023 Workover Engineer: Dusty Ward (265-6531/ dusty.ward@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to pre-rig cut. Pull buckled 7.0” casing near surface. Run new 7” casing and cement OA. Check integrity of 7” casing from expected hole depth and up. If casing is good, stack packer high. If casing is worse than expected, then run new 3.5” x 5.5” tie-back liner, then slim 3-1/2” completion inside it. BOP configuration: Annular / Pipe Rams / Blind Rams / Cross/ Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed 6/28/2021 MIT-IA Failed 11/27/2020 MIT-OA Passed 10/8/2020 IC POT Failed 9/15/202 TBG POT &PPPOT N/A MPSP: 3351 psi using 0.1 psi/ft gradient Static BHP: 3946 psi / 5948’ TVD measured on 7/31/2023 2M-15 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top)Thread (btm) Conductor 123 123 16 15.06 62.58 H-40 Welded Welded Surface 2901 2901 9.625 8.92 36 J-55 BTC BTC Production/ Intermediate 6998 6311 7 6.28 26 J-55 BTC BTC Tubing 6360 5826 3.5 2.992 9.3 L-80 EUE8rd Mod EUE8rd Mod PROPOSED 3.5" COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Camco MMG gas lift mandrels @ TBD 3-1/2" x 7" Packer 2.813" X-landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Camco MMG gas lift mandrel 3-1/2" x 7" Packer 2.813" X-landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Non-sealing Overshot PROPOSED 7.0" Tie-Back 7.0", 26# L80, HYD563 to Surface 7.0" Cementer 7.0" Sealing Overshot REMAINING COMPLETION LEFT IN HOLE Packer @ 6508' RKB (3.250" ID) D nipple @ 6524' RKB (2.75" ID) WLEG @ 6534' RKB Surface Casing Production/Intermediate Casing Conductor A and C-sand perfs 7" PC Leak ~5340' 2M-15 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top)Thread (btm) Conductor 123 123 16 15.06 62.58 H-40 Welded Welded Surface 2901 2901 9.625 8.92 36 J-55 BTC BTC Production/ Intermediate 6998 6311 7 6.28 26 J-55 BTC BTC Liner 6450 5895 5.5x3.5 4.95 15.5 L-80 HYD563MS HYD563MS Tubing 6360 5826 3.5 2.992 9.3 L-80 EUE8rd Mod EUE8rd Mod PROPOSED 3.5" COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco KBG-29 gas lift mandrels @ TBD 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Seals PROPOSED 5.5" x 3.5" Tie-Back 5-1/2", 15.5#, L80, HYD563 MS (5.873" OD) to Surface 5-1/2" x 7.0" Packer 5-1/2", 15.5#, L80, HYD563 MS (5.873" OD) PBR for 3-1/2" Seals 3-1/2" x 5-1/2" Crossover 3-1/2" Camco MMG gas lift mandrel 3-1/2" X landing nipple at xxxx' RKB (2.813" min ID) Seal Assembly PBR 3-1/2" x 7" Packer 2.813" X-landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Non-sealing Overshot PROPOSED 7.0" Tie-Back 7.0", 26# L80, HYD563 to Surface 7.0" Cementer 7.0" Sealing Overshot REMAINING COMPLETION LEFT IN HOLE Packer @ 6508' RKB (3.250" ID) D nipple @ 6524' RKB (2.75" ID) Surface Casing Production/Intermediate Casing Conductor A and C-sand perfs 7" PC Leak ~5340' 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: Replace Tubing 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? Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7021'N/A Casing Collapse Conductor Surface Production 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: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 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: AOGCC USE ONLY Dusty Ward dusty.ward@conocophillips.com (907) 265-6531 Senior Wells Engineer Tubing Grade:Tubing MD (ft): Packer: 6509'MD/5939'TVD SSSV: 1792'MD/1792'TVD Perforation Depth TVD (ft):Tubing Size: J-55 6534' 7/24/2023 Packer: Baker HB SSSV: CAMCO TRDP STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025586 191-033 P.O. Box 100360, Anchorage, AK 99510 50-103-20153-00-00 ConocoPhillips Alaska, Inc. KRU 2M-15 Kuparuk Oil PoolKuparuk Oil PoolKuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6329'6707'6089'2307 6524' MD 123' 2901' 123' 2901' 6311'6998 16" 9-5/8" 81' 2859' Perforation Depth MD (ft): 6606-6626' 6656-6668' 6684-6704' 6704-6724' 6956' 6012-6027' 6050-6059' 6071-6087' 6087-6102' 3-1/2" 7" P s 66 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:51 am, Jun 07, 2023 323-330 20154 VTL 6/22/2023 BOP test to 3000 psig Annular preventer test to 2500 psig X DSR-6/12/23MDG 6/12/2023 10-404 X GCW 06/22/2023 06/23/23Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.23 08:51:44 -08'00' RBDMS JSB 062723 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 15, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Dusty Ward Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Producer 2M-15 (PTD# 191-033). Well 2M-15 was drilled and completed in December of 1991 as a Kuparuk A-sands producer.. The C-sands were perforated in 1999. The well was shut in in 2020 due to subsidence failure and a production casing leak. The well was moved to a subsidence RWO candidate in 2022. If you have any questions or require any further information, please contact me at 503-476-2519. A slim subsidence will be performed on the well. The tubing will be pulled. Then the buckled 7.0" casing near surface will be pulled. Then a 3.5" x 5.5" tie-back liner with gas-tight threads will be ran. Then a slim 3.5" completion will be ran inside the new liner. 2M-15 RWO Procedure Kuparuk Producer PTD #191-033 Page 1 of 2 Remaining Pre-Rig Work 1. Set deep plug for secure and isolation from formation. 2. T-PPPOT, T-POT, IC-PPPOT, and IC-POT. 3. MIT-OA. 4. Install hold-open sleeve in SSSV as necessary. 5. Open lowest GLM at 6440’ RKB in upper completion. Dummy off the rest. 6. Cut the tubing nominally at ~6450 RKB in the middle of the first full joint above the production packer. 7. Prepare well within 48-72 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors N7ES on 2M-15. (No BPV will be installed due to risk assessment done for MIRU/RDMO on N7ES w/o BPV.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3000 psi. Test annular 250/3000 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to pre-rig cut (~6450’ RKB). a. If not all tubing comes due to subsidence, then work additional steps below to clear buckled 7”, then pull remaining completion. Pull Subsided 7.0” Casing 6. Set storm packer or plug in 7” casing and PT to confirm as barrier. 7. ND BOPE. ND old tubing spool. NU BOPE and test flange break. a. Grow/stretch and Cut 7” casing at surface as necessary to deal with subsidence in this step. 8. Pull storm packer or plug. Condition fluid as needed. 9. RU Eline and log 7.0” casing for OA cement from Arctic Pack job. 10. Cut 7.0” casing with cutter above OA cement. a. Circulate out Arctic Pack diesel/slurry as needed. 11. Pull 7.0” casing down to cut (~2000’). a. Make addition cut/pulls/BHA runs as necessary to remove 7”. Run New 3.5” x 5.5” Tie-back Liner 12. RIH with 3.5” overshot, Nipple profile, 3.5” x 7.0” packer, 3.5” x 5.5” crossover, 5.5” x 7.0” packer, and 5.5” tie- back liner to surface. (Crossover to 7.0” at surface for last joint if needed for wellhead termination.) 13. Reverse circulate in CI fluid and freeze protect as needed. 14. Pressure up on tubing to set both the 3.5” x 7.0” and the 5.5” x 7.0” packers. 15. RU SL and RIH to pull isolation sleeve across communication ports in top of PBR assembly. a. Communication port allows pressure communication from 3.5” x 5.5” annulus down to 3.5” x 7.0” annulus. Covered up on initial install to allow packer setting. b. Replace Dual Flapper Check Valve (DFCV) in tubing nipple with plug as necessary. c. If SL not available, then finish steps below to terminate 5.5” and get new tubing spool on. Then RIH and pull sleeve with tubing. 16. PT 5.5” liner to 2500 psig for 30 minutes and chart. (This is the new IA envelope.) 17. Set 5.5” RBP near surface. PT to confirm as barrier. 18. ND BOPE. Finish 5.5” termination. NU new tubing spool. NU BOPE. Test flange breaks. 19. Pull 5.5” RBP. Freeze protect new OA at opportune moment. 2M-15 RWO Procedure Kuparuk Producer PTD #191-033 Page 2 of 2 Install in 3-½” Completion 20. MU 3 ½” slim completion with seals, nipples, and GLMs. RIH with completion. 21. Once on depth, stab in seals and space out as needed. Reverse circulate in CI fluid at opportune time as needed. 22. Pressure test tubing to 3000 psi for 30 minutes and chart. 23. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 24. Confirm pressure tests, then shear out SOV with pressure differential. 25. Install BPV. 26. ND BOPE. NU tree. PT tree. 27. Pull BPV, freeze protect well, and set BPV if necessary. 28. RDMO. Post-Rig Work 29. Pull BPV 30. Pull dual flapper valve. 31. Install GLD. 32. Pull any other plugs and turn over to operations. General Well info: Wellhead type/pressure rating: FMC Gen IV. 7-1/16” 5M psi top flange x 11” 3M psi bottom flange Production Engineer: Natalie Dye Reservoir Development Engineer: Mandy Pogany Estimated Start Date: 7/24/2023 Workover Engineer: Dusty Ward (265-6531/ dusty.ward@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to pre-rig cut. Pull buckled 7.0” casing near surface. Run new 3.5” x 5.5” tie-back liner with dual packers deep. Run slim new 3-1/2” completion. BOP configuration: Annular / Pipe Rams / Blind Rams / Cross/ Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed 6/28/2021 MIT-IA Failed 11/27/2020 MIT-OA Passed 10/8/2020 IC POT Failed 9/15/202 TBG POT &PPPOT N/A MPSP: 2307 psi using 0.1 psi/ft gradient Static BHP: 2915 psi / 6084’ TVD measured on 3/29/2020 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 6,707.0 3/28/2020 2M-15 jhansen8 Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Added PC Leak 5/25/2021 2M-15 jleonar3 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 42.0 Set Depth (ftKB) 123.0 Set Depth (TVD) … 123.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 41.5 Set Depth (ftKB) 2,900.8 Set Depth (TVD) … 2,900.8 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 42.2 Set Depth (ftKB) 6,998.0 Set Depth (TVD) … 6,311.2 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 38.7 Set Depth (ft… 6,534.2 Set Depth (TVD) (… 5,957.9 Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 38.7 38.7 0.11 HANGER FMC GEN IV TUBING HANGER 3.500 1,792.1 1,792.1 0.19 SAFETY VLV CAMCO TRDP-4A-RO SAFETY VALVE 2.812 6,492.9 5,926.8 40.92 PBR OTIS PBR w/ 10' STROKE W/4" SEAL BORE 2.970 6,508.6 5,938.6 40.91 PACKER OTIS HVT RETRIEVABLE PACKER 3.250 6,524.1 5,950.3 40.90 NIPPLE CAMCO D NIPPLE (Nipple Reducer Set 10/05/20) 1.810 6,533.6 5,957.5 40.90 WLEG OTIS RH BALL SEAT SUB/WIRELINE GUIDE (SHEARED), TTL ELMD @ 6523' SWS PERF 6/12/2007 2.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 370.0 370.0 0.20 TUBING RESTRICTION Tubing restriction from 370'-781' RKB when running assemblies longer than 4' w/ OD larger than 2.78" identified by Slickline 9/24/2020 2.990 5,340.0 5,046.1 37.12 PC LEAK While Logging Acoustic LDL, Leak discovered in PC 5340ft - 5360ft 5/24/2021 6.280 6,524.0 5,950.2 40.90 2.75" CA-2 Plug 2.75" CA-2 Plug (32" OAL) 11/13/2020 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,606.0 6,626.0 6,012.2 6,027.4 C-4, 2M-15 10/11/1999 4.0 APERF 60 deg ph; no orientation; SWS 2.5" HC DP chgs6,656.0 6,668.0 6,050.1 6,059.2 A-4, 2M-15 10/12/2007 6.0 APERF 2" HSD PJ OMEGA 60 deg ph6,684.0 6,704.0 6,071.4 6,086.6 A-3, 2M-15 2/26/1992 4.0 IPERF 180 deg. ph; Oriented 44 deg CCW; SWS 4.5" Csg Guns6,704.0 6,724.0 6,086.6 6,101.8 A-3, 2M-15 2/26/1992 4.0 IPERF 180 deg ph; Oriented 34.5 deg CCW; SWS 4.5" Csg GunsStimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 7/11/2001 6,606.0 6,626.0 0.0 0.00 0.00 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,534.4 2,534.4 0.26 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 11/28/2020 2 4,156.7 4,099.9 31.71 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 11/28/2020 3 5,273.2 4,992.9 37.15 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 11/28/2020 4 5,787.2 5,392.8 40.46 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 7/2/1998 5 6,110.7 5,638.2 40.90 OTIS WBD 1 GAS LIFT DMY BK 0.000 0.0 12/31/1997 6 6,440.4 5,887.1 40.91 OTIS LBX 1 1/2 GAS LIFT DMY RM1 0.000 0.0 7/8/2001 Notes: General & Safety End Date Annotation 11/12/2010 NOTE: View Schematic w/ Alaska Schematic9.0 2M-15, 5/25/2021 10:04:23 AM Vertical schematic (actual) PRODUCTION; 42.2-6,998.0 IPERF; 6,704.0-6,724.0 IPERF; 6,684.0-6,704.0 APERF; 6,656.0-6,668.0 FRAC; 6,606.0 APERF; 6,606.0-6,626.0 WLEG; 6,533.6 2.75" CA-2 Plug; 6,524.0 NIPPLE; 6,524.1 PACKER; 6,508.7 PBR; 6,492.9 GAS LIFT; 6,440.4 GAS LIFT; 6,110.7 GAS LIFT; 5,787.2 PC LEAK; 5,340.0 GAS LIFT; 5,273.2 GAS LIFT; 4,156.7 SURFACE; 41.5-2,900.8 GAS LIFT; 2,534.4 SAFETY VLV; 1,792.1 TUBING RESTRICTION; 370.0 CONDUCTOR; 42.0-123.0 HANGER; 38.7 KUP PROD KB-Grd (ft) 41.49 Rig Release Date 12/15/1991 2M-15 ... TD Act Btm (ftKB) 7,021.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032015400 Wellbore Status PROD Max Angle & MD Incl (°) 41.10 MD (ftKB) 6,300.00 WELLNAME WELLBORE2M-15 Annotation Last WO: End DateH2S (ppm) 125 Date 12/15/2019 Comment SSSV: TRDP 2M-15 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top)Thread (btm) Conductor 123 123 16 15.06 62.58 H-40 Welded Welded Surface 2901 2901 9.625 8.92 36 J-55 BTC BTC Production/ Intermediate 6998 6311 7 6.28 26 J-55 BTC BTC Liner 6450 5.5x3.5 4.95 15.5 L-80 HYD563MS HYD563MS Tubing 6360 3.5 2.992 9.3 L-80 EUE8rd Mod EUE8rd Mod PROPOSED 3.5" COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco KBG-29 gas lift mandrels @ TBD 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" Seals PROPOSED 5.5" x 3.5" Tie-Back 5-1/2", 15.5#, L80, HYD563 MS (5.873" OD) to Surface 5-1/2" x 7.0" Packer PBR for 3-1/2" Seals (with port to IA covered with sleeve on install) 3-1/2" x 5-1/2" Crossover 3-1/2" Camco MMG gas lift mandrel 3-1/2" X landing nipple at xxxx' RKB (2.813" min ID) 3-1/2" x 7" Packer 2.75" D-landing nipple at xxxx' RKB (2.75" min ID) 3-1/2" Non-sealing Overshot REMAINING COMPLETION LEFT IN HOLE Packer @ 6508' RKB (3.250" ID) D nipple @ 6524' RKB (2.813" ID) WLEG @ 6534' RKB Surface Casing Production/Intermediate Casing Conductor A and C-sand perfs ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE C:\Users\aebell\Desktop\May 2021 Data Drop\CPA Data Drop 06022021\2021-05-23_15781_2M-15_LeakPointSruvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15781 KRU 2M-15 50-103-20154-00 LeakPoint Survey 23 & 24-May-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM Abby Bell PTD: 191033 E-Set: 35176 ~ ~ WELL LOG ,,~, .. S TRAN3M/TTAL ProActive Diagnostic Services, Inc. To: ACaGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 [907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn; Robert A. Richey 130 West International Airport Road ~~~~~; ~ ~ ~~ ;~ L ~ ~ J Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 ] Caliper Report 08-Dec-0B 2M-15 1 Report / EDE 50-103-2015400 2] Signed Print Name: Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAf3E, AK 99518 PHONE: (907)245-8851 FAX: (907)245-88952 E-MAIL: ~~i,~lsos°~ ~ im~;sairc~ylo .curia WEBSITE: ~vw/~:,rrs~a~svsyle~~.c;arrr ~, _ ~ _ ._ 1 ~? ~ --c~33 ~ c ~~ C:\Documents and Setlings\Owner\Desktop\Transatit_Conoco.docx • • Memory MuttrFinger Caliper Log Results. Summary Company: ConocoPhiNipS Alaska, Inc. Well: 2M-15 Log Date: December 8, 2008 Field: Kuparuk Log No, : 8725 State: Alaska Run No.: 1 APf No.: 50-103-2015400 Pipet Desc.: 3.5" 9.3 Ib. J-55 ABM EUE Top Log Intuit.: Surtace Pipet Use: Tubing Bot. Log Intuit.: 6,525 Ft. (MD) Inspection Type : Potentiall.D. Restriction /nspection COMMENTS This caliper data is tied into the Otis PBR @ 6,493' (Driller's Depth). This log was run to identify potential I.D. restrictions in the 3.5" tubing. The caliper recordings indicate no significant I.D. restrictions throughout the 3.5" tubing logged. The caliper recorded buckling in the 3.5" tubing from surtace to the end of the log interval. The caliper recordings indicate the 3.5" tubing is in good condition with respect to internal corrosive and mechanical damage, with no significant wall penetrations or areas of cross-sectional wall loss recorded. MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 12%) are recorded throughout the 3.5" tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas ofcross-sectional wall loss (> 2°~) are recorded throughout the 3.5" tubing logged. MAXIMUM RECORDED ID RESTRICTIONS No significant t.D. restrictions are recorded throughout the 3.5" tubing logged. Field Engineer: K. Miller Analyst: C. Waldrop Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stallard, TX 77497 Phone: (281} or (888) 565-9085 Fax; f281) 565-1369 E-mail: PDS~Nmemoryiog.com Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907} 659-2314 ~ ~i l-b3~ 1 ~ ~`~ • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (18.7' - 6522.4') Well: 2M-15 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: December 8, 2008 ^ Approx. Tool Deviation ^ Approx. Borehole Profile 26 789 1582 2398 GLM 1 3198 ~ c s .- 3992 Q GLM 2 4793 GLM 3 5595 GLM 4 GLM 5 GLM 6 6402 201.4 6522 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 201.4 1 25 50 75 100 w E z ~ 125 150 175 ~J PDS Report Overview ~~ ~. Body Region Analysis Well: 2M-15 Survey Date: December 8, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f -55 ABM Fl1E 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body metal loss body 2 5 0 200 150 100 50 0 0 to 1 to 10 to 1% 10%~ 20% 20 to 40 to over 40% 85% 85% Number of 'oints anal se d rota) = 208 pene. 0 206 2 loss 99 109 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion contusion ible hole Number of "oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body „_~: metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 Bottorrt of Survey = 201.5 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 ABM EUE Well: 2M-15 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: December 8, 2008 Joint No. Jt. Depth (Ft.) I'~~n. llt>sc~i (Int.l Pen. Body (Ins.) Pcvi. `~~ Metal I~>ss °4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 19 0 0.01 2 I 2.99 PUP 1 26 (! 0.01 i I 2.96 Bucklin . 2 58 ~! 0.01 ~' 2.96 3 89 U 0.01 5 2.97 4 121 0 0.01 =i 2.96 5 153 ~ ! 0.01 -1 I 2.93 6 185 n 0.01 4 I 2.96 7 217 U 0.01 5 I 2.96 Bucklin . 8 248 0 0.01 4 ~' 2.96 9 280 0 0.01 4 5 2.96 10 312 0 0.01 4 ' .96 11 344 U 0.01 5 _' 2.96 12 375 0 0.01 4 I 2.95 13 407 0 0.01 5 2.96 ucklin . 14 439 tt 0.03 1U I 2.93 15 471 t J 0.01 i 2.95 16 503 t) 0.01 4 2 2.96 17 534 U 0.01 5 I 2.96 18 566 t i 0.01 > _' 2.96 19 597 a 0.01 ~t I 2.96 Bucklin . 20 629 U 0.01 5 1 2.96 21 661 ~! 0.01 4 I 2.96 22 693 t? 0.01 -1 I 2.93 23 724 U 0.01 ~1 I 2.96 4 757 0 0.01 ~ _' 2.97 25 789 0 0.01 4 ' 2.96 Bucklin . 26 820 0 0.01 -1 Z 2.96 27 852 0 0.01 5 2 2.94 28 884 0 .01 5 1 2.97 29 916 0 0.01 ~1 -t 2.96 30 947 t i 0.01 4 ' 2.96 31 979 0 0.01 5 1 2.94 Bucklin . 32 1011 t t 0.01 4 2 2.96 33 1042 a 0.01 6 1 2.94 34 1074 0 0.01 .5 I 2.96 35 1106 0 0.01 4 _' 2.97 36 1138 t i 0.01 4 I 2.96 37 1170 0 0.01 a I 2.96 Bucklin . 38 1201 0 0.01 4 ' 2.93 39 1233 ti 0.01 -1 _' 2.96 40 1265 t1 0.01 .} 97 41 1296 ti 0.01 3 I 2.96 42 1328 a 0.01 (~ 1 2.96 43 1360 0 0.01 4 2.96 Bucklin . 44 1392 0 0.01 ~ ~' 2.96 45 1423 0 0.01 i I 2.97 46 1455 t t 0 01 4 .97 47 1487 ~ i 0.01 ~' 2.96 48 1519 0.01 r _' 2.97 49 1550 ~ 0.02 .s I 2.95 Bucklin ~. Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINTTABI, Pipe: 3.5 in 9.3 ppf J-55 ABM EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 2 M-15 Kuparuk ConocoPhillips Alaska, Inc. USA December 8, 2008 Joint No. Jt. Depth (Ft.) I'~~n. I ll~,~~t (ln~.j Pen. Body (Ins.) Pc~n. `i., ~.!~ i.~l I u.. ,. Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 50 1582 i? 0.02 '~ 2.95 51 1613 i! 0.01 i I 2.96 52 1645 i ! 0.01 5 2.93 53 1677 i? 0.01 a 2.96 54 1709 a 0.02 '~ 2.94 55 1741 i1 0.01 -~ .96 Bucklin . 55.1 1772 i? 0.01 ' I 2.92 PUP 55.2 1780 U 0 O ~? 2.81 Camco'TRDP-4A' RO SSSV 55.3 1787 a 0.01 2 I 2.91 PUP 56 795 U 0.01 i _' 2.94 57 182 7 U 0.01 -t 2.94 58 1858 U 0.02 tS I 2.95 Bucklin . 59 1887 U 0.01 5 I 2.95 60 1922 t ~ 0.01 5 I .96 61 1954 ~> 0.01 i~ I 2.95 62 1986 t! 0.01 '~ i 2.96 63 2018 n 0.01 i~ I 2.95 6 049 t! 0.01 -t 2.95 Bucklin . 65 2081 !! 0.01 -t 2.95 66 2113 c ? 0.01 ~ I 2.96 67 2144 i? 0.01 -1 ~' 2.94 68 2176 U 0.01 5 2 2.97 69 2208 t) .01 6 _' 2.96 70 2239 U 0.01 5 1 2.93 Bucklin . 71 2272 U 0.02 1 .96 72 2303 i? 0.01 t~ -t 2.93 73 2335 i) 0.01 i~ ~ 2.95 74 2366 a 0.01 5 1 2.95 75 2398 f) 0.01 5 1 2.96 76 2429 i) 0.02 ~) ~ 2.93 Bucklin . 77 2461 n 0.01 5 _' 2.95 78 2493 i! 0.01 6 3 2.95 78.1 2524 i? 0 t) tl N A GLM 1 tch ~ 8:00 79 2531 a 0.01 ~~ ~ 2.95 80 2563 U 0.01 ~4 I 2.95 81 2595 i! 0.01 6 I 2.95 Bucklin . 82 2626 !~ 0.01 (~ I .95 83 2658 a 0.01 ~1 1 2.95 84 2690 a 0.01 5 1 2.9 85 2722 a 0.01 4 I 2.94 86 27 3 i! 0.02 9 I 2.94 87 2785 I) 0.02 - I 2.94 Bucklin . 88 2 817 i 1 0.02 ti 2.94 89 2849 n 0.01 -1 2.94 9 2881 i! 0.01 -t 2.95 91 2 912 ~ i 0.01 5 _' 2.92 92 2944 !! 0.01 E~ I 2.95 93 2976 i! 0.01 5 4 2.94 Bucklin . 94 3007 t! 0.02 i I 2.95 95 3039 i! 0.02 i 2.95 _ Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipc: 3.5 in 9.3 ppf )-55 ABM EUE Well: 2M-15 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: December 8, 2008 Joint No. Jt. Depth (Ft.) I'c~n. lll~,o-~t (Irn.) Pen. Body (Ins.) PE~n. °-~, ~te~t,~l I u,> ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 3071 t ~ 0.02 9 '~ 2.95 97 3102 ~) 0.01 ~ 2.95 98 3134 U 0.01 ? 2.94 99 3166 U 0.01 i 2.95 Bucklin . 100 3198 ~) 0.02 - 2.96 101 3230 a 0.01 -1 2.97 102 3262 ~) 0.01 ~; 2.95 103 3293 +) 0.01 -l 2.96 104 3325 t? 0.01 5 _~ 2.94 105 3357 t> 0.01 '~ 2.95 Bucklin . 106 3388 U 0.02 2.94 107 3420 t) 0.01 ~~ I 2.95 108 3452 t) 0.02 2.95 109 3483 a 0.03 1 u I 2.93 110 3515 !? 0.01 -1 _' 2.94 111 3547 t) 0.01 -J 1 2.94 B cklin . 112 3579 U 0.01 > I 2.92 113 3610 t) 0.02 8 I 2.95 114 3642 a 0.02 8 2.93 115 3674 t) 0.01 5 I .93 Lt. De osits. 11 3706 tt 0.02 f3 I 2.94 117 3737 t t 0.03 1 U I 2.93 Bucklin . 118 3769 U 0.01 5 1 2 93 119 3801 i ? 0.02 2 2.92 120 3833 a 0.01 (, ; 2.95 121 3864 t) 0.02 ~> 2.95 122 3896 t) 0.02 ~) 2 2.92 123 3928 0 0.02 ~) 1 2.94 Bucklin . 124 3960 U 0.01 (> ~ 2.95 125 3992 (t 0.01 5 1 2.94 126 4023 !) 0.01 4 s 2.94 127 4055 c) 0.02 ~) ~' 2.93 128 4086 a 0.02 ~) 1 2.93 129 4118 It 0.03 10 1 2.92 Bucklin . 129.1 4150 U 0 U 0 N A GLM 2 Latch @ 4:30 130 4156 t) 0.02 ' 2.94 131 4189 0 0.02 ~) I 2.93 132 4221 a 0.03 I _' 2.93 133 4253 U 0.02 - _' .94 134 4284 0 0.02 8 ? 2.93 Bucklin . 135 4316 c) 0.01 5 ~ 2.95 136 4349 0 0.01 (~ I 2.95 13 4381 0 0.01 ~ ? 2.93 138 4413 a 0.02 ~) I 2.93 139 4444 U 0.01 -1 I 2.95 140 4476 t) 0.02 tI 2.95 Bucklin . 141 4508 ~~ 0.02 ti I 2.93 142 4539 t? 0.01 d I 2.94 143 4.571 0.01 5 1 2 95 144 4603 0.01 4 I 2.95 _ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABS Pipe: 3.5 in 9.3 ppf J-55 ABM EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • CATION SHEET 2 M-15 Kuparuk ConocoPhillips Alaska, Inc USA December 8, 2008 Joint No. Jt. Depth (Ft.) I'c~n. ulc.c~r Um.) Pen. Body (Ins.) P<~n. % ~tc~t,c) Icss °~~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 145 4634 t ~ 0.01 4 _' 2.94 146 4666 a 0.02 2.95 B cklin . 147 469$ tt 0.02 ~) I 2.93 148 472 r ~ 0.02 ci I 2.92 149 4761 ~ ~ 0.02 c) 2.92 Lt. De osiis. 150 4793 ~.~ 0.01 ~i ~ 2.90 Lt. De sits. 151 482 5 u 0.02 _ 2.94 152 4857 U 0.02 ti 2.94 Bucklin . 153 4888 a 0.01 5 2.95 154 4920 U 0.02 fi 2.94 1 4952 t~ 0.02 c) _' 2.94 156 4984 t? 0.02 7 I 2.94 157 5015 c ~ 0.01 (~ I 2.94 158 5047 t ~ 0.02 _ 2.95 ucklin 159 5079 U 0.02 ~) .93 160 5110 t~ 0.02 ~~ .93 161 5143 U 0.02 c~ .' 2.93 162 5174 t ~ 0.01 4 _' .93 163 5206 tr 0.02 9 .! 2.93 164 5238 ! ~ 0.03 11 2 2.94 ucklin . 164.1 5269 u 0 0 tr N A LM 3 Lath 9:30 165 5276 U 0.02 2.93 166 5308 t ~ 0.02 c~ _' 2.93 167 5340 U 0.01 ~ tt 2.95 168 5372 U 0.01 V I .93 169 5404 t ~ 0.01 4 _' 2.95 Bucklin . 170 5435 t~ 0.02 c) ? 2.93 171 5467 U 0.01 5 ~' 2.95 172 5499 a 0.0 -l I 2.93 173 5531 a 0.01 ~ I 2.92 174 5563 (1 0.01 4 I 2.94 175 5595 ll 0.01 5 I 2.96 Bucklin . 176 5 27 t1 0.01 4 _ 2.94 177 5659 U 0.02 8 I 2.96 178 5690 t ~ 0.02 - 2.96 179 5722 n 0.02 c) .' 2.94 180 5753 U 0.01 4 I 2.96 180.1 5783 U 0 (1 li N A GLM 4 Latch ~ 1:30 181 5792 l) 0.02 - I 2.94 Bucklin . 182 5824 t~ 0.02 ~ I 2.96 183 5855 U 0.01 4 _' 2.96 184 5887 a 0.01 t, I 2.94 185 5920 (~ 0.01 C. 1 2.96 186 5952 t) 0.02 7 1 2.94 187 5983 a 0.01 4 1 2.96 Bucklin . 188 6015 t ~ 0.01 5 1 2.93 189 6047 t 1 0.01 5 1 2.96 190 6079 U 0.01 4 I 2.93 190.1 6110 It 0 t1 t~ N A LM 5 Latc ~ 12:30 191 6117 a 0.02 7 I 2.95 Penetration Body Metal Loss Body Page 4 PDS REPORT )DINT TABI. Pipe: 3.5 in 9.3 ppf J-55 ABM EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 2 M-15 Kuparuk ConocoPhillips Alaska, Inc USA December 8, 2008 Joint No. Jt. Depth (FL) I'wi. UI,zE~t (Irn.l Pen. Body (Ins.) I'~~n. `;~~ ~t~~t,~l I ~~.~ ~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 192 6149 ~ ~ 0.01 -3 I 2.96 Bucklin . 193 6181 t ~ 0.01 4 U 2. 6 1 4 6212 tt 0.02 `) 2.93 Lt. De osits. 195 6244 t 1 0.01 i _' 2.96 196 6276 U 0.01 6 _' 2.95 197 6307 (~ 0.01 4 1 2.97 198 6339 t~ 0.01 -t 1 2.96 Bucklin . 199 6371 U 0.01 4 2.95 200 6402 O 0.01 (~ .95 200.1 6434 a 0.01 b I 2.9 PUP 200.2 6440 ll 0 ~~ ~ ~ N A GLM 6 Latch ®3:30 200.3 6448 t ~ 0.02 ~ ~ 2.96 PUP 201 6455 t~ 0.02 I 2.94 201.1 6487 ~? 0.01 ~ I 2.95 PUP 201. 6493 11 0 l) t) 2.97 Oti PBR 201.3 6504 ~? 0 l) U 3.25 Otis 'I-iv!' Packer 201.4 6516 ~.? 0.02 t3 I 2.94 PUP 201.5 6522 U 0 l) (~ 2.75 Camc -Ni le NO GO _ Penetration Body Metal Loss Body Page 5 i~ i~ i~ i~ i~ i~ i~ i~ ii i~ i~ i~ II '~ '~ '~ '~ • ConocoPhillips Alaska, Inc. KRU 2M-15 2M-15 - API: 501032015400 Well T e: PROD An le TS: 41 de 6604 sssv SSSV Type: TRDP Orig Com letion: 12/15/1991 Angle @ TD: 40 deg @ 7021 (17x2-1793, Annular Fluid: Last WlO: Rev Reason: PERFS oD:3.5o0) Reference L Ref L Date: Last U ate: 10/132007 Last Ta : 6700 TD: 7021 ftKB Last Ta Date: 9/27/2007 Max Hole An le: 41 de 6300 Casin Strin -ALL STRI NGS Gas Lift Descri lion Slze To Bottom TVD Wt Grade Thread MandrelNalve CONDUCTOR 16.000 0 123 123 62.58 H110 1 (2534-2535 SUR. CASING 9.625 0 2901 2901 36.00 J-55 , PROD. CASING 7.000 0 6998 6311 26.00 J-55 Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread Gas Lift 3.500 0 6534 5958 9.30 J-55 ABM EUE MandreWaNe ~ 2 ~ ~ Perforations Summa (4157-4158 Interval TVD Zone Status Ft SPF Date T e Comment , 6606 - 6626 6012 - 6027 C-4 20 4 10/11/1999 APERF 60 deg ph; no orienfation; SWS 2.5" HC DP ch s Gas Lift 6656 - 6668 6050 - 6059 A-4 12 6 10/12/2007 APERF 2" HSD PJ OMEGA 60 deg h Mantlrewalve 3 (5273-5274, 6684 - 6724 6071 - 6102 A-3 40 4 2/26/1992 IPERF 180 deg. ph; Oriented 44 deg CCW; SWS 4.5" Csg Guns Stimulations 8 Treatments Interval Date T e Comment Gas Litt 6606 - 6626 7/11/2001 FRAC 'C' SAND FRAC indie1Dinmy Valve 4 Gas Lift MandrelsNalves (5787-5788, OD:5.540) 3t MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2534 2534 Otis WB GLV 1.0 BK 0.156 1267 7/8/2001 2 4157 4100 Otis WB GLV 1.0 BK 0.188 1311 7/7/2001 Gas Lift ~ 3 5273 4993 Otis WB OV 1.0 BK 0.250 0 7/7/2001 'ndrevDUmmy - I 4 5787 5393 Otis WB DMY 1.0 BK 0.000 0 7/2/1998 valves (6t11-6112 ~ 5 6111 5638 Otis WB DMY 1.0 BK 0.000 0 2/31/199 , OD:5.540) 6 6440 5887 Otis LB DMY 1.5 RM-1 0.000 0 7/8/2001 Other u s ui .etc. -JEWELRY De th TVD T Descri lion ID Gas Lift 1792 1792 SSSV Camco'TRDP-4A' RO 2.812 '"~~'~r"y v l s 6493 5927 PBR Otis 2.970 a ve (s44o-sa4t 6509 5939 PKR Otis'HVT ReV. 3.250 , oD:6.sso) 6524 5950 NIP Camco'D' Ni le NO GO 2.750 6534 5958 SOS Otis'RH' Bell Seat Sub 2.992 6534 5958 TTL 2.992 PBR (6493-6494, OD:3.500) PKR (6509-6510, OD:6.151) NIP (6524-6525, OD:3.500) T UBING (08534, OD 3 500 : . , ID:2.992) TTL (8634-6535, OD:3.500) FRAC (66066626) Perf (66068626) Pert (6684-6704) Pert (6704-6724) ~ ` • • Con ~ ' ' ocoPh~llips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 JAN O 8 Z00~ Afsaka Oil & Gaa Cvna, Cvnrrt~~u~i~n January 6, 2008 Anchorage Mr. Tom Maunder Alaska Oil & Gas Commission ©~j3 333 West 7~' Avenue, Suite 100 1(~t' Anchorage, AK 99501 ~~~~ vi~~ ~ ~; ~~~~ 1' Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of 12". The remaining volume of annular void respectively was filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on Dec 25, 2007. We mixed 15.7 ppg Class G cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor/sealant was pumped in a similar manner Jan 6, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, Perry ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 1)a+s~ Schlumberger -DCS - _ :' 2525 Gambell Street, Suite 400 • Anchorage, AK 99503-2838 ATTN: Beth ~ ~~ yeti ~~~~ ~~ Well Job # Log Description NO. 4532 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 12/20/07 1J-105 11837540 INJECTION PROFILE ~"1'1'~-(~''-~ 11120/07 1 1A-06 11837542 RST WFL ~'t _!/~ i 11/22/07 1 10-05 11837537 _ LDL C - ( 11117107 1 1B-12 11970607 INJECTION PROFILE J-1' 12/04/07 1 2N-327 11996582 OILPHASE SAMPLER Q~- (a 12/15/07 1 1D-132 11994588 SBHP SURVEY i,~ -- ~ 12/17/07 1 3H-10B 11996580 PATCH EVALUATION = Q 12/13/07 1 3N-02A 11970609 LDL $ - 12105107 1 1C-125 11964553 INJECTION PROFILE - 12/01/07 1 2M-15 NIA PRODUCTION PROFILE ( ~ " 12110107 1 2M-11 NIA PRODUCTION PROFILE ~q - 1 12/08/07 1 3A-036 11970604 SCMT °•}- / 12/01107 1 2T-217A 11978431 SCMT 12/15/07 1 2L-330 11837544 FULLBORE MICRO SCANNER 11/27107 1 2L-330 11837544 SONIC SCANNER 11/27/07 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . EC:;EIVED nc araae 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Opera!. ShutdownD Perforate Q Re-enter Suspended Well 0 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q , Exploratory 0 191-0331 , 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20154-00 ,- 7. KB Elevation (ft): 9. Well Name and Number: RKB 147' / 2M-15 . 8. Property Designation: 10. Field/Pool(s): ADL 25586, ÄLK 2672 Kuparuk River Field 1 Kuparuk Oil Pool / 11. Present Well Condition Summary: Total Depth measured 7021' . feet true vertical 6329' . feet Plugs (measured) Effective Depth measured 6700' feet Junk (measured) true vertical 6084' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 123' 123' SUR. CASING 2860' 9-5/8" 2901' 2901' PROD. CASING 6956' 7" 6998' 6311' Perforation depth: Measured depth: ,6606'-6626',6656'-6668',6684'-6724' 5CANNED NOY o 1 2007 true vertical depth: 6012'-6027',6050'-6059',6071'-6102' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 6534' MD. Packers & SSSV (type & measured depth) pkr- OTIS 'HVT RETR. pkr- 6509' ._". c, ,..I.1':'~'·."··~·'·""·'-"~ Cameo TRDP-4A RO SSSV= 1792' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable RBDMS 8Ft OCT í 9 2007 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure TubinQ Pressure Prior to well operation 392 1040 1169 -- 233 Subsequent to operation 457. 648 1075 -- 236 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory 0 Q / 0 Development Service Daily Report of Well Operations _X 16. Well Status after work: OiIQ GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: none __/J Contact Guy Schwartz @ 265-6958 é?i;t ,-" v. '~ - Printed Name Guy Schwartz Title Wells Group Engineer .- Signature Phone Dat /" "I z.-z./o Preoared bv Sharon Allsuo-Drake 263-4612 . STATE OF ALASKA OCT 2 3 2007 ALASKA OIL AND GAS CONSERVATION COMMISSli~ u DiI..& G C C .- REPORT OF SUNDRY WELL OPERAffoNSA aSh ons.. ommlsslon Form 10-404 Revised 04/2006 OR\G\NAL ~ '-O~ \p ~ ~. ~c.-""7 ~~~ . 2M-15 Well Events Summary . DATE Summary RAN 10' OF 2.5" DUMMY GUN DRIFT. TAGGED BOTTOM @ 6700' SLM. 9/27/07 NO SAMPLE OBTAINED. JOB COMPLETE. 10/12/07 PERFORATED 6656'-6668', 6SPF, 2" POWERJET OMEGA GUNS / . . ConocoPhillipsAlaska, Inc. KRU 2M-15 'YtWJP API: 501002015400 Well TVDe: PROD Anale@TS: 41dea@66~ ~ SSSV Type: TRDP Orig 12/1511991 Angle @ TD: 40 deg @ 7021 SSSV ComDletion: (1792-1793, Annular Fluid: Last W/O: Rev Reason: PERFS OD:3.500) Reference Loa: Ref Loa Date: Last Update: 10/13/2007 Last Taa: 6700 TD: 7021 ftKB __e: 9/27/2007 MaXHole~6300 Gas Lift m DeseriDllon Size Top Bottom TVD Wt Grade Thread MandrelNalve CONDUCTOR 16.000 0 123 123 62.58 H-40 1 SUR. CASING 9.625 0 II; 2901 36.00 J-55 (2534-2535. PROD. CASING 7.000 0 6311 26.00 J-55 ¡lit .1 ~ Size I Top I BDltom I TVD Wt I Grade I Thread Gas Lift 3.500 I 0 I 6534 I 5958 I 9.30 I J-55 I ABM EUE MandrelNalve 2 Interval TVD Zone Status Ft SPF Date Type Comment (4157-4158. 6606 - 6626 6012- 6027 C-4 20 4 10/11/1999 APERF 60 deg ph; no orientation; SWS 2.5" HC DP ehQs 1+r 6656 - 6668 6050 - 6059 A-4 12 6 10/12/2007 APERF 2" HSD PJ OMEGA 60 deg Gas Lift ph MandrelNalve 6684 - 6724 6071- 6102 A-3 40 4 2/26/1002 IPERF 180 deg. ph; Oriented 44 3 deg CCW; SWS 4.5" Csg (5273-5274. Guns -.,.,. Interval I Date Type I Comment Gas Lift ... 6606 - 6626 7/11/2001 FRAC I 'C' SAND FRAC I ndrel/Dummy ill .¡- Valve 4 (5787-5788. St MD TVD Man Mfr Man Type VMtr V Type VOD Latch Port TRO Date Run Vlv OD:5.MO) Cmnt 1 2534 2534 Otis WB GLV 1.0 BK 0.156 1267 7/8/2001 2 4157 4100 Otis WB GLV 1.0 BK 0.188 1311 7/7/2001 Gas Lift ... 3 5273 4993 Otis WB OV 1.0 BK 0.250 0 717/2001 I ndrel/Dummy 4 5787 5393 Otis WB DMY 1.0 BK 0.000 0 7/2/1900 Valve 5 5 6111 5638 Otis WB DMY 1.0 BK 0.000 0 12/31/199 (6111-6112. OD:5.MO) 6 6440 5887 Otis LB DMY 1.5 RM-1 0.000 0 7/8/2001 [ Depth TVD Tvpe Description ID Gas Lift ~~ 1792 1792 SSSV Cameo 'TRDP-4A' RO 2.812 I ndrellDum m y 6493 5927 PBR Otis 2.970 Valve 6 6509 5939 PKR Otis 'HVT Retr. 3.250 (6440-6441. OD:5.960) 6524 5950 NIP Cameo 'D' Nipple NO GO 2.750 6534 5958 SOS Otis 'RH' Ball Seat Sub 2.992 6534 5958 TTL 2.992 PBR IlL (6493-6494, OD:3.500) PKR (6509-6510, OD:6.151) NIP ~ (6524-6525, OD:3.500) Xi TUBING Xi (0-6534, OD:3.500. f-------'--iiii ID2.992) í\ TTL (6534-6535. ~ OD:3.500) FRAC r =~ (6606-6626) Perf (6606-6626) Perf c-:c (6684-6704) - ~-- - r--- Perf === - ~p (6704-6724) _._~- . ""- - f---- -"" Û ~......~~~-~-~._.._-- ~ ./' 01/02/07 Schlumbel'gel' NO. 4092 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth r;;¡fj1F:h,iGANNED JAN 0 8 2007 Company: Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 PI I - ()33 Field: Kuparuk Well Job# Log Description Date BL Color CD 2N-304 11416232 FBHP SURVEY 10/30/06 1 2N-304 11296737 FBHP SURVEY 11/04/06 1 10-109 N/A INJECTION PROFILE 11/27/06 1 ·1J-136 (REDO) 11534188 USIT 12/10/06 1 1R-18 N/A SBHP/DD 12/18/06 1 1G-16 11551836 INJECTION PROFILE 12/19/06 1 10-103 11548555 INJECTION PROFILE 12/20/06 1 3K-09A N/A SBHP SURVEY 12/22/06 1 3K-26 N/A SBHP SURVEY 12/22/06 1 3K-18 11551838 SBHP SURVEY 12/23/06 1 2N-326 11551840 SBHP SURVEY 12/24/06 1 3S-19 . 11548564 PRODUCTION PROFILE 12/25/06 1 2M-10 11551841 PRODUCTION PROFILE 12/25/06 1 2M-16 11551842 INJECTION PROFILE 12/26/06 1 2A-20 11548565 INJECTION PROFILE 12/26/06 1 2M-15 11551843 PRODUCTION PROFILE 12/27/06 1 2M-22 11538773 PRODUCTION PROFILE 12/28/06 1 1J-184 11538775 PRODUCTION PROFILE 12/30/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . PI- -LIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 July 30, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t~ Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2M- 15 (191-033) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent frac treatement on the KRU well 2M-15. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Staff Engineer Phillips Drilling MM/skad RECEIVED AU~ O 1 2001 Alaska 0il & Gas Cons Anchorage' c°mraission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 147 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 5162' FNL, 4951' FEL, Sec. 27, T11 N, RSE, UM (asp's 488169, 5948986) 2M-15 At top of productive interval 9. Permit number / approval number 1246' FSL, 1100' FEL, Sec. 28, T11N, RSE, UM 191-033/ At effective depth 10. APl number 50-103-20154 At total depth 11. Field / Pool 3865' FNL, 1308' FEL, Sec. 28, T11 N, RSE, UM (asp's 486531, 5950287) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7021 feet Plugs (measured) true vertical 6329 feet Effective depth: measured 6728 feet Junk (measured) true vertical 6105 feet Casing Length Size Cemented Measured Depth True vertical Depth .. CONDUCTOR 123' 16" 225 sx AS ~ 123' 123' SUR. CASING 2754' 9-5/8" 540 sx PF E, 485 sx Class w/20 b 2901' 2901' PROD. CASING 6851' 7" 220 sx Class G 6998' 6311' Perforation depth: measured 6606'- 6626', 6684' - 6724' F~EOEi~J~Dv~.. true vertical 6012'- 6027', 6071'-6101' AUG 0 12001 Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 6534' MD. Alaska 0il & Gas Cons. Anchoroge CommiSsion Packers & SSSV (type & measured depth) OTIS 'HVT' RETR. @ 6509' MD. CAMCO 'TRDP-4A' Re @ 1792' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attachment Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 606 788 934 217 Subsequent to operation 1211 1416 1910 204 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ X Gas __ Suspended __ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney263-4574 Signed Title Staff Engineer Date ... Michael Mooney Prepared by Sharon AIIsup-Drake 263-4612 Form 10-404 Rev 06/15/88 · ORIGINAL Date Comment 2M-15 Event History 07/07/01 07/08/01 TAGGED FILL @ 6688' RKB, REPLACED GLV'S W/DV'S @ 2534', 4157' & 5273' RKB, SET 2.75" CRX PLUG @ 6524' RKB, FAILED TO PT TBG, IN PROGRESS [TAG, OPEN-CLOSE A SAND, PT TBG-CSG] REPLACED LEAKING DV @ 2534' RKB, LOADED CASING W/118 BBL'S SEA WATER, PT TBG & CASING TO 3500# HELD, PULLED 2.75" CRX PLUG @ 6524' RKB [GLV, PT TBG-CSG, OPEN-CLOSE A SAND] 07/09/01 07/10/01 07/11/01 PUMPED 900# 20/40 SAND TO ISOLATE A SAND PERFS - WELL BEGAN TO PRESSURE UP WHILE PUMPING DIESEL FLUSH - STOPPED DISPLACEMENT 5.5 BBLS SHORT - ANTICIPATE SAND TOP AT 6638' RKB - FREEZE PROTECT WELL TO 1780' RKB TAGGED SAND PLUG @ 6648' RKB, SET FRAC SLEEVE @ 1792' RKB [TAG, SSSV WORK] PUMPED C SAND FRAC - PLACED A TOTAL OF 132191 LBS 16/20 PROPPANT BEHIND PIPE (INCLUDING 2094# IN SCOUR STAGE)- LEFT 1252 LBS 16/20 PROPPANT IN WELLBORE- 10.6 PPA ON PERFS AT END OF JOB - FLUSHED WITH 57 BBLS 20# GEL - SLOWED RATE AT END OF FLUSH - FRAC 07/13/01 PREFORMED A FCO TO 6850' CTMD. RETURNS WERE 1-1 + ALL DAY. HAND OVER TO PRODUCTION ON THE FLY. [FCO] 07/14/01 PULLED FRAC SLEEVE @ 1792'RKB, TAGGED FILL @ 6811'RKB, PULLED 1" DV'S @ 2534',4157',5273'RKB. RAN GLV'S AT SAME DEPTHS, POST FRAC WORK COMPLETE. [GEV, TAG] Page 1 of I 7/30/01 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 2, 2000 P M C:LORBMFILM.DOC E E L E W A T E R IA L U N D ER THIS MARKER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing _ Alter casing Repair well Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska. Inc, Development X, 148'RKB 3. Address: Exploratory ~ 7. Unit or Property: P.O, Box 100360 Stratagrapic__ Anchorage. AK 99510-0360 Service ~, Kuparuk River Unit 4. Location of well at surface: 8. Well number: 114' FSL, 329' FWL, Sec 27, T11N, R8E, UM 2M-15 At top of productive interval: 9. Permit number/approval number: 1246' FSL, 1100' FEL, Sec 28, T11N, R8E, UM 91-33 Af effective depth: 10. APl number: 1369' FSL, 1256' FEL, Sec 28, T11N, R8E, UM 50-103-20154-00 At total depth: 1 !. Field/Pool: 1412' FSL, 1312' FEL, Sec 28, T11N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7020 feet Plugs (measured) None true vertical 6328 feet Effective Depfl measured 6910 feet Junk (measured) None true vertical 6244 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 225 Sx AS I 123' 123' Surface 2860' 9.625" 540 Sx PF E & 2901' 2901' 485 Sx Class G w/20 bbl PFC top job Production 6956' 7" 220 Sx Class G 6998' 6311' Liner Perforation Depth measured 6606'-6626', 6684'-6724' 0~/~ true vertical 6012'-6027', 6071'-6101' Tubing (size, grade, and measured depth) .. 3.5", 9.3 Ib/ft, J-55 @ 6534' Packers and SSSV (type and measured depth) Pkr: Otis HVT @ 6509'; SSSV: Camco TRDP-4A-RO @ 179~~5~'~\\ 13. Stimulation or cement squeeze summary Perforate 'C4' sand on 10/11/99. Intervals treated (measured) 6606'-6626' Treatment description including volumes used and final pressure Perforated using 2-1/2" HC gun w/DP charges @ 4 spt, final pressure was 1000 psi. 14. Represenfitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 570 283 905 1136 229 Both sands Subsequent to operation 778 720 1073 1028 229 15. Attachments 16. Status of well classification aS: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby, certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~------- Title: Production Engineering Supervisor Date r~,...,,.,.,,., -in AhA r3,,.~r~/.// :h ; / c~ ¢~ ..................... SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ELL SERVICE REPORT 2M-15(4-1)) WELL JOB SCOPE JOB NUMBER 2M-15 PERFORATIONS-E-LINE 1009991843.6 DATE 10/11/99 DAY 1 FIELD ESTIMATE DAILY WORK ADPERF C-4 SAND, 6606' TO 6626' OPERATION COMPLETE I SUCCESSFUL I KEY PERSON ('~ Yes O No ~ Yes O No SWS-STEPHENSON AFC# ICC# I DAILY COST ACCUM COST AK0034 230DS28ML $7,438 $8,893 Initial Tbg I Final Tbg I Initial IA I Fina~ IA I Initial CA I Final CA ITTL Size 800PSII 1000PSII 1450PSII 1450PSII 850PSII 850PSII 0.000 " UNIT NUMBER 2145 SUPERVISOR SCHUDEL / Signe~ I MinID : I Depth' I o.ooo" I OFT DALLY SUMMARY I ADPERF C-4 SANDS 6606'-6626'. TAG TD @ 6731' ELM. [Pelf] TIME 07:45 10:15 10:20 10:25 10:30 11:30 12:30 LOG ENTRY MOVE ON LOCATION, TGSM, DISCUSSED SAFE MEETING LOCATION IN EMERGENCY LOG TIE-IN PASSES. 1-27-92 CBL + CDR SHOT INTERVAL. CCL TO TOP SHOT 9.7'. TAG PBTD AT 6731' ELM. POOH START RIG DOWN COMPLETE RIG DOWN - MOVE TO 2M-21 SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $126.00 APC $150.00 $150.00 HALLIBURTON $0.00 $669.00 LITTLE RED $0.00 $660.00 SCHLUMBERGER $7,288.50 $7,288.50 TOTAL FIELD ESTIMATE $7,438.50 $8,893.50 STATE OF ALASKA AlaSKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate _ Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 114' FSL, 329' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1246' FSL, 1100' FEL, SEC 28, T11N, RSE, UM At effective depth 1369' FSL, 1256' FEL, SEC 28, T11N, R8E, UM At total depth 1412' FSL, 1312' FEL, SEC 28, T11N, RSE, UM 12. Present well condition summary Total Depth: measured true vertical 702O 6328 feet feet 6. Datum elevation (DF or KB) RKB 148 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-15 9. Permit number/approval number 91-33 10. APl number 5o-103-20154-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 6 91 0 true vertical 6244 feet feet Junk (measured) None Casing L e n g t h Structural Conductor 8 0' Surface 2 8 6 0' Intermediate Production 6 9 5 6' Liner Perforation depth: measured 6684'-6724' true vertical 6071'-6101' Size 16" 9 5/8" 7" Cemented Measured depth True vertical depth 225SxAS I 123' 540 Sx PF E & 2901' 485 Sx Class G w/20 bbls PFC Top Job 220 Sx Class G 6 9 9 8' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 AMB-EUE @ 6534' Packers and SSSV (type and measured depth) Pkr: Otis HVT @ 6509'; SSSV: Camco TRDP-4A-RO @ 1792' 13. Stimulation or cement squeeze summary 123' 2901' 6311' ORIGINAL 14. Fracture stimulate 'A' sands on 1/5/98. Intervals treated (measured) 6684'-6724' Treatment description including volumes used and final pressure Pumped 260.3 M lbs 20140 and 12/18 ceramic proppant into formation, fl:) was 6800 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 9 3 2 453 888 1355 283 Subsequent to operation 1 3 0 6 1 1 91 1504 1367 275 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas Suspended Service 7. I he,~y-c.~rtify that the foregoing is true and correct to the best of my knowledge. Signed(/'/''---..~,,.t/~/z~ ./.~~~~ Title Wells Superintendent Form /~4~4 tR(~v('06'~l'~/88'-~ SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ,4. WELL SERVICE REPORT ~' K1(2M-15(W4-6)) WELL JOB SCOPE JOB NUMBER 2M-15 FRAC, FRAC SUPPORT 1220970658.5 DATE DAILY WORK UNIT NUMBER 01/05/98 "A" SAND REFRAC DAY !'0PERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 (~) Yes ~-~ NoI (~) Yes (~) No DS-GALLEGOS C~Ar~Y FIELD AFC# CC# DALLY COST ACCUM COSTS,~.,'~,/S' n ESTIMATE KD1830 230DS28ML $157,285 $170,679 /,.~/-~, [. Initial TbCl Press Final Tbcl Press Initial Inner Ann Final Inner Ann J Initial Ouf~r Ann ] Final Outer Apr~ I 1550 PSI 1800 PSI 400 PSI 500 PSII J .7'~P650 PSI ,. SI DALLY SUMMARY "A" SAND REFRAC COMPLETED. SCREENED OUT. INJECTED 260299 LBS OF PROP IN THE FORMATION W/10.1# PPA OF #12/18 I THE PERF'S. MAXIMUM PRESSURE 6800 PSI AND F.G. (.77) UNABLE TO FREEZE PROTECT WELLBORE. TIME 07:00 11:30 13:00 13:50 15:15 17:45 LOG ENTRY MIRU DOWELL FRAC EQUIP, APC VAC TRUCKS, AND LRS HOT OIL TRUCK. HELD SAFETY MEETING (17 ON LOCATION). PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG AS REQUIRED. SET TRESSAVER AND PT'D HIGH PRESSURE LINE TO 9600 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 28 TO 15 BPM. SLURRY VOLUME PUMPED 401 BBLS. USED 6038 BBLS OF #20/40 PROP. MAXIMUM PRESSURE 5800 PSI AND ENDING PRESSURE 2100 PPSI. STEPPED DOWN THE RATE ATTHE END OF BREAKDOWN. S/D AND OBTAINED ISIP OF 1882 PSI W/F.G. @ (.75). MONITORED WHTP AND PULSED TO DETERMINE CLOSURE. CLOSURE TIME 15.6 MINS @ 1575 PSI. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SLURRY VOLUME PUMPED 124 BBLS. MAXIMUM PRESSURE 3600 PSI AND ENDING PRESSURE 2850 PSI. S/D AND OBTAINED ISIP OF 1992 PSI W/F.G. @ (.77). MONITORED WHTP AND STOOD-BY FOR CLOSURE. CLOSURE TIME 21 MINS @ 1662 PSI AND PAD = 350 BBLS. STOOD-BY WHILE DOWELL WORKING ON EQUIPMENT. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SCREENED OUT. SLURRY VOLUME PUMPED 1682 BBLS. MAXIMUM AND ENDING PRESSURE 6800 PSI. PUMPED 278301 LBS OF PROP (23016 LBS OF #20/40 & 255285 LBS OF #12/18). INJECTED 260299 LBS OF PROP IN THE FORMATION W/10.1# PPA OF #12/18 @ THE PERF'S. LEFT 18002 LBS OF PROP IN THE WELLBORE. UNABLE TO FEEZE PROTECT WELLBORE. 20:00 STARTED R/D. DEPRESSURED THE INNER CSG PRESSURE TO 500 PSI AND R/D LRS HOT OIL TRUCK. 21:30 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. RDMO DOWELL EQUIP. WELL SECURED AND NOTIFIED DSO OF STATUS. 22:30 SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $735.00 APC $5,900.00 $5,900.00 DIESEL $500.00 $500.00 DOWELL $145,385.00 $145,385.00 HALLIBURTON $0.00 $8,250.00 LI-FrLE RED $5,500.00 $9,910.00 TOTAL FIELD ESTIMATE $1 57,285.00 $1 70,680.00 STATE OF ALASKA ALASKA Oi- ,- ND GAS CONSERVATION CL, MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: x Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: x feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Mobil State #1 4. Location of well at surface Granite Point Leg #3, Conductor #9 8. Well number,._ 2384' FNL, 1368' FWK F/NW Corner Section 13, T10N, R12W, SM 11-13RD ~ I At top of productive interval 9. Permit number/approval number 11032' MD, 1166' FNL & 1169' FWL F/NW Corner Section 13, T10N, R12W 91-33 At effective depth 10. APl number 50- 733-20026-01 At total depth 11. Field/Pool 11560', 1140' FNL & 1329' FWL f/NW Corner Section 13, T10N, R12W, SM GP/Middle Kenai 12. Present well condition summary Total depth: measured 11566 feet Plugs (measured) true vertical 11413 feet Effective depth: measured 11516 feet Junk (measured) true vertical 11365 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 642' 18" Driven 684' 682' Surface 3976' 13-3/8" 4018' 3992' Intermediate Production 10014' 9-5/8" 1700 sxs 10055' 9957' Liner 1773' 7" 700 sxs 9787'-11560' 9692'-11407' Perforation depth: measured 11032';-11220'; 11245'-11377' true vertical 10903'-11082'; 11106'-11232' Tubing (size, grade, and measured depth) 2-7/8", 6.4#, L80 @ 10956' Packers and SSSV (type and measured depth) Otis "BWD" Perm Packer @ 10932', Camco SSSV @ ??? 13. Stimulation or cement squeeze summary Xylene Stimulation completed 3/10/97 Intervals treated (measured) 11032'-11377' Treatment description including volumes used and final pressure See attachment 0RII INAL 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1/8/97 172 98 9 600 100 Subsequent to operation 4/1/97 285 145 13 635 150 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: x Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: RE~. !V~D APR 1 5 997 AJask 0il & 6as Cons. Signed: Dale A. Haines ~~ 0~ r.,,... Title: Drilling Manager -~ ' Date: April 8, 1997 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE GRANITE POINT FIELD GP #11-13RD ADL 18761 Xylene Stimulation Day 1-5 (03/3-7/97) Slick line operations - Latch & pull 1-11 GLV's and set dummy valves; all test OK. Day 6 (03/8/97) Heat Xylene in tanks 1 & 2 to 65 deg F. Day 7&8 (03/9/10/97) Pumped ×ylene treatment - Pumped first 50 bbls ~ 1 BPM; pressure increased to 2,300 psi. Pumped next 200 bbls ~ .5 BPM pressure increased to 3,300 psi. Diverted W/gelled diesel salt. Switched to diesel displacement - Pumped 36 bbls ~ .5 BPM ~ 3,250 psi. Pumped next 29 bbls ~ .45 BPM, pressure increased to 3,250 psi. The ISIP = 3,120 psi and bled to 2,100 psi in 5 minutes (with pumps off) and then to 900 psi ~ 6 hrs. The annulus bled from 1,100 psi to 980 psi as job started & stabilized. Annulus pressure was monitored throughout the job and there was no communication. ARCO Alaska, Inc./'-". Post Office [. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 16, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION WELL ACTION Stimulate <'...',-:,~ 2M-18 Stimulate Stimulate ~i'. ? ~-::- 2M-19 Stimulate Stimulate ~.,.~_ ,, ¢ 2M-20 Stimulate ,~ ~-. 2M-21 Stimulate Stimulate ~ ~-~. ~ Stimulate q~_qct 2M-22 Stimulate Stimulate q.z_ 5~ 2M-24 Stimulate Stimulate oi,- o~ 2M-25 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (arch only) FTR051696 (w/o atch) AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate _ Repair well .... O t h e r 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 114' FSL, 329' FVVL, SEC 27, T11N, R8E, UM At top of productive interval 1246' FSL, 1100' FEL, SEC 28, T11N, R8E, UM At effective depth At total depth 1412' FSL, 1312' FEL, SEC 28, T11N, RSE, UM 12. Present well condition summary Total Depth: measured 7020' feet true vertical 6328' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 148' 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-15 9. Permit number/approval number PI 10. APl number 5o-103-20154 11, Field/Pool Kuparuk River Oil Pool feet .... Effective depth: measured 6 91 0' feet true vertical 6244' feet Junk (measured) Casing Length Size Structural Conductor 1 2 3' 1 6" Surface 2 901 ' 9 5/8" Intermediate Production 6998' 7" Liner Perforation depth: measured 6684' - 6724' true vertical 6071' - 6101' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 AMB-EUE, @ 6534' Packers and SSSV (type and measured depth) Cemented 225 SX ASI 540 SX PF E 485 SX CLASS G 220 SX CLASS G Measured depth True vertical depth RECEIVED MAY 20 1994 0ii & Gas Cons. Commission Anchorage CAMCO TRDP-4A-RO @ 1792', OTIS PBR @6493', OTIS HVT PKR @ 6509' 13. Stimulation or cement squeeze summary Intervals treated (measured) 6684' - 6724' Treatment description including volumes used and final pressure See Attached Summary 14. Prior to well operation 4/20/92 Subsequent to operation 6/10/92 Representative Daily Average Production or Injection D.ata OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 302 .1 37 0 1 700 3385 3341 0 1600 Tubing Pressure 186 185 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~~' ~~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 2M-!5 04/28/92 GELLED SEAWATER FRAC W/DS YF140D. PUMPED 235 BBL BREAKDOWN @ 25 BPM. LAST WHTP=3315 PSI, ISIP=1479 PSI, FG=.69 PSI/FT, EXCESS FRIC=693 PSI. PUMPED 1100 BBL PAD @ 25 BPM, LAST WHTP=3319 PSI. PUMPED 227.1MLBS 12/18 CARBOLITE IN 2 TO 12 PPA STAGES, SCREENED OUT 58 BBLS INTO 12 PPA STAGE @ A MAX WHTP OF 7200 PSI. TOT PROPPANT: DESIGNED 301.1MLBS, IN FORM 206.0 MLBS W/ll.8 PPA @ PERF$. TOT FLUIDS: WATER 1948 BBLS, DSL (FLA) 60 BBLS. R£C£1¥ D MAY 20 '~99~ Oil & Gas Cons. Commissio~ Anchorage PERMIT AOGCC Individual Well Geological Materials Inventory DATA T DATA_PLUS Page: 1 Date: 01/19/94 SCALE DATE_RECVD 91-033 91-033 91-033 91-033 91-033 91-033 91-033 91-033 CDN CDR 407 DAILY WELL OP =164 CBT '['~(~ 5200-6862 (COMBO C&C) ~ 5200-6900 USIT L 2900-7021, LWD 2&5 L 2900-7021, LWD 2&5 R COMP DATE: 02/26/92 R 12/09/91-02/27/92 R o- o o d'Z T 2900-6985, OH-CDR/CDN 5 5 12/30/91 12/30/91 03/20/92 03/20/92 03/20/92 01/27/92 02/11/92 02/11/92 yes ~ received? Are dry ditch samples required? Was the well cored? yes~alysis & description received.? Are well tests required?~eived? y~ Well is in compliance IniYi~l ye~ Comments ARCO Alaska, Inc. Date: April 17, 1992 Transmittal #: 8407 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO- 1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2M-1 5 Sub-Surface Directional~ 1 -28-92 921 02 Survey Receipt Acknowledged- ~-- Date: ........... D&M State of Alaska (2 copies) RECEIVED APR 2 1 199~ Alaska Oil & Gas Cons. Commission Anchorage "' '-'", -" ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ,--~¥.~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL 1~1 GAS r--'l SUSPENDED [~ ABANDONED D SERVICE r-'"l 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 91-33 3 Address 8 APl Number P.O. Box 100360, Ancho rage, AK 99510-0360 50-103 -20154 4 Location of well at surface !~ ~ :,:7~;':; :1 7: ~' ........ ~, 9 Unit or Lease Name 114' FSL, 329' FWL, SEC 27, T11N, R8E, UM ~ ~-.;~-~?; ~ 1 ~"~ i KUPARUK RIVER At Top Producing ,nterva, ~ ~,,~-~o ~ ~D' i- ' ~.~.-~,~.z_-~ ~. ~~ 10 Well Number At Total Depth ,~;~~ ! 11 Field and Pool 1412' ESL, 1312' EEL SEC 28, T11 N, R8E, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL I RKB 148', PAD 106' GL ADL 25586, ALK 2672 12 Date Spudded 13 Date T.D. Reached !14 Date Comp., Suep. or Aband. 15 Water Depth, if offshore 16 No. of Completions 12/09/91. 12/12/91. 02/26/92. N A feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost .7020' MD, 6328' TVD 6910' MD, 6244' TVD YES ~ NO r-] 1792, feet MD 1400' APPROX 22 Type Electric or Other Logs Run CDR,CDN,GR,USIT, CBT,GYRO 23 CASING, LINER AND CEMENTING RECORD J SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 123' 24" 225 SX ASl 9-5/8" 36# J-55 SURF 2901' 12-1/4" 540 SX PF E, 485 SX CLASS G 20 BBLS PFC TOP JOB 7" 26# J-55 SURF 6998' 8-1/2" 220 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 6534' 6509' 6684'-6724' W/4-1/2" CSG GUN @ 4 SPF MD 6071'-6101' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 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 I TEST PERIOD ,,~ Flow Tubing (~asing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE =F 28 CORE DATA[~ E F I:; ! ~1 ~ I J Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips, r~, 1_ ~ i... ! · m,, ,.,.- MAR~ 0 1992 Alaska 0il & Gas Cons. C0mm~sm0~--- Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC IVlAI:~ERS FORMATION TESTS NNVlE Include interval tested, pressure data, all fluids recoverd and gravity, lVlEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 6604' 6010' NA KUPARUK C Be'I-rOM 6631' 6031' KUPARUK A TOP 6634' 6033' KUPARUK A BO'FrOM 6806' 6164' 31. LIST OF ATrACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ...... v~_,~_'____~__~___~ Title AREA DRILLI~IGENG~EER 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 2l: 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 2~;~. Method. of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas InjeCts°n, ShULin, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT AP P ROVA L: 2M-15 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25586 ALK 2672 50-103-20154 91-33 DAILY OPERATIONS ACCEPT: 12/08/91 SPUD: 12/09/91 RELEASE: 12/14/91 OPERATION: DRILLING RIG: POOL 7 AFE: AK5784 WI: 55.252072 PAGE: 1 12/09/91 (1) TD: 920' ( 920) SUPV: D S S 12/10/91 (2) TD: 2915' (1995) SUPV:DSS 12/11/91 (3) TD: 2915'( SUPV:DSS o) 12/12/91 ( 4) TD: 5400' (2485) SUPV:KKL 12/13/91 (5) TD: 7020' (1620) SUPV:KKL 12/14/91 ( 6) TD: 7020'( SUPV:KKL o) 12/15/91 (7) TD: 7020' ( SUPV: KKL o) DRILLING MW: 8.9 VIS: 63 MOVE RIG FROM 2M-11 TO 2M-15. NU DIVERTER AND MU BHA. DRILL FROM 96' TO 920. DAILY:S37,683 CUM:$37,683 ETD:SO EFC:$1,227,683 CIRC AND COND FOR CSG 9-5/8"8 2900' MW: 9.3 VIS: 47 DRILL FROM 920' TO 2915'. CBU AND SHORT TRIP TO HWDP. PULLED TIGHT IN SEVERAL SPOTS. RIH AND WASH AND REAM TO TD. POH AND PULLED TIGHT. RIH TO WASH AND REAM TO TD. DAILY:S51,634 CUM:$89,317 ETD:SO EFC:$1,279,317 MU BHA 9-5/8"8 2900' MW: 9.6 VIS: 47 CBU FOR CSG. POH AND RUN 9-5/8" CASING AND CMT SAME. RECIPRICATED WHILE PUMPING CMT AND 2/3 OF DISPLACEMENT. FULL RETURNS. NO CMT TO SURF. PUMPED TOP JOB. ND DIVERTER, NU BOPE AND TEST SAME. DAILY:S130,114 CUM:$219,431 ETD:SO EFC:$1,409,431 DRILLING 9-5/8"8 2900' MW: 9.1 VIS: 37 MU BHA AND TIH. TEST CSG TO 2000 PSI. DRILL FC, FS AND 10' NEW HOLE. PERFORM LOT TO 12.5 PPG EMW. DRILL FROM 2925' TO 5400' DAILY:S102,824 CUM:$322,255 ETD:SO EFC:$1,512,255 DRILLING ~ 9-5/8"8 2900' MW:10.3 VIS: 37 DRILL FROM 5400' TO 7020' DAILY:S70,798 CUM:$393,053 ETD:S0 EFC: $1,583,053 SET SLIPS ON 7" 7"8 6998' MW:10.3 VIS: 0 SHORT TRIP FOR CSG. POOH AND RUN CSG AND CMT CSG. RECIPRICATED THROUGHOUT. FULL RETURNS. DAILY:S176,458 CUM:$569,511 ETD:SO EFC:$1,759,511 RELEASE RIG 7"8 6998' MW:10.3 VIS: 0 SET SLIPS ON 7" AND NU TREE. LDDP IN ORDER TO PICK UP NEW DP ON NEXT WELL. RELEASE RIG 14:00 HRS 12/14/91. DAILY:S117,547 CUM:$687,058 ETD:SO EFC:$1,877,058 SIGNATURE: ~ ~ DRILLING ~RINTEND~ RECEIVED t AR 0 Alaska Oil & Gas Cons. oommisSio~ Anchorage ARCO ALASKA INC. WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 2M-15 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25586 ALK 2672 50-103-20154 91-33 DAILY OPERATIONS PAGE: 1 ACCEPT: 02/25/92 SPUD: RELEASE: 02/26/92 OPERATION: COMPLETION RIG: NORDIC AFE: AK5784 WI: 55.252072 02/26/92 (8) TD: 7020 PB: 6910 SUPV:DB/SB 02/27/92 (9) TD: 7020 PB: 6910 SUPV:DB/SB RD WIRELINE 7"@ 6998' MW:10.3 NaC1/Br MOVE RIG F/2M-13 TO 2M-15,ACCEPT RIG AT 2130 HRS 2-25-92,ND TREE,NU LOPE,TEST SAME TO 3000 PSI,OK, RU SWS,TEST LUBRICATOR TO 1500 PSI,RIH PERF F/6684-6724',4 SPF, 180 DEF PHS,ORIENTED POH, RD SWS DAILY:S25,115 CUM:$712,173 ETD:SO EFC:$1,902,173 RIG RELEASED 7"@ 6998' MW:10.3 NaC1/Br CONT RD SWS,RU AND RIH W/3-1/2" SINGLE COMP AS PER PROCEDURE MU SSSV/C-LINE, TEST SAME TO 5K, OK, CONT RIH,MU HGR/C-LINE TEST C-LINE TO 5K, OK, LAND HGR, RILDS, PRESS TBG F500-3000 PSI IN 500 PSI INCREMENTS TO SET OTIS PACKER, BLEED TO 1800 BOLDS PU AND SHEAR PBR AT 90K#,RELAND TBG, RILDS,TEST SSSV W/500 PSI DIFF,OK, TEST ANN TO 2500 PSI F/15 MIN, OK, PRESS TBG TO 3500 PSI AND SHEAR SOS,SET BPV, ND BOPE,NU TREE,PULL BPV, SET TEST PLUG, TEST TREE TO 250/5000 PSI,OK, TEST PACK- OFF TO 5000 PSI,OK, PULL TEST PLUG, OPEN SSSV, DISPLACE ANN W/12 BBLS DIESEL, PUMP 4 BBLS DIESEL DN TBG, RD LINES,SECURE WELL SITP=300,SICP=0,SIAP=550,RELEASE RIG AT 2000 HRS 2-26-92 MOVE TO 2M-18 DAILY:S157,570 CUM:$869,743 ETD:SO EFC:$2,059,743 SIGNATURE: ~ ~ DRILLING S~R'INTENDEN~ DATE: ORIGINA~ SUB ' SURFACE DIRECTIONAL r-~l UIDANCE r~l ONTINUOUS Ff~ OOL SURVEY RECEIVED Company ARCO ALASKA, INC. MAR ~ 0 199~ Alaska 0il & Gas Cons. CommissiO~ Anchorage Well Name 2M-15 (114'FSL,329'FWL,SEC 27,T11N,R8E,UM) Field/Location KUPARUK RIVER, NORTH SLOPE, ALASKA Job Reference No. 92102 Loc~ged By: D, WAI~NEI~/M. CHENEVEY Date 28-JAN- 1992 Computed By: R. KRUWELL I SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 2M - 15 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 28-JAN-1992 METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: ENGINEER: D. WARNER TANGENTIAL- Averaged deviation and azimuth LINEAR HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 53 DEG 29 MIN WEST COMPUTATION DATE: 4-MAR-92 PAGE 1 ARCO ALASKA, INC. 2M - 15 KUPARUK R[VER NORTH SLOPE, ALASKA DATE OF SURVEY: 28-JAN-1992 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE NEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORT. H/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 0 O0 100 O0 200 O0 300 O0 4OO O0 500 O0 600 O0 700 O0 800 00 900 O0 0 O0 -147.00 0 0 100 200 0 10 300 0 11 400 0 12 500 0 14 600 0 18 699 0 21 799 0 21 899 0 30 N 0 0 E 0.00 O0 -47.00 0 16 N 68 3 E -0.17 O0 53.00 S 55 8 E -0.21 O0 153.00 S 82 41 E -0.48 O0 253.00 N 85 15 E -0.75 O0 . 353.00 N 76 50 E -1.01 O0 453.00 N 70 3 E -1.28 99 552.99 N 61 29 E -1.57 99 652.99 N 55 51 E -1.81 99 752.99 N 61 19 E -2.09 0.00 1 07 0 03 0 O0 0 O0 0 O0 0 O5 0 O0 0 O0 0 O0 0.00 N 0.03 S ' 0.06 N 0.03 S 0.04 S 0.02 N 0.14 N 0.39 N 0.71 N 1.11 N 0.00 E 0.19 E 0.30 E 0.57 E 0 90 E 1 27 E 1 70 E 2 25 E 2 78 E 3 42 E 0 O0 N 0 0 E 19 S 80 34 E 31 N 79 11E 57 S 86 43 E 90 5 87 42 E 27 N 89 15 E 7O N 85 16 E 28 N 8O 6 E 87 N 75 39 E 6C N 72 1 E 1000.00 999.99 852.99 0 32 1100.00 1099.98 952.98 0 29 1200.00 1199.98 1052.98 0 23 1300.00 1299.98 1152.98 0 15 1400.00 1399.98 1252.98 0 12 1500.00 1499.98 1352.98 0 12 1600.00 1599.98 1452.98 0 17 1700.00 1699,97 1552.97 0 23 1800.00 1799.97 1652.97 0 10 1900.00 1899.97 1752.97 0 7 N 68 46 E -2.50 0.05 1.49 N N 75 34 E -3.04 0.20 1.78 N N 83 38 E -3.57 0.21 1.91 N N 75 0 E -3.94 0.00 2.01 N N 62 39 E -4.15 0.00 2.17 N N 65 50 E -4.30 0.10 2.33 N S 82 1 E -4.53 0.60 2.40 N S 58 38 E -5.22 O. O0 2. 10 N S 74 46 E -5.63 0.00 1 .93 N S 75 41 E -5.86 0.00 1.88 N 4.22 E 5.09 E 5.85 E 6.39 E 6.77 E 7.08 E 7.41 E 8.05 E 8.43 E 8.69 E 4 47 N 70 29 E 40 N 70 47 E 15 N 71 58 E 70 N 72 31E 11 N 72 15 E 46 N 71 45 E 79 N 72 2 E 31 N 75 22 E 64 N 77 7 E 89 N 77 48 E 2000.00 1999.97 1852 97 2100.00 2099.97 1952 2200.00 2199.97 2052 2300.00 2299 97 2152 2400.00 2399 97 2252 2500.00 2499 97 2352 2600.00 2599 97 2452 2700.00 2699 97 2552 2800.00 2799 97 2652 2900.00 2899 97 2752 0 0 ,97 0 3 97 0 2 97 0 7 97 0 12 97 0 17 97 0 14 97 0 14 97 0 13 97 0 18 N 61 16 E S 12 55 E S 4 4 E S 33 52 W S 33 22 W 522 1W S 0 51W S 031 E S 3 23 E S 2644 E -5.95 -5.97 -5.99 -6.02 -6 03 -6 09 -6 27 -6 50 -6 73 -7 04 0.00 0.00 0.00 0.00 0.00 0.04 0.11 0.00 0.00 0.22 1.84 N 1.83 N 1.79 N 1 .71 N 1.47 N 1.06 N 0.63 N 0.23 N 0.13 S 0.52 S 8.78 E 8.78 E 8 8.79 E 8 8.75 E 8 8.59 E 8 B.37 E 8 8.28 E 8 8.26 E 8 8.28 E 8 8.38 E 8 8 97 N 78 8 E 97 N 78 13 E 97 N 78 28 E 92 N 78 57 E 72 N 80 17 E 43 N 82 48 E 30 N 85 38 E 26 N 88 23 E 28 S 89 4 E 39 S 86 27 E 3000.00 2999.96 2852.96 0 33 3100.00 3099.96 2952.96 0 30 3200.00 3199.79 3052.79 4 35 3300.00 3299.09 3152 09 8 30 3400.00 3397.60 3250 60 11 15 3500.00 3495.23 3348 23 13 55 3600.00 3591.63 3444 63 16 48 3700.00 3686.80 3539 80 18 46 3800.00 3780.98 3633 98 20 36 3900,00 3873.66 3726 66 23 39 S 51 52 E N 10 7 W N 53 16 W N 52 4 W N 52 53 W N 53 24 W N 53 3 W N 53 11W N 52 13 W N 51 22W -7.79 -8.49 -3.19 8.52 25.64 47.26 73.80 104.46 138.06 175.57 0.12 5.19 3.90 5.61 4.37 3.53 2.95 1 .56 1 .34 3.36 1.08 S 1.44 5 1.73 N 8.81 N 19.35 N 32.25 N 48.17 N 66.57 N 8.89 E 8.96 S 83 6 E 9.50 E 9.61 S 81 23 E 5.25 E 5.53 N 71 45 E 4.07 W 9.71 N 24 47 W 17.57 W 26.14 N 42 14 W 34.92 W 47.53 N 47 17 W 56. 16 W 73.99 N 49 23 W 80.68 W 104.60 N 50 28 W 86.90 N 107.44 W 138.19 N 51 2 W 110.14 N 136.90 W 175.71 N 51 11 W COMPUTATION DATE: 4-MAR-92 PAGE 2 ARCO ALASKA, INC. 2M - 15 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 28-JAN-1992 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR 'COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 4000.00 3963 83 3816.83 27 43 N 51 32 W 4100.00 4051 22 3904 22 30 16 N 50 32 W 4200.00 4136 44 3989 4300.00 4219 33 4072 4400.00 4300 20 4t53 4500.00 4379 B6 4232 4600.00 4459 26 4312 4700.00 4538,67 4391 4800.00 4618.08 4471 4900.00 4697.35 4550 44 32 48 N 50 23 W 33 35 4 N 51 18 W 20 36 50 N 51 24 W 86 37 24 N 51 9 W 26 37 26 N 50 55 W 67 37 24 N 50 55 W O8 37 31 N 51 0 W 35 37 38 N 51 27 W 218 7O 267 25 319 48 375 33 434 11 494 52 555 26 615 96 676 69 737 6O 2 25 2 33 2 25 1 94 I 35 0 19 0 11 0 10 0 25 0 39 137 08 N 170 63 W 218.87 N 51 13 W 167 201 236 273 310 349 387 425 463 69 N 208 37 W 267.47 N 51 10 W 03 N 248 67 W 319.76 N 51 3 W 34 N 292 02 W 375.68 N 51 1 W O0 N 338 02 W 434.49 N 51 4 W 83 N 385 18 W 494.95 N 51 6 W 07 N 432 43 W 555.74 N 51 5 W 40 N 479 59 W 616.51 N 51 4 W 71 N 526.79 W 677.30 N 51 3 W 89 N 574.30 W 738.25 N 51 4 W 5000.00 4776.34 4629.34 37 59 5100.00 4855.18 4708.18 37 56 5200.00 4934.23 4787.23 37 28 5300.00 5013.91 4866.91 37 2 5400.00 5093.63 4946 63 37 14 5500.00 5173.02 5026 02 38 10 5600,00 5250.13 5103 13 40 26 5700.00 5326.18 5179 18 40 31 5800.00 5402.23 5255 23 40 27 5900.00 5478.27 5331 27 40 36 N 51 43 W 798.89 N 52 19 W 860.38 N 52 32 W 921.62 N 52 54 W 982.04 N 53 6 W 1042.41 N 52 26 W 1103.21 N 51 14 W 1166.83 N 51 16 W 1231.71 N 51 18 W 1296.60 N 51 18 W 1361.49 0.23 0 35 0 96 031 0 28 3 63 0 29 0 O0 0 16 0 3O 502.00 N 622.35 W 799 58 N 51 7 W 539.87 N 670.82 W 861 577.20 N 719.38 W 922 613.80 N 767.45 W 982 650.14 N 815.66 W 1043 686.77 N 864,20 W 1103 726.29 N 914.09 W 1167 766,92 N 964.74 W 1232 807.54 N 1015.40 W 1297 848.18 N 1066.06 W 1362 08 N 51 10 W 31 N 51 15 W 72 N 51 21W 07 N 51 27 W 85 N 51 32 W 5O N 51 32 W 43 N 51 31W 37 N 51 30 W 31 N 51 3O W 6000 O0 5554.17 5407 17 40 42 6100 6200 63O0 64OO 6500 6600 670O 6800 6900 O0 5629.86 5482 O0 5705.41 5558 O0 5780.76 5633 O0 5856.22 5709 O0 5931.79 5784 O0 6007.40 5860 O0 6083.26 5936 O0 6159.46 6012 O0 6235.90 6088 86 40 53 41 41 76 41 6 22 40 54 79 40 55 40 40'51 26 4O 29 46 40 16 90 40 1 N 51 26 W 1426.56 N 51 40 W 1491.87 N 51 58 W 1557.37 N 52 8 W 1623.09 N 52 21 W 1688.68 N 52 16 W 1754.17 N 51 54 W 1819.60 N 52 4 W 1884.73 N 52 1 W 1949.47 N 51 49 W 2013.91 0 25 0 28 0 44 0 25 0 12 0 14 0 25 031 012 0.00 888.85 N 1116.91 W 1427.43 N 51 29 W 929.50 N 1168.08 W 1492.77 N 51 29 W 970.02 N 1219.57 W 1558.29 N 51 30 W 1010.46 N 1271.41 W 1624,04 N 51 31 W 1050.59 N 1323.30 W 1689.64 N 51 33 W 1090.64 N 1375.13 W 1755.13 N 51 35 W 1130.87 N 1426.76 W 1820.58 N 51 36 W 1170.99 N 1478.10 W 1885.73 N 51 37 W 1210.80 N 1529.17 W 1950.49 N 51 38 W 1250.61 N 1579.87 W 2014.95 N 51 38 W 7000.00 6312.49 6165.49 40 1 N 51 49 W 2078.17 0.00 1290.36 N 1630.41 W 2079.25 N 51 38 W 7020.00 6327.81 6180.81 40 1 N 51 49 W 2091.03 0.00 1298,31 N 1640.52 W 2092.10 N 51 39 W COMPUTATION DATE: 4-MAR-92 PAGE 3 ARCO ALASKA, INC. 2M - 15 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 28-JAN-1992 KELLY BUSHING ELEVATION: 147.00 FY ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVZAT~ON.~AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 'DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4OOO 5000 6000 7000 7020 0.00 -147.00 O 0 N 0 0 E 0.00 O0 999.99 852.99 0 32 N 68 46 E -2.50 O0 1999.97 1852.97 0 0 N 61 16 E -5.95 O0 2999.96 2852,96 0 33 S 51 52 E -7.79 O0 3963.83 3816.83 27 43 N 51 32 W 218.70 O0 4776.34 4629.34 37 59 N 51 43 W 798.89 O0 5554.17 5407,17 40 42 N 51 26 W 1426.56 O0 6312.49 6165.49 40 I N 51 49 W 2078.17 O0 6327.81 6180.81 40 1 N 51 49 W 2091.03 0.00 0.05 1 0.00 1 0 12 1 2 25 137 0 23 5O2 0 25 888 0 O0 1290 0 O0 1298 0 O0 N 0 O0 E 0.00 N 0 0 E 49 N 4 22 E 4.47 N 70 29 E 84 N 8 78 E 8 97 N 78 B E 08 S 8 89 E 8 96 S 83 6 E 08 N 170 63 W 218 87 N 51 13 W O0 N 622 35 W 799 58 N 51 7 W 85 N 1116.91 W 1427 43 N 51 29 W 36 N 1630.41 W 2079 25 N 51 38 W 31 N 1640.52 W 2092 10 N 51 39 W COMPUTATION DATE: 4-MAR-92 PAGE 4 ARCO ALASKA, INC. 2M - 15 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 28-JAN-1992 KELLY BUSHING ELEVATION: 147.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA 'COURSE ~EASURED VERTICAL VERTICAL DEVIATION .AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG M[N 0.00 0 O0 -147.00 0 0 N 0 0 E O0 O0 O0 O0 0.00 0 6 N 57 36 W 100.00 0 9 S 71 43 E 200.00 0 11 S 89 29 E 300.00 0 13 N 83 31 E 400.00 0 15 N 75 15 E 500.00 0 21 N 66 3 E 600.00 0 22 N 59 48 E 700.00 0 26 N 57 21 E BO0.O0 0 30 N 62 59 E 147.00 147 247.00 247 347.00 347 447.00 447 547.00 547 647.00 647 747.01 747 847.01 847 947.01 O0 O0 O0 O0 947.00 1047.02 1047.00 900.00 0 32 N 71 57 E ENGINEER= D. WARNER 1147.02 1147.00 1000.00 0 27 N 80 53 E 1247.02 1247.00 1100.00 0 19 N 77 51 E 1347,02 1347.00 1200,00 0 16 N 66 32 E 1447.02 1447.00 1300.00 0 12 N 59 27 E 1547,02 1547.00 t400,00 0 10 N 74 52 E 1647.03 1647.00 1500.00 0 26 S 62 0 E 1747.03 1747.00 1600.00 0 13 S 68 2 E 1847.03 1847.00 1700.00 0 10 S 81 43 E 1947.03 1947.00 1800.00 0 3 S 67 13 E . 2047.03 2047.00 1900.00 0 0 N 29 51 E 2147.03 2147.00 2000.00 0 0 S 27 55 E 2247.03 2247 O0 2100.00 0 2 S 11 53 W 2347.03 2347 O0 2200.00 0 10 S 34 39 W 2447.03 2447 O0 2300.00 0 17 S 29 29 W 2547,03 2547 O0 2400.00 0 15 S 12 1 W 2647,03 2647 O0 2500.00 0 14 S 4 8 W 2747.03 2747 O0 2600.00 0 12 S 2 51 E 2847.03 2847 O0 2700.00 0 12 S 12 26 E 2947.03 2947 O0 2800.00 0 27 S 42 14 E 3047.04 3047.00 2900.00 0 33 S 55 14 E 3147.07 3147.00 3000.00 3 28 N 54 3 W 3247.45 3247.00 3100.00 6 54 N 53 0 W 3348.55 3347.00 3200.00 9 48 N 51 41 W 3450.48 3447.00 3300.00 12 20 N 53 32 W 3553.52 3547.00 3400.00 15 32 N 53 3 W 3658.05 3647.00 3500.00 18 1 N 53 9 W 3763.79 3747.00 3600,00 19 55 N 52 41 W 3870.99 3847.00 3700.00 22 39 N 51 33 W 3981.12 3947.00 3800.00 26 57 N 51 28 W VERTICAL DOGLEG .RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION $EVERITY.~ORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 0,00 N 0.00 E 0.00 N 0 0 E -0.16 0,80 0.10 N 0.27 E 0.29 N 69 45 E -0.34 0.00 0.00 N 0.43 E 0,43 N 89 34 E -0.60 0.00 0.04 S 0.72 E 0.72 S 86 41 E -0.87 0.00 0.02 S 1.07 E 1.07 S 89 0 E -1.14 0.04 . 0.07 N 1.47 E 1.47 N 87 22 E -1.42 0.00 0.24 N 1.95 E 1.97 N 82 51 E -1.69 0.00 0,53 N 2.50 E 2.56 N 77 56 E -1.92 0.05 0.89 N 3.05 E 3.18 N 73 41 E -2.26 0.02 1.30 N 3.78 E 4.00 N 70 59 E -2 75 -3 29 -3 77 -4i 05 -4 22 -4 38 -4 82 -5 47 -5 75 -5 94 0.00 1.64 N 0.00 1.85 N 0.21 1.95 N 0.21 2.08 N 0.00 2.25 N 0.00 2.38 N O, 13 2.29 N 0,40 1.97 N O. 15 1.90 N O. 13 1 .85 N 4.63 E 5 47 E 6 13 E 6 58 E 6 92 E 7 22 E 7 70 E 8 27 E 8 56 E 8.76 E 4.91 N 70 31 E 5.77 N 71 19 E 6.44 N 72 24 E 6.90 N 72 29 E 7.27 N 71 59 E 7.60 N 71 44 E 8.03 N 73 24 E 8.50 N 76 34 E 8.77 N 77 29 E 8.95 N 78 4 E -5.95 0.00 1.84 N -5.98 0.00 1.81 N -6.01 0.00 1.77 N -6.02 0.00 1.61 N -6.05 0.13 1.30 N -6, 17 0.00 0.85 N -6,38 0.00 0.44 N -6.61 0.00 0.06 N -6.85 0.04 0.31 5 -7.33 0.24 0.76 S 8 78 E 8 78 E 8 79 E 8 69 E 8 49 E 8 30 E 8 27 E 8 27 E 8.29 E 8.55 E B. 97 N 78 8 E 8.97 N 78 20 E 8.96 N 78 37 E 8.83 N 79 29 E 8.59 N 81 17 E B. 35 N 84 9 E 8.28 N 86 58 E 8.27 N 89 37 E 8.30 S 87 53 E 8.59 S 84 54 E -8.25 -6.89 1.59 16.38 36.02 60.81 91.22 125.55 164.13 210.16 0.20 1.35 S 3.73 0.47 S 3.22 4.61N 0.89 13.68 N 2.15 25.56 N 2.41 40.36 N 1.94 58.63 N 2.38 79.28 N 3.81 3.97 9.26 E 9.36 S 81 42 E 8.23 E 8.25 S 86 46 E 1.43 E 4.82 N 17 17 E 10.25 W 17.10 N 36 51 W 25.89 W 36.38 N 45 22 W 45.78 W 61.04 N 48 36 W 70.09 W 91.38 N 50 5 W 97.52 W 125.68 N 50 53 W 103.00 N 127.95 W 164.26 N 51 10 W 131.76 N 163.94 W 210.33 N 51 13 W COMPUTATION DATE: 4-MAR-92 PAGE 5 ARCO ALASKA, INC. 2M - 15 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY= 28-JAN-1992 KELLY BUSHING ELEVATION= 147.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE NEASURED VERTICAL VERTICAL DEVIATION .AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. ~ZIMUTH DEPTH DEPTH .DEPTH DEG MIN DEG MIN FEET DEG/100 FEET FEET FEET DEG 4095 11 4047.00 3900.00 30 9 N 50 33 W 264.79 4212 4333 4458 4584 4710 4836 4962 5089 5216 2.12 60 4147.00 4000.00 33 6 N 50 28 W 326.34 2.37 94 4247.00 4100.00 35 47 N 51 31 W 394.97 2.64 67 4347.00 4200.00 37 18 N 51 15 W 469.47 0.37 56 4447.00 4300.00 37 27 N 50 56 W 545.88 0.15 48 4547.00 4400.00 37 24 N 50 55 W 622,32 0.08 47 4647.00 4500.00 37 33 N 51 9 W 698.88 0.36 80 4747.00 4600.00 37 54 N 51 38 W 776.03 0.33 63 4847.00 4700.00 37 56 N 52 16 W 854.01 0.35 07 4947,00 4800.00 37 20 N 52 35 W 931.37 0.89 166.12 N 206.47 W 265.00 N 51 11 W 205.40 N 253 97 W 326.63 N 51 2 W 248.61 N 307 38 W 395.33 N 51 2 W 295.11 N 365 64 W 469.87 N 51 6 W 343.15 N 425 15 W 546.36 N 51 5 W 391.41 N 484 53 W 622.88 N 51 4 W 439.66 N 544 07 W 699.51 N 51 3 W 487.81' N 604.41 W 776.71 N 51 6 W 535.97 N 665.78 W 854.71 N 51 10 ~ 583.12 N 727.13 W 932.07 N 51 16 ~ 5341.47 5047.00 4900.00 37 7 N 53 0 W 1007.04 5467.06 5147.00 5000.00 37 24 N 53 0 W 1083.01 5595.89 5247.00 5100 O0 40 25 N 51 14 W 1164.17 5727.38 5347.00 5200 O0 40 30 N 51 17 W 1249.48 5858.84 5447.00 5300 O0 40 30 N 51 16 W 1334.75 5990.54 5547.00 5400 O0 40 41 N 51 25 W 1420.40 6122.67 5647.00 5500 O0 40 54 N 51 43 W 1506.71 6255.19 5747.00 5600 O0 41 9 N 52 3 W 1593.63 6387.79 5847.00 5700 O0 40 55 N 52 21 W 1680.69 6520.12 5947.00 5800 O0 40 54 N 52 13 W 1767.34 0.28 1 .66 0.39 0.05 0.45 0.22 0.27 0.24 628.87 N 787.40 W 1007.71 N 51 23 W 674.52 N 848.13 W 1083.65 N 51 30 W 724.63 N 912.02 W 1164.85 N 51 32 W 778.05 N 978.61 W 1250.22 N 51 31 W 831.44 N 1045.19 W 1335.55 N 51 30 W 885.00 N 1112.09 W 1421.26 N 51 29 W 938.70 N 1179.72 W 1507.61 N 51 29 W 992.35 N 1248.15 W 1594,57 N 51 31 W 0.16 1045.71 N 1316.97 W 1681.64 N 51 33 W 0.33 1098.70 N 1385.56 W 1768.31 N 51 35 W 6652.27 6047.00 5900.00 40 39 N 52 0 W 1853.70 6783.67 6147.00 6000.00 40 17 N 52 3 W 1938.92 6914.49 6247.00 6100.00 40 1 N 51 49 W 2023.22 7020.00 6327.81 6180.81 40 1 N 51 49 W 2091.03 0.43 1151.89 N 1453.62 W 1854.69 N 51 36 W 0.23 1204.31 N 1520.85 W 1939.94 N 51 38 W 0.00 1256.37 N 1587.20 W 2024.27 N 51 38 W 0.00 1298.31 N 1640.52 W 2092.10 N 51 39 W COMPUTATION DATE: 4-MAR-92 PAGE 6 ARCO ALASKA, INC. 2M - 15 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASING TD DATE OF SURVEY: 28-JAN-1992 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 114' FSL & 329' FWL, SEC27 TllN ~8E UM MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 2901 O0 6604 O0 6631 O0 6634 O0 6806 O0 6872 19 6910 O0 6998 O0 7020.00 2900 97 6010 43 6030 87 6033 14 6164 03 6214 60 6243 56 6310 96 6327.81 2753.97 5863.43 5883,87 5886.14 6017,03 6067,60 6096.56 6163.96 6180,81 0.53 S 8.38 E 1132.48 N 1428.82 W 1143.35 N 1442.70 W 1144.56 N 1444.24 W 1213.19 N 1532.23 W 1239.53 N 1565.85 W 1254.58 N 1584.93 W 1289.57 N 1629.40 W 1298.31 N 1640.52 W COMPUTATION DATE: 4-MAR-92 PAGE 7 ARCO ALASKA, INC. 2M - 15 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASING TD DATE OF SURVEY: 28-JAN-1992 KELLY BUSHING ELEVATION: 147.00 FT ENGINEER: D. WARNER ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 114' FSL & 329' FWL, SEC27 T11N RSE UM MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 2901.00 2900.97 2753.97 0.53 S 8.38 E 6604.00 6010.43 5863.43 1132.48 N 1428.82 W 6631.00 6030.87 5883.87 1143.35 N 1442.70 W 6634.00 6033.14 5886.14 1144.56 N 1444.24 W 6806.00 6164.03 6017.03 1213.19 N 1532.23 W 6872.19 6214.60 6067.60 1239.53 N 1565.85 W 6910.00 6243.56 6096,56 1254.58 N 1584.93 W 6998.00 6310.96 6163.96 1289.57 N 1629.40 W 7020.00 6327.81 6180.81 1298.31 N 1640.52 W ,. FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 7020.00 6327.8t 6180.81 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 2092.10 N 51 39 W WELL. 2M-15 (114'FSL,329'FWL,SEC 27,T11N,R8E,UN) HORIZONTAL PROJECTION loO0 : i : : WELL. 2M-15 (114'FSL,329'FWL,SEC 27~T11N,R8E,UM) VERTICAL PROJECTION 3000 AOGCC GEOLOGICAL MAT£FIIALS INVENI-OIqY LIST PEHMIr 1I ~/' - -~-~ WeLL NAME z~,~ cOMPLetION DAtE ~ I ,,-~/I ?~- CO. contact & ~o. , form' rl~'Ceive~ ~ece'ived dale ' ' Commenl. ' ,,, 403. yes no SUndry application ..... 404 yes no report of sund~ appllcalion , , , ii i hsle log ...... hole log . ~ .. log MUD GCT ~' ~ 1EMP 'DiUSFL ........... CML". - ' DLL COl. ~: ~ "PliErs" ' BHCISL CET sPiNNE~ " Oii~i~C Lm otHe~ D~i'~ HEC .sSs .. , pAb~An ui~i~.l ,, Data FDc- ' ' " ' 'FDC H~D LDTICNL ' ' , , , , . ....... CYBER ' ' ~ "core ...... LOOK ~~ ~ ~lul~sis ..... ~S ..... ................ , , , ,. , NGT ,, i .............. ............ , ,, , ~.. . , , , ARCO Alaska, Inc. Date: February 7, 1992 Transmittal #: 8357 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. 2 M - 0 3 Cement Bond Log / 2M 03 Ultrasonic Imager ~/ 2 M - 1 5 Cement Bond Log 2M 1 5 Ultrasonic Imager 1 -27-92 · · 1 -27-92 I -27-92 1 -27-92 Please acknowledge receipt and 5800-7362 5800-7400 5 2 0 0--6-'900 5 2 0 0 - 6"8"~2'6'q e Receipt Drilling Acknowledge: State of Alaska(+sepia) Date- E.CE.t.VE D NsKFEB 1 1 199 AJaska 0il & Gas Cons, Commission Anchorage -. ARCO Alaska, Inc. Date: January 24, 1992 Transmittal #: 8342 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 3Q-01 ~t'" 33 2M-15 Transmitted here with are the following items. one signed copy of this transmittal. ,.~LiSS Tape Listing - - 9 and I 5 2 Tape and Listing 1 - 1 3 - 9 2 DISTRIBUTION: Lynn Goettinger Please acknowledge receipt and return 92017 75339 RECEIVED Date: .......... JAN 2 7 1992 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: December 27, 1991 Transmittal #: 8319 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-:I 119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. 2M-15 j CDN 12-11-13-91 2M-15 CDR 12-11-13-91 Receipt Acknowledged: Please acknowledge receipt 2900-7021 2900-7021 Date: .......... DISTRIBUTION: D&M Drilling Vendor Package(Johnston) NSK State of Alaska(+Sepia) RECEIVED DEC 0 1991 Alaska 0ii 8, Gas Cons. Commissior~ Anchorage TO: THRU: FROM: MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C sm~h~' DATE: December 13, 1991 commiss ionel{ '~ FILE NO: LG1213- 2. DOC Blair Wondzell Sr Petr Eng TELEPHONE NO: SUBJECT: BOP Test Arco 2M-15 Permit No. 91-33 Kuparuk River Unit Louis R Grimaldi Petr Inspector Wednesday, December !! 1991 I traveled to Pool Rig #7 which is presently Drilling Well 2M-15 for Arco in the Kuparuk River Unit to witness the initial ~OP test. The test commenced at 0300 hours and had a duration of 2 1/2 hours. All equipment was tested properly and held the test pressure (3000 psi) without any leakage observed. Ail equipment was in place and correctly assembled including the flare and blooey lines, and the firewall that separates the remote accumulator controls from the BOP stack. The function test on the accumulator was performed and, although API RP 53 requires only one set of pipe rams, the annular preventers and the HCRs to be operated (PARA 5.A.23), Jim Greco (pool tool pusher) operates all hydraulically actuated preventers and valves and still maintains 500 psi above precharge (200 psi min.). I believe this attests to Rig 7's accumulators good condition. The rig and its. surrounding area are kept clean and orderly with no infractions observed. In summary, I witnessed a good BOP test on Pool Rig #7 Drilling Well 2M-I5 in the Kuparuk River Unit. Attachment 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 C?b-,.5, Pnod/Bpns. L1~4,,907-659-7609 DEE~,'91 9'O! No.UUb P.U6 TO: C;ON $ E I~,,VA,~I~ I ON Lonnte c smith Commissioner THRU: Blair E Wondzell sr Petroleum sngr FROM: LOtl Grimaldi Petr Inspector AND GAS COMI~ISSION DATE SUBJECT RECEIVED DEC ! ~ 1991 Alask~ Oil & Gas Cons. Commission Anchorage CPF-5 Prod/Opns. T,U_~,? 0 ?-659-?609 DEC 13'91 9:01 No.O05 P.04 MUD SYSTIE)4S z ' Vt~.I Audi o Trtp tank I ~' Flo. rnont t:or --~i ~ Test Pressure AnnutaP preventer ... ~, 0~]~ P~pe rams ~.~O(:::) Choke line valvee ~ ~ ~ 0 HCR valve ~ ~ 0 0 Kill line valves ~ ~~ Check valve ~ STATE OF ALASKA ALASKA Ol L AND GAS CONeERVAT ION COMM I SS ION BOP Test Report TESj; Initial ~,,, Weekly__ O~her _...;. _.. * _,,. _ ,_ ,_8 g p~tg Press after clo~ure_.. /,_~..~ ~2~.._ .......... pstg Pump tner e!os pre~ 200 pafg ~ ._mln ~.~'~-~_sec _ FU)I ohaege press attained ~~ mtn ~sec , ,~ "' ,~.~ Remo~e Blfnd switch cover KELLY AND FLOOR SAFETY VALVES: Upper Kelly J Test pre,sure Lower Kelly Ball type .... in~tde BOP Choke man(fold _. Number valves / Numbep f! anges ...... ~,__. Adjustable choKes~ Hydraulically operated ehoke Test pressure Test pre,sure ~L--?__'¢~1¢~ ~ .... Test preesure___~ _(?_El 0 TEST RESULTS: Failures (~ Test time ~ ~ hfs Repair or replacement el' felled equipment to be mede ~lth(n ~ daya. Notify the i nspeeto~ end fei'icily with ~rltten/FAXed ver(ftcatfo~ to Commission office. tbut(¢, nt orig - AOGCC Operator Supervisor W I TNESS I~ EL !: I"V E L) ' Alaska Oil & Gas Cons. Commission C.00~ (rev 07/08/91) ARCO Alaska, In?"~ Post Offic .~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 29, 1991 Mr. Lonnie Smith Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: SUBJECT: Applications for Permit to Drill KRU Field Well 2M Pad Addendum to Previously Approved Permits to Drill The attached correspondence is the Alaska Oil and Gas Commission's ruling which approves isolation of Colville Sands at 2M pad by down squeezing cement into the annular space between surface and production casing. This will occur after the primary cement job on the production casing is completed, and applies to those wells which encounter significant hydrocarbon zones within 200' TVD of the surface casing shoe. There have been four drilling permits which have already been approved prior to the ruling mentioned above. ARCO Alaska, Inc. requests that these four previously approved drilling permits also be included in the ruling. The four wells are: Well Permit NO. APl No. Approval D~,te 2M-15 91-33 50-103-20154 03/05/91 2M-16 91-32 50-103-20153 03/05/91 2M-17 91-18 50-103-20150 02/22/91 2M-18 91-19 50-103-20151 02/22/91 If there are any questions, please contact Tim Billingsley at 265-6575. Thank you for your assistance in this matter. Sincerely, Area Drilling Engineer ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany A~ ii~, , ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1~ TELECOPY: (907) 2767542 March 21, 1991 A Wayne McBride Area Drlg Engineer ARCO Alaska, Inc P O Box 100360 Anchorage AK 99510-0360 Re: Alternative cementing procedure for some Kuparuk River Field wells on Drill Site 2M. Dear Mr McBride: This is in reply to the meeting with the Commission on March 8, and your letter of request dated March 11, 1991. The Commission has reviewed the conditions expected to exist on Drill Site 2M, and approves isolation of Colville Sands by down squeezing cement into the annular space between surface, and production casing. This will occur after the primary cement job is completed, and applies to those wells which encounter significant hydrocarbon zones within 200' TVD of the surface casing shoe. If you have any questions, please feel free to call me. ~Sincere~ Lonnie C Smith commissioner LCS/jo ALASKA OIL AND GAS CONSERVATION COMMISSION March 5, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 278-7542 A. W. McBride Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 re: Kuparuk River Unit 2M-15 ARCO Alaska, Inc. Permit No. 91-33 Sur. Loc. ll4'FSL, 329'FWL, Sec. 27, TllN, RSE, UM Btmhole Loc. 1391'FSL, 1395'FEL, Sec. 28, TllN, RSE, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, _ rman Alaska Oi and as Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: .Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.0O5 la. Type of Work Drill X Redrill -- I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil .~X Re-Entry _ Deepen --I Service _ Development Gas ~ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 141', Pad 106' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25586 ALK 2672 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 114' FSL, 329' FWL, Sec. 27, T11N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 1250' FSL, 1205' FEL, Sec. 28, T11N, R8E, UM 2M-15 #U630610 At total depth 9. Approximate spud date Amount 1391' FSL, 1395' FEL, Sec 28, T11N, R8E, UM 21-MAR-91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) property line 2M-16 (proposed) 7074' MD 3885' @ TD feet 25' at surface feet 2560 6356' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 3081 ' feet Maximum hole anc~le 40° Maximum surface 1640 pslg At total depth (TVD) 3305psicj @ 6356' 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Coupling Lenc~th IVD TVD IVD 'I'VD linclude statue data1 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 Cu.Ft. 12.25 9.625 36.0# J-55 BTC 2726' 35' 35' 2761 2761 940 Cu. Ft. AS III & HF-ERW 500 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 7039' 35' 35' 7074' 6356' 200 Cu. Ft. Class G Top 500' above Kuparuk 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 verticaltrue vertical feet Casing Length Size Cemented Measured depth Structural Conductor Cu. R. Sudace Cu. Ft. Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat __ BOP Sketch ~ Diverter Sketch X Drilling program Drilling fluid program ~ Time vs depth plot __ Refraction analysis _ Seabed report _20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Sicjned ~'f~'~'~---7~ Title Area Drilling Engineer Date ~_,./~.F_,~/~/ / '-' Commission Use Only / / I I 9 I Number APl number Ap t~ Permi,~./, ,. ,.~,~ 50- ~) 3 - .2. ~:)/~ ~Z other rec{uirements Conditions of approval Samples required ~Y e s ,,~ N o Mud log required ~ Ye s ,,~ N o Hydrogen sulfide measures ~ Yes ;~' N o Directional survey required ,z~Yes ~ N o Required working pressure for BOPE ~ 2M; .~ 3 M; ~ 5 M' ~ 1 0 M' ~ 1 5 M Ot her:e~~.r_~ ,~ by order of Approv Commissioner the commission Date . . . Form 10-401 I~e'~ ~.~ - Su )mit in triplicate ARCO ALASKA, Inc. Structure : Pad 2M Well: 15 Field : Kuparuk River Unit Location · North Slope, Alaska Irreeted by : jones FOR: T BILLINOSLEY Gte plotted : 6-Feb-91 lot Reference is 15 version oordinotes ore in feet reference slot f15, ue Verticol Depths ore reference wellheod, i-~EASTMAN !ZL/~CHRISTENSEN o · · 400 _ 5 8oo - - 1200- _ ..~ 16oo- Q_ - 2000- _ 2400 - _ -1-- ~.. - I~ 3200- > _ =5 - 4000- _ 4400- - V 4800- 5200- _ - ~0002 I 0 RKB ELEVATION: 141' B/ PERMAFROST 3VD=1391 T/ UGNU SANDS TVD=1431 < West ,oo.oo , 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 I I I I I I I I I I I I I I I I I I I I I LinGO TD LOCATION: 11391' FSL, 1595' FEL 1-1400 28, T1 f 1200 1250' FSL, 1205' FELJ ~ 600 SEC. 28, TI IN, RBE J TARGET '~ 400 WD=6071 TMD=6704 DEP= 1909 1909' (TO TARGET) 114' FSL, 329' FWL SEC, 27, T11N, RBE T/ W SAK SANDS TVD=2001 B/ W SAK SANDS 'Pc'D=2561 95/8" CASING PT T,/D=2761 K-lO TVD=2831 KOP TVD=3081 TMD=3081 DEP=O ~.0o AVERAGE ANGLE 9.oo 59 DEG 41 MIN GO BUILD 3 DEG/tO0 FT · ~ 9 EOC '~/D=4300 TMD=4404- DEP=440 1 TMD=4450 DEP=457 ~ TARGET - T/ ZONE C TVD=6071 TIdD=6704 DEP=1909 \ ~ T/ ZONE A TVD=6087 TMD=6725 DEP=1922 ,N,.N..B/ KUP SANDS 'P,/D=6202 TMD=6874 DEP=2018 -~x~ TD / LOGGING PT %/D=6356 TMD=7074 DEP=2145 i i i i i i i i i i i i 400 800 1200 1600 2000 2400 2oo.00 Vedlc(31 Section on 506.52 ozlmufh wilh reference 0.00 N, 0.00 E from slot #15 200 I 250 I 300 I 350 I 300 . 250 . 200 ..~ ~ I 1 50 . I I %,~?0o ~ ~[500 400 450 500 550 60O 650 ,,~~ I I I 900 I I I I I ~ 1 ?00 I I I I I i ~soo I I / / / / / 900 / / / / / / / 1 O0 5O 5O 100 I 2OO ~'"~300 · 300 300 'q O ;o OO x.q 900 \ \ x ~1 O0 \ \ ~,2300 /' 7o0 · aO0 \ \ \ \ \ · 300 I 250 I 300 I 350 I 400 I 450 I 500 I 550 I 60O 7OO ~ I 300 I I I I I I I 650 I 7OO 300 .25O _ 2OO 150 100 _ 50 _0 _ 50 1'00 DRILLING FLUID PROGRAM (2M-15) Spud to 9-5/8" Drill out to 8~jrface casing weight uo Density 8.6-10.0 8.6-9.6 PV 15-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 1 5-40 4 - 8 APl Filtrate 10-12 8-10 pH 9-1 0 8.5-9 % Solids 10 +/- 4- 7 Weight up to TD 10.0 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1640 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 2M-15 will be 2M-16 (proposed). As designed, the minimum distance between the two wells would be 25' at surface. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations will be pumped down the surface/production casing annulus or designated disposal well. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. - The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2M PAD , . . , . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. ,.dPARUK RIVER UNI', 20" DIVERTER SCHEMATIC 5 HCR \ 6 4 I HCR 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 , 6 5 3 ,.13 5/8" 5000 I-JI BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 X I. A 7: /. O/VS. , E ~, l., F.. £.1.. 00. ¢8?, ?Rg. $~ 70° 15'1~.$7"?' I$0°08'~7', R~? ' I 14 ' t I f ' tOt.O' t04.$ 4~, ~.~8 ~0~1~' I~.~" I~0°0~'~. &09" I I4 ~ ~t ' lOt. O' 104.5 4~, 804.53 ~0~/~' /8,~8 " /~0~08'~.0~ " / / 4 ' 3~' tOt.O' tO~.~ 487,8~9.~4 ~0~1~' t~.~7~" 1~0~0~'~358 " I /~' It' lOt.O' 105.~ X L~E LONG. ~S.L. 4~;~.41 ?0°/~' /~,~79" I~0°0~'~.~30 " tl4' I~' 1~.9' lO~,l ~,~4.~1 ~Oe/E~/8'~9 ' /~OeO~'~. /~" //4 ' ~' 100.8' t05.2 4~,~9.~1 ~O°l~'t~'~l~ " t~OeO~'~/.~O'' It~' ~9' lOGS' 105., ~ 9~4.~? ~0~/~' /~'~' /$OeO~'~O.~20 " //~' //4 ' lO0.?' lOS.~ 4~~.~1 ZOe/~'/~.~80 ~ /~0o0~'4~.9~4', //4 ' /~9' 100.6' I0~.~ d~ 00~.~9 ~00/~'1~.~1" t ~0~ 0~'49.~4" / 14 ' I~' 100.6' 105.~ 4~8, 0~9.45 ~Oe/g'/8.'$$ I ' /~0e 0~'4~S~4 " //4 ' /~9' t~.9' 105.~ 4~,//~.2~ ~Oe/g'/~.~/ ~ /~e0~'4~.~/9 " //4' ~9' 100.3' 105.6 4~, /4~.43 ~0~/~'/~'~3" /~0°0~'4~. /~' //4 ' ~04 ' ~0.2' 105.6 4~8,16&02 ~OelC't~'~" I~0e0~'44,470" /t4' 3~9' t00.~' 105,5 48E; 194,04 ~Oe/~' 1~,~" I ~OeOS'~.X~" I I · ' 3E4' I~,1' 105.6 488, ~i9. tS ~O°/E' /O. Sg~" /50e05'43.0//" I I4 ' 379' I00.0~, ;05,1 400; ~4~.~1 ~0°/~'/~'~'* I~OeO~'4~.EX~" tl4 ' 404' 99.9, 105.~ 4~8; EDA. 0~ ?Oo/~'l~,~" I~OeO~'40.~l" 114 ~ 4~4' 99e8' 105.4 4~, $1~.1~ ?Oel~'l~.~'' /~0~0~"40.0~" t/4 ' 4?9' 99.7' t05.~ · ~, ~44.40 XOet~' I~.~" /50~0~'~.~4" //4 ' ~04' 99.7' 4~, ~.~1 XOe/6' I~.~" /~0~0~'~.~0 ' / / 4 ' ~' 99.6' t04.9 488, 4t9.~ ~Oel¢'lS.¢&6/' t~OeO¢'~laO " I/4' ~79' 99.4' ,,,~,,_ O NSDK. gMO0. C EA,D2MX, 6215D 7 /HEREBY CERTIFY TH~T t AM PROPERLY ~ ~ '. p~ [ . , ~. ~ · ~ .... ~--~ ~' W ~~~'' ~" ' ' ..... Description CHECK LIST FOR NEW WELL PERMITS Company /~rc_r~ . Lease & Well ITEM APPROVE DATE · YES NO (1) _Fee ~pc/_ Z~I 1. Is the permit fee attached .......................................... ~ .~ [. (2) Loc (2 thru (8) (3) Admin ~/°d_ Z//~/qz 9. '('9 thru ~3) ' 10. : .. / - e / 11. (10 and 13) .... 12. 13. (4) Casg (14 thru 22) (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 2.' Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... '~ , , Is administrative approval needed ................................... 7~ Is the lease number appropriate ................................. /F' Does the well have a unique name and num~g~ .... ~ ~- ..... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER [;~d Z//27/~/ '(29 thrff 31) (6) Add: Geology: DW3 RPC Engineering: LCS ~- BEW rev: 11/30/90 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. POOL Additional Remarks: INITIAL GEO. UNIT ON/OFF CLASS STATUS AREA NO. SHORE o ~o Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. R£C£~VED JAN 2 ? ~ Alaska Oil & Gas Cons. commission Anchorage Tape Yeriflcation Listing chlumberger AlasKa Com~uttng Center 05:37 TUNI BDEP TDEP DFPH DFV DFL R~CS MCST ~'I' 0 0 0 O. O, O. O, ,~. TABLE TYPM : CURV ''''''''''''~'~;;;;'i'~;;''''''''''''''''''''''''''''''''''DEPT Dent e ROS2 PEF DCAL DPMT DPOP TNP~ ATR Gamma Ray SS2 ~HO Density - LDT Bul~ Qensit~ Qelta Photoelectric Factor Differential Caliper Density Porosity Demslt¥ Porositv Output from aD Application Program Thermal Neutron Porosltv ** DATA FOR~AT SPECIFICATION RECORD ** ** SET T'YPE - 64EB ** TYPE REPR CODE VALUE ! 66 0 2 66 3 73 4 66 5 66 6 73 7 65 ~ 65 !1 66 13 66 !4 65 !5 66 16 6(> 0 56 1 0.5 FT I 0 ~I$ Tame Verlficatfon Listing ~ChlUmberqer Alaska ComputlDg Center 15-JAN-1992 05:37 ** SET TYPE - CHAN ORDER ~ LO DEPT FT ~5298l 00 000 00 0 ROS~ LWD G/C3 ~5~98! 00 000 O0 0 RHOB Lwo G/C3 152981 oo 000 O0 0 DRHO LWD G/C3 !.5298! O0 000 00 0 PEF Lw!) 152981 00 000 00 0 DCAL LWI) IN 152981 00 000 00 0 DPH! i;WD PU 15298~ 00 000 0O 0 DPO~ LW~ PU 15295~ 00 000 00 0 TNP~ LbO PU ~5~98l 00 000 00 0 ATR LWD OM~M 15~9~! 00 000 O0 0 PSR L~D OM~ ~52981 00 000 00 0 D~R LWD OH~ 15298~ 00 000 00 0 ROPE b~O F/H~ 152981 00 000 OO 0 GR L~O GAPI 152981 00 000 00 0 ** DATA ** AP! APl APl F!LF, ~B N SIZE REPR pROCEsS TYPF CHASM ~OP NUmB SAMP ELEh~ CODE (HEX) 1 ! 1 4 6B 0000000000 1 I l, 4 68 0000000000 I 1 1 4 68 0000000000 1 1 I 4 68 0000000000 t 1 1 4 68 0000000000 ! ! 1 4 68 0000000000 1 I 1 4 68 0000000000 1 I 1 4 68 0000000000 I ! 1 4 68 0000000000 l 1 1 4 68 0000000000 I 1 i 4 68 0000000000 1 1 I 4 68 0000000000 I 1 1 4 68 0000000000 1 I I 4 68 0000000000 , mmm.m--lmm'-- m'm m.'lmm"mm mmmmmmm m.mmmm#mmmmmm#m.mmmmmm~mmm~m~m! 'DEPT. 7021,000 RO$2.hWD -999.250 PEF,L~D 999,250 DCAb'LWD -999,250 TNPH,LWD ~999,250 ATR,LWD -999 250 ROP~.L~ DW 39,561 GR,LWD -999,250' D~PT, 7000.000 ROS2,LWD -999,250 PEF LWD -999,250 DC~L,LWD ~999,250 TNPN:LWD I909,250 ATR,LWD 999,250 ROPF,LWP 50.27~ GR.LWD '999,250 D~PT, 6900,000 ROS2.LWD '99~.250 PEW,LW~ -999,250 DCAL,LWD ',999 250 TNPW,L~D -999.250 ATR.LWD 2,796 ROP~.LWD 41,285 GR,LWD 86,171 D~D~. 6800.000 ROS2.LWP 2,428 PEF.LWD 3,478 DC~b,bWD 0,361 TNPN,LWr) 26,100 ATR.LWD 6,764 ROPF,LwD 81,078 GR.LWD 59,308 DEPT. 6700.000 POS2.LWD 2.2!5 PEF,L~D 2,671 DCAL.LwD 0,~66 TNPH,L~D 28,400 ATR.LWD 25,383 ROPW.L~D 138,455 CR.LWD 38.283 D~PT 6600,000 ROS2,bWD 2,487 PEF[LWr) 4,305 DCAL,LwD 0,630 TNPH.L~D- 36,300 ATR.LWD 2,307 ROPF,L~P 119,205 GR.LWD 113,R08 RHOB.LWO -999,250 DRHO.LWD DPHI,LWD -999,250 DPOR,LWD PSR,bWD -999.250 DER,LWD RHOB.bWD -999,250 DRHO.LWD DPHI,LWD -999,250 DPOR.LWD PSR,LWD -999.250 DER,LWD RHOB,LWD 999 250 DRHO,LWD DPHI,LWD 1999[250 DPOR,bWD PSR,LWD 2,846 DER,LWD RHOB.LWD 2,428 DRHO'LWD DPHI LWD 0,~35 DPOR,LWD PSR:LWD B.110 DER,LwD RHOB.bWD 2.215 DRHO,LWD DPHI,L~D 0,264 DPOR LWD PSR,LWD 39.945 OE~:LWD RHOB,LND 2,487 DRHO LWD DPHI,LW!) 0,099 DPOR:LWD PSR,LWD 2.344 DER.LWD -999,,250 -999,250 -999'~250 -999,250 '999,250 2,S~7 0,~35 ?, 47 0,003 0,264 38,802 0,023 0,099 2,330 ,IS Tape Verification L1stinq ;chlumberQer Alaska ComputJ. nq Center 15-JAN-~992 05:37 PAGE{ 5 DEPT. 6500.000 ROS2,LWD PEF,LWD 3,824 OCAb. LWD TNPH.LWD 48.900 ATR,LWD ~OPE.LW~ 101,694 DEPT. 6400.000 PEF LWD 3,416 DCAL,.LWD TNP}{'L~L. ~'3 40,300 ATR,. ,bWD ROP~,LWD 79,248 GR.LWD DEPT. 6300.000 ROs2.LWD PEV.LWD 4,825 DCAS,LWD TB~PM,LWD 37,400 ATR,bWD ROPW.LWD 131,3~7 GR.LWD DEPT. 6200,000 PEF.LWD 3,602 DC~L,LWD TNPH.LWD 4~,500 ATR,LWD ROPF,LWD 137.41~ GR.LWD DFPT 6!00,000 PEF,LWD 3,743 DC~D.LWD TNPH,LWD 37,400 ATR LWD ROP~.[,W[~ 138,456 GR;LWD DFPT. 6000.000 RD$~,LWD PEF,bWD 4 369 DCAL,LWD TNPM.LW[) 32~60~ ATR.LWD ROPF.LWD 193,277 GR.LWD D~PT. 5900.000 ROS2.LWD PEW,Yin[) 3 225 DCAL.LWD TMPN.[,wD 32:000 ATR.LwD ROP~.LWD 286.729 D~PT. 5800.000 RO$2.bWD PEF LWD 3,6~9 DCA5 LWD TNP~:LWD 40,400 ATR:LWD ROP~.LwD 183.649 GR.LWD DFPT. 5700.000 ~O$2.LWD TB'PH,LWD 36,300 ATR]LWD ROPF.LWD 232.]g8 ~R,6WD D~P~ 5600,000 PEF:LWD 2.774 TNpH.LWn 3].900 ATR.LWD ROPF.L~n 268,543 GR.LW~ DFPT. 5500.oO() ROS2,I,WD P~W,LWn 2.~77 DCAI.,.LND TNPN,LWD 38.300 AT!{.L~D ROPW.L!~n 5!.250 GR.LWD 2,284 RHOB,bWD 2.284 DRHO,LWD -0,006 0,175 DPMI,LWD 0 222 DPOR.SWD 1,980 PSR,SWD ~067 DER.LWD ~.,~6 ~95,223 2 336 RHOB.'LWD 2.336 DRHO.LWD -0,003. 0 142 DPHI,LWD 0,190 DPOR LWD ~'190 3 003 PSR,hWD 3.179 DER:LWD ~ :113 125 341 0.~72 DPHI.SWD 0 120 DPOR,LWD 9A~0 2.236 PSR,LWD 1]992 DER LWD 192,666 0,~38 DP}~I.bWD 0,121 DPOR,LWD 0'i~6 2,~15 PSR,LWD 2.755 DER,[,WD 115.304 2.478 RMOB,LWD 2 478 DRHO.DWD 0,~07 DPHI,LWD 0~104 DPOR.~WD 0,! 3,090 PS~!,LWD 3.095 DER,LWD ~,09~ 110.183 2,554 RHOB, LWD 2 554 DRNO LWD 0,311 DPHI.DWD 0~058 DPOR:LWD 0,~5' 4,069 PSR,LWD 4 064 DER,LWD 4,065 83,098 ' · , ~.437 RHOB.bWD 2,437 DRHO.LWD -0,002 0,2~5 DPHI.SWD 0.129 DPOR,LWD 3.385 PSR.LWD 3.343 DER.LWD 88.220 2,402 RHOB, w . LiD 2 402 DRHO.LWD 0,139 DPHI.LWD 0.~50 DPOR"LWD 3,674 PsR,LWD 3"563 DER.LWD 3,599 103,951 2 437 RHOB.LWD 2.437 DRHO.LWD 0:240 DPHI.LWD 0.129 DPOR.LWD 3,176 PSR.LWD 2,997 DER,LWD 3.056 109.~08 0 154 DP~I,LWD 0.161 DPO~,5WD ~161 3~092 PSR,LwD ~,971 DER.LWD 0~1 81,433 ~.419 RHO~,LWD ~.419 DRMO.LWD 0,002 0.~12 DPHI,LWD 0.140 DPOR,LWD ~ ~40 3,065 PSR.LWD 2.840 DER.LWD 102.605 LIS Tape Verification List~no ~Chlumherger A]a. sKa Comoutln~ Center 15-J~N-1999 05:37 PAGE: 6 DEPT. 5400.000 ROS2.LWD PE~,LWD 3.084 DCAL.LWD .TNPW.LWD 34,200 ATR,LWD ROP~.L'~F~ 79,646 DEPT 5300 000 R[)$2 LWD ,..Er 2:603 ~OP~: ~D 37.600 ATR,LWD LWD 67.16~ GR.LWD DEPT 5200,000 ROS2.SWD PEF'LWD '2,791 9CAL,LWD T~p~. ' ROPM,LWD 38,200 A~R. .LWD 139,531 DEPT. 5100.000 ROS2,LWD PEW LWD ~,019 DCAL,LWD TNP~LWD 40'200 ROPK,LWD 192,29~ GR'LWD DMPT, 5000,000 ROS2,LWD PEF,LWD 2.750 DCAL.LWD TNPH LWD 33,700 ATR.LWD ROPF:LWD 253,141 GR,LWD DEPT, 4900,000 ROS2,LWD PEF.LWO 3,218 DCAL.LWD TNP~,[.~D 37,200 ATR.LWD ROPE.LWD 254,994 GR.LWD DEPT. ~$00.o00 ROS2,LWD PEF,LwD~ 3,050 DC~L.LWD TNPH.LWD 39.800 ATR.LWD ROPE,LWD 221,971 GR,DWD DFPT. 4700,000 ROS2.LWD PEF.LWD 3.24~ DCAL.LWD TNPN LWD 22,100 ATR LWD ~OpF:I~WD 142,856 DEPT. 4600,000 ROS2 LWD PEF L~D 3 108 DCAL~LWD TNDH:L~D 401700 ATR.LWD ROPF,LWD 209,!79 GR,LWD DFPT, 4500,000 ~OS2,LWD PEF.LWD 9,8~6 DCAS.LWO TNPW. L~D 39. 600 ATR. LWD ~OPF · [,wm 245,044 ~R, I,WD DFPT. 4400.000 PEF.L~D 2,843 9CAb. LWD T~PH.!.,WD 4&,50G ATR.LWD ROPF,I,~r' 190,967 GR.LWD 2.3i6 0,000 3,466 1,65~ . . 2 0 2 69 e 2. 76. e 0. 3, 108, 342 626 6!1 763 594 7!2 164 543 606 401 33i 308 930 669 442 415 328 280 2.373 0,309 2,988 116,606 2~ 0. 2, 85. . O. 2, 138. . 0. 1, 92. · O. 1. 90. 432 347 585 629 326 69~ 229 349 104 864 741, 336 08O 772 647 RHOB,LND 2.316 DRHO.LWD DDHI,bWD 0 202 DPOR LWD PSR,bWD 3'286. DER:LWD RHOB.LWD 2 ~ DRHO.LWD DPHI.bWD O~ DPOR,LWD PSR,LWD 2,877 DER,LWD RHOB,LWD 2 351 DRHO.LWD DPHI,LWD 0~18I DPOR,LWD PSR,LWD 2,591 DER,bWD RHOB.bWD 2.164 DRHO,LWD DPHI, DWD O. 294 DPOR,LWD P.R.LWD 2.492 DER.bWD RHOB.LWD 2 331 DRHO.LWD DPHI,LWD 0i193 DPOR,LWD PSR.LWD 2 885 DER.LWD RHOB,LWD 2.442 DRHO.LWD DPHI,LWD 0 126 DPOR,LWD PSR,LWD 3~096 DER,LWD RHOB,LWD 2 373 DRHO.LWD DPHI LWD 0~168 DPOR,LWD PSR:bWD 2.842 DER.LWD RHOB,LWD 2 432 DRHO,LWD DPHI,LWD 0!132 DPOR.LWD P'R,LWD 4 095 DER,BWD ~HOB.LWD 2 326 DRHO,LWD DPHI,LWD 0~196 DPOR.,LWD PSR.LWD 2.618 DER.LWD RHOB.LWD 2.349 DRHO.LWD DPHI,LWD 0.183 DPOR.LWD PSR.LWD 1.748 DER.LWD RHOB.LWD 2.336 DRHO.LWD DPHI.LWD 0.190 DPOR LWD PSR,LWD 1.731 DER~LWD 02 3 44 8'oo · ,i 87 2,95 4 o:.o '4 '0, ~4 -0,004 o' -0,006 "0,078 o '0,011 0,196 2.646 '0.00 0,181 t,790 0,007 0,190 1,747 I$ Tare Verificetlo~ Listing ehlumberqer AlasKa Computinq Center 15-JAN-1992 05:37 PAGEl DEPT, 4300.000 ROS~.LWD PEF.LWD 3,061 DCAL,LWD TNP~.LWD 36,100 ATR.LWD ~[ 289,011 GR,LWD D~PT 4200,(300 ROS2.LWD PEF:LWD 2,730 DCAL,LWD TMPM,L'WD 35 200 ATR,LWD ROPE'LWD 283:825 GR, LWD DEPT. 3900,000 ROS2,LWD PEF,LWD 2,822 DCAh. LWD T~P~.LWD 41,500 ATR.LWD ROPE.LWD 336.!07 GR.LWD DEPT, 3800,000 RO$2,LWD PEF,bWD 2,758 DCAL,LWD TNP~ LWD 35,900 ATR.LWD ROPF:LWD 341.241 GR.LWD DEPT 3700,000 RO,S2 LWD PEF:LWD 3.383 DCAL:L, WD TNP~. L~D 39,000 ATR, LWD ROPE, P~D 264. 746 GR. LWD DEPT 3600.000 ROS2.LWD PEW'LwD. 2.68q, DCAL . LWD TNPH.LWD 40.70~ ATR,LWD ROPE.LWD 102.755 GR.bWD DEPT. 3500.000 R()S2.LWD PEF,L~D 2.820 DCAL,LWD TNPH L~D 37.400 ATR,LWD' ROPE:[,WP 154,~88 GR.bWD DEPT. 3400.000 ~OS2.LWD PEW.bwr> 2,802 DC~h. LWQ T~P~.bwD 41.200 ATR.LWO RmPE,L~? 184.440 G~.bWD DEpT, 3300,000 ROS2.LW{) PEW.LW{} 2.163 DCAL.LWD TMPN.LWD 43.400 ATR.LWD ROPF.LWD 267,445 ~R.LWD 13 10 2,359 RMOB,bWD 2 359 DRMO.LWD O,186 DPHI.LND 0:176 DPOR.LWD 4,604 PSR,LWO 4.414 DER.LWD 1,732 0,000 DPHI,LWD O: 36 DPOR,LWD 2,969 PSR,LWD 2,988 DER,LWD 3.808 2,256 RHOB.bWD 2 256 DRHO.LWD 0,000 DPHI,bWD 0:239 DPOR,bWD ,896 PSR.LWD 2.737 DER.LWD ,953 2.263 RHOB,LWD 2.263 DRHO.EWD 0'076 DPHI,LWD 0.235 DPOR.LWD 2.873 PSR,LWD 2,972 DER,LWD ~,640 2,224 RHOB,bWD 2 ~24 DRHO,LWD 0,008 D~HI,LWD 0:,~.,8 DPOR,LWD 2.465 PSR,bWD 2' 362 DER.LWD 83.008 2,336 RHOB,bWD 2.336 DRHO LWD 0.112 DPHI.LWD 0.190 DPOR:LWD 2,588 PSR,LWD 2,462 DER.LWD 93,040 2,277 RHOB.LWD 2.277 DRHO.bWD 0.254 OPHI.bWD 0 226 DPOR.~WD 2,601 PSR.bWD 2:736 D~R.~WD 72.198 2.287 RHOB.LWD 2.287 DRHO.LWD 0.124 DPHI'bWD 0.220 DPOR,LWD 3'493 PSR,bWD 3.071 DER.LWD 66,506 2 lg5 RHOB.LWD 2.195 DRHO.LWD 0:0 9 DPHI.bWD 0.276 DPOR LWD 3.670 PSR,bWD 3.480 DER~LWD 70.31J 2.179 RHO~.LWD 2.179 DRHO.LWD 0.247 OPHi.bWD 0,285 DPOR.LWD 2,636 PSP,LWD 2.846 DER.LWD 54,335 '0,015 -0,003 ,981 9 -0~004 0,258 2,398 -0:,0 0.2~ 2,214 0,025 506 , '0,016 ,226 ,684 0,011 0,220 3'194 0,007 0,276 3,540 85 ~,762 .IS TaLe Verification Listinq ;cblumberoer alaska ComDuting Center 15-JAN-199~ 05:]7 DEPT. 3200.000 ROS2.LWD PEF.LWD 2.713 DCAb. LND TNPH.LWD 4.2,900 ATR,LW~ ROPF,LWD 150,235 GR,LW .... DFPT 3100,000 ROS2.LW[) PEF*LWD 2.514 DCAL,LWD TNPH~[,WD 44.!0~) ATR,LWD ROP~,LWD 199'56] GR,LWD .... . .... ~. LWD DEP?, ') 3000 n0q ~OS2, ~ PEF.LW[ 2:558 DCAh,LWD TNPH. LW.. 44.900 ATR LWD ROPE. LWD 346.148 GR. LWD D~PT. 2900,000 ROS2.LWD PEF,LWD ~5.330 DCAL,LWD TNPM LWD 54,i00 ATR,LWD RO~'F~LWD -999.250 GR.LWD DFPT PEW'L~D TNPH,LwD 2800.000 ROS2 bWD 100,000 DCALiLWD '999,250 ATR'~LWD -999,250 GR,DWD 773 000 ROS2.LWD 999:250 DCAb,LWD 999.250 ATR,LWD -999,250 GR,LWD DEPT. PEF.bWD TMPH, W' ROPE.Li'D ** END OF DATA ** 2.174 RHOB,LWD 0.043 DFM!,LWD 2,963 PSR,LWD 72.094 2,066 RHOB.bWD 0.000 DPM!.DWD 5.534 PSR.LWD 80.843 2,8093 RHOB.bWD 0, 0 DPHI,LWD 3,024 PSR.LWD 72'796 2,42,]8 RHOB,I~WD 0,_ 4 DPHI.bWD 0.047 PSR,LWD '42,117 2 174 DRHO.LWD 0~288 DPOR.bWD 2.838 DER.bWD 2..066 DRNO.LWD 0,354 DPOR,LWD 5,255 DER.LWD 2 DPOR'LWD 2.975 DER~LWD 2,~38 DRHO,5WD 0, 49 D.POR,DWD 4,081 DER,LWD 2,3 0 RHOB,LWD 2,300 DRHO,LWD 0,4 8 DPHi,LWD 0.212 DPOR,LWD -999,250 PSR,LWD -999,250 DER.DWD -999,250 ~99g 250 RHOB.LWD -999.250 DRHO,LWD 999:250 DPHI LWD -999,~50 DPOR,bWD -999.250 PSR:LWD -999,~50 DER,LWD -999,~50 0,000 0,288 2,880 0,002 0,3 5 4 5,346 '0,019 ~,992 0,249~ 0'048 ',999~ :250 "999,~50 '999,250 **** FTLE TRAILER **** FILM NAME : EDIT .00t SERVICE : FLIC VERSION : 00~06 DAT~ : 92/0~/15 MAX REC SIZE ~ !.024 FILE TYPE : LO LAS? FILE ~ **** TAPE TRAILER **** SERVICE NAME : EDIT DATF : 92/0~/15 O~IGTN : FL!C TAPF NA~E : 75339 CONTINUATION # PREVInU$ TAPE CO~ENT : ARCO ALASKA INC., 2~-15, KUPARUK PIVER, 5n-103-20154-00 IS Ta~e Yeri~catlon [~lstino chlU~ber~er AlasKa ComDut~.n~ Center i5-JAN-~992 05:37 PAGE: **** REEL TRAILER **** SERVICE ~,!A~E : EDIT [~IGIN : ~LIC REEL ~A~E : 75339 CONTINUATION ~ : PREVIOUS RE~L : CON~ENT : ARCO ALASKA lINC., ~-~.5, KUPARUK RIVER, 50-103-20154-00