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Home My WebLink About195-1861. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10295'feet None feet true vertical 6446' feet None feet Effective Depth measured 10012'feet None feet true vertical 6237' feet None feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" x 2-7/8" L-80 9842' MD 6109' TVD Packers and SSSV (type, measured and true vertical depth) 9840' MD N/A 6108' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 5776' 3774' Burst Collapse Production Liner 10249' Casing 6434'10279' 5739' 121'Conductor Surface Intermediate 16" 7-5/8" 84' measured TVD 5-1/2" x 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-186 50-029-22625-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025512 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3Q-22 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 537 Gas-Mcf MD 1800 Size 121' 1428 12901625 0 1140 254 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker GBH-22 Seal Assmy SSSV: None Jan Byrne jan.byrne@conocophillips.com (907) 659-7224Senior Well Integrity Specialist 9946-9960', 9978-9993', 10000-10017', 10031-10061' 6187-6198', 6211-623', 6228-6240', 6251-6273' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 12:52 pm, Sep 22, 2023 Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorge Alaska Date: 2023.09.22 11:31:32-08'00' Foxit PDF Editor Version: 12.1.2 Jan Byrne DTTMSTART JOBTYP SUMMARYOPS 8/24/2023 ACQUIRE DATA ATTEMPT TO BRUSH n' FLUSH TBG UNABLE TO PASS 6397', RAN 5' x 2" DRIVE DOWN BAILER PAST DEBRIS FROM 6397' TO 6450' CLEAN DRIFT TO 9900' SLM RECOVER SMALL AMOUNT OF SAND & COIL SHAVINGS. IN PROGRESS. 8/25/2023 ACQUIRE DATA BRUSH n' FLUSH TBG TO 9833' RKB, RUN 2.29" P2P SAPCER & 2.29" NOGO STINGER TO 2.25" D NIPPLE @ 9833' RKB DPU FAILED TO SET PACKER TOOLS PACKED W/ SAND & COIL SHAVINGS, BRUSH n' FLUSH 2.25" D NIPPLE @ 9833' RKB. IN PROGRESS 8/26/2023 ACQUIRE DATA SET 2.29" P2P SPACER NOGO STINGER (OAL 26.5' OAL / SN: CPP287014) @ 9833' RKB W/ MAXFIRE & 1.69" SHORTY, GOOD DRAW DOWN TEST ON IA FROM 1300 TO 500 PSI. IN PROGRESS. 8/27/2023 ACQUIRE DATA SET 2 7/8 TTS TEST TOOL IN UPPER 2.29" P2P @ 9807' RKB, PULLED OV @ 8101' RKB, REPLACED IN KIND, MIT TBG 2500 (FAILED) NO COMMUNICATION W/ IA, PULLED 2 7/8 TTS TEST TOOL @ 9807' RKB. IN PROGRESS. 8/28/2023 ACQUIRE DATA WITH 2 7/8 TTS TEST TOOL IN 2.29" P2P @ 8907' RKB MIT TBG 2500 (PASS), CMIT TBG x IA 2500 (PASS). JOB COMPLETE. 3Q-22 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 49' of Fill) 10,012.0 3Q-22 4/14/2019 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Install New Stinger Half PatchC/O OV 3Q-22 8/27/2023 jhanse11 Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for OAxATM 10/7/2019 freebd NOTE: GLM'S are 2 7/8" w/ 30' x 2 7/8" joints above and below. 8/16/2014 famaj NOTE: PULLED ERODED OV FROM 9795' WATCH FOR EROSION ISSUES 5/1/2013 lehallf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 37.0 121.0 121.0 62.50 H-40 Welded SURFACE 7 5/8 6.75 37.9 5,776.5 3,774.4 29.70 L-80 BTC-MOD PRODUCTION 5.5"x4.5" 5 1/2 4.77 30.1 10,279.0 6,434.4 15.50 L-80 LTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 37.0 Set Depth 9,842.2 Set Depth 6,109.2 String Ma 3 1/2 Tubing Description TUBING 3.5" x 2.875" Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 37.0 37.0 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 495.3 494.9 5.91 NIPPLE 3.800 CAMCO DS NIPPLE 2.812 3,693.1 2,696.9 60.02 GAS LIFT 4.507 CAMCO KBMM 2.347 6,466.5 4,096.9 63.70 GAS LIFT 4.507 CAMCO KBMM 2.347 8,101.4 4,995.0 52.80 GAS LIFT 4.507 CAMCO KBMM 2.347 9,225.6 5,703.5 52.79 GAS LIFT 4.507 CAMCO KBMM 2.347 9,794.8 6,074.1 42.69 GAS LIFT 4.507 CAMCO KBMM 2.347 9,832.9 6,102.2 41.93 NIPPLE 3.668 CAMCO 'D' NIPPLE 2.250 9,840.4 6,107.8 41.77 SEAL ASSY 4.500 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 9,841.2 6,108.4 41.76 SBE 4.500 BAKER SBE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 53.0 53.0 0.00 Leak leak in Surface casing from 53 -62 7/12/2019 9,807.2 6,083.2 42.44 PACKER - PATCH - UPR Set PIIP Patch Assembly (Assembly includes Upper packer, spacer pipe, AVA D- Nipple Stinger OAL=26.5') (Patch from mid-element of PKR @ 9809.36' to Stinger Seal @ 9832.9' RKB) TTS CPP2 87014 8/26/2023 1.380 9,810.4 6,085.6 42.38 SPACER PIPE Spacer Pipe and & 2.25" AVA D-Nipple stinger (Part of Upper Patch Assembly). Stung into Camco D Nipple @ 9832.9' RKB 8/26/2023 1.380 9,828.0 6,098.6 42.02 LEAK Leak at 9828' ELM. 4/14/2019 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,693.1 2,696.9 60.02 1 Gas Lift GLV BK 1 1,302.0 1/2/2020 0.156 6,466.5 4,096.9 63.70 2 Gas Lift GLV BK 1 1,336.0 1/2/2020 0.188 8,101.4 4,995.0 52.80 3 Gas Lift OV BK 1 0.0 8/26/2023 0.188 9,225.6 5,703.5 52.79 4 Gas Lift DMY BK 1 0.0 7/10/2019 0.000 9,794.8 6,074.1 42.69 5 Gas Lift DMY BK 1 0.0 6/1/2019 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 9,946.0 9,960.0 6,187.2 6,197.7 C-4, 3Q-22 1/10/2007 6.0 APERF 2 1/8" Powerspiral Enerjet, 45 deg phase 9,978.0 9,993.0 6,211.2 6,222.5 A-3, 3Q-22 2/12/2000 8.0 APERF 2 1/8" Enerjet w/alternating DP & BH chgs, 0 deg phasing, +/-90 deg orient from lowside 10,000.0 10,017.0 6,227.7 6,240.5 A-2, 3Q-22 9/26/2005 6.0 APERF 2 1/8" PowerSpiral EJ, 45 deg phasing 10,031.0 10,061.0 6,251.0 6,273.4 A-1, 3Q-22 2/8/1996 4.0 IPERF 180 deg. phasing; Oriented (+/-) 90 deg F/ Lowside; 2 1/8" EnerJet 3Q-22, 9/19/2023 3:41:38 PM Vertical schematic (actual) PRODUCTION 5.5"x4.5"; 30.1- 10,279.0 IPERF; 10,031.0-10,061.0 APERF; 10,000.0-10,017.0 APERF; 9,978.0-9,993.0 APERF; 9,946.0-9,960.0 LEAK; 9,828.0 SPACER PIPE; 9,810.4 PACKER - PATCH - UPR; 9,807.2 GAS LIFT; 9,794.8 GAS LIFT; 9,225.6 GAS LIFT; 8,101.4 GAS LIFT; 6,466.5 SURFACE; 37.9-5,776.5 GAS LIFT; 3,693.1 NIPPLE; 495.3 CONDUCTOR; 37.0-121.0 KUP PROD KB-Grd (ft) RR Date 12/30/199 5 Other Elev 3Q-22 ... TD Act Btm (ftKB) 10,295.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292262500 Wellbore Status PROD Max Angle & MD Incl (°) 65.39 MD (ftKB) 6,346.59 WELLNAME WELLBORE3Q-22 Annotation Last WO: End DateH2S (ppm) 250 Date 1/31/2019 Comment SSSV: NIPPLE 1 Regg, James B (OGC) From:Earhart, Will C <William.C.Earhart@conocophillips.com> Sent:Thursday, March 16, 2023 1:13 PM To:Loepp, Victoria T (OGC); Regg, James B (OGC); AOGCC Reporting (CED sponsored) Cc:Packer, J.Brett; Hobbs, Greg S Subject:3Q-22 (PTD 195-186) BOPE Usage notification Attachments:3Q-22 BOPE Usage Letter_3.16.23_rev1.pdf Jim, Victoria‐ Please see the attached PDF per Bulletin 10‐003A in order to document the use of BOP equipment on 3Q‐22 (PTD 195‐ 186)3/15/2023 by CTU‐6 Please let me know if you have any questions. Thanks Will Will Earhart Well Integrity & Intervention Engineering Supv ConocoPhillips Alaska William.C.Earhart@conocophillips.com ATO‐13‐1300 Office: +1.907.265.1077 Mobile: +1.540.448.1789 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. KRU 3Q-22PTD 1951860 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 16, 2023 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003A, this letter is to follow up on BOPE usage on Schlumberger service coil unit CTU-6 with a written report. Time of BOPE Use: 3/15/2023 at 21:15 hours Well Location: 3Q-22 API Number: 50-029-22625-00-00 PTD Number: 195-186 Rig Name: SLB CTU-6 Operator Contact: Will Earhart (o) 907-265-1077. William.C.Earhart@conocophillips.com Operations Summary: Well 3Q-22 stopped producing 12/18/2022 due to a downhole plug-off event. Hot diesel was unsuccessful attempting to clear the obstruction from service. Service coil CTU-6 was mobilized to pull the tubing patch @9,810ft MD, perform a fill clean out to reestablish communication to the reservoir then re-install the patch. After extensive fishing and jarring efforts, the patch came free and pressure was observed at surface (T/IA= 2338/2782psi).The fish was brought to surface and 12.5ppg brine circulated into the wellbore to reduce pressures (T/IA=1698/1682psi). Due to the BHA and fish length, the plan was to hangoff the fish in the pancake flange, detach from it, shut in the well, lay down the fishing BHA, get back on the well and re-latch the fish and pull it into the lubricator to lay it down. Before the fish could be hung off, a gland nut on the pancake flange started leaking gas to atmosphere and attempts to re-energize were unsuccessful. The decision was made to RIH ~50ft and use the coil BOPE to shear the string. This was executed safely and the fish was pumped downhole to clear the production tree. BOPE Used: Shear Reason for BOPE Use: While hanging off the tubing patch fish in the pancake flange, a gland nut started to leak gas to atmosphere. Actions To Be Taken: CTU-6 has moved off of 3Q-22 and is enroute to 2A-19. The shears will be replaced and a full BOPE test will be performed prior to commencing further well work. A recovery plan is still being developed on how to most effectively re-enter 3Q-22 wellbore and recover the fish. If you have any questions or require any further information, please contact me at my cell phone number above. Sincerely, Will Earhart Well Integrity and Interventions Eng. Supv CPAI Drilling and Wells        P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 13, 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, 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 attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor Roger Mouser Digitally signed by Roger Mouser Date: 2020.10.13 13:10:42 -08'00' By Samantha Carlisle at 1:21 pm, Oct 13, 2020 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 10/13/20 2K 2M 3K 3O 3Q 3R 3S pad Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 2K-30 50103207580000 2170720 22" 0.3 6" 3/8/2020 2.5 9/29/2020 2K-32 50103207570000 2170420 29" 0.5 6" 3/8/2020 3 9/29/2020 2M-37 50103207450000 2160820 30" 0.4 9" 7/31/2020 2.1 9/29/2020 2M-38 50103207460000 2160830 4" N/A 4" N/A 2.5 9/29/2020 3K-32 50029227630000 1970760 10"Conductor extension 10" 4/27/2019 2.5 9/27/2020 3K-34 50029228790000 1980770 14" Conductor extension 14" 4/27/2019 9 9/27/2020 3O-01A 50029218360000 2151910 62" 0.70 11" 3/8/2020 4.25 9/27/2020 3O-19 50029227530000 1970500 13"Conductor extension 13" 4/27/2019 4.25 9/27/2020 3O-20 50029227500000 1970450 21 5.00 17" 9/27/2020 6 9/27/2020 3Q-22 50029226250000 1951860 20' 3.25 8" 3/8/2020 4.25 9/26/2020 3R-101 50029235740000 2170130 21" 0.40 8" 8/14/2020 1 9/26/2020 3R-102 50029235720000 2161570 54" 1.10 6" 8/14/2020 6 9/26/2020 3R-105 50029236510000 2191340 22" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-106 50029236410000 2190970 36" 0.60 9" 8/14/2020 3.5 9/26/2020 3R-107 50029236600000 2191810 32" 0.60 9.5" 8/14/2020 1 9/26/2020 3R-111 50029236430000 2191050 25" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-112 50029236370000 2190850 36" 0.60 14"8/14/2020 7 9/26/2020 3S-611 50103207740000 2181030 11' 10" 2.50 8"6/30/2019 2.5 9/27/2020 3S-612 50103207770000 2181110 43" 0.75 8" 6/30/2019 3.5 9/27/2020 3S-613 50103207350000 2160200 22" 0.75 8" 6/30/2019 1.7 9/27/2020 DSR-4/9/2020 VTL 4/10/20 WELL LOG TRANSMITTAL #905810861 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 3Q-22 Run Date: 6/30/2019 195186 31131 August 22, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 30-22 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22625-00 RECEIVED AUG 2 7 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: Tat/�'/ Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 $ 2019 REPORT OF SUNDRY WELL OPERATIONS ®f1r_r%r% 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations utdown Lj Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑� Re-enter Susp Well ❑ Other: _Tubing patch_ ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. DevelopmentEx ❑ Stratigraphic ❑ Exploratory p ry ❑ Service ❑ 1 195-186 3. Address: 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50-029226250000 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025512 KRU 3Q-22 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field/Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,295 feet Plugs measured feet true vertical 6,446 feet Junk measured feet Effective Depth measured 10,012 feet Packer measured feet true vertical 6237 feet true vertical feet Casing Length Size MD TVD Burst Collapse Conductor 84' 16" 121' 121' Surface 5,739' 7.625" 5777' 3774' Production 9802' 5.5" 9843' 6111' Production 436' 4.5" 10,279 6434' Perforation depth Measured depth 9946 - 10,061 feet True Vertical depth 6187-6273 feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 9842' 6109' Packers and SSSV (type, measured and true vertical depth) Seal Assembly Baker GB -H22 9840' 6108' Patch packer w/ stinger Paragon II Packer 9810 6085' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA NA NA NA Subsequent to operation: NA NA NA NA NA 14.Attachments (required per 20 AAC 25.070, 25.o7t, s 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory ❑ Development❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑� Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Authorized Name: - Sara Carlisle Contact Name: Rachel Kautz/Sara Carlisle Authorized Title: Well Integrity Supervisor Contact Email: 22549ra)conocoohillios.com Authorized Signatur 4vm cro W — �1 G1 S — I I 659-7126 V Date. oC Contact Phone: v /- y� :////CJI y Form 10-404 Revised 4/2017 le ` ` !' "/' " 3gDMSLbA�JUN 2 8 2019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 25, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, R&CE RiED JUN 2 E 2019 AOGCC Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in producer KRU 3Q-22 (PTD 195-186). Please contact Rachel Kautz or me at 659-7126 if you have any questions. Sincerely, Sara Carlisle Well Integrity Supervisor ConocoPhillips Alaska, Inc. Date Event Summary Executive Summary :4biKC7ARI 611101 P1 Kuparuk producer 3Q-22 required a tubing patch to cover a tubing leak located at 9828'. The tubing patch was set across the leak site and subsequent testing passed to confirm tubing integrity was restored. DRIFTED 2.29" DUMMY PATCH TO D -NIPPLE @ 9832' RKB. SET 2.29" P2P (#CPP287033), SPACER PIPE, AVA NO-GO STINGER MID-ELEM @ 9810' RKB. SET TEST TOOL IN P2P. MITT & CMIT IA x T TO 2500 (PASS). PULLED TEST TOOL. JOB COMPLETE. ED TBG TO 2500 PSI FOR 15 MIN. (PASSED MIT CRITERIA); PULLED TEST TOOL @ 9807' JOB COMPLETE. 11T -IA to 2500 PSI. 41TIAL T/I/0= 1000/475/0 EST= 1100/2500/0 (2.3 bbls) 5 MIN= 1100/2425/0 0 MIN= 1100/2400/0. PASS. MIT -T TBG to 2500 PSI. INITIAL T/I/0= 1050/300/0 TEST= 2550/325/0 (1.8 BBLS). 15 MIN= 2260/370/0. BUMP TBG UP: INITIAL= 2250/325/0 TEST= 2550/325/0 (.14 BBLS) 15 MIN= 2505/325/0. GOOD TEST. WELL LOG TRANSMITTAL #905684239 30 93 2 To: Alaska Oil and Gas Conservation Comm. May 23, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue Suite 100 $� "?r. fn p u: Anchorage, Alaska 99501 JUN 2 7 2019 RE: Multi Finger Caliper (MFC) and Leak Detect Log: 3Q-22 Run Date: 5/7/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS ANC@halliburton.com 30-22 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22625-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 0 FRS_ANC@halliburton.com Date: ��% Signed: THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Roger Mouser Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3Q-22 Permit to Drill Number: 195-186 Sundry Number: 319-209 Dear Mr. Mouser: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v✓ W v✓. aogc c.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner of %b DATED this Z day of May, 2019. �Bp�S 01 0Iloll STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 �> 1 APR 2 ? 2njg 1. Type of Request: Abandon LJ Plug Perforations ❑ Fracture Stimulate LJ Repair Well Ld 'p, Operations shutdown LJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ -Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑� Other. SC repaQ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development O Stratigraphic ❑ Service ❑ • 195-186 3. Address: 6. API Number: 1 P. O. Box 100360, Anchorage, Alaska 99510 50029226250000 • 7. If perforating: N/A 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3Q-22 Will planned perforations require a spacing exception? Yes ❑ No ❑ NA 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025512 0 1 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,295' 6,446' 10012' 6237' Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 16" 121' 121' Surface 5,739' 7.625" 5,777' 3774' Production 9802' 5.5" 9843' 6111' Production 436' 4.5" 10,279' 6434' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9946'-10061' 6187'-6273' 3.500" L-80 9,840' Packers and SSSV Type: No Pkr-Seal Assy- Baker GBH22 Seal Assy Packers and SSSV MD (ft) and TVD (ft): No SSSV- CAMCO DS NIPPLE GBH -22 MD=9840 and TVD= 6108'. Cameo DS MD= 495' and TVD= 495' 12. Attachments: Proposal Summary ❑' Wellbore schematic O 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 8/1/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG Q GSTOR ❑ SPLUG ❑ 16. Verbal Approval Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Roger Mouser Contact Name: Roger Mouser / Roger Winter Authorized Title: Well Integrity Field Supervisor Contact Email: N1927@mnomphillips.com Contact Phone: 907-659-7506 Authorized Signature: Pv Date: b COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: f✓� Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance L_I Other: P/70t-bCYC ICUr"-C-h%PI-0cccivr- . Post Initial Injection MIT Req'd? Yes ❑ No M-� MAY 0 2 2019 /L RBDMSkP Spacing Exception Required? Yes ❑ No Subsequent Form Required: lQ 9U ¢ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: / amt/. 5/l // 9 ORIGINAL " Form 10-403 Revised4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 20 2019 Commissioner Hollis S. French Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 3Q-22 (PTD 195-186) to excavate and repair surface casing leak. Please contact Roger Winter or myself at 659-7506 if you have any questions. Sincer ly, Ai Roger Mouser Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Attachments: 10403 application for 3Q-22 SC repair 3Q-22 Well bore schematic Proposal summary PROD WELLNAME 3Q-22 WELLBORE 3Q-22 AChKUP ConocoPh)Ihps Well AtWbutes Max Angle&MD TD MNam¢ WaIIWreA -MIM WNI reS tua d(') MB B) int Btm Most Alaska, Inc. KUPARUKRIVERUNIT 500292262500 PRQD 5.39 6,346.59 10,295.0 Comment H25(Wand pale Avenstan End DMe KBG.Val RIg havease Date SSS,: NIPPLE 140 12(1312013 Lasl M. 1213011995 GGG2,1115211ae."'. I Last Tag "not" Anastasia- DnghgeMS End Dale WalRon, IaatMW By Lest Tap-RKb(Est. 49' or Fill) 10,Ot2.0 4/142019 3012 Tembaej ' ...... "' -"" Last Rev Reason Mr.asiin End Date Wellbrefast MW By Rea Reason: Set Cal Scantling Valve, Real GLV. B Manaified Tbg 4/14/2019 3012 umbaej ..ED al.a Leak Casing Strings Casing Description OD(In) ID (ml Tnp(nKal sN Depth (flag) sal D¢Pln rtvD)....e(I Grade Top TMead CONDUCTOR 16 15.06 37.0 121.0 121.0 62.50 H40 Welded Coning Dnaigs-OD(inI ID(Inl.3 Top(nael semeptn(pKe1 sal Dreln(IVW Wln.en it Topmrad SURFACE 7518 jurne 637.9 5,776.5 3774.4 29.70 L40 BTCMOD Casing Description .01(in la(Inl T0p(RKBI sM Deentalath Sal OeplM1 nVDf... WlM1en (I.., Grade Top Txread .I1DOCTOR:S7.G1QIA 2) PRODUCTION 5.5"x45' 51/2 477 30.1 js 10.279.0 6.430.4 15.50 L-80 LTC-MOD WPPLE: 1953 Tubing Strings Tuhing Oesc�ipli0n Slring Ma... ID(in) Top (MKBI Sel DeplI lit. Set Depth(TVDI(... Wi Tbat) Gmhe Toptonneclion TUBI NG 3.5"x2875" 3112 2.99 3).0 9,8422 6,109.2 9.30 L41 BUEBrd Completion Details ioP(NDI Top Incl Nomino GAS LIFT, 36931 Top (1Ks) (Hail V) bets Des Cam IS (in) 37.0 37.0 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 4963 494.1 5.91 NIPPIE CANDO DS NIPPLE 2.812 9.832.9 6102.2 41.93 NIPPLE CAMCO'IY NIPPLE 2.250 9,840.4 6,107.8 41.77 SEAL ASSY BAKER 6BH-22 LOCATOR SEAL ASSEMBLY 3.000 9,8412 6,1084 41.76 SBE BAKER SBE 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) SURFACE 37.45.n&a Top("") Togincl Top(nKe1 nt B) (•I Den Cam Run Dafe 10 (1n1 9.811.0 6.086.0 42.36 LEAK Slickline lderd4ied Leak In Tbg 4/14/2019 0.000 9.833.0 41.92 2.25"Cat 2.z5.OI.Caandmgvinve 4114)2"19 O.OW ws uEr;a+sss ,102.3 Standing Vahe perforations & Slots glom Den TOP BV01 run QVI) "xotam Top page) Ban Ift"I (aKBI (flKB) Brand! Zone Dise 1 Tyq Can 9,946.0 9,960.0 6187.2 6,197.) C-0, 3Q-22 11102007 6.0 APERF 2118' Pwerspiral Enerlat, GAS LIFE 8,101.4 45 deg phase 9,978.0 9,993.0 6211.2 6.222.5 A,3. 3Q-22 V12QOM 8.0 APERF 2118' Enefjetselallerna0ng DP & BH Ghgs, 0 deg phasing, H-90 deg orient rant Iowside 10,000.0 10,017.0 6.227] 6140.5 A-2,30-22 9262005 6.0 APERF 21 M' PlevaSpiall EJ, 45 deg phasing Can"', 9,225.6 10,031.0 10,061.0 6,251.0 6,273.4 AR 30-22 2/811996 4.0 WERE 180 deg. phasing: Oriented RP) 90 deg FI Lassitude: 2 118'EnerJet Mandrel Inserts a, OAS IFT.a.4e H TW (/VDI Whilelean Su:e TRO Run Tap 1flKB1 1flKBl Make Mcdel ODge) Sees (in) (pini) Ranges, Com 3,693.1 2,686.9 BANCO ft 0,156 1,357A 1),12009 LEAK:981tp 2 6,4 .5 4. AM 0 0.1 1, 7. 512712ODS-_ MKBMMI 3 8,101.4 4,995.0 CAMCO 0.180 1363.0 411412019 4 9,225.6 5703.5 CAMCO 0.188 13470 1/172007 5 9,)94.8 6, 74.1 CAMCO 0.188 0.0 10/4/2014 rvmPLE: sous z2s Gl gassing wxs: Notes: General & Safety end Dam Annomti0o a,eup 1/512009 NOTE VIEW SCHEMATIC w1Alanes SCxeene,19D Sn2013 NOTE: PULLED ERODED OV FROM 8795' WATCH FOR EROSION ISSUES gEPL A5gY: 9,8W A &162014 NOTE: GLM '$ARE 27/8" g0E 9.Bf1 t As."age66a6WO- APERF; suse.9iD- APERF: 10,00 BIBIAO].0- (PERF; 1003141008I.0- PRODUCTION iS,eY: Sal. "gaga ConocoPhillips Alaska, Inc. Kuparuk Well 3Q-22 (PTD 195-189) SUNDRY NOTICE 10-403 APPROVAL REQUEST March, 2019 This application for Sundry approval for Kuparuk well 3Q-22 is for the inspection and repair of surface casing with a suspected surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in tubing 2. Remove the floor grate, well house, flow lines, and other equipment as necessary from around the wellhead. Remove gravel around well head and excavate to —24'. 4. Install nitrogen purge equipment for the conductor and OA (if needed) so that hot work maybe conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a low-pressure test (Open OA shoe) to confirm no fluid to surface. 9. Install anti -corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and return the well to production. 13. File 10-404 with the AOGCC post repair. ConocoPhillips Alaska, Inc. Kuparuk Well 3Q-22 (PTD 195-189) SUNDRY NOTICE 10-403 APPROVAL REQUEST April, 2019 This application for Sundry approval for Kuparuk well 3Q-22 is for the inspection and repair of surface casing with a suspected surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in tubing 2. Remove the floor grate, well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and excavate to --24'. 4. Install nitrogen purge equipment for the conductor and OA (if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a low-pressure test (Open OA shoe) to confirm no fluid to surface. 9. Install anti -corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and return the well to production. 13. File 10-404 with the AOGCC post repair. Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / (~.~'--/¢¢~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds [] Other COMMENTS: Scanned by: ~ianna vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Isl ~ ~ • . ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 18, 2009 ~:~.~~`~~~ aC~~ . ''t 20C~`~ ~~y.~ ~~ ~ ~ ~ `~' `~ ~ ~ Mr. Tom Maunder Alaska Oil & Ga.s Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • .3g , Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, 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 was pumped June 26~', 2009. The corrosion inhibitor/sealant was pumped June 30~' & July 16~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. ~ Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerel , ~ Perry Klein ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/18/09 3H. 31 & 3Q PAD Well Name API # PTD # Initial top o cement Vol. of cement um d Final top of cement Cement top off date Corrosion +nhibitor Conosion inhibitod sealant date ft bbls ft ~ al 31-07 500292154900 1860390 3' NA 3' NA 8.92 7/16/2009 3H-04 501032007600 1870760 30" NA 30" NA 13.6 7/16/2009 3H-08 501032008000 1870800 17" NA 77" NA 3.4 7/16/2009 3H-11 501032009100 1871240 27'.' NA 27" NA 6.37 7/16/2009 3H-19 501032009000 1871330 17" NA 17" NA 5.95 7/16/2009 3H-21 501032009400 1880080 8" NA 8" NA 1.27 7/16/2009 3H-23A 501032020401 1961860 6" NA 6" NA 1.27 ~ 7/16/2009 3H-24 50103202350U 1960150 6" NA 6" NA 1.27 7/16l2009 3H-31 501032020500 1940190 13" NA 13" NA ~ 2.97 7/16/2009 3H-33 501032057800 2081130 19" NA 19" NA 5.52 7/16/2009 3Q-03 500292222100 1911260 SF NA 5" NA 0.9 6/30/2009 3Q-06 500292168300 1861950 43' 6.30 26" 6/26/2009 6,8 6/30/2009 3Q-08A 500292168101 1971930 SF NA 6" NA 1 6/30/2009 3Q-09 500292167400 1861860 SF NA 6" NA 1 6/30/2009 3Q-10 500292167500 1861870 15' 2.50 18" 6/26/2009 6.8 6/30/2009 3Q-11 500292167600 1861880 37' 4.30 23" 6/26/2009 7 6/30/2009 3Q-14 500292166500 1861770 46' 5.10 23" 6/26/2009 7 6/30/2009 3Q-22 500292262500 1951860 SF NA 19" 6/26/2009 6 6/30/2009 - 01/11/08 ~~~~~~~~ N0.4550 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~#~ ~~~,~ `~~ `r~~1'U~ Attn: Christine Mahnken ATTN: Beth ~~B ~ '~ ~4~~' 333 West 7th Ave, Suite 100 ~~~~ Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 1J-164 11964565 INJECTION PROFILE = L 01/04/08 1 3Q-22 11970623 PRODUCTION PROFILE 01/04/08 1 3R-21 11964567 LDL 01106/08 1 3J-12 11970620 INJECTION PROFILE j - a 01/01/08 1 3H-106 11964562 PATCH EVALUATION/LDL UZ~ -! 01/01/08 1 1F-01AL1 11994591 FLOWING BHP SURVEY ~ 12/20107 1 2N-342 11964561 OILPHASE SAMPLER "} _ 12131107 1 2L-330 11970618 SCMT - a 12/30/07 1 2A-20 10194199 RST ~ - ~ 10/30/07 1 1 2X-19 11850441 RST - j~-~ l 07/09107 1 1 C, ~ ( Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1. Operations Performed: . RECEIVED STATE OF ALASKA. 'AN 2 3 2007 ALASKA Oil AND GAS CONSERVATION COMMISSION J e REPORT OF SUNDRY WELL OPERA TIONSlaska Oil & Gas Cons. COO1mission 11 rage Time Extension D D Abandon D Alter Casing D Repair Well D Pull Tubing D Operat. ShutdownD Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB41',Pad21' . 8. Property Designation: ADL 25512~ ALK 2553 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING PROD. CASING Perforation depth: measured 10295' feet true vertical 6446' feet measured 10175' feet true vertical 6358' feet Length Size MD 121' 16" 121' 5735' 7-5/8" 5776' 9802' 5-1/2" x 9843' 436' 4-1/2" 10279' Plug Perforations D Perforate New Pool D Perforate [2] r 4. Current Well Status: Development [2] Stratigraphic D Stimulate D Waiver D Other Re-enter Suspended Well 5. Permit to Drill Number: 195-186/· 6. API Number: 50-029-22625-00 . Exploratory D Service D 9. Well Name and Number: 3Q-22 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 121' 3774' 6111' 6434' Measured depth: 9946'-9960',9978'-9993', 10000'-10017', 10031'-10061' 5CANNED FEB O. 1 Z007 true vertical depth: 6187'-6198', 6211 '-6222', 6228'-6240', 6251'-6273' Tubing (size, grade, and measured depth) 3-1/2" 12.875", L-80, 9842' 19834' MD. Packers & SSSV (type & measured depth) no packer Cameo 'DS' nipple @ 495' 12. Stimulation or cement squeeze summary: Intervals treated (measured) ...... r0, ,t <t,._"...""...,..",,,J_-'-"'¡''f:'''..''''.'.J' ...,,.~. t 13. Treatment descriptions including volumes used and final pressure: none Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 1856 104 1768 363 15. Well Class after proposed work: Exploratory D Development [2] 16. Well Status after proposed work: Oil[2] GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Oil-Bbl 392 . 376 . Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Contact Printed Name Signature Guy Schwartz @ 265-6958 Guy Schw ~ NAL Casin Pressure Tubin Pressure 170 182 Service D WDSPL D Title Phone Wells Group Engineer Date 1_ ~ Z- - 0 :¡ Pre ared b Sharon Aflsu Drake 263-4612 BB :~ I) 2007 t'/ð~ ""þ /·z.1"'7 Æ~Ø;y . 30-22 Well Events Summary . DATE Summary 1/5/07 DRIFTED TBG WITH 15' x 2.125" STEM. TAGGED @ 10175' RKB, EST. 115' RATHOLE. 1/10/07 PERFORATED THE INTERVAL 9946'-9960' GUN DATA: 21/8" POWERSPIRAL ENERJET, 6 SPF, 45 DEG PHASING, API PEN: 27.2", API ENT: 0.32" SHUT IN AND FREEZE PROTECT UPON ARRIVAL. WHP PRIOR TO PERFORATION 650 PSI, HAD BUILT UP TO 700 PSI @ RIG DOWN. RECOVERED STRIP GUN WAS WARPED, INDICATING ALL SHOTS FIRED. 1/16/07 CATCHER SET @ 9833', PULLED GLV'S @ 9795' & 9226' RKB, 1" OV SET @ 9795' RKB. 1/17/07 PULL GLV'S @ 8101',3693' RKB, SET GLV'S @ 8101',9226' RKB, IN PROGRESS. 1/18/07 ATTEMPT TO GET INTO STA #2 w/ POCKET PUNCH. IN PROGRESS. 1/19/07 SET GLV'S @ 3693',6466' RKB, PULL CATCHER @ 9833' RKB. JOB COMPLETE. . . ConocoPhillips Alaska, Inc. KRU 3Q-22 ~ API: 500292262500 Well Tvpe: PROD Anç¡le (1ìJ TS: 41 deç¡ (1ìJ 9946 SSSV Tvoe: NIPPLE Oriç¡ Completion: 12/30/1995 Anç¡le (1ìJ TO: 43 dea ía) 1 0295 Annular Fluid: Last W/O: Rev Reason: TAG FILL, GLV C/O NIP (495-496, Reference Loa: Ref Loa Date: Last Update: 1/20/2007 00:3.500) Last Tao: 10175' TO: 10295 ftKB ~Date: 1/5/2007 Max Hole Anole: 65 deo (1ìJ 6347 TUBING DescriDtion I Size TOD I Bottom I TVD I WI I Grade I Thread (0-3661, I CONDUCTOR I 16.000 I 0 I 121 I 121 I 62.50 I H-40 I 00:3.500, 10:2.992) DescriDtion Size TOD Bottom TVD I WI I Grade I Thread SUR. CASING I 7.625 I 0 I 5776 I 3774 I 29.70 I L-80 I Gas Lift .l.šliilil..:*¡¡II1!I~1 Description Size rOD Bottom TVD I WI I Grade I Thread MandrelNalve PROD. CASING I 5.500 I 0 I 9843 I 6111 I 17.00 I L-80 I 1 (3693-3694. PROD. CASING I 4.500 I 9843 I 10279 I 6434 I 12.60 I L-80 I TUBING Size TOD Bottom TVD WI Grade Thread (3731-6434, 3.500 0 3661 2680 9.30 L-80 EUE 8RD MOD 00:3.500, 2.875 3661 3731 2716 6.50 L-80 EUE 8RD MOD 10:2.992) ... 3.500 3731 6434 4084 9.30 L-80 EUE 8RD MOD 2.875 6434 6504 4114 6.50 L-80 EUE 8RD MOD 3.500 6504 8070 4976 9.30 L-80 EUE 8RD MOD Gas Lift 2.875 8070 8139 5018 6.50 L-80 EUE 8RD MOD MandrelNalve 3.500 8139 9195 5685 9.30 L-80 EUE 8RD MOD 2 2.875 9195 9264 5726 6.50 L-80 EUE 8RD MOD (6466-6467, 3.500 9264 9764 6054 9.30 L-80 EUE 8RD MOD 2.875 9764 9834 6104 6.50 L-80 EUE 8RD MOD TUBING 3.500 9834 9842 6110 9.30 L-80 EUE 8RD MOD (6504-8070. 00:3.500. Interval TVD Zone Status Ft SPF Date TYDe Comment 10:2.992) 9978 - 9993 6211 - 6222 A-3 15 8 2/12/2000 APERF 2 1/8" Enerjet w/alternating DP & BH chgs, 0 deg phasing, +1-90 deç¡ orient from lowside Gas Lift 10000 - 10017 6228 - 6240 A-2 17 6 9/26/2005 APERF 2 1/8" PowerSpiral EJ, 45 deg MandrelNalve ohasina 3 10031 - 10061 6251 - 6273 A-1 30 4 2/811996 IPERF 180 deg. phasing; Oriented (+/-) (8101-8102. I ~~:~~:/ Lowside; 2 1/8" TUBING (8139-9195. St MD TVD Man Mfr Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv 00:3.500, Cmnt 10:2.992) 1 3693 2697 Camco KBMM GLV 1.0 BK 0.156 1357 1/19/2007 2 6466 4098 Camco KBMM GLV 1.0 BK 0.188 1363 1/19/2007 3 8101 4995 Camco KBMM GLV 1.0 BK 0.188 1379 1/17/2007 Gas Lift 4 9226 5704 Camco KBMM GLV 1.0 BK 0.188 1347 1/17/2007 MandrelNalve 5 9795 6076 Camco KBMM OV 1.0 BK 0.313 0 1/16/2007 4 (9226-9227, Deoth TVD TVDe DescriDtion 10 TUBING 495 495 NIP Camco 'OS' Nioole 2.812 (9264-9764, 9833 6104 NIP Camco '0' Nipple NO GO 2.250 00:3.500, 9840 6109 LOCATOR Baker 'GBH-22' 3.000 10:2.992) 9841 6109 SPACE OUT 2.992 9842 6110 SBE Ba ker 3.000 Gas Lift MandrelNalve 5 (9795-9796, TUBING (9764-9834. 00:2.875, 10:2.441) NIP (9833-9834, 00:2.875) LOCATOR (9840-9841, 00:3.500) Perf - - (9978-9993) - - - - Perf = = 10000-10017) - - - - Perf = = 10031-10061) - - - - - -- ) ) Mike Mooney Wells Group Team Leader Drilling & Wells Conoc~illips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 October 18, 2005 R£C O ~/Vf:f' CT2] Alaska 0:4 4 2005 h&Ga S Cons C Anchorage· Of11fr¡/sSion Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 30-22 (APD # 195-186) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforations operations on the Kuparuk well 30-22. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, j/{ . ¡L1l ()~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells SCANNED NOV 0 1 2005 MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONglaska Oil & Gas Cons. Commission Anchorage Abandon D Repair Well D Plug Perforations D Stimulate D Other U' Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate [2] Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [2] Exploratory D 195-1861 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22625-00 7. KB Elevation (ft): 9. Well Name and Number: Rig RKB 41', Pad 21' 3Q-22 8. Property Designation: 10. Field/Pool(s): ADL 25512, ALK 2553 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING PROD. CASING Perforation depth: ) ) RECEIVED OCT 2 4 Z005 measured 10295' 6446' feet feet feet feet true vertical Plugs (measured) Junk (measured) measured 10164' true vertical Length Size MD TVD Burst Collapse 80' 5735' 9802' 436' 16" 7-5/8" 5-1/2" 4-1/2" 121' 5776' 9843' 10279' 121' 3774' 6110' 6434' Measured depth: 9978'-9993',10000'-10020',10031'-10061' true vertical depth: 6211'-6222',6228'-6243',6251'-6273' r~BDMS BFl 0 CT 2 5 2005 Tubing (size, grade, and measured depth) 3-1/2" 12.875", L-80, 9842' MD. Packers & SSSV (type & measured depth) no packer SSSV= Cameo 'DS' Nipple @ 495' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 1112 32 1577 169 15. Well Class after proposed work: Exploratory D Development [2] Service D 16. Well Status after proposed work: Oil[2] GasD WAGD GINJD WINJ D 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: Oil-Bbl 354 356 Casinç¡ Pressure Tubinq Pressure 147 159 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Contact Printed Name Signature WDSPL D Mike Mooney @ 263-4574 Mike Mooney ~)(~ Title Phone Wells Group Team Lead . /. Date /1/ /2 ð ;;; .~ . . Prepared bv Sharon AI1tup~Drake 263-4612 ORIGINAL Form 10-404 Revised 04/2004 Submit Original Only ) 3Q-22 Well Events Summary ') Date Summary 09/21/05 [Perf] - CANCELLED OPS - PERFO WITH SPIROL ENERJET GUN ATTEMPTED - GUN COULD NOT PASS NIP @ 9833 -ID = 2.25". GUN HELD UP ON GLM @ 8101' WHILE RIH. OBSERVE BTM CHARGE (4TH FROM BTM) DISLOGDED SLIGHTLY. 09/26/05 [Perf] - PERFS - 10000 - 10020 FT MD (A2 SAND) WITH 2 1/8" PWR SPIRAL ENERJET GUN. NO PROBS RIH. WORK STRING FREE UP/DN UP TO 800 LBS OVERPULL AFTER SHOOTING. AT SURFACE OBSERVE BOTTOM 3 FT OF GUN DID NOT FIRE - ACTUAL PERF INTERVAL = 10000 - 10017 FT. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2287' FNL, 2026' FEL, Sec.17, T13N, R9E, UM At top of productive interval 1230' FSL, 1171' FWL, Sec.20, T13N, RgE, UM At effective depth At total depth 1065' FSL, 1114' FWL, Sec.20, T13N, RgE, UM Perforate _X Other_ 5. Type of Well: Development __X Exploratow~ Stratigraphic__ Service__ (asp's 516309, 6025787) (asp's 514264, 6018741) (asp's 514207, 6018576) 6. Datum elevation (DF or KB feet) RKB 62 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3Q-22 9. Permit number / approval number 195-186 10. APl number 50-029-22625 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 10295 feet 6446 feet Plugs (measured) Tagged Fill (1/14/00) @ 10192' MD. Effective depth: measured 10192 feet true vertical 6371 feet Junk (measured) Casing Length Size CONDUCTOR 121' 16" SURF CASING 5714' 7-5/8" PROD CASING 9781' 5-1/2" PROD CASING 436' 4-1/2" Cemented Measured Depth 275 Sx AS I 121' 1030 SxAS III & 370 G 5776' 160 Sx Class G 9843' . II II ti II True verticalDepth 121' 3774' 6110' 6434' Perforation depth: measured 9978 - 9993'; 10031 - 10061' true vertical 6211 - 6222'; 6251 - 6273' MAR 2 ? 2001 Alaska Oil & Gas Cons. Commission Anchorage rubing (size, grade, and measured depth) 2.875" & 3.5"; 6.5 & 9.3~, L-80, (in alternating 2-7/8 & 3-1/2" sections) Tubing @ 9842' MD. Packers & SSSV (type & measured depth) No Packer. Camco 'DS' @ 495' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiFBbl Prior to well operation 424 Subsequent to operation 473 Representative Daily Average Productionorlnjection Data Gas-Mcr Water-Bbl 226 27 293 51 Casing Pressure Tubing Pressure 185 186 15, Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 · Prepar~Cd by John Feirce 265-6471 ~ ,.% SUBMIT IN DUPLICATE4 3Q-22 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 1/14/00: RIH & tagged fill at 10192' MD. 2/12/00: MIRU & PT equipment. RIH w/perforating guns & shot 15' of 'A-3' perforations as follows: Added perforations: 9978 - 9993' MD Used 2-1/8" carrier & shot the perfs at 8 spf. POOH w/guns. Rigged down. Returned the well to production w/gas lift & obtained a valid well test. 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 Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1843' FNL, 2886' FEL, Sec. 9, T13N, R9E, UM At top of productive interval 1644' FNL, 2819' FEL, Sec. 16, T13N, R9E, UM At effective depth At total depth 1950' FNL, 2814' FEL, Sec. 16, T13N, R9E, UM 5. Type of Well: Development __X Exploratow__ Stratigraph Service__ (asp's 520699, 6031517) (asp's 520793, 6026442) (asp's 520799, 6026132) 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3R-26 9. Permit number / approval number 195-187 10. APl number 50-029-22626 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 8866 feet 6782 feet Plugs (measured) Tagged Fill (1/24/00) @ 8727' MD. Effective depth: measured 8727 feet true vertical 6685 feet Casing Length Size CONDUCTOR 121' 16" SURFACE CSG 5109' 7-5/8" PROD CSG 8399' 5-1/2" PROD CSG 401' 4-1/2" Junk (measured) Cemented 200 Sx AS I 920 Sx AS III, 320 Sx G 160 Sx Class G il ii Hi Measured Depth True vertical Depth 121' 121' 5161' 4O96' 8451' 6490' 8852' 6772' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 8540-8550';8592-8622' RECEIVED FEB 1;5 2001 6553 - 6561" 6590 - 6611' ' Alaska 0il & Gas Cons. ~;ommissior Anchorage 3.5"/2.875", 9.3#/6.5#, L-80, Tubing (in alternating OD size sections) to 6492' MD. Packers & SSSV (type & measured depth) No Packer. CAMCO CR LOCK, SET K-VALVE (#K319, 190 PSI @ 60 DEG.), SET SLIP-STOP ABOVE (GS) 3/21/2000 @ 514' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 478 Subsequent to operation 609 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 368 68 385 115 Casing Pressure Tubing Pressure 200 199 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Signed Date ~Z"7 ~/)t~ ( Prepare John Peirce 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 3R-26 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 10/24/99: Drifted & tagged fill @ 8739' MD. 10/26/99: MIRU & PT equipment. Added perforations: Reperforated: RIH w/perforating guns & shot 10' of Add perfs and 20' of Reperfs as follows: 854O- 855O' MD 8592 - 8612' MD Used 2-1/8" EJ carriers & shot the perfs at 4 spf & 180 degree phasing. POOH w/guns. Rigged down. 1/24/00: RIH & tagged fill @ 8727' MD. Returned the well to production w/gas lift and obtained a valid well test. THE MATERIAL UNDER THIS cOVER HAS BEEN MICROFILMED ON BEFORE JANUARY M PL A'T-E I A E L U 'N D W E R T H IS M ARK E R C:LORKMFILM.DOC ARCO Alaska, Inc. Post Office Box , ~0360 Anchorage Aiaska 99510-0360 Telephone 907 276 12t 5 April 9, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, First Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the first quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 1999. Annular Injection during the first quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-315 25326 100 0 25426 See Note #! below 25426 2L-325 8397 ~ 100 [ 0 8497 11883 20380 ] 2N-321A 27507 i 100 0 27607 0 27607 3K-23 15 ] 0 [ 0 15 0 15 3K-25 4202 ! 100 [ 0 4302 0 4302 1 1C-15 16695 ] 100 0 16795 0 ] 16795 2L-313 8554 ] 100 I 0 8654 0] 8654 ,Vote #1: Well # 2N-315. The previously re ported volume of 220 barrels was pumped into this annulus during the drilling of the well. This was the volttme required to flttsh and freeze protect the annulus during initial drilling operations, not a volume o.t'disposal fluids rejected prior to the receipt attthorization for annular injection. Total Volumes into Annuli for which bzjection Authorization Expired during the quarter [ Total Total h(1) Total h(2) . Total h(3) Volume Well Name Volume Volume ~ Volume Injected Status of Annulus 1C-12 34995 100 t 0 35095 Open, Freeze Protected 1C-13 26800 i 100 ! 0 26900 Open, Freeze Protected Additionally, to prevent any possible confusion regarding previous reports of volumes injected, and to insure that the State's records are in agreement with ARCO's, we would like to repeat and supplement information we provided with our letter of February 26,1999. The information below is only for those wells for which injection volumes may not have been properly reported at the time of injection. Again, these volumes are the same as those reported with our February 26th letter, and are only reported here again for the sake of clarity. ARCO Alaska. Inc. is a Subsi0iary of Atiantm Flichfieid Company AR3B-6003-C Ms. Wendy Mahan AOGCC First Quarter 1999 Annular Injection Report Page Two ] i Total I Total h(1) ~ Total h(2) Total h(3) Volume I Current Status of Well Name Volume , Volume Volume Injected Annulus i 100 0 16849 i Open. Freeze Protected 2A-22 16749 i ~ . 2F-19 20725 [ 100 i 0 20825 ] Open. Freeze Protected 3K-27 37173 [ 100 0 37273 Open. Freeze Protected 3K-26 33970 ] 100 0 34070 Open. Freeze Protected 1E-31 33645 ! 100 0 33745 Open, Freeze Protected 1E-32 45205 I 100 0 45305 Open. Freeze Protected 3Q-22 6245 ! 100 0 6345 Open. Freeze Protected 1Q-24 23158 ] 100 0 23258 Open. Freeze Protected 1Q-26 25931 I t00 0 26031 Open. Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Steve McKeever Well Files PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS 95-186 ARC 5 L~B~L ~---- 95-186 7207 95-186 ARC 5 PaGe: 1 Date: 02/25/98 RUN RECVD 1 04/26/96 04/11/96 i 04/11/96 10-407 a~COMPLETION DATE DAILY WELL OPS R IA/!~ /~-/ TO ~ Are dry ditch samples required? yes ~___.And received? Was the well cored? yes ~!._Analysis & description received? Are well tests required? { ~es .~ Received? Well is in compliance Initial COMMENTS .HCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 20, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3Q-22 (Permit No. 95-186) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3Q-22. If there are any questions, please call 263-4622. Sincerely, W. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad RECEIVED Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ Status of Well Classification of Service Well OIL ~] GAS r-~ SUSPENDED E~ ABANDONED [] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-186 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22625 4 Location of well at surface ~%-7~.~;:.%.;~¢-~w ..... .~,,~^-,.~.~.~ ~-~-~.~::--. 9 Unit or Lease Name 2287' FNL, 2026' FEL, Sec. 17, T13N, R9E, UM ..... ~ ~" .... Kuparuk River Unit At Total Dopth ~ *' 1 ~ Fiold an0 ~ool 1065' FSL, 1114' ~L, Sec. 20, T13N, R9E, UM KUPARUK RIVER 5 Elevation in feet (indi~te KB, DF, etc.) ~ 6 Lease Designation and Serial No. Ri¢ RKB 41', Pad 21'I ADL 25512 ALK 2553 12 Date Spudded 13 Date T.D. Reached 14 Dine Comp., Susp. or A~nd. 115 Water ~p~h, if of~hore 116 No. of Completions December 21, 1995 December 27, 1995 08-Feb-96 (~d)I NA feet MSLI 1 1, Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 DirectionalSu~ey 120 Depth where SSSV set 121 Thickness of ~rmaEost I 10295' MD & 6~6' ~D 10215' MD & 6387' TVD YES ~ NO~ NA feet MD = 1380' ss APPROX 22 Ty~ Electric or Other Logs Run ARC5/GR 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~ GRADE TOP B~ HOLE SIZE CEME~ 16" 62.58~ H-40 SURF. 121' 24" 275 sx AS 7.625" 29.7¢ L-80 SURF. 5777' 9.875" 1030 sx AS III Lead, 370 sx Class G Tail 5.5" x 4.5" 17¢/12.75¢ L-80 SURF. 10279' 6.75" 160 sx Class G 24 Perforations o~n to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD inte~al, size and numar) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9~2' in casing sealbore 10031'- 10061' MD 4 spf 6251'- 6273' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10031-10061' 193363¢ behind pi~, 8719~ in wetlbore left 13.5~ of 10/14 prop ~ perfs (14240¢ of ¢20/40, 172760¢ of ~12/18, 15082¢ of ~10/14) 27 PROOUCTION TEST Date First Production JMethod of O~ration (Flowing, gas lift, etc.) April 4, 1996I Rowing Date of Test Hours Tested ,PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO April 14, 1996 4.20 TEST PERIOD E 1 49 102 5 0 6~ ,. ~Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 193 1107 24-HOUR RATE E 850 582 29 =24° 28 CORE DATA Brief description of lithology, ~rosity, fractures, apparent dips and presen~ of oil, gas or water. Submit core chips. RECEIVEDORiGiNAL JUN 2 S 1996 Alaska Oil & Oas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE " 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 9946' 6187' Base Kuparuk C 9960' 6198' Top Kuparuk A 9968' 6204' Base Kuparuk A 10099' 6302' Freeze protected with diesel 31. LIST OF ATTACHMENTS Directional Survey, Daily Drilling History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 RECEIVED 5 199 Alaska Oil & Gas Cons Commission r SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-74007 Sidetrack No. Page Company ARCO ALASKA, lNG. Rig Contractor & No. PARKER- 245 Field KUPARUK RIVER UNIT Well Name & No. PAD 3Q/3Q#22 Survey Section Name ANADRILL BHI Rep. CHIP MILCHAK J~lrJl"L~l~ WELL DATA Target TVD (FO Target Coord. N/S Slot Coord. N/S -2287.00 Grid Correction 0.000 Depths Measured From: RKB Target Description Target Coord. E/W Slot Coord. E/W -2026.00 Magn. Declination 27.930 Calculation Method MINIMUM CURVATUI-, Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10mE] Vert. Sec. Azim. 196.12 Magn. to Map Corr. 27.930 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical _ Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment ~]_'_y_~_e_ .......... (_F_~ ..... _.._(_D__D)___._. ___ (__D_D) (FO (FO (FO (FO (Per 100 FO Drop (-) Left (-) MWD 0.00 0.00 0.00 0.00 0,00 0.00 0.00 TIE IN POINT ~EC-95 MWD 121.00 0.00 0.00 121.00 121.00 0.00 0.00 0.00 0.00 0.00 8"MACH 1C-AKO-1.4 DEG. 21 - DEC-95 MWD 264.00 0.00 0.00 143.00 264.00 0.00 0.00 0.00 0.00 0.00 ****GYRO**** 21 -DEC-95 MWD 360.00 2.00 207.00 96.00 359.98 1.65 -1.49 -0.76 2.08 2.08 ****GYRO**** 21 - DEC-95 MWD 452.00 4.75 226.00 92.00 451.81 6.53 -5.57 -4.23 3.19 2.99 ****GYRO**** -- -- 21 -DEC-95 MWD 561.97 7.71 210.43 109.97 561.13 17.62 -15.10 -11.24 3.08 2.69 -14.16 21 -DEC-95 MWD 655,33 10.57 215.65 93.36 653.30 31.77 -27.46 -19.41 3.19 3.06 5.59 21 -DEC-95 MWD 747.51 13.91 209.13 92.18 743.37 50.54 -44.01 -29.73 3,92 3.62 -7.07 21 -DEC-95 MWD 838.71 17.02 204.84 91.20 831.26 74.42 -65.71 -40.68 3.63 3.41 -4.70 22-DEC-95 MWD 933.01 20.24 203.57 94.30 920.61 104.24 -93.19 -53.00 3,44 3.41 -1.35 22-DEC-95 MWD 1025.01 24.79 201.45 92.00 1005.58 139.24 -125.74 -66.43 5.02 4.95 -2.30 -- 22-DEC-95 MWD 1115.50 28.85 200.12 90.49 1086.32 179.93 -163.92 -80.88 4.54 4.49 -1.47 22-DEC-95 MWD 1207.03 30.98 200.32 91.53 1165.65 225.45 -206.75 -96.66 2.33 2.33 0.22 EC-95 MWD 1300.42 32.87 201.01 93.39 1244.91 274.68 -252.95 -114.09 2.06 2.02 0.74 -_. 22-DEC-95 MWD 1391.51 33.16 202.55 91.09 1321.29 324.07 -299,03 -132.51 0.97 0.32 1.69 22-DEC-95 MWD 1482.02 34.98 201.58 90.51 1396.26 374.50 -346.02 -151.55 2.10 2.01 -1.07 ~ 22-DEC-95 MWD 1571.96 35.54 201.57 89.94 1469.70 426.18 -394.31 -170.64 0.62 0.62 -0.01 ~__ ~ '~' ' ' ' 22-DEC-95 MWD 1665.59 36.34 202.08 93.63 1545.51 480.86 -445.32 -191.07 0.91 0.85 0.54 ~ ~--~ O-t i"i'"! 22-DEC-95 MWD 1755.57 37.03 201.95 89.98 1617.66 534.33 -495.16 -211.22 0.77 0.77 -0.14 ~' ("3~- ~"~ 22-DEC-95 MWD 1850.40 40.61 200.09 94.83 1691.54 593.55 -550.65 -232.50 3.97 3.78 -1.96 22-D EC-95 MWD 1941.72 43.68 197.65 91.32 1759.24 654.74 -608.63 -252.28 3.81 3.36 -2.67 ~--, '~' 22-DEC-95 MWD 2035.37 47,27 197.96 93.65 1824.90 721.47 -672.18 -272.70 3.84 3.83 0.33 22-DEC-95 MWD 2129,58 50.41 199.16 94.21 1886.90 792.32 -739.41 -295.29 3.47 3.33 1.27 22-DEC-95 MWD 2221.73 53.37 198.81 92.15 1943.77 864.73 -807.96 -318.87 3.23 3.21 -0.38 " SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-74007 Sidetrack No. Page Company ARCO ALASKA, INC. Rig Contractor & No. PARKER- 245 Field KUPARUK RIVER UNIT Well Name & No. PAD 3Q/3Q#22 Survey Section Name ANADRILL BHI Rep. CHIP MILCHAK ~Je'~l~ WELL DATA Slot Coord. N/S -2287.00 Grid Correction 0.000 Depths Measured From: RKB Target TVD (FT) Target Coord. N/S Target Description Target Coord. E/W Slot Coord. E/W -2026.00 Magn. Declination 27.930 Calculation Method MINIMUM CURVATURL Target Direction (DD) Build\Walk\DL per: lOOff~ 30mE] lomE] Vert. Sec. Azim. 196.12 Magn. to Map Corr. 27.930 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-~'- DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (F'D (FT) (Per lO0 FT) Drop (-) Left (-) -- 22-DEC-95 MWD 2315.76 56.26 199.13 94.03 1997.95 941.48 -880.63 -343.85 3.09 3.07 0.34 8"MACH 1C-AKO-1.4 DEG. -- ~ .~EC-95 MWD 2406.59 59.26 198.57 90.83 2046.39 1018.21 -953.33 -368.66 3.34 3.30 -0.62 -- 22-DEC-95 MWD 2497.17 59.21 198.91 90.58 2092.73 1095.96 -1027.04 -393.67 0.33 -0.06 0.38 22-DEC-95 MWD 2591.07 58.71 199.35 93.90 2141.15 1176.30 -1103.05 -420.03 0.67 -0.53 0.47 -- -- 22-D EC-95 MWD 2866.86 61.94 197.14 275.79 2277.68 1415.70 -1330.59 -494.97 1.36 1.17 -0.80 22-DEC-95 MWD 3143.64 59.80 196.92 276.78 2412.41 1657.43 -1561.75 -565.78 0.78 -0.77 -0.08 22-DEC-95 ........... MWD 3419.08 57.72 197.36 275.44 2555.25 1892.88 -1786.78 -635.17 0.77 -0.76 O. 16 ~_ c... 22-DEC-95 MWD 3698.14 60.06 196.62 279.06 2699.43 2131.76 -2015.26 -704.96 0.87 0.84 -0.27 ~ (:Z:. 22-DEC-95 MWD 3972.37 57.56 195.85 274.23 2841.43 2366.33 -2240.47 -770.56 0.94 -0.91 -0.28 o ~ 22-DEC-95 MWD 4250.85 59.24 197.42 278.48 2987.35 2603.49 -2467.71 -838.48 0.77 0.60 0.56 ~ --= Or~ 23-DEC-95 MWD 4528.99 57.04 198.44 278.14 3134.16 2839.59 -2692.46 -911.18 0.85 -0.79 0.37 ~'3 23-DEC-95 MWD 4804.28 58.06 1 94.06 275.29 3281.92 3071.80 -2915.41 -976.11 1.39 0.37 -1.59 3. 23-DEC-95 MWD 5083.06 60.71 193.82 278.78 3423.88 3311.53 -3148.25 -1033.89 0.95 0.95 -0.09 EC-95 MWD 5358.44 58.58 192.58 275.38 3563.04 3548.83 -3379.57 -1088.18 0.87 -0.77 -0.45 · 23-DEC-95 MWD 5635.47 60.35 195.04 277.03 3703.80 3787.21 -3611.24 -1145.17 1.00 0.64 0.89 23-DEC-95 MWD 5707.40 59.79 195.03 71.93 3739.69 3849.53 -3671.44 -1161.34 0.78 -0.78 -0.01 25-DEC-95 MWD 5882.21 59.92 191.94 174.81 3827.50 4000.51 -3818.41 -1196.59 1.53 0.07 -1.77 4 3/4"MACH 1XL-AKO-1.2 DEG. 25-D EC-95 MWD 6061.99 60.75 196.40 179.78 3916.51 4156.58 -3969.81 -1234.84 2.20 0.46 2.48 25-D EC-95 MWD 6346.58 65.39 195.80 284.59 4045.37 4410.24 -4213.53 -1305.15 1.64 1.63 -0.21 25-DEC-95 MWD 6534.31 62.75 192.96 187.73 4127.46 4578.96 -4377.02 -1347.12 1.96 -1.41 -1.51 25-D EC-95 MWD 6718.63 59.76 188.81 184.32. 4216.12 4739.83 -4535.64 -1377.71 2.55 -1.62 -2.25 25-DEC-95 MWD 6902.42 56.67 188.97 183.79 4312.92 4894.79 -4689.97 -1401.84 1.68 -1.68 0.09 26-DEC-95 MWD 7087.38 53.97 190.73 1 64.96 4418.16 5045.95 -4639.81 -1427.82 1.66 -1.46 0.95 __ 26-DEC-95 MWD 7272.85 56.43 194.47 185.47 4524.02 5197.91 -4988.37 -1461.10 2.12 1.33 2.02 r . SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-74007 Sidetrack No. Page i llP'Itl I,::, Lllr~l Company ARCO ALASKA, INC. Rig Contractor & No. PARKER- 245 Field KUPARUK RIVER UNIT Well Name & No. PAD 3Q/3Q#22 Survey Section Name ANADRILL BHI Rep. CHIP MILCHAK ~r~r~~ WELL DATA Target TVD (ET) Target Coord. N/S Slot Coord. N/S -2287.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ Target Description Target Coord. E/W Slot Coord. E/W -2026.00 Magn. Declination 27.930 Calculation Method MINIMUM CURVATURL Target Direction (DD) Build\Walk\DL per: lOOft[~ 30m[~ 1Omu Vert. Sec. Azim. 196.12 Magn. to Map Corr. 27.930 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (F'D (FT) (FT) (Per 4CC F'r)Drop (-) Left (-) 26-DEC-95 MWD 7549.71 55.06 196.67 276.86 4679.87 5426.71 -5208.79 -1522.48 0.82 -0.49 0.79 4 3/4"MACH lXL-AKO-1.2 DEG. -- .)EC-95 MWD 7731.51 57.27 195.23 181.80 4781.10 5577.70 -5353.98 -1563.95 1.38 1.22 -0.79 __ 26-DEC-95 MWD 7914.46 54.30 194.51 182.95 4883.96 5728.94 -5500.18 -1602.79 1.66 -1.62 -0.39 26-DEC-95 MWD 8099.93 52.82 192.83 185.47 4994.13 5878.00 -5645.14 -1638.07 1.08 -0.80 -0.91 --. 26-D EC-95 MWD 8283.81 50.05 195.25 183.88 5108.76 6021.64 -5784.60 -1672.88 1.82 -1.51 1.32 26-DEC-95 MWD 8470.16 50.21 191.66 186.35 5228.24 6164.47 -5023.66 -1706.15 1.48 0.09 -1.93 26-DEC-95 MWD 8654.21 50.05 194.06 184.05 5346.23 6305.48 -6061.36 -1737.58 1.00 -0.09 1.30 _ 26-DE0-95 MWD 8828.21 51.29 199.72 174.00 5456.56 6439.96 -6190.03 -1776.71 2.61 0.71 3.25 3==, .~ Z 26-DEC-95 MWD 9024.59 51.14 197.20 196.38 5579.59 6592.88 -6335.21 -1825,18 1.00 -0.08 -1.28 ~' 26-DEC-95 MWD 9208.67 52.65 200.49 184.08 5693.20 6737,53 -6472.24 -1871.99 1.63 0.82 1.79 26-DEC-95 MWD 9389.98 54.13 197.89 181.31 5801.34 6882.84 ~609.68 -1919.79 1.41 0.82 -1.43 26-DEC-95 MWD 9482.86 50.82 196.60 92.88 5857.90 6956.47 -6680.01 -1941.65 3.73 -3.56 -1.39 26- D EC-95 MWD 9575.58 47.09 197.38 92.72 5918.78 7026.38 -6746.89 -1962.05 4,07 -4.02 0.82 := ... EC-95 MWD 9874.00 41.1 0 199.30 298.42 6133.01 7233.77 -6943.96 -2027.14 2.08 -2.01 0.65 27-DEC-95 MWD 10040.06 41.50 198.99 166.06 6257.77 7343.22 -7047.49 -2063.08 0.27 0.24 -0.19 27-DEC-95 MWD 10207.69 42.81 197.61 167.63 6382.04 7455.63 -7154.31 -2098.39 0.98 0.78 -0.82 .__ 27-DEC-95 MWD 10295.00 42.81 197.61 87.31 6446.09 7514.94 -7210.86 -2116.34 0.00 0.00 0.00 CLO.DIST=7515.01 'AZI= 198.36 -- RE"lIVED _: 4/12/96 ARCO ALASKA INCORPORATEDj Page: 1 WELL SUM_MARY REPORT UN ~ $ 1996 Alaska Oil & Gas Cons. COI?~J~JOP WELL:3Q-22 RIG:PARKER 245 WI: 55% SECURITY:0 WELL ID: AK8373 AFC: AK8373 TYPE: AFC EST/UL:$ OM/ STATE :ALASKA API NUMBER: 50-029-22625-00 AREA/CNTY: NORTH SLOPE EAST OM FIELD: KUPARUK RIVER UNIT SPUD:12/21/95 START COMP: BLOCK: FINAL: 12/18/95 (1) TD: 121' (121) SUPV:DL DAILY: 12/19/95 (2) TD' 121'( 0) SUPV:DL DAILY: 12/20/95 (3) TD' 121' ( 0) SUPV: DL DAILY: 12/21/95 ( 4) TD: 121'( 0) SUPV:GR DAILY: 12/22/95 ( 5) TD: 1660' (1539) SUPV: GR DAILY: 12/23/95 ( 6) TD: 5255' (3595) SUPV: GR DAILY: 12/24/95 ( 7) TD: 5790'(535) SUPV:GR DAILY' MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG Move utility module and ball mill Oliktok staging area. Prep to move rig module off 3R pad. $24,123 CUM: $24,123 ETD: $0 EFC: $24,123 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG Move rig module off 3R. Shut down. Phase 3 conditions. Visibility 0-0. WOW. $70,483 CUM: $94,606 ETD: $0 EFC: $94,606 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MOVING TO 3Q PAD, WELL 22 Phase 3 conditions. WOW. Prepare drilling module to move from 3R pad. Clean road and access to 3Q pad. Move drill module to 3Q pad. $29,886 CUM: $124,492 ETD: $0 EFC: $124,492 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 PICKING UP DP, STAND IN DERRIC Rig up. Accept rig @ 2100 hrs. 12/20/95. Nipple up diverter system. $70,921 CUM: $195,413 ETD: $0 EFC: $195,413 MW: 9.0 PV/YP: 12/16 APIWL: 10.8 REDUCE MUD WT TO 9.5, POOH Finish PU drillpipe. Function test diverter. Drill to 150', losing returns. Fill annulus with water until losses stabilize. Check surrounding wells, no signs of mud reaching the surface; current well is on 12.5' spacing between an injector and producer. Drill to 1660', weight up mud to 10.0 ppg. Lose returns again. POOH to 600' and re-establish circulation. $91,568 CUM: $286,981 ETD: $0 EFC: $286,981 MW: 9.5 PV/YP: 18/18 DIRECTIONAL DRILLING 9-7/8" HO Drill 9-7/8" hole from 1660' to 5255' $81,537 CUM: $368,518 ETD: $0 EFC: AP IWL' 7.6 $368,518 MW: 9.5 PV/YP' 14/14 APIWL: 6.8 CIRCULATE 7-5/8" CASING Directional drill 9-7/8" hole from 5255' to 5790' Held safety meeting. Run 7-5/8" casing. $79,435 CUM' $447,953 ETD. $0 EFC' $447,953 4/12/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 12/25/95 ( 8) TD: 5790' ( 0) SUPV: GR DAILY: MW: 8.4 PV/YP: 3/ 1 APIWL: 20.0 TEST BOPE Cement 7-5/8" casing. Casing stuck off hanger. Did not bump plugs. Test BOPE to 300/3000 psi. $217,488 CUM: $665,441 ETD: $0 EFC: $665,441 12/26/95 (9) TD- 8067' (2277) SUPV: GR DAILY- MW: 8.8 PV/YP: 5/ 2 APIWL: 14.4 DRILLING 6-3/4" HOLE @ 8067' F.I.T. 8.4 ppg mud, 3775' tvd, 820 psi surface pressure. Directional drill 6-3/4" hole from 5900' to 8067' (2167'). $74,628 CUM: $740,069 ETD: $0 EFC: $740,069 12/27/95 (10) TD- 9825' (1758) SUPV: dL DAILY: MW: 10.7 PV/YP: 13/11 APIWL: 4.8 DRILLING Directional drill and MWD survey from 8067' to 9713'. Had gas to surface. Shut down. Monitor well. Increase mud weight. Shut down. Monitor well. No flow. Drill from 9713' to 9825' $89,548 CUM: $829,617 ETD: $0 EFC: $829,617 12/28/95 (11) TD:10295' (470) SUPV:DL DAILY: MW: 10.7 PV/YP: 16/11 APIWL: 4.2 PREP TO RUN CASING Directional drill from 9825' to 10,295' RU to run 4-1/2" and 5-1/2" casing. $85,942 CUM: $915,559 ETD: $0 EFC: $915,559 12/29/95 (12) TD:10295' ( 0) SUPV:DL DAILY- MW: 8.6 PV/YP: 0/ 0 APIWL: 0.0 FREEZE PROTECT ANNULUS Run 4-1/2" and 5-1/2" casing. Cement casing. Freeze protect annulus. $180,783 CUM' $1,096,342 ETD: $0 EFC: $1,096,342 12/30/95 (13) TD:10295' ( 0) SUPV:DL DAILY: MW: 8.6 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Freeze protect annulus. Test casing and BOP to 3500 psi for 30 min. RIH with 3-1/2" completion equipment. Freeze protect annulus. Test tubing to 2500 psi. Test annulus to 2500 psi. Release rig at 0600 hrs. 12/20/95. $169,682 CUM: $1,266,024 ETD: $0 EFC: $1,266,024 End of WellSummary for Well:AK8373 RECEIVED JUN 2 5 1996 Alaska 011 & Gas Cons. Commissior~ Anchorage ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(3Q-22(W4-6)) WELL 3Q-22 DATE O2/08/96 DAY 2 JOB SCOPE PERFORATE, PERF SUPPORT DAILY WORK PERF 'A' SAND OPERATION COMPLETE YES Initial Tbg Press ! 400 PSI I ISUCCESSFUL YES JOB NUMBER 0115961505.6 UNIT NUMBER KEY PERSON i SUPERVISOR WARNER PAIGE Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSII 500 PSII 500 PSI Final Tbg Press 0 PSI Initial Inner Ann 0 PSI DAILY SUMMARY ! PERF'A' SAND INTERVAL 10031'-10061' USING 2-1/8" ENERJET W/BH CHARGES, 4SPF, 180 DEG PH, ORIENTED +/- 90 DEG F/ I j LOWSIDE. NO WHP INCR NOTED. I TIME 11:00 12:30 13:30 14:00 16:15 17:00 18:00 19:00 19:45 LOG ENTRY MIRU SWS / APC DHP HELD SAFETY MTG - COLD WEATHER PRECAUTIONS PT LUB TO 4000#; TEST OK. RIH WGUN #1 - WGT, CCL, 2-1/8" EJ W/BIG HOLE CHARGES, 2 SPF, 0 DEG PH, ORIENTED 90 DEG CW F/LOWSlDE TO SHOOT 10031'-10061' PER GR/RES DATED 12/28/95 CABLE BACKLASHED; HAD TO REPAIR. ON DO'FI-OM AND TIED IN; BLEED WHP TO 0#. FIRED GUN#1; POH. AT SURF W/GUN#1; WHP = O# PT LUB TO 3000¢; TEST OK. RIH W GUN #2 - WGT, CCL, 2-1/8" EJ W/BIG HOLE CHARGES, 2 SPF, 0 DEG PH, ORIENTED 90 DEG CCW F/LOWSlDE TO SHOOT 10031 '-10061' PER GR/RES DATED 12/28/95 FIRED GUN #2; POH. AT SURF W/GUN #2; NO WHP INCR. NOTED. 20:30 RDMO. RECEIVED JUN 2 5 loo¢ ARCO Alaska, Inc. Date: April 18, 1996 Transmittal #: 9358 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 3M-29 CDR 01/25/96 ~M:2-7- q,¢. ARC 5~ 1 2/28/95 Acknowledged: , DISTRIBUTION: 50-029-22641-00 5742-10295 Date: ~,~ ¢'j~ Mr. Vernon E. Pringle Jr. DeGIoyler and MacNaughton One Energy Square Dallas, TX 75206 ChapmanZu~pan NSK Wells Group NSK 69 Sharon AIIsup-Drake DS Development ATO- 1205 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Clifton Posey Geology ATO - 1251 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Well Job # NO. 10124 Company: Alaska Oil & Gas Cons Comm Field: Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Log Description Date Kuparuk (Open Hole) 96058 CDR 96008 ARC5 LIS BL RF Sepia DIR MWD Tape 960125 1 I I 1 4/11/96 951228 SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: . z) .aL, a IL ALASKA OIL AN~I GAS CONSERYATI~N CO]I~II$SION TONY KNOWL£$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 29, 1995 Michacl Zanghi Drill Site Develop Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3Q-22 ARCO Alaska, Inc. Permit No: 95-186 Sur. Loc.- 2287'FNL, 2026'FEL, Sec. 17, TI3N, R9E, 'UM~' Btmhole Loc. 953'FSL, 1138'FWL, Sec. 20, T13N, R9E, UM Dear Mr. Zanghi: ' Enclosed is thc approved application for permit to drill thc above referenced well. Thc permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations arc made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoc must bc given so that a representative of thc Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Jo~_~ Chairman BY ORDER OF THE COMMISSION df/Enclosures CC: Department of Fish & Game, Habitat Section xv/o encl. Department of Environmental Conservation w/o cncl. STATE OF ~ ALAS. ,,~ OIL AND GAS ~SERVATION COMMISSlu, PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill D lb Type of Well Exploratory [~ Stratigraphic Test D Development Oil X Re-Entry D Deepen D Service [~ Development Gas r~ Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 21' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25512, ALK 2553 4. Location of well at surface 7. Unit or property Name 1 I. Type Bond (see 20 AAC 25.025) 2287' FNL, 2026' FEL, Sec. 17, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1172' FSL, 1201' FWL, Sec. 20, T13N, R9E, UM 3Q-22 #U-630610 At total depth 9. Approximate spud date Amount 953' FSL, 1138' FWL, Sec. 20, T13N, R9E, UM 12/15/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3Q-13 10376' MD 953 ~ TD feet 11.7' ~ 20' feet 2544 6463' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum holeangle 57.7° Maxirnurnsurface 2280 psig At total depth (TVD) 3300 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantit~ of cement Hole Casin~l Wei~lht Grade Couplin~l Len~lth MD 'I'VD MD -rVD (include sta~le data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 9.875" 7.625" 29.7# L-80 LTC 5813' 41' 41' 5854' 3852' 950 Sx Arcticset III & 370 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOD 9879' 41' 41' 9920' 6117' 160 SxClassG 6.75" 4.5" 12.8# L-80 EUE8rdM 456' 9920' 6117' 10376' 6463' Top 500' above Kuparuk 1 9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Meas~ured depth True Vertical depth Structural ~'~ Conductor Surface '7 ~'~',.~ '.,,, ' · · Intermediate Production Liner ~, ~3¢i.,..; Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat D BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot BI Refraction analysis [~ Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify that% ~ ~) [thI foregoin~ is true and correct to the best of my knowledge Date(( Signed F'~-'~ Title Drill Site Develop. Su,v. ~ ~/ ¢ ) ' Commission Use Only Perr~t, NbLmber, _ I Ai~1 nuh'f~oer ._. ~ _ ,,.-"~ ..--, ,,-'- I Approval d.ate /_.,~ /~ _~..- I See cover letter for ~.~-/~ 15o- oz_¥- ~_..?__~,.~L~...~ I 1tl7-"'717~,I°therreciuirements ..... '' -- No Conditions of approval Samples required D Yes J~ No Mu~J log required BI Yes Hydrogen sulfide measures ,~ Yes r~ No Directional survey required ~ Yes ~] No Required working pressure for BOPE [--~ 2M ~ 3M BI 5M D 10M [~ 15M Other:Original Signed By David W, Johnston by order of Approved by Commissioner the commission Date t~ Form 10-401 Rev. 7-24-89 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3Q-22 , . , 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Parker #245: Install diverter system.' Drill 9-7/8" hole to 7-5/8" surface casing point (5,854')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (10,376') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" x 4-1/2" tapered casing string with polished seal bore as part of XO. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 5-1/2" x 4-1/2" casing to 3500 psi. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE and install production tree. Shut in and secure well. , Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 3Q-22 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Dril lina Fluid Svstem: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Weight up to TD General Notes: 10.7 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% 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/ff. This shows that formation breakdown would occur before a surface pressure of 2,280 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3Q-22 is 3Q-13. As designed, the minimum distance between the two wells would be 11.7' @ 20'. Drilling Area Risks- Risks in the 3Q-22 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.7 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ARCO ALASKA, Inc. Pad 3Q 22 slot #22 Kuparuk River Unit North Slope~ Alaska CLEARANCE REPORT by- Baker Hughes !NTEQ Your ref : 22 Version #4 Our ref : prop1397 License : Date printed : 13-Nov-95 Date created : 5-Sep-95 Last revised : 13-Nov-95 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on nTO 29 16.377,w149 51 0.781 Slot location is nTO 28 53.882,w149 52 0.372 Slot Grid coordinates are N 6025784.938, E 516304.813 Slot local coordinates are 2287.00 S 2026.00 W Reference North is True North Main calculation performed with 3-D Minimum Distance method Object wellpath PGMS <O-9397'>,,9, Pad 3N Closest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from M.D. 5-Sep-91 603.2 10175.8 10175.8 ARCO ALASKA, Inc. Pad 3Q 22 slot #22 Kuparuk River Unit North Slope, Alaska CLEARANCE REPORT b~ Baker Hughes !NTEQ Your ref : 22 Version #4 Our ref : prop1397 License : Date printed : 13-Nov-95 Date created : 5-Sep-95 Last revised : 13-Nov-95 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on n70 29 16.377,w149 51 0.781 Slot location is nTO 28 53.882,w149 52 0.372 Slot Grid coordinates are N 6025784.938, E 516304.813 Slot Local coordinates are 2287.00 S 2026.00 W Reference North is True North Main calculation performed with 3-D Minimum Distance method Object welLpath PGMS <O-8020'>,,1,Pad 3Q PGMS <O-10620'>,,Oliktok #1,Pad 3Q PGMS <O-9993'>,,2,Pad 3Q PGMS <0-10145'>,,5,Pad 3Q PGMS <0-9747'>,,6,Pad 3Q PGMS <0-9298'>,~7,Pad 3Q PGMS <O-9400'>~8,Pad 3Q PGMS <0-7990'>~9~Pad 3Q PGMS <0-8390'>,~10,Pad 3Q PGMS <0-7265'>,,11~Pad 3Q PGMS <0-7503'>~,12,Pad 3Q PGMS <0-8190'>,,13,Pad 3Q PGMS <0-8505'>,,14,Pad 3Q PGMS <0-7480'>,,15~Pad 3Q PGMS <0-7300'>,,16,Pad 3Q PGMS <0 - 9640'>,,3,Pad 3Q PGMS <0-7720'>,,4,Pad 3Q 3Q~21(C) Version #4,,21,Pad 3Q Closest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from M.D. 8-Apr-92 361.9 0.0 0.0 26-Aug-91 494.8 1650.0 1650.0 26-Aug-91 336.2 100.0 10032.2 26-Aug~91 261.9 240.0 240.0 26-Aug-91 236.2 100.0 120.0 26-Aug-91 211.5 100.0 425.0 26-Aug-91 184.8 500.0 10020.4 26-Aug-91 111.6 100.0 100.0 26-Aug-91 85.8 475.0 475.0 26-Aug-91 61.0 140.0 3740.0 26-Aug-91 36.7 375.0 375.0 26-Aug-91 11.7 20.0 300.0 26-Aug-91 13.0 300.0 300.0 26-Aug-91 37.8 180.0 10020.4 26-Aug-91 62.6 20.0 20.0 3-Apr-92 311.4 0.0 0.0 1-Sep-92 286.3 160.0 10041.3 lO-Nov-95 87.6 300.0 3920.0 iCreoted by : jones For: D PETRASH D~te plotted : 13-Nov-95 Plot Reference is 22 Version ~4. Coordinates ore in feet reference slot j[22. True Verb;col Dep[hs ore reference RKB (Porker ~245). [ARCO ALASKA, Inc. Structure : Pad .30 Field : Kuporuk River Unit Well : 22 Location : North Slope, Alaska ~o,~ ~ · ~o.oo E asf = = > 520 280 240 200 160 120 80 40 0 40 80 120 160 200 240 280 520 560 O 80_ .. 5o0 ~ ~ 31oo 5 )c ,/*°° o~ 80 _ ~700 J ~500 ~0 / O0 1 ~o 160 _ / / 200 _ 280 _ J 320 _ V 360_ ~ 3900 4oo ' ~20 _ ~0 ~ ~4~00 560 _ ,, ,,,,,,,,,,,,, 320 280 240 Scale 1 - 20.00 _ 80 -- _ 40 _o _ 40 _ 120 _ 160 _ 200 _ 240 _ 280 _ 320 _ 360 V _ 400 _ 440 _ A80 _ 520 _ 560 _ 600 ~40 200 160 120 80 40 0 40 80 120 160 200 240 280 320 ,560 East > 500 _ © © © - LO 04 0 _ aa 500 _ __ - ARCO ALASKA, Inc. Structure : Pad 30 Well : 22 Field : Kuparuk River Unit Location : North Slope, Alaska 1000_ 15oo_ -- 2000_ _ 25oo_ 3000_ - 3500_ - 4000_ -- 4500_ _ 5000_ 5500_ 6000_ 6500_ ICreoted by : jones FOX': D PETRASHi IDote plotted : 13-Nov-95 Plot Reference is 22 Version ~4. !Coordinates ore in feet reference slot N22. ITrue Vertical Depths ore reference RKB (Perker ~245). i S 16.12 DEG W 7392' (TO TARGET) <-- West ........ 2500 2000 1500 1000 500 0 500 SURFACE LOCATION: 2287' FNL, 2026' FEL SEC. 17, T13N, R9E Base Permafrost Top Ugnu Sands West Sok Sands Bose West Sok Sands 5OO g 500 On 0 0 - 0 _1000 _1500 _ _2000 _ _2500 - _3000 - _3500 RKB ELEVATION: 62' 7 5/8 Casing Pt - ? / TARGET LOCATION: _4000 { KOP TVD:300 TMD=300 DEP:O I ~ 3.00 ,172, Fs,, ,2o,, F~,L I 9 O0 R - ~ · SEC. 20, T13N, 9E 4500 I ~ 15.00 TA RG E-"~~ \ BUILD 30EG / mO' TVD 6191 V ~ 21.00 . TM~)~ 10020 - ~ 27.00 DEP=739: 5000 so~T, 710~ - k · WEST 2053 k. 39.00 - %' 4500 B/ PERMAFROST TVD=1602 TMD=1755 DEP=513 ~-.%1.OB _5~00 '-.~o EOC ~v0=~9~5 TMO=~2:5 OE~=~I _6000 ~ 1/ UG~LJ SNDS 1VD=25~2 1MD=3437 DEP=I~16 - ~ Be§in ,~gle Orop 6500 Bose HRZ[/ _7000 ~D=3652 TMD=5479 0EP=3643 '~-..........~ [-~ 7500 7 5/8" CSG PT TVa=3852 TMD=5854 DEP=3960 ~ TO LOC~: MAXIMUM ANGLE '"-.. 955' SL, 1138' /L I / ........ oo .oo DROP 2 40 DEG _ T/ UNIT A TVD=6212 TMO=10048 DER=7409 ~."~ ~,B/ KUP SNDS TVD=6510 TMD=10176 DEP=7492 TD -~/' J/2" CSG PT TVD=6463 TMD=t0376 DEP=7620 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 500 0 500 1000 1500 2000 2500 3000 .3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 Scale 1 · 250.00 Vertical Section on 196.12 azimuth with reference 0.00 N, 0.00 E from slot #22 t~JPARUK RIVER UNIT 20" DIVERTER SCHEMATIC I4 I 5 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PSI ANNULAR PREVENTER. DKP 11/9,94 7 , 6 5 4 3 2 13 5/8" 5000 PSi JOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUliC 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 UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 10. BOP STACK TEST 11. 12. 13. 14. 1. FILL BOP STACK AND MANIFOLD WITH WATER. 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 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. ~INUE TESTING ALL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3(X)0 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 Bo3-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRIllING POSITK:~q. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL A~ODATE 3-1/2" TO ~1/2" PIPE ODS. 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 P1PE RAMS 5. 13-5/8"-5000 PSI DRLG SPOOLW/ CHOKE AND KILL UNES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BliND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR ARCO Alaska, Inc, Post Office Box 100380 Anchorage, Alaska 99510-0380 Telephone 907 278 !215 November 20, 1995 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subiect: Annular Pumping Operations for Well KRU 3Q-22 Dear Mr. Johnston: The request for approval of annular pumping operations on KRU 3Q-22 is enclosed as part of the submitted Permit to Drill application. Please note that the request has been adjusted from previous applications to reflect the latest version of the AOGCC draft annular pumping regulations, 20 AAC 25.080. If you have any questions or input on the request for approval, please contact the Drilling Engineer, Denise Petrash at 263-4183, or myself at 265-6206. Drill Site Development Supervisor AR3B-6003-93 242-2603 ANNULAR PUMPING OPERATIONS WELL KRU 3Q-22 Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3Q-22 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the ddlling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be -sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped dudng the production cement job to cover the formation. It is requested that 3Q-22 be permitted for annular pumping occurring as a result of the drilling project on DS 3Q, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3Q surface casing shoes will be set +_200' vertical below the base of the West Sak into the heart of the shales. Please reference the enclosed directional ddlling plan for other formation markers in this well. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for ddlling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 3900 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 LTC 4790 4072 6890 5857 5.500 15.5 L-80 3 LTC-M 4990 4242 70'00 5950 ARCO ALASKA, Inc. Pad 3Q 22 slot #22 Kuparuk River Unit North Slope, Alaska CLEARANCE REPORT by' Baker Hughes [NTEQ Your ref : 22 Version Our ref : prop139? License : Date printed : 13-Nov-95 Date created : 5-Sep-95 Last revised : 13-Nov-95 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 29 16.377,w149 51 0.781 Slot location is n70 28 53.882,w149 52 0.372 Slot Grid coordinates are N 6025784.938, E 516304.813 Slot local coordinates are 2287.00 S 2026.00 W Reference North is True North Main calculation performed with 3-D Minimum Distance method Object weLLpath PGM$ <O-8020'>,,1,Pad 3Q PGMS <O-10620'>,,Oliktok #1,Pad 3Q PGMS <O-9993'>,,2,Pad 3Q PGMS <O-10145'>,,5,Pad 3Q PGMS <O-9747'>,,6,Pad 3Q PGMS <O-9298'>,,7,Pad 3Q PGM$ <O-9400'>,,8,Pad 3Q PGMS <O-79gO'>,,9,Pad 3Q PGMS <O-8390'>,,lO,Pad 3Q PGMS <O-7265'>,,11,Pad 3Q PGMS <O-7503'>,,12,Pad 3Q PGMS <O-8190'>,,13,Pad 3Q PGMS <O-8505'>,,14,Pad 3Q PGMS <O-7480'>,,15,Pad 3Q PGMS <O-7300'>,,16,Pad 3Q PGMS <0 - 9640'>,,3,Pad 3Q PGMS <O-7720'>,,4,Pad 3Q 3Q-21(C) Version #4,,21,Pad 3Q Closest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from M.D. 8-Apr-92 361.9 0.0 0.0 26-Aug-91 494.8 1650.0 1650.0 26-Aug-91 336.2 100.0 10032.2 26-Aug-91 261.9 240.0 240.0 26-Aug-91 236.2 100.0 120.0 26-Aug-91 211.5 100.0 425.0 26-Aug-91 184.8 500.0 10020.4 26-Aug-91 111.6 100.0 100.0 26-Aug-91 85.8 475.0 475.0 26-Aug-91 61.0 140.0 3740.0 26-Aug-91 36.7 375.0 375.0 26-Aug-91 11.7 20.0 300.0 26-Aug-91 13.0 300.0 300.0 26-Aug-91 3?.8 180.0 10020.4 26-Aug-91 62.6 20.0 20.0 3-Apr-92 311.4 0.0 0.0 1-Sep-92 286.3 160.0 10041.3 lO-Nov-95 8?.6 300.0 3920.0 PERMIT CHECKLIST COMPANY PROGRAM: exp [] dev/~ redrll [] serv [] ON/OFF SHORE ,,~.~ , ADMINISTRATION 1. 3. 4. 5. 6. '7. 8. 9. -- 10. ll. 12. 13. Permit fee attached .................. Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... ENGINEERING ~Y N Y N Y N .Y N .Y N Y N Y N Y N .Y N .Y N Y N .Y N Y N GEOLOGY' 14. Conductor string provided ............... 15. Surface casing protects all known USDWs'. ....... 16. C24T vol adequate to circulate on conductor & surf csg. 17. CM~ vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved.~Wf---/T 22. Adequate wellbore separation proposed. 23. If diverter required, is it adequate..'.'.'.'.'.'.'.'.' 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate .................... 26. BOPE press rating adequate; test to %C~'~ psig.~ 27. Choke manifold complies w/~_PI RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ......... ... 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ 34. Contact name/phone for weekly progress reports . . ./~.. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: 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. 7 * ALASKA COMPUTING CENTER . ****************************** . ............................ ........ SCHLUMBERGER ....... * ............................ ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 3Q-22 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22625-00 REFERENCE NO : 96008 * ALASKA COMPUTING CENTER * ****************************** . ............................ ....... SCHLUMBERGER ....... * ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 3Q-22 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22625-00 REFERENCE NO : 96008 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-APR-1996 13:50 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/04/ 4 ORIGIN : FLIC REEL NAME : 96008 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC., KUPARUK 3Q-22, API #50-029-22625-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/04/ 4 ORIGIN : FLIC TAPE NAME : 96008 CONTINUATION # : 1 PREVIOUS TAPE CO~94ENT : ARCO ALASKA INC., KUPARUK 3Q-22, API #50-029-22625-00 TAPE HEADER KUPARUKRIVER MWDLOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NOW~ER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3Q-22 500292262500 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 4-APR-96 BIT RUN1 96008 MILTON RIZEK BIT RUN 2 BIT RUN 3 17 13N 9E 2287 2026 52. O0 52. O0 21.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 5776.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-APR-1996 13:50 3RD STRING PRODUCTION STRING REMARKS: Well drilled 25-DEC through 28-DEC-95 with ARC5 only. Ail data was collected in a single bit run. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH MWD 5705.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: The depth adjustments shown above reflect no depth shifting as per Dave Shafer. $ STOP DEPTH 10295.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... ....... BIT RUN NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-APR-1996 13:50 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 i 1 4 68 0000000000 ROP MWD F/HR O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RPXXMWD OH~ff4 O0 000 O0 0 1 1 1 4 68 0000000000 RPX MWD OH~ O0 000 O0 0 1 1 1 4 68 0000000000 RPS MWD OHb~l O0 000 O0 0 1 1 1 4 68 0000000000 RPM MWD OH~ O0 000 O0 0 1 1 1 4 68 0000000000 RPD MWD OH~ O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10294.500 ROP.MWD -999.250 FET. MWD -999.250 GR.MWD RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPM.MWD RPD.MWD -999.250 DEPT. 10000.000 ROP.MWD 55.000 FET.MWD 0.978 GR.MWD RPXX.MWD 9.147 RPX.MWD 9.987 RPS.MWD 10.842 RPM.MWD RPD.MWD 11.279 DEPT. 9000.000 ROP.MWD 180.000 FET.MWD 0.236 GR.MWD RPXX.MWD 3.223 RPX.MWD 3.326 RPS.MWD 3.297 RPM. MWD RPD.MWD 3.137 -999.250 -999.250 94.894 11.317 153.458 3.196 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-APR-1996 13:50 PAGE: DEPT. 8000. 000 ROP.MWD RPXX.MWD 4. 029 RPX. MWD RPD.MWD 3. 972 DEPT. 7000.000 ROP.MWD RPJQY.MWD 3.270 RPX.MWD RPD.MWD 3.337 DEPT. 6000. 000 ROP.MWD RPX3~. MWD 2. 667 RPX. MWD RPD. MWD 2. 921 DEPT. 5705.000 ROP.MWD RPXX.MWD -999.250 RPX.MWD RPD.MWD -999.250 152.308 FET. MWD 4.255 RPS.MWD 180.000 FET.MWD 3.446 RPS.MWD 180.000 FET.MWD 2.899 RPS.MWD 0.181 4. 209 0.147 3.434 O. 567 2. 972 180.000 FET.MWD -999.250 -999.250 RPS.MWD -999.250 GR. MWD RPM.MWD GR. MWD RPM. MWD GR. MWD RPM.MWD GR. MWD RPM. MWD 112.157 4. 038 81.163 3.344 90. 936 2. 928 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION ' O01CO1 DATE : 96/04/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUM~JL~Y VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 5705.0 10295.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-APR-1996 13:50 PAGE: $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (~ORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) '. · ~JD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~4~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 28 -DEC- 95 4. OB MEMORY 10295.0 5705.0 10295.0 85 42.8 59.8 ************ RUN 1 DRILLED INTERVAL 5790' - 10295' HOLE ANGLE AT TD = 42.81 DEG @ 10295' RES TO BIT: 42.60'; GR TO BIT: 47.50' TD WELL @ 13:48 27-DEC-95 DATA FROM DOWNHOLE MEMORY $ TOOL NUMBER ARCS 475 6. 750 5776.0 LSND 10.70 39.0 2.990 70.0 3.190 70.0 20000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-APR-1996 13:50 PAGE: 6 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 F/HR O0 000 O0 0 2 1 1 4 68 0000000000 FET LW1 HR O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 RPXX LW1 OP~V~l O0 000 O0 0 2 1 1 4 68 0000000000 RPX LW1 OP~4~ O0 000 O0 0 2 1 1 4 68 0000000000 RPS LW1 OH2V~l O0 000 O0 0 2 1 1 4 68 0000000000 RPM LW1 OPfV~l O0 000 O0 0 2 1 1 4 68 0000000000 RPD LW1 OHP~4 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10294. 500 ROP. LW1 196. 040 FET. LW1 O. 317 GR. LW1 RPXX. LW1 4.198 RPX. LW1 4.366 RPS. LW1 4.380 RPM. LW1 RPD . LW1 4. 285 85. 278 4.310 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-APR-1996 13:50 PAGE: DEPT. 10000. 000 ROP. LW1 RPXX. LW1 9.147 RPX. LW1 RPD. LW1 11. 279 DEPT. 9000. 000 ROP. LW1 RPXX. LW1 3. 223 RPX. LW1 RPD . LW1 3.137 DEPT. 8000. 000 ROP. LW1 RPXX. LW1 4. 029 RPX. LW1 RPD. LW1 3. 972 DEPT. 7000. 000 ROP. LW1 RPXX. LW1 3.270 RPX. LW1 RPD . LW1 3 . 337 DEPT. 6000. 000 ROP. LW1 RPXX. LW1 2. 667 RPX. LW1 RPD. LW1 2. 921 DEPT. 5705. 000 ROP. LW1 RPXX. LW1 1 O00. 000 RPX. LWl RPD. LW1 1000. 000 55. 000 FET. LW1 9. 987 RPS. LW1 180. 000 FET.LW1 3 . 326 RPS. LW1 152. 308 FET. LW1 4. 255 RPS. LW1 180. 000 FET. LW1 3 . 446 RPS. LW1 180. 000 FET. LW1 2. 899 RPS. LW1 0.978 10. 842 0.236 3.297 0.181 4.209 0.147 3.434 0.567 2. 972 180. 000 FET.LW1 O. 000 1000. 000 RPS.LW1 1000. 000 GR. LW1 RPM. LW1 GR. LW1 RPM. LW1 GR. LW1 RPM. LW1 GR. LW1 RPM. LW1 GR. LW1 RPM. LW1 GR. LW1 RPM. LW1 94.894 11.317 153.458 3.196 112.157 4.038 81.163 3.344 90.936 2.928 9.542 1000.000 ** END OF DATA ** **** FILE TRAILER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/04/ 4 ORIGIN : FLIC TAPE NAME : 96008 CONTINUATION # : 1 PREVIOUS TAPE : COM2~FJFT : ARCO ALASKA INC., KUPARUK 3Q-22, API #50-029-22625-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-APR-1996 13:50 PAGE: **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/04/ 4 ORIGIN : FLIC REEL NAME : 96008 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC., KUPARUK 3Q-22, API #50~029-22625~00