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Home My WebLink About196-1481. 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: 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 9010 feet None feet true vertical 6760 feet None feet Effective Depth measured 8730' feet 8244'feet true vertical 6499'feet 6083'feet Perforation depth Tubing (size, grade, measured and true vertical depth) L-80 8311' MD 6137' TVD Packers and SSSV (type, measured and true vertical depth) 8244' MD 515' MD 6083' TVD 515' TVD 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: 4540' 3600' Burst Collapse Production Liner 8962' Casing 6188'899' 4500' 121'Conductor Surface Intermediate 16" 7-5/8" 80' measured TVD 5-1/2"x4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-148 50-029-22702-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025521 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3J-19 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) 42 bbl Gas-Mcf MD 1218 Size 121' 92 bbl 1182258 41 bbl 11558 bbl 119 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 471 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker SABL-3 Packer SSSV: HES X Nipple Jill Simek jill.simek@conocophillips.com (907) 263-4131Staff Well Interventions Engineer 3-1/2"x 2-7/8"x 3-1/2" Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Measured depth 8472-8484', 8590-8655', 8710-8716' feet True Vertical depth 6271-6281', 6373-6431', 6481-6486' feet By Anne Prysunka at 12:00 pm, Dec 07, 2022 DTTMSTART JOBTYP SUMMARYOPS 4/23/2022 PERFORATIONS DRIFT TBG W/ 19' X 1.70" FOR E-LINE 1 11/16" PERF GUNS, TAG 8705' SLM W/ ESTIMATED 25' CORRECTION (8730' RKB) NO ISSUES, READY FOR E-LINE. 10/27/2022 PUMPING TRACKING ONLY FREEZE PROTECT PUMPED 5 BBLS METH DWN FL PUMPED 14 BBLS METH DWN TBG 10/28/2022 REPAIR WELL GUN 1 PERFORATED INTERVAL = 8716'-8710', CCL TO TOP SHOT = 7.15', CCL STOP DEPTH = 8702.9', WORK TO PASS PATCH @ 8332' & NIPPLE @ 8261' ON POOH JOB IN PROGRESS 10/29/2022 REPAIR WELL RIH W/ PERF STRIP #2, UNABLE TO PASS ~4900' RKB, ERATIC WT SWINGS (THOUGHT TO BE ASPHALTINES OBSERVED ON TOOLS FROM PREVIOUS DAY'S RUN), BEGIN LOSING HOLE, CONFER W/ TOWN, DECISION MADE TO BULLHEAD 60 BBL OF HOT-DIESEL FLUSH (CLEAN RIH POST DIESEL FLUSH) GUN 2 PERFORATED INTERVAL = 8655'-8645', CCL TO TOP SHOT = 7.2', CCL STOP DEPTH = 8637.8', ... JOB IN PROGRESS 10/30/2022 REPAIR WELL GUN 3 PERFORATED INTERVAL = 8645'-8635', CCL TO TOP SHOT = 7.2', CCL STOP DEPTH = 8627.8' GUN 4 PERFORATED INTERVAL = 8635'-8625', CCL TO TOP SHOT = 7.2', CCL STOP DEPTH = 8617.8' JOB IN PROGRESS 10/31/2022 REPAIR WELL GUN 5 PERFORATED INTERVAL = 8625'-8615', CCL TO TOP SHOT = 7.2', CCL STOP DEPTH = 8607.8' GUN 6 PERFORATED INTERVAL = 8605'-8595', CCL TO TOP SHOT = 7.2', CCL STOP DEPTH = 8587.8' GUN 7 PERFORATED INTERVAL = 8595'-8590', CCL TO TOP SHOT = 7.0', CCL STOP DEPTH = 8583.0' JOB COMPLETE 3J-19 Perforations Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,730.0 3J-19 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added perforations (10/31/22) 3J-19 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 7/26/2010 ninam NOTE: SECOND TBG LEAK CONFIRMED BELOW 8322' RKB 5/7/2003 osborl NOTE: Found Leak in GLM at ~ 8335' MD. 9/6/2000 osborl General Notes: Last 3 entries Com Date Last Mod By SECOND TBG LEAK CONFIRMED BELOW 8322'' RKB 5/7/2003 Admin Found Leak in GLM at ~ 8335'' MD. 9/6/2000 Admin 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 42.0 121.0 121.0 62.50 H-40 WELDED SURFACE 7 5/8 6.75 40.5 4,540.1 3,599.6 29.70 L-80 BTC-MOD PRODUCTION 5.5"x4.5"@8390' 5 1/2 4.95 36.7 8,998.5 6,749.3 17.00 L-80 LTC-MOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 36.7 Set Depth 8,311.5 Set Depth 6,137.2 String Ma 2 7/8 Tubing Description TUBING WO 3.5x2.875x3.5 Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE-ABM ID (in) 2.44 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) 36.7 36.7 0.09 HANGER 8.000 FMC HANGER 3.500 71.3 71.3 0.18 XO Reducing 3.500 CROSSOVER 2 7/8 x 3 1/2 2.875 515.4 515.0 6.95 NIPPLE 3.668 HES X NIPPLE 2.313 3,122.5 2,650.3 46.92 GAS LIFT 4.703 CAMCO KBMG 2.366 5,145.3 4,000.5 47.45 GAS LIFT 4.703 CAMCO KBMG 2.366 6,547.4 4,946.3 46.96 GAS LIFT 4.703 CAMCO KBMG 2.366 7,626.0 5,645.6 48.60 GAS LIFT 4.703 CAMCO KBMG 2.366 8,176.8 6,030.1 38.82 GAS LIFT 4.703 CAMCO KBMG 2.366 8,226.6 6,069.2 37.71 LOCATOR 4.810 BAKER LOCATOR 2.441 8,228.2 6,070.5 37.68 PBR 4.800 BAKER 80-30 PBR 3.000 8,243.1 6,082.3 37.34 SEAL ASSY 3.770 BAKER KBH-22 SEAL ASSEMBLY 2.420 8,243.9 6,082.9 37.33 PACKER 4.680 BAKER SABL-3 PACKER 2.760 8,261.6 6,097.1 36.93 NIPPLE 3.680 CAMCO D NIPPLE 2.250 8,269.3 6,103.2 36.76 XO Enlarging 3.500 CROSSOVER 2 7/8 x 3 1/2 2.992 8,305.4 6,132.3 35.96 OVERSHOT 4.750 UNIQUE POOR BOY OVERSHOT 3.500 Top (ftKB) 8,305.4 Set Depth 8,382.1 Set Depth 6,195.2 String Ma 3 1/2 Tubing Description TUBING Original Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdMOD 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) 8,335.0 6,156.4 35.15 GAS LIFT 4.742 CAMCO KBMM 2.371 8,351.5 6,169.9 34.69 NIPPLE 3.700 CAMCO 'D' NIPPLE NO GO 2.250 8,363.3 6,179.6 34.36 SEAL ASSY 4.500 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 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) 8,322.0 6,145.8 35.51 PATCH 2 7/8" HES PERMANENT PATCH @ 8322' TO 8344' 3/31/2003 1.860 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) 3,122.5 2,650.3 46.92 1 GAS LIFT GLV BK 1 1,333.0 5/9/2018 0.156 5,145.3 4,000.5 47.45 2 GAS LIFT GLV BK 1 1,354.0 5/9/2018 0.188 6,547.4 4,946.3 46.96 3 GAS LIFT GLV BK 1 1,344.0 5/9/2018 0.188 7,626.0 5,645.6 48.60 4 GAS LIFT GLV BK 1 1,339.0 5/9/2018 0.188 8,176.8 6,030.1 38.82 5 GAS LIFT OV BK 1 0.0 5/8/2018 0.188 8,335.0 6,156.4 35.15 6 GAS LIFT Patch 1 0.0 9/28/1996 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,472.0 8,484.0 6,270.9 6,281.2 C-1, UNIT B, 3J- 19 2/17/2008 6.0 IPERF 1-11/16" EJ, 90 deg phase, +/- 45 deg orient 8,590.0 8,605.0 6,373.4 6,386.7 A-3, 3J-19 10/31/2022 APERF 1.69" SHOGUN STRIP- GUNS (AK ELINE), 60 DEGREE PHASE, 6 SPF 8,592.0 8,612.0 6,375.2 6,392.9 A-3, 3J-19 11/2/1996 4.0 IPERF 2 1/8" Enerjet; 180 deg ph 8,612.0 8,632.0 6,392.9 6,410.7 A-3, A-2, 3J-19 11/1/1996 4.0 IPERF 2 1/8" Enerjet; 180 deg ph 8,615.0 8,655.0 6,395.6 6,431.3 A-3, A-2, 3J-19 10/31/2022 6.0 APERF 1.69" SHOGUN STRIP- GUNS (AK ELINE), 60 DEGREE PHASE, 6 SPF 8,633.0 8,644.0 6,411.6 6,421.4 A-2, 3J-19 2/17/2008 6.0 IPERF 1-11/16" EJ, 90 deg phase, +/- 45 deg orient 3J-19, 12/6/2022 5:19:03 PM Vertical schematic (actual) PRODUCTION 5.5"x4.5"@8390'; 36.7-8,998.5 APERF; 8,710.0-8,716.0 IPERF; 8,633.0-8,644.0 APERF; 8,615.0-8,655.0 IPERF; 8,612.0-8,632.0 IPERF; 8,592.0-8,612.0 APERF; 8,590.0-8,605.0 IPERF; 8,472.0-8,484.0 NIPPLE; 8,351.5 GAS LIFT; 8,335.0 PATCH; 8,322.0 NIPPLE; 8,261.6 PACKER; 8,243.9 GAS LIFT; 8,176.8 GAS LIFT; 7,626.0 GAS LIFT; 6,547.4 GAS LIFT; 5,145.3 SURFACE; 40.5-4,540.1 GAS LIFT; 3,122.5 NIPPLE; 515.4 CONDUCTOR; 42.0-121.0 KUP PROD KB-Grd (ft) 41.00 RR Date 9/28/1996 Other Elev 3J-19 ... TD Act Btm (ftKB) 9,010.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292270200 Wellbore Status PROD Max Angle & MD Incl (°) 52.79 MD (ftKB) 7,377.03 WELLNAME WELLBORE3J-19 Annotation Last WO: End Date 8/21/2003 H2S (ppm) 70 Date 5/28/2016 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,710.0 8,716.0 6,480.9 6,486.4 A-1, 3J-19 10/28/2022 6.0 APERF 1.69" SHOGUN STRIP- GUNS (AK ELINE), 60 DEGREE PHASE, 6 SPF 3J-19, 12/6/2022 5:19:04 PM Vertical schematic (actual) PRODUCTION 5.5"x4.5"@8390'; 36.7-8,998.5 APERF; 8,710.0-8,716.0 IPERF; 8,633.0-8,644.0 APERF; 8,615.0-8,655.0 IPERF; 8,612.0-8,632.0 IPERF; 8,592.0-8,612.0 APERF; 8,590.0-8,605.0 IPERF; 8,472.0-8,484.0 NIPPLE; 8,351.5 GAS LIFT; 8,335.0 PATCH; 8,322.0 NIPPLE; 8,261.6 PACKER; 8,243.9 GAS LIFT; 8,176.8 GAS LIFT; 7,626.0 GAS LIFT; 6,547.4 GAS LIFT; 5,145.3 SURFACE; 40.5-4,540.1 GAS LIFT; 3,122.5 NIPPLE; 515.4 CONDUCTOR; 42.0-121.0 KUP PROD 3J-19 ... WELLNAME WELLBORE3J-19 • • RECEIVED OCT 23 ��: ' ConocoPhillips Alaska AOC C> P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 S N�Ea MAY 201 6 October 20, 2015 - 14-8' Commissioner Cathy Foerster r q6 Alaska Oil& Gas Commission 3 1 1 cl 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: 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 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 spreadsheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincerely, c.y...,y (it j MJ Lo eland ConocoPhillips Well Integrity Projects Supervisor 0 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 10/20/2015 3H,3J,3Q&3S Pad Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 3H-26 501032020800 1940290 9" NA 9" NA 4.3 10/9/2015 3J-18 500292270100 1961470 12" NA 12" NA 8 10/3/2015 3J-19 500292270200 1961480 11" NA 11" NA 4.25 10/5/2015 3Q-21 500292263000 1951930 12" NA 12" NA 5.5 10/9/2015 3S-6A 501032045401 2030880 11" NA 11" NA 9.1 10/3/2015 3S-23A 501032045301 2060430 16" NA 16" NA 6.2 10/3/2015 3S-24A 501032045601 2040610 18" NA 18" NA 6.3 10/3/2015 3S-26 501032036101 2010400 9" NA 9" NA 3.8 10/3/2015 STATE OF ALASKA• �y AO KA OIL AND GAS CONSERVATION COMMISSION OCT 0 8 2015 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r �AQshutdow n r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool Repair Well Re enter Susp Well Other:Conductor Extension rci 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J Exploratory r 196-148 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-22702-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025521 KRU 3J-19 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9010 feet Plugs(measured) None true vertical 6760 feet Junk(measured) None Effective Depth measured 8716 feet Packer(measured) 8244 true vertical 6486 feet (true vertical) 6083 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 1640 630 SURFACE 4500 7-5/8 4540 3600 6890 4790 PRODUCTION 8962 5-1/2 8999 6188 7740 6290 Perforation depth: Measured depth: 8472-8484', 8592-8632', 8633-8644' True Vertical Depth: 6279-6289', 6384-6419', 6420-6430' same N 2 j 16 Tubing(size,grade,MD,and TVD) 3.5&2.875, L-80, 8382 MD,6195 TVD Packers&SSSV(type,MD,and TVD) PACKER= BAKER SABL-3 PACKER @ 8244 MD and 6083 TVD SSSV= HES X NIPPLE @ 515 MD and 515 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA 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 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development Fi Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-531 Contact MJ Loveland/Martin Walters Email N1878@conocophillips.com Printed Name Martin Walte/rs� Title WI Project Supervisor Signature /z Cd7; �/fj, ail Phone:659-7043 Date: 10/5/2015 v7-1- /a///2(//s Ag /°(; f C> RBDMS� Ui.i 12 2015 Form 10-404 Revised 5/2015 Submit Original Only • 3J-19 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/26/15 Welded a 9"x16" .375 62#extension onto the exsisting conductor. 10/05/15 Injected 4.25 gallons of RG2401 sealant into the conductor • • 3J-19 DESCRIPTION OF WORK COMPLETED SUMMARY ti OF rye Alaska Oil and Gas �w\ I�j,�sTHE STATE A ti'.-s�� of LAsKA Conservation Commission •itrit t -_ f- 333 West Seventh Avenue 4:, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALASY'� Fax: 907 276 7542 gwww.aogcc alaska.gov MJ Loveland I -/C.).-----"---------- I WI Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 SCl NNE ' Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3J-19 Sundry Number: 315-531 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, lef.1 Cathy P. Foerster Chair DATED this 8 day of September, 2015 P 0 9 2015 RBDM SE Encl. STATE OF ALASKA , SKA OIL AND GAS CONSERVATION COMA... SION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request' Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Conductor Extension 2.Operator Name. 4.Current Well Class. 5.Permit to Drill Number. ConocoPhillips Alaska, Inc L Exploratory r Development 7 196-148• 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-22702-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Wtll planned perforations require spacing exception? Yes r No r/ KRU 3J-19 - 9.Property Designation(Lease Number). 10 Field/Pool(s): ADL0025521 ', Kuparuk River Field/Kuparuk River Oil Pool• 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft) Total Depth TVD(ft). Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured). Junk(measured): 9010 ' 6760 J 8716'• 6486', None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121' 121' SURFACE 4500 10 4540' 3600' R WED PRODUCTION 8328 5.5 8369' 6188' AUG 2 43 2015 PRODUCTION 629 4.5 8998' 6749' rgl 9 j I(I S . _O l i C C Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade. Tubing MD(ft): 8472-8484',8592-8632',8633-8644' • 6279-6289',6384-6419',6420-6430' 1 3.5 &2.875 L-80 8382 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER SABL-3 PACKER ' MD=8244 TVD=6083 Tubing Patch-2 7/8"HES Patch 8332-8334 , MD=8322 TVD=6145 NIPPLE-HES X NIPPLE - MD=515 TVD=515 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r. Service r 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work: 9/15/2015 WINJ r WDSPL r Suspended r OIL r• 16.Verbal Approval: Date• GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. MJ Loveland/Martin Walters Email. N1878@conocophillips.com Printed Name MJ Loveland Tale: WI Project Supervisor Signature �� ` Phone'659-7043 Date /a.5 //S� Commission Use Only Sundry Number. Conditions of approval. Notify Commission so that a representative may witness 3k5 —G3` _ Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: C — O APPROVED BY TL ,. Approved by: COMMISSIONER THE COMMISSION Date: 9-8— �5— II /°Ja1 i Approved application is valid for 12 monthOrorn the date of appro,.I. Form 10-403 Revised 5/2015 ORIGINAL / it Form and ,,ot�J/ _muzS Aan Duplicate ✓ • • ConocoPhillips i.irkEZVED Alaska AU(3 2 8 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AnCC August 25, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3J-19, PTD 196-148 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska,Inc. Kuparuk Well 3J-19 (PTD 196-148) SUNDRY NOTICE 10-403 APPROVAL REQUEST August 25, 2015 This application for Sundry approval for Kuparuk well 3J-19 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 12". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor 1 .- 1t KUP PROD 3J-19 • ConocoPhillips 0'4 Well Attributes Max Angle&MD TD Alaska,InC. Wellbore API/UWI Field Name Wellbore Status ncl(°I MD(ftKB) Act Btm(ftKB) taxa," 500292270200 KUPARUK RIVER UNIT PROD 57.79 7,377.03 9,010.0 ••• Comment H2S(ppm) Date •Annotation End Date KB-Grd(ft) -Rig Release Date 3J-19,1om2013203..22 PM SSSV:NIPPLE 140 2/152013 Last WO: 8/21/2003 86.00 9/28/1996 Vertical schematic(actua9 Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .____.______._................... _ .. Last Tag:SLM 8,706.0 1/13/2011 Rev Reason:WELL REVIEW osborl 10/7/2013 MANGER;36.7 Casing Sfrings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread J CONDUCTOR 16 15.062 42.0 121.0 121.0 6250 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 75/8 6.750 40.5 4,540.1 3,599.6 29.70 L-80 BTC-MOD • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread a PRODUCTION 5 12 4.950 36.7 8,998.5 6,749.3 17.00 L-80 LTC-MOD .... . ,.. .....,5.5"x4.5"@8390' CONDUCTOR;42.0.121.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(N0)(...WI(Ib/ft) Grade Top Connection NIPPLE;515.1 3 TUBING WO 27/8 2.441 36.7 8,311.5 6.137.2 6.50 L-80 CUL-ABM 3.5x2.875x3.5 Completion Details Nominal ID 1 Top(ftKB) Top(TVD)(ftKB) Top Incl(1) Item Des Com (in) `' I �I 36 7 36.7 0.09 HANGER FMC HANGER 3.500 71.3 71.3 0.18 XO Reducing CROSSOVER 2 7/8 x 3 12 2.875 515.4 515.0 6.95 NIPPLE HES X NIPPLE 2.313 •• GAS LIFT;3.122.5 8,226.6 6,069.2 37.71 LOCATOR BAKER LOCATOR 2.441 8,228.2 6,070.5 37.68 PBR BAKER 80-30 PBR 3.000 8,243.1 6,082.3 37.34 SEAL ASSY BAKER KBH-22 SEAL ASSEMBLY 2.420 8243.9 6,082.9 37.33 PACKER BAKER SABL-3 PACKER 2.760 I 8,261.6 6,097.1 36.93 NIPPLE CAMCO D NIPPLE 2.250 SURFACE;40.5-4,540.1 A 8.269.3 6,103.2 36.76 XO Enlarging CROSSOVER 2 7/8 x 3 1/2 2.992 8,305.4 6,132.3 35.96 OVERSHOT 'UNIQUE POOR BOY OVERSHOT 3.500 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection • GAS LIFT;5,1453- TUBING Original 312 2.992 8,305.4 8,382.1 6,195.2 9.30 L-80 EUE8rdMOD I Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ind(1 Item Des Cent (in) 8,351.5 6,169.9 34.69 NIPPLE CAMCO'D'NIPPLE NO GO 2250 GAS LIFT;6,5474 g! i 8,363.3 6,179.6 34.36 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 IOther In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top OMB) (ftKB) (°) Des Corn Run Date ID(in) GAS LIFT;7,626.0 8,322.0 6,145.8 35.51 PATCH 2 7/8"HES PERMANENT PATCH @ 8322'TO 8344' 3/31/2003 1.860 I Perforations&Slots Shot GAS LIFT;8,176.84 Dens all Top(TVD) Bbn(TVD) (shots Top(18(B) 81m(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 8,472.0 8,484.0 6,270.9 6,2812 C-1,UNIT B, 2/17/2008 6.0 IPERF 1-11/16"EJ,90 deg • 3J-19 phase,+/-45 deg orient • • LOCATOR;8,2266 8,592.0 8,612.0 6,375.2 6,392.9 A-3,3J-19 11/2/1996 ' 4.0 IPERF 21/8"Enerjet;180 deg PBR;8.228.2 1 ph 8,612.0 8,632.0 6,392.9 6,410.7 A-3,A-2,3J- 11/1/1996 4.0 (PERF 21/8"Enerjet;180 deg 19 ph SEAL ASSY;8.243.1 PACKER;8.2439 8,633.0 8,644.0 6,411.6 6,421.4 A-2,3J-19 2/17/2008 6.0 IPERF 1-11/16"EJ,90 deg phase,+/-45 deg orient Mandrel Details St NIPPLE;8.261.6 a ati C on Top(TVD) Valve Latch Port Size TRO Run o No Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m I • 6 8,335.0 6,156.4 CAMCO KBMM 1 GAS LIFT Patch 0.000 0.0 9/28/1996 • 1 3,122.5 2,650.3 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,356.0 8/25/2003 OVERSHOT;8.305.4 I II 2 5,145.3 4,000.5 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,375.0 8/25/2003 ' ~' 3 6,547.4 4,946.3 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,357.0 8/25/2003 4 7,626.0 5,645.6 CAMCO KBMG 1 GAS LIFT GLV BK 0.188' 1,339.0 8/24/2003 PATCH;8,3220- 5 8,176.8 6,030.1 CAMCO KBMG 1 GAS LIFT OV BK 0.250' 0.0 8/24/2003 GAS UFT;8,335.0 Notes:General&Safety I End Date Annotation 9/6/2000 NOTE:Found Leak in GLM at'8335'MD. NIPPLE;8,351.5 5/7/2003 NOTE:SECOND TBG LEAK CONFIRMED BELOW 8322'RKB 7/26/2010 NOTE:View Schematic w/Alaska Schematic9.0 ri SEAL ASSY;8.363.3 (PERF;8.472.0.8.484.0 IPERF;8.5920.8,612.0 IPERF;8,612.0.8,632.0 (PERF;8.633.0.8,644.0 PRODUCTION , 5.5124.5"683901;36.7-8,998.5 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: Beverly"Di~nna"i,'~incent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vince~._~_~Lowell ,, Date: : Is~ ~~~~~~~~~~~~ ~"~s~~~ %'; ~ti 1aC~(~~~ NO. 4639 Schlumberger -DCS _ 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 03/20/08 2W-11 11996609 LDL - 03/17/08 1 3J-19 11996610 PROD PROFILE - ~~( 03/18/08 1 2Z-01A 11994631 PROD PROFILE 03/11/08 1 1E-08 11994632 INJECTION PROFILE 03/12/08 1 2U-12 11994638 PROD PROFILE - 03/16/08 1 U r Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. C; STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION !- F ~ ~ ~" Zu', 5 REPORT OF SUNDRY WELL OPERATIO~I~.. _ ,. ,._ _ , . 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Ot r Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate Q Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 196-148 / ` 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22702-00 \ 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 45' - 3J-19 ` 8. Property Designation: 10. Field/Pool(s): ADL 25521, ALK 2557 Kuparuk River Field !Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 9010' feet true vertical 6760' feet Plugs (measured) Effective Depth measured 8716' feet Junk (measured) true vertical 6486' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURF CASING 4499' 7-5/8" 4540' 3600' PROD CASING 8328' 5-1/2" 8369' 6188' " 8998' 6749' PROD CASING 629' 4-112 / 8644' P rf r th: Measured de th: 8472' 8484' 8592' 8632' 8633' ti d on p , - , - e o a ep - true vertical depth: 6279'-6289', 6384'-6419', 6420'-6430' ~k , ,~ ~d~~ c~~;~G'SCn~9~s ~~~ ~. u Tubing (size, grade, and measured depth) 3-1 /2" & 2.875", L-80, 8381' MD. Packers & SSSV (type & measured depth) Baker SABL-3 pkr ~ 8244' HES 'X' nipple ~ 515' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 195 ~ 653 173 -- 120 Subsequent to operation 288 1327 216 -- 123 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oi10 Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or !+t/A if C.O. Exempt: none Contact Guy Schwartz Printed Name Guy,Schwartz -_ ~ Title Wells Group Engineer Signature ~~ ~ Phone: 265-6845 Date „~ - p2 ~- ~ S P are ha n Allsu -Drake 263-4612 _ ~ Form 10-404 Revised 04/2006 v~ts~'~ ~ ~ ~a ~a~ a~\~a~o~o ,~D 3.3. c~ ~~~ (~ ~~~'' Submit Origi Ony/~O~ • • 3J-19 Well Summary DATE Summary 2/17/08 PERFORATE WELL WITH 1-11/16" ENERJET 6 SPF, 90 DEG PHASING, +/- 45 DEG ORIENTATION. INTERVAL 1:8633'-8644' & INTERVAL 2: 8472'-8484'. API PEN 16.8", EHD 0.28". i ~ Cdtlt?CC1~hl~rtj~S A~~SC~t, Ct1C- 3J-19 - - API: 51 TUBING SSSV T N (34-8353, Annular Fluid: OD:2.875, Reference Lo 3'. ID:2.441) ~~ i „~. r..... o~ OVERSHOT (8305-8306, OD:4.750) PATCH (8322-8344, OD:2.875) NIP (8351-8352, OD:2.875) TUBING (8353-8381, OD:3.500, ID:2.992) Perf (8592-8612) Perf (8612632) PROD 9/28/1! R/21 /21 rr~*+ ~ Last Tag Date: 110/25/2007 _ I Max Hole Angle: 153 deg (~ 7377 I Casco Stnn ALL STRINGS Descri ion Size To Bottom TVD 1 Wt Grade Thread "} CONDUCTOR 16.000 0 121 121 62.50 H-40 • SURF CASING 7.625 0 4540 3600 29.70 L-80 PROD CASING 5.500 0 8369 6188 15.50 L-80 LTC-MOD _ ~ PROD CASING Tubing String -TUBING Size To 4 500 8369 _ Bottom TVD 8998 6.744 12.75 L-RO _ EVE8rdMOD _- ~ Wt Grade Thread 3.500 0 34 34 9.30 L-80 EUE8rdABMod I I 2.875 34 8353 6174 6.50 L-80 EUESrdABMod `' 3.500 8353 Perforation_s_Summary _ - -- interval TVD 8381 6199 ___ _ Zone Status Ft P 9.30 F Dale L-80 T __ EUE8rdABMod Comment 8472 - 8484 6279 - 6289 C-1,UNIT B ' 12 6 2/17/2008 IPERF 1-11/16" EJ, 90 deg phase, +/- 45 de orient 8592 - 8612 6384 - 6402 A-3 20 4 11/2/1996 IPERF 2 1 /8" Ener'eY 180 d h '~ 8612 - 8632 6402 - 6419 A-3 A-2 20 4 11/1/1996 IPERF 2 1/8" Ener'eY 180 de h ~ ':' 8633 - 8644 6420 - 6430 A-2 11 6 2/17/2008 IPERF 1-11/16" EJ, 90 deg phase, +/- 45 deg orient - ____ Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3122 2650 CAMCO KBMG GLV 1.0 BK 0.156 1356 8/25/2003 2 5145 4000 CAMCO KBMG GLV 1.0 BK 0.188 1375 8/25/2003 3 6547 4946 CAMCO KBMG GLV 1.0 BK 0.188 1357 8/25/2003 4 7626 5646 CAMCO KBMG GLV 1.0 BK 0.188 1339 8/24/2003 5 8177 6031 CAMCO KBMG OV 1.0 BK 0.250 0 8/24/2003 6 8335 6158 CAMCO KBMM PATCH 1.0 BK 0.000 0 9/2811996 1 1 __ 1_ PATCH OVER GLM _ --- Other lu 5 equip., etc.) -.JEWELRY -- De h TVD T e _ Descn Ion _ -- D 37 37 HANGER FMC TBG HANGER set 8/20/2003 2.992 515 514 NIP HES'X' NIPPLE se[ 8/20/2003 2.313 8228 6071 PBR BAKER 80-32 PBR set 8/20/2003 3.000 8244 6084 PACKER BAKER SABL-3 PACKER set 8/20/2003 2.760 ~' 8262 6098 NIP CAMCO'D' NIPPLE se[ 8/20/2003 2.250 -° 8305 6132 OVERSHOT UNIQUE POOR BOY OVERSHOT set 8/20/2003 3.500 8306 6133 STUB TBG STUB 2.992 -- - ~ 8322 6147 PATCH 2 7/8" HES PERMANENT PATCH 8322' TO 8344' SET 3/31/2003 1.860 8351 6172 NIP Camco'D' Ni le NO GO 2.250 8363 6183 LOCATOR Baker'GBH-22' 3.000 8381 __6199 SHOE General Notes _ _ _ __ "~ 0~ _ A r KRU 3J-19 ConocOPhillips Mike Mooney Wells Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 September 5, 2003 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 3J-19 (196-148) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 3J-19. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader CPAI Drilling MM/skad ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon [] Suspend [~ Operation Shutdown r-"] Perforate ~ Variance Alter Casing r-~ Repair Well [~ Plug Perforations [~ Stimulate [~ Time Extension ~ Other [~/ Change Approved Program ~] Pull Tubing ~] Perforate New Pool ~m Re-enter Suspended Well r--m 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~l Exploratory ~] 196-148 / 3. Address: Stratigraphic ~] Service ~ 6. APl Number: P. O. Box 100360, Anchora~le, Alaska 99510 50-029-22702-00 7. KB Elevation (ft): 9. Well Name and Number: Rig RKB 41', Pad 45' 3J-19 8. Property Designation: 10. Field/Pool(s): ADL 25521, ALK 2557 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9010' feet true vertical 6760' feet Plugs (measured) Effective Depth measured 8741' feet Junk (measured) true vertical 6509' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURF CASING 4499' 7-5/8" 4540' 3600' PROD CASING 8328' 5-1/2" 8369' 6188' PROD CASING 629' 4-1/2" 8998' 6749' Perforation depth: Measured depth: 8612' - 8632', 8592' - 8612' true vertical depth: 6402' - 6419', 6384' - 6402' Tubing (size, grade, and measured depth) 3.5" / 2-7/8", L-80, 6174'/6199' MD. Packers & SSSV (type & measured depth) SABL-3 packer packer @ 8244' SSSV= NIP SSSV= 516' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casin,q Pressure Tubing Pressure Prior to well operation 293 1315 132 143 Subsequent to operation 184 647 337 149 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run __ Exploratory D Development r'~ Service Daily Report of Well Operations _X 16. Well Status after proposed work: Oil[-~ Gas[~ WAG [~] GINJ F-~ WINJ [~ WDSPL[-'] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.C. Exempt: I Contact Mike Mooney @ 263-4574 / Printed Name Mi.ke ~oon. ey Title Wells Group Team Leader Signature /J~ ~/~,~,. Phone Date ~ Prepared by Sharon AIIsup,;D. rake 263-4612 Form 10-404 Rev~j)S3-~FL SUBMIT IN DUPLICATE ConocoPhillips Alaska Page I of 3 Operations Summary Report Legal Well Name: 3J-19 Common Well Name: 3J-19 Spud Date: 9/17/1996 Event Name: WORKOVER/RECOMP Start: 8/14/2003 End: 8/21/2003 'Contractor Name: Rig Release: 8/21/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Date From- To Hours Code Code PhaSe Description of Operations 8/15/2003 00:00 - 07:00 7.00 MOVE MOVE MOVE Move rig from 1R-14 to 3J-19 - Arrive location @ 0700 hrs. 07:00 - 20:00 13.00 MOVE RURD RIGUP Rig up Nabors 3S - needed a crane to move in BOP stack behind well row. Continue rig up. 20:00 - 21:00 1.00 MOVE RURD MOVE Completed rig up. Accept rig @ 20:00. Held Pre-spud meeting with crew & Toolpusher. i21:00 - 00:00 3.00 MOVE RURD RIGUP ND tree, NU BOP 8/16/2003 00:00 - 01:00 1.00 WELCTL NUND DECOMP Finish NU BOP 01:00 - 07:00 6.00 WELCTL BOPE DECOMP Function test BOP. Test blinds. Body test OK. Trouble stinging into test plug. Plug backed out. Threads on test plug look good so we re-ran it. Pulled test plug. 07:00 - 09:30 2.50 WELCTL BOPE DECOMP Begin pressure test on BOP - close annular - discovered leak below TIW valve - bled off pressure and continued with test - found two valves leaking in the choke manifold - tear down and repair both valves. Unable to get test - tear down valves and wait for parts from Prudhoe. Rig move in progress at Prudhoe causing delay in the parts arriving. Unable to get help from the APC valve crew. 09:30 - 20:00 10.50 WELCTL BOPE DECOMP Load tubing in pipe shed, remove protectors, drift to 2.347". Change out valves 4 & 5 on choke manifold. Tested choke manifold to 250 psi and 5000 psi. 20:00 - 00:00 4.00 WELCTL BOPE DECOMP Attempted to test BOPE, continued to leak. Pulled test plug, tightened connections re-ran still leaking. 8/17/2003 00:00 - 06:00 6.00 WELCTL BOPE DECOMP Changed out two 1/2"- 1/4 turn valves on test pump. Tested VR rams to 250 and 5000 psi, held ok. Attempted test on HRC, VBR and TIW valve and leaked off again. Filled back side, completed remainder of tests ok. Witnessing of tests waived by John Crisp (AOGCC). 06:00 - 08:00 2.00 WELCTL BOPE DECOMP Pull test plug. Run 1 jt of 3-1/2" 8rd screw into hanger. Finish rigging up HES slickline. Pull plug set at 500'. 08:00 - 10:00 2.00 WELCTL OTHR DECOMP Attempt to straight pull out of SBE - unable to pull - worked pipe up and down pulling max. pull @ 138,000#. Unable to pull. Closed Hydril and pressured up to max. differential on IBP >1300# surface pressure and then dump pressure to zero psi to attempt to jar seals loose. Unable to move pipe. 10:00 - 16:00 6.00 WELCTI. OTHR DECOMP Rigged up and RIH w/80 grain string shot to attempt to jar tubing loose. Worked pipe up and down numerous times to attempt to jar loose. Unable to pull seals out of SBE. Rig up chemical cutter with Schlumerger unit. 16:00 - 19:00 3.00' FISH CPBO DECOMP Rig up and RIH w/2 1/8" chemical cutter to attempt to cut tubing mid joint above SBE @ 8306' RKB. Pulled approx. 10,000# over string weight @ 70,000# to cut tubing. 19:00 - 22:30 3.50 FISH CPBO DECOMP Chemical cut tubing @ 8306'. POOH with cutter, hanging up on 2-7/8" GLMs. Worked thru and POOH. Laid down cutting tools, picked up on tubing to confirm cut. Pulled 25K over string wt. and came loose. Rigged down Schlumberger. 22:30 - 00:00 1.50 FISH PULL DECOMP Start POOH laying down 3-1/2" tubing and associated jewelry. 8/18/2003 00:00- 10:30 10.50 FISH PULL DECOMP Pulling and laying down 3-1/2" tubing and 2-7/8" GLMs. Installing thread protectors and unloading pipe shed one row at a time. NORM testing all joints and jewelry coming out. Bottom joint chemical cut looked very good and mid joint as designed. All tubing and mandrels appeared to be in excellent shape. 10:30 - 15:45 5.25 FISH PULD DECOMP Rig up Baker overshot fishing string w/3.5" grapple and normal bumper/oil jar/9 - 3.5" drill collars/accelerator fishing assb. P/U 2 7/8" L-80 tubing (new) as the work string. 15:45 - 00:00 8.25 FISH TRIP DECOMP Start in hole w/Baker fishing assb. and 2 7/8" tubing as a work string. Printed: 8/28/2003 3:23:30 PM ConocoPhillips Alaska Page 2 of 3 Operations Summary Report Legal Well Name: 3J-19 ,Common Well Name: 3J-19 Spud Date: 9/17/1996 Event Name: WORKOVER/RECOMP Start: 8/14/2003 End: 8/21/2003 Contractor Name: Rig Release: 8/21/2003 Group: Rig Name: Nabors 3S Rig Number: Sub PhaSe DescriptiOn of Operations Date From-To Hours Code Code 8/18/2003 15:45 - 00:00 8.25 FISH TRIP DECOMP Using 1610# torque value to make up tubing. Strapping pits every 20 joints. 8/19/2003 00:00 - 01:30 1.50 FISH TRIP DECOMP Continue RIH w/2-7/8" tubing, overshot, jars and drill collars. 01:30 - 02:00 0.50 FISH JAR DECOMP Engaged 3.5" stub with overshot. Jarred for 30 min. @ 105K max. Fish came loose. Picked up 30'. 02:00- 04:30 2.50 FISH CIRC DECOMP Circulate bottoms up. 04:30 - 09:30 5.00 FISH TRIP DECOMP ; POH with fishing tools and fish, standing back 2-7/8" tubing in doubles stacked in derrick. 09:30 - 10:30 1.00 FISH TRIP DECOMP Co-man Change-out Overstreet/Kralick to Gober/Chaney Continued POOH w/fishing tools 10:30 - 12:00 1.50, FISH TRIP DECOMP Continued POOH. At surface with Overshot & no fish. 12:00 - 12:30 0.50 FISH PULD DECOMP Layed down overshot and pieces of grapple fell out of the overshot while breaking it down, found spiral grapple to be broken into pieces. The grapple pieces that came back in the overshot were app: 2" x 1" x 1/4" semicircular. Baker Fishing Rep estimates that possibly 6 to 9 pieces like this were left in the hole. 75% of the grapple left in the hole. 12:30 - 14:00 1.50 FISH PULD DECOMP Make decsion to run Wash-Over Mill. Gather up Baker Wash-Over Mill Equipment. Rig crew taking care of some welding while waiting on Baker Equipment 14:00- 14:30 0.50 RIGMNT OTHR DECOMP Finish up welding 14:30 - 15:30 1.00 FISH PULD DECOMP Unable to get wear ring installed. Hotshot another wear ring from the warehouse 15:30 - 17:30 2.00 FISH PULD DECOMP Installed new wear ring and begin picking up Baker Wash-Over Mill BHA 17:30 - 21:45 4.25 FISH TRIP DECOMP RIH w/tools on 2-7/8" 8rd EUE AB Mod tubing out of derrick. PU single out of pipe shed and then stand 127 out of derrick. 50k up weight. 35k down weight. Tag up on top of stub @ 8292' RKB (Nabors 3S). Set down 10k without rotating. Did not fall over stub.. 21:45 - 22:30 0.75 FISH WASH DECOMP PU 2' above stub. Rotate with tongs @ 1200-1600 ft-lbs. Go down 2' over fish and started taking weight. Release torque. PU above stub. Rotate @ 1200-1800 ft-lbs. Work down and go over stub. Stop rotating and go down 10'. Tag top of stub inside wash pipe. PU above fish. Took 10k over pull to pull off stub. Rotate over stub again. Stop rotation and go down 10'. Tag stub inside wash pipe. PU above fish. Took 5k over to pull off stub. Rotate over stub a third time. Rotate 8' down on stub. Did not tag anything. PU above fish. Took 3k over to ~come off stub. Everything looks good for getting poor boy overshot over the stub. 22:30- 00:00 1.50 FISH TRIP DECOMP Pull 1 stand and LD 1 single. Pull 9 more stands. Hole fill looks good. Continue POOH with 2-7/8" tubing. Pulled 50 stands at report time. 8/20/2003 00:00 - 03:00 3.00 FISH TRIP DECOMP POOH w/2-7/8" tubing to the Wash-Over Mill. 03:00 - 04:00 1.00 FISH PULD DECOMP LD Milling assembly. 1 button broken off the bottom of the washover shoe. Otherwise, the shoe was in good shape. Could not see any marks from setting down on the stub or from rotating over the stub. 04:00 - 06:00 2.00 FISH PULD DECOMP Clear drill collars, milling, and fishing tools out of the pipe shed. Clean up rig floor and prep to run completion. 06:00 - 07:00 1.001 CMPLTN PULD CMPLTN Load poorboy overshot, 2.25" nipple assembly, and packer assembly in pipe shed. Strap all components. Prepare pipe talley for run in hole. 07:00 - 15:00 8.00 CMPLTI'q RUNT CMPLTN Ran completion string per well plan, Unique Overshot(4.75" OD by 3.5" ID), Camco 2.25" D nipple, Baker SABL-3 Packer, Baker PBR (10' eft. stroke), 257 joints of 2-7/8" tubing, including five 2-7/8" KBMG GiLM's, and 2.313" X nipple, & one joint of 3-1/2" tubing under FMC 3-1/2" Printed: 8/28/2003 3:23:30 PM ConocoPhilliPs Alaska Page' 3 of 3 Operations Summary Report Legal Well Name: 3J-19 ,Common Well Name: 3J-19 Spud Date: 9/17/1996 Event Name: WORKOVER/RECOMP Start: 8/14/2003 End: 8/21/2003 Contractor Name: Rig Release: 8/21/2003 Group: Rig Name: Nabors 3S Rig Number: Sub Date FrOm- To Hours Code Code Phase DescriptiOn of Operations 8/20/2003 07:00- 15:00 8.00 CMPLTN RUNT CMPLTN Hanger. 15:00 - 15:30 0.50 CMPLTN RUNT CMPLTN Checked weight 47K up and 30K down. Overshot tagged up on top of 3-1/2" stub set down app: 5K. Pulled up 3' completely off of stub and rotated pipe one full turn and lowered tubing back down. observed overshot slide onto stub and was able to get 5' deeper, down to app: 8294' 15:30 - 16:30 1.00 CMPLTN RUNT CMPLTN Pulled up off of stub saw a 7K over-pull as overshot came off of stub. Re-rigged piping on the floor to allow fluids to be pumped. Lowered tubing back down and overshot slid back over stub and bottomed out @ 8294'. Picked up 2' to 8292' into packer setting position. Prepped to circulate corrosion Inhibited brine. 16:30- 17:00 0.50 CMPLTN ClRC CMPLTN Begin pumping 1% corrosion inhibited 9.6# brine, pumped app: 10 bbls and followed with 46 bbls of 9.6# brine. Placed 8 bbls of corrosion inhibited brine in the IA just above the packer and 2 bbls below the packer in sump. Max pump pressure = 400 psi @ 1.5 bpm. 17:00 - 18:20 1.33 CMPLTI~ PCKR CMPLTN Dropped 2.25" Cat standing valve down the tubing in preparation to set the packer. Waited for standing valve to get to bottom. 18:20 - 18:30 0.17 CMPLTI~ PCKR CMPLTN Pumped down tubing and pressured up to 4500 psi. Witnessed a pressure flucuation indicating packer had set. 18:30 - 19:00 0.50 CMPLTIX PCKR CMPLTN Bled tubing pressure back to 2000 psi. Begin to pull up on tubing to shear PBR. Pulled up to 80K. Bled the tubing down to 0 psi and Re-rigged surface piping to allow more pull. Pressure back up on tubing to 2500 psi. Pull up on tubing slowly to 85K (38K over) and sheared PBR. 19:00 - 19:45 0.75 CMPLTN RUNT CMPLTN Begin space out removed 2-7/8" joint of tbg and replaced with 2-7/8" pup, x-over(2-7/8" x 3-1/2"), PU 3-1/2" joint of tubing. Change power tong dies to 3-1/2". 19:45 - 20:15 0.50 RIGMNT RGRP CMPLTN Could not get 3-1/2" tong dies to bite. Try several die combinations until find the correct dies to bite on 3-1/2". 20:15 - 20:45 0.50 CMPLTN RUNT CMPLTN MU 3-1/2" joint and FMC hanger with 3-1/2" pup joint. Run hanger in on landing joint. 35K down weight. 48K up weight. Land hanger in tubing head. Locator sub is spaced out 1' above top of PBR. PU 2' and drain BOP stack. RIH 2' and land hanger. RILDS and torque up. 20:45 - 22:45 2.00 CMPLTN DEQT CMPLTN Pressure test tubing to 2500 psi. Lost 150 psi in 30 min. Monitor casing for returns. No returns during PT. Bleed off tubing pressure to 0 psi. Install tee in tubing side to monitor pressure. Pressure up tubing to 1500 psi. Pressure test casing to 2500 psi for 15 min. Tubing pressure at 1750 psi. Casing pressure held solid for 15 min. All pressure tests recorded on chart. Bleed off tubing pressure to 0 psi. SOV sheared. Bleed down well pressure to 0 psi. Pull landing joint. 22:45 - 00:00 1.25 WELCTL NUND CMPLTN Pump remaining fluid out of BOP stack. Install BPV in tubing hanger. Begin ND BOP stack. 8/21/2003 00:00 - 04:30 4.50 WELCTL NUND CMPLTN ND BOP stack. NU Tree. Tree has been tested by the valve shop. Tubing head adapter has been redressed by FMC. Pull BPV. 04:30 - 06:00 1.50 CMPLTN SEQT CMPLTN Run test plug. Fill tree with water. PT packoffs to 5000 psi for 10 min. Held good. PT tree to 5000 psi. Pressure dropped 100 psi in 15 min. Bleed off pressure. Pump fluid out of tree. Pull test plug. 06:00- 06:30 0.50 WELLSR PLGM CMPLTN SITP=0 psi. SICP=0 psi. Set BPV. Clean up cellar. Release rig @ 0630 to prep for move to 2U-02. Printed: 8/28/2003 3:23:30 PM ConocoPhillips Alaska, Inc, 3J-19 (34-8,353, 0D:2.875, ID:2.441) OVERSHOI 0D:4.750) PATCH (8322-8344, 0D:2.875) NIP (8351-8352, 0D:2.875) TUBING (8353-8381, OD:3.500, ID:2.992) Perf (8592-8612) Perf (8612-8632) KRU 3J-19 APl: 500292270200 PROD SSSV Type: Annular Fluid: NIPPLE Reference Log: 37' RKB Last Tag: 8741 Last Tag Date: 2/19/2003 Casing String · ALL STRINGS Description CONDUCTOR SURF CASING PROD CASING PROD CASING Tubing String - TUBING Size ] Top 3.500 0 2.875 34 3.500 8353 Perforations Summary Interval I TVD 8592 - 8612 6384 - 6402 8612 - 8632 6402 - 6419 Well Type: Orig Completion: Last W/O: Ref Log Date: TD: Max Hole Angle: 9/28/1996 Bottom TVD 34 34 8353 6174 8381 6199 8/21/2003 9010 ffKB 53 deg.7377 Angle @ TS: Angle @ TD: Rev Reason: Last Update: 32deg@8435 20 deg@9010 WORKOVER, GLV design, pull plug, Cat SV 9/1/2003 Size Top Bottom TVD I Wt GradeI Thread 46.000 0 121 121 162.501 H-40 I 7.625 0 4540 3600 I 29.70 I L-80 I 5.500 0 8369 6188 115.50 L-80 /LTC-MOD 4.500 8369 8998 6749 I 12.75 L-80 [EUE8rdMOr I Wt IGrade I Thread 9.30 I L-80 I EUESrdABMod 6'50 I L'80 I EUE8rdABMod 9.30 I L-80 I EUE8rdABMod IZone I Status I Ft ISPFI Date I Type I Comment A-3 I I 20 I 4 111/2/199611PERF 121/8"Enerjet;180degph A-3,A-2 I I 20 I 4 111/1/199611PERFI21/8"Enerjet;180degph Gas Lift Mandrels:/valves : st I MD I TVD I Man I Ma. I VMfr I VType I voDl'atchl .o. I T.OI Date I Wv I I IMfr I TYPe I I I I I I [Run I Cmnt 11 31221 26501CAMCOI KBMG I IGLV 11.0 I BK 10.156 1135618/25/20031 215145140001CAMCOI KBMG I IGLV 11.0 I BE 10.1881137518/25/2003I 3165471 49461CAMCOI KBMG I IGLV 11.0 I BE 10.188 1135718/25/20031 4176261 56461CAMCOI KBMG I IGLV 11.0 I BE 10.188 1133918/24/20031 518177160311CAMCOI KBMG I IOV I1'° I BE 10.2501 0 18/24/20031 6 I 83351 61581CAMCOI KBMM ] I PATCH I 1.0 I aK 10.0001 0 19/28/19961 (1) 1. PATCH OVER GLM Other (plugsi equipii :etcil Depth TVD I Type 37 37 I HANGER 545 15141 N,P 8228 16074 I PBR 8244 16o84 I PACKER 8262 16098 I NIP 8305 16132 1OVERSHOT 8306 161331 STUB 8322 161471 PATCH 8351 16172 I NIP 8363 161831 LOCATOR 8381 161991 SHOE Description FMC TBG HANGER set 8/20/2003 HES 'X' NIPPLE set 8/20/2003 BAKER 80-32 PBR set 8/20/2003 BAKER SABL-3 PACKER set 8/20/2003 i CAMCO 'D' NIPPLE set 8/20/2003 UNIQUE POOR BOY OVERSHOT set 8/20/2003 TBG STUB 2 7/8" HES PERMANENT PATCH (~ 8322' TO 8344' SET 3/31/2003 Camco 'D' Nipple NO GO Baker 'GBH-22' ID 2.992 2.313 3.000 2.760 2,250 3.500 2.992 1.860 2.250 3.000 3.000 Date I Note 9/6/2000 1 Found Leak in GLM at ~ 8335' MD. 5/7/2003 ISECOND TBG LEAK CONFIRMED BELOW 8322' RKB P E RM I T DATA ..... AOGCC Individual Well Geological Materials Inventory T DATA PLUS ..................................... Page: 1 Date: 11/05/98 RUN RECVD 96-148 96-148 96-148 96-148 CBL -~'~%300-8858 FINAL 11/08/96 ARC5 ,~4450-9008 FINAL 01/17/97 ADN4 .~-~' 4450-9008 FINAL 01/17/97 7576 ~SCHLUM ARCS/ADN4 1,2,3 01/17/97 10-407 DAILY WELL OPS R Are dry ditch samples required? yes ~d received? Was the well cored? yes ~alysis & description received? Are well tests required?~es: ~/Received? yes~ Well is in compliance Initial COMMENTS 1/17/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10710 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia LIS Tape ¢ 3J-17 ~ '7 :~"7 ~-- 97014 PHASOR INDUCTION-SFL & GR 961129 1 3 J-17 97 01 4 PHASOR INDUCTION-SFL 9611 2 9 1 1 ~ 3J-19 ~ '75'7(,p 96288 MWD ARC5/ADN4 961101 1 3J-19 96288 ARC5 961101 I 1 3J-19 96288 ADN4 961101 I I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO ~.~laska;-i~c. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 14, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3J-19 (Permit No. 96-148 & 96-188) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3J-19. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development O~q i ,~- 1997 Alaska Oil & Gas Con~. ~;ommission DKP/skad . '~-~' STATE OF ALASKA ALASI,,. OIL AND GAS CONSERVATION C,.,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1~ StatUs of Well ...... Classification of Servi~:e Well " [] Oil [] Gas [] Suspended [] Abandoned [] Service 12. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-148 96-188 3. Address ...... 8. APl ~'umber .... P. O. Box 100360, Anchorage, AK 99510 50-029-22702 "[~~__ g~--Unit Or Le~.-~e Name 4. Location of well at surface i~- ~3i-i'i~i'.::!i'?i;i.:- ~ Kuparuk River Unit 930' FSL, 565' FWL, Sec. 3, T12N, R9E, UM ~ ~;~.'i~;~ ; ~~' At top of productive interval~/.~///,~h './,,.~ ~~ 10. Well Number 516' FSL, 832' FEL, Sec. 32, T13N, R9E, UM ~-'/~~ _~ ~ 3J-19 Atto~l depth~~~.,~ ' ~' ....... ~ ' ~-~ieid"~nd poOl '" sec. uM ................ ~-~'~ _ Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. Rig RKB 41', Pad 45'I ADL 25521, ALK 2557 '~'2. Date Spudded 113. DateT. D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, ifoffshore ~16. No. of Completions 9/17/96 i 9/25/96~ ~11/2/96 N/A MSLI One ~'7. Total Depth (MD+TVD)/18~ Plug Bac~ DePth (MD+TVD)119. DireCtional Survey[20. Depth Where SSSV set ~1. Thickness of permafr~'st ..... 90~.0 ....... 6760 F~ 8932 6687 F~ ~Yes ~No I N/A MDl . 1465; (ApB.mX;) ..... 22. Type Electric or Other Logs Run ARC5/GR, G~CCUSLTJ 23. CASING, LINER AND CEMENTING RECORD ...... ~ASlNG sE~ING DEPTH HOLE .......... SIZE ~. PER FT. G~DE TOP BOSOM SIZE CEMENTING RE~ AMOU~ PULLED 16" 151.5¢ X-65 SUd. 121' 30" [164SX AS I 7.625" 29.7¢ L-80 Sud. 4540' 9.875" 797 sx AS III & 450 Class G 5.5"x4.5" - 15.5-~&1767- L-80 .... S~-R-; ........ ~-~' ---8:7~-'~ '~-70 ~-cla~-~-~ ...................... 12.75¢ ...................................................................................................................................................................................... ,, ~. ped0rationS Open to Production (MD+TVD of ToP and Bottom 25'.' TUBING RECORD ............................. and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) ........................................... 3.5" ~-~ MD TVD MD TVD ............................................................................................ 8612'-8632' 6402'-6419' 4 spf 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. ...... 8592'-8612' 6384'-6402' DEP~ I~ERVAL (MD) AMOU~ & KIND OF MATERIAL USED 4 spf '~6i2C8632' -t0t~i -p~opp'~nt p'u~ped 223i 89~ '~592c8612' ¢20/40, 202500¢ of ~ 2~i8-;--&~-189¢ of ~¢10/14). Put 221200 in the formation w/12.1¢ ........ 27. P~DUCTION TEST iDa~e FirSt Prod~Ction iMethod 0f d~eration (Fl~ing, gas lift, etc.) ~ Flowing 12/23/96 Date of Test ~Hours Tested P~DUCTION F~ OIL-DEL GAs-MCF WATER-BBL CHOKE SIZE IGAs-OIL RAT~ 1/10/97 i 6 TEST PERIOD" 401 740 1 3 0J 1288 Flow TubingiCasing Pressure~OA~6b~-~b---; -~-Oi~ ................ ~;~-~ ......... ~-WA~:B8-~'--- -Oi~ GRAW~-API (CORR) Press. 25~ 1078 ~4-HouR RATE i 1471 ' 1895 ~ 52 23.5° 28. CORE DATA Brief description of lithology, porosity, fra~ures, apparent dips and presence of oil, 9a~ or water. Submit core ohip~. FR i GINAL JAN ~ 4 ~997 AJas~ 0it & Gas Cons, Commi~i0n ~chorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Ma¢'-~- 30. -- Formation Tests , Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kup. aruk C 8435' 6239' Total pump volumes for this event: Bottom Kupark C 8475' 6273' Category 1. 21135 Top Kuparuk A 8570' 6356' Category 2. 100 Bottom Kuparuk A 8716' 6486' Category 3. 0 Total: 21235 Total To Date: 21235 Freeze protected annulus. 31. List of Attaciiments '" Summary of Daily Drilling Reports, Surveys i32. I hereb~fy tha~he_{0, regoing is true and correct to the best of my knowledge Slgned~"~~---~ Title ~¢L\LL-~I',tC_~ ~-~,J6~l!.~---"~ Date ~, l\~ [~'~r-- · Prepared By Name/Number: ............ INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 11/15/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL'3J-19 RIG:PARKER 245 WELL ID- AK8637 TYPE: AFC:--AK8637 AFC EST/UL'$ 1280M/ 1540M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD' KUPARUK RIVER UNIT BLOCK: SPUD: START COMP' FINAL: WI' 55% SECURITY'0 API NUMBER: 50-029-22702-00 09/16/96 (D 1) TD: 121' (121) SUPV: DCL DAILY: $ 09/17/96 (D 2) TD: 1005' (884) SUPV'RLM DAILY:$ 09/18/96 (D 3) TD: 4550' (3545) SUPV:RLM DAILY:$ 09/19/96 (D 4) TD: 4550' ( 0} SUPV:RLM DAILY:$ 09/20/96 (D 5) TD: 4550' ( 0) SUPV:RLM DAILY:$ 09/21/96 (D 6) TD: 6509' (1959) SUPV:RLM DAILY'$ 09/22/96 (D 7) TD' 6952' ( 443) SUPV:RLM MW: 8.3 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 PICK UP DP Move rig from 3A-17 to 3J pad. Spot drill module over 3J-19. 81,735 CUM:$ 81,735 ETD:$ 0 EFC:$ 1,361,735 MW: 8.8 rISC: 70 PV/YP: 20/24 APIWL: 9.4 DRILLING @ 2000' Accept rig at 0300 hrs. 9/17/96. Nipple up diverter. Function test diverter. Directional drill 9-7/8" hole from 121' to 1005' POOH to pick up insert bit. 113,578 CUM:$ 195,313 ETD:$ 0 EFC:$ 1,475,313 MW: 9.2 VISC: 46 PV/YP: 17/14 APIWL: 6.6 CIRC & COND F/CSG Directional drill 9-7/8" hole from 1005' to 4550' Circ. Pump iow/hi vis sweep. No additional cuttings from sweep. Condition mud. Wipe hole, pulled free to 3899. Backreamed from 3899 to permafrost. 77,118 CUM:$ 272,431 ETD:$ 0 EFC:$ 1,552,431 MW: 9.3 riSC: 63 PV/YP: 28/22 APIWL: 6.4 NIPPLE UP Continue back reaming out of hole to 1469' Pull out to 1284' hole free. RIH to bottom, no fill, no tight hole. Rig up to run casing. Held pre-job safety meeting. Run 7-5/8" casing to 4540' Cement stage one. CIP at 2345 hrs. 9/19/96. 163,297 CUM:$ 435,728 ETD:$ 0 EFC:$ 1,715,728 MW: 8.5 VISC: 33 PV/YP: 4/ 4 APIWL: 18.5 DRILLING Cement 7-5/8" casing, stage 2. CIP @ 0210 hrs. 9/20/96. Wash and ream to 4217' drill out cement to 4432'. Drill cement and float collar at 4452' 104,651 CUM:$ 540,379 ETD:$ 0 EFC:$ 1,820,379 MW: 8.8 VISC: 37 PV/YP: 7/ 8 APIWL: 9.8 POOH F/BIT Drill cement, shoe at 4550 and 10' new hole to 4560' Perform LOT to 12.0 ppg. Directional drill 6.75" hole from 4560' to 5290' Hole packing off. Circulate and pump hi-vis sweep. Wipe hole to shoe, free. Wash bottom 5' Directional drill 6.75" hole from 5290' to 6509' 74,359 CUM:$ 614,738 ETD:$ 0 EFC:$ 1,894,738 MW: 8.9 rISC: 38 PV/YP: 8/ 7 APIWL: 8.6 MILL & CIRC OUT SWEEP Directional drill 6.75" hole from 6509' to 6931' Packing off and torquing up on bottom. Circulate pump hi-vis sweep. POOH. Change bit. Cutting structure completely gone. Wash from 6752 to 6931' Drill on junk. Drilled from 6936' to Date: 11/15/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 DAILY:$ 6950' POOH. Change bit. Make up concave junk mill and boot baskets. RIH w/rotary assembly. 79,480 CUM:$ 694,218 ETD:$ 0 EFC:$ 1,974,218 09/23/96 (D 8) TD: 7099' (147) S UP V: RLM DAILY:$ MW: 9.0 VISC: 41 PV/YP: 13/ 8 APIWL: 6.6 DRILLING RIH w/mill and boot baskets. Wash through tight spot. Wash from 6729' to 6952' Mill on junk from 6952' to 6955' POOH. RIH. Directional drill from 6955' to 7099' Shallow test MWD. 73,763 CUM:$ 767,981 ETD:$ 0 EFC:$ 2,047,981 09/24/96 (D 9) TD: 7877' (778) SUPV:RLM DAILY:$ MW: 11.0 rISC: 42 PV/¥P: 15/ 8 APIWL: 5.4 DRILLING Directional drill from 7099' to 7609' Drill pipe plugging while mixing LCM. Perform open hole FIT to 12.7 EMW at shoe. Pulled drill pipe screen and found poorly processed LCM in screen. Further investigation indicated that quality control at the mill to be the cause. POOH, wash and blow LCM off top of RA source and retrieve same. Lay down slim 1 tool jammed with large pieces of LCM. Directional drill 6.75" hole from 7609' to 7877' 0 CUM'$ 767,981 ETD'$ 0 EFC'$ 2,047,981 09/25/96 (D 10) TD: 9010' (1133) SUPV:RLM DAILY:$ MW: 11.2 VISC: 48 PV/YP: 20/16 APIWL: 4.2 CIRC AND WT UP Directional drill 6.75" hole from 7877' to 9010' CBU. 79,207 CUM:$ 847,188 ETD:$ 0 EFC:$ 2,127,188 09/26/96 (D 11) TD: 9010' ( 0) SUPV: RLM DAILY:$ MW: tl.8 VISC: 50 PV/YP: 21/14 APIWL: 4.4 RUNNING CASING Make several wiper trips. Mud cut with gas and oil from 11.2 to 11.5 ppg. 79,496 CUH:$ 926,684 ETD:$ 0 EFC:$ 2,206,684 09/27/96 (D 12) TD: 9010' ( 0) SUPV:RLM DAILY: $ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RUNNING TUBING Held pre-job safety meeting. Run 4.5" and 5.5" casing to 4522' Run 5.5" casing to 6969' Circulate. Lost returns. Fluid falling on back side. Continue in hole with 5.5" casing to TD. Pump cement. Cement casing. Partial returns during job. CIP at 1912 hrs. 9/27/96. 162,423 CUM:$ 1,089,107 ETD:$ 0 EFC:$ 2,369,107 09/28/96 (D 13) TD: 9010' ( 0) S UP V: RLM DAILY:$ MW: 0.0 rISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RELEASED F/3J-19 Nipple up BOPE. Test all new and reconnected flanges to 300/3000 psi. Run 3.5" completion. Test casing to 3500 psi for 30 minutes. Test 3.5" tubing and 5.5" x 3.5" annulus to 3000 psi for I0 minutes each. ND BOPE. Freeze protect 7-5/8" x 5.5" annulus. Release rig @ 12'30 hrs. 9/28/96. 143,305 CUM:$ 1,232,412 ETD:$ 0 EFC:$ 2,512,412 End of WellSummary for WetI:AK8637 PAGE *********** ~]RVEY PROGRAM COMPANY ARCO ALAS~A~ INC. WELL NAME 3J-19 LOCATION 1 k~PAR~JE LOCATION 2 ALASEA MAGNETIC DECLINATION 27,74 GRID CONVERGENCE ANGLE 0,00 DATE: 17-SEP-% WELL NUMBER 0 WELL HEAD LOCATION: LAT(N/-S) 0.00 AZIMUTH FR~M R~TARY TABLE TO TARGET IS TIE IN F~INT(TIP) : MEASURED DEPTH 121,00 TRUE VERT DEPTH 121,00 INCLINATION 0,00 AZIMUTH 0,00 LATITUDE(N/-S) 0,00 DEPARTURE(E/-W) 0,00 DEP(E/-W) 338,23 0,00 ************* ANADRILL ~************ SURV~i~ CALCULATIONS **********.*** CIRCL~AR ARC METHOD******** M~S1JRED INT~g~L V~ffiCA~ DEPTH DEPTH ft ft f% 121,00 0,0 121.00 284,82 163,8 284,82 375.14 ~.3 375.13 469,07 ?3,? 4..58,90 554,96 85,9 554.18 TARGET STATION AZIMLffH LATITUDE S~CTIOH INCLN, N/-S f~ deg. deg. ft 0.00 0,00 0.00 0,00 -0.96 0.73 135.20 -0.74 -0,94 1,18 284.65 -0,91 1,2I 5,22 269.89 -0,68 6.98 8.43 291.59 1.63 DBOARTURE DISPLACB~EN? at ft ft 0.00 0.00 0.74 i.~ 0,24 0.94 -4,97 5,02 -14,74 14,83 AZIMUTH dea 0,00 135.20 165,22 262.24 276,33 DIS deg/ lOOft 0,00 0.45 2,04 4.35 4.73 645,67 740,24 832,26 920,33 1016.65 90,7 643.71 ?4.6 736.70 92.0 826.79 88.1 912.55 96.3 1005.88 17.89 t0.08 301.27 8.20 -27,70 28.89 32.68 !0.98 3t3,47 18.69 -41.~ 45.35 49.68 12.53 313,15 JI,~. -54.96 63.37 67,97 13.78 315.05 45,50 -69,34 82.93 90.14 14.84 318.70 62.89 -85.58 i06,20 286,49 294.34 299,86. 303.28 306.31 2,49 2,54 1,68 1.50 1,45 1108.38 1199.65 1293.54 1284.44 1476,33 91.7 1094,43 91.3 t182.02 93.9 1271.15 90.9 13~.04 91.9 1439.72 113,06 i5.44 324,05 81,60 t28.05 17.18 326.66 102,71 i66,98 i9.44 3~_7.15 127.43 198.79 22.41 326,57 154,60 235.85 26.38 323.13 185.98 -100,50 129.46 309,08 1.66 -115.05 154,22 311.76 2,07 -131,15 182,86 314.18 2,41 -I48.90 214,64 316,08 3.27 -170.22 252,12 317.53 4.37 1569.21 1638.87 1730.02 1844,66 1926,37 92,9 i522.02 69.7 1599,60 91,2 1675,90 94.7 1752.60 91.7 1824.85 277,75 28,82 325,12 221,27 321,65 31.33 326,68 258,49 370.69 34.99 329.07 300.72 425,61 36,78 221,14 348.63 48i,66. 39,20 3~,05 398,47 -194,63 294,82 318.64 2.62 -220.00 33¢,44 319,60 2,94 -246,46 388.82 320.66 4,25 -274,09 443,63 321,64 2,29 -300.92 499.33 322.94 2.71 2029.60 2121.23 2213,97 2394.80 2858.75 93,2 18~.75 91,6 t962,53 9~.7 2027.55 180.8 2152,42 463.? 2470,54 541,90 41,79 233,17 452,22 604,49 44,62 325,88 508,86 670,60 46.36 339,5-/ 570,06 801.22 ~,31 340,78 6~,i0 1128.61 47,11 341.30 1012,47 -328,76 559.09 322,98 2.88 -255.69 620,65 325.05 3,71 -380.73 685.50 326,26 3,39 -425,0B 813,07 328,48 0.49 -534,79 1145,04 332.16 0,19 3230,06 3505,54 2~68,42 4246,30 4468,84 371.3 275.5 2910.98 462.9 3221.53 277.9 3406.04 222,5 2552.56 1409,67 ~.84 341,~ 1269.67 1611,58 47.60 34!.21 1461.19 1954,56 ~.13 329,61 t784,54 2162,27 48,66 3.'39.97 1979.54 2329,64 .48,97 340.72 2137,26 -621,62 1413.68. 3312.91 -686.46 !614,41 334.64 -801,57 1956.30 325,81 -873.26 2162,64 336.19 -929,70 2330,7I 33~,49 0.28 0.28 0,22 0,29 462!,02 4886.86 5!51.50 543~,07 5716,20 152.2 3653.32 265,8 3828,87 264.6 4OO4.72 286.,6 4197.90 ~8,1 4285,06 2443.66 48.13 236,60 2243,48 2642,89 49,32 345,i3 2431,94 2829.85 47.41 341.20 2621.21 3051,29 47,82 340,~ 2821.26 ~5&.92 47,60 3~W,54 3014.72 -971.17 2444.66 336.59 -1036,42 2643.58 336.~ -1093,58 2840.19 337,35 -1162,74 3051,47 227,60 -t232.77 3257.03 337,76 2,10 2,45 1,32 0,20 0.31 59?2.87 6269,05 6546,54 6823,06 7192,89 276.7 457!,11 276,2 4757,13 277,5 4945,67 ~o.~ 5132,45 369.8 5373.92 3461,63 47,88 339,58 3206,59 3663.65 47,44 340,70 3298.58 3869,10 46.96 340,19 3590,44 4072,01 47,53 3.35.22 3778,25 4352,81 51.36. 3~.52 4037.~ -i304.28 3461,70 337.87 -1373.64 3665.66 337,'~ -t441.78 286.9,10 338,12 -1518,62 4072,02 338,i0 -1626,15 4252,83 338,06 0.10 0,34 0,22 1,31 1,35 PAGE NO. 3 ************* ANAl)RILl. *********~**** ~dRqJb"Y CALCULA?IO~IS ************* CIRCULAR A.RI~ METHOD******** MB~SURED INTB~VAL VE~!CAL TARGET STATION AZIMUTH LATII"dI)E DBPARI~]RE DISPLAC~M~T ~t AZI~TH DLS DE~H D~ S~I~ INC~4. ~-S ~-W d~ ft ft ft ft ~eg deg ft ft ft deg l~ft 7377.02 t~4.1 5487.11 4498,01 52,79 336,~ 4172,!6 -1680,8~ 4498,03 ~B,06 1,61 ~68,46 I91.4 5607.72 ~46.61 49.11 3~,95 4~9.97 -!7~.47 ~646,63 338,06 2,45 7753,60 185.1 57~.91 47~,79 47,47 337,45 ~,73 -1786.~ 4784.81 ~.07 1,34 7935,21 I~1,6 5854,32 4918,02 46.93 3~.89 4~2.~ -1~5,11 4918.03 338.09 1,03 ~.62 ~.4 5915.5! 498!,80 45.47 3~.02 ~.78 -!8~.98 4981.8! 3~,11 1,65 6!17.09 '~5,5 5965,55 ~)46.53 40~10 .342.47 4684.13 -1677.66 5046,53 338.].5 5,69 8307,73 188,6 6134,16 5162.25 35.91 343.59 47~,1~ -I9!!.8,3 5162o25 338,26 2°25 6869.00 561~3 6627.83 5424.16 20.25 345.24 5048.58 -198,3.52 5424.25 338.55 2.79 9010.00 141.0 6760.12 5472.60 20.25 345,24 ~(F/'5,77 -1~5,75 5472.72 3~.61 0.00 ***********~ *********,******* KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(3J-19(W4-6)) WF:I I. JOB SCOPE 3J- 19 PERFORATE, PERF SUPPORT DATE DAILY WORK 11/01/96 SLT-J WELL LOG AND INITIAL A SAND PERFS DAY 1 DAILY OPERATION COMPLETE ] SUCCESSFUL NoI No Initial Tbg Press [Final Tag Press [Initial Ihner Ann i 0 PSII 900 PSII 950 PSI SUMMARY JOB NUMBER 1017961009.4 UN1T NUMBER KEY PERSON SUPERVISOR S. DECKERT JORDAN Final Inner Ann I Initial Outer Ann I Final Outer Ann 950 PSII 700 PSI] 700 PSI SLT-J WELl. LOG COMPLETE. PERF A SAND INfERVAL AT 8612'-8632' W/2-1/8" BIG HOLE ENERJET; 2SPF AT - 90 DEG FROM LOW SIDE OF HOLE; 2 SPF AT + 90 DEG FROM LOW SIDE OF HOLE, RDFN. TIME LOG ENTRY 09:00 MIRU SWS E-LINE` PRE PERF TGSM, PT BOP/LUB OK. SIWHP 0. 10:00 RIH W/SLT-J; GR; WB. 2-1/8" X 32'.LOGGED 8858'-8300'; TD 8867' ELM. POOH 13: 00 RD SLT-J 13:30 RIH W/20'; 2SPF; 2-1/8 E J; GR; WB. MAINTAIN 1320 WHP.PERF 8612'-8632' @ -90 DEG FROM LOW SIDE OF PIPE. WHP DROP TO 1240. POOH. 16:00 RIH W/20'; 2SPF; 2-1/8 EJ; GR; WB. WHP 900.PERF 8612'-8632'@ + 90 DEG FROM LOW SIDE OF PIPE, WHP 900. 18:30 RDFN. KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(3J-19(W4-6)) Wlq I. JOB SCOPE JOB NUMBER 3J-19 PERFORATE, PERF SUPPORT 1017961009.4 UNiT NUMBER DATE 11/02/96 DAY 2 DAILY WORK SLT-J WELL LOG AND INITIAL A SAND PERFS OPERATION COMPLETE ISUCCESSFUL NO I YES Initial Tbg Press Final Tbg Press Initial Inner Ann 920 PSI 800 PSI 1150 PSI KEY PERSON S. DECKERT SUPERVISOR JORDAN Final Inner Ann I Initial Outer Ann I Final Outer Ann 1150 PSI[ 700 PSI I voo PSI DAILY SUMMARY PERF A SAND IN'I~RVAL @ 8592'-8612' W/2-1/8" BIG HOLE ENERJET; 2 SPF AT -90 DEG FROM LOW SIDE OF HOLE; 2 SPF AT +90 DEG FROM LOW SIDE OF HOLE. GUNS STUCK AT 2-7/8" GLM @ 6822'. PULLED OFF AT RS. FISH IS 1-3/8" OTIS FN; MH22/AH38/2-1/8"X6' WB/CCL/2-1/8" MPD/2-1/8" El HEAD/22' STRIP GUN TOTAL OVERALL LENGTH IS 32.5'. STRIP GUN IS FIRED. TIME LOG ENTRY 09:00 MIRU SWS E-LINE UNIT. P/T BOP, LUB OK. 10:00 RIH W/20' X 2-1/8" EJ 2 SPF; 2-1/8" X 6' WB; CCL; MPDPERF 8592'-8612' @-90 DEG FROM LOW SIDE OF PIPE. WHP 910. POOH.ALL SHOTS FIRED. 12:30 RIH W/ 20' X 2-1/8" EJ 2 SPF; 2-1/8" X 6' WB; CCL; MPDPERF 8592'-8612' @+90 DEG FROM LOW SIDE OF PIPE. WHP 810. POOH. 14:0 0 GUN STRIP STUCK AT 2-7/8" GLM 6822'. WORKED CABLE, PUMPED FLUID, BLED OFF;UNABLE TO FREE STUCK FISH. 15: 3 0 WORKED CABLE UP TO MAX. - RAPID PUI~ AND MAINTAINED PULL. UNABLE TO FREE STUCK FISH. 17:15 PULLED OUT OF RS. TOP OF FISH @ 6798' 1S 1-3/8" OTIS FISHING NECK. FISH IS MH22//AH38/2-1/8" X 6' WB/CCL/MPD/2-1/8" ~EJ HEAD/22' STRIP-32.5' OVERALL.STRIP GUN IS FIRED-UNCONFIRMED 19:0 0 RD SWS. HES TO FISH TOOL STRING. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10543 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 11/6/96 Field: Well Job # Log Description Date BL Kuparuk (Reservoir Analysis Logs) RF Sepia Floppy' Disk 2 X- 13 ~ c~ _ I-7 c'I PRODUCTION PROFILE 9 61 0 0 8 I 1 3A-17 ¢~- 1"~ CBL 961029 I 1 3A-18 c~ Lo '~ I~?P CBL 961031 I 1 3J-19 ~ - 1 ~ ~ CBL 961101 I 1 1 E- 19 ~'~ '" O I "? INJECTION PROFILE 961 01 9 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: .CEIVED NOV 0 8 1996 Anchorage PflRKER-2~5 ARCO ID:907-$59-7105 .~_ OCT 03 ~'.96 ',~.~, 10:02 No.O12 P.O1 Calculations Chart Subject File RV Sheel numbor of Date Z.q ~ 405~ · , I Alaska Oil & Gas Cons. Com~tss~dn Anchorage 158-50~1 P~RKER-245 ID'907~659-?106 OCT 03'~6 10:0~ No.O12 P.02 ARCO Alaska, Inc. Poet Office Box 100360 Anchorage, Alaska 911510.03§0 Telephone 907.276-1215 October 3, 1996 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Annular Pumping Approval for KRU Well 3J-17 Dear Mr. Johnston: Kuparuk River Unit Well 3J-17 was permitted to drill on Semptember 13, 1996. The permit application included a request to approve this well for annular pumping operations for the period of one year. The application included information specified in the proposed regulations 20 AAC 25.080, but approval was contingent on the subsequent submittal of a Form 10-403 describing the well's surface casing cement job. Information included in the permit to drill application is not repeated here since it has already been submitted to the AOGCC. We believe that the 3J-17 surface cement job will provide an adequate seal for annular pumping operations and that the well has been cased and cemented according to regulation. ARCO Alaska, Inc., requests approval to commence annular pumping operations on this well as needed for waste disposal as described in the Permit to Drill application. If you have any questions or input on tlxe request for approval, please contact the Drilling Engineer, Denise Petrash at 263-4183, or myself at 265~6206. Mik~E~ghi Drill Slte Development Supervisor RECEIVED OCT 0,3 !998 Alaska Oil & Gas Cons. Commission Anc,%rago P~RKER-2~5 ID~907-659-7106 OCT 03'~6 10'03 N0.012 P.03 STATE OF A~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ Alter casing _ Repair well_ Change approved program_ 2. Name of Operator :ARCO Alaska. Inc. 3. Address P, O, Box 100360, Anchorage, AK 99510 Type of Well: Developmenl Exploratory Stratlgraphlc Servlc~. Operation Shutdown_ Re-enter suspended well _ Plugging _ Time extension _ Stimulate _ Pull tubing._ Variance _ Perforate _ Other _X_ 6. Datum elevation (DF or KB) ~4. Location of well at audace 710' FSL, 563' FWL, Sec. 3, T12N, RSE, UM At lop of productive interval 2454' FNL, 2116' FEL, Sec. 10, T12N, RSE, UM (planned) At effective depth At total depth 2775' FNL, !...847' FEL, Sec, 10, T12Nf R9E~ UM {planned) 12. Present well condition summary Total Depth: measured 4775' feet Plugs None true vertical Rio RKB 41' Pad level 45' fee~ ___ 7. Unll or Property name Kuparuk River Unit 8. Well number 3J-17 9. Permit number .... 96:14_8 10. APl number so.029-22702 11. Field/Pool KUparuk River Field .~-.K..up.a_._.rpk:__River Oil Pool 3974' feet (Note: drilling ahead @ 00:01 10/3/96) Effective deplh: measured 4775' feet Junk None true vertical 3 9 7 4' feet Casing Structural Conduclor Surface Intermediate Production Liner Perforation depth: Length Size 8O' 16" 4329' 7-5/8" measured Nc)ne true vertical Cemented Measured depth True vertical deplh 250 Sx AS I 1 21' 180/1010 sx AS 4450' i11; 352 sx Class G; & 60 sx ASI 121' 3730' ORIGINAL Tubing (size, grade, and measured depth Hone Packers and SSSV (type and measured depth) None 13. Attachmentg Description summary of proposal X Detailed operation program __ BOP sketch _ 14. Estimated date for commencing operation 16, If proposal was verbally approved Name of approver Date approved 15, 81atus of well classlllcallon as: Oil X Gas __ Suspended __ Service ' ' ~ _~q'/~ -~ FOR COMMISSION USE ONLY Conditions ~' appr-6~ii"- N~t~f'~ IIApprovaIoJ~Io~,_/C~ ~ Is true and correct to the besl o! my knowledge. Tills Drill Site Dev. Supv. Commission so represenlatlve may wi[ness Plug integrity ~ BOP Test Location clearance Mechanical Integrity Test Subsequent form require 10- - OrigJHa[ Signed By · / David W. Johnston CommbsIoner Date /~ % ]oj ~., SUSM~T ~N YnihUOATE ' ' Approved ,by the order el the ,C,,,ommission Form 10-403 Rev 08/15/88 ix. Sn~.~e6 RECEIVED 0CT 0 3 1996 Alaska Oil & C-~,s 0oDs. 0ommission Anohora§9 PflRKER-245 OCT 03~6 10:04 No.O12 P.04 KRU 3J~17 Annular Pumping Permit Application Additional Information Please see the attached "Cementing Details" form for Well 3}'-17 for basic details on the cementing operation. Additional information is offered below in support of ARCO Alaska Inc.'s opinion that the surface casing cement job will provide adequate sealing capability for annular pumping operations, and that the well has been cased and cemented according to regulation (AAC 25.030). Surface Hole TD: 4469' MD / 3735' TVD Surface Hole Conditions: Tight spots were seen from mid-West Sak to the base permafrost during the wiper trip at TD, but these were cleared up prior to pulling out of Ihe hole. Casing was run to bottom without problems, with precautionary circulation occurring at 1946'. No fill was seen on bottom. Full returns were seen at all times. Stage Tool Placement: 3J-17 was cemented as a two stage job using Halliburton's Type ti'ES Cementer placed at the base permafrost (1862' MD). Casing Placement: The casing was reciprocated until approximately halfway through the first stage cement job. The pipe was completely free prior to this point. The surface casing shoe was placed at 4450' MD, 19' off bottom. 10-20' off bottom is the planned standard with fluted casing hanger assemblies. Cementing Details: Full returns were seen while circulating on bottom prior to cementing (+10 bpm) and during the cementing operation itself (9-11 bpm) until after starting the displacement. After this point returns gradually decreased as the rig attempted to continue displacing to get cement to surface. The water spacer was seen at the flowline and 10.0 ppg contaminated cement returns were found at the wellhead. 1" line was run to 422' and AS III cement pumped for the top job per AOGCC inspector approval. Excess on the first stage lead cement was 40%, with 35% on the tail cement; cement- contaminated returns were seen after opening the cementer and circulating in preparation for the second stage. The second stage of AS III lead and 60 sx of AS I tail consisted of all the cement present on location. The first stage excess factors were based on historical data (3A-I7 surface hole bond log) and surface hole caliper logs performed at Milne Point, and were very conservatively calculated with the intent of bringing tail cement to 500' above the top of West Sak. Based on the data, there should be an adequate seal for safe annular pumping operations. Diagnostic Logs: None. RECEIVED OCT O,3 1998 Alaska Oil & C-as Cons. Commission Arichorag~ PF:IRKER-245 ID-~qO?-659-?106 OCT 03"'~B '10'04 Nc.O'12 P.05 ARCO Alaska, Inc. Cementing. Details 'Well#: Casing Size 7 5/8" Certtralizers Mud 3J- 17 Field: KUPARUK Date: Hole Diameter Hole Angle I Shoe Depth Float Depth 9 7/8" 38~, ] 4,450' 4,363' State type used, intervals covered and spacinE 26 Gemco centralizers. 4 Gemeco Stop Collars. g/20/g6 washout Weight 9.6/9.2 Gels before YP(prior cond) 22 lbs/100 It2 Gels after YP(afler cond) [PV(prior cond) 18 lbs/100 fl2! 26 cP Total Volume Circulated PV(after cond) 21 CP Spacer Lead Cement STAG E 1/2 Tail Cement 12:26 Type Water 5:09 Type I Mix wtr tamp AS 3 I 60 ~,dditives 25 #/ak D2g 300 ,b.b.!s..,.@_!!- Volume 40/40 No. of sacks 180/1010 ~p.m__, __80o- ps! Weight 8,3 PPG Weight Yield 12.1/12.1 1,94 Type IMixwatertempl Ne. of sacks ! WeightI Yield G/AS 1 60 352/60 15.8/15.7 1.15/0.93 STAGE 1/2 Displacement ADDITIVES STAGE 1' G , 0.25 #/ak D29, 0.2% D46, 0.3% D65, 1% S001 ADDITIVES STAGE 2: G , 0.25 #/ak D29, 0.2% D46, 0...3.%.. D_.65, Rate(before tail at shoe) 9.1 8/5 Reciprocation length 15' Theoretical Displacement 200.5185.45 STAG E 1/2 Calculated top of cement surface Remarks: Rate(tail around shoe) 9.18/5.9 Reciprocation speed 10 Actual Displacemenl 167.365/62.985 ..%..SOp_I ............. Str. Wt. Up 4454 Str. Wt. Dh. 4454 Str. Wi, Mud ?? ClP lO/1/96 Bumped plug IFIoats held 0529/0802 yes/yes yes/yes Include whether full returns were obtained, reciprocation throughout operati_o_n_ and any other perllnent information, Stage 1' Had full returns while circulating, cementing, and displacing. Stopped reciprocating 1200 strokes (102.b._bl)..~to displacement. Opened tool w/3300 p_si, Circ @ 11 bpm @ 650 psi for 447 bbls Stage 2: Had returns as follows durin,g..displacement. 121 bbl-dropped 30% to 20%, 136 bbi- dropped to 13%, 162% ino to 26%, 187 bbl de~ to 18%, 200 bbl dec to 12%, 247. bbl dec to 2~ dec rate to 5 bpm, 275 bbl dec to 0%_ FInlshed displacing @ 60 sp @ 700 psi. Fluid in stack Neighed 10.0 PP__g_on pressure scale/9.8 ppg regular scale. Closing sleeve tripped @ 1700 psi. rep job: Washed unset cement out to 422' K.B, Pumped 55 bbl ASIII and had cement to surface .tier 47 bbl pumped. Bobble Foster, AOGCC, witnessed washinq out of annulus and ga..ve.app.r0v.; to continue operation. Cement company Dowell IRig Contractor Parker Signature R. L. Morrison Jr. RECEIVED OCT 0 3 199~ P~RK£R-245 ZD,.:~?O?-SBg-?lOB OCT OS UqB LO'05 No.OL2 P.OB CASINP~ AND LEAK-OFF FRACTURE TEST,~ Well Name: KRU 3J-17 Supervisor: G.R, Whitlock Date: 10/2/96 Casing Size and Description: 7 5/8, 29.7#~ L-80t BTC MOD Casing Setting Depth: 4449' TMD 3720' -rVD Mud Weight: 9,1 ,ppg EMW -- Leak-off Pressure (PLO) + MW 0.052 x TVD LOT #1 ~ 1400 pst / (0.052 x 3720 ft) + 9.1 ppg -- 16.3 ppg Hole Depth (md)-- 44479 Fluid Pumped .= 1.36 bbls. Pump output = .085 bps 2000 1800 1700 1600 1500 1400 1200 1100 1000 700 600 5OO 400 3OO ~00 100 ......... ,. /n iii nm .............../ ' .... nnl''"' lull "'I · ........... ,1 l: l .... '- :i,,,iS_L --- ................ ,~..~ · _~,. .. .... .?__ ................................ ! ............................... /?' ............ ' I* '" ............ .......................... k~K-OF~ TfiST~ C~ING TEST ...... ~ STROKES PflRKER-245 ID :~907-659-7106 OCT 10'06 No.O12 P.07 CASING AND LEAK-OFF FRACTUR[~ TESTS Well Name: KRU 3J-17 Supervisor: G,R, Whitlock Date: 10/2/96 Casing Size and Description: Casing Setting Depth' Mud Weight: 9.1 LOT/I1 -- I800 psi / (0,052 x 3720 ft) + 9.1 ppg = 18.4 ppg Fluid Pumped = 1.70 bbls. 7 5/8t 29.7#~ L-80, BTC MOD 4449' TMD 3720' TVD ppg EMW = Leak-off Pressure (PLO) ~ MW 0,0,52 x TVD H01e Depth (md)= 4519 Pump output = .085 bps 2000 1900 1600 1700 1500 1500 1400 1200 11o0 10oo 9oo 8oo 7oo 600 500 400 $oo 200 100 0 ARCO Alaska, Inc.. .... Post Office 100360 Anchorage .... ska 99510-0360 Telephone 907 276 1215 September 23, 1996 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subiect: Annular Pumping Approval for K~U Well 3]-19 Dear Mr. Johnston: Kuparuk River Unit Well 3J-19 was perrrdtted to drill on Semptember 4, 1996. The permit application included a request to approve this well for annular pumping operations for the period of one year. The application included information specified in the proposed regulations 20 AAC 25.080, but approval was contingent on the subsequent submittal of a Form 10-403 describing the well's surface casing cement job. Information included in the permit to drill application is not repeated here since it has already been submitted to the AC)GCC. We believe that the 3J-19 surface cement job will provide an adequate seal for annular pump~g operations and that the well has been cased and cemented according to regulation. ARCO Alaska, Inc., requests approval to commence annular pumping operations on this well as needed for waste disposal as described irt the Permit to Drill application. If you have any questiom or input on the request for approval, please contact the Drilling Engineer, Denise Petrash at 263-4183, or myself at 265-6206. Drill Site Development Supervisor AR3B-(;003-!33 ~47~-?,503 KRU 3J-19 Annular Pumping Permit Application Additional Information Please see the attached "Cementing Details" form for Well 3~-19 for basic details on the cementing operation. Additional informatiorr is offered below ir~ support of ARCO Alaska Inc.'$ opinion that the surface casing cement job will provide adequate se~li_ng capability for annular pumping operations, and that the well has been cased and cemented according to regulation (AAC 25.030). Surface Hole TD: 4550' MD / 3606'TVD Surface Hole Conditions: Tight spots were seen from mid-West Sak to the base permafrost during the wiper trip at TD, but these were cleared up prior to pulling out of the hole. Casing was run to bottom without problems, with precautionary circulation occurring at 2118'. No fill was seen on bottom. Full returns were seen at ail times. Stage Tool Placement: 3}'-19 was cemented as a two stage job using Halliburton's Type H ES Cementer placed at the base permafrost (1790' MD). Casing Placement; The casing was reciprocated until approximately halfway through the first stage cement job. The pipe was completely free prior to this point. The surface casing shoe was placed at 4540' MD, 10' off bottom. 10-20' off bottom is the planned standard with fluted casing hanger assemblies. Cementing Details: Full returns were seen while circulating on bottom prior to cementing (+10 bpm) and during the cementing operation itself (7.1-7.6 bpm) until the rig shut down to drop the cementer closing plug with 11.0 ppg cement at s~rface. After this point returns were almost completely lost when the rig attempted to continue displacing cement to surface. Excess on the first stage lead cement was 50%, with 35% on the tail cement; cement-contaminated returns were seen after opening the cementer and circulating in preparation for the second stage. The second stage of AS III only was pumped until cement returned to surface. The first stage excess factors were based on historical data (3A-17 surface hole bond log) and surface hole caliper logs performed at Milne Point, and were very conservatively calculated with the intent of bringing tail cement to 500' above the top of West Sak, Based on the data, there should be an adequate seal for safe annular pumping operations. Diagnostic Logs: None. ARCO Alaska, Inc. Well#: Casing Size 7 5/8" Cementing Details 3J-19 Field: KUPARUK Date: 09/20/96 Hole Diameter Hole Angle I Shoe Depth Float Depth I % washout 9 7/8" 49° ! 4,540' 4~452' I State type used, intervals covered and spacing 24 Gemco and 2 B&W centralizers. 4 Gemeco Stop Collars. Centralizers Mud Spacer Weight 9.519.3 Gels before 6/9 Type Water YP(prior cond) 23 lbs/100 It; Gels after 5/9 YP(after cond) I PV(prior cond) 22 lbs/100 ft21 27 cP Total Volume Circulated 538 bbls @ 11 Volume 40/40 bpm, 700 psi PV(after canal) 25 cP Weight 8.3 PPG _ Lead Type IMix wtr temp No. of sacks Weight Yield Cement AS 3 [ 60 210/587 12.1/12.1 1.94 Additives .25 #/sk D29 Cement G 60 450 15.8 . 1,15 Additives G ~ 0,25 #/sk D29~_0.2% D46, Rate(before tail at shoe) 7.1 Reciprocation length 15' Displacement Theoretical Displacement 204.5 ICIP g/19-20/96 2345/021 0 Calculated top of cement isurface 0.3% 065, 1% S001 Rate(tail around shoe) 7,3 Reciprocation speed 10 fpm Actual Displacement 212,4 Bumped plug I Floats held YES/YES I YES/YES Sir, Wt. Up 180 Sir. Wt. Dn. 140 Str. Wt. Mud 140 Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. Circ.: full returns while circulating and reciprocatin,9, Stage #1:210 sx. AS 3 followed by 400 sx "(3". Had full returns while cem'er~ii'nq and displacing. Reciprocated casinc, i until 134 bbls of 212 total bbls of displacement had been pumped, At that ti the casin~] started floating on the up slroke and 20K was lost on down stroke. Full rtns, on stage l Displaced Sta,(]e #1 with 10.2 bbls 15.8 cement, 25 bbls wash water and 177,2 bbls mud. _Stage #2: Opened ES cementer w/3030 psi. After circulating 101 bbls had cemented contaminat~ mud to surface (17.6 bbls over ~au~e)..C[rc,ulate and condition mud 510 bbls, 7.6 bpm at 500 p.s Put 40 bbls water ahead and pumped 203 bbls 12.1 cement, Had 8.7 spacer to surface after pumping 130 bbls cement, 10.6 cmt to surface I80 bbls cmt a_way, 11.0 cmt to surf 200 bbls cmt away. Pumped a total of 203 bbls 12.1 cmt. Returns started diminishing as displacement began. After displacincJ 25 b_b.l.s:..r..eturn, s were less than 10%. Max. cmt wt. to surf. was 11.0 Steele #1: tail out shoe 400 psi at 7.1 bpm/final press. 1150 psi at 7.3 bpm. Stage #2: lead out cementer 200 psi at 4.8 bpm/final press. 500 psi at 4.9 bpm. Cement Company {Rig Contractor ISignature ;~,, Dowell I Parker IR. L. Mordsen Jr. ' ::" ~-- ? ~" ' CAGING AND LEAK-OFF FRACTURE TE~. ,~ Well Name: KRU 3.1-19 Supervisor: R.L. Morrlson Jr. Date: 9/21/96 Casing Size and Description: Casing Setting Depth; Mud Weight: 8.,55 7,5/8~ 29.7#I L-80~ BTC MOD 4540' TMD ppg 3599J TVD EMW = Leak-off Pressure (PLO) + MW 0.052 x TVD LOT #1 = 645 psi / (0.0~2 x 3,599 ft) + 8.55 ppg = 12.0 ppg Fluid Pumped = 1.80 bbis. Fluid bled back = 1.5 Hole Depth (md)= 4560 Pump output = ,085 bps 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 $00 400 300 200 100 0= I . [',~//II I I LEAK-OFF TEsT 23. 1996 8'54AM ARCO ALASKA iNC ARCO Alaska, Inc. Pos! Office Bo^ t00360 Anchorage, Alaska 99510-0360 Telephone 901 276 1215 September 23, 1996 Dave Johnston Commission Chain'nan Alaska Oil and Gas COnservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subiect: Annular Pumping Approval for KRU Well 31-19 Dear Mr. Johnston: Kuparuk River Unit Well 3J-19 was permitted to drill on Semptember 4, 1996. The permit application included a request to approve this well for annular pumping operations for the period of one year. The application included information specified in the proposed regulations 20 AAC 25.080, but approval was contingent on the subsequent submittal of a Form 10-403 describing the well's surface .casing cement job. Information included in the permit to drill application is not repeated here since it has already been submitted to the AOGCC. We believe that the 3J-19 surface cement job will provide an adequate seal for annular pumping operations and that the well has been cased and cemented according to regulation. ARCO Alaska, Inc., requests approval to commence annular pumping operations on this well as needed for waste disposal as described in the Permit to Drill application. 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 AR3D-G003-93 ~a2.,-2603 ~ Sep. 23. 1996 8'55AM ~0. 1~7. b h z/o 4.~ ARCO ALASKA !NC STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type ol~ Request: Abandon_ Suspend Operation Shutdown Re-enter suspended well _ Alter casing _ Repair welT_ Plugging _ Tim~ extension _ Stimulate Change approved program_ Pull lubing _ Variance _ Peri'orate _ Other · 2. Name of Operator 5. Type of Well: ti. Datum elevation (DF or KB) Development Ria RKB.41' Pad level 45' feet ARCO Alaska. Inc. Exploratory _ _ ~. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River.U. nit 4. Location of well at surface 8. Well number 930' FSL, 565' FWL, Sec, 3, T12N, R9E, UM 3J-19 - . .... At top ol productive interval g. Permit number 4829' FNL, 829' FEL, Sec. 32, T13N, RgE, UM (planned) 96-148 At effective depth 10. APl number 50.029-22702 At total depth 11. Field/Pool Kuparuk River Field 4460' FNL~ 960' FEL~ Sec, 32, T13N~ RgE, UM (planned) Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 6952' i'eet Plugs None true vertical 5220' feet (Note: dril,ing @ 6952'1~:~..._9{2~/~)~)~. Effective depth: measured 6952' feet Junk None true vertical 5220' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6 ' 250 SX AS I 1 21 Suite 4499' 7-5/8" 210/587 sx AS 4540' 3599' Intermediate III & 450 SX Class G Production Liner - .. Perforation depth: measured N~e true vertical · Tubing (size, grade, and measured depth . Packer~ and $$$V (type and measured depth) hi<me 13. Att. achments Description summary ol~ proposal ~ Detailed operation program ~ BOP sketch _ 14. Estim~i'~:i'~ate rot cornm~nc]~g operation ........... ~1~. Status of well classification as: 9/27/96 Oil ~ Gas .. 16. If proposal was verbally approved Name or approver Date approved S e rvice ~;~4,~here-by certify.t.hat ,he ,oregolng is true and correct ,o Ihe best ct my knowledge. FOR COMMISSION USE ONLY i ii Conditions of approval: N ify Commission so ,epresentative may witness IApproval No.C.~,~ / Plug integrity_ BOP Test_ Location clearance~ I Mechanical Integrity Test _ Subsequent form require 10- Original Signed By Commissioner Date Approved by the order of the Commission n,-,,,~ ~,~ ,., , , Form 10-403 Rev 06/15/88 ,I · , LJIIlt~IOFI SUBMIT IN TRIPLICATE Approved Copy Returned 23. i996 8:55A~ ARCO ALAS~fA iNC I<r u 3j- 9 Annular Pumping Permit Application Additional Information Please see the attached "Cementing Details" form for Well 3J-19 for basic details on the cementing operation. Additional information is offered below in support of ARCO Alaska Inc.'s opinion that the surface casing cement job will provide adequate sealing capability for annular pumping operations, and that the well has been cased and cemented according to regulation (AAC 25,030), Surface Hole TD: 4550' MD / 3606' TVD Surface Hole Conditions: Tight spots were seen from mid-West Sak to the base permafrost during the wiper trip at TD, but these were cleared up prior to pulling out of the hole, Casing was run to bottom without problems, with precautionary circulation occurring at 2118'. No fill was seen on bottom. Full returns were seen at ail times. Stage Tool Placement: 3J-19 was cemented as a two stage job using Halliburton's Type H ES Cementer placed at the base permafrost (1790' MD). Casing Placement: The casing was reciprocated until approximately halfway through the first stage cement job. The pipe was completely free prior to this point. The surface casing shoe was placed at 4540' MD, I0' off bottom, 10-20' off bottom is the planned standard with fluted casing hanger assemblies. Cementing Details: Full returns were seen while circulating on bottom prior to cementing (+10 bpm) and during the cementing operation itself (7,1-7.6 bpm) until the rig shut down to drop the cementer closing plug with 11.0 ppg cement at surface. After this point returns were almost completely lost when the rig attempted to continue displacing cement to surface. Excess on the first stage lead cement was 50%, with 35% on the tail cement; cement-contaminated returns were seen after opening the cementer and circulating in preparation for the second stage. The second stage of AS III only was pumped until cement returned to surface. The first stage excess factors were based on historical data (3A-17 surface hole bond log) and surface hole caliper logs performed at Milne Point, and were very conservatively calculated with the intent of bringing tail cement to 500' above the top of West Sak, Based on the data, there should be an adequate seal for safe annular pumping operations. Diagnostic Logs: None. Sep. 23. [996 8'55AM ARCO ALAS~[A INC ~o. 19/.t~ i~. 4/0 ARCO Alaska. Inc. Well#: Casing Size 7 5/8" Centralizers Cementing Details 3J-19 Field: KUPARUK Date: 09/20/96 Hole Diameter Hole Angle I Shoe Depth Float Depth I % washout 9 7/8" 49° I 4,540' 41452' I State type used, intervals covered and spacing 24 Gemco and 2 B&W centralizers. 4 Gemeco Stop Collars. Mud Weight YP(prior cond) YP(after cond) [PV(prior cond) PV(affer cond) 9.5/9.3 23 lbs/100 ft,~ 22 lbs/100 ft2! 27 cP 25 cP Sp~cer Gels before 6/9 Type Water Gels after 5/9 Total Volume Circulated 538 bb!s__~ 11 bpm, 700 psi Volume i 4O/4O Weight 8.3 PPG Lead Type IMix wtr temp No, of sacks Weight Yield Cement AS 3 ! 60 210/587 12.1/12.1 1.94 Additives .25 #/sk D29 Tall Type IMix water tempI No. of sacks Weight Yield Cement G I 60 I 450 1 5.8 1.1 5 Additives G, 0,25 #/sk D29, 0.2% D46 Rate(before tail at shoe) 7.1 Displacement Reciprocation length 15' Theoretical Displacement 204.5 CIP 9/19-2o/96 2345/021 o Calculated top of cement surface 0,3% D65, 1% S00! Rate(tail around shoe) 7,3 Reciprocation speed 10 fpm Actual Displacement 212,4 Bumped plug IFI°ats held YES/YES I YES/YES Str. Wt. Up 180 Sir. WI. Dh. 140 Str, Wt. Mud 140 Remarks: Include whether full returns were obtained, reciprocation throul~hout operation and any' other pertinent information:., ,Circ. ' full returns while circulating] and reciprocatin,9. Stage #1' 210 sx. AS 3 followed by 400 sx "G". Had full returns while cementinq and displacing, Reciprocated casing until 134 bbls of 212 total bbls of displacement had been pumped, At that ti the casing started floatin~ on the up stroke and 20K was lost .,on down stroke. Full rtns, on stageI Displaced Stage #1 with 10.2 bbls 15.8 cement, 25 bbb wash water and 177.2 bbls mud. I _Stage #2: Opened ES cementer w/3030 psi. After circulating 101 bbls had cemented contaminat~ mud to surface (17.6 bbb over gauge). Ci[culate and condition mud 510 bbls, 7.6 bpm at 500 ps Put 40 bbls water ahead and pumpe__d__2_0.3 bbls 12,1 cement, Had 8.7 _s_pacer to surface after pumping 130 bbls cement, 1.0,6 .c. mt to surface 180 bbls cmt a_way, 11,0 cmt to surf 200 b_bl.s cmt. away. Pumped a total of 203 bbls 12.1 cmt. Returns started diminishinB as displacement began. After displac_ing_ 25 .bbL%.r_eturn. s were less than 10%. Max. cmt wt. to surf. was 11.0 Stage #1' tail out shoe 400 psi at 7,1 bpm/final press. 1150 psi at 7.3 bpm. Stage #2: lead out cementer 200 psi at 4.8 bpm/final press. 500 psi at 4.9 bpm. Cement Company [Rig Contractor [Signature Dowell IParker ~R. L. Morrison Jr. ' :' Sep. 23. i996 8'55AM ARCO ALAS~[A iNC ~o. i~Zb CASING AND LEAK-OFF FRACTURE TESTS Well Name: KRU 3,1-19 Supervisor: R.L. Morrison Jr. Date: 9/21/96 Casing Size and Description: Casing Setting Depth: Mud Weight: LOT #1 = 645 psi / (0.052 x 3599 ft) + 8.55 ppg -- 12.0 ppg Fluid Pumped = 1.80 bbls. Fluid bled back = 1.5 7 5/8, 29.7#, L-80~ BTC MOD 4540' TMD 3599' TVD ppg EMW-- Leak-off Pressure (PLO) + MW 0.052 X TVD Hole Depth (md)= 4560 Pump output = .085 bps 2000 1900 1800 1700 1600 1S00 1400 1300 1200 1100 1000 900 700 600 500 400 300 200 100 0 = LEAK-OFF TEST --El-' CASING TEST -- TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION September 4, 1996 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ~Mike Zangh/, Drlg Engr Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 3J-19 ARCO Alaska, Inc. 96-148 930'FSL, 565'FWL, Sec 03, T12N, R09, UM 4460'FNL, 960'FEL, Sec 32, T13N, R09E, UM Dear Mr Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Approval for annular injection is contingent on the operator's submittal of an Application for Sundry Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic logs that were run. The documentation submitted should include a CQL or a valid LOT to assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. 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 shoe must be given so that a representative of the 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 Chairman BY ORDER OF THE COMMISSION slh/encl c: Dept ofFish & Game, Habitat Section- w/o encl Dept of Environmental Conservation- w/o encl _ · ' STATE OF ALASKA ALAS,C, OIL AND GAS CONSERVATION COMMISS~uN PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill E] lb Type of Well Exploratory E] Stratigraphic Test E] Development Oil X Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Rig RKB 41', Pad 45' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora~le, AK 99510-0360 ADL 25521, ALK 2557 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 930' FSL, 565' FWL, Sec. 3, T12N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 4829' FNL, 829' FEL, Sec. 32, T13N, R9E, UM 3J-19 #U-630610 At total depth 9. Approximate spud date Amount 4460' FNL, 960' FEL, Sec. 32, T13N, R9E, UM 9/5/96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'I-VD) property line 3J-08 8979' MD 451'@ TD feet 14.1' @ 475' feet 2555 6628' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 400' feet Maximum hole angle 48.3° Maxirnumsurface 211 7 psig At total depth (TVD) 3300 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~ Weight Grade Coupling Length MD TVD MD TVD linclude stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 9.875" 7.625" 29.7# L-80 LTC 4476' 41' 41' 4517' 3576' 1040 Sx Arcticset III & HF-ERW 390 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOD 8357' 41' 41' 8398' 61 83' HF-ERW 170 Sx Class G 6.75" 4.5" 12.8# L-80 EUECrdM 581' 8398' 6183' 8979' 6628' Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Totaldepth: truemeasuredvertical feetfeet Plugs(measured) r') i Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~u°rr~dacUect°r P~ ~ 6 ~I V ~ D Intermediate Production Liner .~,U[~ 2 0 1996 Perforation depth: measured true vertical Alaskc, 0Il & Gas Cons. C0mmissio~, 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Dril[i'ng program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that thefj~regoingistrCe and correct to the best of my knowledge T~tle Signed - ~-~j[ ' Drill Site Develop. Supv. Date ~./] ~'"'- Commission Use Only Pe.,~____~ u_m/~ ~. , APl nuni~r __ I Approval date /-~ .I ~ I See cover letter for . other requirements 12o-o~?- ~ ~-/'o 2_. I "'/- ~ --"7 tp Conditions of approval Samples required BI Yes ~ No Mud log required F~ Yes -~ No Hydrogen sulfide measures ~ Yes ~ No Directional survey required '~ Yes B No Required working pressure for BOPE E] 2M [] aM F~ 5M r-] 1OM E] 15M Other: dngmal Signe0 ~ David W. Johnston by order of ~'. Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3J-1 9 o . . . 1 . , , , 10. 11. 12. 13. 14. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (4,517')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 (8,979') 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.) 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. NU tubinghead & master valve and upper tree assembly. Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Shut in and secure well. clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 3J-19 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 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% Drilling Fluid System: 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 General Notes- Weight up to TD 10.8 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/ft. This shows that formation breakdown would occur before a surface pressure of 2,117 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3J-19 is 3J-08. As designed, the minimum distance between the two wells would be 14.1' @ 475'. Drillin~ Area Risks- Risks in the 3J-19 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 #2 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 10.8 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. ANNULAR PUMPING OPERATIONS WELL KRU 3J-19 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3J-19 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling 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 during the production cement job to cover the formation. It is requested that 3J-19 be permitted for annular pumping occurring as a result of drilling operations, 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. Please reference the enclosed directional drilling plan for other formation markers in this well. 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 3J surface casing shoes will be set +200' vertical below the base of the West Sak into the heart of the shales, 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 drilling 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 = 3731psi 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 ~;857 5.500 15.5 L-80 3 LTC-M 4990 4 2 4 2 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). ARCO ALASI~A, Inc. Pad 3J Nell : 19 slot #19 Kuparuk River Unit North Slope, ALaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Nughes INTEQ Your ref : 19 Version #5 Our ref : prop1618 License : Date printed : 1-Aug-96 Date created : 1-May-96 Last revised : 1-Aug-96 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 24 56.740,w149 50 43.336 SLot Location is n70 25 5.886,w149 50 26.769 SLot Grid coordinates are N 6002612.344, E 519547.537 SLot Local coordinates are 930.00 N 565.00 E Projection type: alaska - Zone 4, Spheroid: CLarke - 1866 Reference North is True North Report is Limited to clearances less than 500 DECREASING CLEARANCES of less than 1000 feet are ir~Jicated by an asterisk, e.g. 487.4' Object weLlpath PGMS <0-9650 >,,1,Pad PGNS <0-9466 >,,2,Pad PC~qS <0-8496 >,,3,Pad PC.~lS <0-8544 >,,4,Pad PCd4S <0-8750 >,,5,Pad PGMS <0-8627 >,,6,Pad PC. d4S <0-7650 >,,?,Pad PC~tS <O-7320'>,,8,Pad PGMS <O-6790'>,,9,Pad PGNS <O-7344,>,,10,Pad PGMS <O-7865'>,,11,Pad PGMS <O-8296'>,,12,Pad Pr.~IS <O-7670'>,,13,Pad PC~lS <O-8130'>,,14,Pad PGMS <O-8659'>,,15,Pad PGMS <O-8~60'>,,16,Pad 17 Version ~3,,17,Pad 18 Version #6,,18,Pad Closest approach with 3-D Minimu~ Distance method Last revised Distance M.D. 3J 8-Nov-91 189.5 300.0 3J 8-Nov-91 164.7 160.0 3J 8-Nov-91 140.0 20.0 3J 8-Nov-91 115.0 20.0 3J 8-Nov-91 90.0 20.0 3J 8-Nov-91 65.0 20.0 3J 8-Nov-91 40.0 20.0 3J 8-Nov-91 14.1, 475.0 3J 8-Nov-91 59.7 380.0 3J 8-Nov-91 85.0 20.0 3J 8-Nov-91 109.6 425.0 3J 8-Nov-91 132.6 1625.0 3J 8-Nov-91 158.2 450.0 3J 8-Nov-91 185.0 20.0 3J 8-Nov-91 210.0 20.0 3J 8-Nov-91 203.7 1893.9 3J 1-Aug-96 220.0 300.0 3J 1-Aug-96 205.0 280.0 Diverging from N.O. 300.0 160.0 400.0 320.0 20.0 20.0 20.0 475.0 380.0 20.0 425.0 1625.0 450.0 5120.0 1300.0 1893.9 6940.0 280.0 Cre~ted b~ ~ones For: D PETRASH D~te plotted: 1-Aug-g6 - PIct Reference is 19 Version ~5. Coord~notes crc in fee[ reference s~o~[ ~lg. I True Yer~col Depths~RK~ (Porker ~245). AI CO ALASKA, In.c. Structure : Pad 5J Well: 19 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 2400 2000 1600 1200 800 400 0 400 I I ~r I ~ I I JJ I I I I 5600 400 4OO 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 52OO 56OO 6OO0 6400 6800 N 21 77 DEG W I To LOC^T,ON: i ,_ · . E~]~ 14460' FNL, 960' FELl 5200 5169 (TO TAR,.GET) ~,, ISEO'3~'T'~N'R~EI · **Plane of Proposol Q ~ ) 4800 · I TARG~"OCAT,ON: I ~ .00 I 4829' FNL, 829' FELl -~ i KOP ~D=400 TMD=400 DEP=O WD=6161 ~ f ~ nn TMD=8369 [ 9 O0 ' NORTH 4801~ ~ ' BEGIN TURN TO TARG~ ~D=797 TMD=800 DEP=15 WEST 1917~ ~ 12.79 ~ ~200 [ 14.18 ~ 16.01 BLS: 3.00 deg per 100 ft L 18.14 ~ 2o.~ ~9 L 22.98 % 25.58 ~~ ~ 28.25 ' 30.97 7 ~ 33.74 B/ PERMAFROST ~D=1706 TMD=1779 DEP=32 ~ 45.08 EOC ~D=2108 TMD=2311 DEP=672 T/ UGNU SNDS ~D=2166 TMD=2398 DER=737 T/ W SAK SNDS ~ WD=2916TMD=5525 DEP=1577 % ~ 1200 ~D=3376TMD=4216 DEP=20,3 ~x ....... ' -- "~ ~ 800 7 s/a" ~~7 oEP=2~7 ~ ~ Alaska 0~~slor} MAYIMTTM ANC. I.~ % A~9~ ~ o ...................... % ........ :¢- 270 Az . 48.28 DEG · 4O0 ' ~ I SURFACE LOCATION: I ~ [930' ESL, 565' ~L[ COLVILLE. SNDS ~D=5101 TMD=6808 DEP=4026 . ¢7.38 DLS: 2.00 deg per 100 T/'UHIT C ~D=6237 TMD=8468 TMD=5233 T/ UNIT B ~D=6275 TMD=8518 DEP=5265 . T/ UNIT A ~D=6~52 TMD=8618 DEP=5329 ~ I ~ ~ ~ i ~T~ T ~ T/ A3 INTERVAL WD=6364 TMD=8634 DEP=5340 1~~1 ~IN ~ _B/-~p SNDS ~D=6475 TMD=8779 DEP=5433 TD - ~ ~/g" CSG ~T ~D=6628 ~MD=8979 D~=5561 40 BEG 4 I I I t I I I I I I I I I t t I I t I I I I I I I I I I I I I 400 0 400 800 1200 1600 2000 2400 2800 .3200 .3600 4000 4400 4800 5200 5600 6000 Verficol Section (feet) -> Azimuth 338.23 with reference 0.00 N, 0.00 E from slot #19 [c,~t~ ~ io.~ For: D PETBASHI Pie[ R~ren~ ~ 1~ V~n ~5. 520 480 ~40 680 640 ARCO ALASKA, Inc. Structure : Pad 3J Well: 19 Field : Kuparuk River Unit Location : North Slope, <- West (feet) 400 360 320 280 240 200 160 120 80 40 0 40 680 6¢0 600 56O 520 48O 230O 3300 ~100 600 560 520 480 440 4(]O 360 320 280 240 200 16O 120 40 80 120 520 i i 48O 440 400 210 i i 320 2go0 44-0 400 360 1900 1300 320 500 280 _ c~%~ 240 200 120 _ 100 900 ~ 0 O0 / 4o , ~ , , ~ ~ , , , 120 80 40 0 ~0 28,0 240 200 1 0 1 0 <- West (feel) Z 0 KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC 3 2 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THATAN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND 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 TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20"-2000 PSI ANNULAR PREVENTER ~,!.)~o ?. 0 ~-,'" Ai~sk,.s O!l ~.'. rS,ss 6o,mmissior' Cons, EDF 3/10,92 6 13 5/8" 5000 PSI STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2_ ASSURE THAT ACCUML~ATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. ~ OBSERVET1ME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND REOORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. _ I3 . 1. 16' - 2000 PSI STARTING HEAD 2_ 11' - 3000 PSI CASING HEAD 11'. ~_9000__ PSI X 13~J/6- - 5000 PSI SPACER SPOOL 4. 13~/8'. 5003 PSI PIPE RAMS 5. 13~:~' - 5000 PSI DRLG SPO(~ W/ CHOKE AND KILL UNES E 13~/8' - 50(X) PSI DOUBi~ RAM W/ PIPE RAMS ON TOP, BUND RAMS ON BTM 7. 13~/8' - 5000 PSI ANNULAR BOP STACK TEST 1. FlU. BOP STACK AND MANIFCLD 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~ CtJ3SE AI~IULAR PREVENTER AND CHOKES AND BYPASS VALVES ON 3HE MANIFOLD. ALL OTHERS OPEN. 4. ~ ALL CCMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCR~ PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVE& & CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE ENES. 7. TESTTO~ ~ ~~ ~ AS IN ~P 4. (Z]NTINUE TESTING ALL VALVES, MNES, AND CHOKES WITH A 950 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL ClOSING POSITIVE SEN. CHOKE. & OPEN TOP PIPE RAMS AND ClOSE BOTTOM PIPE RAMS. TEST BoTroM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOI. F_ ~ BLIND RAMS AND TEST TO 30(30 PSI FOR 3 MINUTES. B! 1=i=!3 TO ZERO PSI. 1~ OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIF(:XJ3 AND MNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE 11. TEST STANDPIPE VALVES TO 3(XX) PS! FOR 3 MINUTES. 12_ TEST KELLY CO(7~ AND INSIDE BOP TO 3(X)O PSI WITH KCX:)MEY PUMP. 1:~ RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILMNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DA~_Y. VBRS WILL A~ATE :~1/2" TO ~1/2" OR 5" TO 7" PIPE ODS AS i, UG;,. ?. 0 i'Sg~o · FIELD & POOL '~'"'~<::::~,,2<:~ 0 WELL PERMIT CHECKLIST COMPANY ADMiNiSTRATiON ............ Permit fee attached ....................... Lease number appropriate ................... Unique well name and number ................. Well located in a defined pool .................. Well located proper distance from ddg unit boundary ..... Well located proper distance from other wells ......... Sufficient acreage available in ddiling 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 administra~ve approval .... Can permit be approved before 15-day waiL, ........ . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. /J~P~PR ~r;VATE/ 12. ENGINEERING GEOL AREA ,, UNIT# / ~//~/" ~ ON/OFF SHORE__~_~[..~___ REMARKS APPR LGI~OLOGY' 14. Conductor string provided .................. 15. Surface casing protects all known USDWs ......... 16. CMT vol adequate to circulate on conductor & surf csg . . . (~.N 17. CMT vol adequate to fie-in long siting to surf csg ...... ..~ 18. CMT' will cover all known productive horizons ......... C~N 19. Casing designs adequate for C, T, B & permafrost. ..... (..~_~ N 20. Adequate tenk~ge or reserve pit. ............... ~ N 21. If a re<idll, has a 10-403 for abndnmnt been approved .... -Y--N-'~ 22. Adequate wellbore separation proposed ............ 23. If dived:er required, is it adequate ................ 24. Ddlling fluid program schematic & equip list adequate ..... LYJ N 25. BOPEs adequate ............ :... ........... 26. BOPE press rating adequate; test to ,.5,::3~FZ) psig.~., N 27. Choke manifold complies w/APl RP-53 (May 84) ...... L._Y~N 28. Work will occur wifl3out opemlJon shutdown .......... .L.Y~N 29. Is presence of H2S gas probable ............... ........ . 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N / j~ .,) v/~ 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. ~ N 33. Seabed condition survey (if off-shore) ............ /'Y N 34. Contact name/phone for weeid¥ progres.~, reports ..... /. Y N /expmramry only] GEOLOGY: ENGINEERING: COMMISSION: JDH ~ JDN Comments/Instructions: TAB HOW/lib - A.'~-OR~ rev ,U96 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAME : ARCO ALASKA, INC. WELL NAIVE : 3J-19 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292270200 REFERENCE NO : 96288 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/01/15 ORIGIN : FLIC REEL NAME : 96288 CONTINUATION # : PREVIOUS REEL : COB~ENT : ARCO ALASKA INC., KUPARUK 3J-19, API #50-029-22702-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/01/15 ORIGIN · FLIC TAPE NAME : 96288 CONTINUATION # : 1 PREVIOUS TAPE : COI4~ENT : ARCO ALASKA INC. , KUPARUK 3J-19, API #50-029-22702-00 TAPE HEADER KUPARUK RIVER MWD LOGS WELL NAME: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 3J-19 500292270200 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 15-JAN-97 WELL CASING RECORD 1ST STRING 2ND STRING BIT RUN1 BIT RUN2 BIT RUN3 ........................... 96288 96288 96288 MILTON LEBLANC LEBLANC MORRISON MORRISON MORRISON 3 12N 9E 736 227 86.00 86.00 45.OO OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6. 750 7. 625 4540.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 3RD STRING PRODUCTION STRING REMARKS: Well drilled 20-SEP through 26-SEP-96 with ARCS/ADN4. Ail data was collected in three bit runs. $ $ PAGE: **** FILE HEADER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 4490.0 9008.0 BASELINE DEPTH 88888.0 8846.0 8844.5 8833.0 8831.5 8827.0 8827.5 8822.5 8823.0 8821.0 8820.5 8789.0 8790 0 8765.0 8765 0 8732.5 8732 0 8713.0 8713 0 8660.0 8660 0 8642.0 8642 5 8630.0 8630 0 8616.0 8616 0 8608.5 8609 0 8597.5 8597.0 8577.0 8577.5 8568.5 8568.0 8547.5 8546.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD 88886.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 PAGE: 8513 8509 8477 8469 8448 8429 8419 8410 8394 8388 8379 8363 8351 8344 8338 8322.5 8316.5 8309.5 8297.5 4542.0 $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ RE~NLRKS: 8514.0 8509.0 8477.0 8469.5 8448.5 8430.0 8420.5 8411 0 8394 5 8388 0 8379 5 8364 0 8352 0 8345 5 8339 0 8323 0 8316 0 8309 5 8298 0 4542 0 BIT RUN NO. MERGE TOP MERGE BASE 1 4490.0 6931.0 2 6931.0 7607.0 3 7607.0 9008.0 The depth adjustments shown above reflect the MWD GR to the CBT GRCH logged by SWS 1-NOV-96. Ail other MWD curves were carried with the GR. The ADN quadrant outputs are as follows: ROBB/ROBU/ROBL/ROBR are bottom, upper, left, and right quadrant density; and are also listed as RHO1,RHO2,RHO3,RH04 in the LDWG listing. The other outputs (Delta Rho, PEF) are listed with their quadrants as DRHB/DRHU/DRHL/DRHR and PEB/PEU/PEL/PER, The LDWG output of RHOB contains the maximum oriented density readings from the quadrants. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 PAGE: TYPE REPR CODE VALUE 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 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 ~ SAMP ELaM CODE (HEX) DEPT FT 038370 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 038370 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 038370 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 038370 O0 000 O0 0 1 1 1 4 68 0000000000 RPXXMWD OH~M038370 O0 000 O0 0 1 1 1 4 68 0000000000 RPX MWD OH~ 038370 O0 000 O0 0 1 1 1 4 68 0000000000 RPS MWD Otff4M038370 O0 000 O0 0 1 1 1 4 68 0000000000 RPM MWD 0t~4~ 038370 O0 000 O0 0 1 1 1 4 68 0000000000 RPD MWD OH~I 038370 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 038370 O0 000 O0 0 1 1 1 4 68 0000000000 RHO1 MWD G/C3 038370 O0 000 O0 0 1 1 1 4 68 0000000000 RH02 MWD G/C3 038370 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 MWD G/C3 038370 O0 000 O0 0 1 1 1 4 68 0000000000 RH04 MWD G/C3 038370 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 038370 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 038370 O0 000 O0 0 1 1 1 4 68 0000000000 DCALMWD IN 038370 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 038370 O0 000 O0 0 1 1 1 4 68 0000000000 RPM MWD RPM 038370 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9007.500 ROP.MWD 63.032 FET.MWD -999.250 GR.MWD RPXX.MWD -999.250 RPX. MWD -999.250 RPS.MWD -999.250 RPM. MWD RPD.MWD -999.250 RHOB.MWD -999.250 RHO1.MWD -999.250 RHO2.MWD RHO3.~WD -999.250 RHO4.MWD -999.250 DRHO.MWD -999.250 NPHI.MWD DCAL.MWD -999.250 PEF. MWD -999.250 RPM.MWD -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 PAGE: DEPT. 9000. 000 ROP.MWD RPXX. MWD - 999. 250 RPX. MWD RPD.14WD -999. 250 RHOB .MWD POq03 .MWD -999. 250 RH04 .MWD DCAL . MWD -999. 250 PEF . MWD DEPT. 8000.000 ROP.MWD RPXX.MWD 3.190 RPX.MWD RPD.MWD 2.975 RHOB.MWD RHO3.MWD 1.977 RHO4.MWD DCAL.MWD 0.006 PEF. MWD DEPT. 7000. 000 ROP.MWD RPXX. MWD 2. 590 RPX. MWD RPD.MWD 2. 731 RHOB.MWD RH03 .MWD 2. 062 RH04 .MWD DCAL. MWD - 999. 250 PEF. lqWD DEPT. 6000.000 ROP.MWD RPXX.MWD 3.214 RPX.MWD RPD.MWD 2.756 RHOB.MWD PJqO3.MWD 2.136 RHO4.MWD DCAL.MWD 0.197 PEF. MWD DEPT. 5000. 000 ROP.MWD RPXX.MWD 5. 870 RPX.MWD RPD . MWD 4.337 RHOB . MWD RH03 .MWD 2.117 RH04 .14WD DCAL . P4WD O . 203 PEF. MWD 61.210 FET.MWD -999.250 RPS.MWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 RPM. MWD 160.352 FET.MWD 3.125 RPS.MWD 1.968 RHO1.MWD 1.975 DRHO.MWD 40.875 RPM. MWD 140. 625 FET. MWD 2.720 RPS. MWD 2. 324 RHO1 .MWD 2. 177 DRHO . MWD 3. 424 RPM. MWD 137. 949 FET.MWD 3. 085 RPS.MWD 2. 400 RHO1 .~fWD 2. 257 DRHO. MWD 3. 192 R PM . MWD 179. 432 FET.P4WD 5.349 RPS.I4WD 2.261 RHO1. MWD 2.189 DRIqO. MWD 2. 661 RPM. MWD -999.250 -999.250 -999.250 -999.250 -999.250 O. 603 3.166 1. 968 O. 003 1.531 -999.250 2.773 2.324 0.132 77.211 0.314 2.961 2.400 0.229 87.672 0.298 4. 859 2. 261 0.105 58. 750 DEPT. 4490.000 ROP.MWD -999.250 FET.MWD -999.250 RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPD.MWD -999.250 RHOB.MWD -999.250 RHOi.I4WD -999.250 RHO3.MWD -999.250 RHO4.MWD -999.250 DRHO.MWD -999.250 DCAL.MWD 0.050 PEF.MWD -999.250 RPM. MWD -999.250 GR.MWD RPM.MWD RHO2.MWD NPHI.MWD GR.MWD RPM. MWD RHO2.MWD NPHI.MWD GR.MWD RPM.MWD RHO2.MWD NPHI.MWD GR.MWD RPM. MWD RHO2.MWD NPHI.MWD GR.MWD RPM. MWD RHO2.MWD NPHI.MWD GR.MWD RPM. MWD RHO2.tBTD NPHI.MWD -999.250 -999.250 -999.250 -999.250 147.484 3.145 1.977 42. 634 112.703 2.754 1.948 44.110 35. 271 2. 847 2. 013 41. 923 34.906 4.505 2.049 37.695 -999.250 -999.250 -999.250 53.144 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 PAGE: **** FILE HEADER **** FILE NANiE : EDIT .002 SERVICE . FLIC VERSION : O01CO1 DATE · 97/01/15 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: O. 5000 FILE SUAff4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 4486.0 6931 . 0 LOG HEADER DATA DATE LOGGED: 1-NOV-96 SOFTWARE: SURFACE SOFTWARE VERSION: IDEAL DOWNHOLE SOFTWARE VERSION: 4. OC DATA TYPE (MEMORY or REAL-TIME): MEMORY TD DRILLER (FT) : 9008.0 TOP LOG INTERVAL (PT): 4486.0 BOTTOM LOG INTERVAL (PT): 9008.0 BIT ROTATING SPEED (RPM) : 77 HOLE INCLINATION (DEG) MINIMUM ANGLE: 47.5 MAXIMUM ANGLE: 49.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE AR C5 RESISTI VI TY ADN DENS./NEUT. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: TOOL NUMBER ........... ARC5 14 ADN4 6.750 4540.0 LSND 11.20 60.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 PAGE: MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3): RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 150 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ) : 20000 REMARKS: *****RUN 1 DRILLED DEPTH 4550'-6931'******* DISTANCE TO BIT: GR=48.25'; RES=43.33 ADN 4 TOOL RUN UNDER FIELD TEST *****RUN 2 PROCESSED DEPTH 6931'-7607'******* RUN 2 COMBINED TWO BIT RUNS IN FIELD DUE TO SURFACE PROCESSING PROBLEM-CALLED RUN 2 *****RUN 3 DRILLED DEPTH 7607'-9008'******* DATA FROM DOWNHOLE MEMORY $ LIS FORMAT DATA 75.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 104 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG 2'TPE CI-~SS MOD NUI~ Sfi2/IPELI~I CODE (HE, X) DEPT FT 038370 O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 F/HR 038370 O0 000 O0 0 2 1 1 4 68 0000000000 TABD LW1 038370 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 038370 O0 000 O0 0 2 1 1 4 68 0000000000 PiOH LW1 OP~4~ 038370 O0 000 O0 0 2 1 1 4 68 0000000000 P16H LW1 OH~M 038370 O0 000 O0 0 2 1 1 4 68 0000000000 P22H LW1 OH~ 038370 O0 000 O0 0 2 1 1 4 68 0000000000 P28H LW1 OH~I 038370 O0 000 O0 0 2 1 1 4 68 0000000000 P34H LW1 OPf~E4038370 O0 000 O0 0 2 1 1 4 68 0000000000 DPHI LW1 PU 038370 O0 000 O0 0 2 1 1 4 68 0000000000 TNPH LW1 PU 038370 O0 000 O0 0 2 1 1 4 68 0000000000 RHOB LW1 G/C3 038370 O0 000 O0 0 2 1 1 4 68 0000000000 ROBB LW1 G/C3 038370 O0 000 O0 0 2 1 1 4 68 0000000000 ROBU LW1 G/C3 038370 O0 000 O0 0 2 1 1 4 68 0000000000 ROBL LW1 G/C3 038370 O0 000 O0 0 2 1 1 4 68 0000000000 ROBR LW1 G/C3 038370 O0 000 O0 0 2 1 1 4 68 0000000000 DRHB LW1 G/C3 038370 O0 000 O0 0 2 1 1 4 68 0000000000 DRHULW1 G/C3 038370 O0 000 O0 0 2 1 1 4 68 0000000000 DRHL LW1 G/C3 038370 O0 000 O0 0 2 1 1 4 68 0000000000 DRHR LW1 G/C3 038370 O0 000 O0 0 2 1 1 4 68 0000000000 PEB LW1 038370 O0 000 O0 0 2 1 1 4 68 0000000000 PEU LW1 038370 O0 000 O0 0 2 1 1 4 68 0000000000 PEL LW1 038370 O0 000 O0 0 2 1 1 4 68 0000000000 PER LW1 038370 O0 000 O0 0 2 1 1 4 68 0000000000 RPM LW1 RPM 038370 O0 000 O0 0 2 1 1 4 68 0000000000 DCAL LW1 IN 038370 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 6931 . 000 ROP. LW1 302. 670 TABD. LW1 1 . 040 GR. LW1 PiOH. LW1 3. 056 P16H. LW1 2. 932 P22H.LW1 2. 826 P28H.LW1 P34H. LW1 2. 558 DPHI. LW1 29. 533 TNPH. LW1 25. 501 RHOB. LW1 ROBB. LW1 2. 289 ROBU. LW1 2. 295 ROBL. LW1 2. 257 ROBR. LW1 DRHB.LW1 O. 072 DRHU. LW1 O. 603 DRHL.LW1 O. 471 DRHR.LW1 PEB.LW1 3.948 PEU. LW1 2.887 PEL.LW1 3.570 PER.LW1 RPM. LW1 105.308 DCAL . LW1 O . 198 DEPT. P1 OH. LW1 P34H. LW1 ROBB. LW1 DRHB. LW1 PEB . LW1 RPMc LW1 6000 000 3 214 2 756 2 259 0 031 3 367 86. 059 ROP. LW1 211 . 363 TABD. LW1 O. 849 GR. LW1 P16H. LW1 3. 085 P22H. LW1 2. 961 P28H. LW1 DPHI.LW1 37. 412 TNPH. LW1 29. 440 RHOB.LW1 ROBU. LW1 2.176 ROBL. LW1 2.200 ROBR. LW1 DRHU. LW1 0.566 DRHL.LW1 O. 425 DRHR.LW1 PEU. LW1 2.531 PEL . LW1 3 . 010 PER. LW1 DCAL. LW1 O. 218 29 197 2 699 2 163 2 258 0 139 4 481 34.989 2.847 2.033 2.126 0.050 3.532 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 PAGE: DEPT. 5000. 000 ROP. LW1 PiOH. LW1 5.889 P16H. LW1 P34H. LW1 4.363 DPHI. LW1 ROBB . LW1 2.180 ROBU. LW1 DRHB.LW1 O. 030 DRHU. LW1 PEB . LW1 3.334 PEU. LW1 RPM. LW1 65. 000 DCAL. LW1 DEPT. 4485.500 ROP. LW1 P1 OH. LW1 29.231 P16H. LW1 P34H. LW1 O. 667 DPHI. LW1 ROBB. LW1 2. 044 ROBU. LWl DRHB . LW1 - O . 050 DRHU. LW1 PEB. LW1 7. 878 PEU. LW1 RPM. LW1 250. 000 DCAL. LW1 424.637 TABD. LW1 5.369 P22H. LW1 38. 804 TNPH. LW1 2.161 ROBL. LW1 O . 558 DRHL . LW1 2.299 PEL.LW1 0.207 O. 000 TABD. LW1 1 . 495 P22H. LW1 34. 650 TNPH. LW1 2. 086 ROBL. LW1 -0. 080 DRHL.LW1 9. 702 PEL. LW1 O. 065 O . 841 GR. LW1 4. 882 P28H. LWl 26.093 RHOB . LW1 2.148 ROBR.LW1 O . 417 DRHR . LW1 2. 675 PER. LW1 1.375 GR. LW1 O. 676 P28H. LW1 40. 309 RHOB . LW1 2.214 ROBR. LW1 - O. 099 DRHR. LW1 10. 579 PER. LW1 34. 816 4.530 2. 010 2. 091 O. 053 3. 042 19.078 0.574 2.078 1.983 -0.074 6.809 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION . O01CO1 DATE : 97/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: O . 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 6931.0 7607.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 PAGE: 10 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNttOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME) TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (?T) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESISTIVITY ADN DENS./NEUT. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~) 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): 1-NOV-96 IDEAL 4.0C MEMORY 9008.0 4486.0 9008.0 77 47.5 49.0 TOOL NUMBER ........... ARC5 14 ADN4 6.750 4540.0 LSND 11.20 60.0 500 2.150 75.0 *****RUN 1 DRILLED DEPTH 4550'-6931 '******* DISTANCE TO BIT: GR=48.25'; RES=43.33 ADN 4 TOOL RUN UNDER FIELD TEST *****RUN 2 PROCESSED DEPTH 6931'-7607'******* RUN 2 COMBINED TWO BIT RUNS IN FIELD DUE TO SURFACE PROCESSING PROBLEM-CALLED RUN 2 *****RUN 3 DRILLED DEPTH 7607'-9008'******* DATA FROM DOWNHOLE MEMORY 1.0 20000 SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 PAGE: $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 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 038370 O0 000 O0 0 3 1 1 4 68 0000000000 ROP LW2 F/HR 038370 O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI 038370 O0 000 O0 0 3 1 1 4 68 0000000000 PiOH LW2 0I~4~038370 O0 000 O0 0 3 1 1 4 68 0000000000 P16H LW2 OHI~M 038370 O0 000 O0 0 3 1 1 4 68 0000000000 P22H LW2 OHM~I 038370 O0 000 O0 0 3 1 1 4 68 0000000000 P28H LW2 Ot~4M 038370 O0 000 O0 0 3 1 1 4 68 0000000000 P34H LW2 OPIM~038370 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH LW2 PU 038370 O0 000 O0 0 3 1 1 4 68 0000000000 RHOB LW2 G/C3 038370 O0 000 O0 0 3 1 1 4 68 0000000000 ROBB LW2 G/C3 038370 O0 000 O0 0 3 1 1 4 68 0000000000 ROBU LW2 G/C3 038370 O0 000 O0 0 3 1 1 4 68 0000000000 ROBL LW2 G/C3 038370 O0 000 O0 0 3 1 1 4 68 0000000000 ROBR LW2 G/C3 038370 O0 000 O0 0 3 1 1 4 68 0000000000 DRHB LW2 G/C3 038370 O0 000 O0 0 3 1 1 4 68 0000000000 DRHU LW2 G/C3 038370 O0 000 O0 0 3 1 1 4 68 0000000000 DRHL LW2 G/C3 038370 O0 000 O0 0 3 1 1 4 68 0000000000 DRHR LW2 G/C3 038370 O0 000 O0 0 3 1 1 4 68 0000000000 PEB LW2 038370 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 PAGE: 12 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) PEU LW2 038370 O0 000 O0 0 3 1 1 4 68 0000000000 PEL LW2 038370 O0 000 O0 0 3 1 1 4 68 0000000000 PER LW2 038370 O0 000 O0 0 3 1 1 4 68 0000000000 RPM LW2 RPM 038370 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 7607. 000 ROP. LW2 86.120 GR. LW2 - 999 P16H.LW2 -999.250 P22H.LW2 -999.250 P28H. LW2 -999 TNPH. LW2 39. 898 RHOB. LW2 1 . 976 ROBB. LW2 2 ROBL.LW2 1.976 ROBR.LW2 2.199 DRHB.LW2 0 DRHL.LW2 O. 066 DRHR.LW2 O. 070 PEB.LW2 5 PEL. LW2 12. 680 PER. LW2 7. 531 RPM. LW2 - 999 DEPT. 7000. 000 ROP. LW2 137. 400 GR. LW2 109 P16H.LW2 2. 720 P22H. LW2 2. 780 P28H.LW2 2 TNPH. LW2 44 . 463 RHOB. LW2 2.179 ROBB. LW2 2 ROBL . LW2 2.175 ROBR . LW2 2.258 DRHB . LW2 0 DRHL . LW2 0.303 DRHR . LW2 O . 301 PEB . LW2 4 PEL.LW2 4.285 PER.LW2 4. 099 RPM. LW2 - 999 DEPT. 691 O . 500 ROP. LW2 P16H. LW2 -999.250 P22H. LW2 TNPH. LW2 35.527 RHOB . LW2 ROBL. LW2 1. 901 ROBR. LW2 DRHL.LW2 0.222 DRHR.LW2 PEL . LW2 3.744 PER. LW2 0 000 -999 250 1 859 2 093 0 079 3 743 GR. LW2 59 P2 8H. LW2 - 999 ROBB. LW2 2 DRHB. LW2 0 PEB. LW2 4 RPM. LW2 105 250 P1 OH. LW2 250 P34H. LW2 432 ROBU. LW2 084 DRHU. LW2 134 PEU. LW2 25O 410 780 281 281 205 250 150 250 330 064 092 308 P1 OH. LW2 P34H. LW2 ROBU. LW2 DRHU. LW2 PEU. LW2 P1 OH. LW2 P34H. LW2 ROBU. LW2 DRHU. LW2 PEU. LW2 -999.250 -999.250 1.721 0.012 22.386 2.570 2.770 2.050 0.266 4.603 -999.250 -999.250 1.665 0.162 4.649 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 97/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 PAGE: 13 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 97/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NI]MBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SU~FIARY VENDOR TOOL CODE START DEPTH STOP DEPTH 7607.0 9009.0 LOG HEADER DATA DATE LOGGED: 1 -NOV- 96 SOFTWARE: SURFACE SOFTWARE VERSION: IDEAL DOWNHOLE SOFTWARE VERSION: 4. OC DATA TYPE (MEMORY or REAL-TIME): MEMORY TD DRILLER (FT) : 9008.0 TOP LOG INTERVAL (FT) : 4486.0 BOTTOM LOG INTERVAL (FT) : 9008.0 BIT ROTATING SPEED (RPM) : 77 HOLE INCLINATION (DEG) MINIMUM ANGLE: 47.5 MAXIMUM ANGLE: 49.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESISTIVITY ADN DENS./NEUT. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: TOOL NUMBER ........... ARC5 14 ADN4 6.750 4540.0 LSND 11.20 60.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 PAGE: 14 MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3) '. RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2.150 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MA TRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: *****RUN 1 DRILLED DEPTH 4550'-6931'******* DISTANCE TO BIT: GR=48.25'; RES=43.33 ADN 4 TOOL RUN UNDER FIELD TEST *****RUN2 PROCESSED DEPTH 6931'-7607'******* RUN2 COMBINED TWO BIT RUNS IN FIELD DUE TO SURFACE PROCESSING PROBLEM-CALLED RUN 2 *****RUN3 DRILLED DEPTH 7607'-9008'******* DATA FROM DOWNHOLE MEMORY $ LIS FORMAT DATA 75.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 104 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 PAGE: 15 ** SET TYPE - CHAN ** N~ SERV UNIT SERVICE API g~PI API API FILE ~ NUI~B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 038370 O0 000 O0 0 4 1 1 4 68 0000000000 ROP LW3 F/HR 038370 O0 000 O0 0 4 1 1 4 68 0000000000 TABD LW3 038370 O0 000 O0 0 4 1 1 4 68 0000000000 GR LW3 GAPI 038370 O0 000 O0 0 4 1 1 4 68 0000000000 PiOH LW3 OH~R4 038370 O0 000 O0 0 4 1 1 4 68 0000000000 P16H LW3 OH~ 038370 O0 000 O0 0 4 1 1 4 68 0000000000 P22H LW3 0P24~ 038370 O0 000 O0 0 4 1 1 4 68 0000000000 P28H LW3 0P24~038370 O0 000 O0 0 4 1 1 4 68 0000000000 P34H LW3 OP24M 038370 O0 000 O0 0 4 1 1 4 68 0000000000 DPHI LW3 PU 038370 O0 000 O0 0 4 1 1 4 68 0000000000 TNPH LW3 PU 038370 O0 000 O0 0 4 1 1 4 68 0000000000 RHOB LW3 G/C3 038370 O0 000 O0 0 4 1 1 4 68 0000000000 ROBB LW3 G/C3 038370 O0 000 O0 0 4 1 1 4 68 0000000000 ROBU LW3 G/C3 038370 O0 000 O0 0 4 1 1 4 68 0000000000 ROBL LW3 G/C3 038370 O0 000 O0 0 4 1 1 4 68 0000000000 ROBR LW3 G/C3 038370 O0 000 O0 0 4 1 1 4 68 0000000000 DRHB LW3 G/C3 038370 O0 000 O0 0 4 1 1 4 68 0000000000 DRHULW3 G/C3 038370 O0 000 O0 0 4 1 1 4 68 0000000000 DRHL LW3 G/C3 038370 O0 000 O0 0 4 1 1 4 68 0000000000 DRHR LW3 G/C3 038370 O0 000 O0 0 4 1 1 4 68 0000000000 PEB LW3 038370 O0 000 O0 0 4 1 1 4 68 0000000000 PEU LW3 038370 O0 000 O0 0 4 i 1 4 68 0000000000 PEL LW3 038370 O0 000 O0 0 4 1 1 4 68 0000000000 PER LW3 038370 O0 000 O0 0 4 1 1 4 68 0000000000 RPM LW3 RPM 038370 O0 000 O0 0 4 1 1 4 68 0000000000 DCAL LW3 IN 038370 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9009. 500 ROP. LW3 61. 682 TABD. LW3 PiOH.LW3 2.242 P16H.LW3 2.328 P22H. LW3 P34H. LW3 2 . 185 DPHI. LW3 29. 497 TNPH. LW3 ROBB. LW3 2. 091 ROBU. LW3 2.309 ROBL. LW3 DRHB.LW3 O. 044 DRHU. LW3 O. 073 DRHL.LW3 PEB . LW3 47.423 PEU. LW3 16.791 PEL . LW3 RPM. LW3 109. 813 DCAL . LW3 O . 038 DEPT. 9000. 000 ROP. LW3 66. 667 TABD. LW3 PiOH.LW3 2.242 P16H.LW3 2.328 P22H.LW3 P34H.LW3 2.185 DPHI.LW3 29. 497 TNPH. LW3 ROBB. LW3 2. 091 ROBU. LW3 2.309 ROBL. LW3 DRHB.LW3 O. 044 DRHU. LW3 O. 073 DRHL.LW3 PEB . LW3 47.423 PEU. LW3 16.791 PEL . LW3 RPM. LW3 109. 813 DCAL . LW3 O . 038 2 160 2 310 -999 250 1 998 0 026 166 329 2 160 2 310 -999 250 1 998 0 026 166 329 GR. LW3 P28H. LW3 RHOB. LW3 ROBR . LW3 DRHR. LW3 PER. LW3 GR. LW3 P28H. LW3 RHOB. LW3 ROBR . LW3 DRHR . LW3 PER. LW3 78.152 2.230 2.163 2. 421 O. 067 7. 939 78.152 2.230 2.163 2.421 0.067 7.939 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-JAN-1997 14:30 PAGE: 16 DEPT. 8000. 000 ROP. LW3 PiOH.LW3 3.278 P16H. LW3 P34H. LW3 3 . 135 DPHI. LW3 ROBB. LW3 2.371 ROBU. LW3 DRHB.LW3 O. 027 DRHU. LW3 PEB. LW3 6.459 PEU. LW3 RPM. LW3 111. 000 DCAL. LW3 DEPT. P1 OH. LW3 P34H. LW3 ROBB. LW3 DRHB. LW3 PEB. LW3 RPM. LW3 7465.000 -999 250 -999 250 2 028 0 293 4 112 0 000 ROP. LW3 P16H. LW3 DPHI. LW3 ROBU. LW3 DRHU. LW3 PEU. LW3 DCAL. LW3 137. 500 TABD. LW3 3. 215 P22H. LW3 32.402 TNPH. LW3 1. 932 ROBL. LW3 -0. 008 DRHL.LW3 143. 426 PEL. LW3 O. 037 - 999.250 TABD. LW3 - 999. 250 P22H. LW3 37. 672 TNPH. LW3 2. 028 ROBL. LW3 O . 293 DRHL . LW3 4.112 PEL . LW3 O. 000 1. 494 GR. LW3 3 . 274 P28H. LW3 43. 126 RHOB. LW3 2.162 ROBR. LW3 O . 037 DRHR . LW3 17. 859 PER. LW3 O. 000 GR. LW3 -999. 250 P28H. LW3 36. 209 RHOB. LW3 2. 028 ROBR. LW3 O . 293 DRHR . LW3 4.112 PER. LW3 144. 704 3.283 2.115 2.146 O. 031 18. 823 -999.250 -999. 250 2. 028 2. 028 0.293 4.112 ** END OF DATA ** **** FILE TRAILER **** FILE NAIVE : EDIT .004 SERVICE : FLIC VERSION ' O01CO! DATE : 97/01/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 97/01/15 ORIGIN : FLIC TAPE NAME - 96288 CONTINUATION # : 1 PREVIOUS TAPE : CO~J4ENT : ARCO ALASKA INC. , KUPARUK 3J-19, API #50-029-22702-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/01/15 ORIGIN · FLIC REEL NAME : 96288 CONTINUATION # : PREVIOUS REEL : CORR4ENT : ARCO ALASKA INC. , KUPARUK 3J-19, API #50-029-22702-00