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196-122
196-122 T38927 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.13 08:42:12 -08'00' Originated: Schlumberger PTS- PRINTCENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760fax Delivered to: tf AOGCC e ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 •.. Anchorage, AK 99501 19 6122 30991 • 12Ju1-19 12Ju119•JW02 __j%NAME API # ORDERSERVICE # FIELD NAME DELIVERABLE DESCRIPTION DATA TYPE ColorDESCRIPTION DATELOGGED Prints CD's IA -25 30-11 3K-23 50-029-22116-00 50-029-21676-00 50-029-22771-00 EBNL-00028 EBNL-00029 EBNL-00030 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL PPROF LDL LDL FINAL FIELD FINAL FIELD FINAL FIELD 21 -Jun -19 22 -Jun -19 23 -Jun -19 1 1 1 2V-02 1Y-14 1H-109 1H-113 1H-117 3H-146 50-029-21037-00 50-029-20910-00 50-029-23595-00 50-029.23588-00 50-029-23602-00 50-103-20092-02 EBNL-00034 EBNL-00035 EBNL-00036 EBNL•00037 EBNL-00038 EOSH-00062 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL WL (PROF IPROF IPROF IPROF IPROF LDL FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 27 -Jun -19 28 -Jun -19 29 -Jun -19 30 -Jun -19 1- Jul -19 3 -Jul -19 1 1 1 1 1 1 2G -14A 1B-06 18-09 3G-03 1R -22A 50-029-21161-01 50-029-20603-00 50-029.20655-00 50.103-20245-00 50-029-22206-01 EOSH-00064 EOSH-00065 EOSH-00066 EOSH-00067 EOSH-00048 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL LDL PPROF IPROF PPROF LDL FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 5- Jul -19 6 -Jul -19 7 -Jul -19 8 -Jul -19 8 -Jul -19 1 1 1 1 1 14 Name Signature Please return via courier or sign/scan and email a copy 0g11Vj Date and CPAI. Schlumberger -Private ATransmittal Receipt signature confirms that package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Auditor - 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. I~'~ - i~0O~, 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: Bevedy~Vincent Nathan Lowell Date: ~ .~ ,~'" ~si [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • • ConocoPhillips ECEIVED Alaska OCT 0 9 2012 P.O. BOX 100360 G ANCHORAGE, ALASKA 99510 -0360 CC October 5, 2012 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 — -3 Anchorage, AK 99501 Commissioner Dan Seamount: 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 cement was pumped in the summer /fall of 2012. The corrosion inhibitor /sealant was pumped in the month of September 2012.The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor . • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/05/2012 1 D,WSW,1 F,2F,2L,2T,2Z,3G,3I & 3M 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 1D-113 50029229170000 1981780 2" n/a 8" n/a 5.1 9/27/2012 1D-117 50029228440000 1972370 7' 0.80 25" 7/22/2012 8.7 9/27/2012 WSW -11 50029208820000 1822120 SF n/a 8" n/a 2.9 9/30/2012 1F-11 50029209930000 1831150 19'8" 3.40 12" 7/22/2012 3.4 9/27/2012 2F -19 50029227280000 1962010 7'5" 1.30 18" 9/19/2012 19 9/27/2012 2L -305 50103202790000 1982400 SF n/a 7" n/a 4.4 9/28/2012 2T -28 50103202250000 1950920 9" n/a 27" n/a 13.6 9/27/2012 2Z -10 50029213780000 1851370 5'9" 0.80 _ 23" 9/19/2012 7.7 9/30/2012 3G -03 50103202450000 1961220 2" n/a 12" n/a 7.5 9/28/2012 31 -06 50029219350000 1890380 7' 0.80 11" 7/22/2012 6 9/28/2012 3M -13 50029217200000 1870400 7'7" 0.50 12" 7/22/2012 4.7 9/28/2012 I ' STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Other 0 Conductor Rill Tubing Perforate New Pool Waiver Extension Alter Casing ® g ❑ ❑ ❑ Time Extension ❑ Change Approved Program ❑ Operat Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: — ConocoPhillips Alaska, Inc. Development j Exploratory ❑ 196 -122 3. Address: 6. API Number: Stratigraphic ❑ Service ❑ P. O. Box 100360, Anchorage, Alaska 99510 " 50- 103 - 20245 -00 — Q0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 0025547 3G -03 9. Field /Pool(s): . Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7501 feet Plugs (measured) None true vertical 6145 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 508 true vertical 0 feet (true vertucal) 508 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 1640 630 SURFACE 3490 7.625 3531 3084 4790 6890 PRODUCTION 7456 5.5 7488 6135 6290 7740 Perforation depth: Measured depth: 7060' - 7238' MD e True Vertical Depth: 5816' - 5949' TVD AUG Tubing (size, grade, MD, and ND) 3.5 ", L -80, 6965 MD, 5744 ND filOn CC Packers & SSSV (type, MD, and ND) PACKER = BAKER GBH -22 SEAL ASSEMBLY, 6947 MD, 5730 ND SSSV = CAMCO "DS" NIPPLE, 508 MD, 508 ND 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. 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 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory ❑ Development r,_,` - Service ❑ Stratigraphic X 15. Well Status after work: - Oil pi Gas ❑ WDSPL Daily Report of Well Operations GSTOR ❑ WINJ r WAG GINJ ['i ❑ SUSP ❑ SPLUG ❑ 16. 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 311 -394 Contact MJ Loveland /Martin Walters Printed Name Martin W / allteers Title Well Integrity Project Supervisor Signature /31 // A 1 Phone: 659 - 7043 Date 8/14/12 Form 10-404 Revised 10 , � MS AUG 17 20 � ' � e(7 Submit Original Only 3G -03 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/09/Ill Pull measurement for conductor extension 01 /09 /12IReceived approval from state to extend conductor 08 /13 /12IWeld 8.5" of 62# .375 (16 "casing) extension onto 16" conductor I , . . .. ‘,. .. . ,. ., k. . ' - [ ... , -. --' ; - . . r ..._ %., A. 4... ‘ • I 4 , . . . . ., , ... ,.. - ,,. , - ,,,, ,... . . . . .t. . I fr,,, 7,.. . . . . ., , . • . ,.. . .. . - . . „ . . - .. tV - ....44. * 1 - ... ,., / . r Ket A. 34 -O 5 FAD l'/6 -12.z- Regg, James B (DOA) From: NSK Well Integrity Proj [N1878 ©conocophillips.com] �� ] Sent: Friday, January 13, 2012 5:11 PM (71(1 I 1 v To: Regg, James B (DOA) Cc: NSK Prod Engr Specialist Subject: FW: 3G -03 Wellhead movement Attachments: 3G -03 10 -403 Conduct ext approval.pdf; 3G -03 196 -122 sealant 10- 404.pdf Jim. December3,011 ConocoPhillips requested & received approval (Sundry 311 -394) for a conductor extension on 3G -03 (PTD 196 -122). The extension should be completed in the first quarter 2012. Additionally the conductor annulus cement top is at 16" and was topped with corrosion inhibiting sealant in 2009 which is currently visible at the top of the conductor. There was no indication of surface casing corrosion at that time the sealant was pumped. Please let me know if you need any additional information about this well. Regards MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. iQ � Office (907) 659 -7043 FEB - w MJ's Cell (907) 943 -1687 From: Regg, James B (DOA) [mailto:jim.reggC@alaska.gov] Sent: Friday, January 13, 2012 3:04 PM To: NSK Prod Engr Specialist Cc: DOA AOGCC Prudhoe Bay Subject: [EXTERNAL]RE: 3G -03 Wellhead movement We disagree with CPAI's status quo for KRU 3G -03 (PTD 1961220). The surface casing pipe flutes were observed by an AOGCC Inspector on 12/11/2011 to be well above its proper position inside the conductor pipe; he was able to move the wellhead by pushing and pulling the tree. Reasons for this condition are undetermined but represent an abnormal, substandard condition. Vibration, subsidence, well "slugging ", and the extreme temperatures /differential temperatures can cause stress cracking of welds, improper Toads the S- riser, and excessive movement of the production tree. Surface casing flutes that are inside the conductor provide added stability that mitigates lateral movement. Another substandard condition that allows well head movement is the lack of cement in the surface casing by conductor pipe; no cement was observed inside and near the top of the conductor pipe. There have been indications of surface casing corrosion in other wells where similar conditions were observed. The AOGCC requests CPAI take appropriate actions to mitigate the movement of the KRU 3G -03 production tree. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907- 793 -1236 From: NSK Prod Engr Specialist [ mailto :n1139@conocophillips.com] Sent: Thursday, December 15, 2011 9:50 AM 1 • To: Jones, Jeffery B (DOA) Cc: CPF1&2 Ops Supt; Regg, James B (DOA); NSK Fieldwide Operations Supt; NSK Prod Engr & Optimization Supv Subject: 3G -03 Wellhead movement Jeff, CPAI conducted an inspection of the 3G -03 Wellhead movements reported during the 3G SVS Pad test conducted on 12/11/11. At this time, CPAI does not believe the reported wellhead movement poses any threat to the environment, personnel, or equipment. As indicated below, we will continue to monitor the well. Bob Christensen / Darrell Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7535 Kuparuk Pager: 659.7000; #924 CPAI Internal Mail: NSK -69 This email may contain confidential information. If you receive this e-mail in error, please notify the sender and delete this email immediately. 'ell Integrity Field Supv y, December 15, 2011 8:36 AM Integrity Proj G -03 12/12/11 report of well head movement: 12/14/11 went to 3G pad to investigate well #3 movement and found well has very little movement but warrants further investigation because flutes are not in contact with landing ring - may need conductor extension. At this time we do not fore see a problem but will continue to monitor. Roger Winter Wells Supervisor NSK 69 Wells Group Office 206 F Wing Office # 659 -7506 Cell # 943 -1055 2 . • • k SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMJSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Martin Walters Well Integrity Project Supervisor t q . 1 " ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3G -03 Sundry Number: 311 -394 Dear Mr. Walters: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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. incerely, Daniel T. Seamount, Jr. Chair DATED this s day of January, 2012. Encl. STATE OF ALASKA " Iv i RECEIVED , ALASI�IL AND GAS CONSERVATION COMMIS , 7011 APPLICATION FOR SUNDRY APPROVALS tt- ' � DE ' 20 AAC 25.280 hairs Ott & Gas Cons. Commission 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Change Ae@gram r Suspend r Rug Ferforations r Perforate r Pull Tubing r Time Extension r / Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other:Conductor Extension r • ✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r' _ Exploratory r 196 -122 , 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20245 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 3G - ' 9. Property Designation (Lease Number): 10. Field / Pool(s): I ADL 0025547 , 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): 7501 - 6145 ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121' 121' 1640 630 SURFACE 3490 7.625 3531' 3084' 4790 6890 PRODUCTION 7456 5.5 7488' 6135' 6290 7740 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7060' - 7238' MD 5816' - 5949' TVD 3.5" L - 80 6965 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) SSSV = NIPPLE - 3.5" X 2.875" CAMCO "DS" NIPPLE MD= 508 TVD= 508 Packer = Baker 80-40 Seal Assembly MD= 6946 TVD= 5730 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/25/2012 Oil r - Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland /Martin Walters Printed Name Martin Walters Title: Well Integrity Project Supervisor a ! , / rr, Signature r' (' 27fV :d G Phone: 659 -7043 Date: 12/25/11 Commission Use Only �� Sundry Number:' y ) - sot/ Conditions of approval: Notify Commission so that a representative may witness l /� Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: /a- 09 / /t APPROVED BY / Z Approved by: RB COMMISSIONER THE COMMISSION Date: ifCi 1� S JAN 0 ,. 201 � Form 10 -403 Revised 1/2010 48 R 1 G 1 NA L A ` Submit in D Iicate • • ConocoPhillips Alaska, Inc. Kuparuk Well 3G -03 (PTD 196 -122) SUNDRY NOTICE 10 -403 APPROVAL REQUEST December 25, 2011 This application for Sundry approval for Kuparuk well 3G -03 is to extend the conductor to original hei ht so as to prevent any further corrosion to SC. This well is a Kuparuk gas lifted oil g p Y p g well and is currently on line. At some point during normal operations the conductor subsided about 7.5 inches. 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. If possible, install anti - corrosion coating on SC as specified by CPAI Corrosion Engineer. 4. Extend the conductor to starter head and fill the void with cement and top off with sealant. 5. File 10 -404 with the AOGCC post repair. NSK Problem Well Supervisor 05/07/05 i KUP 3G -03 ConocoPhillips °- gel! Attributes ax Angle & MD TO Wellbore APIIUWI Field Name Well Status Inc'( ") M D (8148) Act Btm (fd48) ylyps 501032024500 KUPARUK RIVER UNIT PROD 42.66 j 7,500.98 7,501.0 "" Comment H2S (ppm) Date Annotation End Date KB - Ord (R) Rig Release Dab Well Config. - 3G 1 2329 PM - SSSV: Nipple 160 12/10/2009 Last WO: 1/18/2009 8/6/1996 Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,375.0 12/1/2009 Rev Reason: ADD 12/11/2009 PERFS Imosbor 1/22/2010 Casing Strings Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 37 ilMtir " CONDUCTOR 16 15.062 41.0 121.0 121.0 62.50 H ss Casing Description String 0... String ID ... Top (8148) Set Depth (f... Set Depth (TVO) ... String Wt... String ... String Top Thrd SURFACE 75/8 6.750 40.5 3,530.7 3,084.4 29.70 L Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVO) ... String Wt... String ... String Top Thrd PRODUCTION 5.5x4 5 1/2 4.950 32.0 7,487.7 6,134.9 17.00 L -80 LTC-MOD Tubing Strings Tubing Description String 0... String ID ... Top (8K8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.991 36.5 6,965.1 5,743.8 9.30 L -80 IBTM Completion Details Top Depth CONDU _ _ (TVD) Top Incl Komi_ at -121 Top (814B) (MB) (1 Rem Description Comment ID (In) 36.5 36.5 0.99 HANGER FMC Gen IV Hanger w /pup 2.867 507.8 507.8 0.74 NIPPLE 3.5" x 2.875" Camco "DS" Nipple (EUE 8rd) (w /collar) 2.875 6,908.0 5,700.3 39.98 NIPPLE 3.5" x 2.813" Camco "D" Nipple 2.813 • 6,946.5 5,729.6 40.20 SEAL ASSY Baker 80-40 GBH -22 Seal Assembly w /6' pup 3.010 Perforations & Slots Shot GAS LIFT, Top (TVD) Btrn (TVD) Dens 2.645 Top (81(B) Btm (RKB) (RKB) (RKB) Zone Date (sh... Type Comment 1 7,060 7,080 5,815.6 5,830.9 C-4, 3G-03 9/1/1999 4.0 RPERF 2 1/8" EnerJet 7,060 7,076 5,815.6 5,827.8 C4, 30-03 10/25/1997 4.0 RPERF 21/8" ENerJet, Zero deg. phasing 7,076 7,096 5,827.8 5,843.1 C-4, C-3, G1, 8/28/1997 4.0 IPERF 218" EnerJet, Zero deg. phasing 30-03 7,144 7,148 5,879.3 5,882.4 A -5, 3G-03 12/12/2009 6.0 APERF 2.5" Millenium Chg, 60 deg phase SURFACE, 7,160 7,180 5,891.4 5,905.2 A-3, 3G-03 8/29/1996 4.0 IPERF 21/8" EnerJet, Oriented ( + / -) 90 deg. 41 - 3331 F/ lowside 7,160 7,180 5,891.4 5,905.2 A-3, 30-03 9/26/1996 4.0 RPERF 2 1/8" EnerJet, Oriented ( + / -) 90 deg. F/ )owside GASLIFT, 5� 7,180 7,210 5,905.2 5,928.0 A -3, A-2, 3G-03 8/24/1996 4.0 IPERF 2 1/8" EnerJet, Oriented ( + / -) 90 deg. F/ lowside 7,212 7,222 5,929.5 5,937.1 A -2, 3G-03 12/11/2009 6.0 APERF 2.5" Millenium guns, 60 deg phase 7,232 7,238 5,944.6 5,949.1 A -2, 3G-03 12/11/2009 6.0 APERF 2.5" Millenium guns, 60 deg phase GAS LFT Stimulations & Treatments 5.598 Bottom Min Top Max 86. Top Depth Depth Depth Depth (TVD) (TVD) (RKB) (RK8) (RKB) (RKB) Type Date Comment 7,060.0 7,080.0 5,815.6 5,830.9 FRAC 9/18/1999 PUMPED FRACTURE TREATMENT, SCREENED OUT WITH 6 PPG ON PERFS, 21400# IN GAS LIF l '4! FORMATON, 16,900# IN WELLBORE. 6,401 Notes: General & Safety End Date Annotation 1/24/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 a GAS LIFT ll 6,858 El NIPPLE. 6,908 IN I SEAL ASSY, , 6 _1 6,946 7 RPERF, 7,060 - 7,076 FRAC, 7,060 I I RPERF, 7060.7,080 IPERF, 7,0767,096 RPERF, 7,144 -7,148 RPERF, Mand D etails 7'180. ERR. \ Top D eplh Top Port 71B (T Intl 00 Valw Latch Slxe TRO Run IPERF, Stn Top MB) (RK (1 Make Model ('n) Sery Type Type (in) (psi) Run D at e Com... 7,194-7,210 1 2,644.8 2,388 37.43 CAMCO KBG -2 -9 1 Gas Lift GLV INT 0.156 1 1/26/2009 2 4 3 39.38 CAMCO KBG -2 -9 1 Gas L GLV INT 0 .1 56 1 1/26/2009 RPERF, 3 5,598.4 4,686.1 40.98 CAMCO KBG -2 -9 1 Gas Lift GLV INT 0.188 1,259.0 1/25/2009 7,212 -7,222 4 6 5,306.0 38.95 CAMCO KBG -2 -9 1 Gas Lift GLV (NT 0 .1 88 1 1/25/20 APERF, 5 6,858.4 5,662.2 39.71 CAMCO KBG-2 -9 1 Gas Lift 'OV INT 0.250 0.0 1/25/2009 7,232 -7,238 PRODUCTION 5 5x4, 32 -7,488 N TD, 7,501 STATE OF ALASKA ALASKSIL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS R~C~IVED IAhJ 2 7 z0~a ~. operations Pertormed: Abandon ~ Repair w ell ~° Rug Pfrrforations ~ Stimulate ~°"" ~ ~~° C~IIM111SS10~1 ° Pull Tubin ~"`" P AR C i f t N P l W i ~~ ~ " s o g ver ~ er as ng ~ er ora e ew bo a ~ en i n Change Approved Program "` Operat. Shutdown ~"" Pbrforate Re-enter uspended W~ ®«~ 2. Operator Name: 4. Current Well Status: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~` Exploratory ~`°' 196-122 3. Address: Stratigraphic ~` Service ~® API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20245-00 7. Property Designation: Well Name and Number: ADL 25547 3G-03 9. Field/Pool(s): Kuparuk River Field /Kuparuk Oil Pool 10. Present Well Condition Summary: , Total Depth measured 7501 feet Plugs (measured) None true vertical \ 6145 feet Junk (measured) None Effective Depth measured 7422' feet Packer (measured) 6947' MD, 5730' TVD true vertical 6086' feet (true vertucal) Casing. Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121' SURFACE 3490 7.625 3531 3085' PRODUCTION 7456 5.5 7488 5742' 6135' Perroration depth: Measured depth: 7060'-7096', 7144'-7148', 7160'-7210', 7212'-7222', 7232'-7238' True Vertical Depth: 5816'-5843', 5879'-5882', 5891'-5928', 5930'-5938', 5945'-5950' s~r.~3~~I~~~-i~,~ `~~'~l ~~~ Tubing (size, grade, MD, and TVD) 3.5, L-80, 6965 MD, 5730 TVD Packers & SSSV (type, MD, and TVD) SBE@6947' MD, 5730' TVD Camco DS nipple @ 508' MD, 508' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 320 1473 345 -- 204 Subsequent to operation 325 1902 389 -- 208 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development Service . Well Status after work: Oil Gas WDSPL "` Daily Report of Well Operations XX GSTOR ~` WAG ~""'" GASINJ ~" WINJ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce Cpl 265-6471 Printed Name John Peirce Title Wells Engineer Signature ~ ~ ' r Phone: 265-6471 Date 11~~I.~c~ .~ Form 10-404 Revised 7/2009 RBCyMS JAN 2 7' 2010 ~~ Submit Original Only /•Z7 /o ~ ~ ~1~fa 3G-03 Well Events Summary DATE SUMMARY 12/1/09 TAGGED @ 7375' SLM, EST. 1 ~ATHOLE. DRIFTED TBG WITH 12' x 2.~& 12' x 2.77'; NO RESTRICTIONS. READY FOR E-LINE. 12/11/09 PERFORATED 7232'-7238' AND 7212'-7222' WITH 2.5" GUNS, MILLENNIUM HMX, DP, 6 SPF, 60 DEG PHASING. WILL RETURN TOMORROW FOR 3RD GUN RUN. 12/12/09 PERFORATED 7144'-7148' - 2.5" MILLENNIUM HMX DP CHARGES, 6SPF, 60 DEG PHASING. Ct)EIOC<31~'11~~i~S 1 ~` Well Attributes Wellbore API/UWI Fieltl Name Well Status - / 501032024500 KUPARUK F.I .' I INIT (PROD .. ; C ment H2S '~11 Date A tation iEntl Date SSSV: Nipple I ::~ 12110/2009 Last WO: 1/1: ••• Woll COnfg 3G-0a, 1122120" _. '-~. _ Schema[4 Aiubl A tation Depth (ftK6) EndU Annotation Last lag nLM 7,375 0 ~ 12'1. uJ Rev Reason: ADD 12/11/2009 PERF IlCasinq Strings HANGER. 3] CONDUCTOR, 41-121 NIPPLE, 508 -- -- GAS LIFT. -.-_ 2.645 GAS LIFT, 5,598 GAS LIFT. snot GAS LIFT, 6,858 NIPPLE, 6,908 - SEAL ASSV, __ 6.946 RPERF, 7,0fi0~],076 FRAC, 7.060 RPERF,_ 7.060-],080 IPE Rf, ___- ],076-7,096 7.146-] 148 RPERF, 7,160-].180 IPERF._,. __- 7,160-].180 IPERF,_ 7.1 aoa.210 APERF, _ _._._ 7.212-],222-- APERF, 7,232-],238 3G-03 8/6!1996 Casing Description String 0... Striny ID .. Top (ftKB) Set Depth (i... Set Depth (ND) ... String WL.. String ... String Top Thrd CONDUCTOR 16 15.0 G2 41.0 121.0 1210 62.50 H-00 Casing Description String 0... Strung IIJ - Top (ftKB) Set Depth (f... Set Depth (ND) ... IlString Wt... String ... String Top Thrd SURFACE 7518 f "'i0 40.5 3,530.7 3,084.4 29.70 L-80 _ Casing Description String 0... String IIJ _ Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... :,String ... String Top Thrd PRODUC TION 5.5x4 51/2 I 4415!1 32.0 ~, LTC-MOD 7,481.7 6,134.9 17.00 L-80 Tubing Strings __ . ~ - - -- Tubing Description ~, String 0... IStrir.g IU .. Top (ftKB) Set Depth (f... Set Deptn (ND) ... String Wt... Str g... String Top Th1d TUBING ~' 31/2 !1111 36.5 6,965.1 5743.8 9.30 L-80 IBTM Com letion Det ails ' Top Depth ~ (ND) Top Intl INOmi... Top (HKB) (ftKB) (°) Item De.sc ription Comment _ ID (in). 36.5 36.5 0.991 HANti~LF: FMC Gen IV Hanger w/pup 2.867 507.8 507-8 0.74iNIPF'LF 3.5" z 2.875" Camco "DS" Nipple (EUE 8rd) (wlcollar) 2.875 , 6,908.4 5.700.3' _._ _._. 39.98NIPF'LL- 3.5" z 2.813" Camco "D" Nipple 2.813 6,946.51 5,729.6 _- - 40.20 SEAL ASi Y Baker 80-00 GBH-22 Seal Assembly w/6' pup 3.010 ~ Perforations & Slots .- -. _ ._ ___. _. -- snot I Top (TVD) Btm (TI; I:)j Dens 1 Btm (HKB) Top (ftKB) (ftK6) iftKE': i Zone Date (sh-~ Type Commend 7,060: 7,080 5,815.6 5,,83!1 i C~4, 3G-03 9/1/1999 4.0 RPERF ~2 1/8" EnerJet 7,0601 7,076 5,875.6 5,82 8 C~4, 3G-03 10/25/1997 4.0 RPERF 21/8" ENerJet, Zero deg. phasing __ 7,076 7,096 5,827.8 S,f4:; I C-4, C-3, C-1, 8/28/1997 4.0 (PERF 2 118" EnerJet, Zero deg. phasing 3G-03 7,144 7,148 5,879.3 _. ..- 5,88:' 4 A-5, 3G-03 12!12/2009 ~ 6.0 RPERF 25" Millenium Chg, 60 tleg phase 7,160 7,180 5,891.4 5;90;5 2 a-3, 3G-03 8/2911996 4.0 IPERF 2 1/8" EnerJet, Oriented (+/-) g0 deg. ' Ff lowside 7,160 7,180 5,891.4 F: ~O!S.2 A-3, 3G-03 9126/1996 4.0 RPERF 2 1/8" EnerJet, Orientetl (+/.) 90 deg. Fl lowside 7,180 7,210 5,905.2 E -'I:. ii A-3, A-2, 3G-03 8/24/1996 4 0 IPERF 2 1/8" EnerJet, Oriented (+1-) 90 deg. I F/lowside 7,212 '1 7,222 5,929.5 ,_„_, i A-2, 3G-03 12/11/2009 6.0 RPERF 1 25" Millenium guns, 60 deg phase 72321 7,238 5,944 6 '~N I; A-2, 3G-03 12/11/2009 6 0 APERF 1 2.5" Millenium guns, 60 deg phase Stimula tions 8t Treatme nts e.~~no~~,. - _ Min Top Maz Btm '. Top Depth Depth Depth Dep[h (ND) (TVC~ (HKB) (ftKB) (ftKB) INKE:' Type _ Date Comment 7,060.0 7,080.0 5,815.6 S,g.311 s; FRAC 9118/1999 PUMPED FRACTURE TREATMENT, SCREENED I OUT WITH 6 PPG ON PERFS, 21400# IN i FORMATON, 16,900# IN WELLBORE. Notes: General 8 $afety -- --- _-_-- - - - - -- - End Date _ _ Annotation __ _ 1/24/2009 (NOTE: VIEW SCHL;L:' .' Iti: w/Alaska Schematic9.0 1 Mandrel Details _. - --- _ _ Top Depth Top port (TVD) Intl ! OD Valve Latch S¢e TRO R n Stn Top (ftK6) (ftKSi (°) Male Model lint Serv Type Type (in) (p ) Run D t . C_om... l 1 2,644.8 2,3884 3743 CAI'dl C.i:1 r;GG-2-9 i 1 Gas Litt GLV INT 0.156 1,252.0 1/26/2009 2 4449.9 3,807.2 39.38 CAI'oICO hHG-2-9 1 Gas LiR GLV INT 0.156 1,238.0 1/26/2009 3 55984 4,686.1 40.98 CAlbll;~i Pi H(3-2-9 1 Gas Lih GLV INT 0.1881 1,25901/25/2009 :~ ~ 1; RFI-2-9 4 6,400.61, 5,306.0 38.95 CAI'aIC I . _ - 1 Gas Lift GLV INT 0.188 ~i 1,244.0 125/2009 -5 fiRSR 41 50622 39.71 CAfolCiilr;b''s-2-9 1 Gas Lift OV ,IN7 0.250 0.01/25/2009 PROOUCnoN 55x4.32-7,486 rD, 7so1 ~ -- • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 3G-03 Run Date: 12/12/2009 December 16, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3G-03 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20245-00 PLEASE ACKNOWLEDGE RECEIl'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. 1 ~1 ~o'~o~c7 Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael. b arreto@halliburton. com Date: • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 12, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite,~,~ ~, i~'~Y x, ~'~a~ Anchorage, AK 99501x='~~-J"'--'~" ~' Dear Mr. Maunder: ~~-D3 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped February 15th 2009. The corrosion inhibitor/sealant was pumped March 10th and 11th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, M.J. Loveland r~y~' -l~'J ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/12/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3G-02 190-137 SF NA 16" NA 1.7 3/11/2009 3G-03 196-122 SF NA 16" NA 1.7 3/11/2009 3G-05 190-075 12'6" 1.80 19" 2/15/2009 4.25 3/10/2009 3G-06 190-069 8'4" 1.20 18" 2/15/2009 3.5 3/10/2009 3G-07A 190-085 25'6" 3.40 18" 2/15/2009 3.4 3/10/2009 3G-11 190-076 22" NA 22" NA 4.25 3/10/2009 3G-14A 197-251 SF NA 17" NA 3.4 3/10/2009 3G-17 190-122 5' 0.80 16" 2/15/2009 2.55 3/10/2009 3G-18 190-125 18" NA 18" NA 4.25 3/10/2009 3G-19A 201-106 18" NA 18" NA 2.55 3/10/2009 3G-21A 198-052 21' 2.80 2'10" 2/15/2009 12.75 3/10/2009 3G-25X 196-136 SF NA 7" NA 2.55 3/10/2009 FJ~'~ ~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Company: Alaska Oil & Gas Cons Comm +~~~° _ ' `.j~~' Attn: Christine Mahnken ~; ~ u. ~~:.J~i~ ~~~ "" ' 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 03/03/09 3H-33 1 D-130 2A-26 3H-33 3C-06 2N-318 3H-33 3J-06 1 D-119 G-03 B04C-00006 ANHY-00049 ANHY-00053 AYS4-00039 8146-00005 8146-00006 B04C-00006 B14B-00008 AYS4-00044 AYS4-00043 USIT _ INJECTION PROFILE ~) ~ ~ - PERF/SBHP SURVEY ~ _ L (~ (p . SFRT _ - GLS ~/ - ~ SBHP SURVEY _ _ / (} SONIC SCANNER - ~' PRODUCTION PROFILE INJECTION PROFILE , '~ - - :.. ~ ~ PRODUCTION PROFILE - f' - 02/09/09 02/12/09 02/16/09 02/23/09 02/23/09 02/24/09 02/09/09 02/27/09 02/28/09 02/27/09 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317: Thank you. • STATE OF ALASKA ~~~ V ~~, exS ~E~3 ~~ 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATICS l ~'~ & Gas Cons. Eomn AnnKnretin 1.Operations Performed: Abandon ^ Repair Well Q Plug Perforations ^ Stimulate ^ Other Alter Casing ^ Pull Tubing Q Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillipS Alaska, InC. Development ^~ Exploratory ~ 196-122 / 3. Address: Stratigraphic ^ .Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20245-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 54' 3G-03 . 8. Property Designation: 10. Field/Pool(s): ADL 25547 ' Kuparuk River Field / Kuparuk Oii Pool 11. Present Well Condition Summary: Total Depth measured 7501' feet true vertical 6145' feet Plugs (measured) Effective Depth measured 7422' feet Junk (measured) true vertical 6086' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 3436' 7-5/8" 3531' 3085' PRODUCTION 6921' 5-1/2" 6962' 5742' PRODUCTION 525' 4-1/2" 7488' 6135' Perforation depth: Measured depth: 7060'-7096', 7160'-7210' r/'J~ ~ ' ' ' '~ _ t. a ` ~ true vertical depth: , 5891 5816 -5843 -5928' ~ r',;,~, ~a ~ Tubing (size, grade, and measured depth) 3-1 /2" , L-80, 6965' MD. Packers & SSSV (type & measured depth) Baker SBE @ 6946.5' Camco'DS' nipple @ 508' 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 SI -- Subsequent to operation 402 1600 719 -- 233 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ 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 NiA if C.O. Exempt: none Contact Erik elson 2 3 Printed Name gels Signature Title Phone: 263-4693 Wells Engineer /0 Date /~~~~~~ Pre ared b Sharon All u Drake 263-4612 Form 10-404 Revised 04/2006 ~ ~'~ ~~~ ~ ~ ~'+ ~~ ~ Submit Ori nl ~.., ~ Y/• CanocoPhillips Ai.: emu, lik-: ... _ _~e coma '1f~tag ~_ __. Sghe_InLIp~AgV HANGER. 37 CONDUCTOR. 0-121 NIPPLE. 508- , GAS LIFE, _ 2,6x6 SURFACE,- 0-3,531 GAS LIFE, 6,x50 GAS LIFE, 5.598 GAS LIFT fi,601 GAS LILT, 6,658 KUP ~ 3G-03 Wellbore APVU WI 'Field Name ',Well Status Prodllnj Type Illncl (°) MD (ftK8) Ad Btrn (flKB) 501032024500 .KUPARUK RIVER UNIT '.PRODi 42.66 7500.98 7,501.0 iComment IH2S (ppm) Date Annotation IEnd Date ~KBGrd (ft) Rig Release Dab SSSV~ Nipple- 160 I 7/1/2008 (Last WO: I 11182009 , ~ 8/6/1996 A notation iDepth (flKB) End Date Annotation End Date Last Tag: SLM I 7,383.0 I 1/30/2009 Rev Reason: POST FCO TAG I _ Casin Strin s Casing Description String 0... String ID ... Top (flKB) Set Depth (f... Set Depth (ND) ... String Wl... String ._ String Top Thrd CONDUCTOR 16 15.062 0.0 121.0 1210 62.50 H-00 Casing Description String 0... String ID ... Top (ftK8) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top ThM SURFACE 75/8 6.750 0.0 3,531.0 3.084.7 1 29.70 L-80 Casing Description String 0... String ID ... Top (flKB) Sat Depth (f..- Se[ Depth (ND) ... Siring Wt... String ... String Top Thrtl PRODUCTION S 1/2 4.500 0.0 6,963.0 5,742.2 17.00 L-80 ~ICasing Description String O._ , String lD ... Top (ftK8) Set Depth (f... Set Depth(ND)... ISiring Wt... String... String TOp Thrd PRODUCTION 41/2 ' 3.795 6,963.0 7,488.0 6,135.1 ' 12.75 L-80 Tubing Strin -__ gs Tubing Description String O._ String ID ...TTOP IftK81 Set Depth (f... Se[ Depth (ND) ... String Wt_.String _. String Top Thrd UBING 31/2 ~ 2.991 I 36.5 I 6,965.1 I 5,743.8, 9.30 ! L-80 '~, IB1M ;ompletion Det ~ITop De Pth'~ ails _ _... -. __.. (ND) '. ToP Inc! ' op (flKB) (flKB) ~ (°) Item Description CommeM ID (in 36.5 36.5 0.99 HANGER FMC Gen IV Hanger w/pup 2.86 507.8 507.8 0.74 NIPPLE 3.5" x 2875" Camco "DS" Nipple (EUE Srd) (w/collar) 2.87 6,908.01 5,700.3 i 39.98 NIPPLE 3.5" x 2.813" Camco "D" Nipple w/RHC Plug (EUE Srd) (w/collar) 2.81 6,946.5 ' S,729.6'I ~--- J--~ 40.20iSEAL ASSY Baker 80-00 GBH-22 Seal Assembly w/6'pup 3.01 'erforat ions -- - -',sna '. Top (TVD) Btm (ND) ~ ~ Dens op (flKB) etrn (flKB) (ftK8) (ftK8) Zone ~ Data (sh... Type CommeM 7,060.0 7,080.0 5,815.6 5,830.9 C-0, 3G-03 9/1/1999 4.0 RPERF 2 1/8" EnerJet 7,060.0 7,076.0 5,815.6 5,827.8 C-0. 3G-03 1025/1997 4.0 RPERF 1 2 1/8" ENerJet, Zero deg. phasing 7,076.0 7,096.0 5,827.8 5,843.1 C-0, C-3, C-1, 8/28/1997 4.0 IPERF x ,21/8" EnerJet, Zero deg. phasing 3G-03 - __ 7,160.0 7,180.0 5,891.4 5,905.2 A-3, 3G-03 8/29/1996 4.0 IPERF 2 1/8" EnerJet, Oriented (+/_) 90 deg. F/ lowsltle 7,160.0 7,180.0; 5,891.4 5,905.2 A-3, 3G-03 9/26/1996 4.0 RPERF 2 1/8" EnerJet, Oriented (+/-) 90 deg. ~ F/ lowsitle 7,180.0 7,2100 5,905.2 5.928.0 A-3, A-2 3G-03 824/1996 ~ 4 0 IPERF 2 1/8" EnerJet, Orientetl (+/-) g0 deg 8 I -_ F/ lowside stimula Min Top tions Treatme Max Btrn TOp Depth nts Bottom ~ -i Daplh Depth Depth (ND) lT11D1 (ft KBJ (flKB) 1 (flKB) (ftK8) Type ~' Date CommeM 7,060.0 7,080.0 ' 5,815.6 5,830.9'FRAC '9178!1999 PUMPED FRACTURE TREATMENT, SCREENED .OUT WITH 6 PPG ON PERFS, 21400tt IN FORMATON, 16,900tJ IN WELLBORE {otes: General End Date & Safety Annotation 242009 NO iE VIEW SCFIEMATIC w/Alaska Schemanc9.0 ~^ NIPPLE. 6.908 - - SEAL ASSY, _ fi,966 PRODUCTION, 0-6.463 IPE Rf, ],076-7,096 IPERF,_ ],160-7.180 RPERF. 7.160],180 IPERF, ],180-7,210 PRODUCTION, 6.963~7.a88 TD. 7,501 landrel Details Top Depth Top _.-. -.. _.... '_ PoA VD ) Inc! OD Valve Latch Size TRO R n flKB n To ftK8 ( ) PI ) (°) Make Model (in) Serv Type Type (N fps) Run Date Comm_ . , 1~ 2,644.8 2,388.4 37.43 CAMCO'KBG-2-9 1 Gas Llft GLV INT 0156 1,2520, I 1/26/2009 _- 2 4,449.9 3,807.2 39.38 CAMCO KBG-2-9 11 Gas Lift IGLV INT 0.156 1,238.0 '1/26/2009 3 5,598 4 4,686.1 40.98 CAMCO KBG-2-9 1 Gas Lift IGLV INT 3116 1,259.0 1/25/2009 _- 4 6,400.6 5,306.0 38.95 CAMCO KBG-2-9 1 Gas Lift GLV INT 3116 1,244.0 1/25/2009 5 6.858.4 __- 5,662.2 39.71 CAMCO KBG-2-9 1 Gas Lift OV INT 1/4 0.0 1/25/2009 -_ r1 ConocaPhi~lips Time Log & Summary ~ue„v,~w ~e~ ~e~°~,n~ Report Well Name: 3G-03 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 1/11/2009 2:00:00 AM Rig Release: 1/17/2009 9:30:00 AM Time La s - - - _---- Date From To Dur S. Depth E Depth Phase Code Subcode T__C_omment 1/11/2009 24 hrSummarv RDMO well 3G-26, hung tree in cellar, spotted rig over well 3G-03, spotted tanks and mud shack, loaded 290 bbls sea-water in pits, RU kill tank and hard line, pulled BPV, attempted to kill well with sea-water, monitored and weighted up surface volume to 8.6ppg, circulated around and monitored, well dead, installed BPV, ND tree, installed test dart, NU BOP, broke down annular to CO seals under element. 00:00 01:30 1.50 MIRU MOVE OTHR P Hung tree in cellar, spotted pit liner and T mats, spotted well head e ui ment behind well. 01:30 03:00 1.50 MIRU MOVE PSIT P Pulled rig over well, leveled up and installed handy-berm, installed hardline to kill tank, spotted tanks and mud shack. Accepted Nordic Rig 3 at 2:00 AM, 1 /11 /2009 03:00 04:00 1.00 COMPZ RPCOM RURD P Loaded 290 bbls sea-water in pits, staged lubricator on rig floor, checked sump alarms, prepped circ hoses in cellar. 04:00 07:30 3.50 COMPZ RPCOM NUND P PU lubricator, RU on tree, pull BPV. ~ SITP = 2,140, IA = 2,070, OA = 0 -- psi. MU upper circ hose on tree, test hardline at 120 air/250/2,600 si. 07:30 14:00 6.50 COMPZ WELCTL KLWL P Killed well by pumping 8.5 ppg seawater. Pumped 175 bbls before getting returns to kill tank, venting gas. Pumped @ 3BPM/400 psr. Switched to seawater w/.6% Safe-Cube. Pumped total of 312 bbls. SD monitor well, 0 psi on IA & tubing, small flow back on IA from charging well. Monitored well, slight increase. 14:00 17:00 3.00 COMPZ WELCTI KLWL P Wei ht up fluid to 8.8 ppg. Pumped 230 bbls 8.8 ppg SW 325 psi @ 3 SPM .SD monitor well. IA'0' Tubing '0'. Lost 191 bbls to formation during both circulations. 17:00 22:00 5.00 COMPZ WELCTt NUND P Set BPV. ND tree, NU BOPE, remove cap and element rubber from annular to CO seals, start rack and tall of 3 1/2" IBT com letion tb . 22:00 00:00 2.00 COMPZ RIGMN7 RGRP P Remove cap and element rubber from annular to CO seals, start rack and tall of 3 1/2" IBT com letion tb . 1 /12/2009 Re-assemble annular assembly, NU riser, had pressure on IA, killed well pumping through BPV, mixed and pumped hi-vis pill, bullheded pill over perfs, CBU, monitored well, CO BPV, installed blanking plug, shell test stack, test BOPE. F'~ge 1 of • Time Logs 'Date From To Dur S. De th E. Depth Phase Code Subcode T Comment__ ~ __ _ 00:00 06:00 6.00 COMPZ RIGMNT RGRP P Fabricate lifting device for annular piston, cont rack and tally 3 1/2" IBT tbg, Co seals, clean out body cavity, 06:00 07:30 1.50 COMPZ WELCTI NUND P Continue NU BOPE riser. 07:30 08:30 1.00 COMPZ WELCTI BOPE P Atttem t to test BOPE. Check IA, 650 psi on IA. Rig up to kill well. Pull blankin lu MU landin 't. 08:30 10:30 2.00 COMPZ WELCTL KLWL P PJSM. Opening PSI on IA 620 psi. Start pumping, took 720 psi to offset BPV. Pumped @ 2BPM,200 psi. ICP 720 FCP 200 si. still asin . 10:30 11:00 0.50 COMPZ WELCTL KLWL P Mix up hi-vis pill. 11:00 12:00 1.00 COMPZ WELCTI KLWL P Pumped 20 bbl hi-vis pill, chased with 18 bbls to get on spot, closed IA and bullhead 12 bbls @ 2 BPM w/500 si to et ill over erfs. 12:00 12:30 0.50 COMPZ WELCTI KLWL P Opened IA, circulated bottoms up 2.5 BPM @ 390 ICP, 350 FCP (8.7+ 12:30 14:00 1.50 COMPZ WELCTI KLWL P Shut down pump, monitor well, static. 14:00 15:00 1.00 COMPZ WELCTI NUND P Pull landing jt. RU kill line. Opened IA and monitor while chan in out BPV. 15:00 16:00 1.00 COMPZ WELCTI BOPE P Confirmed no pressure under BPV. Pulled and re laced BPV. Well static. 16:00 00:00 8.00 COMPZ WELCTI BOPE P Start tests on BOPE 250/2600 psi. Witnessing waived by Bob Noble @ 14:30 hrs 1/12/2009. 1 /13/2009 Pull blanking plug, install landing joint, RU and circ down tbg with 8.7 ppg to kill well, pu-I landing joint, pull BPV, MU landing joint and top drive, circ surf to surf at hi rate, monitor well, BOLD's, pull hanger to floor, CBU at hi h rate, decom lete 00:00 03:00 3.00 COMPZ WELCTI NUND P RD test equipment, RU circ lines in cellar to kill well, thaw out kill line, check hardline to kill tank with air, test cellar manifold and choke line connections. 03:00 04:00 1.00 COMPZ WELCTL OTHR P Drain stack, PU retrieval joint and pull blanking plug, install landing joint and circ hose. 04:00 06:00 2.00 COMPZ WELCTI CIRC P O enin PSI on IA 480 si. Start pumping, took 680 psi to offset BPV. Pumped @ 2 1/2 BPM, ICP 700 psi. Pumped 200 bbls 8.7 ppg brine. FCP 250 psi @ 2 BPM. Monitor well, static. 06:00 07:30 1.50 COMPZ WELCTL CIRC P Pull testjt. out. Pull BPV. RU landin 't. ~ ~_ Page 2 ot~ ~ Time Logs -_ - __ _- Date From To Dur S. De th E. De th Phase Code Subcode T Comment - 07:30 - 09:00 1.50 COMPZ WELCTI CIRC -- P - - Pumped 250 bbls 9.0+ppg brine displacing 8.7 ppg from hole. ICP 430 psi @ 4 BPM. When good 9.0+ ppg all around, SD monitor well. FCP 540 psi @4 BPM.WeII taking fluid at rate of approx. 10 BPH. Lost approx. 110 bbls to formation while um in . 09:00 10:00 1.00 COMPZ RPCOM PULD P RU kill line & top drive. BOLDS. Unland hanger by pulling 140K. Pull hanger to rig floor. Filled hole with 2 bbls. 10:00 11:30 1.50 COMPZ WELCTI CIRC P Circulate bottoms up ICP 430 psi w/4 BPM, FCP 430 psi w/4 BPM. Monitor well, still taking fluid @ a rox. 10 BPH. 11:30 22:00 10.50 6,933 0 COMPZ RPCOM PULD P POOH laying down 3 1/2" tubing & 2 7/8"jewelry. Found heavy corrosion on cou lin s from GLM #1 to Seal assy. 2 7/8 TBG was buckled below 3 1/2 TBG and Jts 205 and 206 had holes corroded from out side. 22:00 23:00 1.00 0 0 COMPZ RPCOM OTHR P Un load pipe shed, change over to RIH w/ 3 1/2 PH-6 23:00 00:00 1.00 0 95 COMPZ RPCOM PULD P MU Mule shoe and RIH to 95', POOH due to Gas break out in fluid. Frothing out of TBG. Change out Mule shoe to IBOP. Monitor well - Well bubblin w/ no flow. 1 /14/2009 RIH w/ 3 1/2 Work string 2 7/8 IBOP to 3,653'. SWI due to well flowing. Kill well w/ 9.1 ppg KWF. Monitor well and RIH to 6,555'. Circulate 2 hole volumes. POOH w/ 3 1/2 PH-6 in derrick. Land hanger w/ landing jt. and SWI. WO E line to RIH w/ 2 1/8" IBP. Trouble shoot E line elect. s stem. 00:00 01:00 1.00 0 3,653 COMPZ RPCOM TRIP P RIH w/ 2 7/8 IBOP to 3,653' 01:00 03:30 2.50 3,653 3,653 COMPZ WELCTI CIRC T Well began to flow w/gas @ surface.SWl w/ UPR's @ 01:10 hrs. SIDP 150 psi. SICP 150 psi. ICP 170 psi DPP. 200 psi choke @ 1 bpm. Circulate 1.5 hole vol. Notified Anc Eng., and John Krisp w/ AOGCC 01:55 AM. 03:30 04:00 0.50 3,653 3,653 COMPZ WELCTI OWFF T Monitor well for flow -Open UPR's - Well static w/ as break out. 04:00 05:00 1.00 3,653 3,653 COMPZ WELCTI CIRC T CBU @ 3 bpm @ 280 psi. Well Static -Blow down TD. 78 bbl Fluid losses to erfs Burin well kill o s. 05:00 06:30 1.50 3,653 COMPZ RPCOM TRIP P Continue to RIH f/ 3,653' to 6,555' 06:30 08:30 2.00 COMPZ WELCTL CIRC P Circulate thru gas buster to condition hole fluid. ICP= 380 psi @ 3 BPM FCP=400 psi staged rate down to keep down the yo-yoing. Pumped total of two hole volumes (275 bbls.) lost 66 bbls. 08:30 09:00 0.50 COMPZ WELCTI OWFF P Monitor well, taking fluid @ approx. 8 BPH. 09:00 09:30 0.50 COMPZ WELCTI TRIP P Blow down Top Drive. RU floor for ullin out of hole. Monitorin well. raga ~ pf Time Logs ___ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 09:30 14:30 5.00 COMPZ ~WELCTt TRIP P _ POOH standing back PH6 workstring. Hole fill was double what calculted until we of to 892'. Well started flowin back. SI UPR. 14:30 15:00 0.50 COMPZ WELCTI CIRC P Circulated over top of hose from 892' w/9.0+, ICP 80 psi @ 1 BPM. FCP= 50 psi @ 1 BPM. Shut down well static. 15:00 15:30 0.50 COMPZ WELCTI TRIP P POOH w/remaining 10 stands. PU and land old tubing hanger, RILDS. Stabbed TIW valve and shut in. 30mins ress = 150 si 15:30 17:30 2.00 COMPZ WELCTL WOEQ P Wait on E-line to run IBP. 17:30 00:00 6.50 COMPZ WELCTL WOEL T Trouble shooting electrical problems w/ generator on E line unit. Load lubricator and BOP's in pipe shed while trouble shootin . 1/15/2009 Continue to trouble shoot E line Elect. system. PJSM Make gage run to PBTD. RIH w/ IBP to 7,020' and set and test to 1,500 si. RD E line. Bleed off well and RIH w/ 3 1/2 work strin w/ seal ass to 1,419'. 00:00 01:00 1.00 COMPZ WELCTL WOEL T Continue Trouble shooting electrical roblems w/ enerator on E line unit. 01:00 01:30 0.50 COMPZ WELCTL SFTY P Held PJSM w/ E line and rig crew. 01:30 06:00 4.50 COMPZ WELCTI OTHR P MU Lubricator, BOP's, and gau ecL_ run tools. PT Lub to 800 psi. Equalize to 400 psi open TIW valve and RIH to 7,210' and to u on fill. POOH. 06:00 07:00 1.00 COMPZ WELCTI OTHR P Bleed off lubricator. Break out gauge run tools, install 2 1/2" IBP. 07:00 08:30 1.50 COMPZ WELCTL OTHR P RIH w/IBP and et on de th @ 7.30 w/center of element, 7024' w/fishing neck. 08:30 09:30 1.00 COMPZ WELCTI OTHR T Attem t to set IBP, would not set. 09:30 10:30 1.00 COMPZ WELCTI OTHR T POH w/IBP. 10:30 11:30 1.00 COMPZ WELCTL WOEQ T Wait on replacement IBP from Deadhorse. 11:30 12:30 1.00 COMPZ WELCTL OTHR T Shut TIW, bled pressure off lubricator. ND failed IBP. NU new IBP. 12:30 15:00 2.50 COMPZ WELCTL OTHR T RIH @ 100' per hr. Correlate and get on spot. Set IBP @ 7030' to center of element, 7024' to top of fishing neck. Confirmed set by lowering back down and stacking wt. When icked u lost 100#. PU hole 200'. 15:00 15:30 0.50 COMPZ WELCTL OTHR P 700 psi on 5 1/2" casino. Bled off to '0". Attempted to pressure upon IBT to 1350 psi, 4 1/2' IF xover leaked. Bled off ressure. 15:30 16:00 0.50 COMPZ WELCTL OTHR P POOH with running tool. 16:00 19:00 3.00 COMPZ WELCTI OTHR P Bled off pressure. Rig down E-line. NU head pin. Presssure test IBT to 1500 psi held good. Bled pressure off. Finish ri in down SWS. ~~__~_ ~ ~a~e 4 €~f ~i Time Low -- -- - -- - _ Date _ From To Dur S. Depth E._ Depth Phase Code Subcode_ T Comment _ ___ ~ 19:00 20:30 1.50 COMPZ WELCTI OTHR P RU choke line to BOP stack, BOLDS, Pull hanger to rig floor. RU Boue line from to IA. 20:30 22:30 2.00 COMPZ WELCTL BOPE P Install test plug. Test 2 7/8 HT PAC IBOP, Choke Manifold valves 2,5,and 6, Upper VBR's, and 3 1/2 8rd Full opening safety valve @ 250/2,600 psi. Pull test plug. Equipment used in well shut in on 1-14-09 @ 01:10 AM. 22:30 23:00 0.50 COMPZ WELCTL OWFF P Fill hole and monitor. 23:00 00:00 1.00 0 1,419 COMPZ RPCOM TRIP P MU Seal ass and RIH w! 3 1/2 PH-6 work string to 1,419'. 45k up wt, 45k do wt. 1!16/2009 Continue to RIH f/ 1,419' to 6,973' - NO go and pull out of CSR. CBU. Stab seal assy and PT IA to 2,500 si. POOH la in down PH-6 and seal ass . RIH w/ 3 1/2 Production strip to 4,385'. Sli and cut drill line. 00:00 06:30 6.50 1,419 6,961 COMPZ RPCOM TRIP P Continue to RIH w/ seal assy on 3 1/2 PH-6 f/ 1,419' to 6,961' conditioning hole volume w/ 9.1 ppg brine. 06:30 07:30 1.00 6,961 6,942 COMPZ RPCOM DHEQ P Lowered seals into SBE wlpump on, pressure increased when seals entered SBE. RIH and tagged locator. Pressure test IA to 2500 psi and held for 10 min. Bleed off. Pulled seals back up to 6942' and RU to circulate. 07:30 08:00 0.50 6,942 6,942 COMPZ RPCOM CIRC P Circulated hole clean, (175 bbls) 5 BPM @ 1120 psi. Returns clean w/no oil/gas, shut down pump, well static. 08:00 15:30 7.50 6,942 0 COMPZ RPCOM TRIP P POOH w/PH6 workstring laying down. LD xover and seal assembl . 15:30 17:00 1.50 0 0 COMPZ RPCOM OTHR P Clean rig floor, MU proper tools for runnin com letion. 17:00 22:30 5.50 0 4,385 COMPZ RPCOM PULD P PU and MU 3 1/2, 9.3#, L-80, IBTM w/SCC Recompletion string as per Run order. RIH to 4,385' 65k up wt, 60k do wt. 22:30 00:00 1.50 4,385 4,385 COMPZ RIGMNT SVRG P PJSM, Slip and Cut 96' of 1 1/8"drill line. Ins ect brakes and linka e. 1 /17/2009 Continue to Service rig. Continue to RIH f/ 4,385' to 6,450'. PU and MU HES Storm pkr and RIH and set @ 66'. PT. ND BOP &TBG Spool. chage packoff. NU TBG Spool & BOP. Test. Pull HES Pkr. RIH w/ Compl. and land. PT. 00:00 01:00 1.00 4,385 4,385 COMPZ RIGMNT SVRG P Continue to service rig 01:00 04:30 3.50 4,385 6,527 COMPZ RPCOM PULD P Continue to RIH w/ 3 1/2 Recompletion f/ 4,385' to 6,450'. PU and MU HES RTTS Storm PKR and set 66' and PT to 2,500 si. 04:30 15:30 11.00 6,527 6,527 COMPZ RPCOM NUND P ND BOP and TBG Spool. Change out pack off, cut off 1" of 51/2"and NU New TBG s ool and BOP. Page ~ of S Time Lo s -~- - - -- Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15:30 16:30 _ 1.00 6,527 6,527 COMP Z LCTI EW BOPE P __ Retest Blinds, DSA, tubing head, Choke manifold valves 2,5,6. Witnessing of shell test waived by Jeff Jones. 16:30 18:00 1.50 6,527 6,450 COMPZ RPCOM PULD P Blow down lines. Pull test plug. MU Halliburton retrieving tool. RIH screw into RTTS, check for pressure, PU and released acker. POOH and LD. 18:00 19:00 1.00 6,450 6,968 COMPZ RPCOM PULD P MU and RIH from w/ 2.875" DS Nipple and 16 jts 3 1/2, 9.3# L-80 IBTM TBG. Tag @ 6,956' w/ mule shoe @ 6,968'. PU and pump @ .5 bpm and locate and pressure up, veri seals in SBE. 19:00 20:30 1.50 6,968 6,855 COMPZ RPCOM HOSO P Space out w/ 2.5' off locator and MU Han er. 20:30 21:30 1.00 6,855 6,855 COMPZ RPCOM OTHR P Pump 20 bbl corr. inhibited fluid and chase w/ 50 bbl KVVF. Spotting 10 bbls inside and 10 bbls outside from 5,706' to 6,855' (top of SBE). Drop Ball and rod wait to fall to 6 908' and seat in RHC Plu . 21:30 00:00 2.50 6,855 6,965 COMPZ RPCOM DHEQ P Land hanger w/mule shoe @ 6,965'. 85k up wt, 73k do wt and 35k block wt. RILDS, Test TBG to 2,500 psi for 15 minutes. 81eed back to 2,000 psi. PT IA to 3,000 si for 30 minutes. Bled off IA to 0 psi and bleed down TBG to 0 si. Shear out SOV @ 6,858' @ 1,700 si. RD PT E ui ment. 1!18/2009 ND BOP & NU Tree PT Tree. FP RDMO. Released Nordic 3 rig @ 0930 hrs 1/18/2009 00:00 02:00 2.00 6,965 6,965 COMPZ RPCOM NUND P Set BPV, ND BOPE 02:00 04:00 2.00 6,965 6,965 COMPZ RPCOM NUND P NU Adapter and Tree. AI Rosentrater DSO verified oreintation of wellhead. PT 250/5,000 psi. Remove TTP. 04:00 09:30 5.50 COMPZ RPCOM FRZP P PJSM, RU and PT lines @ 2,600 psi. Pump 72 bbls diesel down IA for freeze protect from 3100' MD. Allow to U-tube thru jumper hose at surface. Install BPV. Back rig off well, Clean cellar etc. with Super Sucker. Release Nordic 3 rig @ 0930 hrs. 1/18/2009 Pala o of 6 3G-03 Post Rig Workover Summary DATE SUMMARY • 1/14/09 DEPTH DETERMINATION, F D TOP OF FILL AT 7210'. RAN BAKER IBP AND SET IN 4.5" CASING. IBP SET WITH MID ELEMENT AT 7030' 1/24/09 PULL BALL AND ROD FROM 6908' RKB.REPLACE SOV WITH DV @ 6857' RK6.30 MIN MITT-- PASS.30 MIN MITIA--PASS. IN PROGRESS. 1/25/09 REPLACED DV WITH 1/4" ORFICE @ 6857' RKB.REPLACED DV WITH GLV (3/16" PORT,TR0=1244#) @ 6401' RKB.REPLACED DV WITH GLV (3/16" PORT,TR0=1259#).NEGATIVE TEST ON IA IS GOOD.IN PROGRESS 1/26/09 REPLACED DV WITH GLV (5/32" PORT,TR0=1238#) @ 4450.REPLACED DV WITH GLV(5/32" PORT,TR0=1252#) @ 2645' RKB.DRAW DOWN IA.GOOD.PULL 2.81" PLUG BODY FROM 6908' RKB.MOVED 2.5" BAKER IBP TO 117' UPHOLE TO "D" NIPPLE @ 6908' RKB.IN PROGRESS 1/27/09 ATTEMPTED PULL BAKER 2.5" IBP FROM 6908' RKB. APPARENT MINIMAL MOVEMENT UPHOLE. IN PROGRESS. 1/28/09 PULLED 2.5" BAKER IBP; RECOVERED 2 OF 3 SEALING ELEMENTS. TAGGED @ 7187; SLM. READY FOR CTU. 1/29/09 PERFORM FCO DOWN TO 7356' CTMD USING SLICK-DIESEL /GEL AND NITROGEN LEAVING 146' FEET OF RAT HOLE. HAD GOOD 1 FOR 1 RETURN WITH LIGHT TO MEDIUM SAND MIXED IN WITH GEL PILLS. PUMP 50 bbls OF 60 DEG SLICK-DIESEL DOWN FLOWLINE AND PT FOR 5 MINS.RETURN WELL BACK TO PRODUCTION. WELL READY FOR DRIFT & TAG FOR UPCOMING PPROF. 1/30/09 TAGGED @ 7383' SLM, EST. 193' RATHOLE. READY FOR E/L. Gentlemen, ~~~-~aa • At 23:30 hrs on 1-13-09 Nordic Rig 3 on 3G-03 was out of the hole w/the 3'/2 De-completion. The trip sheet showed calculated hole fill of 22.4 bbls and actual was 104 bbls, 81.6 bbls over calculated hole fill. They had made up a mule shoe on the 3'/s Work string to be laid down and ran in the hole to 95' when they had to pull back out of the hole with the same due to fluids frothing over the top of the tubing stub. They monitored the well, which was only bubbling w/ no flow. They swapped out the mule shoe and ran an IBOP on bottom of the work string to 3,653'. The well began to flow w/gas @ surface, so they closed in UPR's and made up top drive. Obtained SIP's @ 01:10 AM to 01:30, SIDP 150 psi, SICP 150 psi. Circulated 9.1 ppg KWF @ 1 bpm w/ ICP of 170 psi DPP and 200 psi choke side. They circulated 1 '/2 times the hole volume w/ FCP 130 psi DPP and 150 psi choke side. We monitored well for flow and opened UPR's - well static w/gas break out. CBU @ 3 bpm @ 280 psi, shut down and monitor well -Static w/ no gas break out. Blow down Top drive. Fluid losses to formation during this well kill were 78 bbls. Continue to RIH f/ 3,653' to 6,555' as of 06:00 hrs plan to condition hole volume. Update: On bottom (6555')@ 06:00 hrs, circulated two hole volumes, well dead. POOH w/workstring w/IBOP, hole fill was double coming out until 900'+/-. Shut down monitored well, small flow. Shut UPR. Circulated hole @ 900'. Well dead. POOH w/remaining 10 stands. Landed tubing hanger back with landing jt and TIW valve in top and shut TIW valve. Initial shut in pressure 50 psi. After 30 min. pressure 150 psi. Plans are to run a Inflatable Bridge Plug and set just above perfs @ 7020' for well control. We will retest the UPRs , IBOP and TIW valve after IBP is set, tested and verify well dead. Update: January 15, 2009 IBP was set and Pressure tested to 1,500 psi. Casing was pressure bled off. Monitor well no flow. All equipment used in well shut in on 1-14-09 was tested @ 250/2,600 psi. Items tested are as follows: Choke manifold valves 2, 5 and 6, 2 7/8 HT PAC IBOP, 3 % EUE FOSV and Upper VBR's. As 2300 hrs crews was RIH w/ work string and seal assy. PTD # 196 - 122 ~ ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Nelson, Erik O [Erik.Nelson@conocophillips.com] Sent: Friday, January 16, 2009 11:30 AM To: Maunder, Thomas E (DOA) Subject: PTD # 196 - 122 Attachments: 3G-03 well control on 1-14-09.doc Mr. Maunder, As we spoke on the phone here is the latest write-up from the Wellsite Company reps. Just making sure you were fully in the loop. If you have any questions, comments, or need for further information please don't hesitate to contact me. Thank you for your time. Also, please correct me if I'm mistaken in just putting the PTD# in the subject line and removing the original subject statement. Q Erik Q Nelson Workover~Wells Engineer ConocoPhillips Alaska, Inc. Office #I507 700 G. Street Anchorage, AK 9950I Office (907) 263 - 4693 Cell (907) 748 - 0640 From: Nordic 3 Company Man Sent: Friday, January 16, 2009 2:59 AM To: 'AOGCC Inspectors' Cc: Gober, Howard; Nelson, Erik Q; Ennis, J J; CPA Wells Supt; Nordic 3 Toolpusher; Nordic 3 Tour Pusher Subject: January 15, 2009 update on 3G-03 well control shut in on January 14, 2009 Here is a record of events that took place during the well control shut in and prior to commencing normal operations. If any questions feel free to call. Thanks, Rick Overstreet /Peter Nezaticky (Days) Randy Dolcater / Rance Peterson (Nights) Nordic 3 Co Man Office: 907-659-7446 Qr~ r.~E~ ~ ~ crt cs3rJ 3/24/2009 3G-03 Nordic Rig 3 ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Crisp, John H (DOA) Sent: Wednesday, January 14, 2009 7:03 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Noble, Robert C (DOA); Jones, Jeffery B (DOA); Scheve, Charles M (DOA); Grimaldi, Louis R (DOA) Subject: FW: 3G-03 Nordic Rig 3 Attachments: 3G-03 well control on 1-14-09.doc From: Nordic 3 Company Man [mailto:n1433@conocophillips.com] Sent: Wednesday, January 14, 2009 7:01 AM To: AOGCC Inspectors Cc: Gober, Howard; Nelson, Erik Q Subject: 3G-03 Nordic Rig 3 Gentlemen here is list of events that occurred on Nordic rig 3 @ 3G-03. «3G-03 well control on 1-14-09.doc» Rick Overstreet /Peter Nezaticky (Days) Randy Dolcater / Rance Peterson (Nights) Nordic 3 Co Man Office: 907-659-7446 Fax: 907-659-7566 (~. e 3/24/2009 oN OR BEFO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate _ Pull tubing _ Alter casing Repair well Other 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska. Inc. Development X. 41' RKB 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 2538' FNL, 320' FWL, Sec 24, T12N, R8E, UM 36-03 At top of productive interval: 9. Permit number/approval number: 2232' FNL, 1347' FEL, Sec 24, T12N, RSE, UM 96-122 At effective depth: 10. APl number: 2168' FNL, 1114' FEL, Sec 24, T12N, RSE, UM 50-103-20245-00 At total depth: 11. Field/Pool: 2155' FNL, 1063' FEL, Sec 24, T12N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7501 feet Plugs (measured) None true vertical 6145 feet Effective Deptt measured 7422 feet Junk(measured) None true vertical 6086 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 260 Sx AS I 121' 121' Surface 3490' 7-5/8" 720 Sx AS III & 3531' 3085' 330 Sx Class G Production 7450' 5.5 X 4.5" 153 Sx Class G 7488' 6135' Liner Perforation Depth measured 7060'-7096', 7160'-7210' ~ ~ ....'~. ~¢~',~,~ true vertical 5815'-5843', 5891'-5929' ~.,~, ~., Packers and SSSV (type and measured depth) P~cker: Baker GBH-22 Locator @ 6962'; SSSV: None, nipple @ 51 13, Stimulation or cement squeeze summary Fracture stimulate 'C' sands on g/18/gg Intervals treated (measured) 7060'-7080' Treatment description including volumes used and final pressure Pumped 21400 lbs of ceramic proppant into formation, final pressure was 4000 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 473 283 495 1038 188 Pre gas-lifted rates Subsequent to operation 45 3 635 53 167 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations ~X Oil X Gas Suspended Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 R~/~16~15/88 SUBMIT IN DUPLICATE",x , Alaska, Inc. ~-~- ~ .KUPARUK RIVER UNIT .. ELL SERVICE REPORT ~ 3G-03(4-1)) WELL JOB SCOPE JOB NUMBER 3G-03 FRACTURING. 0829990657.3 DATE DAILY WORK UNIT NUMBER 09/18/99 FRACTURE TREATMENT DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 9 ~ Yes 0 NoI ~ Yes 0 No DS-YOAKUM ODELL FIELDAFC# ICC# I D^,LYOOS ^CC MOOST ESTIMATE 999356 230DS36GL $154,226 $363,498 I oa IfinalOA ITTLSize Initial Tbg I FinalTbg I Initial IA Final IA I Initial 916PSII 300PSII 325P81 500PSII 0PSI 0PSII 2.992 ,, 2.250 "I 6954FT DALLY SUMMARY I PUMPED FRACTURE TREATMENT, SCREENED OUT WITH 6 PPG ON PERFS, 21400# IN FORMATON, 16,900# IN WELLBORE. I SMALL STRIP OF TREESAVER RUBBER LEFT IN HOLE. [Fra¢-Refrac] TIME LOG ENTRY 05:00 RIG UP DS FRAC EQUIP 07:30 PRIME UP, SET TREESAVER, PRESSURE TEST TO 11,000 PSI, GOOD TEST. 08:10 PUMP BREAKDOWN, 30 BPM, 40# XL GEL. GOOD BREAKDOWN SEEN. PERFORM SDT, XS FRIC = 845 PSI. ISlP = 2043 PSI, FG = .79. 08:30 PUMP SCOUR STAGE. 20 BPM, 40# XL GEL, I PPG SAND SCOUR. PERFORM SDT, XS FRIC = 536 PSI, ISIP = 1940 PSI, FG = .77. 08:50 PUMP DATAFRAC. 75 BBLS 40# XL GEL. ISIP = 2278 PSI. FG = .83. POSSIBLE MULTIPLE FRACTURES SEEN IN DATAFRAC. INCREASE PAD TO 150 BBL. 09:35 PUMP FRAC SLURRY STAGES. 40# GEL, 20 BPM, TREATING PRESSURE ~ 4000 PSI. SCREENED OUT WITH 6 PPG ON PERFS, 21400# BEHIND PIPE, 16900# IN WELLBORE. FLUSH EQUIPMENT, RIG DOWN. · 11:30 DOWELL RIGGED DOWN, WELL SECURE. SMALL STRIP OF TREESAVER RUBBER LEFT IN WELL. SERVICE COMPANY- SERVICE DAILY COST ACCUM TOTAL $0.00 $704.20 aPC $14,400.00 $39,700.00 ARCO $8,700.00 $12,292.00 DOWELL $130,026.00 $288,427.00 HALLIBURTON $0.00 $6,803.00 LITTLE RED $1,1 00.O0 $7,900.00 PEAK $0.00 $750.00 SCHLUMBERGER $0.00 $6,922.00 TOTAL FIELD ESTIMATE $154,226.00 $363,498.20 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X, 41' RKB 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360 Stratagrapic.__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 2538' FNL, 320' FWL, Sec 24, T12N, R8E, UM 3G-03 At top of productive interval: 9. Permit number/approval number: 2232' FNL, 1347' FEL, Sec 24, T12N, R8E, UM 96-122 At effective depth: 10. APl number: 2168' FNL, 1114' FEL, Sec 24, T12N, R8E, UM 50-103-20245-00 At total depth: 11. Field/Pool: 2155' FNL, 1063' FEL, Sec 24, T12N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7501 feet Plugs (measured) None true vertical 6145 feet Effective Deptt measured 7422 feet Junk (measured) None true vertical 6086 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 260 Sx AS I 121' 121' Surface 3490' 7-5/8" 720 Sx AS Ill & 3531' 3085' 330 Sx Class G Production 7450' 5,5 X 4,5" 153 Sx Class G 7488' 6135' Uner Perforation Depth ~ ~¢'~"~.~ ~-,, '- measured 7060'-7096~, 7160'-721 O' ~-%' TM true vedical 5815'-5843', 5891'-5929' ~\ '~" ' :''-,J ; Tubing (size, grade, and measured depth) ~%~,'- ~,' 3.5", 9.3 lb~fi, L-80 @ 6976' Packers and SSSV (type and measured depth) Packer: Baker GBH-22 Locator @ 6962'; SSSV: None, nipple @ 512' 13. Stimulation or cement squeeze summary Perforate 'C' sands on 9/1/99 Intervals treated (measured) 7060'-7080' Treatment description including volumes used and final pressure Perforated well w/2-1/8" EJ gun & BH charges @ 4 spt, final pressure was 400 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 473 283 495 1038 188 Pre gas-lifted rates Subsequent to operation 45 3 635 53 167 15. Atlachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil X Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ Title: Production Engineering Supervisor Date /0/Z~/~ Signed Form 10-404 Re,, 5/88 SUBMIT IN DUPLICAT.,~, ~ Alaska, Inc. WELL JOB SCOPE 3G-O3 FRACTURING. DATE 09/01/99 DAY 1 FIELD ESTI MATE DAILY WORK . PERFORATE OPERATION COMPLETE ] SUCCESSFUL ('~ Yes O NoI ~ Yes O No AFC# I CC# 999356 230 DS36G L $7,922 InitialTbg IFinalTbg IlnitiallA ' IFinallA! 400PSII 400PSII 1000PSI 1000PSI IDAILY COST KUPARUK RIVER UNIT · · LL SERVICE REPORT 3G-03(4-1 )) I JOB NUMBER 0829990657.3 UNIT NUMBER 2128 KEY PERSON SUPERVISOR SWS-ELMORE- i K,~,LICK/ .. ACCUM COST ' - ' Initial OA IFinal OA I~-lLSize 500PSII 500PSII 6,976." FT DAILY SUMMARY PERFORATED 7060'-7080', 4 SPF, BIG HOLE WITH 2 1/8" ENERJETS. I TIME LOG ENTRY 07:45 MIRU SWS 2128 ELMORE,TGSM,PT 3000#. 09:10 RIH W! GUN 1,20' 2 1/8" EJ GUN 2 SPF BIG HOLE - ORIENTED -90 DEG FROM LOW SIDE OF HOLE. 09:50 TIE-IN TO SHORT JOINTS. 10:05 LOG UP - PERF 7060'7080'- ORIENTED 90 DEG FLSH - POOH. 11:00 RIH W/GUN 2. 11:25 RETIE-IN TO SHORT JOINTS. 11:30 LOG UP AND SHOOT - GUN 2 ORIENTED +90 DEG FLSH, SHOOT SAME DEPTH AT 7060' - 7080' - POOH. 12:15 AT SURFACE WITH ALL SHOTS FIRED - BD, RD. 13:00 RDMO SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $8o.o0 APC $1,000.00 $1,000.00 HALLIBURTON $0.00 $669.00 LITTLE RED $0.00 $600.00 SCH LUMBERG ER $6,922.00 $6,922.00 TOTAL FIELB ESTIMATE $7,922.00 $9,271.00 PERMIT 96-122 96-122 AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS PROD- GAS L I FT PROD-SPIN/TEM/ ~ 7~~025-7240 L PRES 521-7280 Page: 1 Date: 07/21/98 RUN RECVD FINAL 12/18/97 FINAL 12/18/97 10-407 ZR/CYMPLETION DATE ~/~6/ DAILY WELL OPS R ?/2~ / TO ~/ l~/ Are dry ditch samples requmred? yes ~___~d received? Was the well cored? yes n__~Analysis & description received? Are well tests required? yes ~_~.~_~eceived? .~as___n~/~ Well is in compliance Initial COMMENTS // i / yes -no 1. Operations Performed: STATE OF ALASKA AL, ,,,KA OILAND GAS CONSERVATION COMMIb,.,,ON REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Qperator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 320' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 2232' FNL, 1347' FEL, Sec. 24, T12N, R8E, UM At effective depth 2168' FNL, 1114' FEL, Sec. 24, T12N, R8E, UM At total depth 2155' FNL, 1063' FEL, Sec. 24, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7501 6145 feet feet 6. Datum elevation (DF or KB) RKB 41 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-03 9. Permit number/approval number 96-122 10. APl number 5o-103-20245-00 11. Field/Pool feet Plugs (measured) Kuparuk River Field/Oil Pool None Effective depth: measured 7 4 2 2 true vertical 6086 feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 260 Sx AS I 720 Sx AS III & 330 Sx Class G 153 Sx Class G 80' 16" 3490' 7-5/8" 7450' 5.5 x 4.5" measured 7060'-7096',71 60'-7210' true vertical 581 6'-5843',5891 '-5929' Measured depth 121' 3531 ' 7488' True vertical depth 121' 3085' 6135' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 6976' & 4.5", 12.7#/ft., L-80 @ 6962'-7488' Packers and SSSV (type and measured depth) Packer: Baker GBH-22 Locator @ 6962'; SSSV: None, Nipple @ 512' 13. Stimulation or cement squeeze summary Perforate 'C' Sands on 10/25/97. Intervals treated (measured) 7O60'-7O76' Treatment description including volumes used and final pressure Perforate using 2-1/8" EJ guns w/ DP charges @ 4 spf, 0° phasing, fp was 1430 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2 6 4 95 243 820 169 Subsequent to operation 403 2 2 0 296 815 173 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 7. I her~,v~rtify that the foregoing is true and correct to the best of my knowledge. Signet /~'.~,~ Title Wells Superintendent ,, .! SUBMIT IN DUP~IC~ATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~' WELL SERVICE REPORT ~ ~' K1(3G-03(W4-6)) WELL JOB SCOPE JOB NUMBER 3G-03 PERFORATE, PERF SUPPORT 1 020972010.4 DATE DAILY WORK UNIT NUMBER 10/25/97 PERFORATE 7076'-7076'. SWS 8393 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR _ 1 (~) Yes O NoI ® Yes O No ELMORE BB..~n~~, FIELD AFC~ CC~ DAILY COST ACCUM COST ESTIMATE KAWWRK 230DS36GL $6,721 $8,960 Initial Tb.q Press Final Tbq Press initial Inner Ann Final Inner Ann I Initial Outer A~n ~ ~'Final Outer Ann 275 PSI 1430 PSI 700 PSI 700 PSII 400 PSI 400 PSI DAILY sUMMARY PERFORATE "O" SAND F/7060- 7076' ELM W/2-1/8" EJ DP @ 4 SPF & 0 DEG PHASING. TIME LOG ENTRY 07:00 08:45 MIRU SWS (ELMORE & CREW). TGSM. CALL FOR RADIO SILENCE. MU 2-1/8" GUN ASSEMBLY (VVT/CCL/MPD/16' 2-1/8" EJ DP @ 4 SPF & O DEG PHASED). TL-32'. PT BOPE TO 3000 PSI. SI WELL @ WING. RIH TO 7166' ELM. TIE INTO 8/29/97 SWS PERF RECORD. A~-FEMPT TO FIRE GUNS @ PERF DEPTHS OF 7060-7076' ELM. NO SURFACE INDICATION OF FIRING. POOH TO CHECK GUNS. AT SURFACE. 10:30 GUNS DID NOT FIRE. WIRE CAME LOOSE ON PRIMER CORD CONNECTION. REMAKE UP GUN. PT BOPE. 11:00 RIH TO 7166' ELM. TIE IN & PERFORATE F/7060 - 7076' ELM W/2-1/8" EJ DP, 4 SPF & O DEG PHASING. SAW GOOD SURFACE INDICATION. POOH. 12:15 AT SURFACE. ALL SHOTS FIRED. BEGIN RD & RELEASE RADIO SILENCE. 13:00 BRING WELL ON LINE @ WING. FINISH RD, TURN OVER TO PRODUCTION & MOVE TO 3R-18. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $336.00 APC $250.00 $250.00 HALLI BURTON $0.00 $1,023.00 LR-FLE RED $0.00 $880.00 SCHLUMBERGER $6,471.00 $6,471.00 TOTAL FIELD ESTIMATE $6,721.00 $8,960.00 1 2/1 0/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11632 Company: Alaska Oil & Gas Cons Comm Attn' Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 3F-5 ~ ~ - c~q ~ PRODUCTION PROFILE 971 1 2 4 I 1 3 F-1 0 .~-,-~ ~ ~"7 I PRODUCTION PROFILE 9 71 11 9 I 1 3 F-15 ~ .~ -- ~> ~ I ~ INJECTION PROFILE 971 01 4 I 1 3 G-03 ~ (-¢' - I ~ ~' PRODUCTION PROFILE 971 01 6 I 1 3G-03 ',J.~' PRODUCTION PROFILE 971 026 I 1 3H-01 '~.~ - I~ ~) PRODUCTION PROFILE W/DEFT 971 030 I 1 3 K-22 ~ ~7 - O L(~.~ ~ I ~ PRODUCTION PROFILE 9 71 1 2 6 I 1 3 K-23 ~ ~ - O4 ~ PRODUCTION PROFILE 971 1 27 I 1 30-20 C~.'?- (3c/~-- GAS LIFTSURVEY 971026 I 1 3Q-08A ~---(~ --- I~' ~ BRIDGE PLUG SETrlNG RECORD 971015 I 1 3R-18 <:~ ~. - (~l-~ GAS LIFT SURVEY 971025 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: STATE OF ALASKA ALAbr'U~, OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 320' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 2232' FNL, 1347' FFL, Sec. 24, T12N, At effective depth 2168' FNL, 1114' FEL, Sec. 24, T12N, At total depth 2155' FNL, 1063' FEL, Sec. 24, T12N, R8E, UM R8E, UM 12. Present well condition summary Total Depth: measured 7 5 true vertical 61 6. Datum elevation (DF or KB) RKB 41 feet 7. unit or Property name Kuparuk River Unit 8. Well number 3G-03 9. Permit number/approval number 96-122 10. APl number 50 - 103-20245-00 11. Field/Pool Kuparuk River Field/Oil Pool R8E, UM 01 feet 45 feet Plugs (measured) None Effective depth: measured 7 4 2 2 true vertical 6086 feet feet Junk (measured) None Casing Length Size Structural Conductor 8 0' I 6" Surface 34 9 0' 7 - 5 / 8" Intermediate Production 7450' 5.5 X 4.5" Liner Perforation depth: measured 7076'-7096', 71 60' - 7210' true vertical 5828'-5843', 5891'- 5929' Cemented Measured depth True vertical depth 260 Sx AS I 121 ' 121 ' 720 Sx AS III & 3531' 3085' 330 Sx Class G 153 Sx Class G 7488' 61 35' ORIGINAL Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 6976' & 4.5", 12.7#/ft., L-80 @ 6962'-7488' Packers and SSSV (type and measured depth) ..~ Packer: Baker GBH-22 Locator @ 6962'; SSSV: None, Nipple @ 512' 13. Stimulation or cement squeeze summary ~'~ .... ¢-. ~ "~ Perforate 'C' sand on 8/28/97. Intervals treated (measured) 7076'-7096' Treatment description including volumes used and final pressure Perforate using 2-1/8" EJ guns w/ DP charges @ 4 spf, 0° phasing, fp was 100q.,.~,s,i:.,;-~ · ,, ~'J~ ,, n,,~.-tfi~ 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5 1 5 3 2 0 190 800 187 Subsequent to operation 780 4 7 7 726 810 201 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby~rtify that the foregoing is true and correct to the best of my knowledge. Signed /~.~.~ ~ Title Wells Superintendent Form 10-49'~- R~v" 0~1~/88 ~ - - Date ,///~ SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~' WELL SERVICE REPORT '~ K1(3G-03(W4-6)) WELL JOB SCOPE JOB NUMBER 3G-03 PERFORATE, PERF SUPPORT 0822971 659.15 DATE DAILY WORK UNIT NUMBER 08/28/97 PERFORATE "C" SANDS F/7076 - 7096' ELM SWS-8293 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes O NoI (~) Yes O No SWS-ELMORE BLACK FIELD AFC_,ff CC,# DAILY COST AOOUM COST ESTIMATE KAWWRK 230DS36G L $1 0,41 8 $12,312 Initial Tbq Press Final Tbcl Press Initial Inner Ann Final Inner Ann I Initial Outer Ann ]Final Outer Ann 250 PSI 1 000 PSI 850 PSI 750 PSII 0 PSII 0 PSI DALLY SUMMARY PERFORATE F/7076- 7096' ELM W/2-1/8" EJ DP @ 4SPF, 0 DEG PHASING / ORIENTATION TIME LOG ENTRY 07:45 09:00 10:30 13:00 14:30 16:00 16:30 MIRU SWS 8393 (ELMORE & CREW). MU GUN ASSEMBLY (1-11/16" WT/CCL/MPD/20'-2-1/8" EJ DP @ 4 SPF, O DEG PHASING/ORIENTATION) TL-25.7'. TGSM. PT 3000#. SI WELL. RIH W/GUN ASSEMBLY TO 7180' ELM. TIE IN TO 9/24/96 SWS PERF RECORD. RUN JEWELRY LOG F/7180-6900' ELM. LOG UP & ATTEMPT TO PERFORATE F/7076-7096' ELM. GUNS WOULD NOT FIRE. CHECKED FOR SURFACE PROBLEMS. POOH TO CHECK DOWNHOLE CONNECTIONS. AT SURFACE. CHECKED ALL COMPONENTS ON GUN & REPLACED BLASTING CAP. PT & RIH TO 7180' ELM.' TIE IN AS BEFORE. A'I-I'EMPT TO PERFORATE. GUNS WOULD NOT FIRE. POOH. AT SURFACE. TEAR DOWN ALL GUN CONNECTIONS. FOUND FAULTY CONNECTOR TO BLASTING CAP. WIRED DIRECTLY TO BLASTING CAP. PT. RIH AS BEFORE. TIE IN & PERFORATE F/7076-7096' ELM W/2-1/8" EJ DP @ 4 SPF, O DEG PHASING / ORIENTATION. SAW GOOD INDICATIONS AT SURFACE. POOH. AT SURFACE. ALL SHOTS FIRED. BEGIN RD. RD COMPLETE. OFF LOCATION. LEAVE SI W/PILOTS GAGGED. TURN OVER TO PRODUCTION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $168.00 APC $300.00 $300.00 HALLIBURTON $0.00 $846.00 LIq-I'LE RED $0.00 $880.00 SCHLUMBERGER $10,118.00 $10,118.00 TOTAL FIELD ESTIMATE $1 0,418.00 $1 2,31 2.00 STATE OF ALASKA ALAor~,,A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown m pUll tubing Alter casing Stimulate X Plugging Perforate Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538" FNL, 320' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 2232' FNL, 1347' FEL, Sec. 24, T12N, R8E, UM At effective depth 2168' FNL, 1114' FEL, Sec. 24, T12N, R8E, UM At total depth 2155' FNL, 1063' FEL, Sec. 24, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7501 6145 6. Datum elevation (DF or KB) RKB 41 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-03 9. Permit number/approval number 96-122 10. APl number 50 - 103-20245-00 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet feet Effective depth: measured 7 4 2 2 true vertical 6086 feet Junk (measured) None feet 13. 14. Casing Length Size Structural Conductor 8 0' 1 6" Surface 3 4 9 0' 7 - 5 / 8" Intermediate Production 7450' 5.5 x 4.5" Liner Perforation depth: measured 7160' 7210' true vertical 5891' - 5929' Cemented Measured depth True vertical depth 260 Sx AS I 121 ' 121 ' 720 Sx AS III & 3531' 3085' 330 Sx Class G 153 Sx Class G 7488' 61 35' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 6976' & 4.5", 12.7#/ft., L-80 @ 6962'-7488' Packers and SSSV (type and measured depth) :i'~.~ Packer: Baker GBH-22 Locator @ 6962'; SSSV: None, Nipple @ 512' Stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 5/28/97. '' Intervals treated (measured) 71 60' - 7210' Treatment description including volumes used and final pressure Pumped 127 Mlbs of 20/40,12/18, & 10/14 of ceramic proppant into formation, fp was 8100 psi Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5 1 5 320 190 795 187 Subsequent to operation 780 477 776 810 201 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. Form,~,404' I~e¢ 06¢I'5/1¢~- ~' I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent Date /~,~ ~ "~_ ,~ ,,~ SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~, WELL SERVICE REPORT ~ K1(3G-03(W4-6)) WELL JOB SCOPE JOB NUMBER 3G-03 FRAC, FRAC SUPPORT 0521 971853.10 DATE DAILY WORK UNIT NUMBER 05/28/97 "A" SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~ Yes O NoI ® Yes O No CHANEY FIELD AFC~ CC# DALLY COST ACCUM COST Sigh'ecl' , ,~ ,/" ESTIMATE KDl137 230DS36GL $97,883 $104,102 ~,.,, , {~., ~'? Initial Tbcl Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 540 PSI 1 500 PSI 380 PSI 500 PSII 250 PSII ~00 PSI DAILY SUMMARY "A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 126953 LBS OF PROP W/12.8# PPA OF #10/14 @ THE PERF'S. FREEZE PROTECTED TBG DOWN TO 4900' RKB W/43 BBLS OF DIESEL. MAXIMUM PRESSURE 8100 PSI & F.G. @ (.77) TIME LOG ENTRY 06:00 MIRU DOWELL FRAC EQUIP, APC VAC TRK, AND LRS HOT OIL TRK. HELD SAFETY MEETING (15 ON LOCATIONI. 08:00 PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG AS REQUIRED. PT'D HIGH PRESSURE LINES AND EQUIP TO 10000 PSI. 08:15 09:15 10:25 PUMP BREAKDOWN W/50# DELAYED XL GW @ 25 TO 15 BPM. VOLUME PUMPED 355 BBLS. USED 6105 LBS OF #20/40 PROP FOR SCOUR. MAXIMUM PRESSURE 8100 PSI AND ENDING PRESSURE 2800 PSI. S/D AND OBTAINED ISlP OF 1880 PSI W/ F.G. @ (.76). STOOD-BY AND MONITORED WHTP, PULSED FOR CLOSURE. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 174 BBLS. MAXIMUM PRESSURE 4900 PSI AND ENDING PRESSURE 3800 PSI. S/D AND OBTAINED ISlP OF 2018 PSI W/F.G. @ (.78). STOOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. COMPLETED THRU FLUSH. PUMPED 128603 LBS. INJECTED 126953 LBS OF PROP (9700 LBS OF #20/40, 109300 LBS OF #12/18, & 9603 LBS OF #10/14) W/12.8# PPA OF #10/14 @ THE PERF'S. LEFT 1650 LBS OF PROP IN THE WELLBORE. ESTIMATE TOP OF FILL @ 6979' RKB. FREEZE PROTECTED TBG DOWN TO 4900' RKB W/43 BBLS OF DIESEL. VOLUME PUMPED 860 BBLS. MAXIMUM AND ENDING PRESSURE 6400 PSI. S/D. 11:30 STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS HOT OIL TRK. 12:15 13:00 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. R/D COMPLETE AND DOWELL LEAVING LOCATION. WELL SECURED AND DSO NOTIFIED OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACbUM TOTAL $0.00 $693.00 APC $5,400.00 $5,700.00 DIESEL $400.00 $400.00 DOWELL $90,543.00 $90,543.00 HALLIBURTON $0.00 $3,246.00 LI'I-I'LE RED $1,540.00 $3,520.00 TOTAL FIELD ESTIMATE $97,883.00 $1 04,102.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 320' FWL, Sec. 24, T12N, At top of productive interval 2232' FNL, 1347' FEL, Sec. 24, T12N, At effective depth 2168' FNL, 1114' FEL, Sec. 24, T12N, At total depth 2155' FNL, 1063' FEL, Sec. 24, T12N, 12. Present well condition summary Total Depth: measured 7 5 true vertical 61 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service R8E, UM R8E, UM R8E, UM 6. Datum elevation (DF or KB) RKB 41 7. unit or Property name Kuparuk River Unit 8. Well number 3G-03 9. Permit number/approval number 96-122 10. APl number 50-103-20245-00 11. Field/Pool Kuparuk River Field/Oil Pool R8E, UM 01 feet 45 feet Plugs (measured) None feet Effective depth: measured 7422 true vertical 6 0 8 6 feet Junk (measured) None feet 13. 14. Casing Length Size Structural Conductor 8 0' 1 6" Surface 34 9 0' 7 - 5 / 8" Intermediate Production 7450' 5.5 X 4.5" Liner Perforation depth:, measured 7160'- 7210' true vertical 5891' - 5929' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 6976' & 4.5", Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth 260 Sx AS I 121 ' 1 21 ' 720 Sx AS III & 3531' 3085' 330 Sx Class G 153 Sx Class G 7488' 61 35' ORIGINAL 12.7#/ft., L-80 @ 6962'-7488' Packer: Baker GBH-22 Locater @ 6962'; SSSV: None-, Nipple @ 512' Stimulation or cement squeeze summary ' ....... . . ,... Fracture Stimulate 'A' Sands on 10/4/96 Intervals treated (measured) 71 60' - 7210' Treatment description including volumes used and final pressure Pumped 97 MIbs of 20/40,12/18, & 10/14 of ceramic proppant into formation, fp was 5250 psi Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 4 1 5 385 39 825 228 Subsequent to operation 1202 1 6 5 1 168 846 180 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 7. I hereb~/d'~ify that the foregoing is true and correct to the best of my knowledge. Signed ~/~,~./' Title Wells Superintendent Form 10-,~4~ ,i~'e~'- ~6/1~/~8'''~ SUBMIT IN DUPLICATE AR(~O Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 6, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3G-03 (Permit No. 96-122) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3G-03. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad .... STATE OF ALASKA ALASKa, OIL AND GAS CONSERVATION C.. MMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG "1. status of Well ..................... Classification of ServiCe Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-122 31 Address ' ' '8. APINur~ber P.O. Box 100360, Anchorage, Alaska, 99510-0360 50-103-20245 ........................... 4. Location of well at surface ; i.:~LhViP,.,-_',!d~-;! i i'-~,~,;:z ,:?~;:i'; 9. Unit or Lease Name 2538' F NL, 320' F WL, Sec. 24, T12N, R GE, ,M ;,--:~'¢~,: K uparuk River Unit At top of productive inte~al. ¢~ ~~::' 'L: ,r . ,- '.' , 10. Well Number " ~;: ~'"'"'~'{~ ..j Fie'Id 3G-03 2232' FNL, 1347' FEL, Sec. 24, T12N, PGE, UM · ........ ~ ';-~.f i i¥ and pooi At total depth 2155' FNL, 1063' FEL, Sec. 24, T12N, PGE, UM ... Kuparuk River 5: EleVation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. L Rig RKB 41' Pad 54'~ ADL 25547 ALK 2561 ~12. Date Spudded ~13. Date T.D. Reached } 14. Dat~ Comp., Susp., or Aband.115."Water depth, if offshore ~16. No. of Completions ~ 7/30/96 i 8/3/96 I 8/29/96 I N/A MSLI One '17. Total Depth (MD+TV~) ~i8. Plug Back Depth (MD+TVD)~19. Dir~cti°~al SU~veyl20. DePth Where SSSV set~l. ThiCkness of Permafrosl : 7501 6145 F~ 7422 6086 F~ ~Yes ~No I N/A MD[ 1380' (Approx.) 22. Type Electric or Other Logs Run ARC5/GR, GR/CCUSLTJ 23. CASING, LINER AND CEMENTING RECORD ........ CASING sE~ING DEPTH ' HoLE __S_~E .... ~. BEn FT. G~DE -- ~-~ [--~O~-M SIZE CEMENTING RECORD AMOU~ PULLED 16" 62.5¢ H-40 SURF. 121' 24" 260 sx ASl 7.625" 29.7¢ L-80 SURF. 3531' 9.8~5" 720 sx AS III, 330 sx Class G 5.5"x4.5" ~-7~/1-2:75~ ........ E:8~ ........ [---SU-~F~---~ ..... ?-4~-~-'----,'----~77~-~ .... i-~--~-X---O-I-~'~-~ ...................................... I ....... ............................................... 24. Perforations open to Production (MD+TVD of Top and Bottom ~25. TUBING RECORD and interval, size and number) s,z. I 2 spf 3.5~92.875- --j' ....... -69-76~ .............................. MD TVD MD TVD 7160'-7180' 5891 '-5906' - .................................... 7180'-7210' 5906'-5929' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. , ,, DEP~ I~ERVAL (MD) AMOUNT & K~ND OF MATERIAL USED ............ 7160'-7210' :97000¢ behind pipe w/12.5 ppa 10/14 at peff .... .. - .......................... 2000¢ proppant left in pipe. ......... ~7. ' ...... pRoDucTioN TEST ' ' Date First Production" ~Method of Operat~'~ (Fl~wing, gas lift, et°~) .... 9/7/96 i Gas Lift Date of Test jHours Teste~'- P~d~'CTIO~F~ [OIL-BBL - GAS-MCF -' W~{~-AT~- ......... ~-~-~'~i~-~ ....... ~-~-~;~--~-~ .............. 10/18/96 j 17.8 TEST PERIOD ' I 1242 1597 78 : 1 76 I 1 884 'Press... 18~. 11 _4-HouR ~ ............ RATE ~. o . 50 , 1 674 21 52 1 05 =24 28. CORE DATA Brief description ~ lithology, p~osity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~'-~ ~..- ,:, ..= .. ,~ ,. ,~., - ... ,. ! ..................... Form 10-407 Rev. 07-01-80 Submit In Duplicate , ' Geologic Marl,~' 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 Kuparuk C 7060' 5816' Total pump volumes: Bottom Kuparuk C 7100' 5846' Category 1. 6373 Top Kuparuk A 7139' 5876' Category 2. 100 Bottom Kuparuk A 7292' · 5990' Category 3. 0 Total for this time period: 6473 Total to Date: 6473 FREEZE PROTECTED WITH DIESEL 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I herebyk-e~ify~tr~foregoing is true and correct to the best of my knowledge ........ S ig_~_ed ~:~_ ~ ........... Title '~('~.L(-_.~. __~G.~,....N~.._~ ....... .D_..a.!__e 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' 8/6/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:3G-03 RIG:PARKER WELL ID: AK8597 AFC: AK8597 TYPE: -- STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD: START COMP: BLOCK' FINAL: WI: 55% SECURITY:0 AFC EST/UL:$ OM/ OM API NUMBER: 50-103-20245-00 7/29/96 (1) PBTD: 121(0) SUPV:RLM DAILY' MW: PV/YP: APIWL: DRILLING @ 547' Move rig 301' from 3G-25 to 3G-03. Accept rig at 22:30 hfs 7/29/96. Nipple up diverter. $34,927 CUM: $34,927 ETD: $0 EFC:$34,927 7/30/96 (2) MW: 10.0 PV/YP: 27/39 APIWL: 7.2 PBTD: 3540(3419) CIRC FOR CASING SUPV:RLM Spud at 03:21 hrs. 7/30/96. Directional drill from 121' to 2777' Hole packed off. Regain circulation and circulate hole clean. Directional drill from 2777' to 3540' DAILY: $91,153 CUM: $126,080 ETD: $0 EFC:$126,080 7/31/96 (3) PBTD: 3540(0) SUPV:RLM DAILY- MW: 10.2 PV/YP: 26/26 APIWL: 6.2 CHANGE HYDRIL CAP SEAL Pumped 50 bbl, 200+ viscosity sweep. Wipe hole. Pulled to 2480' last 2 stands pulled tight. Back ream out to 2304'. Hole packed off. Regain circ. Circulate clean. Large amounts of sand and clay. Continue to back ream and circ. RIH to 3540', no fill. Pump 70 bbl, 200+ viscosity sweep. POOH, work through tight hole 1700-1600'. Pull to 1380' tight and swabbing. Circulate hole clean. POOH, no further problems. Ran 7-5/8" casing to 3531' Cement casing. CIP at 2202 hrs. 7/30/96. $179,741 CUM: $305,821 ETD: $0 EFC:$305,821 8/1/96 (4) PBTD: 4204(664) SUPV:RLM DAILY' MW: 10.2 PV/YP: 5/5 APIWL: 16.8 DRILLING @ 4900' Nipple up 13-5/8" BOPE. Test all lines to 300/3000 psi. Drill cement to 3422'. Test casing to 2000 psi for 30 min. Drill cement, float shoe, cement, float collar and 10' new hole to 3550'. Perform leak off to 14.4 ppg EMW. Drill to 4204' $78,439 CUM: $384,260 ETD: $0 EFC:$384,260 8/2/96 (5) MW: 9.9 PV/YP: 12/8 APIWL: 5.2 PBTD: 6243(2039) DRILLING @ 6700' SUPV:RLM Directional drill 6.75" hole from 4204' to 6243' DAILY: $106,454 CUM: $490,714 ETD: $0 EFC:$490,714 8/3/96 (6) PBTD' 7501( 1258) SUPV-RLM MW: 11.6 PV/YP: 25/25 APIWL: 3.8 POH T/RUN CASING RIH, ream 90' to bottom, no fill. Directional drill 6.75" hole from 6243' to 7044' Had connection gas while drilling at 7044'. Shut down pump and work pipe. CBU. Flow increase. Weight up to 11.6 ppg. Work pipe. CBU. no flow increase. Directional drill 6.75" hole from 7044' to 7501' DAILY: 8/4/96 (7) PBTD: 7501(0) SUPV:RLM DAILY: 8/5/96 (8) PBTD: 7501(0) SUPV:RLM DAILY: $95,079 CUM: $585,793 ETD' $0 EFC'$585,793 MW: 11.6 PV/YP: 26/22 APIWL: 4.4 NIPPLE UP STACK Held pre-job safety meeting. Run 4.5" and 5.5" casing to 7488'. Cement casing. CIP at 2356 hrs. $156,684 CUM: $742,477 ETD: $0 EFC:$742,477 MW: 8.5 PV/YP: APIWL: RIG RELEASED Monitor well, flowed back 40 bbls mud after cement job. Run 3.5" completion. Pressure test 4.5"x5.5" casing to 3000 psi for 30 minutes. No bleed off. Freeze protect well. Rig release at 0600 hrs. 8/6/96. $127,208 CUM: $869,685 ETD: $0 EFC:$869,685 KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(3G-03(W4-6)) 3G-03 DATE 09/26/96 DAY 10 JOB SCOPE JOB NUMBER FRAC, FRAC SUPPORT 0825961726.1 UN1T NUMBER DAILY WORK RE-PERF "A" SAND OPERATION COMPLETE ] SUCCESSFULYES YES I Initial Tbg Press [ Final Tbg Press ! Initial Inner Ann 1120 PSI 1140 PSI 800 PSI KEY PERSON SUPERVISOR SWS-BAILEY CHANEY/BLACK Final Inner Ann 800 PSI Initial Outer Ann I I 300 PSI Final Outer Ann 300 PSI DAILY SUMMARY RE PERF "A" SAND 7160 - 7180 W/2-1/8" DEEP PENETRATING ENERJETS, 2 JSPF @ +90 DEG FROM LOW SIDE AND 2 JSPF @ -90 DEG I FROM LOW SIDE. 4 JSPF TOTAL TIME LOG ENTRY 14:00 MIRU SWS E-LINE UNIT CONDUCT SAFETY MEETING & PRESSURE TEST LINES. 16:00 RIH W/CCL, MPD & 20' 2-1/8" ENERJETS DEEP PENETRATING CHGS, 2 JSPF +90 DEG FROM LOW SIDE. TIED INTO INITIAL PERFS F/7180-7210 & SHORT JT @ 7108. FIRED GUN, POH. 17:30 OOH, ALL SHOTS FIRED. M/U GUN RUN #2. PRESSURE TEST LINES, LUB AND BOPE TO 31300 PSI. RIH W/GUN RUN #2, 2 JSPF - 90 DEG FROM LOW SIDE. 19: 30 OOH, ALL SHOTS FIRED. RD SWS E-LINE UN1T. 20:30 WELL SECURE AND EVERYBODY OFF LOCATION KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(3G-03(W4-6)) WELL JOB SCOPE JOB NUMBER 3G-03 FRAC, FRAC SUPPORT 0825961726.1 UN1T NUMBER DATE 08/29/96 DAY 2 DAILY DAILY WORK PERFORATE A SAND OPERATION COMPLETE ] SUCCESSFUL YES YES Initial Tbg Press 800 PSI SUMMARY KEY PERSON SWS-SCHWARTZ SUPERVISOR ELLIS Final Tbg Press ] Initial Inner Ann 800 PSI[ 100 PSI Final Inner Ann [ I 100 PSI Initial Outer Ann ] 300 PSI I Final Outer Ann 300 PSI PERF'D THE A SAND FROM 7160 - 7180' (20') W/4 JSPF BIG HOLE CHARGES USING A 2-1/8" ENERJET. SHOTS ORIENTED 90 DEGREES [ CW & 90 DEGREES CCW FROM LOW SIDE. TIME 14:00 14:30 15:00 15:15 16:00 16:15 17:00 17:45 19:00 19:30 LOG ENTRY MIRU SWS E-LINE UNIT. TGSM JOB PLAN & FUSIBLE. MU 2-1/8" ENERJET GUNS (20') & CCL. PRESSURE TESTED LUBRICATOR TO 3000 PSI. RIH W/PERF GUNS. PERF'D THE A SAND FROM 7160-7180' (20') W/2 JSPF BIG HOLE CHARGES ORIENTED 90 CW FROM THE LOW SIDE OF THE HOLE USING A 2-1/8" ENERJET. STIP 800 PSI PRIOR TO SHOOTING. S1TP AFTER SHOOTING 800 PSI. POH W/PERF GUNS. ALL SHOTS FIRED. RIH W/PERF GUNS. PERF'D THE A SAND FROM 7160-7180' (20') W/2 JSPF BIG HOLE CHARGES ORIENTED 90 CCW FROM THE LOW SIDE OF THE HOLE USING A 2-1/8" ENERJET. STIP 800 PSI PRIOR TO SHOOTING. SITP AFTER SHOOTING 800 PSI. POH W/PERF GUNS. ALL SHOTS FIRED. RD SWSE-LINE KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(3G-03(W4-6)) WI~ I. JOB SCOPE 3G-03 PERFORATE, PERF SUPPORT DATE 08/24/96 DAY 1 DAILY DAILY WORK INITIAL 'A' SAND PERFS OPERATION COMPLETE [SUCCESSFUL YES YES lmitial Tbg Press [ Final Tbg Press [ Initial Inner Ann 0 PSI 1000 PSI 0 PSI SUMMARY KEY PERSON SWS-SCHWARTZ Final Inner Ann I 500 PSI I JOB NUMBER 0823961956.8 UNIT NUMBER SUPERVISOR PENROSE Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI DEG FROM LOW SIDE (TOTAL OF 4 JSPF). SHOT WITH 175 PSI UNDERBALANCE. PERFORATED INTERVAL 7,180' - 7,210' (30') W/2-1/8" 'BIG HOLE' ENERJETS, 2 JSPF @ +90 DEG FROM LOW SIDE AND 2 JSPF @ -90 TIME 19:30 20:30 21:05 21:35 21:50 22:10 22:45 23:55 00:30 01:10 LOG ENTRY MIRU SWS E-LINE EQUIP AND LRS PUMPING EQUIP. HOLD PRE-JOB SAFETY MEETING, M/U GUNS ON WL, PRESSURE TEST LINES, LUB AND BOPE TO 3,500 PSI. RIH W/GUN RUN #1. PRESSURE TEST BACKSIDE TO 2,500 PSI FOR 15 MINUTES WHILE RUNNING GUNS IN HOLE. BLEED BACK TO 500 PSI. LOG 7,360' TO 7,850'. PRESSURE TUBING TO 800 PSI TO YIELD 175 PSI UNDERBALANCE FOR PERFORATING. TIE IN, FIRE GUN (2-1/8" 'BIG HOLE' ENERJETS, 2 JSPF @ +90 DEG F! LOW SIDE OF HOLE). BLEED OFF TUBING PRESSURE, POH. OOH, ALL SHOTS FIRED. M/U GUN RUN #2. PRESSURE TEST LINES, LUB AND BOPE TO 3,500 PSI. RIH W/GUN RUN #2. TIE IN, FIRE GUN (2-1/8" 'BIG HOLE' ENERJETS, 2 JSPF @ -90 DEG F/LOW SIDE OF HOLE), POH. OOH, ALL SHOTS FIRED. RDMO SWS AND LRS. 02:00 WELL SECURE AND EVERYBODY OFF LOCATION. 4~ -~ -:'l 'l? ? T API~ 50-i03-202~5-(:0 COMPANY ARCO ALASEA~ WELL NAME 3G-03 LOCATION i EUPARU~ LOCATION 2 ALASKA bu:~v~:~ ANGL~ 0.00 TIE IN POINT(TiP) : M~ASu~uunr~n ~zz~O0 TRUE U~RT 3~F'TH 121~wnn AZimUTH 0,00 D[PAR?UR] ....... ~ u,,~u~' "": 0,00 0,00 i,5A. . 0,76 37,~.j i ,71 4,33 2+i3 13i ,49 - ~4,~, 7~57 4,17 ~2~.''~ -9 ~ -57 44,5~ :'v,?4 :LS degi iOOft 3.00 0.42 2,01 :,24 928.16 1020,22 9~ 3 9~6 60 ,~! ,~ , i01a,48 !104,61 1191,21 35,37 !4,40 132,23 -30,91 == ^~ i2 120 80.44 19.80 114,v~ 22,''''171 15,81 28,91 48,72 74,28 127,55 129,38 128,12 !24,98 2,18 4,81 4,22 5.39 2,94 i385.~^ 1566,37 ~659~~ 89.2 ,~'~".76 ?2,5 1360,58 ?0.8 !443, ~yc 90.3 1525.76 9~,2.~ 1608.'~ 108,94 21,23 ~' - 23,97 . . ~/ -~ ,/: 214.82 26.06 93.~oo -~.93~.~ ~ ^ ~.~ ~=8,~4 27,&O ~I,~'~ ~87,71 167.05 £37.i8 279 O~ · 121.50 117,72 i14,29 111,22 108.32 3,53 2,70 i751,13 ~4~,34 ~°°A O0 2488,80 91.6 z686.53 91.2 1762.04 93,7 i836.27 275.2 2048,34 277,7 2264.74 o05.z~ o8.i? -. 356.43 35,58 85,89 -84,76 ~,3.w 39,49 ~5,73 -80,58 ~o.o. 39,69 ~7 15 %9,69 .~ -~ ~' 90 86.05 -59,40 /,.~,/0 Ol , 363,36 420,25 595,25 768,89 ~24.28 373,1! 427.?i 599,32 771.18 105,64 103,13 100.85 96,68 94,42 3.79 3.48 4,18 0.34 0.69 3655,62 273.5 ~"~ ~o.,72 277.'7 2699.05 275.8 2913.42 14i.6 3025.96 i98.0 3184,64 929.i~. 37.08 8~.61. -45."',:~ 'ii02,29 40.03 o/ "=. 47-34.^" u~ 1275."~ /o 37.?5 &6.25 -24.58 1~oI.77~' 36.83 88."~, -19. 10 1480,20 36.65 84.91 -10,18 934.76 1!07.50 1280.75 !484.66 935 1108 1280 i484 ,02 ,70 92.8I 91,76 91.i0 90.80 ?0,39 0.44 i.24 0.80 0.80 0.47 3842,49 4ii6.53 4394,84 419~.09 186.9 3335.77 274.0 3551.76 277.9 3764.33 277.6 3980.37 279.2 4195.07 l]¥~,vv 35,-v~= 82,~.~ 1,82 1758.14 40.53 ~1.61._ =J,~ 16 1936.89 39.68 84.46 46,91 2110.*~ 69.76 ~ 38.1& 80,~ 2289.08 41.34 85.43 9!.49 !593,89 i~o0.79 1938.45 ~I£1,30 4 ! i7o0,97 1939,02 2112,"-5 2290,18 89,93 89,18 88.61 88,11 87,71 1.00 1 0.73 1.07 1.62 5228.83 6066.05 ...-- .4 ,% 277.5 4405.41 278.0 4616.99 279,3 5045.00 182,4 5188.27 2469.'¢I ~^ .~.13 81.42 112.1o 2850.06 40.81 88.04 128.59 ~ 7' ~^ i33.33 coo3..o 41,32 89,~v ~^" ' 36 150 ~,2/ ,85 Z?~O? 3121,11 39,60 ~',60,/ 173.64 2.547.61 283!.44 300~,~5 44 7 1470.73 2650,74 2834,58 3009.93 ~IcI,48 87.40 87.22 87.30 87.13 86.81 1.04 i.56 0.29 2.75 1.59 8435 ~ ~619.29 ,5892,91 186.9 5333,04 :84.0 5476.68 ~/o.0 5688.77 277,3 5899.11 24t,3 6078,75 · ~.,:,_,:, :~. 38,8.7 / ,:',., 60 200, -~^ :'~,"~ -~.:'~ .4 ? ? ,4 -'~. '~"~."* · .Jo ,*t/ .-' ~, 3£ ~:.~o ,,~o 7£ 3520,v7"'" 39,90 73,7";.' _.97F,3.5.. '::A'-~ ~ .............. ' 326--, ..:-,5%.,95 ~:,""' 33 7'..>,6i 368,i0 3350,94 ~. - oj~O.iv ~697.42 3856.12 86.46 86.08 85,50 84.94 84.52 0.52 0.8i 0.54 0.56 0.54 ..... deg/ .:.o~6.;u 3915.66 84,39 0,03 ARCO Alaska, Inc. Ii i ...... Phone: FAX #: Phone #: _Kuparuk Drill Site Devel°pment P, O. BOX 100360 ANCHORAGE. AK 9951_00-0360 ~sz'_~." "',- .. · . ,).. - ', °z .... ~'. ..,, m m __ mm _ ~ - - ' ': '" ':-""<'; :'~' :" :1 .':comments: zdrO~:~ -~¢- ~.~--',-C)~:.~. ~-\;~-:~ v--se_ ~,~-'-':~'~':"" · ~,~,~L,~-._ _ ¢,~.: .~.. ~¢~~,s :~ *o[%.1~ "' ":~':'" ~ ~:~:~-~,._.-_~;, c.,~L¢' '~;~ ~;_ ~q. a&,,, ....... - ...... ARCO Alaska, Inc .... Post Office ~ Anchorage, A,,.,~ka 99510-0360 Telephor~e 907 276 1215 August 1, 1996 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subiect:. Annular Pumping Approval for KRU Well 3G-03 Dear Mr. Jolmston: Kuparuk River Unit Well 3G-03 was permitted to drill on ~uly 10, 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 3G-03 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 descn'bed 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 AR30-6003.93 2,~2-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATICN COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type DJ' R;quest: Abandon Suspend Operation Shutdown Re-enter suspended well Alter casing _ Repair well - Change approved -program _ Plugging _ Pull tubing_ Tirn~ extension Stimulate - Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Loca'~n of well at surface 5. Type o! Well: Development Exploratory Stratigraphic Service 2538' FNL, 320' FWL, Sec. 24, T12N, R8E, UM At top o! productive interval 2285' FNL, 1407' FEL, Sec, 24, T12N, RSE, UM (planned) -- At effective depth At total depth 2261' FNL~ 1137' FEL~._S,.ec. 24, T12N~ RSEr UM {planned) t2. Present well condition summaq/ Total Depth: measured 3640' feet Plugs None true vertical 6. Datum elevation (DF or KB) Ria RKB 41' Pad level 55' rest 7, Unit or Property name Kuparuk River Unit 8. Well number 3G-03 g. Permit number 96-122 10. APl number so-1 03-20245 11. Reid/Pool Kuparuk River Field Kuparuk River Oil Pool 3092' feet (Note: preparing to drill out at present time) Effective depth: C~s~ng Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 3442' feet Junk None true vertical 3018' l~eet Length Size Cemented 8 0' 1 6" 250 Sx AS I 3490' 7-5/8" 720 sx AS II1 & 330 sx Class G measured None true vertical Measured depth True vertical deplh 121' 121' 3531' 3085' 113, Tubing (size, grade, and measured depth N(me Packers and SSSV (type and measured depth) None ^ttachmeriis Description euromart/of proposal X Detailed operation program sketch 14. Estimate;:l data Ior commencing operation 8/5/96 Oil X Gas _ .16, If proposal was verbally approved Name of approver Date approved $ ervic e 7. q,,hereby eertify,,that the foregoing is true and correct to the best of my knowledge. i,~ne~'~~ L ~A,~ ~.Tit, e Drill Site Dev. Supv. ' ~} - k.../ ' FOR COMMISSION USEONLY' Condition.~ Of approval: N6tity Comr~J~,i~)n so representative rr~y Witness 15. '~L~tus o['well--~lassifica~n- as: Suspended _ Plug integrRy __ gOP Test Location clearance Mechanical Integrity Test Subsequent form require 10- t~O"7 Approved by lhe order, of lhe Commission ()riginnl Rioned By Commissioner Form 10-403 Rev o6/15/88 David W. Johnston ApprOved CeO¥ Returned IAoproval No. ' , /5' SUBMIT IN TRIPLICATE KRU 3G-03 Annular Pumping Permit Application Additional Information Please see the attached "Cementing Details" form for Well 3G-03 for basic details on the cementing operation. Additional information is offered below ir~ 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 ~o regulation (AAC 25.030). Surface Hole TD: 3540' MD / 3092'TVD Surface Hole Conditions: The well briefly packed off while drilling in the surface hole at 2777' MD. Tight spots and packing off were seen throughout the wellbore during the wiper trip at TI3, and all circulations saw large amounts of sand and clay returns. Casing was run to bottom without problems, with circulation occurring at 1160', 2127', and 2809' due to fight hole conditions. No fill was seen on bottom. All circulation while drilling and runn~g casing saw full returns when not packing off. Casing Placement: The fluted hanger was landed as planned. The surface casing shoe was placed at 3531' MD, 9' 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 (12 bpm) and during the cemenfia~g operation itself (9 bpm). 5 bbls of 12.1 ppg cement were seen at surface. Excess on the lead cement was 150% (1.5 times the calculated gauge hole volume) and 30% on the tail cement. These excess factors are based on historical data and are calculated with the intent of bringing cement to surface during the primary job. Based on the data, there should be an adequate seal for safe annular pumping operations. Diagnostic Logs: None. ARCO Alaska, Inc '~y, ...... ij.~,,,,,,,L ........... ,....... ,. ,........,,. I~ Il I II s1 m FACSIMILE = ::::: :: :' TR AN S M 1_8_8_[O_ N = :: ....... _ ~ mnI II II It .... ~ ii I ii ii · ..... I I ii ~ il i['"'"" .... tl II II II -~+ ! ......... Cumber of Pages (Cover +): _ _ Kuparuk Drill Site Development P, O. BOX 100360 ANCHORAGE. AK 98510-0,350 _,, ~?_~.':____ "_-' ._ ARCO Alaska, Inc. Well#: 3G-03 Field: KUPARUK Casing Size 7 5/8' Centralizers Mud Spacer Lead Cement Tail Cement Displacement Hole Diameter 9 7/8" Hole Angle I Shoe Depth 42~ .[ 3530,66' Cementin~t Details r....~3 ~-e:-- [ 7/31/96 Float Depth % washout 3,442' State type usedr intervals covered and spacing 18 Gemco centralizers. 2 Gemeco Stop Collars. YP(prior cond) 36 lbs/lOO ft2 Gels after 9/19 W. eight 10.1/10.1 Gels before 1 1/31 YP(after cond) IPV(prior cond) ?.6 lbs/100 ft21 28 cP Total Volume Circulated 922 bbls at 12 bpm 1 Volume 40 No. of sacks I Weight 720! 12.1 Type Water Type IMix wtr temp AS 3 I 50 Additives .25 #/sk D29 Type ]Mix water tempi No. of sacks Weight G I 5OI 330 15.8 Additives G ~ 0.25 #/sk D29~ 0,2% D46~ Rate(before tail at shoe) 8.@ bpm Reciprocation length 15' 0.3% D65, 1% $1 Rate(tail around shoe) 8.9 bpm Reciprocation speed 10 fpm Actual Displacement 160.2 Bumpedno plug [Floats held yes Theoretic al Displacement 158.2 lCIP 7/31/96 2202 hfs Calculated top of cement surface Remarks: Include whether full returns were obtained, reclprocatlon throughout operation and any other pertinent Information. .Reciprocated casing until 34 bbls tail cement had been pumped. PV(after cond) 26 cP Weight 8.3 PPG Yield 1.94 Yield 1.15 St]'. Wt. Up 155 Str, Wt, Dn 135 Str, Wt. Mud , m, i Full returns while circulating and cementing, Had 5 bbls 12.2 ppg cement returns to surface. Cement Company IRig Contractor , Dowell 1 Parker ISignature R. L, Morrison Jr. Aug. 2. !996 P, '/2 7' 25AM ARCO ALAStfA iNC No, 1063 ARCO Alaska, Inc. Illll I FACSIMILE TRA ,NSMISSlON Ii iii i Bi I lllllll II I1 ~'",'.."i II lB I II Fall .... i!1 I i ii If dl Itu 11 1 I II Ill i Ii II · I II II I II II · I IIII Ill III .~.,.h. Il I I fill F,, ,I II, I, ,I 111 II II I IIII !1 III II II II ~ !1 ii II,,., I I, ,I h"l la I · Il il ~ll lB II Il Kuparuk Drill Site Development P. O. BOX 10~3360 ANCHORAGF_ AK 995_170360 ~'~"~ z~-~.~/_ ' 27¢- 7%~ " z7 P_-/4$5.. ~ ~_ · .~.::~.,...- ~.~ ~ . · ,. _ - .... I al mil m m ........ ~ __ Au¢. Y'EbAM A~GO ALASKA !N~ .C.,A$1NG AND LEAK-OFF FRACTURE TES_T_S ~o, LUOJ Li L Well Name: KRU 3G-03 Date: 8/1/96 Supervisor: R.L. Morrison Jr, Casing Size and Description: 7 5/8, 29,7#, L-80, BTC Casing Setting Depth: 3531' TMD 3084' TVO Mud Weight: 8.50 ppg EMW = Leak-off P. ressure (PLO) + MW 0.052 x TVB LOT = 950 psi / (0.052 x 3084 ft) ,- 8.5 ppg = 14.42 ppg Fluid Pumped = 1.53 bbls. Fluid bled back -- 1.5 bbls ~ooo .... ~aoo i ........ F ' , 1500 1400 ' 1000 800 ,, ' 700 I'' , ' ~,00 '-- 300 ~ ZOO 100 -- i STROKES , · r-- -J I : , I' ~'"' LEAK-OF~: T I I I I I | 7') -7---' ."' (~/. l(~ AND LEAK-OFF FRACTURE T_E~ ..... . Well Name: KFIU 3G-03 Date: 8/1/96 Supervisor: R.L. Morrison Jr. Casing Size and Description: 7 5/8, 29.7#, L-80, BTC Casing Setting Depth' 3531' TMD 3084' TVD Mud Weight 8.60 ppg EMW = Leak-off Pressure .(_P_L_,O), + MW 0,052 x TVD LOT = 925 psi / (0.052 x 3084 fi) + 8,6 ppg = 14.36 ppg Fluid pumped -- 1.53 Fluid bled back -. 1.75 2000 ---~ ................... 180o ......... !., 1700 -- i 1200 , ;300 ..... i' ' ~2oo/ ' '- "7 ............ ~ I , 000 , · · gOO __ .C .... , 800 ....... 700 i " coo · ., ~ 400 4-- 200 ~- I I ' , lOO .r- ..... ~ ...... 0 I ', [ STROKES : "'-'~--'LEAK-OFFTE'ST - 'I ;~ CASING TEST - 1 I I ~ ! · f · "1 ......... '1 .....--'-i ] - ALAS~ OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 10, 1996 M. Zanghi, Drill Site Develop. Supv. ARCO Alaska, Inc. P 0 Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 3G-03 ARCO Alaska, Inc. Permit No: 96-122 Sur. Loc. 2538'FNL, 320'TWL, Sec. 24, T12N, RSE, UM Btmhole Loc. 2261'FNL, l137'FEL, Sec. 24, T12N, RSE, 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 mn. 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 wimess the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o cncl. STATE OF ~ · , ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill I--I I b Type of Well Exploratory E] Stratigraphic Test C] Development Oil X ' Re-Entry [~ Deepen r'l Service BI Development Gas D Single Zone X Multiple Zone r=! 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Ricj RKB 41', Pad 54' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25547, ALK 2561 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) 2538' FNL, 320' FWL, Sec. 24, T12N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 2285' FNL, 1407' FEL, Sec. 24, T12N, RSE, UM 3G-03 #U-630610 At total depth 9. Approximate spud date Amount 2261' FNL, 1137' FEL, Sec. 24, T12N, R8E, UM ~/22/96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3G-02 7470' MD 1137 @ TD feet 25.0' @ 120' feet 2650 6173' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035(e)(2)) Kickoff depth 550' feet Maximum hole angle 38.7° Maximum surface 181 7 psig At total depth ('I-VD) 3200 psig 18. Casing program Settinc, I Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length ME) TVD MD TVD (include 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 3452' 41' 41' 3493' 3070' 940 Sx Arcticset III & HF-ERW 290 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOD 6925' 41' 41' 6966' 5780' HF-ERW 170 Sx Class G 6.75' 3.5' 9.3# L-80 EUESrdlV 504' 6966' 5780' 7470' 61 73' Top 500' above Kuparuk 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary ORIGINAL Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth c~t°rnU~tu~;:lr R E C E IV E D Surface Intermediate Production J U N 2 {~ Liner Perforation depth: measured Alaska 0il & Gas Cons. C0mmi~si0r~ true vertical Anchorage 20. Attachments Filing fee X Property plat D BOP Sketch X Diverter Skelch X Drilling program X Drilling fluid program X Time vs depth plot I--I Refraction analysis D Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify lhat the for~egoing is true and correct to the best of my knowledge Signed /~. ~'~ / Title Drill Site Develop. Supv. Date ( ~ ) Commission Use Only Perry_it Number -- I~, ~'API number ~,,~. I Approval date !e/q: r~,~] I See cover letter for /~;~'~"--//'2. ~ 5 0-,,,/(::~7,~' -' ~ ~ ~ ~"Z"~.~ I o. ther requirements Conditions of approval Samples required C] Yes ,~ No Mud log i Yes J~' No Hydrogen sulfide measures ~ Yes D No Directional survey required '~ Yes D ~o Required working pressure for BOPE D 2M J~ 3M D 5M D leu D Other: Odcr~al Signore 8y David W. Johnston by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 in triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3G-03 1. Move in and rig up Parker #245. 2. Install diverter system. 3. Drill 9-7/8" hole to 7-5/8" surface casing point (3,493')according to directional plan. 4. Run and cement 7-5/8" casing. 5. Install and test BOPE to 3000 psi. Test casing to 2000 psi. 6.---......~;-i~rill out cement and 10' of new hole. Perform leak off test to ~-2.5 ¢,~,~ F_MW: .;:~;-'7~-' ~"~l~rill 6-3/4" hole to total depth (7,470') according to directional plan. 8. Run open hole evaluation logs or LWD tools as needed. 9. Run and cement 5-1/2" x 3-1/2" 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.) 10. Pressure test 5-1/2" x 3-1/2" casing to 3500 psi. I 1. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. 1 2. 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. 1 3. Shut in and secure well. 14. Clean location and release rig in preparation for perforating. RECEIVED JUN 2 ~ 199~ Alaska 011 & G~s Cons. (;ommis~ion Al~ci~0mg~ DRILLING FLUID PROGRAM Well KRU 3G-03 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +_10% Drill out to wei~lht up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.9 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Dril~-Fluid System: '-:¢; .-_~;;'--.-T~ndem Brandt Shale Shakers ---':~ ::- Tr-i'iSl~' 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: 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 1,817 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3G-03 is 3G-02. As designed, the minimum distance between the two wells would be 25.0' @ 120'. Drillin~ Area Risks: "¢lisks in the 3G-03 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 10.9 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 3G-03 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. fNote that cement rinseate will not be in!ected 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 3G-03 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. --?l~-..requested that 3G-03 be permitted for annular pumping occurring as a result of drilling .~:~eratib'h~, 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 3G 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 'I'VD) + 1500 psi Max Pressure = 3420 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. 'OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 LTC 4790 4072 6890 5857 5.500 15.5 L-80 3 LTC-M 4990 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 ALASKA, !nc· Pad 3G 3 stol Kuparuk River Unit North SLope, ALaska CLEARANCE REPORT Baker H~]hes !NTEG Y~r ref : 3 Version {2){Jr ref : prop1493 License : Date printed : 29-Nay-96 Date created : 9-Jan-96 Last revised : 29-May-96 FieLd is centred on nTO 16 18.576,wlSO 5 56.536 Structure is centred on nTO 2] 12.884,w150 0 47.469 SLot Location is n70 22 47.92],w150 0 ~.104 Stol Grid coordinates are N 5988560.264, E 498698.202 SLot Local coordinates are 25~.00 S 320.00 E Reference North is True North Main caLcuLation perfomed with 3-D Minim[~n Distance methoci Object weL [path CLosest apl=roach with 3-D mininun distance method Last revised Distance M.D. Diverging fro{n 15-May-91 5~0.0 100.0 3660.0 15-May-91 137.3 744.4 744.4 14-May-91 372.3 772.2 772.2 1S-May-91 540.0 100.0 14-#ay-91 415.1 60.0 120.0 14-#ay-91 440.0 100.0 120.0 20-Jun-91 4~5.1 50.0 120,0 15-May-91 490.0 60.0 120.0 15-May-91 515.1 60.0 120,0 15-May-91 565.1 60.0 3660.0 14-#ay-91 200.1 60.0 120.0 14-May-91 25.3 100.0 120.0 14-May-91 225.0 100.0 100,0 14-May-91 339.8 140.0 140.0 14-#ay-91 25.0 - 120.0 120.0 14-Nay-91 45.9 744.4 744.4 20-Jun-91 71.2 672.2 1250.0 15-May-91 100.1 100.0 120.0 15-May-91 100.1 100.0 120.0 14-May-91 119.9 716.7 716.7 14-May-91 167.1 694.4 694.4 ,,-,.,-,, ,,,., ,,o.o R EIVED t4-#ay-91 362.4 (~30.0 ~'-Kmy-~ ~.0 400.0 400.0 JUN g 1996 Alaska Oil & Gas Cons. Commission ~50 0 ~ 0 .. ~ $§0 RKB ELEVA'rtON: 95' ARCO ALASKA, rlc. Structure : Pad 3G Well : 5 Field : Kuparuk River Unit Location : North Slope, Alaska SURFACE LOCATION: 2538' FNL, 320' F"WL SEC. 24, T12N, RSE · East > ICreated by : jonea For: 1) PETRASH IDote plotted : 2g-May-g6 IPlot Reference is ,3 Version ~14. Coordlnotee ore in feet reference slot True Vertical Depthe ~t~_?_r~rc~ ,,~K8 (Parker 350 0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4-200 I I I I I I I I . I I I I I I I ! I I I I I I I I I I 700 , . KOP 1¥D=550 TMD=550 DEP=O e"- ~e ~j:p~'~ - | .>_~.~,._~,.u,., TVD=716 TMD=717 DEP=.I 2 ~ ¢~o" .,,.et' .,,..~,- ~,~ [ ~ I ._ -_ _.. '- .4- 6,14 I ~13.~ 3 o£~ / loo' ~ "-~ c'o,, / ~. 25.o7 -t '~,2801 B/ PERMAFROST _ / ~3~96 TVD=1595 TMD=1631 DEP==214 .... 1750_ X~3'~.92 T/ UGNU SNDS TVD=1795 TMD=l$64 DEP=333 TD LOCATION: _ 'X~6.8~ LOC WD=1918 TMD=2016 DEP=424 2261' FNL. 1137' FEL x, ~ SEC 24 T12N RSE ~oo_ X · , , ~ ~ 2285' FNL. 1407' FEL - ~ SEC. 24, T12N. RSE 2450_ ~ T/ W SAK SNDS TV0=2470 TMD=2724 DEP=866 TARGET 7VD-5835 TMD--7036 ' DEP=3562 2800_ NORTH 25.3 N ,, B/ W SAK SNDS TVD=2870 TMD=5237 DEP=1187 EAST 3553 ~"~, 7 5/8" CSG PT TVD=5070 TMD=3495 DEP=1547 .3150_ ~=~OS~M~=~EP=~ss N 85.93 DEC E ~oo_ 356~' (TO TARGET) · ,*PLANE OF PROPOSAL*,* - 4200. AVERAGE ANGLE - 3s.?z PE 4550. 49OO. 5250_ 'x~\ B/ HRZ 'B/D=5625 TMD=6767 DEP=3594 5600. 5'~z" TABGET - T/ UNITS D/C TVD=5885 T~D=?036 DEP=356~ ~. T/ UNIT B TVD=S860 TMD=7068 DEP=3582 5950J T/ A3 INTERVAL TVD=5913 TMD=71.56 DEP=$625 '~. T/ UNIT A TVD=5898 TMD=7117 DEP=3613 B/ KUP SNDS TVD--6017 TMD-=7270 DEP=3708 TD - ,"~1~, ° 63001 '/'~ ~ 6650! I I I I I I I I I I I I I I I I I I I I I I I I I I 350 0 .350 700 1050 1400 1750 2100 2450 2800 3150 5500 3850 4200 Scale 1 : 175.00 Vertical Section on 85.93 azimuth with reference 0.00 N, 0.00 E from slot Scale 1 - 20.00 120 80 280 J I~~_ I 240 · 160 _ ARCO ALASKA, Inc. Structure : Pad 3G Well : 3 Field : Kuparuk River Unit Location : North Slope, Alaska Eas~ --> 80 120 160 2OO 240 280 ! I I I I I I I I I I 320 360 400 I I I I I iCreot~l by : jono~ For: D PETRASH IDate plott~d : 2g-May-g6 IPlot Reference is 3 Vemion ii4. iCoordinotes are in feet reference slot ITrue Vertical Depths are reference RKB (Perker I~Z45). 440 480 520 I I I I I 560 ~ 240 · · 0 0 200 0 160 I I V 120 80 8O 120 160 _ 200 240 280 _ _ 320 _ -- 360 400 2600 80O 120 80 40 Scale 1 : 20.00 1800 1200 1400 0 40 80 1600 1800 460O 120 160 200 240 280 East > 520 560 2O0O Alaska Oil & gao. Cons. Commission Anchor~g9 560 120 80 80 120 160 200 240 280 320 360 40O I I V i UPARUK RIVER UNI'I 20" DIVERTER SCHEMATIC 6 4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. , MAINTENANCE & OPERATION uPOn INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS, · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL Of THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER, DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 I3 13 5/8" 5000 PSI BOP STACK ACCUMULATOR CAPACITY TEST CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2, CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3, CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 30(X) PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. [ OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE MNE VALVES. ~ CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE MNES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. & OPEN TOP PIPE RAMS AND CLOSE BO3-rOM PiPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. ~ OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3(xx) PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILUNG POSITION. 11. TEST STANDPIPE VALVES TO 3(xx) PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 30(X) PSI WITH KOOMEY PUMP. 13, RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2' TO 5-1/2' OR 5' TO 7' PIPE ODS AS APPROPRIATE. 1. 16' -2000 PSI STARTING HEAD 2. 11' - 3000 PSI CASING HEAD 3. 11' -3000 PSI X 13-5/8' - 5(X)O PSI SPACER SPOOL 4. 13-5/8' - 5000 PSI PIPE RAMS 5. 13-5/8' -5000 PSI DRLG SPOOLW/ CHOKE AND KILL LINES 6. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' -5000 PSI ANNULAR RECEIVED JUN 2 ~ 199~; Alaska 011 & Gas Cons. CommJssio~ Anchomga · WELL . r~_,.l-'ilvii i v, ,.--,..,:',.;...,~ , COMPANY . ~ FIELD & POOL ~/?~./~_~c~ INIT CLASS ~)~__~4./ //--f'~2'// G'EOL AREA ?.~_.~ UNIT# '/ /,//g('..j . ON/OFF SHORE__~)Z:~_._ ADMINISTRATION N 1. Permit fee attached ....................... ~ tN 2. Lease number appropriate ................... 3. Unique well name and number ................ N 4. Well located in a defined pool ................. N 5. Well located proper distance fi'om drtg unit boundary .... N 6. Weii located proper distance from ct~her wells ........ N 7.,..,..~' ,ffici,=,m~., a,','-' .... ~..~73 available in dfi!lin~ unit. N 8. If deviated, is ...... ~'~-"' slat' ;'"~--,~ .,= ..... {nc ....,, N 9. Operator only affected party ..... '. '. '. '. ". ". ". ". ". ". ". ". ".' N 10. ©¢erator has ~pmpfiate bond in ~orce ............ ~ 11. Permit can be issued wi~out conservation order ...... N 12. Permit ca~ be issued without administraQve approval .... N 13. Can permit be approved before 15-day wait .......... N ENGINEERING REMARKS APPR DATE u:--.,JLO~Y 14. Conductor string orovided ................... (~ N 15. Surface casing p~otects all known USDWs ...... .... {,~ N 16. CMT vol adequate to circulate on conductor & surf csg . . . ~1~ ,.1~ 17. CMT vol adequate to tie-in long s~ng to surf csg ...... ,~ 18. CMT will cover all known productive hodzons ......... ,~ N 19. Casing designs adequate for C, T, B & perrnairost. ..... .~I~ N 20. Adequate tankage or reserve pit ................ ,,,,~'~ N 21. If a re-drill, has a 10--403 for abndnmnt beenapproved .... (~ N 22. Adequate wellbore separation proposed ............ ~ N 23. If diverter required, is it adequate ................ N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs adequate ........................ N 26. BOPE press rating adequate; test to .___psig N 27. Choke manifold complies w/APl RP-53 (May 84) ...... .~Y~N 28. Work will occur without operation shutdown ......... 29. is presence of H2S gas probs:~ie .............. 31. Da~,, presented on potenti~ ovemressure zones ....... Y~ ,,,/~~ ~ 32. _~ismio sd,~}_is of sn~low g~ ~ones ............ ./ N 33. Sewed ~ndi~cn sumey (if off-shore) ........... /. Y N ~. Con,ct n~me/pnone for w~ progre~ re~...../ . . Y N ~.'-OLO~Y. ENGINEERING: COMMISSION: JD H ~CJ:~/~ ~/~ JDN TAB; Comments/instructions:
