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186-152
Or i g i n a t e d : D e l i v e r e d t o : 1ͲMa r Ͳ24 Ha l l i b u r t o n A l a s k a O i l a n d G a s C o n s e r v a t i o n C o m m . Wi r e l i n e & P e r f o r a t i n g At t n . : Na t u r a l R e s o u r c e T e c h n i c i a n At t n : F a n n y H a r o u n 3 3 3 W e s t 7 t h A v e n u e , S u i t e 1 0 0 69 0 0 A r c t i c B l v d . A n c h o r a g e , A l a s k a 99 5 0 1 An c h o r a g e , A l a s k a 9 9 5 1 8 Of f i c e : 9 0 7 Ͳ27 5 Ͳ26 0 5 FR S _ A N C @ h a l l i b u r t o n . c o m Th e t e c h n i c a l d a t a l i s t e d b e l o w i s b e i n g s u b m i t t e d h e r e w i t h . P l e a s e a d d r e s s a n y p r o b l e m s o r co n c e r n s t o t h e a t t e n t i o n o f t h e s e n d e r a b o v e WE L L N A M E A P I # S E R V I C E O R D E R # F I E L D N A M E J O B T Y P E D A T A T Y P E L O G G I N G D A T E P R I N T S # D I G I T A L # E S E T # 12 Z Ͳ16 5 0 Ͳ02 9 Ͳ21 3 6 3 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 6 ͲFe b Ͳ24 0 1 23 B Ͳ10 5 0 Ͳ02 9 Ͳ21 3 6 8 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 2 9 ͲNo v Ͳ23 0 1 33 F Ͳ14 5 0 Ͳ02 9 Ͳ21 5 0 0 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 4 ͲFe b Ͳ24 0 1 43 H Ͳ13 A 5 0 Ͳ10 3 Ͳ20 0 8 9 Ͳ01 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 1 1 ͲJa n Ͳ24 0 1 53 H Ͳ33 A 5 0 Ͳ10 3 Ͳ20 5 7 8 Ͳ01 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 1 0 ͲDe c Ͳ23 0 1 63 H Ͳ33 A 5 0 Ͳ10 3 Ͳ20 5 7 8 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 1 0 ͲDe c Ͳ23 0 1 72 A Ͳ10 A 5 0 Ͳ10 3 Ͳ20 0 5 6 Ͳ01 n / a K u p a r u k R i v e r R a d i a l B o n d R e c o r d F i e l d & P r o c e s s e d 2 6 ͲFe b Ͳ24 0 1 83 K Ͳ17 5 0 Ͳ02 9 Ͳ21 6 4 2 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 2 ͲDe c Ͳ23 0 1 93 K Ͳ24 5 0 Ͳ02 9 Ͳ22 9 3 5 Ͳ00 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 2 9 ͲDe c Ͳ23 0 1 10 3 K Ͳ24 5 0 Ͳ02 9 Ͳ22 9 3 5 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 3 0 ͲJa n Ͳ24 0 1 PL E A S E A C K N O W L E D G E R E C E I P T B Y S I G N I N G A N D R E T U R N I N G A C O P Y O F T H E T R A N S M I T T A L L E T T E R T O T H E A T T E N T I O N O F : Fa n n y H a r o u n , H a l l i b u r t o n W i r e l i n e & P e r f o r a t i n g , 6 9 0 0 A r c t i c B l v d . , A n c h o r a g e , A K 9 9 5 1 8 FR S _ A N C @ h a l l i b u r t o n . c o m Da t e : Si g n e d : Tr a n s m i t t a l D a t e : T3 8 5 8 0 T5 8 5 9 1 T3 8 5 9 0 T5 8 5 9 1 T3 8 5 8 9 T3 8 5 8 9 T3 8 5 8 8 T3 8 5 8 7 T3 8 5 8 6 T3 8 5 8 5 18 5 - 1 0 9 18 5 - 1 1 4 18 5 - 2 9 2 19 6 - 1 9 7 20 9 - 1 0 3 22 3 - 0 9 2 18 6 - 1 5 2 19 8 - 2 4 9 Me r e d i t h G u h l Di g i t a l l y s i g n e d b y M e r e d i t h Gu h l Da t e : 2 0 2 4 . 0 3 . 0 4 1 5 : 5 0 : 3 7 - 0 9 ' 0 0 ' 186 -1 52 3K Ͳ17 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9584'feet 8718'feet true vertical 6949'feet None feet Effective Depth measured 9309'feet 7984', 8001, 8665', 8816', 9082' feet true vertical 6743'feet 5848', 5859', 6299', 6400', 6580' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 2-7/8" L-80/J-55 9111' MD 6600' TVD Packers and SSSV (type, measured and true vertical depth) 7984' MD 8001' MD 8665' MD 8816' MD 9082' MD N/A 5848' TVD 5859' TVD 6299' TVD 6400' TVD 6580' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 4761' 3704' Burst Collapse Production Liner 9482' Casing 6897'9513' 4724' 115'Conductor Surface Intermediate 16" 9-5/8" 77' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 186-152 50-029-21642-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025629 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3K-17 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 106 Gas-Mcf MD 973 Size 115' 1366 12571356 68 138660 159 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 815 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: Baker FH Packer w/ SBE Packer: Camco HRP-1-SP Packer Packer: Baker 80-32 DB Perm Packer SSSV: None Jan Byrne jan.byrne@conocophillips.com (907) 659-7224Staff Well Integrity Specialist 8970-8994', 9189-9334' 6503-6520', 6655-6792' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Jan Byrne DN: OU=Wells AK, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2023.12.21 06:05:29-09'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne By Grace Christianson at 1:24 pm, Dec 21, 2023 DTTMSTART JOBTYP SUMMARYOPS 12/1/2023 REPAIR WELL PULLED OV STA# 5 7989' RKB, POCKET OPEN. PULLED GLV STA# 4 7153' RKB. SET 1/4" OV STA# 4 7153' RKB, PULLED PRONG & PX PLUG BODY @ 8718' RKB, JOB IN PROGRESS. 12/2/2023 REPAIR WELL BUSH & FLUSH TBG FOCUSING ON PATCH SET AREA ~8000', RAN DMY PATCH DRIFT, NO ISSUES. SET LOWER PACKER MID ELEMENT @ 8001' RKB, IN PROGRESS #CPP287048 12/3/2023 REPAIR WELL SIT ON TTS TEST TOOL IN LWR PACKER @ 8001' RKLB, PASSING CMIT 2500 PSI. SET UPPER PATCH, UPPER ELEMENT @ 7984', SIT ON TTS TEST TOOL SET IN UPPER PACKER, PASSING MIT-T FROM UPPER PKR @ 7984' RKB, PASSING 2500 PSI CMIT IA x T......JOB COMPLETE # CPP287040/CPAL287058 3K-17 Tubing Patch Summary or Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,309.0 3K-17 10/31/2018 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Move OV uphole, Set Patch 3K-17 12/3/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 - RKB PROD/TBG DIFFERENT RIGS 7/27/2010 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 38.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 37.0 4,761.4 3,704.5 36.00 J-55 BTC PRODUCTION 7 6.28 30.7 9,512.8 6,896.7 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 35.0 Set Depth 8,775.0 Set Depth 6,372.6 String Max No 2 7/8 Tubing Description TUBING WO Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE-8rd ID (in) 2.41 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.0 35.0 0.26 HANGER 7.060 CAMERON McEVOY TUBING HANGER Camero n McEvoy Gen IV 2.950 524.7 524.6 2.07 NIPPLE 3.703 CAMCO 'DS' NIPPLE CAMCO 2.312 3,153.0 2,591.9 43.00 GAS LIFT 4.750 2 7/8 X1" KBGM GLM. SN. 327AE03 CAMCO KBMG 2.347 4,775.2 3,713.4 49.80 GAS LIFT 4.750 2 7/8 X1" KBGM GLM. SN. 358AC10 CAMCO KBMG 2.347 6,147.7 4,624.6 47.77 GAS LIFT 4.750 2 7/8 X1" KBGM GLM. SN. 352AC10 CAMCO KBMG 2.347 7,153.4 5,301.6 48.85 GAS LIFT 4.750 2 7/8 X1" KBGM GLM. SN. 321AC10 CAMCO KBMG 2.347 7,989.3 5,851.6 49.47 GAS LIFT 4.750 2 7/8 X1" KBGM GLM. SN. 331AE03 SOV CAMCO KBMG 2.347 8,581.7 6,243.2 48.15 GAS LIFT 4.750 2 7/8 X1" KBGM GLM. SN. 334AC03 CAMCO KBMG 2.347 8,635.8 6,279.3 48.07 LOCATOR 3.460 SEAL LOCATOR SUB Baker 2.440 8,636.8 6,280.0 48.06 SEAL ASSY 3.230 80-32 SEAL ASSEMBLY (OAL= 21.05') Baker 2.410 8,642.8 6,284.0 48.05 PBR 5.860 BAKER 80-32 PBR Baker 3.250 8,665.0 6,298.8 47.98 PACKER 5.960 BAKER FH PACKER w/SBE Baker 2.380 8,718.1 6,334.4 47.89 NIPPLE 3.250 HES X NIPPLE CAMCO 2.313 8,767.7 6,367.6 47.91 OVERSHOT 6.010 BAKER POORBOY OVERSHOT w/ 5.69' swallow Baker 2.460 Top (ftKB) 8,772.2 Set Depth 9,110.7 Set Depth 6,599.8 String Max No 2 7/8 Tubing Description TUBING Original Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABM OD ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,798.4 6,388.2 47.92 SBR 4.750 CAMCO OEJ SBR 2.312 8,815.9 6,400.0 47.90 PACKER 5.937 CAMCO HRP-1-SP PACKER 2.347 8,856.2 6,427.0 47.84 PRODUCTION 4.750 MERLA TMPD 2.375 8,927.7 6,475.1 47.71 PRODUCTION 4.750 MERLA TMPD 2.375 8,966.7 6,501.3 47.64 BLAST RINGS 2.875 BLAST RINGS (2) 2.441 9,041.7 6,552.1 46.85 PRODUCTION 4.750 MERLA TMPD 2.375 9,080.6 6,578.9 46.17 SEAL ASSY 3.500 G-22 LOCATOR SEAL ASSEMBLY Baker 2.408 9,082.5 6,580.2 46.13 PACKER 5.656 BAKER 80-32 'DB' PERMANENT PACKER 3.250 9,086.2 6,582.7 46.07 SBE 4.250 80-30 SEAL BORE EXTENSION Baker 3.250 9,099.3 6,591.8 45.84 NIPPLE 3.668 CAMCO 'D' NIPPLE NO GO 2.250 9,109.9 6,599.3 45.64 SOS 3.750 CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,983.9 5,848.1 49.47 PACKER - PATCH - UPR Set upper patch assembly 2.29" P2P packer, spacer pipe, & anchor latch (OAL 18.95') TTS P2P & Anchor latch CPP2 87040 /CPAL 28705 8 12/3/2023 1.375 7,987.0 5,850.1 49.47 SPACER PIPE Spacer pipe CPAI 12/3/2023 1.600 7,989.0 5,851.4 49.47 LEAK - TUBING LEAK IDENTIFIED @ 7989' RKB ON LDL RUN 10/5/23 10/5/2023 2.410 8,001.0 5,859.2 49.46 PACKER - PATCH - LWR Set LWR P2P packer. TTS P2P CPP2 87048 12/2/2023 1.375 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,153.0 2,591.9 43.00 1 GAS LIFT GLV BK 1 1,347.0 11/25/2013 0.156 4,775.2 3,713.4 49.80 2 GAS LIFT GLV BK 1 1,326.0 11/25/2013 0.156 6,147.7 4,624.6 47.77 3 GAS LIFT GLV BK 1 1,306.0 11/25/2013 0.156 7,153.4 5,301.6 48.85 4 GAS LIFT OV BK 1 0.0 12/1/2023 0.250 3K-17, 12/20/2023 6:11:55 PM Vertical schematic (actual) PRODUCTION; 30.7-9,512.8 IPERF; 9,326.0-9,334.0 RPERF; 9,275.0-9,281.0 IPERF; 9,275.0-9,281.0 IPERF; 9,263.0-9,264.0 FRAC; 9,189.0 IPERF; 9,258.0-9,259.0 IPERF; 9,253.0-9,254.0 IPERF; 9,244.0-9,245.0 IPERF; 9,229.0-9,246.0 RPERF; 9,231.0-9,232.0 IPERF; 9,207.0-9,208.0 IPERF; 9,205.0-9,206.0 IPERF; 9,203.0-9,204.0 IPERF; 9,199.0-9,200.0 IPERF; 9,189.0-9,209.0 RPERF; 9,189.0-9,209.0 NIPPLE; 9,099.3 PACKER; 9,082.5 PRODUCTION; 9,041.7 IPERF; 8,970.0-8,994.0 PRODUCTION; 8,927.7 PRODUCTION; 8,856.2 PACKER; 8,815.9 NIPPLE; 8,718.1 PACKER; 8,665.0 LOCATOR; 8,635.8 GAS LIFT; 8,581.7 PACKER - PATCH - LWR; 8,001.0 SPACER PIPE; 7,987.0 GAS LIFT; 7,989.3 LEAK - TUBING; 7,989.0 PACKER - PATCH - UPR; 7,983.9 GAS LIFT; 7,153.4 GAS LIFT; 6,147.7 GAS LIFT; 4,775.2 SURFACE; 37.0-4,761.4 GAS LIFT; 3,153.0 NIPPLE; 524.7 CONDUCTOR; 38.0-115.0 HANGER; 35.0 KUP PROD KB-Grd (ft) 39.01 RR Date 8/29/1986 Other Elev 3K-17 ... TD Act Btm (ftKB) 9,584.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292164200 Wellbore Status PROD Max Angle & MD Incl (°) 50.78 MD (ftKB) 2,700.00 WELLNAME WELLBORE3K-17 Annotation Last WO: End Date 10/31/2013 H2S (ppm) 125 Date 1/14/2008 Comment SSSV: NIPPLE Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,989.3 5,851.6 49.47 5 GAS LIFT OPEN 1 0.0 12/1/2023 0.000 8,581.7 6,243.2 48.15 6 GAS LIFT DMY BK-5 1 0.0 10/30/2013 0.000 8,856.2 6,427.0 47.84 7 PROD DMY BK 1 0.0 4/13/2004 0.000 8,927.7 6,475.1 47.71 8 PROD DMY BK 1 0.0 4/13/2004 0.000 9,041.7 6,552.1 46.85 9 PROD DMY BK 1 0.0 11/22/2010 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,970.0 8,994.0 6,503.5 6,519.7 C-1, UNIT B, 3K- 17 12/8/1986 12.0 IPERF 5" Csg Gun, 120 ph 9,189.0 9,209.0 6,655.3 6,669.7 A-3, 3K-17 6/13/1996 4.0 RPERF 2 1/8" EJ; 180 ph; Ort +/- 90 F/Lowside 9,189.0 9,209.0 6,655.3 6,669.7 A-3, 3K-17 4/24/1988 4.0 IPERF 2 1/8 Tornado Link, 90 ph 9,199.0 9,200.0 6,662.5 6,663.2 A-3, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,203.0 9,204.0 6,665.4 6,666.1 A-3, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,205.0 9,206.0 6,666.8 6,667.5 A-3, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,207.0 9,208.0 6,668.3 6,669.0 A-3, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,229.0 9,246.0 6,684.2 6,696.6 A-2, 3K-17 4/24/1988 4.0 IPERF 2 1/8 Tornado Link, 90 ph 9,231.0 9,232.0 6,685.7 6,686.4 A-1, 3K-17 12/8/1986 1.0 RPERF 4" Csg Gun, 0 deg ph 9,244.0 9,245.0 6,695.1 6,695.9 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,253.0 9,254.0 6,701.7 6,702.5 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,258.0 9,259.0 6,705.4 6,706.1 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,263.0 9,264.0 6,709.1 6,709.8 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,275.0 9,281.0 6,717.9 6,722.4 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,275.0 9,281.0 6,717.9 6,722.4 A-2, 3K-17 12/8/1986 1.0 RPERF 4" Csg Gun, 0 deg ph 9,326.0 9,334.0 6,755.9 6,761.9 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,189.0 9,334.0 1 FRAC 6/20/1996 0.0 0.00 0.00 3K-17, 12/20/2023 6:11:56 PM Vertical schematic (actual) PRODUCTION; 30.7-9,512.8 IPERF; 9,326.0-9,334.0 RPERF; 9,275.0-9,281.0 IPERF; 9,275.0-9,281.0 IPERF; 9,263.0-9,264.0 FRAC; 9,189.0 IPERF; 9,258.0-9,259.0 IPERF; 9,253.0-9,254.0 IPERF; 9,244.0-9,245.0 IPERF; 9,229.0-9,246.0 RPERF; 9,231.0-9,232.0 IPERF; 9,207.0-9,208.0 IPERF; 9,205.0-9,206.0 IPERF; 9,203.0-9,204.0 IPERF; 9,199.0-9,200.0 IPERF; 9,189.0-9,209.0 RPERF; 9,189.0-9,209.0 NIPPLE; 9,099.3 PACKER; 9,082.5 PRODUCTION; 9,041.7 IPERF; 8,970.0-8,994.0 PRODUCTION; 8,927.7 PRODUCTION; 8,856.2 PACKER; 8,815.9 NIPPLE; 8,718.1 PACKER; 8,665.0 LOCATOR; 8,635.8 GAS LIFT; 8,581.7 PACKER - PATCH - LWR; 8,001.0 SPACER PIPE; 7,987.0 GAS LIFT; 7,989.3 LEAK - TUBING; 7,989.0 PACKER - PATCH - UPR; 7,983.9 GAS LIFT; 7,153.4 GAS LIFT; 6,147.7 GAS LIFT; 4,775.2 SURFACE; 37.0-4,761.4 GAS LIFT; 3,153.0 NIPPLE; 524.7 CONDUCTOR; 38.0-115.0 HANGER; 35.0 KUP PROD 3K-17 ... WELLNAME WELLBORE3K-17 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Braidenhead Repair Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9584'feet 8718'feet true vertical 6949' feet None feet Effective Depth measured 9309'feet 8665', 8816', 9082'feet true vertical 6743' feet 6299', 6400', 6580'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 2-7/8" L-80/J-55 9111' MD 6600' TVD Packers and SSSV (type, measured and true vertical depth) 8665' MD 8816' MD 9082' MD N/A 6299' TVD 6400' TVD 6580' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 4761' 3704' Burst Collapse Production Liner 9482' Casing 6897'9513' 4724' 115'Conductor Surface Intermediate 16" 9-5/8" 77' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 186-152 50-029-21642-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025629 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3K-17 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 115' ~ ~~ Well remains Shut-In ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker FH Packer w/ SBE Packer: Camco HRP-1-SP Packer Packer: Baker 80-32 DB Perm Packer SSSV: None Roger Mouser n1927@conocophillips.com (907) 659-7506Well Integrity Field Supervisor 8970-8994', 9189-9334' 6503-6520', 6655-6792' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E= N1927@conocophilllips.com Reason: I am the author of this document Location: Date: 2023.09.20 11:07:44-08'00' Foxit PDF Editor Version: 12.1.2 Roger Mouser P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 19, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Please find the enclosed 10-404 from ConocoPhillips Alaska, Inc. for the Bradenhead repair on KRU 3K-17 (PTD 186-152). If you have any questions, please feel free to contact me or my alternate, Brennen Green, at 659- 7506 Sincerely, Well Integrity Field Supervisor N1927@conocophillips.com ConocoPhillips Alaska, Inc. Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@ conocophilllips.com Reason: I am the author of this document Location: Date: 2023.09.20 11:04:35-08'00' Foxit PDF Editor Version: 12.1.2 Roger Mouser DTTMSTART JOBTYP SUMMARYOPS 8/26/2023 ACQUIRE DATA (AC-EVAL) T-POT (PASSED) T-PPPOT (PASSED) IC-POT (PASSED) IC-PPPOT (PASSED) DEGAS OA FOR MIT-OA (IN- PROGRESS) 8/27/2023 ACQUIRE DATA (AC EVAL) : MIT-OA TO 1800 PSI (PASS) 8/28/2023 ACQUIRE DATA (AC-EVAL) TIFL (FAILED DUE TO INFLOW & PRESSURE INCREASE) OA-DDT (PASSED) 8/30/2023 REPAIR WELL (BH REPAIR) CLEANED THE BH (COMPLETE) MISTRAS UT / MT THE WELD AREA (COMPLETE) 9/1/2023 REPAIR WELL BRUSH n' FLUSH TBG. SET 2.313" XX-PLUG W/ FILL EXTENSION @ 8718' RKB. USING HOLE-FINDER PER PASSING TEST ON TBG @ 7976' RKB, PULL AND REPLACE OV IN ST# 5 @ 7989' RKB, JOB IN PROGRESS 9/2/2023 REPAIR WELL RAN HOLE FINDER TO TO ABOVE PLUG,TEST FAILED. MADE SEVERAL STOPS, FAILED @ 8707' RKB - 7986' RKB. GOT A TEST @ 7941' RKB, APPARENT LEAK IN TBG JUST ABOVE OV. SMART WIRE LDL NEEDED. WELL STILL SECURED FOR BRAIDENHEAD REPAIR. 9/3/2023 ACQUIRE DATA (BH REPAIR) T X IA CDDT (FAILED). DUE TO T & IA PRESSURE INCREASE AND T & IA FL MOVEMENT DURING MONITOR PERIOD, CONFER WITH WSC FOR PLAN FORWARD. 9/5/2023 REPAIR WELL SET 2.5" AVA CATCHER ON TOP OF XX PLUG @ 8718' RKB. PULL O.V FROM STA 5 @ 7989' RKB. CIRC OUT 235 BBLS CORROSION INHIBITED SW FOLLOWED BY 85 BBLS DIESEL, U TUBE FOR FP. ATTEMTPT CMIT (FAILED) JOB IN PROGRESS 9/6/2023 REPAIR WELL PULL 2.5" AVA CATCHER FROM TOP OF XX PLUG @ 8718' RKB. SET STUBBY HOLE FINDER ON TOP OF PLUG, GOOD PRESSURE TEST. PULL 2.31" XX PLUG FROM X NIPPLE @ 8718' RKB. SET 2.31" PX PLUG IN NIPPLE @ 8718' RKB, PERFORM CMIT TxIA (PASSED) SET O.V. IN STA 5 @ 7989' RKB, READY FOR BH REPAIR WORK, ALSO SET UP FOR SMART WIRE LDL. 9/7/2023 ACQUIRE DATA (BH REPAIR) T X IA CDDT (IN PROGRESS). 9/8/2023 ACQUIRE DATA (BH REPAIR) OA DDT COMPLETE, INSTALL OA N2 PURGE JEWELRY, PURGED OA WITH N2. 9/9/2023 ACQUIRE DATA (BH REPAIR) PURGED OA WITH N2 (COMPLETE). 9/12/2023 ACQUIRE DATA (BH REPAIR) TEST BH HEATING EQUIPMENT COMPLETE. 9/13/2023 ACQUIRE DATA (BH REPAIR) WELD BH (COMPLETE). 9/14/2023 ACQUIRE DATA (BH REPAIR) MITOA WITH N2 TO 1400 PSI (PASSED) MISTRAS MT/UT WELD AREA. (ALL OK) MISTRAS COMPLETED OIG INSPECTION WITH FLIR CAMERA FOR QUAD OOOOa EVENT. READY FOR SMART WIRE LDL. 3K-17 Braidenhead Repair Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,309.0 3K-17 10/31/2018 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set plug ,Swap OV. 3K-17 9/6/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 - RKB PROD/TBG DIFFERENT RIGS 7/27/2010 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 38.0 115.0 115.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 37.0 4,761.4 3,704.5 36.00 J-55 BTC PRODUCTION 7 6.28 30.7 9,512.8 6,896.7 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 35.0 Set Depth 8,775.0 Set Depth 6,372.6 String Ma 2 7/8 Tubing Description TUBING WO Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE-8rd ID (in) 2.41 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 35.0 35.0 0.26 HANGER 7.060 CAMERON McEVOY TUBING HANGER Camero n McEvoy Gen IV 2.950 524.7 524.6 2.07 NIPPLE 3.703 CAMCO 'DS' NIPPLE CAMCO 2.312 3,153.0 2,591.9 43.00 GAS LIFT 4.750 2 7/8 X1" Camco KBGM GLM. SN. 327AE03 CAMCO KBMG 2.347 4,775.2 3,713.4 49.80 GAS LIFT 4.750 2 7/8 X1" Camco KBGM GLM. SN. 358AC10 CAMCO KBMG 2.347 6,147.7 4,624.6 47.77 GAS LIFT 4.750 2 7/8 X1" Camco KBGM GLM. SN. 352AC10 CAMCO KBMG 2.347 7,153.4 5,301.6 48.85 GAS LIFT 4.750 2 7/8 X1" Camco KBGM GLM. SN. 321AC10 CAMCO KBMG 2.347 7,989.3 5,851.6 49.47 GAS LIFT 4.750 2 7/8 X1" Camco KBGM GLM. SN. 331AE03 SOV CAMCO KBMG 2.347 8,581.7 6,243.2 48.15 GAS LIFT 4.750 2 7/8 X1" Camco KBGM GLM. SN. 334AC03 CAMCO KBMG 2.347 8,635.8 6,279.3 48.07 LOCATOR 3.460 BAKER SEAL LOCATOR SUB Baker 2.440 8,636.8 6,280.0 48.06 SEAL ASSY 3.230 BAKER 80-32 SEAL ASSEMBLY (OAL= 21.05') Baker 2.410 8,642.8 6,284.0 48.05 PBR 5.860 BAKER 80-32 PBR Baker 3.250 8,665.0 6,298.8 47.98 PACKER 5.960 BAKER FH PACKER w/SBE Baker 2.380 8,718.1 6,334.4 47.89 NIPPLE 3.250 HES X NIPPLE CAMCO 2.313 8,767.7 6,367.6 47.91 OVERSHOT 6.010 BAKER POORBOY OVERSHOT w/ 5.69' swallow Baker 2.460 Top (ftKB) 8,772.2 Set Depth 9,110.7 Set Depth 6,599.8 String Ma 2 7/8 Tubing Description TUBING Original Wt (lb/ft) 6.50 Grade J-55 Top Connection EUE8rdABMO D ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,798.4 6,388.2 47.92 SBR 4.750 CAMCO OEJ SBR 2.312 8,815.9 6,400.0 47.90 PACKER 5.937 CAMCO HRP-1-SP PACKER 2.347 8,966.7 6,501.3 47.64 BLAST RINGS 2.875 BLAST RINGS (2) 2.441 9,080.6 6,578.9 46.17 SEAL ASSY 3.500 BAKER G-22 LOCATOR SEAL ASSEMBLY 2.408 9,082.5 6,580.2 46.13 PACKER 5.656 BAKER 80-32 'DB' PERMANENT PACKER 3.250 9,086.2 6,582.7 46.07 SBE 4.250 BAKER 80-30 SEAL BORE EXTENSION 3.250 9,099.3 6,591.8 45.84 NIPPLE 3.668 CAMCO 'D' NIPPLE NO GO 2.250 9,109.9 6,599.3 45.64 SOS 3.750 CAMCO SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,712.0 6,330.3 47.88 OTHER Set baited PX prong in plug body. 2.5" bait sub, (12"), PX prong( 57.5") OAL 69" 9/6/2023 0.000 8,718.0 6,334.3 47.89 TUBING PLUG Set PX plug body w/ fill ext (OAL 47") 9/6/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,153.0 2,591.9 43.00 1 GAS LIFT GLV BK 1 1,347.0 11/25/2013 0.156 4,775.2 3,713.4 49.80 2 GAS LIFT GLV BK 1 1,326.0 11/25/2013 0.156 6,147.7 4,624.6 47.77 3 GAS LIFT GLV BK 1 1,306.0 11/25/2013 0.156 7,153.4 5,301.6 48.85 4 GAS LIFT GLV BK 1 1,325.0 11/24/2013 0.188 7,989.3 5,851.6 49.47 5 GAS LIFT OV BK 1 0.0 9/6/2023 0.250 8,581.7 6,243.2 48.15 6 GAS LIFT DMY BK-5 1 0.0 10/30/2013 0.000 8,856.2 6,427.0 47.84 7 PROD DMY BK 1 0.0 4/13/2004 0.000 8,927.7 6,475.1 47.71 8 PROD DMY BK 1 0.0 4/13/2004 0.000 9,041.7 6,552.1 46.85 9 PROD DMY BK 1 0.0 11/22/2010 0.000 3K-17, 9/19/2023 2:56:33 PM Vertical schematic (actual) PRODUCTION; 30.7-9,512.8 IPERF; 9,326.0-9,334.0 IPERF; 9,275.0-9,281.0 RPERF; 9,275.0-9,281.0 IPERF; 9,263.0-9,264.0 FRAC; 9,189.0 IPERF; 9,258.0-9,259.0 IPERF; 9,253.0-9,254.0 IPERF; 9,244.0-9,245.0 IPERF; 9,229.0-9,246.0 RPERF; 9,231.0-9,232.0 IPERF; 9,207.0-9,208.0 IPERF; 9,205.0-9,206.0 IPERF; 9,203.0-9,204.0 IPERF; 9,199.0-9,200.0 RPERF; 9,189.0-9,209.0 IPERF; 9,189.0-9,209.0 NIPPLE; 9,099.3 PACKER; 9,082.5 PRODUCTION; 9,041.7 IPERF; 8,970.0-8,994.0 PRODUCTION; 8,927.7 PRODUCTION; 8,856.2 PACKER; 8,815.9 TUBING PLUG; 8,718.0 NIPPLE; 8,718.1 OTHER; 8,712.0 PACKER; 8,665.0 LOCATOR; 8,635.8 GAS LIFT; 8,581.7 GAS LIFT; 7,989.3 GAS LIFT; 7,153.4 GAS LIFT; 6,147.7 GAS LIFT; 4,775.2 SURFACE; 37.0-4,761.4 GAS LIFT; 3,153.0 NIPPLE; 524.7 CONDUCTOR; 38.0-115.0 HANGER; 35.0 KUP PROD KB-Grd (ft) 39.01 RR Date 8/29/1986 Other Elev 3K-17 ... TD Act Btm (ftKB) 9,584.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292164200 Wellbore Status PROD Max Angle & MD Incl (°) 50.78 MD (ftKB) 2,700.00 WELLNAME WELLBORE3K-17 Annotation Last WO: End Date 10/31/2013 H2S (ppm) 125 Date 1/14/2008 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,970.0 8,994.0 6,503.5 6,519.7 C-1, UNIT B, 3K- 17 12/8/1986 12.0 IPERF 5" Csg Gun, 120 ph 9,189.0 9,209.0 6,655.3 6,669.7 A-3, 3K-17 6/13/1996 4.0 RPERF 2 1/8" EJ; 180 ph; Ort +/- 90 F/Lowside 9,189.0 9,209.0 6,655.3 6,669.7 A-3, 3K-17 4/24/1988 4.0 IPERF 2 1/8 Tornado Link, 90 ph 9,199.0 9,200.0 6,662.5 6,663.2 A-3, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,203.0 9,204.0 6,665.4 6,666.1 A-3, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,205.0 9,206.0 6,666.8 6,667.5 A-3, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,207.0 9,208.0 6,668.3 6,669.0 A-3, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,229.0 9,246.0 6,684.2 6,696.6 A-2, 3K-17 4/24/1988 4.0 IPERF 2 1/8 Tornado Link, 90 ph 9,231.0 9,232.0 6,685.7 6,686.4 A-1, 3K-17 12/8/1986 1.0 RPERF 4" Csg Gun, 0 deg ph 9,244.0 9,245.0 6,695.1 6,695.9 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,253.0 9,254.0 6,701.7 6,702.5 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,258.0 9,259.0 6,705.4 6,706.1 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,263.0 9,264.0 6,709.1 6,709.8 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,275.0 9,281.0 6,717.9 6,722.4 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,275.0 9,281.0 6,717.9 6,722.4 A-2, 3K-17 12/8/1986 1.0 RPERF 4" Csg Gun, 0 deg ph 9,326.0 9,334.0 6,755.9 6,761.9 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,189.0 9,334.0 1 FRAC 6/20/1996 0.0 0.00 0.00 3K-17, 9/19/2023 2:56:34 PM Vertical schematic (actual) PRODUCTION; 30.7-9,512.8 IPERF; 9,326.0-9,334.0 IPERF; 9,275.0-9,281.0 RPERF; 9,275.0-9,281.0 IPERF; 9,263.0-9,264.0 FRAC; 9,189.0 IPERF; 9,258.0-9,259.0 IPERF; 9,253.0-9,254.0 IPERF; 9,244.0-9,245.0 IPERF; 9,229.0-9,246.0 RPERF; 9,231.0-9,232.0 IPERF; 9,207.0-9,208.0 IPERF; 9,205.0-9,206.0 IPERF; 9,203.0-9,204.0 IPERF; 9,199.0-9,200.0 RPERF; 9,189.0-9,209.0 IPERF; 9,189.0-9,209.0 NIPPLE; 9,099.3 PACKER; 9,082.5 PRODUCTION; 9,041.7 IPERF; 8,970.0-8,994.0 PRODUCTION; 8,927.7 PRODUCTION; 8,856.2 PACKER; 8,815.9 TUBING PLUG; 8,718.0 NIPPLE; 8,718.1 OTHER; 8,712.0 PACKER; 8,665.0 LOCATOR; 8,635.8 GAS LIFT; 8,581.7 GAS LIFT; 7,989.3 GAS LIFT; 7,153.4 GAS LIFT; 6,147.7 GAS LIFT; 4,775.2 SURFACE; 37.0-4,761.4 GAS LIFT; 3,153.0 NIPPLE; 524.7 CONDUCTOR; 38.0-115.0 HANGER; 35.0 KUP PROD 3K-17 ... WELLNAME WELLBORE3K-17 STATE OF ALASKA • RECEIVED AiiiikA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS NOV 14 2013 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other GCC Alter Casing r Pull Tubing 17 Stimulate-Frac [ Waiver fl Time Extension Change Approved Program rOperat. Shutdown r Stimulate-Other fl Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Fi Exploratory r _ 186-152 3.Address: 6.API Number: Stratigraphic (l Service P.O. Box 100360,Anchorage,Alaska 99510 50-029-21642-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25629 • 3K-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 9584 feet Plugs(measured) 8839 true vertical 6951 feet Junk(measured) none Effective Depth measured 9426 feet Packer(measured) 8665, 8816, 9083 true vertical 6830 feet (true vertical) 6299,6400,6580 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 4724 9.625 4761 3705 PRODUCTION 9482 7 9513 6897 SCANNE® i'�'_ i. r l Perforation depth: Measured depth: 8970-8994,9189-9209, 9229-9246,9253-9254,9258-9259,9263-9264,9275-9281,9326-9334 True Vertical Depth: 6504-6520,6655-6670,6684-6697,6702-6703,6705-6706,6709-6710,6718-6722,6756-6762 Tubing(size,grade,MD,and ND) 2.875, L-80, 9111 MD,6600 ND Packers&SSSV(type,MD,and ND) PACKER-BAKER FH PACKER W/SBE @ 8665 MD and 6299 TVD PACKER-CAMCO HRP-1-SP PACKER @ 8816 MD and 6400 ND PACKER-BAKER 80-32'DB' PERMANENT PACKER @ 9083 MD and 6580 TVD NIPPLE-CAMCO'DS'NIPPLE @ 525 MD and 525 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development Fi • Service r Stratigraphic fl 16.Well Status after work: Oil F r'.. - Gas r WDSPL fl Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Theresa Lee(cry,263-4827 Email Theresa.M.Lee(c�conocophillips.com Printed Name Theresa Le Title Wells Engineer � Signature 1.-- / n 1 Phone:263-4837 Date 1 I I 1..1. 13 SEE' ■■ li-/e NOVu1 Form 10-404 Revised 10/2012 12//9`/J Submit Original Only Al KUP PROD • 3K-17 ConocoPhillips r Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) t.an,,caphapc 500292164200 KUPARUK RIVER UNIT IPROD 50.78 2,700.00 9,584.0 Comment Date Annotation End Date KB-Grd(ft) Rig Release Date 3K-17.11/1/201310:25:39 AM SSSV:NIPPLE I H2S(ppm)125 1/14/2008 Last WO: 10/31/2013 39.011 8/29/1986 Vertical schematic(actual) Annotation I Depth(ftKB) End Date Annotation Last Mod By End Date ---------- Last Tag:SLM 19,302.0 2/4/2012 Rev Reason:WORKOVER osborl 11/1/2013 HANGER;35.0 b` if Casing Strings 1 4 391'r suo0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth MKS) Set Depth(ND)...Wt/Len(I...Grade Top Thread 1 III CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 37.0 4,761.4 3,704.5 36.00 J-55 BTC jai CONDUCTOR;38.0115.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread In PRODUCTION 7 6.276 30.7 9,512.8 6,896.7 26.00 3-55 BTC NIPPLE;524.7 Tubing Strings Ili Tubing Description I String Ma...I ID 5e) I Top(ftKB) I Set Depth(ft..f Set Depth(ND)(...I Wt(lb/ft) 'Grade ITop Connection FS TUBING WO 27/8 2.411 350 8,77501 6,3726 6.50 L-80 EUE-8rd GAS LIFT;3,153.0 Completion Details ft Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Core (in) 35.0 35.0 0.26 HANGER CAMERON McEVOY TUBING HANGER 2.950 524.7 524.6 2.07 NIPPLE CAMCO'DS'NIPPLE 2.312 SURFACE;37.04,761.4 ® 8,635.8 6,279.3 48.07 LOCATOR BAKER SEAL LOCATOR SUB 2.440 ir GAS LIFT;4.775.2 8,636.8 6,280.0 48.06 SEAL ASSY BAKER 80-32 SEAL ASSEMBLY(OAL=21.05') 2.410 4 8,642.8 6,284.0 48.05 PBR BAKER 80-32 PBR 3.250 I. 8,665.0 6,298.8 47.98 PACKER BAKER FH PACKER w/SBE 2.380 GAS LIFT;6,147.7 8,718.1 6,334.4 47.89 NIPPLE HES X NIPPLE wIRHC BALUROD 2.313 8,767.7 6,367.6 47.91 OVERSHOT BAKER POORBOY OVERSHOT w/5.69'swallow 2.460 5 Tubing Description 'String Ma...IID(in) 'Top(ftKB) Set Depth(ft..l Set Depth(ND)(...I Wt(lb/ft) 'Grade ITop Connection GAS LIFT;7,153.4 TUBING Original 27/8 2.441 8,772.2 9,110.7 6,599.8 650 J-55 EUEBrdABMOD Mil El Completion Details 1.1 Nominal ID GAS LIFT;7,969.3 Top(ftKB) Top(ND)(ftKB) Top Intl(°) Item Des Com (in) 8,798.4 6,388.2 47.92 SBR CAMCO OEJ SBR 2.312 8,815.9 6,400.0 47.90 PACKER CAMCO HRP-1-SP PACKER 2.347 GAS LIFT;8,Se1.7 8,966.7 6,501.3 4764 BLAST RINGS BLAST RINGS(2) 2.441 El El 9,080.6 6,578.9 46.17 SEAL ASSY BAKER G-22 LOCATOR SEAL ASSEMBLY 2.408 LOCATOR;8,635.8 9,082.5 6,580.2 46.13 PACKER BAKER 80-32'DB'PERMANENT PACKER 3.250 SEAL ASSY;8,838.8 PBR;8,642.8 9,086.2 6,582.7 46.07 SBE BAKER 80-30 SEAL BORE EXTENSION 3.250 PACKER;8,665.0 -`'- 9,099.3 6,591.8 45.84 NIPPLE 'CAMCO'D'NIPPLE NO GO 2.250 or- 9,109.9 6,599.3 45.64 SOS CAMCO SHEAR OUT SUB 2.441 III NIPPLE;8,718.1 . Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) M Top(ND) Top Inc! Al Top(ftKB) (ftKB) C) Des Corn Run Date ID(in) • 8,837.0 6,414.1 47.86 CATCHER 2.23x95"CATCHER ON WRP 9/12/2013 0.000 OVERSHOT;8,767.7 8,839.0 6,415.5 47.86 PLUG WEATHERFORD WRP PLUG 9/11/2013 0.000 lir 9,099.3 6.591.9 45.84 VALVE CAT STANDING VLV SET IN NIPPLE 11/16/2010 SBR;8,798.4 . Perforations&Slots PACKER;8,815.9 ' ' Shot Dens CATCHER;8,8370 Top(ND) Btm(ND) (shots# PLUG;8,839.0 / Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn II 8,970.0 8,994.0 6,503.5 6,519.7 C-1,UNIT B, 12/8/1986 12.0 IPERF 5"Csg Gun,120 ph PRODUCTION;8,856.2 3K-17 PRODUCTION;8,927.7 iinl 9,189.0 9,209.0 6,655.3 6,669.7 A-3,3K-17 4/24/1988 4.0 IPERF 2 1/8 Tornado Link,90 I. ph IPERF;8,97 I 9,189.0 9,209.0 6,655.3 6,669.7 A-3,3K-17 6/13/1996 4.0 RPERF 2 1/8"EJ;180 ph;Ort'E/- 068.994.0 90 F/Lowside I� 9,199.0 9,200.0 6,662.5 6,663.2 A-3,3K-17 12/8/1986 1.0 IPERF 4"Csg Gun,0 deg ph PRODUCTION;9,041.7 Ilk 9,2036 9,204.0 6,665.4 6,666.1 A-3,3K-17 12/8/1986 1.0 IPERF 4"Csg Gun,0 deg ph lal SEAL ASSY;9,080.6 - 9,205.0 9,206.0 6,666.8 6,667.5 A-3,3K-17 12/8/1986 1.0 IPERF 4"Csg Gun,0 deg ph PACKER;9,082.5 - 9,207.0 9,208.0 6,668.3 6,669.0 A-3,3K-17 12/8/1986 1.0 IPERF 4"Csg Gun,0 deg ph NIPPLE;9,0993 W 9,229.0 9,246.0 6,684.2 6,696.6 A-2,3K-17 4/24/1988 4.0 IPERF 2 1/8 Tornado Link,90 VALVE;9,099.3, ,®: : ph 5 9,231.0 9,232.0 6,685.7 6,686.4 A-1,3K-17 12/8/1986 1.0 RPERF 4"Csg Gun,0 deg ph SOS;9,109.9 ',Y 9,244.0 9,245.0 6,695.1 6,695.9 A-2,3K-17 12/8/1986 1.0 IPERF 4"Csg Gun,0 deg ph RPERF;9,189.0-9,2090 9,253.0 9,254.0 6,701.7 6,702.5 A-2,3K-17 12/8/1986 1.0 IPERF 4"Csg Gun,0 deg ph IPERF;9,189.0-9,209.0.1 - IPERF;9,199.0-9,200.0-z-: 9,258.0 9,259.0 6,705.4 6,706.1 A-2,3K-17 12/8/1986 1.0 IPERF 4"Csg Gun,0 deg ph - 9,263.0 9,264.0 6,709.1 6,709.8 A-2,3K-17 12/8/1986 1.0 IPERF 4"Csg Gun,0 deg ph IPERF;9,203.0-9,204.0 9,275.0 9,281.0 6,717.9 6,722.4 A-2,3K-17 12/8/1986 1.0 RPERF 4"Csg Gun,0 deg ph IPERF;9,205.0.9,206.0-_ 9,275.0 9,281.0 6,717.9 6,722.4 A-2,3K-17 12/8/1986 1.0 IPERF 4"Csg Gun,0 deg ph IPERF;9,207.0-9.208.0-= 9,326.0 9,334.0 6,755.9 6,761.9 A-2,3K-17 12/8/1986 1.0 IPERF 4"Csg Gun,0 deg ph - Stimulations&Treatments - Min Top Max Btm RPERF;92310-9,2323-=. Depth Depth Top(ND) Bhn(ND) IPERF;9,229.0-9,246.0-' (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn IPERF;9.244.0-9,245.B--7 9,189.0 9,334.0' 6,655.3 6,761.9 FRAC 6/20/1996 A-SAND FRAC-136,7904 propppant behind pipe;left 10009 in wellbore @ 8.1 ppa;13,800#10/40& - 123,9909 12/18 proppant IPERF;9,253.09,2540- Mandrel Inserts St IPERF;9,2580-9,259.0-•-• ati C FRAC;9,189.0 on Top(ND) Valve Latch Port Size TRO Run o IPERF;9.263.09,264.0 No Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m RPERF;9,279.0-9.281.0 7 3,153.0 2,591.9 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/30/2013 IPERF;9,275.0.9,281.0E 2 4,775.2 3,713.4 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/30/2013 3 6,147.7 4,624.6 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/30/2013 IPERF;9,326.0-9334.0-- 4 7,153.4 5,301.6 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/30/2013 5 7,989.3 5,851.6 CAMCO KBMG 1 GAS LIFT SOV BEK-2 0.000 0.0 10/30/2013 1 DC PRODUCTION;30.7-9,512.8 KUP PROD 3K-17 orl ConocoPhillips Alaska.Inc. canocor+rru►s --- 3K-17,11/1/201310'.25:40 AM Vertical schematic(actual) HANGER,35.0 ��ill r icia Mandrel Inserts ati O Valve Latch Port Size TRO Run o M. No Top(MB) T(11KB B Make Model OD(in) Sere Type Type (in) (psi) Run Date m CONDUCTOR;38.0.115.0 . 6 8,581.7 6,243.2 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/30/2013 7 8,856.2 6,427.0 MERLA TMPD 1 PROD DMY BK 0.000 0.0 4/13/2004 NIPPLE;524.7 - — 8 8,927.7 6,475.1 MERLA TMPD 1 PROD DMY BK 0.000 0.0 4/13/2004 111 9 9,041.7 6,552.1 MERLA TMPD 1 PROD DMY BK 0.000 0.0 11/22/2010 Notes:General&Safety GAS LIFT;3,153.0 End Date Annotation 7/27/2010 NOTE:View Schematic w/Alaska Schematic9.0-RKB PROD/TBG DIFFERENT RIGS SURFACE;37.0-4761.4----° * GAS LIFT;4,775.2 GAS LIFT;6,147.7 GAS LIFT;7,153.4 GAS LIFT;7,988.3 GAS LIFT;8,581.7 LOCATOR;8,635.8 F j SEAL ASSY.8,636.6 t�P3� PBR;8,642.8 PACKER;8,665.0 - NIPPLE;6718.1 OVERSHOT;8,767.7 '%. SBR;8,798.4 PACKER;8,815.9 CATCHER;8,837.0 y)� PLUG;8,839.0 PRODUCTION;8,856.2 PRODUCTION;8,927.7 IPERF;8,970.08,994.0 I I 1■ PRODUCTION;9,041.7 L■l� SEAL ASSY;9,080.6 PIP PACKER;9,082.5 NIPPLE;9.099 3-% VALVE;9.099.3• I SOS;9,109.9 sir RPERF;9,1890-9209.0 IPERF;9,189.0.9,209.0., IPERF;9199.0.9,200.0—= IPERF;9,203.0-9,204.0 IPERF;9,2060-9,206.0—) IPERF;9.207.0-9,208.O—•=4 RPERF;8,231.0-9,232.0��� IPERF;9,229.0-9,246.0 IPERF;9,244.O-9.245.O------ IPERF;9,253.0.9,254.0— IPERF;9,258.0-9,259.0--i FRAC;9,189.0 IPERF;9,263.0-9,264.0----.—' RPERF;9,275.0&,281.0 IPERF;9,275.0-9.281.01�� IPERF;9,326.0-9,334.0—' PRODUCTION;30.7-9,512.8 3K-17 Pre Rig Well Work Summary • • DATE SUMMARY 9/9/2013 RAN 1.90" DRIFT TO TD @ 9283' RKB, MADE SBHP STOP @ 9250' RKB FOR 30min (4247 PSI 162.9 DEGREES) IN PROGRESS 9/10/2013 DROPPED 2.29"AVA CATCHER, PULLED RK-DGLV FROM STA#6 @ 8748' RKB, BK-OGLV FROM STA# 3 @ 6988' RKB & BK-LGLV's FROM STA#2 @ 5560' RKB &STA# 1 @ 3090' RKB, SET BK-DGLV's IN STA# 1 @ 3090' RKB &STA#2 @ 5560' RKB, IN PROGRESS 9/11/2013 SET BTM-DGLV IN STA#3 @ 6953' SLM/6988' MD, PULLED 2.29"AVA CATCHER FROM D-NIP @ 9045' SLM/9099' RKB, SET 2.25"WFD WRP @ 8839' RKB, LRS PERFORMED PASSING CMIT-TxIA @ 3000psi, IN PROGRESS. NOTE: BLED TBG DOWN FROM 1800 PSI TO 225 PSI, IA FROM 1750 PSI TO 300 PSI. 9/12/2013 SET 2.23"X 95" CATCHER ON WRP @ 8839' RKB. JET CUT TUBING @ 8773' RKB. SET 2.35"X 174" (1.81" ID) HOLD OPEN SLEEVE IN TRDP-1A @ 1824' RKB.WELL READY FOR DHD NOTE: TBG ONLY CAME UP 25 PSI OVER NIGHT, GAS BREAKING OUT AT SURFACE. 9/13/2013 (PRE-RWO)T POT- PASSED; T PPPOT- PASSED; IC POT- PASSED; IC PPPOT- PASSED; MITOA- PASSED; FUNCTION TESTED T LDS ALL FUNCTIONAL • Conoco hillips Time Log & Summary Wellvlew Web Reporting Report Well Name: 3K-17 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 10/25/2013 11:00:00 PM Rig Release: 10/31/2013 6:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/25/2013 24 hr Summary Release rig from 3K-35 at 18:00hrs. PJSM on moving rig. Pull off of 3K-35. Place liner and mats around 3K-17, Hang tree in cellar and place new tubing spool behind well. Lay mats in front of rig. Conduct CPAI Rig acceptance check list.Accpet rig at 23:00hrs 10/25/2013 18:00 21:00 3.00 0 0 MIRU MOVE MOB P PSJM on moving rig,take down berming, lift up stairs.Jack rig up. DSO on site, pull off of 3K-35. Remove rig mats, liner and cellar mats. Confirm well secure on 3K-17. Lay liner and set"T"mats. Set rig mats for the rig proper. 21:00 22:00 1.00 0 0 MIRU MOVE MOB P Hang tree in cellar. Spot equipment behind well head. Clean cellar on 3K-35 22:00 23:00 1.00 0 0 MIRU MOVE MOB P Pull rig over 3K-17 and set down. Confirm centered over wellhead. Accept rig @23:00 hrs 10/25/2013 23:00 00:00 1.00 0 0 COMPZ RPCOM KLWL P Hook up lines to the kill manifold, tree, and IA. Connect lines to kill tank. Begin take on fluid in pits. IA-300psi OA-450psi 10/26/2013 Continue to take on fluid to the pits. Test lines to the kill tank. Pull BPV. Killed well. Set BPV and tested from below 1000psi 10min. N/D tree. N/U BOPE. Tesrt BOPE to 250/3000psi. State waived right to witness test. Rig down test equipment. Hold AAR on BOP testing. 00:00 04:30 4.50 8,773 8,773 COMPZ RPCOM MOB P Continue to take on fluids for well control&klill , RU lines 04:30 05:00 0.50 8,773 COMPZ RPCOM SFTY P Pre-Spud meeting 05:00 05:30 0.50 8,773 8,773 COMPZ WELCTL MPSP P Pulled BPV 05:30 09:00 3.50 8,773 8,773 COMPZ WELCTL KLWL P Opened up well SITP= 160 PSI. SIAP=270 PSI, OA=450 Psi. Intinal CP= 1100 Psi @ 4.5 BPM. Circulated 474 BBLs of 8.6#brine FCP=855 Psi. SD pumps 0 PSI both sides. Bleed OA to kill tank. 09:00 10:00 1.00 8,773 8,773 COMPZ WELCTL OWFF P Monitor well for flow for 30 min.s 10:00 10:30 0.50 8,773 8,773 COMPZ WELCTL MPSP P Installed BPV and tested to 1000 PSI. in direction of flow for 10 min's good test. 10:30 12:30 2.00 8,773 8,773 COMPZ WHDBO NUND P PJSM ND tree 12:30 16:00 3.50 8,773 8,773 COMPZ WHDBO NUND P NU BOPE and hook up lines. Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 23:00 7.00 8,773 8,773 COMPZ WHDBO PRTS P PJSM test BOPE 250/3000 PSI (1)Blinds , Stand pipe kill , choke 4,11,12, 3.5 IF dart,TD Hyraulic UKV. Passed (2) BR, Kill HCR,Lower TD , 3.5 IF FOSV, Choke 3,7,9,10 Fail/Passed (Gray Lock Leaked on choke side high test) (3)3 1/2"LPR, 3.5 FOSV 8rd, Choke 2,5,8 Fail/Passed(3 1/2"8rd FOSV failed, replaced with new, CV 8 failed Re-greased) (4)3 1/2"Annular, Man Kill, 3.5 FOSV 8rd, Choke 6. Passed (5) UPR W/3 1/2"TJ Manual Kill, Choke HCR Passed (6) UPR 3 1/2"TJ, Manual Kill, Manula Choke Passed (7)2 7/8" LPR Passed (8)2 7/8"Annular, Manual Kill, CV 2,5,6 Passed (9)2 7/8"UPR Manual Kill, Choke valve#1 Passed Accumulator test. Initial-3000psi Actuate all BOP(function upper pipe rams 2x's for blinds)1900 psi First 200psi-16sec Final 3000psi-86sec Ann. closing time 16sec Upper,Lower Ram closing time 4sec. each 4 N2 bottles @ 2000 psi Electric pump kick on at 2800psi off at 3000psi Air pump kick on at 2600psi off at 2700psi Tested Methane and H2S monitors-Good Checked flow show&pit level indicator equipment-Good 23:00 23:30 0.50 8,773 8,773 COMPZ WHDBO PRTS P Rig down test joints, blow down lines. Allign stack and choke valves for Well operations. Close IA valve. Continue to bleed OA 23:30 00:00 0.50 8,773 COMPZ WHDBO SFTY P Conduct AAR on BOPE testing, captured lessons learned and best practices. 10/27/2013 Pull test dart and BPV, Make up landing joint. BOLDS. Pull hanger free. Circulate hole volume 7bpm. Flow check. Pull out of hole laying down 2 7/8"J-55 tubing inspecting for corrosion. Stop and condition fluid at 8,000'. Continue to pull ouf of hole laying down spooling up SSSV control line. Set storm packer at 4596'and test. N/D BOPE. N/D tubing spool using Hydratight system. 5 1/4"of casing growth. Pull and re-land 7" casing with 75k in tension. Remove remainder of tubing spool studs. Page 2 of 6 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 8,778 8,778 COMPZ WHDBO THGR P Pump out stack. Verify Opsi on IA. Pull test dart and BPV. 01:00 02:30 1.50 8,778 8,778 COMPZ WHDBO THGR P PJSM, Make up landing joint to hanger and top drive. BOLDS.Verify no pressure on IA. Unseat hanger at 55K free travel at 80K Pull tight at 110k 20' up.Work back down. 02:30 03:30 1.00 8,778 8,778 COMPZ RPCOM CIRC P Circulate 320bbls surface to surface at 7bpm 1820psi. Work pipe back up to tight spot and pass clean while circulating. Rig up Camco SSSV spooling unit. 03:30 04:00 0.50 8,778 8,778 COMPZ RPCOM OWFF P Flow check well. 04:00 06:00 2.00 8,778 8,000 COMPZ RPCOM PULL P POOH with production string laying down . Recovered 32 SS bands of 33 that were originally run. 06:00 07:30 1.50 8,000 8,000 COMPZ RPCOM CIRC T well out of balance small up tubing. Circulated 50 BBLs of 8.6#brine down tubing.well in balance. 07:30 08:00 0.50 8,000 8,000 COMPZ RPCOM OWFF T monitor well for flow 30 min 08:00 15:00 7.00 8,000 4,491 COMPZ RPCOM PULL P Continue to POOH laying down production equipment. 15:00 17:30 2.50 4,491 4,596 COMPZ RPCOM OTHR P Prep floor for storm packer. PJSM. PU 7"26#Baker R3 storm packer. RIH with packer. Had to work the packer into the well head do to bending. Set packer @ 114 ft with 20K tubing wieght below. Laid down setting t000l. 17:30 18:00 0.50 4,596 4,596 COMPZ RPCOM PRTS P Pressure test packer to 2750 PSI for 10 min's. 18:00 21:00 3.00 4,596 4,596 COMPZ RPCOM NUND P Blow down lines. De-energize accumulator. _Nipple down BOPE stack. 21:00 22:30 1.50 4,596 4,596 COMPZ WHDBO NUND P Confirm OA is zero and open to atmosphere. Bleed off void. Use Hydratight system and control release casing growth on nipple down of tubing spool. Pack off came out with tubing spool. Total casing growth of 5 1/4". 22:30 23:30 1.00 4,596 4,596 COMPZ WHDBO CUTP P Make up 7"26#spear assy. Engage 7"casing. Pull 100k up reset slips and land with 75k in tension. Lay down speer assy. 1'pulled up in addition to 5 1/4"of growth. 23:30 00:00 0.50 4,596 4,596 COMPZ WHDBO CUTP P Remove remainder of Tubing spool studs from well head flange. 10/28/2013 Made cut on 7"with Wachs cutter. Install pack-off. Make up tubing spool and tighten same. Test pack-off to 250/3000psi 10minutes each test. N/U BOPE. Test breaks to 250/3000psi. Pull test plug. Pull Storm Packer. Cont.to lay down completion. Install Wear Bushing. Make up dress off assembly. Page 3 of 6 • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 4,596 4,596 COMPZ WHDBO CUTP P Make cut on 7"pipe with Wachs cutter. Cut off 12.4375" 01:30 03:30 2.00 4,596 4,596 COMPZ WHDBO WWSP P Install pack-off and tubing spool. Tighten bottom flange on tubing spool. 03:30 04:00 0.50 4,596 4,596 COMPZ WHDBO WWSP P Test pack-off to 250/3000psi for 10min each. Bottom flange on tubing spool 3000psi 80%7"J-55 casing colapse 3464psi 04:00 09:00 5.00 4,596 4,596 COMPZ WHDBO NUND P Nipple up BOPE, choke and kill lines. 09:00 10:00 1.00 4,596 4,596 COMPZ WELLPF PRTS P Body test BOPE 250/3000 Good test. 10:00 11:00 1.00 4,596 4,596 COMPZ WELLPF OTHR P Picked up retriving tool. Released storm packer 11:00 19:00 8.00 4,596 0 COMPZ RPCOM PULL P Laid down packer&continue to lay down production equipment. Cut joint 14.44 max od of flare 3.25" Tally out of the hole 8770.88' 19:00 20:00 1.00 0 0 COMPZ RPCOM OTHR P Clean and clear rig floor 20:00 20:30 0.50 0 0 COMPZ RPCOM OTHR P Install wear ring. 6 1/4"ID, 6 15/16" OD, 9 3/8"long 20:30 22:00 1.50 0 230 COMPZ RPCOM TRIP P Picked up BHA#2 Dress off Mill/ scraper assembly 22:00 00:00 2.00 230 2,213 COMPZ RPCOM TRIP P Trip in the hole with 3 1/2"PH-6 Work string assembly. 10/29/2013 Trip in hole with dress off mill assy, tag top of tubing stub @ 8769' RKB. Set 5K down, mill and dress stub, wash down to 8779'. Pump Hi Visc sweep, chase with 350 bbls @ 6 bpm, 1300 psi. Flow check-TOOH sideways with workstring. Lay Down BHA at surface,good inspection, light metal debris and sand in bootbasket. P/U 2 7/8"Completion string as per procedure. 00:00 04:30 4.50 2,213 8,725 COMPZ RPCOM TRIP P Trip in hole with 2 7/8"dress off mill/scraper assy. on 3 1/2" PH-6 workstring 04:30 06:00 1.50 8,725 8,770 COMPZ RPCOM MILL P Tag tubing stub at 8770', begin to dress off. Up wt-130k Dn wt-100k Rot wt-113 Rpm-60 Tq-2700 Rate-6bpm Pressure-1400psi 06:00 08:00 2.00 8,770 8,780 COMPZ RPCOM CIRC P Pumped 30 BBL hi-vis sweep. Worked tubing down to 8779' 08:00 08:30 0.50 8,780 8,780 COMPZ RPCOM OWFF P Monitor well 30 mins. 08:30 20:30 12.00 8,770 0 COMPZ RPCOM PULL P POOH laying down 3.5"PH-6 hydril work string and BHA#2 Mill assembly. Lay down&inspect BHA @ surface. Good, had light metal debris and sand in boot basket. 20:30 22:00 1.50 0 0 COMPZ RPCOM PULD P Pull Wear ring, clean up rig floor, drain stack. Strap and setup completion string in running order as per procedure. Page4of6 j • Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 0 1,200 COMPZ RPCOM PUTB P PJSM-P/U completion string. Pull wear bushing while lowering Packer through wellhead, clear drift. Install- continue TIH with Completion string. 10/30/2013 TIH with 2 7/8"completion string down to 8770' locate top of fish. Circulate 240 bbls of corrosion inhibitor. Station packer, No-go 8775'set 5K. P/U weight 84K, down weight 69K. Drop ball&rod,wait 30 minutes,try to get to seat/test RHC plug. Continue to leak off, called out SL, RU and RIH,tagged up at 2600'-continue to RIH,tapped down into place. Pressure up to 1500 psi, POOH with SL. Space out and set packer @ 8775' @ 2600 psi. Space out 6' PBR, P/U tubing hanger and set in place. Test tubing 3000 psi/30 minutes, IA 3000 psi/30 minutes. Good test, Shear SOV @ 1680 psi. 00:00 06:00 6.00 1,200 8,750 COMPZ RPCOM PUTB P Continue TIH with 2 7/8"Completion string. 06:00 08:00 2.00 8,750 8,750 COMPZ RPCOM CIRC P Circulate Inhibited Brine around backside prior to setting packer. 08:00 08:30 0.50 8,750 8,750 COMPZ RPCOM OTHR P Droped ball&rod spaced out Poorboy overshot. Let rod fall. 08:30 12:00 3.50 COMPZ RPCOM PACK P attempted to pressure up on RHC plug to set packer.Able to circulate @ 2 BPM @ 670 psi.worked tubing up&down to shake rod free. Re- pressure up hit 1500 Psi. Pressure drop right off. reversed 5 BBLs to clear any dope. Re pressured up able to circulate @ 2 BPM @ 590 psi. 12:00 14:30 2.50 COMPZ RPCOM PACK T Call out slick line to attempt to seat Ball/rod or pull. 14:30 17:30 3.00 COMPZ RPCOM SLKL T Spot HES slick line unit up to rig. PJSM RU HES slick line. RIH with 2" Graple catch with shear down. 17:30 19:00 1.50 COMPZ RPCOM SLKL T RIH with SL, tap down on ball&rod. Test to 1500 psi for 5 minutes. Disconnect from ball/rod while holding 1500 psi. POOH with SL,set aside while setting and testing Packer. 19:00 21:00 2.00 8,775 8,775 COMPZ RPCOM PACK P Pressure up and set packer-2500 psi, hold for 10 minutes. Test to 1000psi on backside-good test. Release SL. Pressure up 1500 psi and P/U on PBR shear @ 105K. String weight 84K. Bleed off pressure, space out 6 ft. Mark pipe, lay down pipe and P/U landing jiont with tubing hanger. 21:00 00:00 3.00 8,775 0 COMPZ RPCOM PRTS P Roll C-pump, slowly land tubing hanger in place and seal assembly. RILDS. Pressure test tubing to 3000 psi/30 minutes. bleed down to 2000 psi,test IA to 3000 psi/30 minutes. Good tests. Bleed down and pressure up on SOV,sheared at 1680psi. 10/31/2013 Set BPV,test-failed, pull BPV. Set second BPV test to 1000 psi. ND BOPE, NU tree test 250/5000psi. Freeze protect well, equalize. Set BPV. RDMO. Rig release 18:00 hrs Page 5 of 6 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 0 0 COMPZ WHDBO MPSP T Install BPV, pressure up to 1000 psi. BPV leaked by. Drain stack to retrieve. BPV laying across hanger neck. Call out for magnet, retrieve and inspect. Threads are good, must not have been fully engaged. 03:00 04:00 1.00 0 0 COMPZ WHDBO MPSP P Set new BPV-test to 1000 psi. hold for 15 minutes. 04:00 07:30 3.50 0 0 COMPZ WHDBO NUND P Jet BOPE stack, ND BOPE. Clean final pit. 07:30 09.30 2.00 0 COMPZ WHDBO NUND P NU tree adaptor and tree. 09:30 10:00 0.50 COMPZ WHDBO PRTS P Test adaptor tto 250/5000 psi good test fuction open Surface Safety valve. 10:00 12:00 2.00 COMPZ WHDBO PRTS P Test tree to 250/5000 psi&chart. 12:00 12:30 0.50 COMPZ WHDBO MPSP P Pulled BPV 12:30 15:00 2.50 COMPZ WHDBO FRZP P PJSM RU LRS.Frezze protect well to 2000 ft with 85 BBLS of Diesel. RD LRS 15:00 15:30 0.50 COMPZ WHDBO FRZP P Let well equalize. O psi on both sides. 15:30 17:30 2.00 COMPZ WHDBO MPSP P Installed BPV and SWI. 17:30 18:00 0.50 COMPZ MOVE MOB P PJSM-Rig release 18:00 hrs. Page 6 of 6 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 6, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 3K -17 Run Date: 10/27/2009 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 3K -17 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 21642 -00 20 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating 2 Attn: Rafael Barreto 6900 Arctic Blvd. f t-( Anchorage, Alaska 99518 Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barreto @halliburton.com NOV r Date: NOV 3 a O y Signed: j ~ ~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 3K-17 Run Date: 8/31/2009 September 11, 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 3K-17 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21642-00 ~~.'~, ~;':~:~ _ .. y'..~~_,; ~~~~5 ~ ' ~ ~~~~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perfarating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 90?-273-3~35 rafael.barreto@halliburton.com ` Date: ~ ~ " a ~ ; ~ ;" Signed: ~ ~~ ;~'~ a, ~~ ~ ~ ~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 3K-17 Run Date: 8/17/2009 September 11, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Baneto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K-17 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21642-00 ::. : _ ~R (~i '.~'~ 1 1 , «~ \ 3 ~ f! ,~ _ 4 1 v+.Ni _ .. .. . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael . b arreto@halliburton. com Date: ` , . l~~~~~~ l`~~~3 ~, iJ~' l Signed: r' " '~'~ %}'...._ . • ~~t~~1, ~ T. t,~~~ i'~~''~'=~1 T:~11~17rT'F~~ ~,IDo ~laslca ~il ~nd ~ias ~~ns~~i~~i~n ~~~?~r?o Agt~,: ~hristin~ I~ilahnlc~r~ 3~s ~J~T~s~ 7ih ~~~,n~~, ~ui~~ l~t~~ ~~ic?~o~~g~, ~las~~~, ~95~~ RE: Packer Setting Record: 3K-I~ ~ul~ 27, 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 3K-17 ~~~ -- I~~ ~ ~ ~~~ 1 CD Rom =~~w`~.`~;~a~~,~,~ .'`.{~~. .. _ ~{.~~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton. com ~ Date: Signcd: ~ ~ Digital Data in LAS format 50-029-21642-00 ~,/ C~ Uif,~LL LL7~ TRA/1f~IVI/TT,4L '. P DiRgNOS~ic SeRwccs, Iwc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 859-5102 • RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transm'~ttal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road `'z,~~'~c°~ii,~~~ ~{'1 ~~ ~~~ Suite C Anchorage, AK 99518 Fax (907j 245-6952 1) Caliper Report 09,Jun-09 3K 17 1 Report / E~ 50-029-21642-00 2) PHONE: (9071245-8951 Fwc: (90712/6-88852 E-/NAIL : pdsanchoraaeCc~memorvlog.com WEBSIrE : www.memorvloa.com C:~Documet~ and Settings~ownet~Desxwp~ransmif_c~oco.aonc • • Memory Muni-Finger Caliper Log Results summary Company: ConocoPhillips Alaska, Inc. Well: 3K-17 Log Date: June 9, 2009 Field: Kuparuk Log No.: 7334 State: Alaska Run No.: 3 API No.: 50-029-21642-00 Pipet Desc.: 2.875" 6.5 Ib. J-55 EUE 8RD ABMOD Top Log Intv11.: 6,308 Ft. (MD) Pipet Use: Tubing Bot. Log Intvl1.: 8,894 Ft. (MD) ~ Inspection Type : Comasive 8 Mechanical Damage Inspection ' COMMENTS This caliper data is tied into the top of Production Mandrel 7 ~ 8,856' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 2.875" tubing logged is in good condition, with the exception of a 25°~ wall penetration recorded at an isolated pit in joint 217 (7,076'}. No significant areas of cross- , sectional wall loss or LD. restrictions are recorded throughout the tubing logged. The caliper recordings indicate slight buckling throughout the interval of 2.875" tubing logged. This is the third time a PDS caliper has been run in this well and the 2.875" tubing has been fogged. A ' comparison between the current and previous log (February 15, 2004) indicates no increase in corrosive damage during the time between logs. A comparison graph illustrating the differences in maximum recorded penetrations on a joint-by joint basis between logs is included in this report. MAXIMUM RECORDED WALL PENETRATIONS : Isolated Pit (25°~) Jt. 217 @ 7,076 Ft. (MD) No other significant wall penetrations (> 14°~) are recorded throughout the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS ' No significant areas of cross-sectional wall loss (> 6°~) are recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS '' No significant LD. restrictions are recorded throughout the interval logged. III' Field Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: S. Ferguson PrcActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford. TX. 77497 Phone: (281) or (888) 565-40$5 Fax: {281) 565-1369 E-mail: PDSia?memarylag.cam Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (90i') 659-2314 ~~1 • • Maximum Recorded Penetration ti ~~~~ Comparison To Previous Well: 3K-17 Survey Date: June 9, 2009 Field: Kuparuk Prev. Date: February 1 5, 2004 Company: ConocoPhillips Alaska, Inc Tool: UW MfC 24 No. 218370 Country: USA Tubing: 2.87.1 6.5 Ib J-55 FUf SRD AB Overlay 0 5 Max Rec 0 1 . Pen. (m 00 1 ils) 50 2 00 195 205 214 224 234 ~ Z c 0 243 2 53 262 269 ~~.~,. .! : (1110 (,,1,~ i i,if, ' 1, rf 111 __ 1 Difference -100 -5 Diff. in Max 0 . Pen. (mils 0 5 ) 0 100 205 i 214 -- 224:.. 4 iv ~ 234 Z c O 243 {~ d ~ I v 253 262 269 -19 -9 0 9 19 Approx. Corrosion Rate (rnpy) • • PDS Report Overview ~~ ~~ Body Region Analysis Well: 3K-17 ~ Survey Date: June 9, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal sL• C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 2.875 ins 6.5 f -55 EUE 8RD ABMOD 2.441 ins 2.875 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body Moll metal loss body 60 40 0 2 0 0 to 1 to 10 to 1% 10%° 20% 20 ro 40 ro over 40% 85% 85% Number of 'oints anal se d rotal = 77 pene. 0 57 19 loss 24 53 0 1 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ihle hole Number of 'oints dama ed total = 1 1 0 0 0 0 Damage Profile (% wall) ~ penetration body ~_.: metal loss body 0 50 100 198 GLM 3 235 GLM 4 GLM 5 GLM 6 PROD 7 Bottom of Survey = 2 71 Analysis Overview page Z • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE SRD ABMGWeII: 3K-17 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: June 9, 2009 Joint No. Jt. Depth (Ft.) I'en. Ul~tic~t Unc.'~ Pen. Body (Ins.) Pen. °% Vlc~tal Ioti~ ~, Min. LD• (Ins.} Comments Damage Profile (%wall) 0 50 1UU 195 6340 U 0. 3 14 .36 Sli t ckli 196 6372 t) 0. 1 4 _' 2.36 197 6405 U 0.02 I1 ~ 2.40 198 6437 U 0.03 12 -I .37 99 6470 tt 0.01 f> 2.39 Sli ht BucMi 2 0 650 n 0.02 ~' S 2.39 e o 'ts. 201 65 3 u 0.03 I ? 2.39 202 6566 U 0.01 ~ 2.40 203 6598 a 0.01 r> 2.36 2 4 66 0 U 0.03 14 ~. 2.36 Sli ht Bucklin . 05 663 U 0.03 1 ~1 2. 7 2 6 696 U 0. I U _) 2.36 07 67 8 U 0.02 ~ ,' 2.40 208 6761 U 0.0 11 4 2. 9 i ht uckli 209 6 94 U 0.02 11 5 2.39 210 6824 U 0.03 14 5 .38 Lt. De sits. 211 6857 ti 0.01 6 ~ 2.37 Lt. De osits. 212 6889 U 0.0 9 2.40 1 6920 U 0.02 8 2.41 14 6952 U 0.02 ~) 2. Sli t Bucklin . 214. 69 6 U 0 0 n N A GLM L tch 10:3 215 6993 U .OZ ~ -! 2.41 16 7025 tt 0.03 12 s .37 217 7058 U 0.05 25 -t 2.41 Isolated ittin . 18 7 91 It 0. ~ 9 219 7122 U 0.02 ~ 2.38 Sli ht Bucklin . 220 7152 U 0.01 I 2.37 221 7184 a 0.02 1 U 2.38 222 7215 I) 0.01 2.3 223 7245 U 0.01 6 I 2.35 24 7277 U 0 02 9 5 2 36 Sli t cklin . 225 7308 a 0.02 10 U 2.37 6 7339 U 0.01 4 2.40 Z27 7372 ~ ~ 0.02 8 ~ 2.40 228 7404 U 0.01 7 2.37 Lt. De osits. 229 7437 n 0.02 10 ~ 2.36 30 7470 U 9 I 2.41 Sli ht Bucklin . 231 7502 U 0.03 12 ~ 2.35 232 753 t~ 0.0 1U I 2.37 233 7566 t ~ 0.02 9 4 2.42 234 7598 t ~ 0.01 4 2.39 235 7631 U 0.01 t, _' 2.40 Sli ht Bucklin . 36 7664 U 0.02 ~3 I .38 2 7 7697 U 0.01 3 I 2.36 3 7729 U 0.01 3 I 2.38 239 7761 ti 0.02 ~) 2.39 239.1 7793 ~~ 0 0 tl N A GLM Latch ~ 3:00 240 7800 a 0.01 4 I 2.37 Sli ht Bucklin . 1 7833 i ~ 0.0 3 I .3 242 7865 ~ ~ 0.02 1 1 2.35 ,~ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf )-55 EUE 8RD ABMGWeII: 3K-17 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: June 9, 2009 Joint No. Jt. Depth (Ft) Pen. Ul,yet Iln~.) Pen. Body (Ins.) 1'c~n. °io ~tc•t,rl Loss °~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 243 7 9 t t 0.01 V ? 2.38 2 7 3 tt 0.01 G 2.40 245 79 3 (1 0.01 I .38 246 7995 U 0.02 tS ! ~ 2.38 Sli ht Bucklin 247 8027 U 0.01 -1 I 2.38 248 8059 tt 0.01 4 I 2.36 249 8092 t t 0.01 (~ I 2.39 250 8125 r t 0.02 ti I 2.38 251 81 7 (t 0.03 12 1 2.35 252 8189 a 0.01 4 ! .37 Sli ht Bucklin . 53 8221 a 0.02 8 It 2.38 54 8254 U 0.01 b t 2.38 Lt. De osi 254.1 8286 tt 0 tt U N A GLM 5 Latch ~ 3:00 255 8293 U 0.03 1 ; 2.32 Lt. De osits. 256 8326 U 0.01 i r? 2.36 257 8359 tt 0. 1 (~ I 2.38 Sli ht Bucklin . 258 8392 t t 0.02 t3 ~' 2.39 259 8423 U 0.01 0 2.34 60 8458 (1 0.02 't 2.38 61 8489 t t 0.01 ~ ~ i .38 262 8523 tt 0.02 1 1 1 2.36 Sli ht Bucklin . 263 8554 (t 0.02 ti 2.37 264 8585 It 0.02 I I n 2.35 t. De osits. 265 8619 U 0.01 - 2.39 66 8650 c t 0.01 (~ t ~ 2.34 267 8684 tt 0.02 11 2.38 Sli ht Bucklin . 268 8716 tt 0.02 1 1 _' 2.32 Lt. De osits. 268.1 8749 tt 0 (t (t N A GLM 6 Latch @ 11:00 269 8759 t t 0.01 ~1 _' 2.37 269.1 8791 1) 0 tl U 2. 1 Camco 'OE ' SBR 69.2 881 I t 0 t t U 2.35 Carr co 'HRP-I-SP' Packer 270 8824 U 0.03 1 d u 2.36 Sli ht Bucklin . 70.1 8856 U 0 tt U N A Production ndrel 7 Latch ~ 2:00 271 8863 U 0.02 `~ ~ 2.38 _ Penetration Body Metal Loss Body Page 2 PDS Report Cross Sections Well: 3K-17 Survey Date: June 9, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers; Z4 Tubin 2.875 ins 6.5 f -55 EUE 8RD ABMOD __ Analyst: C. Waldrop Cross Section for Joint 217 at depth 7075.843 ft Tool speed = 43 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 98 Tool deviation = 53 ° Finger 5 Penetration = 0.054 ins Isolated Pit 0.05 ins = 25% Wall Penetration HIGH SIDE = UP i • Cross Sections page 1 Kur 3K-7 7 ConocoPhillips +~ ~ ~ ~ ~ ~ AI, ,,, it . .--~ ._ W are eld ame Well SYetus 500292164200 KUPARUK RIVER UNIT PROD n ( 50.78 2,700.00 9,584.0 _.. - -. Comnelt 2C tppn) Dne Amolatlan -Ord Rip Neese e SSSV: TRDP 125 7112008 Last WO: 39 07 8/29/7986 0 5 01 ~I u1 hM - A/egtanon Depm 1 Dane Atnodtlon . B70 Dale Last Tag; ELMD 9.292.0 129/2009 Rev Reason: GLV C/O. TAG 2/22009 las Strin CONDUCTOR, 115 ~9 Dew MI g(~g ltil t Sel Depm l~al Set Dlp1117TVD) l~l ~~q ~~ T 7trA sarory valve, 1,a2a o. CONDUCTOR 1 6 15.062 0.0 115.0 115.0 62.60 Hd0 SURFACE 95 18 8.765 0.0 4.761.0 3.704.2 36.00 Jb5 GAS LIFT. PRODUCTION 7 6.151 0.0 9,512.0 6.896.2 26.00 J-55 3090 ~ Tubl Strl s suRFACe. ce ~ 1 en ~ ~~~ ~) ~ ~sl pncq Iloanq a ax x tep ma GAS LIFT. TUBING 27 /8 2.441 0.0 9,111.0 6, .1 6.50 J35 EUE8RD M... 5'50° Other I n Hok A ll Jevtw l : T Run 8 RetTiev Fish etc. GAS LIFT, 6 988 toP Top DepBt 1ND) mKS1 Top etG rl DesagMon eommaR Ran ale ID lW 1,824.0 1,687.7 41.33 S afety Valve Cameo TRDP-IA-SSA' 12l&1986 2.310 PATCN 7045 3,090.0 2, 6.5 44.87 G AS LIFT ERL/VTMPD/1/DMVBK//! Comment: STA 1 1730/2009 2.375 PATCH, 7,0]2 5.560.0 4,227.6 48.08 G AS LIFT MERLARMPD/t/ MY K!!/ConrrenC STA2 1/30!2009 2.375 8, .0 5,192.9 48.92 G ASU MERLA/TMPD7IIDMYBK///Cortxltent: S A3 17312009 2.375 7.045.0 5,230.4 48.96 P ATCH TOP ECLIPSE PACKER ASSEMBL W!S ACKER SNAP 8/122004 1.320 GAS LIFT, 7 794 LATCH ASSEMBLY (OVL 34.35' W/1.320" ID) 7,072.0 5,248.1 48.93 P ATCH TTOM ECLIPSE PACKER WIMID ELEMENT 6(/2004 1.468 GAS LIFT, 7 794.0 724.7 5 49 45 G AS LIFT MERLA/fMPD/1/DMYBKIi/Comment: STA4 6112004 2 375 8.287 , , . . 8,287.0 6,047.3 48.T/G AS LIFT MERLA7TMPD/1/DMYBKlII Comment STAS 926/1 2.375 GAS UFr, 8 ]48 8,748.0 6,354.5 48.00 G AS LIFT MERLA/TGPD/1.5lDMY/RK//7 Canmart: STAG 5JJ72004 2.375 . 8,798.0 6,388.0 47.92 S BR Camco'OEJ' SBR 12!817986 2.313 SaR e 79a 8,816.0 6,400.2 47.94 P ACKER Carnco'HRP-137 PACKER 121811986 2.347 , . 8, 56.0 6,426.9 47. P RO ION M RLA/TMPD/1/DMY/BK/I/Comment: STA7 411 2.375 _ 8,9 8.0 6,475.3 4 .71 P RODUCTION M RLNTMPDIIIDMYBK/// Comment: STA 8 4/132004 2.375 PACKER, 6,816 9,042.0 6,552.8 46.93 P ROWCTION MERLA7TMPQ'1/DMV/BK/// Comment: STA 9 4/1312004 2.375 9,083.0 6,580.6 46.15 P ACKER Baker'DB' PACKER 12/8/1986 3.250 PRODUCTION, 9 099 0 6 591 7 45 8 N IPP E amca'd Nipple GO 12!811 86 250 2 a.ass , . . . . . 9.110.0 6,599.3 4 .64 S O Cameo 12/8/1986 2.441 PROOUCr1oN. 8.928 9,111.0 6,600.1 45.62 T TL 11/8/1986 2.441 Petlora tions IPERF, &1et e,s7o5,s9a T~1~yD) !6n^~ pqa Top IRNBI B6n Mml plKel Zone Dete leh- Cannleat PRODUCTION. 8,970.0 8,994.0 6,503.6 6,519.7 C -1, UNR B, 1218!1986 12.0 IPERF 5" Csg Gun. 120 ph 9,042 3 K 17 9,189.0 9,209.0 6.655.3 8,669.6 A -3, 3K-17 4124/1988 4.0 IPERF 2 118 Tornado Lilt 90 ph PACKER, 9,083 9.189.0 9.209.0 6,855.3 6,869.6 A -3, 3K-17 Nt3/7996 4.O RPERF 21/8"EJ; 180 ph; Ort+/-9D F/Lowside 9 199.0 200.0 9 6 662. 6 663.1 A J 3K-77 111&1986 1.0 IPERF 4" Csg Gun 0 deg ph NIPPLE, sp9s . , . . , , 9,203. 9,204.0 6,666.3 6,666.0 A J. 3K-17 12/817986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,205.0 9,206.0 6.666.7 6, .4 A -3. 3K-17 12/8/1 7.0 IPERF 4' Csg Cxn. 0 deg ph sos, 9,110 9,207.0 9.208.0 6,668.2 6,668.9 A -3, 3K- 7 11/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph rrL, e,»1 9,229.0 9,246.0 6,884.1 8,696.6 A -2, 3K-17 424/1988 4.0 IPERF 2 tl8 Tomado Lnk 90 ph IPERF, 9,1895,209 9,231.0 9,232.0 6,885.6 8,686.3 A -1, 3K-17 12/8!7986 7.0 RPER 4" C Gun, 0,4,,,~ ~ "ON ph s.lasasos 9.244.0 9,245.0 6,69 .1 6,695.8 A -2.3K-17 12/8!1986 1.0 IPERF 4" sg Gun, 0 deg ph y,lyyy sou 9,253.0 9,254.0 6,701.7 6,702.4 A -2. 3K-17 11/8/1986 t.0 1PERF 4"Csg Gun,Odeg ph 9,258.0 9,259.D 05. ,06.1 A - , 3K-17 1 8/1986 1.0 IPERF 4" Csg Gun, 0 deg IPERF, 9 263 0 9 264 11 709 6 1 6 709 8 A -2 3K-17 12/8/1986 1 0 !PER 4' Csg 0 deg ph 9.2035.204 , . , . , . , . , . , 9,275.0 9281.0 6.717.9 6,722.4 A -2, 3K-17 12/811986 1.0 IPERF 4' Csg Gun, 0 deg ph roEaF 9275.0 9,281.0 6,717.9 6.722 4 A -2, 3K-17 12/&1986 1-0 RPERF 4" Csg Gun, 0 deg ph 9.2055.206 9,326.0 9,334.0 6.755.9 6.761 9 A -2, 3K-17 1218/ 986 1.0 IPERF 4" Csg Gun. D deg ph IPERF Notes: Cie+felal 8 . 8,207-8.208 Date A4egttben 71242004 NOTE: WAVERED LL: IAxOA COMMUNICATION RPERF, 9,231-8,232 IPERF, 9,2295,266 IPERF , 9,2445,245 IPERF, 9,2535,256 IPERF. 9.256-9.259 IPERF, 9,2619,264 IPERF. 9.2755.281 RPERF , 9,2755.281 IPERF 8,326-9.334 PROWCTION. 9.512 TD, 9,584 • To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 • RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ~,,~:~~~~ ~~~ ~¢ F~ ~~~; 3. a/~ 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245$952 1 j Caliper Report 21 Apr~09 3K 17 1 Report / EDE 2) ~~~ -~ s a ~ ~-~~y Signed : Print Name: 50-029-21642-00 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907}245-8951 FAx: (907)245-88952 E-MAIL :. - - _ -- ~ _ ; wEBSITE C:\Documents and Settings\Ownet~Desktop\Transmit_Conoco.docac Memory Multi-Finger Caliper S Log Restults Summary Company: ConocoPhillips Alaska, Inc. WeU: 3K-17 Log Date: Apri121, 2009 Field: Kuparuk Log No.: 7323 State: Alaska Run No.: 2 API No.: 50-029-21642-00 Pipet Desc.: 2.875" 6.5 Ib. J-55 EUE 8RD ABMOD Top Log IMvl1.: Surtace Pipet Use: Tubing Bot. Log Intvl1.: 7,062Ft. (MD) inspection Type : Corrosive 8 Mechanical Damage Inspection COMMENTS This caliper data is dell into the top of the GLM 3 ~ 6,988' (DriJJer's Depth). This log was run to assess the crondltion of the tubing with respell to intemal corrosive and mechanical damage. The caliper recordings indicate the 2.875" tubing logged is in good to fair condition, with a maximum reoorded wall penetration of 37% recorded in an isolated pit in joint 217 (7,060'). Other recorded damage appears in the form of shallow tine corrosion. A 3-D log plot of the caliper recordings from 6,982' to 7,062' (EOL) is included in this report. No significant areas of cross-sectional wall loss or l.D. restrictions are recorded throughout the intetvat logged. Although not presenting a significant I.D. restriction, the caliper recordings indicate slight budding from --6,120' to 7,062' (EOL). This is the second time a PDS caliper has been run in this well and the second time the 2.875° tubing has been logged. A comparison between the current and previous log (February 15, 2004) indicates no increase in corrosive damage to the 2.875" tubing logged during the time between logs. A comparison graph illustrating the differences in maximum recorded penetrations on a joint-by~oint basis between logs has been included in this report. MAXIMUM RECORDED WALL PENETRATIONS Isolated Pit (37%) Jt. 217 C~ 7,060 Ft. (MD) No other significant wall penetrations (> 19°k) are recorded throughout the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No s~nificant areas of cross-sectional wall loss (> 6%} are recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded throughout the interval logged. Field En ineer: l~hn. }~1cCrossan Analyst: i~`r Yang Witness: S. rerguson ProActive Diagnostic Sen~ices, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: f281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.cem Pn ~dhoe Ba;~ Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • PDS Multifinger Caliper 3D Log Plot ~, . Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3K-17 Date : April 21, 2009 Description : Detail of Caliper Recordings from 6,982' to 7,062' (EOL) of the 2.875" Tubing o • Correlation of Recorded Damage to Borehole Profile Pipe 1 2.875 in (49.2' - 7057.8') Well: 3K-17 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: April 21, 2009 A pprox. Tool De viation ^ A pprox. Boreho le Profil e 818 1612 2434 GLM 1 p 3250 ~ _c L 4061 v 4875 GLM 2 5695 6507 GLM 3 217 7058 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 217 25 50 75 100 ` w E ~, Z ~ 125 ~ o 150 175 200 z~ • • PDS Report Overview ~~ Body Region Analysis Well: 3K-17 Survey Date: April 21, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 2.875 ins 6.5 f -55 EUE Srd ABMOD 2.441 ins 2.875 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body -, ::,: metal loss body 150 100 50 0 0 to 1 to 10 to 1% 10°/ 20% 20 to 40 ro over 40% 85% 85% Number of 'oints anal se d rotal = 221 gene. 0 147 73 loss 119 102 0 1 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line rir~ hole /pons pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 7 2 0 5 0 0 Damage Profile (9'o wall) ~ penetration body ;.:.. metal loss body 0 50 100 1 48 GLM 1 147 GLM 2 197 GLM 3 Bottom of Survey = 217 Analysis Overview page 2 • Maximum Recorded Penetration ~-1, S,. Comparison To Previous Well: 3K-17 Survey Date: April 21, 2009 Field: Kuparuk Prev. Date: February 15, 2004 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 No. 218370 Country: USA Tubing: 2.875" 6.5 Ib J-55 EUE Srd Overlay Difference • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE Srd ABMOD Well: 3K-17 Body Wall: 0.217 in field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 21, 2009 Joint No. Jt. Depth (Ft.) I'c•n. I ll,.r•I (In,.) Pen. Body (Ins.) I'c•n. ",4, ~k•I;~I I oss ",~ Min. LD• (lns.) Comments Damage Profile (%wall) 0 50 100 1 15 I) 0.03 12 1 .38 .1 49 a ~) 3 .38 PUP 1. 65 a 0.01 ~; I) 2 P P 1.3 69 ~) 0.03 I ~ s 2.4 UP 2 1 U 0.01 2.39 3 1 6 ) .02 li 2.38 4 139 r) 0.02 t3 _' 2.39 5 171 I) 0.02 ri 2.37 6 04 ~) 0.01 6 I 2.40 7 236 U 0. 2 1 U 1 .3 8 269 (1 02 I[1 ~ .38 9 301 ~) 0.02 I t) I .40 10 3 4 t) 0.02 ~S 2.37 11 366 a 0.02 1 ~) 2.37 2 399 U 0 03 1~ 1 .38 13 432 ~) 0.0 t3 ~' 2.42 14 463 1) 0. ki _' 2.39 15 49 a 0.02 I U _' 2.41 16 5 u 0.01 7 (1 2.40 17 5 9 u 0.02 ti 1 2.41 18 592 I) 0.0 1 1 2. 1 624 I) 0.02 I 1 ? 2.40 0 657 U 0.02 II I 2.40 21 690 t) 0.0 ~) I 2.38 72 a 0. rs 23 755 l1 0.02 l u I 2.38 24 787 t) 0.02 ~~ 11 2.39 25 818 U 0.02 ~) 11 2.39 6 849 ~) 0.01 7 I1 2.39 27 880 I) 0.02 t9 I 2.41 28 91 I) 0.02 ti I 2.41 29 945 ~) 0.02 Ill I 2.39 30 978 It 0.02 1 2.41 31 1011 a 0.02 ~) _' 2.39 3 1043 U 0.01 i I 2.38 33 1075 I) 0.02 8 U 2.39 34 11 7 (1 0.02 ti ~ ~ .39 35 1138 a 0.02 ti ~ ~ 2.39 36 1169 U 0.02 t3 a 2.39 37 1200 (1 0.01 b it 2.39 38 1 31 a .02 `~ I 2.39 39 1263 U 0.02 ii 11 2.39 1294 a 0.01 ~1 I 2.39 41 1326 I) 0.01 7 u 2.39 4 1356 l~ 0.01 4 ~) 2.39 43 1388 t~ 0.01 c, 1 2.38 44 1420 c ~ 0.02 ti 1 .39 45 1451 I) 0.02 t~ U 2.39 1484 I) .01 r, 1 47 1516 ~~ 0.01 -1 I 2.39 _ Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE Srd ABMOD Well: 3K-17 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 21, 2009 Joint No. Jt. Depth (Ft.) I'c~n. I Jliu~t Urn.1 Pen. Body (Ins.) F'en. % ti1c~l,rl I cxs °~~ Min. LD• (Ins.) Comments Darnage Profile (%wall) 0 50 100 48 1547 0 0 02 10 _' 2.3 49 1579 ~ ? 0.02 ~) I 2.40 50 1612 U 0.02 10 I .38 51 1645 U 0.02 F3 U 2.39 52 1677 tt .03 I ~ I 2.42 53 1710 0 0. 2 ~i tt 2.39 54 1741 0 0.02 ti I 2.37 55 1773 0 0.02 Ill 0 .37 55.1 1806 tt 0.02 I 2.40 P P 55.2 1 10 U 0 U U 2.31 Camco TRDP-1 A-SSA saf valy 56 1819 ~ t 0.02 10 _' 2.38 57 1851 t t 0.01 G 1 2.40 58 1884 t t 0.03 11 I .37 59 1916 t t 0.03 I -1 2 .41 60 1948 t I 0.02 8 ~' 2 38 61 1980 0 0.02 11 1 2.39 62 2013 0 0.02 £t r t 2.39 63 042 tt 0.02 ~t I 2.37 64 2075 a 0.02 £3 ' 2.39 65 2108 U 0.02 11 1 2.37 66 2141 U 0.02 1 U Z 2.37 67 2173 tt 0.0 ~t 1 2.37 68 2206 t 1 0. 14 ~ 2.38 69 2239 a 0.02 11 1 2.36 0 1 0 0.0 9 I .36 71 2304 n 0.03 1 Z 1 2.37 72 2336 t1 0.0 £i I 2.38 73 2369 U 0.03 12 3 2.36 74 40 (1 0.02 £3 I 2.38 75 2434 t t 0.02 11 I 2.36 76 2467 0 0.0 '> 2.38 77 2499 0 0.02 is I 2.38 78 2531 U 0.03 I ~ i) 2.36 79 2564 0 0.02 £t 2.36 80 2596 a 0.02 lU 2.39 81 2628 U 0.01 7 _' 2.38 82 2660 t t 0.03 1 ~ 0 2.39 83 2693 t ~ 0.02 1 U I 2.38 84 2725 tt 0.03 I2 _' 2.40 85 2757 t~ 0.02 £i 1 2.38 86 2790 a 0.01 b ,' 2.38 87 2822 (t 0.02 ~) I 2.41 88 2855 ~ t 0. 2 £3 2.39 89 2888 tt 0.04 1£3 2.38 Isolated it6n . 90 2918 0 0.01 7 t 2.38 91 2951 tl 0.02 t3 I 2.35 92 29 3 tt 0.02 11 I 2.39 93 3016 t~ 0.02 11 2.35 94 3048 ~ ~ 0.02 ti I .39 94.1 3080 ~~ 0 i~ N A GLM 1 Latch @ 1:30 _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8rd ABMOD Well: 3K-17 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 21, 2009 Joint No. Jt. Depth (Ft.} I'e~n. llpu~l (Ins.) Pen. Body (Ins.) N~~n. % ~1c•I,il loss °~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 95 3088 t) 0.02 11 _' 2. 8 96 31 0 0 0.02 11 ~ 2.39 97 3152 0 0.02 11 ~ .38 98 3185 U 0.02 ~) _' 2.37 99 3217 (I 0.02 t3 _' .3 100 3250 t) 0. 2 t3 I 2.38 101 3282 U 0.03 11 2.39 102 3315 U 0.02 8 I 2.39 103 3348 t) 0.03 13 I 2.38 104 3380 ~ 0.02 8 ~ 2.39 105 3412 U 0.02 t3 2.41 106 3445 U 0.02 L3 ~ 2.39 107 3478 0 0.02 I1 1 2.36 108 3510 a 0.0 ~) ~' 2.41 109 3543 t) 0.02 ti I 2.38 110 3575 U 0.01 I .39 111 3608 t) 0.02 i I 2.38 112 3641 U 0.03 11 .40 1 3 3671 U 0.01 7 1 2.40 114 3704 U 0.03 12 I 2 3 115 3735 t) 0.02 11 2 36 116 3767 a 0.02 f~ 2.39 117 3800 U 0.02 ti ? 2.41 118 3833 U 0.03 12 _' 2.41 11 3866 a 0. 1 (~ -1 2.39 120 3898 U 0.02 t3 I 2.41 121 3931 I) 0.02 8 i 2.37 122 3963 l) 0.02 ft 1 2.40 123 3996 0 0.02 t3 r~ 2.35 124 4028 l) 0.02 r9 2.38 125 4061 0 0.02 t; 2.39 126 4093 t) 0.02 is 1 2.40 1 7 4126 O 0.02 11 I 2.39 128 4159 0 0.02 ti _' 2.40 129 4191 0 0.02 tt 2.37 130 4224 0 0.02 1 U ~ I 2.37 131 4256 a 0.02 ~) 2.40 132 4289 U 0.03 12 U 2.35 133 4322 a 0.03 I ~ I 2.36 134 4354 a 0.02 t3 2.41 135 4386 0 0.02 ~) _' 2.35 136 4420 0 0.02 10 _' 2.39 137 4451 l) 0.02 ti Z .36 138 4484 ) ~ 0.02 1 U -1 2.40 139 4516 ~) 0.02 ~I 2. 9 140 4548 ~) 0.03 1 z _~ 2.35 141 4581 U 0.03 I~ _' 2.41 142 4614 t ~ 0.02 ~) 2.41 143 4645 ~ ! 0.03 ` ' .35 144 4679 0.03 2.36 Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE Srd ABMOD Well: 3K-17 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 21, 2009 Joint No. )t. Depth (Ft.) I'c~n. U)xe>t (Ins.) Pen. Body (Ins.) Pen. °io ~1ct~il I ~~~~ ~~ Min. LD• (Ins.) Comments Damage Profile (% wall) D 50 100 145 4712 a 0.02 8 I 2.3 14b 4744 t) 0.03 11 I 2.35 147 4777 i) 0. 3 1 ~ .? 2.35 148 4809 U 0.03 13 1 2.35 149 4842 t ~ 0.02 73 I 2.38 150 4875 ti 0.02 lI I 2.39 151 4907 t) 0.02 ti I 2.3 152 4939 t) 0.02 1 l) ~ ~ 2.3 153 4971 U 0.04 18 I 2.36 154 5005 U 0.02 1 i1 ' 2.40 155 5038 t) 0.03 11 _' 2.34 156 5071 U 0.02 1 U I 2.39 157 5102 a 0.02 II 2.38 158 5134 U 0.0 11 2.35 159 51 7 U 0.02 1I I 2.37 160 5199 t~ 0.03 12 ? .35 161 523 a 0.02 1 U 2.36 162 5265 l) 0.03 1 ~1 ~' 2.35 Shallow line co rosion. 163 5298 t ~ 0.03 15 3 2.39 Shallow line corrosio . 16 5329 U 0.04 1 ~ I 2.38 Shallow line corrosion. 165 5362 U 0.03 13 2.38 166 5395 t) 0.04 1 ~) 2.36 Shallow line corrosion. 167 5428 U 0.04 18 ~ 2.38 Shallow line corrosion. 168 5459 U 0.02 1 U 2.35 169 5493 t) 0.02 11 I 2.37 170 5525 U 0.03 1 ~ I 2.38 170.1 5556 U 0 ) O N A G M 2 Latch @ 2:30 171 5564 l) 0.02 8 1 2.40 172 5597 t) 0.02 8 I 2.41 173 5628 a 0.02 II I 2.35 174 5663 U 0.02 £3 I 2.40 175 5695 t~ 0.02 1 tl I 2.35 176 5728 l) 0.03 1 ~ 2.37 177 5761 U 0.02 11 2.37 178 5792 t) 0.02 9 _' .35 179 5825 U 0.02 10 3 2.38 180 5856 U 0.02 8 I 2.38 181 5890 t) 0.04 1 ~ 2.39 182 5922 a 0.02 ti I .39 183 5954 tt 0.02 £t 1 2.38 184 5987 t~ 0.02 ~) I 2.40 185 6019 a 0.02 8 I 2.38 186 6053 t) 0.02 11 :' 2.38 187 6085 t) 0.02 8 _' 2.38 188 6117 U 0.03 12 n 2.35 Sli ht buckli 189 6149 t t 0.02 I t) I 2.38 190 6181 t ~ 0.03 I.1 i 2.38 191 6213 t) 0.02 1 1 U 2.36 Lt. De osits. 192 6246 l) 0.02 8 ~ 2.38 193 6279 U 0.02 8 > 2.3£3 51i~ht bucklin . Penetration Body Metal Loss Body Page 4 • • PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-5S EUE Srd ABMOD Well: 3K-17 Body Wall: 0.217 in Field: Kuparuk Upset Wall: 0.217 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.441 in Country: USA Survey Date: April 21, 2009 Joint No. Jt. Depth (Ft) I'r~n. I ll,tic~t Iln..) Pen. Body (Ins.) Pc~n. °~, 1~tc~l~il I r~ss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 194 6312 ~ ~ 0.04 1 ~) :1 .38 195 6344 ~ r 0.02 ti ~ 2.38 196 6377 t~ 0. 1 ~) I .39 197 6409 t~ 0.02 ti .3 198 6442 ~ ~ 0.02 t3 i I .38 li ht ucklin . 19 473 ~~ 0.01 - u 8 200 6507 a 0.02 8 I .39 01 6536 U 0.03 13 t~ .34 Lt. D its. 202 6570 t) 0.02 10 .39 03 66 2 U .02 1O 1 ,3 SI' t b cklin . 4 634 U .02 1(> 35 20 6666 U 0.02 11 ? 35 20 6700 ~t 0.0 I I .37 2 7 6732 U 0.02 1 r~ .34 8 765 U 0 2 l U I 2.38 Sli ht uckli 2 9 6797 U 0.02 1 t) i 1 2.36 210 682 U 0. 3 1 ~ I 2.32 Lt. De osits. 11 686 U 0.0 11 r .35 212 6894 a 0.02 t3 I .38 213 6923 a 0.02 1 1 I 2.35 Sli ht bu I' 14 6957 ~~ D.0 ~i 2.37 214 1 988 u 0 t~ t~ N A GLM Latch ~ 11:00 15 699 U 0.02 ~~ tI .38 2 6 7029 l) 0.02 is ~l 2.39 7 7 58 ~ 0.08 ~ 38 Is ted it. Sli t b c lin . Penetration Body Metal loss Body Page 5 ~ ~ ~ ~ ~ ~^ ~ ~ ~ s ~ _ ~ ~ ~ ~ ~ ~ ~^ ~S PDS Report Cross Sections Well: 3K•17 Survey Date: April 21, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc, Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 2.875 ins 6.5 f -55 EUE 8rd AB~UOD Anal st: HY. Yan Cross Section for Joint 217 at depth 7059.863 ft Tool speed = 43 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 97 Tool deviation = 48 ° Finger 24 Penetration = 0.08 ins Isolated Pit 0.08 ins. = 37% Wall Penetration HIGH SIDE = UP u Cross Sections page 1 KUP 3K-17 ConocoPhillips w®n am wtlbae ~ ~ a iuu Tu ,I.1~",. ..1 ~, . ... --~-_- -_ 500292184200 KUPARUK RIVER UNfT PROD 50.78 2,700.00 9,584.0 ... so101 PiA - - - - taommete SSSV: TRDP (ppttQ 125 7/1!2008 Atelodtlan Las[ WO: 39.01 p 8!8188 8!29/1986 n Last Tag: ELMD 9,292.0 n 1/29/2009 Rev Reason: GLV C/O. TAG ?/212009 CONDUCTOR. { Stfl s ~ ~ ~ ~ 115 Desalptl ott 8 IMI ~ 9n) T ~ (M~ (~6) ~ (bs4q trade TIM sorely venre. CONDUCTOR 1 6 15.062 0.0 115.0 i t .0 6 . 0 H-40 t.aza a l SU FACE 95! 8 8.765 0.0 4,761.0 3,7 04.2 36.00 J , GA$ LIFT, PRODUCTION 7 6.151 D.0 9,512.0 6.8 96.2 2 .00 J35 3090 Tub! 8t s SURFACE. Y Gehl I 4.781 lY4/ly Deecrlpd en Snl NU Top 1~~ ~a Ibee4 ftia4e Tap ttltd cASUFr, KING 2 / 8 2.Mt 0.0 9.111.0 6,6 00.1 6.50 Jb5 E U SRDABM... s.~0 t)tlYer M Hol e A n Run a Retriewbl Fish et c. GPS LIFT (NW Toplnd . 6.968 (M~ ) (9 C etlenult fM OeLt D 1,824.0 1,68 7.7 41.33 Sa fety Valve Centco TROP-IA-SSA' 1 1986 2.310 PATCH, 7 ots 3,09D.0 2,54 6.5 44.6 UFT 1/DMYBK!// Cmrrten[ : STA 7 1!30 !2009 .3 5 PATCH, 7,072 5.560.0 4,22 7.6 18.08 G AS UFT MERLARMPd11DMYBK/// Catmint STA 2 1/30 2009 2375 .0 5,79 2.9 48.92 FT RLA/TMPd1 MYBKI// Cmrnlent : STA3 1x31 .3 5 GAS LIFT 7 791 7,045.0 5,23 0.4 48,86 PA TCH T U ACKER ASSE Y W/ ACKER 6 SNAP LATCH ASSEMBLY (OVL 34.35' W/1.320" ID) 12 2004 1.320 ,0 .0 5,24 8.1 48.93 A T H BO OM CUPSE PACKE R WINpO E LEMENT / 2004 1.468 GAS LIFT, 7 9 5 7 8 287 , 4.0 ,72 4. 49.45 G AS U MERLAlTMPd IDMVBKI/I Camlerlt STA4 611! 2004 2.3 5 ,287.0 6,04 7.3 18.77 U MERI.A/TMPdi/DMY/BK/// Camlettt: STA5 9r1B /1989 2.3 GAS LIFT, $,748.0 6,35 4. 48. MERLA(TGP 1. /DMY/R !/ ~ S A 1 04 2.375 8.768 8, .0 6, .0 4 .9 SB R Camro'OEJ' SBR 11/8 /1986 2. 13 8,816.0 6,40 0.2 47.94 PA CKE Camco'H P-1SP'PACKE R 12/8 /1986 2.34 sm.8798 8,866.0 8,42 6. 47.86 PR O C ION MERL MPd IDMYBKIII Catmint : ST 7 4113 /2 .37 8,929.0 6,47 5.3 47.71 P DUC ION RLMM d1/DMYI // Camlerx: STA8 Mt3 12004 2.375 PACKER. B,tl18 9,042.0 6,55 2.8 46.93 P O ON ME Pd1/D /BK/// Cotmlent: TA 9 411 .375 9,083.0 ,58 0.6 46.15 A KE aka' PAC 721 1 6 3. 6 PROOUCrION, 8 088 0 6 59 1 45 85 NI PP 'd Np le 1 /986 2 25D 8 856 , . , . . p . 9,11 .0 ,59 9.3 45.64 SO S Cameo 12/8 11986 2. 1 PROwcnoN. 9,111.0 60 0.1 45.62 TT L 12/8 /198 447 2 8,828 , . Pertora gons IPERF, Suet BA70-8.996 TuP fTV~ !1611 fTY~ ~Ft9 T Mn p1Ke) A~1 late Dae lel~- ty pe cattettn lt PR0DUC710N. 8.9 0.0 8,99 4.0 6.503. 6,519. - ,UNIT 12!&1986 12.0 PE 5' Csg Gun, 12 ph 9,oe2 3K-17 9,789.0 9.20 9.0 6, .3 6,689.6 A- 3. 3K-1 1/2U7998 4.0 R 1/8 Tarledo Utir. ph PACKEx.s.oe3 9,789.0 9, 9. 6, .3 6,669.6 A- 3, 3K-17 6/131996 4.0 1/8"EJ;180ph:Ort +/-90 F/Lowside 9 1 0 9 20 0 662 5 683 6 1 A 3 3 -1 12/&1986 1 0 I E R 4 Csg Gun 0 deg ph NiPP1E, a.o99 , . . . , . . . . . . 9.203. 9,20 4.0 6,665.3 6,666.0 A J. 3K-17 28!1986 1.0 IP 4" Csp Cxn, 0 deq pA 9.205.0 9,20 6.0 6, .7 6,667.4 A 3, 3 -17 12/&1986 1.0 IPER F 4" Csg , 0 deg ph sos. a ~ 10 9,207.0 9,20 8.0 6,668.2 6,668.9 A- 3, 3K-1 J 12/8/1986 7.0 IPERF ' Csg Cxn, 0 deg ph iTL.9.111 ,229.0 9,24 .0 6,884.1 6, 96.6 A- 2, 3 -1 4/24/1988 4.0 IPE 2 1/8 Tornado Little 90 ph 9,169-8,109 9,231.0 9, .0 ,885.6 6,688. - t, 3K- 1986 1.0 F d° Csg Gun, 0 deg pA RPERF 8.1888.209 9,244. 9,24 5.0 6,695.1 6,69 .8 A- 2, K- 7 11!8!1986 1.0 IPER F 4' C Gun, deg ph s9 IPERF, 9,198S.zoo 9,253. 8,25 4.0 6,701.7 8,702.4 A- 2, 3K 17 117&1988 1.0 IPER F 4" sg Gun, 0 deg ph 9,258. 9,2 9.0 6, 0 .4 6, .1 - 2, 3K- 7 218!1 6 .O IPER 4°Cag Gun.O eg ph IPERF, 9,263.0 9,26 4.0 8,709.1 6,709. A- 2. 3K-1 12/8/ 986 1. IPER 4" Csg Gun, 0 deg ph s.2m5.204 9,275.0 ,28 1.0 .717.9 6,722.4 A- 2. 3K-17 12/811988 1.0 IPER F 4" Csg Gun, 0 deg ph IPeRF, 9.2 5. 9,26 1.0 6,717. ,22.4 A- 2, 3K-17 12/8/1986 1.0 RP RF 4" Csg Gun, 0 deg ph s,2os-9.zo6 9,3 6.0 9.33 4.0 8,7 .9 ,761.9 A- 2, 3K-17 12/8/1986 1.0 IP F 4° Csg . 0 deg IPERF PlOtes: c 3ale isi a ~~ . 8,207-0,108 a te 1 7 2412 004 NOTE: WAIVE RED LL: IAx OA COMMUNICATION RPERF. 9,231 232 IPERF , 9.229-0.2<8 IPERF. 9,1W-0,145 IPFTtF, 9.1535.254 IPFAF, 9,158-0.259 IPERF. 8.2835.184 IPERF, 8,2750,181 RFERF, 9,275-9,181 IPERF. 9.3265,334 PRODUCTION, 9,512 TD. 9$84 3K-17 (PTD 1861520) Report of failed TIFL Page 1 of 2 • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, November 28, 2008 4:31 PM lC ~ y~(~~ I ~ To: 'NSK Problem Well Supv' 111 ~/ y Subject: RE: 3K-17 (PTD 1861520) Report of failed TIFL 1 ( M Thank you; sorry far the confusion. Jim Regg 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, November 28, 2008 4:22 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: RE: 3K-17 (PTD 1861520) Report of failed TIFL Jim, This well has been waivered for IAxOA communication since 11/2004 and has been reported on the quarterly SCP report to the AOGCC since the 4th quarter report o 2004. Please let me knout if you Would like any more information. Brent Rogers/Martin Waiters Problem Wells Supervisor ConocoPhillips Alaska, inc. Desk Phone {907} 659-7224 Pager {907} 659-7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, November 28, 2008 3:26 PM To: NSK Problem Well Supv Subject: RE: 3K-17 (PTD 1861520) Report of failed TIFL Tl0 plot for 3K-17 also indicates high OA pressure. In fact, it appears the well has operated With pressures above 1000 psi since sometime in August. Ida not have any record of notice of high OA pressure as required CO 494: "The operator shall notify the AOGCC within three working days after the operator identifies a well as having (a) sustained inner annulus pressure that exceeds 2000 psig or (b) sustained outer annulus pressure that exceeds 1000 psig Did you notify the Commission as required? Jim Regg 11/28/2008 3K-17 (PTD 1861520) Report of failed TIFL Page 2 of 2 • AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Saturday, October 25, 2008 12:58 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 3K-17 (PTD 1861520) Report of failed TIFL Tom, Jim Kuparuk gas lifted producer 3K-17 (PTD 1861520) failed a TIFL on 10/24/08. The TIO prior to the test was 140/1270/1020. A leaking GLV is suspected. Slickline will troubleshoot the leak and repair if possible. Attached is a 90 day TIO plot and wellbore schematic. Please let me know if you have any questions. «3K-17 schematic.pdf» «3K-17 90 day TIO plot.jpg» Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 11i2si2oo8 n KRU 3K-17 PTD 186-152 10/25/2008 1 OI ZS~ Zo - -- KUP ~ 3K -17 ~tJt~UCi3P~"11~ 1~~35 ~ -__ ~ WellAttrtbutes _ i .. . I ~ Woro 'Fbur:l F,aIJ Harm. Well Siatus Pr tlfinj Well Type Irrul a tl ir,u titNdi IU i maxi llL.. l .. 500292164200 KUPARUK RIVER UNIT PROD 50.78 2,700.00 9,584.0 ... Commanl H25 (ppm) Date Annotation End Date KB-0rd (ft) Rig Release Date - weuc r ~ -~1 ------ PM SSSV: TRDP 125 7/1/2008 Last WO: 39.01 8/29/1 986 ° ~.~~ ~~. - -~ _-~- 4nnotaton Depth (HKB) E nd Date Annotation End Date Last Tag: 9,272.0 6/27/2008 Rev Reason: ELMD TAG 10/10/2 008 O DUCTOR C ~ Casing Strings ~(,~D C N , 115 ~ String OD String ID Sal Depth Sat D pth (ND) Slring Wt Siring Cesin9 Deacri lion p (in 1 (in) Top (NKB) (flKB) (kKB) (Ibadt) Orade String Top Thrtl salary vama, ~ ~ CONDUCTOR 1 6 15.062 0.0 115.0 115.0 62.50 H-00 ~ 1824 1 "~ `~' + ~c SURFACE 95/ 8 8.765 0.0 4,761.0 3,704.2 36.00 J-55 GAS LIFT. -{i. ~,.--9 PRODUCTION 7 _6.151 _ - - 0.0 9,512.0 - 6,896.2 26.00 J-55 _ -. ,. -_...- 2~; ~'-' "~ (~PSi 3090 ~- Tubin~Strings _ - _ SURFACE, ~ Stang rill String ID Set Depin Ser liepth tl VU) 't ing Wt String 4,761 - Tubing Deauiptbn (in) (in) lop (kKB) (kK8) (flKB) (Ibalk) Orade String Top Thrd TUBING 2 7/ S 2.441 0.0 9,111.0 6,600.1 6.50 J-55 EUE SRD AB GAS uFr, ssfio - ~ -7 MOD '~ Other In Hole (All Jewelry: Tubing Run E~ Retrievable, Fish, etc.} -- - ... GAS T 9 T..y Oeyur 6,988 (ND) Top Top (flKB) (kKB) Inc! (°) Deacriplion Comment Run Date ID (in) 1,824.0 1,687.7 41.33 Safety Valve Camco TRDP-IA-SSA' 12/8/1986 2.310 PATCH, 7,046 .'_-_ -_=, 3,090.0 2,546.5 44.67 GAS LIFT MERLARMPDIt/GLV/BK/.156/1364/ Comment: STA 1 3/19Y2004 2.375 PATCH, 7,072 - 5,560.0 4,227.6 48.08 GAS LIFT MERLAlfMPD/1/GLV/BK/.156/1350/Comment STA2 3/19/2004 2.375 6,988.0 5,192.9 48.92 GAS LIFT MERLAITMPD/1/GLV/BW.188/1371/Comment: STA3 3/19/2004 2.375 GAS LIFT, 7,794 ~~ 7,045.0 5,230.4 48.96 PATCH TOP ECLIPSE PACKER ASSEMBLY W/SPACKER 8 SNAP 6/12!2004 1.320 LATCH ASSEMBLY (OVL 34.35' W/1.320" ID) GAS LIFT, ~ ~ "M 7,072.8 5,248.1 48.93 PATCH BOTTOM ECLIPSE PACKER W/MID ELEMENT set 6/7/2004 1.468 e,Te7 - 6/7!2004. ATTEMPT TO SET TOP PACKER FAILED, ' FISHED & PULLED 6/8/04 GAS LIFT' e.74a ~ 7,794.0 5,724.7 49.45 GAS LIFT MERLA/TMPD/1/DMY/BK/// Comment: STA 4 6/1/2004 2.375 8,287.0 6,047.3 48.77 GAS LIFT MERLA/TMPD/1/DMY/BW//Comment: STAS 9/26/1999 2.375 SBR, 8,]98 8,748.0 6,354.5 48.00 GAS LIFT MERLA/TGPD/1.5/DMY/RK///Comment: STA6 5/31/2004 2.375 ' 5,798.0 6,388.0 47.92 SBR Camco'OEJ' SBR 12/8/1986 2.313 I 8,816.0 6,400.2 47.94 PACKER Camco'HRP-I-SP' PACKER 12/8/1986 2.347 PACKER, 6,616 ~ i.'-xz~-= - - 8,856.0 6,426.9 47.86 PRODUCTION MERLA/TMPD/1/DMY/BK///Comment: STA7 4/13/2004 2.375 _ 8,928.0 6,475.3 47.71 PRODUCTION MERLAITMPD/1/DMY/BK///Comment: STAS 4/13/2004 2.375 PRODUCTION, _ I e,as6 _ ~ 9,042.0 6,552.8 46.93 PRODUCTION MERLA/TMPD/1/DMY/BK///Comment: STA9 4/13/2004 2.375 i 9,083.0 6,580.6 46.15 PACKER Baker'DB' PACKER 12/8/1986 3.250 PRODUCTION, -J~' 6,s26 '~ _ 9,099.0 6,591.7 45.85 NIPPLE Camco'D' Nipple NO GO 12/8/1986 2.250 _ 9,110.0 6,599.3 45.64 SOS Camco 12/8/1986 2.441 IPERF, ' 9,111.0 6,600.1 4$.62 TTL 12/8/1986 2.441 8 970-6,994 Perforations PRODUCTION, ~ 1- ~ ---~ - ~ ~ -~-~-~ ~- snot 9,042 - Top (ND) Btm (ND) Dena Top (kKB) Bim (kKe) (kKB) (flKB) Zona Date (sh-~ Type Comment NIPPLE,9099 1 l SOS, 9,710 TTL, 9,111 IPERF, 9,189-9,209 RPERF, 9,169-9,209 - IPERF, 9,199-9,200 IPERF, 9,203-9,204 IPERF, 9,205-9,206 IPERF, 9,207-9,208 - RPERF, 9,231-9,232 IPERF, 9,229-9,246 IPERF, 9,244-9,245 IPERF, 9,253-9,254 IPERF, 9,256-9,259 _ IPERF, 9,263-9,264 IPERF, 9,2289,281 RPERF, 9,2289,281 IPERF, 9,326-9,334 PRODUCTION, 9,512 ~- TD,9,584 7 FlLowside 9,229.0 9,246.0 6,684.1 6,696.6 A-2, 3K-17 4/24/1988 4.0 IPERF 2 1/8 Tornado Link, 90 ph 9,231.0 9,232.0 6,685.6 6,686.3 A-1, 3K-17 12/8/1986 1.0 RPERF 4" Csg Gun, 0 deg ph 9,244.0 9,245.0 6,695.1 6,695.8 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,253.0 9,254.0 6,701.7 6,702.4 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,258.0 9,259.0 6,705.4 6,706.1 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,263.0 9,264.0 6,709.1 6,709.8 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,275.0 9,281.0 6,717.9 6,722.4 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph 9,275.0 9,281.0 6,717.9 6,722.4 A-2, 3K-17 12/8/1986 1.0 RPERF 4" Csg Gun, 0 deg ph 9,326.0 9,334.0 6,755.9 6,761.9 A-2, 3K-17 12/8/1986 1.0 IPERF 4" Csg Gun, 0 deg ph Notes: General & Safety _ _- _ _ -- ~nd bare Annotation 11/24/2004 NOTE: WAIVERED WELL: IA x OA COMMUNICATION . . ~ ConocoPhillips Alaska JUL 3 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 "t\,tI..\E.D ~UG () 1 2007 SCI"'\l'&'1 \, t6b- ~ G:}- Dear Mr. Maunder: Enclosed pleasefmd a spreadsheet with a list of wells from the Kuparuk field (KRD). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ') / __,é/ 711-il/07- Perry KI . ConocoPhillips Well Integrity Supervisor ) . IIJI ') .i ')!OU^-r' ~:'~ ,J .i ~ & ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/28/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft na ç¡al 3K-1 186-101 19' 2.6 19" 7/7/2007 7 7/27/2007 3K-2 186-102 53' 7.2 9" 7/7/2007 3.7 7/22/2007 3K-3 186-103 43' 5.8 11" 7/7/2007 4.2 7/27/2007 3K-5 186-123 66' 9.0 26" 7/7/2,007 9.6 7/22/2007 3K-6 186-124 58' 7.9 13" 7/10/2007 4.8 7/22/2007 3K-7 186-125 70' 10.5 35" 7/7/2007 13.2 7/22/2007 3K-8 186-126 54' 4.0 9" 7/10/2007 3.6 7/22/2007 3K-9 186-174 26' 9.0 16" 7/10/2007 6 7/22/2007 3K~11 186-164 43' ..... 6.5 21" .. 7/10/2007 ..' 7.8 . 7/16/2007 3K-13 186-136 8" none 8" 7/10/2007 3.1 7/16/2007 3K-14 186-137 8" none 8" 7/10/2007 3.1 7/16/2007 3K-15 186-138 50' 6.0 22" 7/10/2007 8.4 7/22/2007 3K-16 186-139 46' 7.0 27" 7/10/2007 9.6 7/22/2007 3K-17 186-152 56' 8.0 30" 7/10/2007 10.7 7/22/2007 3K-18 186-151 38' 5.5 23" 7/10/2007 8.4 7/22/2007 1. Operations Performed: j~jL- .~ REPORT OF SUNDRY WELL OPERATIONS D Suspend D Operation Shutdown D D Repair Well 0 Plug Perforations D D Pull Tubing D Perforate New Pool D 4. Current Well Status: Development - B Stratigraphic D ~.. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Abandon Perforate D' Stimulate D '? 1004 Alter Casing Change Approved Program 2. Operator Name: 'ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 69' V,aria:~ëe D Annular Disp. D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 186-152/ 6. API Number: 50-029-21642-00 Exploratory D Service D Other D 9. Well Name and Number: 3K-17 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING Perforation depth: 10. Field/Pool(s): Kuparuk Oil Pool measured 9584' feet true vertical 6951' feet measured 9584 feet true vertical 6951 feet Length Size MD 115' 16" 115' 4692' 9-5/8" 4761' 9443' 7" 9512' Plugs (measured) Junk (measured) TVD 115' 3704' 6896' Measured depth: 8970-8994, 9189-9209, 9229-9246, 9253-9281, 9326-9334' true vertical depth: 6504-6520,6655-6670,6684-6697,6702-6723,6756-6762' Tubing (size, grade, and measured depth) 2-7/8", J-55, 9111' MD. Packers & SSSV (type & measured depth) pkr~ CAMCO 'HRP-1-SP'; BAKER 'DB' pkr= 8816'; 9083' SSSV~ SSSV SSSV~ 1824' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 120 325 104 320 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: Oil0 GasD WAGD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 115 419 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Burst Collapse jUl 17S?nQl\ CasinQ Pressure 1378 1285 TubinQ Pressure 169 166 Service D GINJD WINJD WDSPLD I Sundry Number or N/A it C.O. Exempt: Contact Dethlefs/McConnell Printed Name 4erry DetJ~e~~ Signature Y~C_"~-"'Z:':-"?5 Title Problem Well Supe "\,¡ Phone 659-7224 OR\G\NAL "-. ""-.. "....J ) Form 1 0-404 Revised 2/2003 . Date 7/-Ø¡/ SUBMIT IN DUPLICATE ( ConocoPhillips Alaska, Inc. Kuparuk We1l3K-17 (PTD 1861520) Report of Sundry Operations 07/05/04 ConocoPhillips Kuparuk production we1l3K-17 tubing was patched 05/14/04 to repair a tubing leak at 7054' MD. The patch was 2-7/8", 20-feet long, retrievable style. The patch set depths were: Top: 7042' MD Bottom: 7062' MD On 5/17/04 a TIFL failed showing T x IA communication still exists. The patch was tested by Slickline and found to be leaking. On 5/31/04 the retrievable patch assembly was pulled from the well. On 6/7/04 the patch was set again. The Well Service Report (WSR) is as follows: BOTTOM PACKER OF WEATHERFORD PATCH SET WITH ELEMENT AT 7072' RKB. UPPER PACKER WITH LATCH ASSY & SPACER PIPE LATCHED TO BOTTOM PACKER GOING DOWN @ 200 FPM. LATCHING CONFIRMED BY PULLING 800 LBS OVER NORMAL UP WEIGHT. NO INDICATION OF PACKER SETTING. COULD NOT LOG OFF. PULLED OFF WEAKPOINT. 49.75' FISH LEFT IN HOLE WITH TOP AT 7026' RKB. On 6/8/04 the Eline tools and patch extension were recovered from the well. The WSR is as follows: FISHED E-LINE TOOL STRING AND PULLED UPPER PACKER AND STINGER ASSEMBLY @ 7026' RKB (( LOWER PACKER STILL IN HOLE )) On 6/12/04 the top of the patch was reset. The WSR is as follows: SET ECLIPSE PACKER WI SPACER PIPE AND SNAP LATCH ASSEMBLY (34.35' TOTAL LENGTH AND HAS A 1.320 ill ) @ 7072' RKB On 6/15/04 the post patch TIFL failed again showing T x IA communication still exists. The situation with patching this well is still under consideration. The well remains shut-in. NSK Problem Well Supervisor 07/05/04 .~.I~.' ConocoPhiUips Alaska, Inc. 3K-17 API: 500292164200 SSSV Type: ' TRDP Annular Fluid: SSSV (1824-1825, 00:2.875) SBR (8798-8799, 00:2.875) PKR (8816-8817, 00:6.151) PKR (9083-9084, OD:6.151) NIP (9099-9100, OD:2.875) TUBING (0-9111, 00:2.875, ID:2.441 ) Perf (9189-9209) Perf (9231-9231 ) Perf (9253-9253) Perf (9275-9281) Perf (9326-9334) Reference Log: Last Tag: 9328 Last TaQ Date: 3/17/2004 Casing String - CASINGS Description CONDUCTOR SURF CASING PROD CASING Tubing String - TUBING Size I Top 2.875 0 Perforations Summary Interval TVD 8970 - 8994 6504 - 6520 9189 - 9199 6655 - 6663 9199 - 9199 6663 - 6663 9199 - 9203 6663 - 6665 9203 - 9203 6665 - 6665 9203 - 9205 6665 - 6667 9205 - 9205 6667 - 6667 9205 - 9207 6667 - 6668 9207 - 9207 6668 - 6668 9207 - 9209 6668 - 6670 9229 - 9231 6684 - 6686 9231 - 9231 6686 - 6686 9231 - 9244 6686 - 6695 9244 - 9244 6695 - 6695 9244 - 9246 6695 - 6697 9253 - 9253 6702 - 6702 9258 - 9258 6706 - 6706 9263 - 9263 6709 - 6709 9275 - 9281 6718 - 6723 9326 - 9334 6756 - 6762 ~ä$¡tiltt¡M~hdtiÎs~alvij$ , St MD TVD' Man Mfr 1 2 3 4 5 6 3090 2547 5560 4228 6988 5193 7794 5725 8287 6047 8748 6354 Merla Merla Merla Merla Merla Merla ( KRU Well Type: PROD orig Completion: 8/29/1986 Last W/O: Ref LOQ Date: TD: 9584 ftKB Max Hole AnQle: 51 deg (éi) 2700 Size Top 16.000 0 9.625 0 7.000 0 Bottom 9111 Zone Status C-1 ,UNIT B A-3 A-3 A-3 A-3 A-3 A-3 A-3 A-3 A-3 A-2 A-2 A-2 A-2 A-2 A-2 A-2 A-2 A-2 Man TMPD TMPD TMPO TMPD TMPD TGPO 3K-17 AnQle (éi) TS: 48 deg (ã) 8906 AnQle (éi) TD: 41 deg (ã) 9584 Rev Reason: Set Top Eclipse Packer Last Update: 6/21/2004 Bottom TVD Wt Grade Thread 115 115 62.50 H-40 4761 3704 36.00 J-55 9512 6896 26.00 J-55 TVD I Wt I Grade I Thread 6600 6.50 J-55 EUE 8RD AB MOD Ft SPF Date Type 24 12 12/8/1986 IPERF 10 8 6/13/1996 RPERF 0 9 4 8 0 9 2 8 0 9 2 8 0 9 2 8 2 4 0 5 13 4 0 5 2 4 0 1 0 1 0 1 6 2 1 GLV GLV GLV DMY DMY DMY 6/13/1996 RPERF 6/13/1996 RPERF 6/13/1996 RPERF 6/13/1996 RPERF 6/13/1996 RPERF 6/13/1996 RPERF 6113/1996 RPERF 6/13/1996 RPERF 4/24/1988 IPERF 4/24/1988 IPERF 4/24/1988 IPERF 4/24/1988 (PERF 4/24/1988 IPERF 12/8/1986 IPERF 12/8/1986 IPERF 12/8/1986 IPERF 12/8/1986 RPERF 12/811986 IPERF Comment 5" CSQ Gun, 120 ph 2 1/8" EJ; 180 ph; Ort +/- 90 F/Lowside 2 1/8" EJ; 180 ph; Ort +/- 90 F/Lowside 2 1/8" EJ; 180 ph; ort +/- 90 F /Lowside 2 1/8" EJ; 180 ph; ort +/- 90 F/Lowside 21/8" EJ; 180 ph; Ort +/- 90 F/Lowside 21/8" EJ; 180 ph; Ort +/- 90 F/Lowside 2 1/8" EJ; 180 ph; Ort +/- 90 F/Lowside 2118" EJ; 180 ph; ort +/- 90 F/Lowside 21/8" EJ; 180 ph; Ort +/- 90 F/Lowside 2 1/8 Tornado Link, 90 ph 21/8 Tornado Link, 90 ph 2 1/8 Tornado Link, 90 ph 2 1/8 Tornado Link, 90 ph 2118 Tornado Link, 90 ph 4" Csg Gun, 0 deg ph 4" CSQ Gun, 0 deg ph 4" Csg Gun, 0 deg ph 4" Csg Gun, 0 deg ph 4" Csg Gun, 0 deg ph V OD I Latch Port TRO' Date Vlv Run Cmnt 1.0 BK 0.156 1364 3/19/2004 1.0 BK 0.156 1350 3/19/2004 1.0 BK 0.188 1371 3/19/2004 1.0 BK 0.000 0 6/1/2004 1.0 BK 0.000 0 9/26/1999 1.5 RK 0.000 0 5/31/2004 7 8856 6427 Merla TMPO 8 8928 6475 Merla TMPD 9 9042 6553 Merla TMPD . øtftijr(ÞIUg$¡...;èêI Jlp~¡.êtd;¡)..~;..ÛEWELR¥. Depth TVD' Type 1824 1688 SSSV 7045 5230 PACKER Port TRO DMY 1.0 BK 0.000 0 DMY 1.0 BK 0.000 0 DMY 0 Run 4/13/2004 4/13/2004 4/13/2004 Vlv Cmnt ID 2.310 1.320 1.468 7072 5248 PACKER 8798 6388 SBR 8816 6400 PKR 9083 6581 PKR 9099 6592 NIP 9110 6599 SOS 9111 6600 TTL Cameo'TROP-1A-SSA' TOP ECLIPSE PACKER ASSEMBLY W/SPACKER & SNAP LATCH ASSEMBLY (OVL 34.35' W/1.320" 10) BOTTOM ECLIPSE PACKER W/MID ELEMENT set 6/7/2004. ATTEMPT TO SET TOP PACKER FAILED, FISHED & PULLED 6/8/04 Cameo 'OEJ' Cameo 'HRP-1-SP' Baker 'DB' Cameo '0' Nipple NO GO Cameo t= 2.313 2.347 3.250 2.250 2.441 2.441 Alter Casing Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 69' 1. Operations Performed: r"\ ~ Abandon STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS D Suspend D Operation Shutdown D D Repair Well 0 Plug Perforations D D Pull Tubing D Perforate New Pool D 4. Current Well Status: Development - B Stratigraphic D Perforate D Variance D Annular Disp. D Stimulate D Time Extension D Other D Re-enter Suspended Well D 5. Permit to Drill Number: 186-152/ 6. API Number: 50-029-21642-00 Exploratory D Service D 9. Well Name and Number: 3K-17 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 10. FieldlPool(s): Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING Perforation depth: measured 9584' feet true vertical 6951' feet measured 9584 feet true vertical 6951 feet Length Size MD 115' 16" 115' 4692' 9-5/8" 4761' 9443' 7" 9512' Plugs (measured) Junk (measured) TVD Burst Collapse 115' 3704' 6896' RECEIVF:") MAY 202004 Alaska Oil & Gas COf¡v. --"""h,f.¡on Anchorage Measured depth: 8970-8994,9189-9209,9229-9246,9253-9281,9326-9334' true vertical depth: 6504-6520,6655-6670,6684-6697,6702-6723,6756-6762' Tubing (size, grade, and measured depth) 2-7/8', J-55, 9111' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP'; BAKER 'DB' pkr= 8816'; 9083' SSSV= SSSV SSSV= 1824' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Oil-Bbl 115 419 Representative Daily Average Production or Injection Data Gas-Me! Water-Bbl 120 325 104 320 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: oil0 GasD WAGD WDSPLD CasinQ Pressure 1378 1285 TubinQ Pressure 169 166 Service D GINJD WINJD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Dethlefs/McConnell p~inted Name ~erry DethlefoS ~ Signature 7 ~~ c ? ~ Title Problem Well Supel'\¡ Phone 659-7224 ORIGINAL R8DMS 8Fl MAV 2 V 7"O~ ~?,A/ Date SUBMIT IN DUPLICATE Form 10-404 Revised 2/2003 . r"\ ~ ConocoPhillips Alaska, Inc. Kuparuk We1l3K-17 (PTD 1861520) Report of Sundry Operations 05/17/04 ConocoPhillips Kuparuk production we1l3K-17 tubing was patched 05/14/04 to repair a tubing leak at 7054' MD. The patch is 2-7/8", 20-feet long, retrievable style. The patch set depths are: Top: 7042' MD Bottom: 7062' MD NSK Problem Well Supervisor 05/17/04 SSSV (1824-1825, OD:2.875) SBR (8798-8799, OD:2.875) PKR (8816-8817, OD:6.151) PKR (9083-9084, OD:6.151) NIP (9099-9100, OD:2.875) TUBING (0-9111, OD:2.875. ID:2.441) Perf (9189-9209) Perf (9231-9231) Perf (9253-9253) Perf (9263-9263) Perf (9275-9281) Perf (9326-9334) ~ ConocòPhUlips Alaska, Inc. 31<117 c,!' "............. API: 500292164200 SSSV Type: TRDP Annular Fluid: Reference Log: Last Tag: 9328 LastTag Date: 3/17/2004 Casing String "eASINGS Description CONDUCTOR SURF CASING PROD CASING Tubing String-TUBING ~~~~ I T~P. t, Pèrforations:,SUll'Ímary ; Interval TVD 8970 - 8994 6504 - 6520 9189 - 9199 6655 - 6663 9199 - 9199 6663 - 6663 9199 - 9203 6663 - 6665 9203 - 9203 6665 - 6665 9203 - 9205 6665 - 6667 9205 - 9205 6667 - 6667 9205 - 9207 6667 - 6668 9207 - 9207 6668 - 6668 9207 - 9209 6668 - 6670 9229 - 9231 6684 - 6686 9231 - 9231 6686 - 6686 9231 - 9244 6686 - 6695 9244 - 9244 6695 - 6695 9244 - 9246 6695 - 6697 9253 - 9253 6702 - 6702 9258 - 9258 6706 - 6706 9263 - 9263 6709 - 6709 9275- 9281 6718 - 6723 9326 - 9334 6756 - 6762 Gas lift MandrèlsNalves, c St MD TVD Man Mfr .~ KRU Well Type: PROD Orig Completion: 8129/1986 Last W/O: Ref Log Date: TO: 9584 ftKB Max Hole Angle: , 51 deg @ 2700 Size 16.000 9.625 7.000 , , Zone Status C-1,UNIT B A-3 A-3 A-3 A-3 A-3 A-3 A.3 A.3 A-3 A-2 A-2 A-2 A-2 A-2 A-2 A-2 A-2 A-2 A-1 1 3090 2547 Merla 2 5560 4228 Merla 3 6988 5193 Merla 4 7794 5725 Merla 5 8287 6047 Merla 6 8748 6354 Merla PiØduction ' MandrelsIValYø St MD TVD Man Mfr Man Type Man Type TMPD TMPD TMPD TMPD TMPD TGPD VMfr VMfr 7 8856 6427 Merla TMPD 8 8928 6475 Merla TMPD 9 9042 6553 Merla TMPD Other (ÞIuQs. èéìuip.. etc.)- JEWELRY Depth TVD Type 1824 1688 SSSV 8798 6388 SBR 8816 6400 PKR 9083 6581 PKR 9099 6592 NIP 9110 6599 SOS 9111 6600 TTL Cameo'TRDP-1A-SSA' Cameo 'OEJ' Cameo 'HRP-1-SP' Baker 'DB' Cameo '0' Nipple NO GO Cameo Top 0 0 0 3K-17 Angle @ TS: 48 deg @ 8906 Angle@TD: 41 deg@9584 Rev Reason: add port size, tag Last Update: 5/1412004 Bottom TVD Wt Grade Thread 115 115 62.50 H-40 4761 3704 36.00 J-55 9512 6896 26.00 J-55 "" Wt I Grade I Thread 6.50 J-55 EUE 8RD AB MOD , , Ft SPF Date Type 24 12 12/8/1986 IPERF 10 8 6/13/1996 RPERF 0 9 4 8 0 9 2 8 0 9 2 8 0 9 2 8 2 4 0 5 13 4 0 5 2 4 0 1 0 1 0 1 6 2 8 1 V Type GLV GLV GLV GLV DMY OV V Type DMY DMY DMY 6/13/1996 RPERF 6/13/1996 RPERF 6/13/1996 RPERF 6/13/1996 RPERF 6/13/1996 RPERF 6/13/1996 RPERF 6/13/1996 RPERF 6/13/1996 RPERF 4/24/1988 IPERF 4/24/1988 IPERF 4/24/1988 IPERF 4/24/1988 IPERF 4/24/1988 IPERF 12/811986 IPERF 12/8/1986 IPERF 12/811986 IPERF 12/8/1986 RPERF 12/8/1986 IPERF VOD Latch Port 1.0 BK 0.156 1.0 BK 0.156 1.0 BK 0.188 1.0 BK 0.188 1.0 BK 0.000 1.5 RK 0.188 V OD Latch 1.0 1.0 1.0 BK BK BK Description Comment 5" Csg Gun, 120 ph 21/8' EJ; 180 ph; Ort +/- 90 F/Lowside 21/8" EJ: 180 ph; Ort +/- 90 F/Lowside 21/8" EJ; 180 ph; Ort +/- 90 F/Lowside 2 1/8" EJ; 180 ph; Ort +/- 90 F/Lowside 21/8" EJ; 180 ph; Ort +/- 90 F/Lowside 21/8" EJ; 180 ph; Ort +/- 90 F/Lowside 2 1/8" EJ; 180 ph; Ort +/- 90 F/Lowside 21/8" EJ; 180 ph; Ort +/- 90 F/Lowside 2 118" EJ; 180 ph; Ort +/- 90 F/Lowside 2 1/8 Tornado Link, 90 ph 2 1/8 Tornado Link, 90 ph 2 1/8 Tornado Link, 90 ph 2 1/8 Tornado Link, 90 ph 2 1/8 Tornado Link, 90 ph 4" Csg Gun, 0 de¡¡ ph 4" Csg Gun, 0 deg ph 4" Csg Gun, 0 deg ph 4" Csg Gun, 0 de¡¡ ph 4" Csp Gun, 0 deg ph TRO Date Run 1364 3/1912004 1350 3/1912004 1371 3/1912004 1355 3/1912004 0 9/26/1999 0 3/19/2004 Vlv Cmnt Port TRO Date Vlv Run Cmnt 0.000 0 4/1312004 0.000 0 4/1312004 0.000 0 4/13/2004 ID 2.310 2.313 2.347 3.250 2.250 2.441 2.441 é\ o~Lo-lû~ c!ds". WEU LOG TRANSMrn- AL ProActive Diagnostic SelVices, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 AE: Distribution - Final Print(s} The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 WELL DATE loG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUE LINE Open Hole 1 Res. Eva!. CH 1 1 1 Mech. CH 3K-17 2-15-04 Caliper Survey 1 Apt or 2 Color Signed: ~4 '" ö \. ~ J... ~ '- G - C"<. ~ ~ AÎ'- Date: RECEIVED MAR 2 2 2004 Print Name: Alaska Oil & Gas Q)ns. COIrIIßID PRoAcTivE DÎAGNOSTic SERVicES, INC., PO Box 1 ~69 STAffoRd ~ Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com RBDMS RD MAR 2 5 2004 } ~'ÚJ - )5~ - Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: CONOCOPHILLIPS ALASKA INC February 15, 2004 5317 1 27/8" 6.5 lb. J-55 EUE 8RD Tubing Well: Field: State: API No.: Top Log Intvl1.: Bot. Log IntvI1.: 3K-17 Kuparuk Alaska 50-029-2164200 Surface 9,O84Ft. (MD) Inspection Type: Tubing Patch Assessment COMMENTS: This caliper data is tied into the Packer @ 9,083' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages for potential patching operations. The caliper recordings indicate that the 2 7/8" tubing is in good to fair condition. The maximum recorded wall penetration of 25% wall thickness is recorded in pup joint 1.3 @ 84'. A minimum 10 of 2.20" is recorded in Joint 264 @ 8,596', in an area of buckled tubing. The buckled tubing is recorded in the interval from 6,300' - 8,800'. No Significant Cross-sectional wall loss is recorded in the interval logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting. Corrosion Line Corrosion. Corrosion ( 25%) ( 24%) ( 24%) ( 21%) Pup Jt. Jt. Jt. Jt. 1.3 131 160 194 @ @ @ @ 84 Ft. (MD) 4,261 Ft. (MO) 5,204 Ft. (MD) 6,314 Ft. (MD) No other significant wall penetrations (>20%) are recorded throughout the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No Significant Cross-Sectional Wall Loss (>12%) is recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: Buckling. Min 10 = 2.20 Jt. 264 @ 8,596 Ft. (MD) Buckling. Min 10 = 2.25 Jt. 254 @ 8,259 Ft. (MD) Buckling. Min 10=2.25 Jt. 267 @ 8,693 Ft. (MD) Buckling. Min 10 = 2.26 Jt. 253 @ 8,252 Ft. (MD) Buckling. Min ID=2.26 Jt. 268 @ 8,750 Ft. (MD) I Field Engineer: D. Cain Analyst: J. Thompson Witness: M. Chaney RBDMS RD ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 RECEIVED MAR 2 2 2004 Alaska Oil & Gas Cons. Cornmí8aion Anchcøge MAR 2 5 2004 - - Q. Well: Field: Company: Country: 3K-17 KUPARUK CONOCOPHILLIPS ALASKA USA I Tubing: Weight 6.5 ppf Grade & Thread J-55 EUE 8RD Nom.OD 2.875 ins Penetration and Metal Loss (% wall) - penetration body 250 - metal loss body 200 150 100 50 0 0 to 1% 1 to 10% 10 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 281) pene. 0 75 202 4 0 loss 41 238 1 1 0 0 0 Damage Configuration ( body) 40 30 20 10 0 Isolated pitting general line ling hole 1 poss corrosion corrosoon corrosoon ible hole Number of joints damaged (total = 62) 33 19 10 0 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 2.441 ins February 15, 2004 MFC 24 No 99628 1.69 24 J. Thompson Upper len. 1.2 ins Lower len. 1.2 ins Nom. Upset 2.875 ins Damage Profile (% wall) - penetration body 0 1 - metal loss body 50 100 GLM6 GLM 5 GLM4 ~ GLM3 =f GLM2 GLM 1 Bottom of Survey = 276.1 Analysis Overview page 2 Joint Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 LosS 1.0. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 \..- - 1 29 0 0.02 10 2 2.34 - ~ 1.1 62 0 0.01 6 4 2.37 pUP " 1.2 77 0 0.01 4 1 2.41 PUP t - U 82 0 0.05 25 21 2.40 PUP Isolate Pittin2. 2 84 0 0.Q3 14 2 2.35 3 116 0 0.02 11 1 2.36 II 4 149 0 0.03 15 3 2.36 Shallow oittin2. II 5 181 0 0.03 13 2 2.35 II 6 213 0 0.02 10 2 2.37 II 7 246 0 0.02 11 2 2.35 II \ \ \ 8 279 0 0.02 10 2 2.35 : \ 9 312 0 0.03 12 1 2.35 10 344 0 0.03 14 2 2.35 11 376 0 0.03 15 2 2.35 Shallow pittin¡1;. 12 409 0 0.02 10 2 2.36 13 441 0 0.04 18 2 2.35 Shallow nittin2. . 14 473 0 0.02 11 2 2.34 \ 15 506 0 0.03 12 1 2.37 II 16 538 0 0.01 6 1 2.36 . \ 17 570 0 0.02 11 2 2.34 II 18 603 0 0.03 14 3 2.37 lIt 19 635 0 0.02 11 2 2.37 II \ 20 666 0 0.03 12 1 2.37 II 21 699 0 0.03 13 1 2.35 II 22 732 0 0.03 13 2 2.33 II 23 764 0 0.Q3 14 2 2.34 II 24 796 0 0.02 7 1 2.36 Lt. Denosits. II \ 25 827 0 0.01 6 1 2.38 II 26 858 0 0.01 6 1 2.38 . 27 889 0 0.03 12 1 2.37 II 28 922 0 0.02 11 1 2.36 II 29 955 0 0.01 4 2 2.35 Lt. Denosits. 30 987 0 0.03 12 2 2.37 II 31 1019 0 0.03 13 1 2.38 II 32 1052 0 0.01 7 1 2.38 . 33 1083 0 0.02 7 1 2.39 . 34 1115 0 0.01 6 1 2.38 . 35 1147 0 0.02 8 1 2.39 ,. 36 1177 0 0.01 5 1 2.39 . 37 1209 0 0.02 8 1 2.40 II 38 1240 0 0.02 7 1 2.40 II 39 1271 0 0.02 9 0 2.39 II 40 1302 0 0.01 7 1 2.40 II 41 1334 0 0.02 9 1 2.38 II 42 1365 0 0.01 6 1 2.39 \ 43 1396 0 0.01 6 2 2.39 . 44 1428 0 0.01 7 2 2.39 . 45 1459 0 0.02 11 2 2.37 II 46 1492 0 0.02 7 1 2.40 II 47 1524 0 0.01 6 1 2.39 . - PDS REPORT JOINTTABULATION SHEET -- 3K-17 KUPARUK CONOCOPHILUPS ALASKA USA February 15, 2004 pipe: Body Wall: Upset Wall: Nominal 1.0.: 2.875 in 6.5 ppf J-55 £U£ BRD 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: - - - Page 1 - - 'Penetration Body Metal Loss Body Pipe: Body Wall: Upset Wall: NominaII.D.: Joint No. 48 49 50 51 52 53 54 55 55.1 55.2 56 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 94.1 PDS REPORT JOINT TABULATION SHEET 2.875 in 6.5 ppf J-55 EUE 8RD 0.217 in 0.217 in 2.441 in Depth (Ft.) 1555 1587 1621 1652 1685 1718 1749 1781 1813 1817 1826 1858 1892 1923 1955 1988 2021 2050 2082 2115 2147 2179 2212 2245 2277 2310 2342 2374 2407 2440 2472 2505 2537 2570 2602 2633 2666 2698 2730 2762 2795 2827 2860 2893 2923 2956 2988 3021 3053 3085 Pen. Upset (Ins.) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.02 0 Pen. Body (Ins.) 0.02 0.03 0.03 0.03 0.03 0.02 0.02 0.03 0.02 0 0.03 0.02 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.01 0.02 0.03 0.03 0.01 0.02 0.01 0.02 0.01 0.03 0.03 0.02 0.03 0.03 0.04 0.03 0.04 0.04 0.04 0.02 0.03 0.03 0.03 0.02 0.04 0.03 0.03 0.03 0.03 0.02 0 Pen. Metal % Loss % 10 12 12 12 13 7 10 12 7 0 12 11 15 14 13 13 12 12 12 5 10 12 13 5 9 6 10 6 12 15 10 15 14 17 13 17 18 18 10 12 12 14 7 17 13 12 16 12 10 0 2 2 2 1 2 1 2 1 1 0 2 2 3 2 1 1 1 1 3 3 2 3 4 1 2 2 2 4 2 3 3 3 2 3 3 2 4 3 5 2 3 3 3 4 5 3 2 4 2 0 Min. I.D. (Ins.) 2.37 2.38 2.37 2.37 2.38 2.36 2.36 2.36 2.40 2.31 2.36 2.37 2.36 2.37 2.35 2.35 2.35 2.35 2.34 2.33 2.32 2.27 2.29 2.29 2.29 2.32 2.34 2.35 2.37 2.34 2.35 2.34 2.34 2.33 2.34 2.34 2.32 2.32 2.33 2.32 2.34 2.34 2.31 2.31 2.32 2.33 2.33 2.31 2.33 N/A Well: Field: Company: Country: Survey Date: 3K-17 KUPARUK CONOCOPHILLIPS ALASKA USA February 15, 2004 Comments Lt. Deposits. PUP SSSV Shallow pitting. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Lt. Deposits. Shallow pitting. Lt. Deposits. Lt. Deposits. Shallow pitting. Shallow pitting. Lt. Deposits. Lt. Deposits. Shallow corrosion. Shallow corrosion. Lt. Deposits. Shallow corrosion. Lt. Deposits. Lt. Deposits. Lt. Deposits. Shallow pitting. Lt. Deposits. Lt. Deposits. Lt. Deposits. Shallow corrosion. Lt. Deposits. Lt. Deposits. GLM 1 Page 2 Damage Profile (%wall) 0 50 100 I I I I I I II II II ~I t: ~ I ~ t! \ I \ I I I , I I I \ I \ I ~ I f: \ I : I I: \ I II ~ I I Penetration Body Metal Loss Body PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD Well: 3K-l 7 Body Wall: 0.217 in Field: KUPARUK Upset Wall: 0.217 in Company: CONOCOPHllLiPS ALASKA NominaII.D.: 2.441 in Country: USA Survey Date: February 15, 2004 Joint Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % loss I.D. Comments (%wall) (Ins.) (Ins.) % (Ins.) 0 50 100 95 3093 0 0.03 13 3 2.29 : I 96 3125 0 0.02 7 2 2.29 97 3157 0 0.03 14 3 2.30 It. Deposits. ~I 98 3190 0 0.01 6 1 2.32 99 3222 0 0.03 13 2 2.33 ) I 100 3255 0 0.03 13 1 2.34 \ I 101 3287 0 0.02 11 3 2.32 It. Deposits. \ I 102 3320 0 0.03 12 2 2.33 \ I 103 3352 0 0.03 15 2 2.33 Shallow pitting. ¡ I 104 3385 0 0.02 9 3 2.33 105 3417 0 0.03 14 4 2.34 Corrosion. It. Deposits. ¡: 106 3450 0 0.03 13 4 2.34 It. Deposits. 107 3482 0 0.02 10 2 2.33 It. Deposits. 1 I 108 3515 0 0.03 13 2 2.34 It. Deposits. \ I 109 3548 0 0.03 16 2 2.34 Shallow pitting. I I 110 3580 0 0.03 13 2 2.33 \ I 111 3612 0 0.03 12 2 2.32 It. Deposits. \ I 112 3645 0 0.03 12 2 2.34 It. Deposits. \ I 113 3676 0 0.03 16 2 2.36 Shallow pitting. It. Deposits. \ I 114 3708 0 0.02 10 1 2.34 I I 115 3739 0 0.03 13 3 2.34 Lt. Deposits. I I 116 3772 0 0.03 12 1 2.30 \ I 117 3804 0 0.04 17 2 2.32 Shallow pitting. II 118 3836 0 0.03 15 2 2.33 Shallow pitting. \ I 119 3871 0 0.03 12 3 2.33 It. Deposits. ~ I 120 3900 0 0.03 12 4 2.33 Lt. Deposits. ~I 121 3935 0 0.02 10 3 2.33 Lt. Deposits. \ I 122 3967 0 0.03 16 2 2.32 Shallow pitting. Lt. Deposits. ~ 123 4000 0 0.02 10 6 2.32 It. Deposits. 124 4032 0 0.03 15 2 2.33 Shallow pitting. It. Deposits. 125 4065 0 0.03 14 3 2.33 Shallow pitting. Lt. Deposits. \ I 126 4097 0 0.03 12 3 2.34 Lt. Deposits. \ I 127 4129 0 0.04 18 2 2.32 Shallow pitting. Lt. Deposits. t I 128 4162 0 0.03 15 3 2.31 Shallow pitting. Lt. Deposits. ~ I 129 4195 0 0.02 10 2 2.32 It. Deposits. 130 4228 0 0.03 12 3 2.32 Lt. Deposits. \ I 131 4260 0 0.05 24 3 2.32 Corrosion. Lt. Deposits. \ I 132 4293 0 0.03 13 2 2.31 Corrosion. Lt. Deposits. \ I 133 4325 0 0.02 11 2 2.33 It. Deposits. ! I 134 4357 0 0.03 16 3 2.31 Shallow pitting. Lt. Deposits. \ I 135 4390 0 0.04 17 2 2.32 Shallow pitting. \ I 136 4423 0 0.04 17 2 2.31 Shallow pitting. It. Deposits. I I 137 4455 0 0.03 15 4 2.31 Shallow pitting. Lt. Deposits. i: 138 4487 0 0.03 14 3 2.30 Lt. Deposits. 139 4519 0 0.02 10 2 2.31 Lt. Deposits. I 1 I 140 4552 0 0.03 12 3 2.32 It. Deposits. I I 141 4584 0 0.02 11 3 2.32 It. Deposits. \' 142 4617 0 0.02 10 2 2.32 It. Deposits. \ I 143 4649 0 0.03 12 2 2.32 It. Deposits. \ I 144 4681 0 0.04 19 4 2.30 Shallow corrosion. It. Deposits. ~ I IPenetration Body Metal Loss Body Page 3 Pipe: Body Wall: Upset Wall: NominaII.D.: Joint No. 145 146 147 148 149 150 151 152 153 154 155 156 157 158 159 160 161 162 163 164 165 166 167 168 169 170 170.1 171 172 173 174 175 176 177 178 179 180 181 182 183 184 185 186 187 188 189 190 191 192 193 PDS REPORT JOINT TABULATION SHEET 2.875 in 6.5 ppf J-55 EUE 8RD 0.217 in 0.217 in 2.441 in Depth (Ft.) 4714 4747 4780 4812 4846 4878 4909 4942 4974 5007 5040 5072 5105 5136 5168 5201 5234 5266 5298 5331 5364 5396 5429 5462 5494 5525 5557 5567 5598 5631 5662 5695 5728 5761 5793 5826 5857 5890 5922 5955 5987 6019 6052 6085 6118 6151 6180 6214 6248 6280 Pen. Upset (Ins.) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Pen. Body (Ins.) 0.01 0.03 0.03 0.04 0.03 0.03 0.03 0.03 0.02 0.03 0.03 0.03 0.03 0.02 0.03 0.05 0.04 0.04 0.04 0.04 0.04 0.04 0.04 0.03 0.04 0.04 0 0.03 0.03 0.02 0.04 0.04 0.02 0.04 0.03 0.03 0.04 0.03 0.04 0.04 0.03 0.02 0.03 0.04 0.02 0.03 0.03 0.03 0.02 0.02 Pen. Metal % loss % 6 13 16 18 13 13 14 13 9 13 13 16 14 10 13 24 19 19 18 18 16 18 18 16 19 20 0 12 12 7 16 18 10 18 12 13 18 14 18 16 15 10 14 17 11 14 16 13 10 10 4 5 2 2 3 3 3 3 2 2 4 3 2 5 4 4 3 4 4 4 4 4 5 2 4 3 0 3 3 3 3 4 3 4 5 4 3 3 2 2 2 3 2 3 3 3 2 2 3 4 Min. 1.0. (Ins.) 230 2.31 2.30 2.29 2.29 2.30 2.33 2.30 2.32 2.29 2.29 2.27 2.27 2.28 2.30 2.29 2.30 2.29 2.32 2.30 2.31 2.31 2.31 2.33 2.32 2.29 N/A 2.31 2.31 2.32 2.31 2.30 2.31 2.29 2.29 2.29 2.31 2.31 2.31 2.32 2.33 2.32 2.31 2.33 2.33 2.33 2.35 2.34 2.33 2.33 Well: Field: Company: Country: Survey Date: 3K-17 KUPARUK CONOCOPHllUPS ALASKA USA February 15, 2004 Comments Lt. Deposits. It. Deposits. Shallow pitting. Shallow pitting. Lt. Deposits. It. Deposits. Lt. Deposits. It. Deposits. It. Deposits. It. Deposits. line Corrosion Lt. Deposits. line Corrosion. Lt. Deposits. It. Deposits. Lt. Deposits. line corrosion. Lt. Deposits. line corrosion. It. Deposits. line shallow corrosion. Lt. Deposits. line shallow corrosion. Lt. Deposits. Shallow corrosion. Lt. Deposits. Shallow line corrosion. Lt. Deposits. Shallow line corrosion. It. Deposits. line corrosion. Lt. Deposits. Shallow corrosion. It. Deposits. Shallow corrosion. Lt. Deposits. Shallow corrosion. It. Deposits. Corrosion. It. Deposits. GLM 2 Lt. Deposits. Lt. Deposits. Lt. Deposits. Shallow pitting. Lt. Deposits. Shallow corrosion. Lt. Deposits. Lt. Deposits. Shallow pitting. Lt. Deposits. It. Deposits. Lt. Deposits. Shallow pitting. It. Deposits. Lt. Deposits. Line shallow corrosion. Shallow pitting. Shallow pitting. It. Deposits. Shallow pitting. It. Deposits. Lt. Deposits. Shallow pitting. It. Deposits. It. Deposits. Lt. Deposits. Slight Buckling. Page 4 Damage Profile (% wall) 0 50 100 I .1 \ I II \ I J 1 \ 1 \ I II \ I I I \ I \ 1 II I . 1 I I I I I : . I II I: \ I , . I I ~ I . \ I : I II I I . I I I I II ~I \ I II \ I i I \ I J I \ I . I I I . I J I \ I . I I Penetration Body Metal loss Body - PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD Well: 3K-17 Body Wall: 0.217 in Field: KUPARUK Upset Wall: 0.217 in Company: CONOCOPHILLIPS ALASKA NominaII.D.: 2.441 in Country: USA Survey Date: February 15, 2004 Joint Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (Ins.) (Ins.) % (Ins.) 0 50 100 194 6311 0 0.05 21 6 2.36 Corrosion. Slight Buckling. ,: 195 6345 0 0.03 16 3 2.30 Corrosion. Slight Buckling.. 196 6377 0 0.02 10 3 2.34 Slight Buckling. \ I 197 6409 0 0.02 11 2 233 Slight Buckling. \ I 198 6441 0 0.02 10 2 2.30 Slight Buckling. : I 199 6475 0 0.02 7 3 2.32 Slight Buckling. 200 6508 0 0.03 13 3 2.33 Slight Buckling. \ I 201 6538 0 0.03 13 2 2.33 Slight Buckling. \ I 202 6569 0.03 0.03 14 2 2.32 Slight Buckling. I I 203 6603 0 0.04 20 2 2.31 Slight Buckling. II 204 6635 0 0.02 11 5 2.35 Slight Buckling. 1: 205 6668 0 0.03 12 3 2.33 Slight Buckling. 206 6700 0 0.03 14 6 2.34 Slight Buckling. '1 207 6732 0 0.01 4 2 2.35 Slight Buckling. 208 6765 0 0.03 12 3 2.31 Slight Buckling. I I 209 6798 0 0.02 10 4 2.31 Slight Buckling. ~ I 210 6828 0 0.03 13 3 2.34 Slight Buckling. ~ I 211 6861 0 0.03 12 2 2.33 Slight Buckling. I I 212 6892 0 0.02 11 4 2.29 Slight Buckling. ~ I 213 6924 0 0.03 13 1 2.34 Slight Buckling. I I 214 6955 0 0.03 12 4 2.32 Slight Buckling. r I 214.1 6988 0 0 0 0 N/A GLM 3 215 6996 0 0.03 15 3 2.32 Moderate Buckling. \ I 216 7029 0.02 0.03 15 2 2.32 Moderate Buckling. \ I 217 7060 0 0.03 15 3 2.30 Moderate Buckling. \ I 218 7092 0 0.03 12 3 2.30 Moderate Buckling. ~ 219 7124 0 0.04 17 5 2.30 Moderate Buckling. 220 7155 0 0.03 14 4 2.30 Moderate Buckling. f I 221 7187 0 0.02 11 3 2.29 Moderate Buckling. 222 7217 0 0.03 12 3 2.31 Corrosion. Moderate Buckling. ~ 223 7248 0 0.03 12 10 2.28 Moderate Buckling. 224 7279 0 0.02 10 12 2.30 Moderate Buckling. 225 7310 0.03 0.03 12 1 2.30 Moderate Buckling. 226 7343 0 0.02 10 3 2.33 Corrosion. Moderate Buckling. I I 227 7375 0 0.03 15 2 2.31 Corrosion. Moderate Buckling. I I 228 7408 0 0.02 9 2 2.38 Moderate Buckling. I I 229 7439 0 0.02 8 4 2.36 Moderate Buckling. ~ 230 7471 0 0.03 13 5 2.33 Moderate Buckling. 231 7503 0 0.03 13 2 2.29 Moderate Buckling. 232 7536 0 0.02 9 4 2.32 Moderate Buckling. 233 7567 0 0.04 20 6 2.33 Moderate Buckling. r: 234 7601 0 0.04 17 4 2.29 Moderate Buckling. 235 7633 0.04 0.04 18 2 2.31 Moderate Buckling.. II 236 7666 0 0.03 15 2 2.32 Moderate Buckling. \ I 237 7698 0 0.03 15 4 2.33 Moderate Buckling. ¡: 238 7730 0 0.03 13 5 2.33 Moderate Buckling. 239 7762 0 0.03 15 4 2.32 Moderate Buckling. I I 239.1 7793 0 0 0 0 N/A GLM 4 ~I 240 7804 0 0.03 14 7 2.34 Moderate Buckling. 241 7833 0 0.04 18 2 2.34 Moderate Buckling. I I IPenetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABULATION SHEET Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD Well: 3K-17 Body Wall: 0.217 in Field: KUPARUK Upset Wall: 0.217 in Company: CONOCOPHILLIPS ALASKA NominaILD.: 2.441 in Country: USA Survey Date: February 15, 2004 Joint Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss !.D. Comments (%wall) (Ins.) (Ins.) % (Ins.) 0 50 tOO 242 7866 0 0.02 11 4 2.34 Moderate Buckling. ~ I 243 7899 0 0.04 17 3 2.30 Moderate Buckling. \ I 244 7932 0 0.03 15 3 2.30 Moderate Buckling. ~ I 245 7965 0 0.04 19 3 2.28 Moderate Buckling. \ I 246 7998 0 0.04 19 2 2.27 Moderate Buckling. II 247 8029 0 0.03 15 2 2.28 Moderate Buckling. t: 248 8061 0 0.04 18 5 2.31 Moderate Buckling. 249 8093 0 0.03 13 4 2.31 Moderate Buckling. 250 8126 0 0.02 9 4 2.33 Moderate Buckling. I I 251 8158 0 0.03 13 4 2.30 Moderate Buckling. ~ I 252 8189 0 0.03 12 4 2.32 Moderate Buckling. 1: 253 8223 0 0.04 18 3 2.26 Moderate Buckling. 254 8256 0 0.04 18 4 2.25 Moderate Buckling. II 254.1 8287 0 0 0 0 N/A GLM 5 L 255 8296 0 0.04 19 5 2.28 Buckling. 256 8327 0 0.04 18 2 2.28 Buckling. ~: 257 8359 0 0.04 18 6 2.31 Buckling. 25B B392 0 0.04 17 3 2.32 Buckling. 259 8424 0 0.04 19 3 2.31 Buckling. ~ I 260 8456 0 0.02 11 4 2.32 Buckling. ~ I 261 8489 0 0.04 19 3 2.30 Buckling. r! 262 8522 0 0.04 20 7 2.31 Buckling. 263 8554 0 0.04 16 3 2.30 Buckling. 264 8587 0 0.04 16 5 2.20 Buckling. 265 8619 0.02 0.03 14 3 2.26 Buckling. I \ 266 8652 0 0.03 15 5 2.27 Buckling. 1: 267 8685 0 0.04 18 6 2.25 Buckling. 268 8717 0 0.04 17 5 2.26 Buckling. 268.1 8750 0 0 0 0 N/A GLM 6 ~ I 269 8760 0 0.03 13 5 2.30 Buckling. 269.1 8794 0 0 0 0 2.31 SBR II 269.2 8818 0 0 0 0 2.35 PACKER 270 8825 0 0.03 13 2 2.33 Lt. Deposits. ¡ I 270.1 8851 0 0 0 0 N/A Prod Man 7 271 8865 0 0.03 12 3 2.35 Lt. Deposits. ~ 272 8897 0 0.01 7 2 2.36 272.1 8927 0 0 0 0 N/A Prod Man 8 I 273 8937 0 0.02 9 3 2.39 Lt. Deposits. I 274 8965 0 0.02 9 6 2.35 275 8999 a 0.01 3 6 2.35 275.1 9028 0 0.01 5 3 2.37 PUP 275.2 9041 a a 0 0 N/A Prod Man 9 ~I 276 9051 0 0.03 16 6 2.30 Isolated pitting. Lt. Deposits. 276.1 9083 0 0 0 0 3.25 PACKER I Penetration Body Metal Loss Body Page 6 ~. PDS Report Cross Sections Well: Field: Company: Country: Tubing: 3K-17 KUPARUK CONOCOPHILLIPS ALASKA USA 2.875 ins 6.5 ppf J-55 EUE 8RD Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: February 15, 2004 MFC 24 No 99628 1.69 24 j. Thompson Cross Section for joint 1.3 at depth 83.46 ft Tool speed = 56 Nominal 10 = 2.441 Nominal 00 = 2.875 Remaining wall area = 79 % Tool deviation = 0 ' Finger 15 Penetration = 0.054 ins Cross Sections page 1 k;;::::~ÞHIL;LIPS Àla.{~rl;;}'lnc. ~ At Sibs. of Pt4I.llPS PEmðLE\.t.4bøN'l' , 3K.17 . - API: 5110282164200 . Well T¥DI: PROD = = TFI~p . . ~~; 8$t19_¥ ~er_la9=. '. Of.'1J..-G¡,..- Rell,¡ j.tt:" --TaG:, - .J...,J ,I, .."*t1K8 lJØ TrIa OUt; - '1 -r ...... Hvht 51 doG . ~ ~h 1:= t. fÓ' I ~m I PROOCASING ?ÐOO ¡ !lS1} ~ mrint - TUBING. ' :87& 1 T~ I B~ I ~ I ~ l ~de I PettorÏdÏone SIlCMlUY InIIørYaI WI) Zone SQtÚs 8010 - 8004 650&.6520 C.t .UNIT IS 1'12/64/21'11'14 sssv - (18t+I82S. 00:2.8761 seA (8m.a- rouTS) PICA 18IItrtØ17. 00:8.15t) PKR (OQU-IOIM. 01>.8.15') NO GO (~'9!OO. OC.2.87S TUBiNG (1).1111. oo1..87S. ID:U41) I'dl! (9"'92001 I'dll (92S1-a231) Pell (lJ253425G POll (927H281) P~II rm6-m4I 16:1'19 913765'37314 :r. ."- l" " NSK WELLS GROUP PAGE 05 .~.:':. ,~,:: .:KRU 3K~11 A(lqIt Z 1'8: ""11. $$06 Arde '1C5:"'1 d8ø l"~ R81AeøDn: TIg. GlV..' ;¡ I.nt u.ø-: ~koO' . :'~ I = Ie; I ThroacI 6898 2 ;.OO J-:iIj ThleØ EUE_8RO AB MOl) . itllll.lt. IIe5 . IIIIœ A-3 91111- lil89 68G3 . 6883 A.3 9199-9203 8883 . 666.5 A.! II2O:J . !I2Q; 8àII5 "GaCIŠ A.a 11203 . t2OS CI665 . 66&7 A.t . ~-!Rœ 0fJf1-"1 "".3 9205 . mT 81.-- A.a 8207 .1201 61168 . 61168 ~3 9207 - 9209 EI898 . 6670 A4 '. Ft SPf D:Ita T..ø» ëamment 24 12 1t/811988 ÆftF )'Csg Iiun. 120 pi¡ 10 . em/ll1116 /V'&fF tl".6J; ,acfp,.:OIt...-go ~ 8, 8/1311998 RPaIF ~'eopb:OIt+I-80 - FIlcMSIIIII 4 8 8/1311- RPfjAf 2118' E.t 180 I/I;Odotl'9C) I"IlOMÍdII 0 SI ClI3f1aD6 RPeRF 21lrEJ:'SOIJh:0It...... O a 8 611311- I P\.PEAF ~18QpIt;OIt""'90 FJlowside 0 t 0113111196 APeRF I! W'EJ: ,aoplt;OII....9Q 2 8 1if1311911f1 APERF .r-~lIOp I:Ott'¡-80 FflGlOl8ide 0 9 S'1311!1t6 RPERF 21J8'~õ 180 pit: 0It 4-00 I'ILowIId8. . 2 8 611311996 APeRF 2118-e.¡;111Opn:Ort"'-( O ~ 2 .. AllMliIlB8 ....... 2 ~ 11llll84cL1.Jok...90 DII 0 .5 ~"' ~.!1lBTOmR4ðI.illk.90øII 13 .t 412411* ~- i!: 111 fomarIø I.fØk, er 'ò 5 ~'IISB, ~ 21I6T~()Ì1k,'" -:- ;: . .cl24l'lJIII!' IPW 2 ~I!I Tomedo I.. t4<. to ",. - 0 1 1tJBk981 IPERF ".ClllGuI. 0"'" 0 , 1:lII/1- IPERF .tf'C8IIGun.Odeøph 0 , ,~O. IilERF "'ClQØIIn,OcI8Q /1 tI ~ 1~111118 Ff'E1V ... Ç8!1Gun. Odeg,rIb.. II 1 .,21111'9IIIiI ~ '¡.~.Gull..Ocfeø.tiIí- -- 1m:m~ -ns::= ~~, !l23t -1I:Me . l1888:tíØs A.2 t:::= =:= ~i ~ - R53 6102. . ~ A>J =:~ ß:b ~~ 9215 . 9281 8718 . 8123 A-2 ~ 1tlK"rDZ: M St Mg 1VD Mall Ma" I 3090 2!4t':: = 2 5(i6O 4t2Ð MwfII 'TW'D 3 ~ ~tJ'.J NOIQ TIM"O .. 7'9« '~IIer1B 'aiPD - 5 B281 6041 1181l1li . Utl'D . - 8 1748 ~. -t,ferla TGPO PrOductIon ManclnlllNalYes St YD TVD Man Ma" lit!' TvIl8 7 II8SI!I fl4t7 Nerta rúÞo (I ¡me 11475 Merta - TNPO ....L .\IJI42..65ß .""" rUPD 0tII8I' (;lluaa. l1li"" lite.) . JEWELÄY ~ = -= CànIeoTROP.IA.w.' Ø788 8388 SSA C8tIIco 'OEJ' BaIS lWoo PKÀ c.n-'HRP-1-sP' . Q( 3 6681 PKR SlIker 'DB' ;m := ~ ='O.~ SIll 6800 111. - T.., Ç,H e. 't11.'' U<ß 1~~1. ..03 S£:'ë ~~v~ Ð ~T'.p.( '*Z- -.3 1-8~ ~~ DV Ð ~ c.{ , 1-2.0-01 t...z..C-o'i ~>JN""':> lßú-L.é,c4L ~~ L.) roool 7~O'¡.V...w... SF"'.\, z..:Z...E7 c:..A-~ ~&- C-lg-D'{ Y Mtr Y TrPe V OÐ Latch -£,'",,'1.0 ,'J1oII'.0 ~J1I.o -f,J} V" ~:X oMy t.5 Port TRO D-. VIY 'hm ::fjllll o.1~ 1309 ~ .~k UI8J31G. ~,'.. '(/I' 0.250 b ~,¡'1 .~~ O.DilO 0 ..., ,-¡t)u"" o.oao O. tI26I'I'. O.OQØ. 0 i Ql27/ttæ rJ BK IÎK = V Iot'r V Type Y OD LAtch Port TRO Date VIII . RIt" emAt I:l1o1., t.O BIt 0.000 0 8J3aI:IOO1 - -nM'( 1.0 Bit 0.000 0 8nOI2OO , 'm¡y 1.6 Sf( Ð.OOO 0 1JlJ\IaOO1 DesÇfïptiOn ......~...~. , ID i UI0 2.3;3 203"1 3.2$0 2250 2.141 -- . .......--!d!L -- -- --- 01/29104 Schlumberger NO. 3109 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ( Well Job # Log Description Date BL Color CD 3N-11 <-In-r~"l+ 10709696 JEWELRY WITH PRESS & TEMP 01/25/04 1 1F-05 \'7:;:1- ,~.~ 10709698 INJECTION PROFILE 01/27/04 1 1Y-13 i~;:S"OkL:? 10709699 INJECTION PROFILE 01/27/04 1 " 3K-17 \ ~lr)'-I.c:j~ 10709697 LDL 01/26/04 1 1 F-01 ~ <~ 1'1 10709693 LDL 01/22/04 1 3J-14 '>i~'-~S<;S 10709690 PRODUCTION PROFILE 01/17/04 1 2H-06'(~;;5-)((F¡ 10709694 SBHPSURVEY 01/23/04 1 I , " ( 'i,', .... '*" ).' " ,;,;, ". '. "., ,"" " RECEIVED '" " '-, -", SIGNED: ...,~¡~~)\ \~-It~-'\"'ÀQ ~"":::-^'0 DATE: "- , ,...";',',, ;j', ';~~~, ' , " Please sign and return one copy of this transmittal to Beth at the above address or fax to (90'h :5'è1-831t.,Tb.ån.k'~aOi!&GasCons.Comrnision ,.' ' , ,,' ,;,""....., , ; ". . ': ;,',' ", ':, '::~'),:':':: "",' , Anf_e ~q 'rdI<J¡~~,Q¡e~: U", ~:,-,!:,~> ql\ ~ 'OiVi" :',' ":-,((,,,l¿""',,JI \1t.''\:J r,;;.t...' ~- ! ~ !CJ¡ tJI ,",,' 1'- u. ' , -~.~ , \r,/~ I~ MEMORANDUM .- State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor DATE: May 18, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 3K Pad May 18,2001: I traveled to Phillips Alaska's Kuparuk River Field to witness Safety Valve System tests. Ernie Barndt was Phillips Rep. in charge of SVS testing. Testing was conducted in a safe & efficient manner. I witnessed one failure, SSV on 3K-27 would not pass the DP test. The valve was serviced & passed the re-test The AOGCC test report is attached for reference. I inspected 14 well houses on lQ Pad wi no problems witnessed. 'SUMMARy: I witnessed SVS testing in Kuparuk River Field. 14 wells, 28 components tested' 1 failure witnessed. 3.57% failure rate. 14 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc CC.; NON-CONFIDENTIAL SVS KRU 3K 5-18-01jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Operator Rep: Emie Barndt AOGCC Rep: John Crisp Submitted By: Date: Field/Unit/Pad: Kuparuk River Unit 3K Pad Separator psi: LPS 65 HPS 5/18/01 Weft Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 3K-01 1861010 65 70 50 P P OIL 3K-03 1861030 65 70 55 P P OIL 3K-06' 1861240 65 70 50 P P OIL 3K-09A 1861740 65 60 54 P P OIL 3K-10 1861630 65i 70 52 P P OIL '3K-11 1861640 65 70 50 P P OIL 3K-14 1861370' 65 60 58 P P OILi ,, 3K-16 1861390 65 70 70 P P OIL 3K-17 1861520 65 60 35 P P' OIL 3K-23 1970970 65 70 58 P P OIL 3K-24 1982490 65 70, 50 P P OIL 3K-27 1970460 65 70 52 P 4 OILi 3K-32 1970760 65 70 55 P P OILi 3K-35 1971090 65 70 50 P P OIL Wells: 14 Components: 28 Failures: 1 Failure Rate: 3.57% [-19o Day Remarks: RJF 1/16/01 Page 1 ofl SVS KRU 3K 5-18-01jc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate ~(, Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 985' FSL, 315' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1912' FSL, 1833' FWL, Sec. 2, T12N, R9E, UM At effective depth 1365' FSL, 1476' FWL, Sec. 2, T12N, R9E, UM At total depth 1276' FSL, 1411' FWL, Sec. 2, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 9584 6968 6. Datum elevation (DF or KB) RKB 69 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-17 9. Permit number/approval number 86-152 10. APl number 50-029-21642-00 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet feet RECEIVE Effective depth: measured 9 4 2 6 true vertical 6855 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 4724' 9-5/8" 9478' 7" measured 9189' 9209', true vertical 6654' 6668', Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 9097' Packers and SSSV (type and measured depth) feet Junk (measured) None feet Cemented Measured depth 1540 # Poleset 1 1 5' 1400SXAS III & 4761' 335 Sx Class G 490 Sx Class G 9 51 3' 175 Sx AS I 0 199 ~Uaska 0il & Gas Con;. Col True vertical deP~choral~8 115' 3718' 6918' 9229'-9246', 9253', 9258', 9263', 9275'-9281', 9326'-9334' 6683'-6695', 6701', 6704', 6708', 6717'-6721', 6755'-6761' PKR'S: Camco HRP-1-SP @ 8815', Baker DB @ 9082'; SSSV: Camco TRDP-1A-SSA @ 1806' 13. Stimulation or cement squeeze summary Fracture Stimulate 'A' Sands on 7/18/96 Intervals treated (measured) ORIGINAL 9189'-9207' Treatment description including volumes used and final pressure . Pumped 136.8 Mlbs of 20/40,12/18, & 10/14 ceramic proppant into formation, fp was 5643 psi 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1 3 0 1 5 7 1 1405 153 Subsequent to operation 438 554 7 1412 172 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent SUBMIT IN DUPLICATE ARCO Alaska, Inc. ~ -4UPARUK RIVER UNIT ~ '' WELL SERVICE REPORT ~ K1(3K-17(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-17 · FRAC, FRAC SUPPORT 0616961231.5 DATE DAILY WORK UNIT NUMBER 06/20/96 'A' SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR ~ 1 (~ Yes O NoI (~ Yes O No DS-YOAKUM PENRO,.~E .,~//, ESTIMATE KM1230 230DS36KL $114,623 $114,623 Initial Tb.q Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I F~nal Outer Ann 458 PSI 400 PSI 1546 PSI 500 PSII 0 PSII 0 PSI DALLY SUMMARY REFRAC'D 'A' SAND AS DESIGNED. CUT FINAL PROP RAMP SHORT & WENT TO FLUSH EARLY DUE TO INCREASING WHP. PLACED 136,790 LBS PROPPANT BEHIND PIPE, LEFT 1,000 LBS IN WELLBORE @ 8.1 PPA. 23 BBLS DIESEL PUMPED DOWN WELL. USED 13,800 LBS 20/40 AND 123,990 LBS 12/18 PROPPANT. TIME LOG ENTRY 14:00 MIRU DOWELL FRAC EQUIP & APC SUPPORT EQUIP. 14:45 HOLD PRE,JOB SAFETY MEETING, WORK UP AND QC FLUIDS, PRIME PUMPING EQUIP, PRESSURE TEST TO -8,300 PSI. 15:30 START PUMPING BREAKDOWN/CONDITIONING STAGE. PUMPED PER PROGRAM. 15:55 END BREAKDOWN/CONDITIONING STAGE, S/D. FFP = 6,120 PSI, ISIP = 2,300 PSI. MONITOR WHP. 16:45 START DATAFRAC. PUMPED PER PROGRAM. 17:10 END DATAFRAC, S/D. FFP = 5,305 PSI, ISIP = 2,353 PSI. MONITOR WHP, CALcuLATE PAD VOLUME. 18:15 START FRAC - PUMP PAD. PUMPED PER PROGRAM. 18:40 END PAD, START ADDING 20/40 PROPPANT @ 2 PPA. 18:45 SWAP TO 12/18 PROPPANT @ 2 PPA, RAMP UP TO 8 PPA, THEN PLATEAU @ 8 PPA. 19:30 WHP INCREASING TOO RAPIDLY, CUT JOB SHORT - GO TO FLUSH. 19:35 S/D WITH 29 BBLS DIESEL DOWNHOLE. FFP = 5,643 PSI, ISIP = 3,080 PSI. MONITOR WHP. 19:50 END PRESSURE MONITORING. FSIP = 2,412 PSI. RDMO DOWELL AND APC. 21:30 WELL SECURE AND EVERYBODY OFF LOCATION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $7,235.00 $7,235.00 ARCO $580.00 $580.00 DOWELL $106,808.00 $106,808.00 TOTAL FIELD ESTIMATE $114,623.00 $114,623.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X 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 985' FSL, 315' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1912' FSL, 1833' FWL, Sec. 2, T12N, R9E, UM At effective depth 1365' FSL, 1476' FWL, Sec. 2, T12N, R9E, UM At total depth 1276' FSL, 1411' FWL, Sec. 2, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 9584 6968 6. Datum elevation (DF or KB) RKB 69 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-17 9. Permit number/approval number 86-152 10. APl number 50-029-21642-00 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet Effective depth: measured 9 4 2 6 true vertical 6855 feet Junk (measured) None feet Casing Length Size Structural Oonductor 8 0' 1 6" Surface 4 724' 9 - 5 / 8" Intermediate Production 9478' 7" Liner Perforation depth: measured 9189' true vertical 6654' Cemented Measured depth True vertical depth 1540 # Poleset 1 15' 1 15' 1400 Sx AS III & 4761' 371 8' 335 Sx Class G 490 Sx Class G 9 51 3' 6 91 8' 175 Sx AS I 9209', 9229'-9246', 9253', 9258', 9263', 9275'-9281', 9326'-9334" 6668', 6683'-6695', 6701', 6704', 6708', 6717'-6721', 6755'-6761' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 9097' Packers and SSSV (type and measured depth) PKR'S: Camco HRP-I-SP @ 8815', Baker DB @ 9082'; SSSV: Camco TRDP-1A-SSA 13. Stimulation or cement squeeze summary 14. Re-perforate 'A' Sands on 6/13/96 ORIGINAL Intervals treated (measured) 91 89'-9209' ~AF[ 2 0 1997 ,, Treatment description including volumes used and final pressure Perforate using 2-1/8" EJ w/ BH Charges, 4 spf, 180° PH, oriented +/- 90° f/ Iowsidfiask;a011&Ga~Cons, C0a~ Representative Daily Average Production or Injection Data AI1CI10Fagl~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 130 1 57 1 1405 153 130 1 57 1 1405 153 16. Status of well classification as: Oil X Gas Suspended Service 7. I hereby ce_dify that the foregoing is true and correct to the best of my knowledge. Signed ~'~"J~ .~~,4.~ Title Wells Superintendent Form 10-.4/d"4 ~R~v'/06'¢I'5/8'8~ - SUBMIT IN DUPLICATE ARCO Alaska, Inc. ' KUPARUK RIVER UNIT ' ~ WELL SERVICE REPORT ~ K1(3K.17(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-17 PERFORATE, PERF SUPPORT 0612961 148.1 DATE DAILY WORK UNIT NUMBER 06/13/96 PERF 'A' SAND ,, DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes O NoI ® Yes O No SWS-BAILEY PAIGE FIELD AFC~ CC~ DALLY COST ACCUM COST ~_n~c~~)~ ESTIMATE 230DS36KL $10,064 $10,064 ~. , ,,, Initial Tb.cl Press Final Tb.q Press Initial Inner Ann Final Inner Ann J Initial Outer Ann J Final Outer Ann[ -- 200 PSI 200 PSI 1200 pSI 1200 PSII 0 PSI~ 0 PSI DALLY SUMMARY RE-PERFED 'A' SAND INTERVAL FROM 9189'-9209' (REF DIL DATED 8/27/86) USING 2-1/8" EJ W/BH CHARGES, 4 SPF, 180 DEG PH, ORIENTED +/- 90 DEG F/LOWSIDE TIME LOG ENTRY 11:30 MIRU SWS. HELD SAFETY MTG. 12:45 PT LUB TO 2500#; TEST OK. RIH W/GUN#1 - WGT BAR, MPD, CCL, 2-1/8" EJ W/BH CHARGES, 2 SPF, 0 DEG PH, ORIENTED -90 DEG F/LOWSIDE TO SHOOT 9189'-9209' (REF DIL DATED 8/27/86/ !' BLEED WHP; 300# UNDERBALANCED. FIRED GUN#l; POH. 14:00 14:45 AT SURF W/GUN#l; ALL SHOTS FIRED 15:15 16:00 16:30 AT SURF W/GUN#2; ALL SHOTS FIRED 17:00 RDMO TO 3K-14. PT LUB TO 2500~; TEST OK. RIH W/GUN~2 - WGT BAR, MPD, CCL, 2-1/8" EJ W/BH CHARGES, 2 SPF, 0 DEG PH, ORIENTED +90 DEG F/LOWSIDE TO SHOOT 9189'-9209' (REF DIL DATED 8/27/86) BLEED WHP; 300# UNDERBALANCED. FIRED GUN#2; POH. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL SCHLUMBERGER $10,064.00 $10,064.00 TOTAL FIELD ESTIMATE $10,064.00 $10,064.00 STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION CC,,~IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well /f//;¢ '~'~-/ OIL [~. GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .// 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-152 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21642 4. Location of well at surface 9. Unit or Lease Name 985' FSL, 315' FWL, Sec.35, T13N, RDE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1602' FSL, 1721' FWL, Sec. 2, T12N, RDE, UN 3K-17 -. At Total Depth 11. Field and Pool 1233' FSL, 1435' FWL, Sec. 2, T12N, RDE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 69' ADL 25629, ALK 2562 12. Date Spudded 13. Date T.D. Reached 14. Date Comp.i Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/21/86 08/27/86 02/02/87* N/A feet MSL 1 i7. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9584'NB 6949'TVD 9426'MB 6830'TVD YES ~ NO []I 1824' feetMD 1700' (Approx) 22. Type Electric or Other Logs Run DIL/SP/SFL,GR, FDC/ENL, Cal, CET/GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62 5# H-40 Surf 115' 24" 1540# Poleset 9-5/8" 36.0# J-55 Surf 4761' 12-1/4" 1400 sx AS III & 335 sx Class G 7" 26.0# J-55 Surf 9513' 8-1/2" 490 sx Class G & 175 sx AS I . , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) See attached. 2-7/8" 9111' 8816' & 9083' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Adder dum, dated 02/05/87~ for Fracture dal ~. .., 27. N/A PRODUCTION TEST Date First Production t Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL O'IL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ . . . 28. CORE DATA Brief description 'of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None , *Note: Drilled RR 08/29/86. Well perforated & 'cubing ran 12/09/86. .-' ' . Form 10-407 Rev. 7-1-80 WC2: 05:3: DAN I CONTINUED ON REVERSE SIDE Submit in duplicat~ 29. 30. NAME GEOLOGIC MARKbRS MEAS. DEPTH Top Kuparuk C 8906' Base Kuparuk C ii 8994' !! Top Kuparuk A !~ 91 62' Base Kuparuk A i 9336' i !, 31. I__IST OF ATTACHMENTS Addendum (dated 02/05/87). TRUE VERT. DEPTH 6459' 6518' 6635' 6762' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR,and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 SUB-SURFACE DIRECTIONAL SURVEY [~UIDANCE r~']ONTINUOUS [-~"] OOL CompanY A~CO ALASKA, INC. Well Name 3K-17 (985' FSL; 315' FWL?SEC 357T13N~R9E~UM1 Field/Location KUPARUK, NORTH. SLOPE~ ALASKA Job Reference No. Date 72106 16-NOV-86 Lo~3c3ed By: Computed By: PEPPEL HALSTEAD SCHLUMBERGER GCT DIRECTIONAL SURVEY CD$'TDMER LISTING FOR ARCO ALASKA, INC. 3K-17 KUPARUK NORTH S'LOPE,ALASKA SURVEY DATE: 16 NOV 86 ENGINEER: PEPPEL METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH .. INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET. AZIMUTH OF SOUTH 36 DEG 37 MIN WEST COMPUTATION DATE: lO-DEC-86 PAGE ARCO ALASKA, INC. 3K-17 KUPARUK NORTH SLOPE,ALASKA DATE OF SURVEY: 16 NOV 86 KELLY BUSHING ELEVATION: 69.00 FT ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -69.00 0 0 N 0 0 E 100.00 100.00 31.00 0 44 S 46 5 W 200.00 199.99 130.99 0 45 S 50 1 W 300.00 299.9.8 230.98 0 44 S 35 49 W 400.00 399.97 330.97 0 52 S 48 37 W 500.00 499.96 430.96 1 14 S 36 44 W 600.00 599.85 530.85 4 37 S 39 36 W 700.00 699.16 630.16 8 40 S 40 57 W 800.00 797.33 728.33 13 11 S 39 6 W 900.00 893.85 824.85 16 34 S 39 35 W 1000.00 988.94 919.94 19 43 1100.00 1081.80 1012.80 23 42 1200.00 1172.17 1103.17 26 36 1300.00 1260.95 1191.95 28 25 1400.00 1347.76 1278.76 31 8 1500.00 1432.10 1363.10 33 54 1600.00 1513.65 1444.65 36 36 1700.,00 1592.81 1523.81 38 41 1800.00 1669.75 1600.75 40 34 1900.00 1744.60 1675.60 42 41 2000.00 1816.91 1747.91 44 27 2100.00 1887.50 1818.50 45 42 2200.00 1956.68 1887.68 46 41 2300.00 2024.75 1955.75 47 32 2400.00 2091.76 2022.76 48 22 2500.00 2157.63 2088.63 49 14 2600.00 2222.23 2153.23 50 15 2700.00 2285.58 2216.58 50 47 2800.00 2349.68 2280.68 49 28 2900.00 2414.74 2345.74 48 52 3000.00 2482.40 2413.40 46 8 3100.00 2552.45 2483.45 44 24 3200.00 2625.86 2556.86 41 45 3300.00 2700.46 2631.46 41 59 3400.00 2774.38 2705.38 42 43 3500.00 2847.45 2778.45 43 21 3600.00 2919.76 2850.76 44 1 3700.00 2991.25 2922.25 44 51 3800.00 3061.62 2992.62 45 36 3900.00 3131.28 3062.28 46 3 VERTICAL DOGLEG 'RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E 0.62 0.13 0.46 S 0.42 W 1.93 0.24 1.34 S 1.43 W 3.14 0.55' 2.24 S 2.25 W 4'.64 0.39 3.40 S 3.22 W 6.08 2.54 4.43 S 4.22 W 10.42 5.60 7.80 S 6.98 W 21.95 4.71 16.69 S 14.34 W 40.80 4.10 31.14 S 26.49 W 66.85 2.45 51.35 S 42.98 W 0.00 N 0 0 E 0.62 S 42 45 W 1.96 S ,46 52 W 3.17 S 4,68 S 43 26 '.' 6.12 S 43 36 10.46 S 41 49 .-~ ' 22.01 S 40 39 40.89 S 40 23 W' 66.96 S 39 55 W S 38 40 W 97.70 4.04 S' 38 0 W 134.72 3.73 S 38 22 W 177.51 1.69 S 38 21 W 223.49 2.30 S 37 52 W 273.08 2.95 S 38 23 W 326.77 3.20 S 37 24 W 384.60 2.56 S 35 29 W 445.69 2.22 S 34 29 W 509.52 1.38 S 32 12 W 575.73 3.20 75.20 S 62.61 W 97.85 S 39 46 W 104.37 S 85.42 W 134.87 S 39 17 W 138.03 S 111.86 W 177.67 S 39 1 W 174.04 S 140.50 W 223.67 S 38 54 W 213.11 S 171.06 W 273.27 S 38 45 W 255,34 S 204.25 W 326.98 S 38 39 W 300.86 S 239.95 W 384.82 S 38 34 W 350.02 S 276.21 W 445.88 S 38 16 W 402.37 S 312.78 W 509.64 S 37 51 W 457,62 S 349.43 W 575.78 S 37 21 W S 29 26 W 642~40 1.53 S 29 37 W 714~,66 1.23 S 3033 W 78~J8''~ 1.08 S 31 27 W 85 S 32 26 W 933~,,,,'28 c_.. S 33 19 W 1008.~36 ~"'~~1917 S 34 2 W 108~9 18 S 33 47 W 116'~.~0 P':~ s ))w s zs w i~".~ S 31 20 W 1387. 0 -~, S 31 26 W I458.',0 S 30 16 W 1525. S 30 5 W 1591.8~8 S 30 24 W 1658. S 30 59 W 1726.72 S 31 25 W 1795.50 S 31 35 W 1865.13 S 32 13 W 1935.93 S 33 20 W 2007.51 8 3.65 0.95 0.54 0.74 0.73 0.61 1.18 1.01 1.08 517.09 S 384.54 W 644.40 S 36 38 W 578.84 S 419.24 W 714.72 S 35 54 W 641.34 S 455.41 W 786.58 S 35 22 W 704.09 S 493.18 W 859.64 S 35 0 767.10 S 532.43 W 933.77 S 34 45 W 830.25 S 573.33 W 1008.97 S 34 37 893.78 S 615.64 W 1085.29 S 34 33 957.76 S 659.15 W 1162.66 S 34 32 1022.68 S 700.04 W 1239.33 S 34 23 W 1088.35 S 738.19 W 1315.08 S 34 8 W 1151.52 S 775.98 W 1388.58 S 33 58 W 1212.31 S 813.37 W 1459.89 S 33 51 W 1270.60 S 848.15 W 1527.67 S 33 43 W 1328.20 S 881.56 W 1594.13 S 33 34 W 1386.42 S 915.44 W 1661.38 S 33 26 W 1445.1'2 S 950.28 W 1729.57 S 33 19 W 1504.18 S 986.11 W 1798.60 S 33 14 W 1563.77 S 1022.67 W 1868.48 S 33 11 W 1624.14 S 1060.13 W 1939.51 S 33 8 W 1684.47 S 1098.96 W 2011.26 S 33 7 W ARCO ALASKA, INC.. 3K-17 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 10-0EC-86 PAGE DATE OF SURVEY: 16 NOV' 86 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH BEG MIN DEG MIN 4000,00 3200,26 3131,26 46 43 4100.00 3268,34 3199,34 47 32 4200.00 3335,.15 3266,15 48 23 4300,00 3401,68 3332.68 48 15 4400..00 3468,10 3399,10 48 32 45,00.00 3534.03 3465.03 48 57 4600,00 3599,32 3530,32 49 27 4700,00 3664,07 3595,07 49 53 4800.00 3728.50 3659.50 49 46 4900,00 3792,81 3723.81 49 59 5000.00 3857.43 3788,43 49 26 5100.00 3922,70 3853.70 49 11 5200.00 3988.16 3919.16 48 59 5300.00 4053.93 3984.93 48 43 5400-00 4119.95 4050.95 48 31 5500,00 4186,31 4117,31 48 16 5600°00 4253.17 4184,17 47 57 5700.00 4320.37 4251.37 47 35 5800,00 4387.95 4318,95 47 14 5900.0,0 4456.07 4387.07 46 55 69.00 FT S 34 15 W 2079.83 S 35 2 W 2153.03 S 36 7 N 2227.42 S 37 29 W 2302.07 S 38 25 W 2376.81 S 39 34 W 2451.93 S 40 8 W 2527.54 S 41 i W 2603.58 S 41 56 W 2679,75 S 41 54 W 2756.01 0,87 1,25 1,30 0,79 0,82 0,85 0.42 1,27 1,00 0,44 1744.59 S 1139.30 W 2083.65 S 33 8 W 1804.86 S 1180.93 W 2156.87 S 33 11 W 1865.44 S 1224.12 N 2231.22 S 33 16 W 1925,15 S 1268,93 W 2305.73 S 33 23 W 1984.08 S 1314.92 W 2380.25 S 33 32 W 2042,53 S 1362,22 W 2455.11 S 33 42 I 2100,63 S 1410,81 W 2530,42 S 33 53 2158.60 S 1460.27 W 2606.14 S 34 4 ~ 2215.69 S 1511.15 W 2681.96 S 34 17 W 2272.68 S 1562.32 W 2757.88 S 34 30 W S 41 39 W 2832.01 S 41 32 W 2907.49 S 41 21 W 2982.81 S 41 3 W 3057.90 S 40 57 W: 3132.79 S 40 42 W 3207.39 S 40 15 W 3281.59 S 39 57 W 3355.50 S 39 41 ~ 3429,09 S 39 23 W, 3502.21 0.94 0.19 0.23 0.29 0.63 0.93 0.33 0.36 0.67 0.41 2329-56 S 1613.19 W 2833.59 S 34 42 W 2386.23 S 1663.48 W 2908.82 S 34 52 W 2442.88 S 1713,53 W 2983.93 S 35 2 W 2499.57 S 1763.13 W 3058.84 S 35 11 W 2556.27 S 1812.39 W 3133.57 S 35 20 W 2612.84 S 1861,34 W 3208,04 S 35 27 W 2669.42 S 1909.59 W 3282.13 S 35 34 W 2726.05 S 1957.31 W 3355.95 S 35 40 W 2782.67 S 2004.50 W 3429.47 S 35 46 W 2839.12 S 2051.12 W 3502.53 S 35 50 W 6000.00 4524,22 4455.22 47 28 6100.00 4591.36 4522.36 47 55 6200.00 4658.50 4589,'50 47 36 6300.00 4725.99 4656.99 47 29 6400,00 4793,79 4724.79 47 9 6500,00 4862.00 4793,00 46 52 6600,00 4930.57 4861,57 46 30 6700.00 4999.55 4930.55 46 26 6800.00 5067,90 4998.90 47 59 6900,00 5133,97 5064.97 48 51 7000.00 5199.74 5130.74 48 55 7100.00 5265.46 5196.46 48 54 7200.00 5331.24 5262.24 48 48 7300.00 5397.13 5328.13 48 32 7400.00 5463.84 5394.84 48 2 ?500.00 5530.56 5461.56 48 19 7600.00 5596.75 5527.75 48 46 7700.00 5662.39 5593.39 49 11 7800.00 5727.41 5658.41 49 28 7900.00 5792.52 5723.52 49 30 S 38 31W 3575.32 S 37 43 W 3649.41 S 37 33 W 3723.50 S 37 21 W 3797.29 S 37 3 W 3870.79 S 36 51 W 3943.92 S 36 42 W 4016,71 S 36 27 W 4089.10 S 36 28 W 4162.09 S 36 30 W 4237.15 S 36 27 W 4312.48 S 36 28 W 4387.85 S 36 36 W 4463.17 S 36 38 W 4538.39 S 36 i0 W 4612.89 S 35 41 W 4687.37 S 35 43 W 4762.32 S 35 35 W 4837.74 S 35 23 W 4913.71 S 35 26 W 4989.60 1.68 0.26 0.37 0.51 0.34 0.31 0.73 0.23 2.56 0.08 0,16 0.23 0.21 1,07 0,45 0,53 0,42 0,50 0,49 0.50 2895.92 S 2097.27 W 3575.59 S 35 54 W 2954.33 S 2142.86 W 3649.65 S 35 57 W 3013.02 $ 2188.12 W 3723.73 S 35 59 W 3071.60 S 2233.00 W 3797.50 S 36 0 W 3130.13 S 2277.46 W 3870.99 S 36 2 W 3188.57 S 2321.42 W 3944.11 S 36 3 W 3246.87 S 2365.00 W 4016.89 S 36 4 ~ 3305.00 S 2408.14 W 4089.28 S 36 4 W 3363.73 S 2451.49 W 4162.27 S 36 5 W 3424.07 S 2496.14 W 4237.33 S 36 5 W 3484.64 S 2540.92 W 4312.66 S 36 5 ~ 3545.27 S 2585.70 W 4388.02 S 36 6 W 3605.77 S 2630.57 W 4463.34 S 36 6 W 3666.11 S 2675.47 W 4538.56 S 36 7 W 3726.08 S 2719.68 W 4613.06 S 36 7 W 3786.38 S 2763.40 W 4687.55 $ 36 7 W 3847.26 S 2807.13 W 4762.50 S 36 6 W 3908.54 S 2851.12 W 4837.93 S 36 6 W 3970.42 S 2895.22 W 4913.91 S 36 5 W 4032.29 S 2939.19 W 4989.81 S 36 5 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN COMPUTATION DATE: lO-DEC-86 PAGE 3 ARCO ALASKA~ INC. DATE DF SURVEY: 16 NO'V 86 3K-17 KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: PEPPEL 69.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 800'0.00 5857.29 5788.29 49 28 8100.00 5922.80 5853.80 48 51 8200.00 5988.72 5919.72 48 42 8300.00 6054.68 5985.68 48 44 8400.00 6120.82 6051.82 48 24 8500.00 6187.46 6118.46 48 4 8600.00 6254.21 6185.21 48 10 8700.00 6321.15 6252.15 47 53 8800.00 6388.17 6319.17 47 55 8900.00 6455.15 6386.15 47 46 S 35 10 W 5065.76 S 34 8 W 5141.28 S 32 53 W 5216.36 S 31 38 W 5291.30 S 31 4 W 5365.97 S' 31 12 W 5440.19 S 31 15 W ~514.31 S 32 34 W 5588.34 S 34 57 W 5662.46 S 36 59 W 5736.70 1.09 0.86 0.84 0.89 0.19 0.20 0.62 1.51 1.62 1.61 40.94.39 S 2983.32 W 5065.99 S 36 4 W 4156.53 S 3026.30 W 5141.52 S 36 3 4219.20 S 3067.85 W 5216.64 S 36 1 W 4282.76 S 3107.96 W 5291.64 S 35 58 W 4346.88 S 3146.86 W 5366.39 S 35 54 4410.69 S 3185.42 W 5440.69 $ 35 50 4474.41 S 3223.95 W 5514.91 S 35 46 4537.59 S 3263.05 W 5589.02 S 35 43 W 4599.26 S 3304.32 W 5663.19 ' S 35 41 W 4659.35 S 3347.92 W 5737.43 S 35 41 9000.00 6522.45 6453.45 47 34 9100.00 6590.90 6521.90 45 50 9200,00 6661.74 6592.74 43 56 9300.00 6734.94 6665.94 41 51 9400.00 6810.29 6741.29 40 54 9500.00 6885.86 6816.86 40 54 9584.00 6949.34 6880.34 40 54 S 38 3 w 5810.65 S 37 49 W 5883.53 S 37 53 W 5954.08 S' 37 19 W 6022.20 S 38 1 W 6087.93 S 38 1 W 6153.41 S 38 1 W 6208.40 1.23 4717.85 S 3393.19 W 5811.35 S 35 43 W 2.10 4775.28 S 3438.09 W 5884.20 S 35 45 W 1.99 4831.04 S 3481.34 W 5954,72 S 35 46 W 1.89 4885.05 S 3522.87 W 6022.82 S 35 47 W O.OO 4937.02 S 3563.14 W 6088.52 S 35 49 W 0.00 4988.61 S 3603.48 W 6153.97 S 35 50 W 0.00 5031.95 S 3637.37 W 6208.94 S 35 51 W COMPUTATION DATE: lO-DEC-86 PAGE 4 ARCO ALASKA~ INC. 3K-17 KUPARUK NORTH SLOPE,ALASKA DATE DF SURVEY: 16 NOV 86 KELLY BUSHING ELEVATION: 69.00 FT ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN 0.00 0.00 -69.00 0 0 1000.00 988.94 919.94 19 43 2000.00 1816.91 1747.91 44 27 3000.00 2482.40 2413.40 46 8 4000.00 3200.26 3131.26 46 43 5000.00 3857.43 3788.43 49 26 6000.00 4524.22 4455.22 47 28 7000.00 5199.74 5130.74 48 55 8000,00 5857.29 5788.29 49 28 9000.00 6522.45 6453.45 47 34 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 S 38' 40 W 97.70 S 29 26 W 644.40 S 31 20 W 1387.10 S 34 15 W 2079.83 S 41 39 W 2832.01 S 38 31 W 3575.32 S 36 2? W 43~2.48 S 35 10 W 5065.76 S 38 3 W 5810.65 9584.00 6949.34 6880.34 40 5~ S 38 1 W 6208.40 0.00 4.04 1.53 1.78 0.87 0.94 1.68 0.16 1.09 1.23 0.00 N 0.00 E 0.00 N 0 0 E 75.20 S 62.61 W 97.85 S 39 46 W 517.09 S 384.54 W 644.40 S 36 38 W 1151.52 S 775.98 W 1388.58 S 33 58 W 1744.59 S 1139.30 W 2083.65 S 3'3 8 W 2329.56 S 1613.19 W 2833.59 S 34 42 ~ ;~ 2895,92 S 2097.27 W 3575.59 S 35 54 W 3484.64 S 2540.92 W 4312.66 S 36 5 W 4094.39 S 2983.32 W 5065.99 S 36 4 W 4717.85 S 3393.19 W 5811.35 S 35 43 W 0.00 5031.95 S 3637.37 W 6208.94 S 35 51 N ARCO ALASKA, INC. 3K-17 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 10-DEC-86 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -69.00 0 0 N 0 0 E 69.00 69.00 0.00 0 44 S 42 19 W 169,01 169.00 100.00 0 47 S 49 11 W 269.02 269.00 200.00 0 40 S 38 10 W 369.03 369.00 300.00 0 54 S 42 25 W 469.04 469.00 400.00 0 45 S 38 48 W 569.09 569.00 500.00 2 58 S 39 35 W 669.54 669.00 600.00 7 16 S 39 39 W 770.97 769.00 700.00 11 52 S 39 34 W 874.10 869.00 800.00 15 55 S 39 21 W 978.85 969.00 PAGE 5 DATE OF .S'U'RVEY: 16 NOV' 86 69.00 FT VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E 0.22 0.25 0.17 S O.14.W 1.51 0.17 1.07 S 1.10 W 2.76 0.14 1.94 S 2.02 W 4.17 0.21 3.06 S 2.87 W 5.58 0.53 4.03 S' 3.92 W 8.40 4.70 6.24 S 5.68 W 17.75 4.28 13.49 S 11.61 W 34.48 5.26 26.24 S 22.49 W 59.57 2.60 45.73 S 38.34 W S 39 8 W 90.67 S 37 57 W 129.10 S 38 21 W 175.91 S 38 17 W 227.91 S 37 59 W 286.14 S 38 15 W 352.17 S 36 1 W 426.84 S 34 30 W 508.87 S 31 4 W 598.47 S 29 25 W 695.93 900.00 18 54 1086.02 1069.00 1000.00 23 11 1196.45 1169.00 1100.00 26 33 1309.19 1269.00 1200.00 28 39 1424.93 1369.00 1300.00 31 48 1544.80 1469.00 1400.00 35 13 1669.63 1569.00 1500.00 38 4 1799.00 1669.00 1600.00 40 33 1933.42 1769.00 1700.00 43 23 2073.57 1869.00 1800.00 45 23 2217.97 1969,00 1900.00 46 49 2365.85 2069.00 2000.00 48 3 2517.44 2169.00 2100.00 49 24 2673.71 2269.00 2200.00 50 51 2829.66 2369.00 2300.00 49 26 2980.57 2469.00 2400.00 46 34 3122.98 2569.00 2500.00 43 35 3257.73 2669.00 2600.00 41 45 3392.68 2769.00 2700.00 42 40 3529.68 2869.00 2800.00 43 33 3668.71 2969.00 2900.00 44 30 3810.56 3069.00 3000.00 45 39 3954.54 3169.00 3100.00 46 25 4100.98 3269.00 3200.00 47 32 4250.95 3369.00 3300,00 48 15 4401.36 3469.00 3400.00 48 33 4553.42 3569.00 3500.00 49 15 4707.66 3669.00 3600.00 49 55 4863.00 3769.00 3700.00 50 0 5017.76 3869.00 3800.00 49 21 S 30 44 W 799.41 S 32 5 W 907.88 S 33 26 W 1021.57 S 34 11 W 1141.51 S 30 7 W 1260.76 S 31 10 W 1373.10 S 31 10 W 1474.07 S 30 5 W 1563.84 S 30 22 W 1653.88 S' 31 9 W 1747.03 S 31 33 W 1843.22 S 32 20 W 1943.46 S 33 55 W 2046.85 S 35 2 W 2153.75 S 36 56 W 2265.50 S 38 26 W 2377.83 S 39 55 W 2492.25 S 41 9 W 2609.42 S 41 56 W 2727.81 S 41 37 W 2845.43 O.O0 N 0 0 E 0.22 S 40 21W 1.53 S 46 0 W 2.80 S 46 8 W 4.19 S 43 14 W 5.63 S 44 13 8.44 S 42 18 ~, 17.80 S 40 43 W 34.56 S 40 35 W 59.67 S 39 58 W 3.63 3.96 1.78 2.43 2.59 2.59 2.39 1.34 3.06 1.35 69.71 S 58.20 W 90.82 S 39 51 W 99.94 S 81.95 W 129.24 S 39 21 W 136.78 S 110.86 W 176.07 S 39 i W 177.51 S 143.24 W 228.10 S 38 54 W 223.42 S 179.09 W 286.34 S 38 42 W 275.25 S 220.03 W 352.39 $ 38 38 W 334.72 S 265.20 W 427.05 S 38 23 W 401.84 S 312.41 W 508.99 S 37 51 W 477.06 S 361.41 W 598.50 S 37 8 W 562.42 S 409.93 W 695.96 S 36 5 W 1.15 1.19 1.22 1.01 0.66 2.46 3.85 0.66 0.72 0.81 652.60 S 462.07 W 799.62 S, 35 17 W 745.56 S 518.83 W 908.32 S 34 50 W' 841.29 S 580.61 W 1022.20 S 34 36 W 940.86 S 647.71 W 1142.25 S 34 32 W 1042.13 S 711.36 W 1261.78 S 34 19 W 1139.49 S 768.70 W 1374.53 S 34 0 W 1225.93 S 821.66 W 1475.82 S 33 49 W 1303.78 S 867.40 W 1565.96 S 33 38 W 1382.13 S 912.92 W 1656.42 S 33 26 W 1462.60 S 960.81 W 1749.96 S 33 lB W 1.10 0.97 0.94 1.26 1.03 0.83 0.72 1.27 0.48 0.68 1545.03 S 1011.16 W 1846.50 S 33 12 W 1630.52 S 1064.17 W 1947.07 S 33 7 W 1717.26 S 1120.79 W 2050.64 S 33 7 W 1805.45 S 1181.34 W 2157.50 S 33 11 W 1896.03 S 1246.78 W 2269.23 S 33 19 W 1984.88 S 1315.56 W 2381.27 S 33 32 W 2073.55 S 1388.06 W 2495.26 S 33 47 W 2163.00 S 1464.14 W 2611.95 S 34 5 W 2251.61 S 1543.39 W 2729.80 S 34 25 W 2339.63 S 1622.14 W 2866.97 S 34 44 W COMPUTATION OAT'E: lO-DEC-86 PAGE 6 ,~O AL~SKA, INC. DATE OF SURVEY: 16 NOV 86 3K-17 KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: PEPPEL 69,00 FT INTERPOLATED VALUES FO.R EVEN 100 FEET OF SUB-SEA DEPTH TRUE SD'B-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES' MORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 5170.79 3969.00 3900.00 49 4 5322.83 4069.00 4000.00 48 42 5473.91 4169.00 4100.00 48 25 5623.63 4269.00 4200.00 47 53 5772.06 4369.00 4300°00 47 24 5918.92 4469°00 4400.00 46 53 6066.64 4569.00 4500.00 47 53 6215.56 4669°00 4600.00 47 33 6363.51 4769.00 4700.00 47 16 5510.25 4869.00 4800-00 46 50 S 41 25 W 2960.84 S 41 0 W 3075.00 S 40 49 W 3187.93 S 40 11 W 3299.10 S 39 45 N 3408.60 S 39 19 W 3516.01 S 37 49 W 3624.66 S 37 31 W 3734,99 S 37 10 W 3844.02 S 36 50 W 3951.40 0.49 0.28 0.23 0.44 0.93 0.40 0.40 0.21 0.46 0.38 2426.34 S 1698.96 W 2962.02 S 35 0 N 2512.51 S 1774.39 W 3075.90 S 35 13 w 2598.06 S 1848.59 W 3188.61 S 35 25 W 2682.82 S 1920.92 W 3299.61 S 35 36 W 2766.88 S 1991.38 W 3408.99 S 35 44 ~' 2849.80 S 2059.89 W 3516.32 S 35 51 2934,76 S 2127.71 W 3624,91 S 35 56 ." 3022,13 S 2195,12 W 3735,21 S 35 59 W 3108.78 S 2261.30 W 3844.22 S 36 1 ~ 3194.55 S 2325.91 W 3951.59 S 36 3 W 6655.T0 4969.00 4900.00 46 21 6801.63 5069.00 5000.00 48 1 6953.25 5169.00 5100.00 48 52 7105.38 5269.00 5200.00 48 53 7257.33 5369.00 5300.00 48 47 7407,71 5469.00 5400,00 48 2 7557.97 5569.00 5500.00 48 34 7710.11 5669.00 5600.00 49 14 7863.86 5769.00 5700.00 49 22 8017.98 5869.00 5800.00 49 19 S 36 33 W 4057.03 S 36 28 W 4163.29 S 36 28 ~ 4277.25 S 36 28 W 4391.90 S 36 40 W 4506.31 S 36 8 W 4618.62 S 35 42 W 4730.75 S 35 34 W 4845.40 S 35 24 W 4962,16 S 35 0 W 5079.41 0.35 2.54 0.13 0.22 0.05 0.45 0.50 0.63 0.28 1.24 3279.22 S 2389.06 W 4057.21 S 36 4 W 3364.69 S 2452.20 W 4163.47 S 36 5 W 3456.31 S 2519.99 W 4277.43 S 36 .5 W 3548.53 S 2588.11 W 4392.08 S 36 6 W 3640.38 S 2656.31 W 4506.48 S 36 7 w 3730.70 S 2723.06 W 4618.79 S 36 7 W 3821.63 S 2788.69 W 4730.93 S 36 7 W 3914.77 S 2855.58 W 4845.59 S 36 6 W 4009,92 S 2923,28 W 4962,36 S 36 5 W 4105,56 S 2991,16 W 5079,63 S 36 4 W 8170.12 5969.00 5900.00 48 42 8321.73 6069.00 6000.00 48 42 8472.37 6169.00 6100.00 48 6 8622.21 6269,00 6200,00 48 5 8771.41 6369.00 6300.00 47 54 8920.56 6469.00 6400.00 47 42 9068.37 6569.00 6500.00 46 28 9210.02 6669.00 6600.00 43 45 9345.37 6769.00 6700.00 40 58 9477.69 6869.00 6800.00 40 54 S 33 15 W 5193.96 S 31 24 W 5307.57 S 31 11 W 5419.73 S 31 25 W 5530.81 S 34 18 W 5641,25 $ 37 21 W 5751.90 S 37 57 W 5860.71 S 37 49 W 5960.99 S 37 55 W 6052.16 S 38 1 W 6138.80 0.97 0.75 0.28 1.05 1.76 1.27 1.95 1.96 2.26 0.00 4200.40 S 3055.59 W 5194.22 S 36 2 W 4296.68 S 3116.50 W 5307.93 S 35 57 W 4393.13 S 3174.76 W 5420.21 S 35 51 W 4488.58 S 3232.55 W 5531.43 S 35 45 W 4581.81 S 3292,25 W 5641,98 S 35 41 W 4671.44 S 3357.13 W 5752.63 S 35 42" 4757.27 S 3424.08 W 5861.39 S 35 44 4836.49 S 3485.58 W 5961.62 S 35 46 w 4908.83 S 3541.11 W 6052.77 S 35 48 W 4977.10 S 3594.48 W 6139.37 S 35 50 W 9584.00 6949.34 6880.34 40 54 S 38 i W 6208.40 0.00 5031.95 S 3637.37 W 6208.94 S 35 51 W COMPUTATION DATE: lO-DEC-86 PAGE 7 ~ AL ~KA, INC. 3K-17 KUPARUK NORTH SLOPE~ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD DATE OF SURVEY: 16 NOV 86 KELLY BUSHING ELEVATION: 69.00 FT ENGINEER: PEPPEL INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB SURFACE LOCATION AT ORIGIN: 985' FSL, 315' FWL, SEC 35, T13N, RgE, UM TVD RECTANGU'L~R COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 8906.00 8994.00 9162.00 9336.00 9426.00 9584.00 6459.19 6390.19 4662.88 S 3350.61 W 6518.42 6449.42 4714.35 S 3390.45 ~ 6634.55 6565.55 4810.09 S 3465.03 W 6761.92 6692.92 4903.97 S 3537.36 W 6829.94 6760.94 4950.44 S 3573.63 W 6949.34 6880.34 5031.95 S' 3637.37 W A, ~.0 ALASKA, INC. 3K-1T KU'PARUK NORTH SLOPE~ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATION DATE: ,~,~******** STRAT'IGRAPHIC MEASURED DEPTH BELOW KB 8906.00 8994.00 9162.00 9336.00 9426.00 9584.00 lO-DEC-B6 PAGE DATE OF SURVEY: 16 NOV 86 KELLY BUSHING ELEVATION: 8 69.00 ENGINEER: PEPPEL SUMMARY ORIGIN= 985' FSL, 315' TVD FROM KB SUB-SEA 6459.19 6390.19 6518.42 6449.42 6634.55 6565.55 6761.92 6692.92 6829.94 6760.94 6949.34 6880.34 SU FWL, SE RECTA NORT RFACE LOCATION AT C 35, T13N, RgE, UM NGULAR COORDINATES H/SOUTH EAST/WEST 4662. 4714. 4810. 4903. 4950. 5031. 88 S 3350.61 35 S .3390.45 09 S 3465.03 97 S 3537.36 44 S 3573.63 95 $ 3637.37 FINAL MEASURED DEPTH WELL LOCATION AT TO: TRUE SUB-SEA VERTICAL VERTICAL DEPTH DEPTH 9584.00 6949.34 6880.34 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET OEG MIN 6208.94 S 35 51 FT SCHLUMBERGER 0 1 REC T I ONAL SURVE Y COMPANY ARCO ALASKA INC WELL 3K- 17 F ! 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PROJECTION ON VERTICAL PLANE 2:lE;. - 3S. SCALEB IN VERTICAL DEPTHS HORIZ SCALE = 1/2000 IN/FT ARCO Alaska, Inc. Post Office Bc 00360 Anchorage. Alaska 99510-0360 Telephone 907 276 12!5 November 9, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate are multiple Reports of Sundry Well Operations on the following Kuparuk wells. Conversions 3N-11, 3N-10, 3N-05, 3N-04, 3F-12, 3F-03, 3F-08, 3N-03, 13, 1E-21, 1E-19, 1E-23, 1E-lA, 1E-04, 1E-16 and1E-27 Fractures and Stimulations '3K-14, 3C-16, 3K-17, 1E-14, 3N-17, 3F-16 and 2V-12 Perforations 3N-11, 3F-11 and 3N-8A Failed MIT 3N-12, 3N- 1E-30 If you have any questions, please call me at 265-6840. Sincerely, G. B. Srr~llwood Senior Operations Engineer Attachments cc: J. Gruber M. L. Hagood S. P. Twiggs KOE1.4-9 ATO 1478 ATO 112O ATO 1130 RECEIVED ARCO Alas~:a. Inc. is a Subsidiary of AtlanticRicntieidComl~any STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska,, In(;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 985' FSL, 315' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1602' FSL, 1721' FWL, Sec. 2, T12N, R9E, UM At effective depth 1315' FSL, 1498' FWL, Sec. 2, T12N, R9E, UM At total depth 1233' FSL, 1435' FWL, Sec. 2, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 69 7. Unit or Property name Kuparuk River Unit 8. Well number :~K-17 ~('-~ -~ ~. ~ 9. Permit number/approval number 8-471 10. APl number 50-029-21842 11. Field/Pool Kuparuk River Oil Pool 9584' MD feet Plugs (measured) 6949' TVD feet None Effective depth: measured true vertical 9426' MD feet Junk (measured) 6830' TVD feet None Casing Length Structural Conductor 80' Surface 4 72 4' Intermediate Production 9 51 3' Liner Perforation depth: measure Size Cemented Measured depth True vertical depth 1 6" 1540# Poleset 115' MD 115' TVD 9-5/8" 1400 Sx AS III & 4761' MD 3704' TVD 335 Sx Class G 7" 490 Sx Class G & 9513' MD 6896' TVD 175 Sx ASI 8970-8994', 9199', 9203', 9205', 9207', 9231' MD 9244', 9253', 9258, 9263', 9275'-9281', 9326'-9334' MD 13. 14. true vertical 6694', 6701', 6704', 6708', Tubing (size, grade, and measured depth) 2-7/8", J-55, tbg w/tail @ 9097' Additional Perfs: MD: Packers and SSSV (type and measured depth) TV D: HRP pkr @ 8802', DB pkr @ 9069' & TRDP -1A-SSA SSSV @ 1810' feet 6502'-6518', 6661', 6664', 6666', 6667', 6685' TVD 6717'-6721', 6755'-6761' TVD 9189'-9209', 9229'-9246' 6644';6668', 6683'~6~,~5' ',:,~i:;;J~ .t)Jl & Gr~s Cons. C0mreis~i0i~ Stimulation or cement squeeze summary Refer to Well Service Report Intervals treated (measured) Refer to Well Service Report Treatment description including volumes used and final pressure Refer to Well Service Report Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 100 45 0 1100 Tubing Pressure 100 Prior to well operation 445 175 0 1160 112 Subsequent to operation 16. Status of well classification as: Oil X Gas Suspended Service 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations X Date ///'~/~ ~ SUBMIT IN DUPL.~ATE 17. I hereby certify that the foLegoing is true and correct to the best of my knowledge. Signed/,-:/ ~'/'~'r/.~'~) ~~'''''~rJ''-~'''v'~ Title Sr. Operations Engineer Form 1'0-404 R~v 06/15/88 ARCO Alaska, Inc. Date: August 26, 1988 Transmittal #: ¢280 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted hereWith are the following items. Please acknowledge- receipt and return one signed copy of this transmittal. 3 H- 2 2 Kt~paruk Well Pressure Report 6 - 2 9 - 8 8 Amerada 3 H - 2 2 - Kuparuk Well Pressure Report 8 - 1 0 - 8 8 Sand 'A' 3H-1 8 Bottom-Hole Pressure Survey 8- 22- 88 PBU 3 K - 1 7 Kuparuk Fluid Level Report 8 o 1 9 - 8 8 Casing 3 B - 1 4 Kuparuk Fluid Level Report 8 - 1 9 - 8 8 Casing 3 B - 1 3. Kuparuk Fluid Level Report 8 - 1 9 - 8 8 Casing Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska Chevron Mobil Unocal SAPC ~ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL CONTRACTOR r,,-MARKS ~-BDT FFIELD - DISTRICT- STATE ~:I'IME WELL SERVICE REPORT T'~ATE [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report oF OF~ miles] REMARKS CONTINUED: DESCRIPTION DALLY ACCUM. TOTAL CAMCO OTIS SCHt~UMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts Diesel Methanol ' Supervision Pre-Job Safety Meeting AFE' TOTAL FIELD ESTIMATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,¢SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing [] Other Fi Stimulate ~ Plugging [] Perforate [] Pull tubing [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 69 Feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, Alaska 99510-0360 Kuparuk River Unit 4. Location of well at surface 985' FSL, 315' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1602' FSL, 1721' FWL, Sec. 2, T12N, R9E, UM At effective depth 1315' FSL, 1498' FWL, Sec. 2, T12N, R9E, UM At total depth 1233' 7. Well number 3~-!7 Producer 8. Approval number 8-47;I 9. APl number 5O-- 029-21642 FSL, 1435' FWL, Sec. 2, T12N, R9E, UM 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical 9584' MD feet 6949' TVD feet Plugs (measured) None Effective depth: measured 9426' MD feet true vertical 6830' TVD feet Junk (measured) None Casing Length Structural 80~ Conductor 4724' Surface Intermediate 9513 ' Production Liner Perforation depth: measured Size Cemented Measured depth True Vertical depth 16" !540# Poleset 115' MD 115' TVD 9-5/8" 1400 SX ASIII & 4761' MD 3704' TVD 335 SX Class G 7" 490 SX Class G & 9513' MD 6896' TVD & 175 SX ASI 8970'-8994' 9199' 9203' 9205' 9207' 9231' MD 9244' 9253' 9258' 9263' 9275'-9281' 9326'-9334'MD 6502'-6518', 6661', 6664', 6666', 6667', 6685' TVD true vertical 6694', 6701', 6704', 6708', 6717'-6721', 6755'-6761 TVD Additional Perfs Tubing (size, grade and measured depth) MD: 9189'-9209, 9229'-9246' 2-7/8" J-55 tbg w/tail (~ 9097' TVB: 6644'-6668', 6683'-6695' Packers and SSSV (type and measured depth) HRP-1 pkr ~ 8802', DB pkr @ 9069'& TRDP-1A-SSA SSSV @ 1810' 12. Stimulation or cement squeeze summary Attached Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 88 40 0 0 329 122 0 1200 Tubing Pressure 100 95 14. Attachments Daily Report of Well OperationsZX~E] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ¢ f'l ,*' ,-. F°rm 10'404-Rev'- 1~~485'' ~-.¢E Date ~' ~/~ Submit in Duplicate~}/ WELL: 3 TUD · PERFS: G.(.,. x'?- MD · PERFS: HOLE tiNGLE l, PERFS: Iq'E SAND pERF INTERVAL . COMPANY TYPE DENSITY PHASING ACTUAL ..L...L%t C~ VOLUME RATE PRESSURE ACTUAL PROP. ANN. , ,~ ,. / ~ , ~ ,,, / ~ , , / , EFF. PAD: ~ T ~\s EFF. SLURRY: ~ ~\~. EFF. PROP: WHTPR: L,,-~ / C FRRC 6RRD: .~u, / ~. ISIP: ~-~-~o / ~. TBG.FRIC: z~c~ PERF FRIC: T o~ / DESIGN UOLUME STG/CUM LOS INTERVAL: FLUID TEMP: FLUID U I SC: %~-- ~-~-~ LERK OFF: 5 MIN. I0 MIN. NOTES: STATE OF ALASKA ALASK,~ OIL AND GAS CONSERVATION COMM,._,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ".:. Operation Shutdown i ] Re-enter suspended well [-3 Alter casing Eq Time extension Change approved program ~ Plugging _r-j Stimulate ~, Pull tubing ' ' Amend order F-! Perforate [; Other 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, .a. nchorage, 4. Location of well at surface 99510-0360 A~q~ c~Sp[rc~du3clt~v~ i~lrCa,sec'35' T13N, R9E, UM ' lptTh2 ]602 FSL 1' FWL Sec At e3fective ~le ' ' 1315' FSL, 1498' FWL, Sec. At total depth 191t ' 11.'~'~sen't ~N-e~l c-o~3Ttior~ ~'r~rn~a~7 ' Total depth: measured 8 ' 95 4 ND true vertical6949, TVD feet Effective depth: measured feet true vertical9426' MD feet 6830' TVD Length Size Casing Structural Conductor 80' Surface 4724' XXXXIXO~,~te Production 9513' Liner xxxxxxx, xxx,x Perforauon aepth: measured 2, T12N, R9E, UM 2, T12N, R9E, UM 9 T1 ?IV PO~ I IM feet 16" 9-5/8" 11 5. Datum elevation (DF or KB) RKB 69 6. Unit or Property name Ku,n_aru!< Piv~r Ilnil-. 7. Well number 3K- 17 /~,4. ~ ~J '~ ~c/t 8. Permit number Permit ¢85-152 9. APl number 5o- 029-21642 10. Pool Kuparuk River Oil Peel Plugs (measured) None Junk (measured) None Cemented Measured depth 1540# Poleset 115' MD 1400 SX ASIII & 4761' MD 335 SX Class G' 490 SX Class G & 9513' MD & 175 SX ASI ~ue Vertical depth 115' TVD 3704' TVB 6896' TVD 8970'-8994', 9199', 9203', 9205', 9207', 9231' MD 9244', 9253', 9258', 9263', 9275' -9281', 9326' -9334' MD truevertica~6502,_6518, 6661' 6664' 6666' 6667' 6685' TVD 6694', 6701' 6704' 6708' 6717'-6721' 6755'-6761' TVD Tubing (size, grade and measured depth) ' ' 'Additional 'Perfs 2-7/8", J-55, tbg w/tail @ 9097' MD: 9189'-9209', 9229'-9246' Packers and SSSV (type and measured de~th) TVD: 6644'-6668', 6683'-6695' HRP pkr @ 8802'~ DB pkr @ 9069' & TRDP-1A-SSA SSSV ¢ 1810' 12.Attachments Description summary of proposal 13. Estimated date for commencing operation 14. If proposal was verba!ly approved Name of approver L. Smith Anch0raq¢ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~4,& 7 A. ~''¢~ ~¢~'"¢¢~OTitle Sr. Operations Engineer Commission Use Only Date6/16/88 Conditions of approval Approved by ORiGiN:At SIGNED BY LONNIE C. SMITH Notify commission so representative may witness [] Plug integrity [] BOP Test E'., Location clearance Approved COpy Returned ff~ E3 Commissioner [ Approval No. by order of the commission Date feet Form 10-403 Rev 12-1-85 Submit in triplicate Attachment 1 Kuparuk Well 3K-17 Fracturing Procedure April 28, 1988 Summary: Well 3K-17 will be refractured in the A Sand with gelled diesel and propped with 16- 20 mesh Carbo-Lite proppant. A diesel/10% Musol soak is recommended prior to the treatment for asphaltene control. The treatment consists of a pre-pad for ISIP calculations, pad, and 16-20 mesh Carbo-Lite slurry stages pumped "on-the-fly" at 20 BPM. Proppant concentrations are ramped up from 2 to 10 PPG. Silica Flour is added only to the pre-pad and pad stages, for leak-off control. Pre Job Checklist: 1. Replace GLVs at 3076', 6974', and 8734' with DVs. Pressure test tubing. 2. Inspect all tanks for cleanliness. 3. Check diesel for contamination prior to gelling, i.e. "black diesel", water, etc. 4. Check proppant for fines due to excessive handling. Request sieve analysis of proppant and obtain proppant sample. 5. Record proppant weight before and after the fracture treatment. 6. Obtain a sample of the gelled diesel with breaker. Treatment Procedure: 1. RU fracturing equipment. Install "Tree Saver". Pressure test all lines. * Note: Well 3K-17 has a 3-1/8" CIW tree w/ a 3-1/2" tbg hanger. 2. Pressure up annulus to prevent buckling the tubing. Set pressure to account for thermal effects, achieving a maximum of 3500 psi during the treatment. 3. Pump 100 bbl Pre-pad stage. Shut down for ISIP calculations. * Check tank straps against metered volume. Correct flush volume accordingly. 4. Set pumps to trip off at 7250 psi wellhead pressure. Rate should be reduced if pressure exceeds 7000 psi. ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A . Pump fracture treatment per attached schedule: * All slurry stages should be mixed "on-the-fly". * Use silica flour in the PRE-PAD and PAD ONLY at 40 Ibs/Mgal. should contain NO silica flour. Slurry stages * The gelled diesel pre-pad, pad, and slurry stages should contain an 8 hour breaker. * Strap tanks "on-the-fly" during the pad stage to insure meter accuracy. * Ramp up slowly between slurry stages to avoid high density spikes. * Call flush as the densimeter drops from 10 PPG. * Expected Wellhead Treating Pressure: WHTP 516O psig Fracture Gradient 0.77 psi/ft TVD (6577' TVD) Tubing Friction 270 psi/1000 ft (9062' TVD) 6. Bleed down annulus pressure after the treatment. Flowback 1. , . . . Procedure: Begin flowback 8 hours after the fracture treatment. Crack open choke to establish a 5 to 10 bbl per hour flow rate. If excessive proppant is produced, reduce rate. Do not exceed 10 bbl per hour for the first three days of flowback. Record tank straps, choke settings and WHPs during the flowback. * The flowback is intended to remove gel residue without disturbing the proppant. Each day obtain one fluid sample for shakeout. When the shakeout shows no gel or proppant, and the BS&W is less than 2%, the well can be turned to the 3K production facilities. After the third day of flowback, reduce the FTP by 100 psi every 12 hours. Send strap sheets to J. Currier/B. O'Dell for transmittal to Anchorage Engineering. Obtain a 24 hour A Sand only well test. ARCO Alaska inc. is a subsidiary of Atlantic Richfield Company AR3B-6OO1-A KUPARUK WELL 3K-17 'A' SAND REFRACTURE PUMPING SCHEDULE *April 28, 1988' STAGE FLUID DESCRIPTION CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS BBLS BPM PPG DESCRIPTION LBS STG/CUM BBLS 1 DIESEL/10% MUSOL 40.0 1 0 1 DOWN 20 SHUT 20 20 20 20 20 20 20 20 2 DIESEL FLUSH 50.0 .............................................. SHUT 3 GD PRE-PAD 100.0 4 GD PAD 500.0 5 GD w/2 PPG 18.4 6 GD w/4 PPG 1 7.0 7 GD w/6 PPG 31.6 8 GD w/8 PPG 73.9 GD w/9 PPG 43.0 GD w/10 PPG 27.8 GD FLUSH 54.0 +SV 0 40/ 40 56 0 - - 0 50/ 90 96 OVERNIGHT TO SOAK ................................................... 0 40 Ibs/Mgal SILICA FLOUR 0 1 00/ 1 00 56 DOWN FOR ISIP ...................................................... 0 40 Ibs/Mgal SILICA FLOUR 0 500/ 600 156 2 16/20 M CARBO-LITE 1544 20/ 620 656 4 16/20 M CARBO-LITE 2856 20/ 640 676 6 16/20 M CARBO-LITE 7972 40/ 680 696 8 16/20 M CARBO-LITE 24841 1 00/ 780 736 9 16/20 M CARBO-LITE 16239 60/ 840 836 1 0 16/20 M CARBO-LITE 11661 40/ 880 896 0 - - 0 54/ 934 936 TOTAL GELLED DIESEL = 951.7 BBLS + SV ..... TOTAL MUSOL = 4.0 BBLS ,....~ ..~, .~,~ i~ll fluids should be maintained at 70 to 90 F on the surface. 16/20 M CARBO-LITE = SILICA FLOUR = 2. Stages 3 and 4 are Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for an 8 hour break. 3. Stages 5 through 10 are Gelled Diesel (8 hour break), WITHOUT SILICA FLOUR. 4. Stage 11 is Gelled Diesel with Iow temperature breaker ( 8 hour break). 5. Stage 11 should include a volume adjustment for surface equipment between the wellhead and densimeter. 6. This job is intentionally underflushed by 1.5 bbls. The blender tub should be bypassed at flush. 65113 LBS 1008 LBS Sundry Notice- Well 3K-17 A Sand Fracture Treatment No BOP's will be used during the treatment. The treatment will be pumped through a manifold on the surface, with a tree saver on the wellhead. No workover fluids will be used during the treatment. A Sand pressure (6200'SS)-- 3155 psi, 12/15/86 Amerada Static STATE OF ALASKA ALASr,,A OIL AND GAS CONSERVATION CON .... ,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 985' FSL. 315' FWL. Sec.35 T13N, R9E, UM At top of productive interval ' 1602' FSL, 1721' FWL, Sec. 2, T12N, R9E, UM At effective depth 1315' FSL, 1498' FWL, Sec. 2, T12N, R9E, UM At total depth 1233' FSL, 1435' FWL, Sec. 2: T12N: RgE, UM 5. Datum elevation (DF or KB) RKB 69 feet 6. Unit or Property name Ku~aruk Riwr Unit 7. Well number 3K-17 8. Permit number Permit #86-152 9. APl number 50-- 029-21642 10. Pool KuDar~Jk Riwr fltl-~nl 11. Present well condition summary Total depth: measured 9584' MD feet true vertical 6949' TVD feet Effective depth: measured 9426' HD feet true vertical feet 683O' TVD Casing Length Size Structural 80' 16" Conductor Surface 4724' 9-5/8" X X X ~k'~4 R ~r~X(XcJ~ ~t e Production 9513' 7" xxx k xxxx Plugs (measured) None SE,° 'Z Junk (measured) None.~$~0ii & 6~s Co~s. 6om~tssio~ Cemented Measured depth True Vertical depth 1540# Poleset 115' MD 1400 SX ASIII & 4761' MD 335 SX Class G 490 SX Class G & 9513' MD 115' TVD 3704' TVD 6896' TVD & 175 SX ASI Perforation depth: measured 8970'-8994' 9199' 9203' 9205' 9207' 9231' MD 9244' 9253' 9258' 9263' 9275' -9281' 9326' -9334' true vertical6502,_6518, 6661' 6664' 6666' 6667' 6685' TVD 6694' 6701' 6704' 6708' 6717'-6721' 6755'-6761' Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 9097' Packers and SSSV (type and measured depth) HRP nkr 0 ggO?' ~g ,n_~- fa qN~q' ~ TPrlP_I/1_~A ~! m 1~1N' , .~ ..................... ~ · ,. 12.Attachments Description summary of proposal (~ Detailed operations program © Convert well from oil producer to water in~ic_ctnr 13. Estimated date for commencing operation October 1, 1987 MD TVD BOP sketch 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _/:)~-.Z,.~ "/~" ~/~~-~(~Lc.,'~¥~' '"';"~ Title Sr. Operations Engineer Date9/16/87 Commission Use Only Conditions of approval Approved by Notify commission so representative may witness Approval No. [] Plug integrity [] BOP Test [] Location c earance Commissioner the commission Date ¢ --:c~' Form 10-403 Rev 12-1-85 Submit in triplicate (~ ARCO Alaska, Inc Post Office t~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: May 12, 1987 Transmittal # 5976 RETURN TO: ARCO Alaska, Inc.' Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2Z-7 3K-9A 3K-8 3K-17 IA-10 3Q-16 lA-2 3Q-15 3M-6 3M-2 3M-5 3M-7 3M-4 3M-3 3M-1 2Z-5 2Z-5 CET Log 4-20-87 8275-8597 CBL 11-14-86 5408-7460 CET 11-15-86 7148-8376 CET 11-15-86 7940-9400 CET 11-21-86 8650-8936 CBL 12-20-86 5349-7173 CET 12-21-86 7095-7781 CBL 12-20-86 5453-7360 CBL 4-30-87 5300-7312 CBL 4-28-87 6500-8295 CBL 4-28-87 6200-8795 CBL 4-30-87 6300-8359 CBL 4-28-87 7950-9845 CBL 4-28-87 5800-7933 CBL 4-28-87 4900-7187 Squeeze & Plug/Retainer Record 4-30-87 8090-8144 CET 4-30-87 7000-8324 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC .. - T 1987 //' , ./~a:Oll a Gas Cons. Commission - ~~...~ ...... - ~cborag~ ~State..:of.~ ~Alas~ -.. (+sepia}'~:~ BPAE Chevron ' ....~ /' . ~ ~ ..~ ~.'.. ;, .'~.; Un,on Vau~L (~) ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichlleldCompany STATE Of ALASKA ALASKA ..,iL AND GAS CONSERVATION COMMI, .ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown '-' Stimulate ~. Plugging - PerforateX Pull tubing - Alter Casing ~ Other ~ COMPLETE 2. Name of Operator ARCO Alaskai Inc. 3. Address P.O. Box 100360 Anchorage, AK 4. Location of well at surface 5. Datum elevation (DF or KB) RKB 69 ' Feet 99510-0360 6. Unit or Property name Kuparuk River Unit 7. Well number 985' FSL, 315' FWL, 5ec.35, T13N, R9E, UM At top of productive interval 1602' FSL, At effective depth 1315' FSL, At total depth 1233' FSL, 11. Present well condition summary Total depth: measured true vertical Effective depth: 1721' FWL, Sec. 2, T12N, R9E, UM 1498' FWL, Sec. 2, T12N, RgE, UM 1435, FWL, Sec. 2, T12N, R9E, UM ,, 9584 ' MD 6949 ' TVD measured 9426 'MD true vertical 6830 ' TVD 8. Approval number 9. APl number 50--. 029-21642 10. Pool Kuparuk River 0il Pool feet feet Plugs (measured) None feet feet Junk (measured) None Casing Length Size Conductor 80 ' 16" Surface 4724 ' 9-5/8" Producti on 9513 ' 7" Cemented Measured depth 1540# Pol eset 115'MD 1400 sx AS III & 4761 'MD 335 sx Class G 490 sx Class G & 9513'MD 175 sx AS I True Vertical depth 115'TVD 3704'TVD 6896'TVD Perforation depth: measured See Attached true vertical See Attached Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ~ 9111' Packers and SSSV (type and measured depth) HRP pkr ~ 8816', DB pkr ~ 9083' & TRDP-1A-55A 55SV L~ 1824' 12. Stimulation or cement squeeze summary i . N/A. mervais treated (measured) Treatment description including volumes used and final pressbre 13. Representative Daily Average Production or Injection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Well Hi story w/Addendum, dated 11/19/86) Daily Report of Well Operations -X ' Copies of Logs and Surveys Run ~ Gyro 15.1 hereby certify that the foregoing is true and correct to the best of my knowledgec~'- --~--'~~-~' Form 10-404 Rev. 12-1-85 ~/ Submit in Duplicate (DAM) SW0/149 REPORT Of SUNDRY WELL OPERATIONS 3K-17 Item #11. Perforation Depths: MD 8970 9199 9203 9205 9207 9231 9244 9253 9258 9263 9275 9326 -8994'* -9281' -9334' Perforated w/1 spf, 0° phasing *Perforated w/12 spf, Spiral phasing TVD 6502 -6518' 6661 6664 6666 6667 6685 6694 6701 6704 6708 6717 -6721 ' 6755 -6761 ' SWO/1 49a: dmr ADDENDUM WELL: 9/09/86 11/17/86 3K-17 Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak; tst OK. Rn CET/GR/CCL f/9400' - 7940' WLM. Rn GCT gyro f/surf to 9350'. Rn GR/JB to 9406' WLM, RD Schl. 1)~i1-1 lng S~'pervisor Oirand Gas Company Daily Well Hmtory-Final Report and submit the "Final Rel~3rt" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Flfl~~lld bo submitted also when operations are suspenDed for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. Tho "Final Report" form may be used for reporting the entire operation if alsace is available. I Accounting cost center code District IC°unty °r Parish /TM mlask¢3. Alaska North Slope Borough Field ILease or Unit [Well no. Kuparuk River ADL 25629 3K-17 Auth. or W.O. no. ~Title AFE AK1495 J Completion Nordic 1 API 50-029-21642 Operator ARCO Alaska, Inc. IA'R'c°' w'l'- 56.24% Iaband°nmentlc°strT°ta, number °f wells (active °r inactive) °n thisIcenter priOrof thist° pluggingwell and Complete 12/08/86 ! 1900 hrs. Date and depth as of 8:00 a.m. Old TD Released rig Complete record for each day reported 7" @ 9513' 9426' PBTD, RIH w/GR/JB 9.9 ppg Brine Accept Rig @ 1900 hfs, 12/08/86. NU BOPE &tst. RU WL, perf A-sand 1 spf 9326-9334', 9275-9281', 9263', 9258', 9253', 9244', 9231', 9207', 9205', 9203', 9199'. Perf C-Sand 8970'-8994', 12 spf. RIH w/6" GR/JB. 12/09/86 12/10/86 7" @ 9513' 9426' PBTD, RR 6.8 ppg diesel RU & rn 274 jts, 2-7/8", 6.5#, J-55 EUE 8RD AB-Mod tbg & 2 jts, 2-7/8", 6.5#, J-55 BTC tbg w/SSSV @ 1824', HRP Pkr @ 8816', DB pkr @ 9083', & TT @ 9111'. Tst tbg & ann to 2500 psi. Tst SSSV; OK.' ND BOPE, NU &tst tree to 250/5000 psi. Displ well w/diesel. RR @ 2315 hrs, 12/9/86. Al&sk& Oil & G~s Gons, gommission J New 9426 ' PBTD TD PB Depth Date IK nd of rig 2315 hrs. 12/9/86 I Rotary Classifications (oil, gas, etc.) 0±1 Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date ! Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. !Water % GOR Gravity Allowable EIfective date corrected The above is correct Signature For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor WELL COMPLETION OR RECOMPLETION REPORT & LOG 3K-17 (cont.) Item #24. Perforation Depths: MD 8970 -8994'* 9199 9203 9205 9207 9231 9244 9253 9258 9263 9275 -9281' 9326 -9334' Perforated w/1 spf, 0° phasing *Perforated w/12 spf, Spiral phasing TVD 6502 -6518' 6661 6664 6666 6667 6685 6694 6701 6704 6708 6717 -6721' 6755 -6761' WC2/O53a ADDENDUM WELL: 3K-17 9/09/86 Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak; tst OK. 11/17/86 Rn CET/GR/CCL f/9400' - 7940' WLM. Rn GCT gyro f/surf to 9350'. Rn GR/JB to 9406' WLM, RD Schl. 2/02/87 Frac Kuparuk "A" sand perfs 9199' 9203' 9205' 9207' 9231' 9244' 9253' 9258' 9263' 9275'-9281' and 9326'-9334' perf procedure dated 1/12/87 as follows: Stage 1: 40 bbls 145° hot diesel @ 1.5 - 5 BPM, 6500-5325 psi Stage 2: 150 bbls gelled diesel pre-pad @ 5 - 20 BPM, 5327'-7000-6480 psi Stage 3: 20 bbls gelled diesel pad @ 20 BPM, 6450 - 6530 psi Stage 4: 24 bbls gelled diesel 1# 100 mesh @ 20 BPM, 6530-6640 psi Stage 5: 250 bbls gelled diesel pad @ 20 BPM, 6640-6085 psi Stage 6: 32 bbls gelled diesel 2# 20/40 @ 17 BPM, 6085-5705 psi Stage 7: 32 bbls gelled diesel 4# 20/40 @ 17 BPM, 5705-5540 psi Stage 8: 32 bbls gelled diesel 6# 20/40 @ 17 BPM, 5540-5125 psi Stage 9: 25 bbls gelled diesel 8# 20/40 @ 17 BPM, 2125 - 5000 psi Stage 10:54 bbls gelled diesel flush @ 17 BPM, 5000 - 5800 psi Intentionally underflushed 2 bbls. Fluid to Recover: 659 bbls diesel Sand in Csg: 537# 20/40 Sand in Zone: 1000# 100 meSh & 23,990# 20/40 Ave Pressure: 5900 pSi Release well to Production. ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO' ARCO ALASKA, INC. ATTN' Kuparuk Records Clerk ATO-1119 P.O. Box 100S60 Anchorage, AK 99510-0360 Transmittal #5854 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Finals (blueline unless specified otherwise)' 3K-1~~ 5" DIL '~ 5" FDC '~2" FDC ~ 5II FDC ~2" DIL ~ Cyberl 8-27-86 4761-9572 Porosity 8-27-86 4761-9548 Raw 8-27-86 4761-9548 Porosity 8-27-86 4761-9548 Raw 8-27-86 4761-9548 8-27-86 4761-9548 ook 8-27-86 4761-9548 3K-14~Cyberlook 8-4-86 8300-8900 --"2" DIL 8-4-86 4752-8948 ~2I' FDC Porosity 8-4-86 8000-8922 5" FDC Raw 8-4-86 8000-8922 ~2" FDC Raw 8-4-86 4752-8922 -~5" FDC Porosity 8-4-86 8000-8922 "'~5II DIL 8-4-86 4752-8948 3K-16'~ 5" DIL '"~2" DIL ~'"~ 5" FDC ~ ~ "~'5" FDC ~2" FDC ~2" FDC Raw ~ Cyberlook 8-19-86 4893-9046 8-19-86 4893-9046 Porosity 8-19-86 8275-9021 Raw 8-19-86 8120-9021 Porosity 8-19-86 8275-9021 8-19-86 8120-9021 8-19-86 4893-9006 Receipt Acknowledged' aska Oil & Gas Cons. Corem!, Anchorage Date' Distribution' NSK Drilling State of Alaska<'(+ sepia)i Rathmel 1 Vault (film) D&M Johnston (yen. pkg) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCornpany ._ STATE OF ALASKA ALASKA ~L AND GAS CONSERVATION COMMIS._.ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend - Operation Shutdown ~ Re-enter suspended well -- Alter casing - Time extension ~ Change approved program ~ Plugging ~ Stimulate ~- Pull tubing- Amend order- Perforate-- Other '- 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage~ AK 99510 4. Location of well at surface 985' FSL, 315' FWL, Sec 35, T13N, R9E, UM At top of productive interval 1912. FSL, 1833' FWL, Sec. 2, T12N, R9E, UM (Approx) At effective depth 1365' FSL, 1476' FWL, Sec. 2, T12N, R9E, UN (Approx) At t(~16~le~stLh, 1411' FWL, Sec. 2, T12N, R9E, UM (Approx) 5. Datum elevation (DF or KB) 69 ' RKB 6. Unit or Property name K~Lnar~k River [Init 7. Well number 3K-17 8. Permit number 86-152 9. APl number 50-- 029-21642 10. Pool Kuparuk R-iver 0'il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80, 4724' 9513' Production 9584 ' MD feet 6968 ' TVD feet 9426'MD 6855 ' TVD feet feet Size 16" 9-5/8" 7" Plugs (measured) Junk (measured) None None Cemented 1540# Poleset 1400 sx AS III & 335 sx Class G 490 sx Class G & 175 sx AS I Measured depth 115 'HD 4761 'MD 9513 'MD True Vertical depth 115 'TVD 3718 'TVD 6918 ' TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) None None RECEIVED SEP 2 5 ]986 Alaska 0ii & Gas Cons. C0mm.ss,, ~ ~ ~ ~ r Anch0ra?~ 12.Attachments Description summary of proposal !-i Detailed operations program Well H-is'cory, Addendum (dated 9-16-86) 13. Estimated date for commencing operation - November, 1986 BOP sketch 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~'~J~ ~~.~4~/ Title Associ ate Engineer Commission Use Only (DAM) SA/110 Date Conditions of approval Approved by Notify commissionsorepresentativemaywitness I ApprovalNo. ~_7~/ Plug integrity ~, BOP Test © Location clearance o:~,7~ Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Companyv'~' Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District County, parish or borough IState Alaska North Slope Borough Alaska Field Lease or Unit IWell no. Kuparuk River ADL 25629 I 3K-17 Tit e Drill Auth. or W.O. no. AFE AK1495 DoYon 9 API 50-029-21642 Operator ARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun IDate IHour Pr or status if a W.O. Spudded I 8/21/86 I 0030 hrs. Date and depth as of 8:00 a.m. 8/21/86 8~22~86 8/23/86 thru 8/25/86 8/26/86 Complete record for each day reported 16" @ 115' 735', (620'), Drlg Wt. 9.0, PV 21, YP 23, PH 9.0, WL 12.6, Sol 5 Accept ri~ @ 2200 hrs, 8/20/86. NU diverter sys. 8/21/86. Drl 12¼" hole to 735'. Spud well @ 0030 hrs, 16" @ 115' 4000', (735'), Drlg Wt. 9.4, PV 17, YP 11, PH 9.0, WL 10.0, Sol 8 DD & surv 12¼" hole to 4000'. 616', 5.4°, S36.5W, 615.83 TVD, 7.16 VS, 5.76S, 4.26W 1078', 23.4°, S36.1W, 1062.12 TVD, 120.16 VS, 95.95S, 72.35W 1546', 35.4°, S39.4W, 1470.64 TVD, 346.80 VS, 274.60S, 211.91W 1862', 41.8°, S33.0W, 1717.23 TVD, 544.11VS, 434.92S, 326.97W 2422', 48.6°, S32.7W, 2111.83 TVD, 940.61VS, 768.74S, 542.51W 9-5/8" @ 4761' 7830', (3920'), TIH Wt. 9.2, PV 3, YP 3, PH 9.5, WL 8.2, Sol 6 Drl to 4785', short trip to HWDP, C&C, POH. RU & rn 119 jts, 9-5/8", 36#, ~J-55 BTC csg w/FC @ 4860', FS @ 4761' Cmt w/1400 sx AS III w/10#/sx Gilsonite. Tail in w/335 sx C1 "G" w}2% S-1 & .2% D-46. Displ using rig pmps, bump plug. ND diverter. NU & tst BOPE. TIH to FC, tst csg to 2000 psi. DO cmt & flt equip + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Turbine drl & surv 8½" hole f/4795'-7830'. 2991', 45.9°, S45.9W, 4060', 47.1°, S47.1W, 4720', 49.9°, S49.9W, 5220', 49.1°, 840.9W, 5786', 47.5°, S41.5W, 6351', 47.6°, 837.1W, 6604', 46.6°, 836.4W, 7545', 48.7°, 837.2W, 2498.07 TVD, 1357.02 VS, 1123.47S, 763.31W 3255.71TVD, 2109.00 VS, 1760.56S, 1166.74W 3691.87 TVD, 2603.76 VS, 2147.90S, 1475.00W 4016.59 TVD, 2982.41VS, 2431.33S, 1728.42W 4393.11TVD, 3403.66 VS, 2749.30S, 2006.78W 4774.45 TVD, 3820.10 VS, 3071.91S, 2270.83W 4946.67 TVD, 4005.43 VS, 3220.41S, 2381.72W 5572.71TVD, 4707.83 VS, 3777.81S, 2809.26W 9-5/8" @ 4761' 8653', (823'), TIH Wt. 10.0, PV 10, YP 14, PH 9.5, WL 4.8, Sol 10 Drl & surv 8½" hole to 8653'. 7888', 49.7°, S35.0W, 5796.83 TVD, 4967.46 VS, 3987.59S, 2962.23W 8389', 48.7°, S30.7W, 6125.27 TVD, 5345.22 VS, 4301.46S, 3173,2QW~ 8578', 48.5°, S30.6W, 6250.26 TVD, 5486 22 VS, 4423.4~~i~u SEP 2 5 1986 ;Nasl(a 011 & Gas Cons. Co~,.~':-,is~i The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ITitle Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report operation if space is available. Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are sus0ended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative -'.est data in blocks provided. The "Final Report" form may be used for reporting the entire County District Alaska L .... or Parish North slope Borough Field Kuparuk River or uo~t APL 25629 Auth. or W.OA~% AK1495 T tle Drill rAccounting cost center code State Alaska IWe"3~---17 Doyon 9 API 50-029-21642 Operator ARCO AlaSka, Inc. A.R.Co. ~6.24% Spudded or W.O. beaun Spudded Date 8/21/86 otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well / 0 hrs.'HOur 003 IPriOr statos if a W'O' Date and depth as of 8:00 a.m. 8/27/86 8/28/86 8/29/86 Complete record for each day reported 9-5/8" @ 4761' 9584', (931'), TIH Wt. 10.0,' PV 16, YP 9, PH 9.5, WL 4.4, Sol 11 Drl & surv 8½" hole to 9584'. 8578', 48.5°, S30..6W, 6250.26TVD, 5486.22VS, 4423.43S, 3245.47W 9-5/8" @ 4761' 9584', (0'), LD DP Wt. 10.0, PV 18, YP 8, PH 10.0, WL 4.0, Sol 12 Fin short trip, circ, spot 50 bbls diesel pill, POH. RU Schl, rn DIL/SP/SFL f/9582' WLM - 4761', GR f/9582' WLM - 1000', FDC/CNL f/9582' WLM - 4761' & CAL f/9582' WLM - 4761', RD Schl. TIH, circ, spot 50 bbl diesel pill, POOH, LD DP. 9494', 40°, S42W, 6904 TVD, 6125.21VS, 4938.41S, 3623.77W 7" @ 9513' 9584' TD, 9426' PBTD, RR 9.9 Ppg NaCl/NaBr Chg rams to 7". RU & rn 231 jts, 7", 26#, J-55 BTC csg w/¥C @ _ 9428', FS @ 9513', Mkr Jt @ 9135'. Cmt w/lO0 sx 50/50 Pozz w/4% D-20, .2% D-46 & .5% D-65, followed w/390 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ w/9.9 ppg brine, bump plug. CIP @ 2200 hrs, 8/27/86. ND BOPE, NU & tnt 11" 5000 tbg spool & tnt to 3000 psi. RR @ 0200 hrs, 8/29/86. Otd TO Released rig 0200 hrs. New TO Date 9584' TD IPeoepth 9426' PBTD 8/29/86 IKind of rig Rotary Classifications (oil, gas, etc.) Type compleLion (single, dual, etc.) Oil Single Producing method Fiow'~ t'lg official reservoir name(s~ Kuparu~ Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas ITest time Production I ~)il on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % CDR Gravity Allowable Elfective date corrected .... The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor , ( ADD END U M -------- WELL: 3K-l7 9/09/86 Arctic Pak w/l7S sx AS I, followed by 60 bbls Arctic Pak; tst OK. . REtE\'JED SEP 251986 0" ¡ Gas Cons, Commissi:. A\aska' ~m~hOraQ2 ~~ '1-/ ~ - ~ ~ Drilling Supervisor Date ARCO Alaska, Inc, Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 09-10.86 TRANSMITTAL ~ 5753 ~ 3K 17 08-27-86 Run #1 . ~3K-16. 08-19-86 Run #1 ~'3K-15 08-12-86 Run #1 ~2T-6 08-21-86 Run #1 ~ 2T-4 08-12-86 Run #1 ~-2T- 5 09-03-86 Run #1 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmit_tal,. ; Open Hole ~s Tapes ~~ L, istings.:~chl' One of each 0992.5-9606. 0059.0-9071.0~/ 0968 0-9302 0987 5-8235 0991/0- 7694. ~.~/~ Receipt Acknowledged: / L.,//' ~/~~5 fg_.~__/ (,,. ~/Date: ~ ....................... --... / Naska Oil & Gas Cons. Comm.,!ssi~ ¢'~t at e of~ Arlch0ra~.~ ARCO Al,lika, Inc. is a Subsidiary of AtlanticRichfieldComp'l'r~Y August~ 7, 1986 ~.'~. J. B. Ke~in Regional Drilling Engineer _ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3K- 17 ARCO Alaska, Inc. Permit No. 86-152 Sur. Loc. 985;FSL, 315'F~, Sec.35, T13N, R9E, UM. Btm~hoie Loc. 1431'FSL, !475'FI~, Sec. 2, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled~ Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~)trU~y~you~rs, ~ ~ C. V, Chatt'er'ton Chai~an of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COI{-{ISSIOB? dlf EnclosUre cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowe~z STATE OF ALASKA ALASKA O~- AND GAS CONSERVATION COrvIMISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill "¢ Redrill ~1 lb. Type of well. Exploratory [] Stratigraphic Test ~ Development Oil .'~ Re-Entry ~ Deepen'~1 Service ~ Developement Gas ~ Single Zone ~3 Multiple Zone ~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool !ARCO Alaska, Inc. RKB 69' , PAD 35' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River 0i 1 Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25629 ALK 2562 4. Location of well at surface 7. Unit or property Name 11. Type Bond lsee20AAC 25.025) 985'FSL, 315'FWL, Sec.35, T13N, RgE, UM Kuparuk River Unit 5tatewide At top of productive interval 8. Well nu .tuber Number 1912'FSL, 1833'FWL, Sec.2, T12N, RgE, UM 3K-17 i~8088-26-27 At total depth 9. Approximate spud date Amount 1431'FSL, 1475'FWL, $ec.2, T12N, RgE, UN 08/16/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD aod TVD) property line 9384 ' MD 985' (~ surface feet ~K-16 25'¢ surface feet 2.560 (6819'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle48 0 Maximum surface 2205 psig At total depth ErVD) 3/.+00 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2 ~.. ii !611 co ~.#. M . Il_ ~'~ tu ~ 1 ,-I ~nl q~l '~! ,i .'1 ~ i '1 .'1 ~ I _._ ,) n n ,...~ HF-FRW B~ ~v (~lm~ C hl~nd ~)-1/2" 7" 26.0# J-~ BTC 9350' 34' 34' 9384' ~6819' 200 sx Class G(minimum HF-ERW TOC 5(0' abov top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~ b Conductor i EEEIV Surface Intermediate ,P-~LJ[~ ~" (:..[bO0 Production, ¢ m AmJ(a 0il & Gas Cons. n0mm~,,,~o,* Liner Anchcrage Perforation depth: measured true vertical 20. Attachments Filing fee .~ Property plat ~ BOP Sketch .~ Diverter Sketch S~ Drilling program ,~ Drilling fluid program ~,, Time vs depth plot ~ Refraction analysis ~ Seabed report © 20 AAC 25.050 requirements/'~ 21. I herel~y certify that the foregoing is true and correct to the best of my knowledge Signed~~.~~7~~ Title Regional Dri,ling Engineer Datec~,~/~, ' ~) ~ ' Commission Use Only (HRE) PD/PD304 Permit Num~_152 I APi hurry,r9_21642 I Ap~vb%t,_86 I See cover letter 50-- for other requirements Conditions of approval Samples required ~ Yes ~'No Mud Icg required ~ Yes ~ No Hydrogen sulfide measures ~ Yes [] No Directional survey required ~ Yes ~ No Required worki~u~2~M; ~ 10M; .~ 15M~ ,_..,~/.. e,~.~ Other: q/~~~~/,~ by order of Approved by Commissioner the commission Dat . .. Form 10-401 Rev. 12-1-85 Sub~ triplicate P-ADL3K,L::WELL NO',-!i 7- PROPOSED KUPARUK--FtELD,i NORTH SL'OPE. ALASKA EASTNAI~ WH[PSTOCKi. i INC.. .... Q .............. SUBF~ .............................................................................................. ....... KOP_ .... TVD=SQQIMD-=50O .DEP_=O 9 BUILD 3 DEO _I_uu~L_~_.~.t5""" ............ pER~,~-, ........................................................................ I' -- BASE: PERMAFROST TVD=1721 11'113=1825 DEP-441 20.00 ..... ~.C_ ...... I ~Top UGNU SNDS TVD'2674' TND'3222 DE'P'~-462 ' - ............ : ........... I 4000 _ 5000._ 600.0 _ 7000 . . '"'x. K- 1 2 TVD-=--3524- TMD .-4486i. DEP--2397- ....... '_._.: _ ~x/ 9 5/8' CS¢ PT {._.._.~.._.T__V_D=3_724 TMD-4783 DEP-2617 , · ' AVERAGE ANGLE -~ RECEIVED ..... -- 47 DEG 44 MIN_ ................. ~ , ' ~Jaska Oil & Gas Cons. CornmJssiorL TX ZONE D TVD--S274-THD=8574 DEP=5423 T/ ZONE 0 TVD'6350 TMD'868Z DEP=5507 T/ zoNE ^ TVD-SSS TAR~E:T CNTR TVD=6624 TMD=9095 DEP=SeOa ~,' B/ KUP SNDS TVD=6684 TMD=9184 DEP=Se74 TD (LOG PT) TVD=6819 TMD=9384 DEP=6022 1 000 2000 3000 4000 5000 6000 7000 VERTICAL SECT-ION - ..... : ............. SL;~I:E: 1- -_IN;-: =_-- TO00 'FEETS_ '- 5000 4000 ' . JOI::iQ_ ~ . . . . WEST-EAS-T ..... 3000 2000': 1000 I I I · - . ~OOQ_ 4000_ - 5000 _ TAI~ET CENTER T~~4. .......... DEP-~ WEgT 34~4 0 1000 ! I ........... L:._:: £ S%tR~ LOC4T[OtI, · 905' FSL. 3!5' Fi, fl, ' b"E~.' 35, T13N. RgE . _ _ · _ RECEIVED · ~ ~ ,-,.; .. Auu- 6 ].986 Alaska 0il & Gas Cons, Commission Anchorage TARGET LOCAT'[ ON I 1603" FSI..- 1603'~'FWL SEC. 2. T12N. RgE ................ S.:. 3~:.-~G.:..~:::- M I-N .... W ............. 5505'~-'(TO TARGET:) TD LOCATION t 1431' FSL, 147'5' FWL SEC. 2, T12N, RgE · .... - ~ ............... ~ ....... ~_ ........ [~_i=.L~L .... IL:'__-.~ -~LL" "~ r I~2 '~ ' ' ~ ~ , ~.-~., r-~' ~3 ..... ~"~. ' ' ~ ......... ~- ~:o_~:_~ ....... ~~. :~oo:::.-: .... __~::_: .... --__~ . ..~.-:.:_ ~_ . .~- ~ ......... - ._. ~ .......... ~ ....... ~ .... ~ ' ', ' - ' I ,-' l'- '?::. ~- I I , ~ ....... _.. :~ ................... ~ ..... .-L~ :- ...... ~-- . ........ ~ ....... ~---~---~ ....... / : ~ _ 900 .... 80:0-- .... 700 60.0_ _ 50_0 .... 400 _ /. / / / / 1702 ~ 1455 / /- l \ \ 1 ........................... ~-- \' ! ~ 1 555 I \ I \ I \ .......... \ 1902 ~ 1802 I i I I I I I 2073 I i RECEIVED ', I Au-rs -'-6 1986 ~\1951 I Alaska. Oil & Gas Cons. Commission Anchorage \ I i I ' I _...ZOO-. 600_ _ 500 _. 400. GENERAL DRILLING PROCEDUh~ KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out. preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE SHAKERS DEOAS,SER [ CLF..ANER STIR ~ STIR STIR / TYPICAL MUD SYSTEM SCHEMATIC LWK4/ih RECEIV[D Alaska Oil & Gas Cons. Commission Anchora_ne Density PV YP Viscosity Initial Gel 10 Minute Ge1 Filtrate API pH % Solids DRILLING FLUID PROGRAM Spud to 9-5/8" Surface Casing 9.6-9.8 15-30 20-40 50-100 5-15 15-30 2O 9-10 10_+ Drill out to Weight Up 8.7-9.2 5-15 8-12 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 6 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed,well. Lw~5 / ih KUPARUK R I VER UN I T 20" D I VERTER $CHEMAT I C DESCRIPTION 1, 1G" CONDUCTOR. 2, TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY, S. TANKO UPPER QUICK-CONNECT ASSY, 6. 20" 2000 PSI ORILLINQ SPOOL W/lO" OUTLETS. 7. 10" HCR BALL VALVES W/lO" DIVERTER LINES, A SINQLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO,ACHIEVE DOI,~IND DIVERSION. 8 20 2000 PSI ANI~AR PREVENTER. . · ARCO ALASKA,' INC., REQUESTS . APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S.O3S(b) tq~ & [ MRINTENANCE & OPERRTION 4 ECE!VE¢ 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOINN~IND DIVERSION. DO NOT SHUT IN WELL UNOER ANY C I RCUMSTANCES. Anchorage SI (X)84002 7 6 TEST I. Q-E(]( ~ FILL AO3JVU.ATC~ RF. SI~OIR TO ~ LEV~. WITH ~IC FLUID. 2. ASBI,8~ THAT ACC1.MJ.AT~ PR~ IS ~ PSI WITH 3. ~ TII~, ~ CLC)~E Ali. UNITS SIhLLTA~E~Y ALL UNITS Ai~ CLOSED WITH QHA;~ING PUrl: OFF. 4. R~ ON NADC R~aORT, TI-[ A~AaLE LONER LIMIT IS 45 SE~ CLC~INO TII~: ~ 12DO PS! REI~A!NING 13-5/8" BCP STACK TEST !. FILL B(]a STA(]( ~ (:NO(E MANIFOLD V~TH ARCTIC DIESEL O-~O( THAT ALL LO0( ~ ~ IN VWEI. LJ-EAD Ft.lJ.Y RETRACTED. SEAT TEST PLUG IN WITH RU~qI~ JT AN3 RUN IN L~ 3. CLOSE ~ ~ MN> MN~LJAL KILL AN:) LII~[ VALVE. S ~ TO BCP STACX. ALL 4. ~ UP TO ~ P~I ~ HCLD FC~ I0 MIN. IN- (:]~EASE PRE~'~__.~ TO ~ PSI ~ HOD FCR ~0 MIN. B~ ~-n PR~ TO 0 PSI. Lib[ VALVES. CL~_r~_E_ TC~ PIPE RAIV~ AN3 H(~ VALVES ON KILL AN3 (]HO(E 6. TEST TO 250 PSI ~ 3(300 PSI A8 IN STEP 4. 7. CONTINL~ TESTING ALL VALVES, LIbE, S, AN:) WITH A 2.50 PSI LO/i ~ _3000__ PSI HI(~I. TEST AS iN ST~ 4. oo ~OT P~~ TZ~T /U~ ~ ,~AT ;A NOT A FLLL CLOSING POSITIYE SEAL CHOKE, CI~.Y Ft,I~-'TI~ TEST a-K3q~6 TI-~T CO ~ FI,LLY Ci_OS~. 8. ~ TCI3 PIF~ RAMS ~ CLC~E BOTTCM PIF~ RAMS. TEST BOTT(3~4 PIPE RAMS TO 2.50 PSI MN:) 3000 PSI. 9. ~ BOTTCM PIP~ RAMS, BACX OUT RLJNNIN~ JT I0. CLOSE BLIN:) RAMS AN3 TEST TO 2_50 PSI AN3 3000 PSI. II. ~ BLIN:) RAMS AJ~) ~:'r~IEVE-TEST PLUG. MAKE MAN~F~ AN3 LI~ES AR~ FULL CF ~IN~ FLUID. ~ ALL VALVES IN C~ILLIN~ P0S!TICI~. I~- TEST STAI~i3IP~ VALVES, KFt_IYo KELLY COQ<S, CRILL PIPE SAFETY VALVE, At~ I~IDE ~ TO 2.50 PSI 3CO3 PSI. 13. PECCJ~D TEST IN:'~TICIN CIN BLONOUT P~m/ENTER TEST FCt~o SIGN, AN) SE.N> TO CRILLIN~ ~ISCI~. 14. PF_J:~ CO, J3LET~ BCI:~ TEST ~ NIPP~,ING UP WEEt<LY THEREAFTF_R FLINCTIONALLY ~TE ~ DAILY (X~4001 ,~EV. MAY I 5,, 19~ ARCO Alaska, inc. :;. Post Office B0-~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 7, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built-Location Plat - 3K Pad (Wells 1 - 18) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU1/12 Encl osure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany LOCATED IN PROTRACTED LOCATED IN PROTRACTED I. ALL COORDINATES ARE A.S.E~ZONE4. ~ALL DISTANCES SHOWN ARE TRUE ~.HORIZONTAL POSITIONS BASED ON ~K CONTROL MONUMENTS PER LHD 4. VERTICAL POSITIONS BASED ON 5K TBM No. 4 ~ TBM No. 5 PER LHD ~ ASS~. 5.0. G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED EIXX-D070 rev.~ , CER~FICA~ OF SURVEYOR: I HEREBY C~I~ THAT I AM ~ROPERLY ~. ,.~, REGISTERED AND LICENSED ~ PRACTICE LAND ~RVEYING IN ~E STATE OF ALASKA ~D THAT ][ THIS PLAT REPRESENTS A COCATION SURVEY ~ -.. ' ' '" MADE BY ME OR UN~R MY SUPERVISION, AND ~ " .-' ARE CO~E~.AS OF 5 MAY 1986. ~ llHimm_ D..t SURVEYED z ..Y ,~.6 FOR:---- .. ARCO KUPARUK Alaska, PROJECT Inc. ': "'. .... ~.~w.~ DRILL SITE 5K CONDUCTOR ~, CHECK LIST FOR NEW WS~.I, PERMITS ITEM APPROVE DATE (1) Fee' . ~_~ .~-. 7~& 1. (2~ tl~ru 8)'~ (3) adn~n ~ ~':-¢~ 9. (9 thr~ '13) 10. f,TI4' ' (10 and 139 r' 12. 13. (4) Casg ' (14 thru 22) (23 thru--~~ (29 th~u 31) (6) Add: Geology: WVA Eng~n_eering: rev.. 07/18/86 6.011 14. 15. 16. 17. 18. 19. 20. 21. 22. ,,.iL Is the permit fee attached ........................................., ~.~_ 2. Is well to be located ina defined pOol ............ 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Lease & Well No. /~ 7( ~t. J/C-/'? NO ~ For 29. 30. 31. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface .......... Will cement tie in surface and intermediate or production strings... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonnmnt procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~ O oo psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) ............ ' ...... Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ " If an offshore loc., are survey results of seabed conditions presented- 32. Additional requirements ............................................. INITIAL GEO. '' UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX' No special 'effort has been made to chronologically organize this category of information. .o /(urrttf( 3/<.- /7 '(o~J1 ;'01(J,) '- iff: 03 I J 9 ~~~~~~~'~-~þ~#~#~'~~~~~~~~~-~~ MICROfilMED ¥#~~'~I~~'~'~'~'~¥~¥¥-~~~~~~~~ ,I. ..I, '.' ',' ÐaleJk /~- ,.I. .', ,,' ", ..I. ...';" 'f' ',' ~~~~~~~~~#~¿~,~~~~~~,~~~,~~ ~~~~~¥~~~~¥~~~¥~¥~~~~~~...~ *-~---,---------,----_.~* *----SCHLUMBERGER----* *----~-------~,-------* ~~#~~~,,~~,~~¿~,~~~~~~~~~~~~ ~~~~~~¥~~~~~~~~¥¥¥~~'~~ LIS TAPE UO¡SSIUlUlO ?Sfil?JOlpUV VE R I F I CAT ION L I Sf I N G . a uO:J sea, liD ~W 9861 ~ Z d3S (]31t'3J3~ .VP OlO.H02 VERIFICATION LISTING PAGE 1 ~* REEL HEADER ** 5ERVICE NAME :EOIT )ATE :86/08/29 )RIGIN : ~EEL NAME :142674 :ONTINUATION # :01 ;)REVIOUS REEL: :OMMENTS :LIBRARY TAPE ~* TAPE HEADER ** SERVICE NAME :EOIT JATE :86/08/29 JRIGIN :FS1A TAPE NAr"1E : :ONTINUATION ~ :01 PREVIOUS TAPE: :OMMENTS :LIBRARY TAPE *~******** EOF ********** ** FILE HEADER ** FILE NAME :EOIT .001 SERVICE NAME: VERSION:# : DA T E : MAXIMUM LENGTH: 1024 FILE TYPE: PREVIOUS FILE : ** INFORMATION RECORDS ** MNEM CONTENTS UNIT TYPE CATE SIZE CODE ---- --~-_.~-- ---- ---- ---- ~--,~ ---- CN : ARCO ALASKA, INC. 000 000 018 065 WN : 3K-17 000 OÛO 006 065 FN : KUPARUK RIVER ODD 000 014 065 RANG: 9E 000 000 002 065 TOWN: 13N 000 000 004 065 SECT: 35 000 000 002 065 COUN: NORTH SLOPE OO~ 000 012 065 STAT: ALASKA 000 000 006 065 CTRY: USA 000 000 004 065 MNEM CONTENTS UNIT TYPE CATE SIZE CODE -,--- -~---~-- _._-- ---- ---,~ -~-~ --~- PRES: E 000 000 001 065 ~:~ ,;, C OM MEN T S::o:~ ******************************************************************************** . VP 010.H02 VERIFICATION LISTING PAGE 2 - ...1... ..."..:# "''''t''''''''''''','' : SCHLU~3ERGER ....1:.. ...' : ALASKA COMPUTING C2NTER ::: t*****************;~************~,*~:****~:********~:*****~:*~:***:~************************ :Of-1PANY = ARC:J ALASKA INC ~ E Ll = 31<-17 :IELD = KUPARUK :OUNTY = NORTH SLOPE 30ROUGH ;TATE = ALASKA JOB NUMBER AT ACC: 71685 ~UN #ONE, DATE LOGGED: 27 ~UG 86 - D P: T HALSTEAD :ASING = 9.625" @ 4761' - 3IT SIZE = 8.5" TO 9584' r Y P E FLUID = WEIGHTED POLYM=R )ENSITY = 10.0 L3/G RM = 3.830 @ 63 OF iISCOSITY = 42.0 S RMF = 4.020 @ 63 OF )H = 9.5 RMC = 1.880 @ 63 OF :LUID LOSS = 4.4 C3 RM AT BHT = 1.708 @ 150 OF ~ATRIX SANDSTONE ,'1,...4". ,.t... ...~, ,-, THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS .},.... oI...J.. ,t. ..... -.' '.' '.'" "I'" 'I"""''i''¥~ ~******}~***************************************~,******************************* .VP 010.H02 VERIFICATION LISTING PAGE 3 * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ..... ,.t, ,(' '(' ,I.. SCHLUM3ERGER lOGS INCLUDED WITH THIS MAGNETIC TAPE: .... ..... '... ,I, .¡, ',' 'I' ,I, DUAL INDUCTION SPHERICALLY FOCUSED LOG (OIL) ,.t, '/" ,,.. ,'. DATA AVAILABLE: 9572' TO 4161" ~ ',' ,,.. ,', FORMATION DENSITY COMPENSATED LOG (FDN) ),~ '.' ,I, COMPENSATED NEUTRON LOG (FDN) ,.. 'I' .,. ,I, DATA AVAILABLE: 9548' TO 4761' ,to ." .... ,I. GAMMA RAY IN CASING (GR.CNL) ..... ',' '/" ,', DATA AVAILABLE: 4761" TO 1000" ..... '.' 't' ,I, ,c, '/" '.' * * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 4 1 66 1 8 4 73 60 9 4 6S .1IN 16 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API API API API FILE SIZE SPL REPR PROCESS ID ORDER # lOG TYPE CLASS MOO NO. CODE (OCTAL) DEPT FT 00 000 00 0 0 4 1 68 00000000000000 S,FLU OIL DHMM 00 2.20 01 0 0 4 1 68 0000.000000.0000 ILD OIL OHMM 00 120 46 0 0 4 1 68 00000000000000 ILM DIL OHMM 00 120 44 0 0 4 1 68 00000000000000 SP OIL MV 00 010 01 0 0 4 1 6S'QOOOOOnooooooO .VP 010.H02 VERIFICATIûN LISTING PAGE 4 ;R OIL GAP I 00 310 01 0 0 4 1 68 00000000000000 ;R FDN GAP I 00 310 01 0 0 4 1 68 00000000000000 :AL I FDN IN 00 280 01 0 0 4 1 68 00000000000000 <HO 8 FDN G/C3 00 350 02 0 0 4 1 68 00000000000000 )RHO FJN G/C3 00 356 01 0 ('¡ 4 1 68 00000000000000 \,i ~R AT FDN 00 420 01 0 0 4 1 68 00000000000000 ~NRA FDN 00 000 00 0 0 4 1 68 00000000000000 I.JÞHI FDN PU 00 890 00 0 0 4 1 68 00000000000000 'JCNL FDN CPS 00 330 31 0 0 4 1 68 00000000000000 FCNL FDN CPS 00 330 30 0 0 4 1 68 00000000000000 GR CNL GAPI 00 310 01 0 0 4 1 68 00000000000000 ~* DATA ~::~: DEPT 9606.0000 SFLU 2.3184 ILD 8.2109 ILM 2.4941 SP -9.1500 GR 105.9375 GR 105.9375 CALI 8.0781 RHOa 2.5488 DRHO 0.1797 NRAT 3.2168 RNRA 3.3789 NPHI 38.6119 NCNL 1950.0000 FCNL 577.0000 GR -999.2500 OEPT 9600.0000 SFLU 2.8164 ILo 8.2031 ILM 2.4902 SP -10.5000 GR 105.9315 GR 105.9315 CALI 8.0781 RHOS 2.5488 DRHO 0.1797 NRAT 3.2168 RNRA 3.3789 NPHI 38.6719 NCNL 1950.0000 PCNt 577.0000 GR -999.2500 DEPT 9500.0000 SFLU 2.5059 ILD 3.1426 ILM 3.1777 SP -10.2813 GR 99.6250 GR 99,.6250 CALI 8.6719 RHOB 2.4668 DRHO 0.1245 NRAT 3.3203 RNRA 3.5996 NPHI 39.6484 NCNL 2108.0000 PCNl 585.5000 GR -999.2500 DEPT 9400.0000 SFLU 2.4688 ILD 2.5723 IlM 2.6660 SP -5.7518 GR 99.8750 GR 99.8750 CAtI 9.0000 RHOS 2.3965 DRHO 0.0649 NRAT 3.3867 RNRA 3.7090 NPHI 40.3809 NCNL 1751.0000 FCNL 472.0000 GR -999.2500 DEPT 9300.0000 SFLU 3.6602 ILO 3.7010 ILM 3.7910 SF> -1.0078 GR 77.3125 GR 77.3125 CALI 8.7813 RHOS 2.4707 DRHO 0.0649 NRAT 3.1270 RNRA 3.2520 NPHI 35.9375 NCNL 2384.0000 FCNL 733.0000 GR -999.2500 DEPT 9200.0000 SFLU 63.3125 ItO 27.0781 ILM 36.0313 SP -29.2656 GR 46.5625 GR 46.5625 CALI 7.9766 RHOB 2.2617 DRHO 0.0166 NRAT 2.5311 RNRA 2.6836 NPH I 27.5879 NCNl 3108.0000 FCNL 1158.0000 GR -999.2500 OEPT 9100.0000 SFLU 5.4648 ILD 5.6953 ILM 5.8203 SP -17.2656 GR 88.5000 GR 88.5000 CALI 8.8828 RHOS, 2.4121 ORHO 0.0322 NRAT 3.0000 RNRA 3.2324 NPHI 33.4473 NCNL 2298.0000 FCNL 710.5000 GR -999.2500 OEPT 9000.0000 SFLU 6..5352 ILD 7.0156 ILM 7.1055 SF> -9.0469 GR 84.1250 GR 84.1250 CALI 8.7134 RHO B 2.4043 DRHO 0.0269 NRAT 2. 8711 RNRA 3.0742 NPHI 31.6406 NCNL 2484.0000 FCNL 808.0000 GR -999.2500 .vp OlG.H02 VERIFICATION LISTING PAGE 5 ) E P T 8900.0000 SFlU 3.5137 ILD 3.1660 ILM 3.3633 ;p -12.0625 GR 105.4375 GR 105.4375 CALI 11.6484 <HO õ 2.5156 DRHJ 0.0610 NRAT 2.1754 R NR A 2.8145 ~p H I 27.4414 NCNL 2045.0000 FC NL 726.5000 GR -999.2500 )E PT 8800.0000 SFLU 5.2578 ILD 3.8281 ILM 4.1797 ;P -15.5313 GR 39.0000 GR 99.0000 CALI 10.8906 <HO ð 2.6445 DRHO 0.2793 NRAT 2.7578 RNRA 3.0000 ~PH I 27.4902 NCNL 2438.0000 FCNL 812.5000 GR -999.2500 JE PT 8700.0000 SFLU 1.6875 ILO 1.8135 ILM 1.8496 5P -7.0234 GR 123.3750 GR 123.3750 CALI 9.4375 ~H08 2.3027 DRHO 0.0396 NRAT 3.7734 RNRA 3.8437 ~PHI 46.7773 NCNL 1600.0000 FCNL 416.2500 GR -999.2500 JE PT 8600.0000 SFLU 1.8199 ILD 2.0762 ILM 2.2422 5P -8.5469 GR 109.4375 GR 109.4375 CALI 13.8672 ~H08 -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 ~PH I -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 JEPT 8500.0000 SFLU 1.9844 ILD 2.0898 ILM 2.1348 SP -6.3203 GR 116.1250 GR 116.1250 CALI 11.9531 ~H08 -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 ~PHI -999.2500 NCNl -999.2500 FCNL -999.2500 GR -999.2500 )E PT 8400.0000 SFLU 2.8574 ILD 3.0781 ILM 3.1387 SP -12.2734 GR 199.2500 GR 199.2500 CAll 11.5859 ~H08 -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 I.Jp H I -999.2500 NCNL -99'9.2500 FCNl -99'3.2500 GR -999.2500 lEPT 8300.0000 SFLU 2.0293 ILO 1.3516 ILM 1.5693 SP -4.8125 GR 222.0000 GR 222.0000 CALI 10.2422 ~HOB -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 \I.P H I -999.2500 NCNL -9~39.2500 FCNL -999.2500 GR -999.2500 DEPT 8200.0000 SFLU 1.9541 ILD 2.3672 ILM 2.4453 S<P -8.0156 GR 128.6250 GR 128.6250 CALI 10.6406 RHOa -999.2500 DRHO -999..2500 NRAT -999.2500 RNRA -999.2500 \JPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 DEPT 8100.0000 SFLU 2.0059 ILO 2.1602 ILM 2.2129 SP -5.2461 GR 107.7500 GR 107.7500 CALI 10.1094 RHOa -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 DEPT 8000.0000 SFLU 2.0957 ILD 2.2402 ILM 2.2988 SP -4.8008 GR 93.3750 GR 93.3750 CALI '9.3150 RHOS -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 DEPT 7900.0000 SFLU 2.3262 ItD 2.5078 ILM 2.5586 SP -6.5117 GR 94.8750 GR 94.8750 CALI 10,.1562 RHOB 2.3984 ORHO 0.0122 NRAT 2.9238 RNRA 3.0917 .vP 010.H02 VERIFICATION LISTING PAGE 6 J PHI 30.7129 NCNL 1972.0000 FCNL 636.5000 GR -999.2500 ) E PT 7800.0000 SFLU 3.0103 ILD 3.2383 IlM 3.1680 ;p -11.5469 GR 85.5000 GR 35.5000 CALI 8.8437 ~HO S 2.3672 DRHD 0.1353 NRAT 3.0488 RNRA 3.1621 JPH I 34.4238 NCNL 2092.0000 FCNL 661.5000 GR -999.2500 )E PT 7700.0000 SFlU 3.0977 ILO 3.2391 ILM 3.3828 ;p -15.5000 GR 110.7500 GR 110.7500 CALI 11.5078 ~HO 8 -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 J PH I -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 )E P T 7600.0000 SFLU 2.4082 ILD 2.5020 ILM 2.5293 ;P -16.0313 GR 101.5625 GR 101.5625 CALI 10.9531 ~HOB -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 ~ PH I -999.2500 NCNL -999.2500 FCNl -999.2500 GR -999.2500 ) E PT 7500.0000 SFLU 2.0957 ILD 2.2051 ILM 2.2734 ;P -11.2734 GR 93.1875 GR 93.1875 CALI 10.1656 ~HOB -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 ~p H I -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 JEPT 7400.0000 SFLU 2.7246 ILD 2.9941 ILM 3.0176 ;P -19.0313 GR 105.8125 GR 105.8125 CALI 10.6484 ~HOB -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 ~PHI -999.2.500 NCNL -9.39.2500 FCNL -999.2500 GR -999.2500 JEPT 7300.0000 SFLU 2.8574 ILO 2.6895 ILM 2.8594 5P -16.3438 GR 97.5625 GR 97.5625 CALI 9.8612 ~HOB -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 \sP H I -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 DEPT 1200.0000 SFLU 2.7891 ILO 3.1504 IlM 3.1895 SP -21.5469 GR 106.62.50 GR 106.6250 CAtI 9.1891 RHOB -999.2500 DRHC -999.2500 NRAT -999.2300 RNRA - 999 . 25 0 0 ~PHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 DEPT 7100.0000 SFLU 3.0488 ILD 3.1797 ILM 3.2656 SP -22.2813 GR 103.9375 GR 103.9375 CALI 10.1797 RHOS -999.2500 DRHQ -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 DEPT 1000.0000 SFLU 2.9902 ILD 3.1158 ItM 3.2598 SP -25.5156 GR 123.3125 GR 123.3125 CALI 10..6016 RHOB -999.2500 ORHO -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI '-'399.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 OEPT 6900.0000 SfLU 2.1211 ItD 2.4180 ILM 2.4180 SP -22.5000 GR 91.8125 GR 91.8125 CALI 10.0938 RHOB -999.2500 ORHO -999.2500 NRAT -999.2500 RNR 4 -999.2500 NPHI -999.2500 NCNl -999.2500 FCNL -999.2500 GR -999.2500 DEPT 6800.0000 SFLU 3.9414 ILD 3.8359 ILM 4.0508 SP -27.2656 GR 93.5625 GR 93.5625 CALI 10.4766 .VP OlO.H02 VERIFICATION LISTING PAGE 7 cHO S 2.4590 ORHO 0.0527 Nt< AT 2.7520 RNRA 2.8066 JPH I 27.7832 NCNL 2316.0000 FCNl 825.0000 GR -999.2500 )E P T 6700.0000 SFLU 2.5176 ILD 2.4141 ILM 2.5181 ; p -47.3125 GR 90.3125 GR 90.3125 CALI 11.0000 ~HO a 2.2617 ORHG 0.0342 NRAT 3.1387 RNR,A 3.2715 ~PH I 33.1543 NCNL 19a6.0000 FCNl 607.0000 GR -999.2500 )EP T 6600.0000 SFLU 3.4297 ILD 3.7422 ILM 3.7383 ;p -32.0313 GR 100.2500 GR 100.2500 CAt! 10.4315 <HO B 2.3535 DRHO 0.0117 NRAT 2.9941 RNRA 3.1328 ~PH I 31.4453 NCNL 2370.0000 FCNL 756.5000 GR -999.2500 )E PT 6500.0000 SFLU 2.7949 ILO 3.1660 IlM 3.1055 ;p -34.2813 GR 103.4375 GR 103.4375 CALI 10.6875 ~HO 8 -999.2500 DRHO 0.0225 NRAT -999.2500 RNRA -999.2500 ~PH I -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 )EPT 6400.0000 SFLU 2.3672 ILO 2.7910 ILM 2.7051 SP -33.0313 GR 89.5000 GR 89.5000 CALI 10.5391 ~HOB -999.2500 DRHO 0.0684 NRAT -999.2500 RNRA -999.2500 \JPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 jE PT 6300.0000 SfLU 2.6602 ILD 2.8984 ILM 2.8496 SP -33.5313 GR 92.3125 GR 92.3125 CALI 10.7500 RHOB -999.2500 DRHD 0.0234 NRAT -999.2500 RNRA -999.2500 NPH I -999.2500 NCNL -999.2500 FCNl -999.2500 GR -999.2500 jEPT 6200.0000 SFLU 2.5898 ILD 2.5156 IlM 2.5410 SP -37.0313 GR 100.6250 GR 100.6250 CALI 11.7109 RHOS -999.2500 ORHO 0.0303 NRAT -999.2500 RNRA -999.2500 'JPHI -999.2500 NCNL -999.2.500 PCNL -999.2500 GR -999.2500 DEPT 6100.0000 SFLU 2.8047 ILO 3.1348 ILM 3.0879 5P -37.5000 GR 102..5625 GR 102.5625 CALI 11.1328 RHOS -999.2500 DRHO 0.0527 NRAT -999.2500 RNRA - 999. 25 00 NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 DEPT 6000.0000 SFLU 2.5762 ILD 2.9707 ILM 2.8828 SP -39.0000 GR 98.6250 GR 98.6250 CALI 10.6250 RHOB -999.2.500 DRHO 0.0024 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 DEPT 5900.0000 SFLU 2.3984 ILD 2.7813 ILM 2.7246 SP -20.7500 GR 92.5625 GR 92.5625 CALI 11.3438 RHOS -999.2500 DRHO 0.0464 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 DEPT 5800.0000 SFLU 3. 5078 ILO 3.5098 ILM 3.4980 SP -.20.6250 GR 88,.5000 GR 88.5000 CALI 10.6484 RHOB -999.2500 DRHO 0.0444 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 OEPT 5700.0000 SFLU 2.3574 lLO 2.7813 ILM 2.7070 _VP OlO.H02 VERIFICATION LISTING PAGE 8 5P -18.3750 GR 100.9375 GR 100.9375 CALI 12.6094 ~HO B -999.2500 DRHD 0.0259 NRAT -999.2500 RNRA -999.2500 ~ PH I -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 )E PT 5600.0000 SFLU 2.7832 ItD 3.1504 ILM 3.0918 5P -24.5781 GR 86.1875 GR 86.1815 CALI 12.8672 ~H08 -999.2300 DRHO 0.0131 NRAT -999.2500 RNRA -999.2500 ~PH I -999.2500 NCNL -999.2500 FCNt -999.2500 GR -999.2500 JEPT 5500.0000 SFlU 3.3633 ILO 3.5131 ILM 3.6504 5P -29.5938 GR 36.8150 GR 96.8150 CALI 11.4453 ~HOB -939.2500 ORHO 0.0244 NRAT -999.2500 RNRA -999.2500 ~PH I -999.2500 NCNL -999.2500 FC Nl -999.2500 GR -999.2500 JEPT 5400.0000 SFLU 2.9961 ILD 3.5059 ILM 3.3411 5P -30.0156 GR 87.5625 GR 87.5625 CALI 11.5859 ~HDa -999.2500 DRHO 0.0254 NRAT -999.2500 RNRA -999.2500 -JPHI -999.2500 NCNl -999.2500 FCNL -999.2500 GR -999.2500 )E PT 5300.0000 SFLU 2.2518 ILO 2.1500 ILM 2.6563 5P -28.3906 GR 84.5625 GR 84.5625 CALI 13.1188 ~HOB -9'99.2500 DRHO 0.0711 NRAT -999.2500 RNRA -999.2500 ~PHI -993.2500 NCNL -939.2500 FCNL -999.2500 GR -999.2500 JEPT 5200.0000 SFLU 2.4570 ILO 2.9395 ILM 2.7930 5P -30.3125 GR 96.8750 GR 96.8750 CAtI 13.2344 ~HDB 2.3125 DRHD 0.0786 NRAT 3.4297 RNRA 3 . 6270 ~PH I 37.4023 NCNL 1890.0000 FCNL 521.0000 GR -9'99.2500 JEPT 5100.0000 SFLU 2.2631 ILO 2.7422 ILM 2.6016 SP -29.3125 GR 87.7500 GR 87.1500 CALI 13.1094 <HOB 2.3184 DRHO 0.0152 NRAT 3.7129 RNRA 4.0000 IJPHI 42.6270 NCNL 1817.0000 FCNL 454.2500 GR -999.2500 D.E PT 5000.0000 SFLU 12.4141 ILO 10.,9141 ILM 11.7344 SP -70.1250 GR 84.2500 GR :84.2500 CALI 11.1344 RHOS 2.1406 DRHO 0.0127 NRAT 3.3130 RNRA 3.6602 \JPHI 37.1094 NCNL 1931.0000 FCNL 527.5000 GR -999.2500 DEPT 4900.0000 SFLU 2.3145 ILO 3.1152 ILM 2.8750 SP -27.8281 GR 103.1815 GR 103.1875 CALI 14.5703 RHOS 2.2617 DRHO 0.0356 NRAT 3.5020 RNRA 3.6660 NPHI 38.0859 NCNL 1786.0000 FCNL 487.0000 GR -999.2500 DEPT 4800.0000 SFLU 3.1934 ILO 4.2461 IlM 3.8612 SP -40.3125 GR 74.1250 GR 74.1250 CAtI 13.1875 RHOB 2.1895 DRHD 0.0161 NRAT 3.6699 RNR A 4.0181 NPHI 41.7969 NCNL 1693.0000 fCNL 414.7500 GR 96.5000 OEPT 4700.0000 SFLU -999.2500 ILD -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 RHOa -999.2500 DRHO -9'39.2500 NRAT -999..2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2.500 FCNL -999.2500 GR 74.3125 .VP OlO.H02 VERI~ICATION LISTING PAGE 9 )E P T 4600.0000 SFlU -939.2500 Ii r. -999.2500 IL~ -999.2500 ... .t.J ; P -'999.2500 GR -9gS.2500 GR -9'39.2500 CALI -999.2500 ~HOe. -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 . PH I -999.2500 NCNL -999.2500 FCNl -999.2500 GR 52.6250 )E P T 4500.0000 SFLU -939.2500 IL D -999.2500 ILM -999.2500 ;p -9'39.2500 GR -999.2500 GR -999.2500 CALI -999.2500 ~HO B -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 JPH ¡ -999.2500 NCNL -939.2500 FCNL -999.2500 GR 58.1813 )E PT 4400.0000 SFLU -999.2500 ILD -999.2500 ILM -999.2500 ;p -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 (HOB -999.2500 DRHO -9~39.2500 NRAT -999.2500 RNRA -999.2500 JP H I -999.2500 NCNL -999.2500 FCNL -999.2500 GR 41.4315 ) E P T 4300.0000 SFLU -999.2500 !LD -999.2500 ILM -999.2500 ;p -999.2500 GR -999.2500 GR -999.2500 CAL I -999.2500 ~HOB -999.2500 ORHO -999.2500 NRAT -999.2500 RNRA -999.2500 JPH I -999.2500 NCNL -999.2500 FCNL -999.2500 GR 54.2813 JEPT 4200.0000 SfLU -999.2500 ILO -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 ~HO B -999.2500 DRHO -999.2500 NRAT -999.2.500 RNRA -999.2500 ~PHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR 52.4688 )E PT 4100.0000 SFLU -999.2500 ILD -999.2500 ILM -999.2500 SP -999.2.500 GR -999.2500 GR -999.2500 CALI -999.2500 ~H08 -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 'lPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR 38.9062 DE PT 4000.0000 SFLU -999.2500 ILD -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 RH08 -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -99'3.2500 FCNL -999.2500 GR 43.6563 DEPT 3900.0000 SFLU -999.2500 ILD -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 RHOS -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR 56.7500 OEPT 3800.0000 SFLU -999.2500 ILD -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CAL I -999.2500 RHOS -999.2500 DRHO -999.2500 NRAT --999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 FCNL -9'39.2500 GR 51.0625 DEPT 3700.0000 SFLU -999.2500 ILD -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 RHOS -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNl -999.2500 fCNL -999.2500 GR 21.5000 DEPT 3600.0000 SFLU -999.2500 ILO -999.2500 I L~1 -999.2500 SP -999.2500 GR '-999.2500 GR -999.2500 CALI -999.2500 RHOS -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR 44.2813 .vP OlO.H02 VERIFICATION LISTING PAGE 10 )E PT 3500.0000 SFLU -999.2500 ILO -999.2500 ILM -999.2500 ;p -999.2500 GR -<;99.2500 GR -999.2500 CALI -999.2500 ~HO 8 -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 JPH I -999.2500 NCNL -9'39.2500 FCNL -999.2500 GR 46.8150 )E P T 3400.0000 SFLU -939.2500 ILD -999.2500 ILM -999.2500 ;p -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 ~ HO õ -999.2500 ORHJ -999.2500 NRAT -999.2500 RNRA -999.2500 ~PH I -999.2500 NCNL -999.2500 FCNL -999.2500 GR 31.6094 )E P T 3300.0000 SFLU -9::19.2500 IlD -999.2500 ILM -999.2500 ;p -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 <HOB -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 ~PH I -999.2500 NCNL -999.2500 FCNL -999.2500 GR 50.3150 JEPT 3200.0000 SFLU -999.2500 ILO -999.2500 ILM -999.2500 SP -999.2500 GR -939.2500 GR -9/39.2500 CALI -999.2500 ~HO B -999.2500 DRHD -999.2500 NRAT -999.2500 RNRA -999.2500 I,JPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR 55.4688 DEPT 3100.0000 SFLU -999.2500 ILD -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 RHOS -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2.500 NCNL -999.2500 FCNL -999.2500 GR 46.2181 OEPT 3000.0000 SFLU -999.2500 ILO -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 RHDB -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR 49.4688 OEPT 2900.0000 SFLU -999.2500 ILO -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 RHOS -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL - 9 99 '. 2 50 0 FCNL -999.2500 GR 28.4531 OEPT 2800.0000 SFLU -999.2500 ItO -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 RHOB -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR 39.1562 DEPT 2100.0000 SFLU -999.2500 ILD -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 RHOB -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR 33.1250 OEPT 2600.0000 SFLU -999.2500 ILD -999.2500 ILM -999..2500 SP -\399.2500 GR -999.2500 GR -999.2500 CALI -999.2500 RHOB -999.2500 DRHD -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 fCNL -999.2500 GR 34.0000 DEPT 2500.0000 SFLU -999.2500 ILO -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 RHOB -999.2500 DRHO -9'39.2500 NRAT -999.2500 RNRA -999.2500 .vP OlO.H02 VERIFICATION LISTING PAGE 11 ~PH I -999.2500 NCNL -9j'3.2500 FCNl -999.2500 GR 45.8437 )E PT 2400.0000 SFLU -999.2500 !LO -939.2500 IlM -999.2500 ;p -999.2500 GR -9',9.2500 GR -999.2500 CALI -999.2500 ~HO B -999.2500 Or<HO -999.2500 f\¡RAT -999.2500 RNRA -999.2500 ~p HI -'3'99.2500 NCNL -999.2500 FCNL -999.2500 GR 33.8150 )E PT 2300.0000 SFLU -999.2500 ILO -999.2500 IlM -999.2500 ;p -999.2500 GR -939.2500 GR -999.2500 CALI -999.2500 <H 0 a -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 ~p H I -999.2500 NCNL -999.2500 FCNl -999.2500 GR 33.3438 )E P T 2200.0000 SFLU -99'9.2500 IlD -999.2500 ILM -999.2500 5P -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 ~HOB -999.2500 ORHO -999.2500 NRAT -999.2500 RNRA -999.2500 ~PH I -999.2500 NCNL -999.2500 FCNL -999.2500 GR 21.3906 JE PT 2100.0000 SFLU -999.2500 ILD -999.2500 ILM -999.2500 5P -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 ~H08 -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 ~PH I -999.2500 NCNL -999.2500 FCNL -999.2500 GR 44.5313 )EPT 2000.0000 SFLU -999.2500 ILD -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 ~HOB -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 "PHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR 21.2656 :>EPT 1900.0000 SFLU -999.2500 ILD -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 RHOS -999.2500 DRHO -9'99.2500 NRAT -999.2500 RNRA -999.2500 \JPHI -999.2500 NCNl -999.2500 fCNL -999.2500 GR 45.1813 JEPT 1800.0000 SFLU -999.2500 ILD -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 RHOB -999.2500 DRHO -999.2500 NRAT - 915;9.25 00 RNRA -999..2500 \JPHI -999.2500 NCNl -999.2500 FCNl '-999.2500 GR 49.0938 DEPT 1700.0000 SFLU -999.2500 ILO -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 RHOB -999.2500 DRHO -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 ¡::CNL -999.2500 GR 19.1562 DEPT 1600.0000 SFlU -999.2500 ILD -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CAtI -999.2500 RHOS '-999.2500 DRHû -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 FCNL -999.2.500 GR 30.2813 DEPT 1500.0000 SFLU -999.2500 ILO -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 RHOS -999.2500 ORHO -999.2500 NRAT -999.2500 RNRA -999.2500 NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR 34.0625 DEPT 1400.0000 SFLU -999.2500 ILO -999.2500 IlM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 C.ALI -999.2500 .vp 010.H02 VERIFICATION LISTING PAGE 12 ¡H03 -9~9.2500 DRHO -939.2500 NRAT -999.2500 RNRA -999.2500 JP H I -999.2500 NCNL -999.2500 FCNL -999.2500 GR 49.3438 ) E P T 1300.0000 SFlU -999.2500 ILO -999.2500 ILM -999.2500 ;P -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 ~H J 6 -999.2500 DRHD -939.2500 NRAT -999.2500 RNRA -999.2500 JPH I -999.2500 NCNL -999.2500 FCNL -999.2500 GR 31.3438 )E PT 1200.0000 SFlU -999.2500 ILD -999.2500 ILM -999.2500 ;P -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 ~H 08 -999.2500 ORHO -999.2500 NRAT -999.2500 RNRA -999.2500 JPH I -999.2500 NCNL -999.2500 FCNL -999.2500 GR 42.9062 )E PT 1100.0000 SFlU -999.2500 ILD -999.2500 ILM -999.2500 ;p -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 ~HOB -999.2500 ORHO -999.2500 NRAT -999.2500 RNRA -999.2500 ~P HI -999.2500 NCNL -999.2500 FCNl -999.2500 GR 35.5938 lE PT 1000.0000 SFLU -999.2500 ILO -999.2500 ILM -999.2500 5P -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 ~H06 -999.2500 ORHO -999.2500 NRAT -999.2500 RNRA -999.2500 ~PH I -999.2500 NCNL -999.2500 fCNL -999.2500 GR 51.7188 JE PT 992.5000 SFLU -999.2500 ItO -999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALI -999.2500 ~H08 -999.2.500 D'RHO -999.2500 NRAT -999.2500 RNRA -999.2500 \JPHI -9'99.2500 NCNL -999.2500 FCNL -999.2500 GR 44. 5938 ** FILE TRAILER ** FILE NAf'i\E :EDIT .001 SERVICE NAME . . VERSION #. . . DATE: MAX I MUML ENG TH : 1024 FILE TYPE . . NEXT FILE NAME . . ********** EOF ********** ** TAPE TRAILER ** SERVICE NAME :EDIT DATE:86/08/29 ORIGIN :FS1A TA P E NAME : CONTINUATION # :01 NEXT TAPE NAME: COMMENTS :lIBRARY TAPE **REEL TRAILER ** SERVICE NAME :ED!T DATE :86/08/29 .VP OlD.H02 VERIFICATION LISTING P~GE 13 JRIGIN . . ~ EEL N A Î~ E :142674 :ONTINUATICN # : 01 ~tXT REEL NAME . . :OMMENTS :LIBRARY TAPE ********** EOF ********** ********** EOF *~:********
