The URL can be used to link to this page

Home My WebLink About204-034Originated:Delivered to:9-Nov-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 2N-345A 50-103-20264-01 906623204 Tarn Perforation Record Field- Final 25-Jul-20 0 1 2 2U-02 50-029-21268-00 906648446 Kuparuk River Packer Setting Record Field- Final 11-Aug-20 0 1 3 CPF-1A 50-029-21243-00 n/a Shallow Sands Leak Detect Log Field- Final 26-Aug-20 0 1 4 2G-08 50-029-21125-00 906640095 Kuparuk River Leak Detect Log and Plug Setting RecordField- Final 4-Aug-20 0 1 5 2M-24 50-103-20171-00 906622440 Kuparuk River Packer Setting Record Field- Final 7-Aug-20 6 2M-24 50-103-20171-00 906622440 Kuparuk River Packer Setting Record Field- Final 8-Aug-20 7 2M-33 50-103-20240-00 906598622 Kuparuk River Multi Finger Caliper Field- Processed 9-Aug-20 0 1 8 1A-23 50-029-22131-00 n/a Kuparuk River Leak Detect Log Field- Final 11-Aug-20 0 1 9 2B-02A 50-029-21154-00 n/a Kuparuk River Leak Detect Log Field- Final 27-Aug-20 0 1 10 2M-10 50-103-20157-00 906659029 Kuparuk River Multi Finger Caliper Field- Processed 15-Aug-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 Received by the AOGCC 11/09/2020 11/09/2020 Abby Bell PTD: 2040340 E-Set: 34235 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8557' feet N/A feet true vertical 5414'feet N/A feet Effective Depth measured 8557'feet 5270'feet true vertical 5414'feet 3726'feet Perforation depth Measured depth 8120'-8135', 8265'-8295'feet True Vertical depth 5200'-5208', 5272-5287'feet Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 5261' MD 3721' TVD Packers and SSSV (type, measured and true vertical depth)5270' MD 527' MD 3726' TVD 527' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 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: Steve Drake Contact Name: Authorized Title:Senior Wells Engineer Contact Email: Contact Phone: Packer: Baker HR ZXP Liner Top Packer SSSV: Camco DS Landing Nipple Senior Engineer: Senior Res. Engineer: Collapse 5414' BurstTVD 109' 2307' 3833' 16" 7-5/8" 5-1/2" 3-1/2" 5450' 8556' Conductor Surface Intermediate Production Length 80' 2760' 5422' Size Authorized Signature with date: Authorized Name: Liner Kuparuk River Field/ Tarn Oil Pool 3303' Casing Structural N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 270 4. Well Class Before Work: N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 140 Gas-Mcf measuredPlugs Junk measured N/A Tubing Pressure KRU 2N-345A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-034 50-103-20264-01-00 5. Permit to Drill Number:2. Operator Name N 3. Address: measured true vertical Packer 900 800 90 Representative Daily Average Production or Injection Data 2701000 Casing Pressure ConocoPhillips Alaska, Inc. WINJ WAG 25 Water-Bbl MD 109' 2789' ADL 375074 P.O. Box 100360 Anchorage, AK 99510 Steve Drake (907) 263-4062 steve.g.drake@conocophillips.com 50 950 Oil-Bbl Development Service GINJ SUSP SPLUG Gas Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Steven G. Drake Digitally signed by Steven G. Drake Date: 2020.10.15 15:06:01 -08'00' By Samantha Carlisle at 3:17 pm, Oct 15, 2020 VTL 11/03/20 DSR-10/15/2020 SFD 10/20/2020RBDMS HEW 11/25/2020 STIMULATE-4/30/2020 CLEANOUT Continue moving to 2N-345A, arrive on location, RU, PT, freeze protect FL w/10 bbls of diesel. RU LRS, PT. RIH and HOT flush tubing from 4,000' to surface with 3 passes. FCO w/ nitrogen from 4,000' to 8,390'. Lay in slick seawater from 8,391' to 2,600' and diesel to surface. (IN PROGRESS READY FOR EL) STIMULATE-5/1/2020 CLEANOUT RIH W/ RST. TAGGED TOP OF PERFS @ 8120', UNABLE TO GET PASS PERFS. POOH. RIH W/ SLIM TOOLSTRING. SET DOWN ON PERFS @ 8120'. ATTEMPTED PUMPING, ONLY ABLE TO PUMP .25 BPM @ 3000 PSI. UNABLE TO GET THROUGH PERFS. POOH. PUMPING5/4/2020 TRACKING ONLY fREEZE PROTECT 5 BBLS DIESEL DWN FLOWLINE & 30 BBLS DIESEL DWN TBG. "JOB COMPLETE" (AC EVAL) SI TIFL FAILED DUE TO IA PRESSURE INCREASE ANDANNCOMM5/29/2020 INFLOW TAG @ 8125' RKB & MEASURED BHP @ 8101' RKB (2668 PSI).ANNCOMM7/8/2020 BRUSHED 2.75" D NIPPLE @ 5219' RKB (( UNABLE TO PUMPED INTO WELL )), SET 2.75" CSV @ 5219' RKB. PULLED & REPLACED OV ( IN KIND ) @ 5154' RKB. (OV CHECK WAS WASHED OUT) OBTAINED PASSING MIT-T TO 2500 PSI., PULLED 2.75" CSV @ 5219' RKB, JOB COMPLETE. STIMULATE-7/23/2020 CLEANOUT RAN MULTIPLE BAILERS UP TO 2.5" & CLEARED WHAT APPEARED TO BE FILL BRIDGE @ 8124' RKB & TAGGED TD @ 8384' RKB (EST. 249' OF RATHOLE); BRUSH n' FLUSHED & GAUGE TBG W/ 2.67 GAUGE RING (SEEING RESTRICTION @ 5478' RKB) DOWN TO 8383' RKB; ATTEMPT TO DRIFT W/ 2.5" DMY PERF GUN & UNABLE TO PASS RESTRICTION @ 5478' RKB. ATTEMPT TO BRUSH n' FLUSH AGAIN W/ 2.67" GAUGE RING AND UNABLE TO PASS RESTRICTION @ 5478' RKB. IN PROGRESS. STIMULATE-7/24/2020 CLEANOUT BRUSH n' FLUSH (W/ 2.71" CENT, TANDEM BLB, & 2.71" GAUGE RING) HAVING TO WORK TOOLS AGGRESSIVELY TO FROM 5450'-5956' RKB TO PASS & DRIFT DOWN TO 8379' RKB; UNABLE TO DRIFT PAST 5472' RKB W/ 2.5" X 24' OR 2.5" X 12' DUMMY GUNS; DRIFT W/ 15' X 2 1/8" STEM W/ 2.25" BAILER @ 150' PER MIN DOWN TO 8379' RKB; DRIFT W/ 2.78" CENT. W/ NO ANOMALIES DOWN TO D-NIPPLE @ 5219' RKB. IN PROGRESS. ((TUBING APPEARS TO HAVE IMPINGEMENT @ 5472' RKB)) READY FOR E-LINE TO PERF W/ 2" GUNS. STIMULATE-7/25/2020 CLEANOUT PERFORATE LINER FROM 8265'-8295' RKB W/ 2" X 30' HSC (2" 6SPF 60SPHASE MAXFORCE CHARGES) CORRELATED TO BAKER RISISTIVITY GR LOG DATED 14-MAY--04. JOB COMPLETE. 2N-345A Perf Operations Summary DTTMSTART JOBTYP SUMMARYOPS Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 84' of Rathole) 8,379.0 7/24/2020 2N-345A zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Add New Perfs 7/25/2020 2N-345A zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 29.2 Set Depth (ftKB) 109.0 Set Depth (TVD) … 109.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 29.3 Set Depth (ftKB) 2,789.2 Set Depth (TVD) … 2,307.0 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-MOD Casing Description PRODUCTION Post S/T OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 27.5 Set Depth (ftKB) 5,450.0 Set Depth (TVD) … 3,833.5 Wt/Len (l… 15.50 Grade L-80 Top Thread MOD Casing Description WINDOW A OD (in) 5 1/2 ID (in) 4.50 Top (ftKB) 5,428.0 Set Depth (ftKB) 5,440.0 Set Depth (TVD) … 3,827.4 Wt/Len (l… 15.50 Grade L-80 Top Thread Casing Description LINER OD (in) 3 1/2 ID (in) 2.99 Top (ftKB) 5,252.5 Set Depth (ftKB) 8,556.0 Set Depth (TVD) … 5,414.4 Wt/Len (l… 9.30 Grade L-80 Top Thread HYDRIL 511 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,252.5 3,716.4 54.64 SBE BAKER SEAL BORE TIE BACK EXTENSION 4.125 5,269.8 3,726.4 54.57 PACKER BAKER HR ZXP LINER TOP PACKER 3.410 5,278.2 3,731.3 54.54 PBR BAKER POLISHED BORE NIPPLE 3.250 5,282.7 3,733.9 54.52 HANGER BAKER HMC LINER HANGER 2.920 Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 26.3 Set Depth (ft… 5,260.8 Set Depth (TVD) (… 3,721.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.3 26.3 0.00 HANGER FMC TUBING HANGER 3.500 526.7 526.6 1.12 NIPPLE CAMCO DS LANDING NIPPLE 2.875 5,203.6 3,688.2 54.84 SLEEVE-C BAKER CMU SLIDING SLEEVE (CLOSED 7/3/2004) 2.813 5,219.7 3,697.4 54.77 NIPPLE CAMCO D NIPPLE 2.750 5,258.1 3,719.6 54.62 LOCATOR LOCATOR SPACER 2.950 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,472.0 3,846.7 53.93 IMPINGEMENT TUBING APPEARS TO HAVE BUCKLING THAT RESTRICTS FULL OD LONG ASSEMBLIES. 7/24/2020 2.991 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,120.0 8,135.0 5,200.1 5,207.6 S5, 2N-345A 6/13/2004 6.0 IPERF 2.5" HSD, 2506 HJ, HDX charges, 60 deg phase 8,265.0 8,295.0 5,272.4 5,287.2 S5, 2N-345A 7/25/2020 6.0 APERF 2" HSC, 6 SPF, 60S PHASE, Maxforce charges Frac Summary Start Date 6/30/2004 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 6/30/2004 Top Depth (ftKB) 8,120.0 Btm (ftKB) 8,135.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,439.9 2,122.7 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 5/18/2004 2 4,298.1 3,173.9 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 5/18/2004 3 5,154.6 3,660.1 CAMCO KBG-2- 9 1 GAS LIFT OV BTM 0.313 0.0 7/8/2020 Notes: General & Safety End Date Annotation 5/18/2004 NOTE: SIDETRACKED WELL 2N-345A, 7/26/2020 7:21:27 AM Vertical schematic (actual) LINER; 5,252.5-8,556.0 APERF; 8,265.0-8,295.0 FRAC; 8,120.0 IPERF; 8,120.0-8,135.0 IMPINGEMENT; 5,472.0 PRODUCTION Post S/T; 27.5-5,450.0 WINDOW A; 5,428.0-5,440.0 LOCATOR; 5,258.1 NIPPLE; 5,219.7 SLEEVE-C; 5,203.6 GAS LIFT; 5,154.6 GAS LIFT; 4,298.1 SURFACE; 29.3-2,789.2 GAS LIFT; 2,439.9 NIPPLE; 526.7 CONDUCTOR; 29.3-109.0 HANGER; 26.3 KUP PROD KB-Grd (ft) 36.60 Rig Release Date 7/19/1998 2N-345A ... TD Act Btm (ftKB) 8,557.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032026401 Wellbore Status PROD Max Angle & MD Incl (°) 64.61 MD (ftKB) 5,664.47 WELLNAME WELLBORE2N-345A Annotation Last WO: End Date 5/22/2004 H2S (ppm) 40 Date 11/23/2015 Comment SSSV: NIPPLE w�\ v , s THE STATE of 7'j �� \�� / /�, Alaska 011 Gas (ALASKA -+) ® Conservation Commission �,, GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Q. Anchorage, Alaska 99501 -3572 ALAS"' Main: 907.279.1433 Fax: 907.276.7542 Martin Walters SCANNED JUN 2013 Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, 2N -345A Sundry Number: 313 -314 Dear Mr. Walters: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. F erster Chair DATED this 4 day of June, 2013. Encl. STATE OF ALASKA , ' a ,, ' 1 °'. ; .� • • A OIL AND GAS CONSERVATION COM SION C� 2 f S I � �� 1. ,> 26 APPLICATION FOR SUND RY APPROVALS „.„1 20 AAC 25.280 ` II '" t 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Change Approv dd Rrogram r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other: Conductor Extension ■ I✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J • Exploratory r 204 -034 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20264 -01 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r 2N - 345A • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0375074 . Kuparuk River Field / Tarn Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 8557 •5414 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 109' 109' 1640 630 SURFACE 2760 7 -5/8 2789' 2309' 6890 4790 PRODUCTION 5423 5 -1/2 5450' 3833' 7000 4990 LINER 3304 3 -1/2 8556' 5413' 10160 10540 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8120 -8135 • 5199 -5206 3.5 L -80 5261 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) BAKER HR ZXP LINER TOP PACKER • MD = 5270 TVD = 3727 CAMCO DS LANDING NIPPLE • MD = 527 TVD = 527 12. Attachments: Description Summary of Proposal •• r 13. Well Class after proposed work: Detailed Operations Program BOP Sketch r Exploratory r Stratigraphic r Development 17. Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/1/2013 Oil r • Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Martin Walters / MJ Loveland Email: N 1878 cr cop.com Printed Name Martin Walters Title: Well Integrity Projects Supervisor Signature /��!/'i (te Phone: 659 -7043 Date: 06/16/13 Commission Use Only Sundry Number: 3 :3) / Conditions of approval: Notify Commission so that a representative may witness ✓✓ Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r JUN 2 6 RBDMS c6 I,) Other: Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /Q _ d O �/ APPROVED BY 7 Approved by: � ONER THE, COMMISSION Date: �/ pi d 8 II�dL� vii IS Vdl�cJ Iii 1� iif fivlii the a cll d}�1itivaI. N AN Form 10 -403 (Rev ed 10/2012) °Rum' A Su bmit Form and Attachments in Duplicate I ) \ \' YF b/Z / /'3 � � ,.i.., • • +, z ConocoPhillips Alaska `' t c„ P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 16, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2N -345A, PTD 204 -034 conductor extension. Please contact Martin Walters or MJ Loveland at 659 -7043 if you have any questions. Sincerely, fit /1 Martin Walters ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 ConocoPhillips Alaska, Inc. Kuparuk Well 2N -345A (PTD 204 -034) SUNDRY NOTICE 10 -403 APPROVAL REQUEST June 16, 2013 This application for Sundry approval for Kuparuk well 2N -345A is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to SC. At some point during normal operations the conductor subsided about 15 ". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10 -404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor KU P 2N -345A ConocoPhilli • • • .r�► Well Attributes Max Angle & MD TO I , Wellbore APIIUWI Field Name Well Status Inc! C) MD (MB) Act Btm (ftKB) ca+omRUlkps 501032026401 TARN PARTICIPATING AREA PROD 64.61 5,664.47 8,557.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date ••• Well ConfiP.:•2N 3454. 12/6(201280543 AM SSSV: NIPPLE 40 10/17/2011 Last WO: 5/22/2004 36.60 7/19/1998 Schematic - Actual : Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,132.0 12/2/2012 Rev Reason GLV C10, TAG ninam 12/6/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVO) String Wt... String String Top Thrd ....1 , �. CONDUCTOR 16 15.062 29.3 109.0 109.0 I 62.50 ((40 WELDED HANGER, 26 Casing Description Strip 0... Strip ID ... Top (ftKB) Set De f Set Depth (TVD) Strip Wt... Strip String Top Thrd a >:.. 9 P 9 9 P( 1 Depth P( -- Pt ITV ) •- 9 9- 9 P ' ; SURFACE 7 5/8 6.875 29.3 2,789.2 2,309.0 29.70 L - 80 BTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.950 27.5 5,450.0 3,832.6 15.50 L -80 MOD W ., , Casin Post- Descrip tion String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd i l l WINDOW 51/2 4.500 5,428.0 5,440.0 3,826.4 15.50 L - 80 Casing Description String 0... String ID ... Top MKS) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd LINER 3 1/2 2.992 5,252.5 8,556.0 5,413.5 9.30 L -80 HYDRIL 511 CONDUCTOR, +� `qh" "`� 29-109 Liner Details Top Depth NIPPLE, 527 (ND) Top Inc! N009... Top (ftKB) (ftKB) ( Item Description Comment ID (in) 5,252.5 3,716.5 54.74 SBE BAKER SEAL BORE TIE BACK EXTENSION 4.125 5,269.8 3,726.5 54.64 PACKER BAKER HR ZXP LINER TOP PACKER 3.410 5,278.2 3,731.3 54.59 PBR BAKER POLISHED BORE NIPPLE 3.250 5,282.7 3,733.9 54.56 HANGER BAKER HMC LINER HANGER 2.920 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING X 1/2 2.992 26.3 5,260.8 3,721.3 9.30 L -80 EUE8RDMOD Completion Details GAS LIFT, Top Depth 2,440] ITVOI Top Inc' Nomi... i Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 26.3 26.3 -0.39 HANGER FMC TUBING HANGER 3.500 526.7 526.5 0.19 NIPPLE CAMCO DS LANDING NIPPLE 2.875 5,203.7 3,688.2 54.84 SLEEVE -C BAKER CMU SLIDING SLEEVE (CLOSED 7/3/2004) 2.813 5,219.7 3,697.8 54.94 NIPPLE CAMCO D NIPPLE 2.750 5,258.1 3,719.7 54.71 LOCATOR LOCATOR SPACER 2.950 Casing 9 N l Z Perforations & Slots SU I Shot 29 -2.789 Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eh.- Type Comment 8,120 8,135 5,199.2 5,206.8 S5, 2N -345A 6/13/2004 6.0 IPERF 2.5" HSD, 2506 HJ, HDX charges, 60 swir ', deg phase GAS LIFT t,, ... a;'LC. •o- 4 298 Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 8,120.0 8,135.0 5,199.2 5,206.8 FRAC 6/30/2004 67,1848 16/20 PROPPANT w/6.3 ppa ON PERFS & f 49,952# BEHIND PIPE GAS LIFT, Notes: General: & Safety .... 5.155 ,1 End Date Annotation 5/18/2004 NOTE: SIDETRACKED WELL 11/24/2010 NOTE: View Schematic w/ Alaska Schematic9.0 I SLEEVE -C. 5,204 I i NIPPLE, 5,220 !,,.. LOCATOR, 5,258 !l !I WINDOW, 5.4440 PRODUCTION Mandrel Details Post- Worko45 Top Depth Top Port 27-5,450 (ND) Incl OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) P) Make Model (in) Sery Type Type (in) (psi) Run Date Com... IPERF, 1 2,439.9 2,122.6 56.71 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 5/18/2004 8,120 - 8,135 2 4,298.1 3,174.5 56.46 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 5/182004 FRAC, 8,120 _ _ __.' 3 5,154.6 3,660.1 55.03 CAMCO KBG - 2 - 9 1 GAS LIFT OV BTM 0.313 0.0 12/3/2012 LINER, ,252-8,556 TD 5 (2N- 345A), N A 8,557 • ~ ~~. MICROFILMED 03!01 !2008 D4 NOT PLACE ~_ ,.. ~~ ~. - 4.,r ~;. _;~ ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertstMicrofitm Marker.doc . . ConoccrPhillips Alaska Re.ee.\VED SEP 1 2 2007 . sion A'aska on & Gas Cons. carom!S Anchorage P.o. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 07, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 . . 2, 7..0fJ7 Anchorage, AK 99501 SGAN~ED SE? 1 -0:34' a~~J 3L\-b Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of fonn 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped on September 5,2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, \~'- ~ ~end ConocoPhillips W ell Integrity Field Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 91712007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name PTD# cement pumced cement date inhibitor sealant date ft bbls ft Qal 2N-320 199-001 4" nla 4" nla 2 9/5/2007 2N-321 198-173 6" nla 6" nla 2 9/5/2007 2N-323 198-071 1" nla 1" nla 1 9/5/2007 2N-325 198-163 10" nla 10" nla 2 9/5/2007 2N-326 200-155 9" nla 9" nla 3.5 9/5/2007 2N-337 206-163 6" nla 6" nla 1 9/5/2007 2N-339 198-100 8" nla 8" nla 2.5 9/5/2007 2N-341 198-103 3" nla 3" nla 1 9/5/2007 2N-342 207-068 18" nla 18" nla 4.5 9/5/2007 2N-343 198-092 4" nla 4" nla 2 9/5/2007 2N-345 204-034 9" nla 9" nla 3.5 9/5/2007 ) ?, JIIlC1'1 DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Permit to Drill 2040340 Well Name/No. KUPARUK RIV U TARN 2N-345A Operator CONOCOPHILLlPS ALASKA INC APll~03-~~2~1-~ Y MD 8557 /' TVD 5414 /' Completion Date 6/13/2004 --- Completion Status 1-01l Current Status 1-01l UIC N REQUIRED INFOR!JIATION Directional su~ Mud log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GR, Res (data taken from logs Portion of Master Well Data Maint Well Log Information: . Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Rpt Directional Survey 5450 8557 7/15/2004 ~..."l\~ ~ I ndl:lwtiuIIIRto",;!tivity 25 Blu "I- . 5750 8~~7 °rp.n 7/15/200d 00g Induction/Resistivity 25 Blu 4 5750 8557 Open 7/15/2004 DSN 12571, GR Rpt LIS Verification 25 4 7/15/2004 ~ Induction/Resistivity 25 Blu 4 5750 8557 Open 7/15/2004 DSN 12571, GR C Lis 12571 Induction/Resistivity 0 0 7/15/2004 MPR, LIS, TIF, GRAPHICS J.e9' G'i!11ma Fté:!Y c.-..i ~ Blu 5250 8372 Case 7/1/2004 SLIM CEMENT MAP TOOUGAMMA RAy/eel Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments . ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Daily History Received? 1}N ~N Formation Tops Analysis Received? ~ Comments: Compliance Reviewed By: ~ Date: 2-7 ~ vv-.' a. ~ <.ø e Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Dealion Reference: 2N-345A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blue line - MPR TVD Log LAC Job#: 637896 ./ Sent By: Glen'Ílorel I,} /'--~h",,~,i',. !i Received Ry:.'.-é/U:c ~-i I /' I f t í / . ¡;U¿Uúflt L . ~ atJ'.., 03 t 12 ,,- 7/ /J / '&ill BAKER HUGHES Anchorage GEOScience Center Date: July 1,,4, 2004 -~ 1.-; ) 10 ú Date: 11"-'-/ I T PLEASE ACKNOWLJIDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 iII'LI!M;-jOO--J)OtI!:I.rITStl¡¡; - -- - -;';;;;'-';-~~~:::--";. ~'" w" : --... .... ....... .., .-:.;. Co ~.. -. or !!"-':-:.: ..,.."... . . ~c">,"' ~ ...... , -'" -- ... ... -).' ," >." ',. ~"" , .;,_;..:....'C».',_ , -- -"7---~ ,~:.-! e Conoc~hillips e Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 July 14, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2N-345A (APD # 204-034) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Kuparuk well 2N-345A. If you have any questions regarding this matter, please contact me at 265-6830 or Philip Hayden at 265-6481. Sincerely, ~ - \~~- R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /skad D04 OR\G\NAL e STATE OF ALASKA __ ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U GINJ D 2. Operator Name: WINJ D WDSPL D Plugged D Abandoned D 20AAC 25.105 No. of Completions _ ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 144' FNL, 1113' FEL, Sec. 3, T9N, R7E, UM At Top Productive Horizon: 237' FNL, 1233' FEL, Sec. 4, T9N, R7E, UM Total Depth: 120' FNL, 1794' FEL, Sec. 4, T9N, R7E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 460479 -' y- TPI: x- 455080 y- Total Depth: x- 454520 y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GR, Res 22. CASING SIZE WT. PER FT. 62.5# 29.7# 15.5# 9.2# GRADE H-40 L-80 L-80 L-80 16" 7.625" 5.5" 3.5" 5911866 5911803 5911923 , Zone- 4 Zone-4 Zone- 4 1b. Well Class: Development 0 Exploratory D Service D Stratigraphic Test D . ' !f ~þ 12. Permit to Drill Number: J J..1t¿ 1.7 .. .~ 20641.llif.'4...204-034 13. API Number: Suspended D 20AAC 25.110 Other WAGD 5. Date Comp., Susp., or Aband.: 6. Date Spudded: May 7,2004 7. Date TD Reached: May 14. 2004 8. KB Elevation (It): 30' RKB /151' AMSL 9. Plug Back Depth (MD + TVD): 8395' MD / 5335' TVD 10. Total Depth (MD + TVD): 8557' MD /5414' TVD 11. Depth where SSSV set: Landing Nipple @ 527' 19. Water Depth, if Offshore: N/A CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 28' 108' 28' 108' 28' 2791' 28' 2307' 28' 5428' 28' 3818' 5252' 8556' 3715' 5414' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 8120'-8135' MD 5199' - 5207' TVD 6spf 26. Date First Production July 5, 2004 Date of Test Hours Tested 7/8/2004 Flow Tubing press. 299 psi 27. 12.5 hours Casing Pressure 944 Test Period --> Calculated 24-Hour Rate -> 24. SIZE 3.5" 50-103-20264-01 14. Well Name and Number: 2N-345A 15. Field/Pool(s): Kuparuk River Field Tarn Oil Pool 16. Property Designation: ADL 375074 17. Land Use Permit: L 31961 20. Thickness of Permafrost: feet MSL 1050' MD HOLE AMOUNT CEMENTING RECORD SIZE PULLED 24" 9 cu yds High Early 9.875" 40 sx ASIIILW, 240 sx Class G 6.75" 42 bbls Class G 4.75" 115 sx GasBlok TUBING RECORD DEPTH SET (MD) PACKER SET 5261' 5270' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 8120'-8135' MD 67184# of 16/20 proppant r-¿~ii::;,t fñ:1Nt !t' DAn: ~ ,,-./J.b. .,V~,Er¡ ·IED· \ ~ , ",._ ".1 CONTINUED ON REVERSE OR\G\NAL CHOKE SIZE IGAS.OIL RATIO 883 PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc.) Flowing Production for OIL-BBL GAS-MCF 2295 1509 OIL-BBL GAS-MCF 3757 3317 CORE DATA 25. WATER·BBL 34 WATER-BBL 65 100% OIL GRAVITY - API (corr) not available Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Form 10-407 Revised 12/2003 NONE RBDMS 9Ft JUL 1 9 1004 ~fC:, 28. e 29. e GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 2N-345A T3 7900' 5091' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Philip Hayden @ 265-6481 Printed Na~v Thomas Title: Signature '\ ,\. ~e Kuparuk DrillinQ Team Leader '"¿G..> 6'8 3>ò Date 7 (f :J(lo '( Prepared by Sharon Allsup-Drake 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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 f"'\f)I("1 1: f' ,_"...' ~:: :i 1\ I Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-345 2N-345 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 5/3/2004 Rig Release: 5/19/2004 Rig Number: Spud Date: 7/7/1998 End: Group: 5/3/2004 07:30 - 09:00 1.50 MOVE DMOB DEMOB 09:00 - 00:00 15.00 MOVE MOVE DEMOB 5/4/2004 00:00 - 07:30 7.50 MOVE MOVE MOVE 07:30 - 10:30 3.00 MOVE RURD MOVE 10:30 - 12:00 1.50 WELCTL NUND DECOMP 12:00 - 13:00 1.00 WELCTL NUND DECOMP 13:00 - 14:30 1.50 WELCTL OTHR DECOMP 14:30 - 16:00 1.50 WELCTL CIRC DECOMP 16:00 - 17:00 1.00 WELCTL NUND DECOMP 17:00 - 17:30 0.50 WELCTL NUND DECOMP 17:30 - 20:00 2.50 WELCTL NUND DECOMP 20:00 - 00:00 4.00 WELCTL NUND DECOMP 5/5/2004 00:00 - 01 :00 1.00 WELCTL NUND DECOMP 01 :00 - 03:30 2.50 WELCTL OTHR DECOMP 03:30 - 08:30 5.00 WELCTL BOPE DECOMP 08:30 - 10:00 1.50 RIGMNT RSRV DECOMP 10:00 - 10:30 0.50 WELCTL NUND DECOMP 10:30 - 12:00 1.50 ABANDI\ WLHD DECOMP 12:00 - 13:00 1.00 ABANDI\ CIRC DECOMP 13:00 - 13:30 0.50 ABANDI\ RTRV DECOMP 13:30 - 14:30 1.00 ABANDI\ OTHR DECOMP 14:30 - 15:00 0.50 ABANDI\ OTHR DECOMP 15:00 - 20:30 5.50 ABANDI\ RTRV DECOMP 20:30 - 00:00 3.50 WELCTL NUND DECOMP 5/6/2004 00:00 - 01:15 1.25 WELCTL NUND ABANDN 01:15 - 01:30 0.25 LOG SFTY ABANDN 01:30 - 03:15 1.75 LOG ELOG ABANDN 03:15 - 06:00 2.75 LOG ELOG ABANDN 06:00 - 06:30 0.50 RIGMNT RSRV ABANDN 06:30 - 08:15 1.75 WELCTL EORP ABANDN 08: 15 - 09:00 0.75 WELCTL BOPE ABANDN 09:00 - 11 :30 2.50 DRILL PULD PROD 11 :30 - 12:00 0.50 DRILL OTHR PROD 12:00 - 16:30 4.50 DRILL PULD PROD 16:30 - 17:30 1.00 DRILL CIRC PROD 17:30 - 18:30 1.00 DRILL DEOT PROD Move rig off well 2T -218 and move to end of pad. Perform welding operations in cellar. Clean well site. Move off pad @ 09:00 hrs 5/3/2004 Move rig from 2T pad to 2N pad. Stop @ 23:00 hrs and check lug bolts. Wait at 2 mile turnoff from 17:30 hrs to 18:30 hrs for crew change. Check lug bolts @ 00:45 hours. Continue moving to 2N. Stop every mile tro check lug nuts. Pull onto pad @ 04:45. Pull over well @ 06:00 and line up. Spot sub Rig up tarps and handi-berm. Hang riser. Run comm line from camp to rig. Spot cuttings tank. Accept rig @ 10:30 hrs 5/4/2004. Pull VR plugs. N/U flanges on annulus valves RlU lubricator and pull BPV RlU to displace freeze protect from well. Take on water for rig pits Displace freeze protect from well Blow down and rig down circulating equipment. Pull tree cap Install two-way check N/D tree and adapter flange. Remove tree from cellar for shipping Remove adapter spool from BOPE. N/U BOPE and riser Finish N/U riser Change saver sub to 2-7/8" AOH. Remove grabber and install cylinder shim Body test BOPE and test all BOPE to 250/5000 psi-annular 250/3500 ps. Jeff Jones, AOGCC, waived witnessing BOP test. Cut and slip drilling line Pull two-way check M/U landing joint and screw into hanger. Pull hanger. Pulled tight 20' up. Pump 35 bbl water and displace well w/ mud UD landing jt. and tubing hanger RlU floor to stand back 3-1/2" tubing and service rig Put rig on highline power @ 15:00 hrs 5/5/2004 POOH w/3-1/2" production tubing and stand back in derrick. Recovered hanger w/ pup (3.40'), 191 jts of tubing (5959.14'), 1 cut jt. (14.36'), "Do nipple (1.58'). RKB to LLDS=26.30' Top of fish @ 6004.78' RlU and bleed off 9-5/8" x 5-1/2" annulus. Change out 5-1/2" packoff Finish changing 5-1/2" packoff. Test to 5000 psi-OK. Set wear ring RlU e-line and hold safety meeting. RIH w/4.812" gauge ring and junk basket to 5950' POOH MIU Baker K-1 CIBP and RIH. Set @ 5458' wlm. POOH and RID e-line Set make-up torque on top drive to 5700 ft-Ibs. Set drilling torque limit @ 5200 ft-Ibs Pull wear ring. Change bottom PR's to 2-7/8" and install test plug Test door seals to 3500 psi and pull test plug. Set wear ring M/U BHA #1: mills DC's, xo's and HWDP Change handling tools to 2-7/8" d.p. P/U 2-7/8" d.p and RIH. Tag @ 5451' dpm Circ and condition mud. P/U= 73k, s/o= 50k,Rot=53k, Torque= 4200 ft-Ibs, 4 bpm @ 2200 psi RlU and test casing to 3500 psi for 30 minutes. Pressure to 3240 psi in 30 minutes. Test bottom PR's to 250/3500 psi w/ casing test Printed: 5/26/2004 3:58:39 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-345 2N-345 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 5/3/2004 Rig Release: 5/19/2004 Rig Number: Spud Date: 7f1/1998 End: Group: 5/6/2004 18:30 - 19:30 19:30 - 00:00 00:00 - 01 :00 01:00 - 02:15 02:15 - 04:15 04:15 - 04:45 04:45 - 09:00 09:00 - 09:45 09:45 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 15:00 15:00 - 15:45 5nt2004 5/8/2004 15:45 - 19:15 19:15 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 01 :30 01 :30 - 03:45 03:45 - 04:30 04:30 - 06:30 06:30 - 07:00 07:00 - 07:30 07:30 - 13:00 5/9/2004 13:00 - 13:15 13:15 - 13:30 13:30 - 14:00 14:00 - 14:30 14:30 - 16:30 16:30 - 17:30 17:30 - 18:00 18:00 - 20:45 20:45 - 22:15 22:15 - 00:00 00:00 - 03:00 03:00 - 05:00 05:00 - 06:30 06:30 - 08:00 08:00 - 10:00 10:00 - 10:30 10:30 - 12:00 12:00 - 13:00 13:00 - 13:15 13:15 -15:30 15:30 - 16:30 16:30 - 17:00 17:00 - 00:00 1.00 WELCTL BOPE 4.50 DRILL TRIP 1.00 DRILL TRIP 1.25 DRILL PULD 2.00 WINDOWPULD 0.50 WINDOWOTHR 4.25 WINDOWTRIP 0.75 WINDOWSETW 2.25 WINDOWSTWP 1.00 WINDOWSTWP 1.00 WINDOWOTHR 1.00 WINDOWSTWP 0.75 DRILL LOT 3.50 WINDOWTRIP 2.75 WINDOWPULD 1.00 WINDOWOTHR 1.00 WINDOWPULD 1.50 DRILL PULD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD 2.25 DRILL PULD PROD 0.75 DRILL 2.00 DRILL 0.50 DRILL 0.50 DRILL 5.50 DRILL PULD PULD TRIP DEQT PULD 0.25 DRILL TRIP 0.25 DRILL CIRC 0.50 DRILL TRIP 0.50 DRILL OTHR 2.00 DRILL REAM 1.00 DRILL DRLG 0.50 DRILL OTHR 2.75 DRILL DRLG 1.50 DRILL OTHR 1.75 DRILL TRIP 3.00 DRILL TRIP 2.00 DRILL PULD 1.50 DRILL PULD 1.50 DRILL PULD 2.00 DRILL OTHR 0.50 RIGMNT RSRV 1.50 DRILL PULD 1.00 DRILL 0.25 DRILL 2.25 DRILL 1.00 DRILL 0.50 DRILL 7.00 DRILL PULD OTHR TRIP REAM REAM DRLG PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD Test upper PR's to 250/3500 psi Blow down top drive and POOH Finish POOH w/ BHA Break out sub and lifters for MWD tools. M/U whipstock and orient. RIH w/ BHA Test MWD @ 40, 50, and 60 spm-OK RIH w/2-7/8" d.p. out of derrick Orient whipstock and set. Mill window from 5428' to 5445' Drill formation while opening window from 5445' to 5460' Hole packed off. Work pipe Ream through window and pump sweep Perform LOT to 1130 psi @ 3833' TVD w/1 0.1 ppg mud. 15.7 ppg EMW Pump pill. Blow down topdrive and POOH POOH w/ BHA, UD drill collars, mwd and mills M/U stack washer and wash BOP stack Ship out all Baker tools and milling equipment M/U drilling BHA,including motor and MWD. Shallow test MWD-no signal. UD MWD and repair-bad memory module. Upload MWD and pick back up. Shallow test MWD-OK. Continue making up BHA M/U bit and orient motor RIH w/ HWDP Shallow test MWD-OK RIH pickup singles out of pipeshed from 731' to 4416'. Fill pipe and circulate every 1000' RIH w/ stands from 4416' to 4870' Hit tite spot Wash through tite spot from 4870' to 4886' RIH from 4885' to 5359' Orient motor and slide through window from 5339' to 5440' Wash and ream and clean up hole from 5440' to 5460' Drill from 5460' to 5478' GR in MWD quit Reboot MWD computer in attempt to get GR to work-no joy Drill from 5478' to 5535' P/U= 65k, S/0=45k, Rot=55k Lower boot failure in riser. POOH wet and monitor well 1 0 stands out. Continue POOH POOH wI 2-7/8" d.p. UD jars and bumper sub. R/U tongs to handle 3-1/2" MWD tools UD flex collars. Download MWD. Drain motor. UD MWD and attempt to UD LWD-probe would not come out of collar Work on MWD tools Service rig Orient motor and P/U monels. Top monel would not make up. UD same Continue to p/u BHA Shallow test MWD-OK. Blowdown top drive RIH w/2-7/8" d.p. to 5400', fill pipe @ 3100' Orient motor and work through window Wash and ream from 5455' to 5535' Drill from 5535' to 5813'. ADT=5.2, AST=2.6, ART=2.6, P/U=68k, S/0=45k, Rot=54, Rotary=0-85, WOB=2-4, Pump=2400 @ 78 spm Printed: 5/26/2004 3:58:39 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-345 2N-345 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 5/3/2004 Rig Release: 5/19/2004 Rig Number: Spud Date: 7f7/1998 End: Group: 5/9/2004 17:00 - 00:00 7.00 DRILL DRLG PROD 5/10/2004 00:00 - 03:30 3.50 DRILL DRLG PROD 03:30 - 04:30 1.00 RIGMNT RGRP PROD 04:30 - 12:00 7.50 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 5/11/2004 00:00 - 05:30 5.50 DRILL DRLG PROD 05:30 - 06:30 1.00 RIGMNT RSRV PROD 06:30 - 12:00 5.50 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 5/12/2004 00:00 - 04:15 4.25 DRILL DRLG PROD 04:15 - 05:45 1.50 DRILL CIRC PROD 05:45 - 11 :45 6.00 DRILL REAM PROD 11 :45 - 12:00 0.25 DRILL CIRC PROD 12:00 - 12:15 0.25 DRILL OTHR PROD 12:15 - 12:30 0.25 DRILL TRIP PROD 12:30 - 13:15 0.75 DRILL CIRC PROD 13:15 - 16:15 3.00 DRILL TRIP PROD 16:15 - 18:45 2.50 DRILL TRIP PROD 18:45 - 20:00 1.25 WELCTL OTHR PROD 20:00 - 22:00 2.00 WELCTL OTHR PROD 22:00 - 00:00 2.00 WELCTL BOPE PROD 5/13/2004 00:00 - 03:00 3.00 WELCTL BOPE PROD 03:00 - 04:00 04:00 - 06:00 06:00 - 06:30 06:30 - 08:45 08:45 - 09:00 09:00 - 09:30 1.00 RIGMNT RSRV PROD 2.00 DRILL PULD PROD 0.50 DRILL OTHR PROD 2.25 DRILL PULD PROD 0.25 DRILL OTHR PROD 0.50 RIGMNT RSRV PROD (141 gpm). TVD=4008 Drill from 5813' to 5951' Replace wash pipe and packing in swivel Drill from 5951' to 6308' TVD= 4264', ART =6.0, AST =2.2, ADT =8.2 Drill from 6308' to 6826'. TVD=4540'. P/U=63k, S/0=58k, Rot=55k, Torque= 3230 ft-Ibs off/3600 ft-Ibs on. ART=7.1, AST=2.6, ADT=9.7 Rotary=85 rpm, WOB=1-3k, Pump = 2900 @ 78 spm (155 gpm) Directional drill 4 3/4" hole f/6826' to 7037' (TVD= 4657'). ART 2.9 hrs, AST = 1.2 hrs Replace grabber dies/ Service rig. Directional drill 4 3/4" hole f/7037' to 7158' (TVD= 4719'). ART 1.5 hrs, AST = 2.1 hrs. PU wt 75k, SO wt 48k, Rot wt 60k, torque 3600 ftIlb off bttm, 4000 ftlJb off bttm, WOB 1-3k, rpm 86, mtr rpm 345. Directional drill 4 3/4" hole f/7158' to 7605' (TVD= 4942'). ART 7.6 hrs, AST = 1.0 hrs. PU wt 85k, SO wt 50k, Rot wt 60k, torque 3625 ftlJb off bttm, 4040 ftlJb on bttm, WOB 1-3k" rpm 86, mtr rpm 345. Directional drill 4 3/4" hole f/7605' to 7750' (TVD= 5021 '). ART 2.6 hrs, AST = 1.2 hrs. PU wt 85k, SO wt 50k, Rot wt 60k, torque 3625 ftlJb off bttm, 4040 ftlJb on bttm, WOB 1-3k" rpm 86, mtr rpm 345. Pump hi vis 12.8ppg sweep while reciprocate pipe. Stand back a stand and continue backream and circ. sweep out. Approx 20% increase in cuttings. Monitor well OK. POOH, Backream out w/150 gpm and 85 rpm. Pull through window, noticed 10k overpull. OK. Monitor well. RIH f/5341' to 5445'. Pass back through window, no problem. Circ BU. POOH on elevators w/2 7/8" DP. Work BHA. Stand back 2 7/8" SWDP. UD MDC, jars, Pull and UD MWD probe. Wash out BOP stack w/ wash tool. Pull FMC wear bushing. Set FMC test plug, test plug leaking. Pull test plug. Use FMC combination test plug/running tool. Locating crossover subs to be able to screw into test plug and to be able to test, especially lower pipe rams +/- l' f/ test plug. Checking on HOWCO RTTS w/ storm valve. Checking f/ different 2 7/8" test joint f/ warehouse w/1 0" donut on bottom. Test BOPE. Test upper pipe rams (27/8" x 5" variables, blinds, inside and outside kill and choke valves to 250 psi low and 5000 psi high. Test annular to 250 psi low and 3500 psi high. Tested choke manifold while POOH to 250 psi low and 5000 psi high. Tested and calibrated alarm set points on H2S and methane gas alarms While POOH. Witness of BOP test waived by AOGCC inspector Chuck Scheve. Continue testing BOPE. Witness of BOP test waived by AOGCC inspector Chuck Scheve. Test lower pipe rams, upper and lower top drive valves, floor safety valve, and floor dart valve to 250 psi low & 5000 psi high. Test accumulator. Change out TD 2 7/8" AOH saver sub. PU/MU BHA# 5. Upload MWD tools. Orient MWD, MU bit, PU 2 NMDC's, jars, RIH w/2 7/8" SWDP. Shallow test MWD. OK Service TD and blocks. Printed: 5/26/2004 3:58:39 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-345 2N-345 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 5/3/2004 Rig Release: 5/19/2004 Rig Number: Spud Date: 7/7/1998 End: Group: 5/13/2004 09:30 - 12:00 2.50 DRILL TRIP PROD RIH w/2 7/8" DP f/730' to 5358' (TOW @ 5428'). Fill pipe @ 3070' . 12:00 - 12:45 0.75 DRILL CIRC PROD Fill pipe. Orient and slide through window f/5358' to 5445'. 12:45 - 14:00 1.25 DRILL TRIP PROD RIH w/2 7/8· DP f/5445' to 7515'. 14:00 - 14:45 0.75 DRILL CIRC PROD Fill pipe, break eire, monitor well. No loss, no gain. 14:45 - 17:30 2.75 DRILL REAM PROD MAD pass logging f/7529' to 7750' (221 '). rotating @ 60 rpm,circ @ 130 gpm, 2460 psi, ROP 150 ftlhr Max gas 285 units 17:30 - 18:15 0.75 DRILL CIRC PROD Pump Hi vis weighted sweep. 18:15 - 00:00 5.75 DRILL DRLG PROD Directional drill 4 3/4· hole f/7750' to 7960' (TVD= 5118'). ART 3.9 hrs, AST = 0.0 hrs. PU wt 90k, SO wt 53k, Rot wt 63k, torque 4100 ftllb off bttm, 4500 ftllb on bttm, WOB 1-3k, rpm 85, mtr rpm 347. Pumping 153 gpm w/ 3500 psi. Background gas 30-40, drilled gas 193 units max. 5/14/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Directional drill 4 3/4· hole f/7960' to 8370' (TVD= 5323'). ART 8.5 hrs, AST = 1.2 hrs. PU wt 92k, SO wt 50k, Rot wt 65k, torque 4350 ftIIb off bttm, 4550 ftllb on bttm, WOB 1-4k, rpm 85, mtr rpm 347. Pumping 153 gpm w/ 3650 psi. Background gas 400-500 units, max gas 1092 units @ 8233'. 12:00 - 18:30 6.50 DRILL DRLG PROD Directional drill 4 3/4" hole f/8370' to 8557' (TVD= 5414'). ART 5.4 hrs, AST = 0.0 hrs. PU wt 92k, SO wt 50k, Rot wt 65k, torque 4350 ftIIb off bttm, 4550 ftIIb on bttm, WOB 1-4k, rpm 85, mtr rpm 347. Pumping 153 gpm w/3650 psi. Background gas 400-500 units, max gas 1092 units @ 8233'. 18:30 - 21 :30 3.00 DRILL CIRC PROD Pump up survey, SPR # 1 MP, pump 15 bbl hi-vis 12.3 ppg sweep, circ 3x BU while circ sweep out of hole. Pull a stand a hour while circ 3 BU. 21 :30 - 00:00 2.50 DRILL REAM PROD Continue Backreaming out of hole f/8190' to 7655'. 5/15/2004 00:00 - 00:15 0.25 DRILL OBSV PROD Monitor well @ 7655'. OK. 00:15-01:15 1.00 DRILL TRIP PROD RIH f/7655' to 8557'. No Fill. Hole OK. 01:15 - 02:15 1.00 DRILL CIRC PROD Pump 15 bbl highvis 12.3 ppg weighted sweep. Circ sweep w/ rotate and recip.. Max bottoms up gas 138 units. 02:15 - 05:00 2.75 DRILL REAM PROD Start Back reaming slow f/ 8474' to 7624' ,while circ 3 au after sweep. 153 gpm,3600 psi- 3000 psi, 85 rpm 05:00 - 06:15 1.25 DRILL CIRC PROD Circ hole clean (2 BU) w/ continue to move up hole(7624'-7434'), 153 gpm, 85 rpm. Sticky clay returns. 06: 15 - 06:30 0.25 DRILL OBSV PROD Monitor well. OK. 06:30 - 11 :30 5.00 DRILL REAM PROD Continue to backream f/7434' to 5445'. Tight spot @ 5877' 25k overpull, work through, go back through three times, ok. 77 spm 2500 psi, 85 rpm. Drop 1.96" rabitt w/11 0' wire @ 6397', monitor well, ok. 11 :30 - 11 :45 0.25 DRILL OTHR PROD Orient MWD, pull f/5445' through window to 5358'. 11 :45 - 12:00 0.25 DRILL OBSV PROD Monitor well. Static. 12:00 - 12:45 0.75 DRILL TRIP PROD Attempt to pull pipe using trip tank. Swabbing. monitor well. 12:45 - 15:15 2.50 DRILL TRIP PROD Pump out f/ 5390 to 4160' w/70 gpm w/ 800 psi, hole fill ok. 15:15 - 15:30 0.25 DRILL TRIP PROD Attempt to pull f/4160' to 4130' w/o pump. Swabbing. 15:30 - 16:15 0.75 DRILL TRIP PROD RIH f/4130' to 5358'. 16:15 - 16:30 0.25 DRILL OTHR PROD Orient MWD @ 5358'. Slide through window to 5452' 16:30 - 16:45 0.25 DRILL TRIP PROD RIH f/ 5452' to 5610 16:45 - 17:45 1.00 DRILL CIRC PROD Pump hi vis 12.3 ppg weighted sweep w/ Backream slow f/ 5610' to 5452' 17:45 - 18:15 0.50 DRILL TRIP PROD Pull through window to 5358', monitor well. 18:15 - 19:15 1.00 DRILL TRIP PROD POOH f/ 5358' to 4130' 19:15 - 21:15 2.00 DRILL TRIP PROD POOH f/ 4130' to 730' 21:15 - 22:45 1.50 DRILL OTHR PROD Remove busted up HT38 thread protector f/ mousehole. Printed: 5/26/2004 3:58:39 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-345 2N-345 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 5/3/2004 Rig Release: 5/19/2004 Rig Number: Spud Date: 717/1998 End: Group: 5/15/2004 22:45 - 00:00 1.25 DRILL PULD PROD UD 2 7/8" spiral hwdp, Drain mtr, break bit. 5/16/2004 00:00 - 01:15 1.25 DRILL PULD PROD UD BHA 01:15 - 01:45 0.50 DRILL OTHR PROD Download Baker MWD tools. 01:45 - 02:15 0.50 DRILL PULD PROD UD MWD and BHA. 02: 15 - 03:00 0.75 DRILL OTHR PROD Clean rig floor, clean out drip pan, drain stack, refill w/10.3 ppg mud. 03:00 - 03:15 0.25 LOG SFTY PROD PJSM wI Schlumberger WL for RU and running e line logs. 03:15 - 05:15 2.00 LOG ELOG PROD RU, MU tools. Start in hole @ 0415 hrs, tag up @ 5468'. 05:15 - 06:15 1.00 LOG ELOG PROD Work tool string to try and get past 5468'. No progress. 06:15 - 07:15 1.00 LOG ELOG PROD POOH w/ WL tools. RID Schlumberger. 07:15 - 07:45 0.50 RIGMNT RSRV PROD Service blocks and top drive. 07:45 - 12:00 4.25 DRILL OTHR PROD Clear BHA f/ pipe shed. Clean 3 1/2" Hydrillliner connections and thread protectors. RU to run liner. 12:00 - 12:30 0.50 CASE SFTY PROD PJSM on running 3 1/2" 9.2 ppf, L-80, Hydril 511 liner. 12:30 - 21 :15 8.75 CASE PULR PROD Run 3 1/2" 9.2 ppf, L-80, Hydril 511 liner. Apply centralizers over stop collars 3/2 joints, #1 thru # 33. Joint 34 thru 37 install 1/1 centralizers over stops in middle of joint. Note: While run in hole, after MU joint # 18 (1600 hrs), background gas 150-225 units. 21 :15 - 22:00 0.75 CASE CIRC PROD Circ liner @ 2635'.4 bpm 85 spm, 700 psi w/10.3 ppg MW. 22:00 - 22:30 0.50 CASE SFTY PROD PJSM w/ crew on running 3 1/2" liner. Continue circulating during meeting. Circ total of 3800 strokes. Max gas units @ BU 660 units. 22:30 - 00:00 1.50 CASE PULR PROD Continue running 3 1/2" 9.2 ppf, L-80, Hydril 511 liner. Jts #86-joint # 104. All of 31/2" hydril tubing in hole @ midnight. Depth 3264'. 5/17/2004 00:00 - 00:45 0.75 CASE OTHR PROD PU/MU Baker liner hanger and packer assembly. Fill w/ temblock. RIH 1 stand 2 7/8" DP. 00:45 - 01 :30 0.75 CASE CIRC PROD Circ casing liner volume @ 64 spm, 620 psi. 85 spm 900 psi. PU wt 57k, SO wt 30k. Max gas 575 units @ 1075 strokes. 01 :30 - 04:15 2.75 CASE RUNL PROD RIH f/ 3400' to 5388' w/3 1/2", 9.2 ppf, L-80, Hydril 511 liner on Weatherford 2 7/8" AOH DP. Fill each stand w/ fillup hose. Run 22 stands. 04:15 - 06:00 1.75 CASE CIRC PROD Circ liner above window @ 64 spm w/1 000 psi. Max gas units 872 @ 1540 strokes. 06:00 - 09:30 3.50 CASE RUNL PROD RIH f/5388' to 8538' w/3 1/2", 9.2 ppf, L-80, Hydril 511 liner on Weatherford 2 7/8" AOH DP. Fill each stand wI fillup hose. Run 22 stands. 09:30 - 10:30 1.00 CASE OTHR PROD MU/RU Baker cement head. Circ and tag bottom @ 8560'. PU wt 115k, SO wt 45K, Block wt 20k. 10:30 - 12:00 1.50 CEMENTCIRC PROD Circ starting with 1 bpm 10.4 ppg @ 750-830 psi. stage up to 1.6 bpm @ 1000 psi. Max gas units 1600 units @ 2400 strokes. 12:00 - 13:30 1.50 CEMENTCIRC PROD Continue circ and recip liner. Stage up to 2.5 bpm 10.4 ppg @ 1160 psi. Increase to 3 bpm w/1500 psi 13:30 - 13:45 0.25 CEMENT SFTY PROD PJSM prior to cementing liner. Continue to circ @ 3 bpm 10.4 ppg w/ 1500 psi. 13:45 - 14:45 1.00 CEMENTCIRC PROD Continue circ and recip liner. Pump 3 bpm 10.4 ppg w/1500 psi. Dowell Batch mix cement and prep for spacer CW 100 and MP @ 11.5 ppg. 14:45 - 15:30 0.75 CEMENT PUMP PROD Dowell pump, 5 bbl CW 100 @ 8.3 ppg(2bpm 970 psi), test lines to 4000 psi, pump 15 bbls CW 100 @ 8.3 ppg(2bpm 970 psi) followw/20 bbls mud push @ 11.5 ppg(2bpm 1040 psi), follow w/ 25 bbls Gasblok cement @ 15.8 ppg(2bpm 540 psi). Shut down, flush lines w/5 bbl water, drop wiper plug. PU wt 110, SO wt 45k 15:30 - 16:00 0.50 CEMENT DISP PROD Rig displace cement w/1 0.4 ppg mud @ 3 bpm (caught up w/ cement @ 6.84 bbls pumped), at 22.4 bbls displ1060 psi, at 33 bbls displ1260 psi, at 42.5 bbls displ1440 psi, slowed down to 2 bpm last 7 bbls, at Printed: 5/26/2004 3:58:39 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-345 2N-345 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 5/3/2004 Rig Release: 5/19/2004 Rig Number: Spud Date: 7/7/1998 End: Group: 0.50 CEMENTDISP PROD 50.5 bbls displ1030 psi. Bump plug @ calc strokes (1077), pressure up 500 psi over circ pressure. Bump plug wI 1550 psi. hold f/5 min. CIP @ 1550 hrs 5/17/2004. 1.00 CEMENT OTHR PROD Increase pressure to 3500 psi to set hanger and release running tool. Slack off all dp string weight to see that liner is set. OK. Bleed pressure to check floats. OK. Pressure up 500 psi. PU to clear dog sub above top of liner. PU wt 65k. Down weight 50k. Block weight 20k. Apply all of dp weight to string 4 times. PU and SO rotating, weight @ 55k down to top of packer wI to 25k weight. RU, test packer to 1000 psi. Hold pressure f/1 0 min. OK, lost 20 psi. Bleed off pressure. RID cement head. Mud out of balance flowing ("U" tubing fl annulus to dp). Monitor well. MU Top drive. circ wI 10.4 ppg mud @ 4 bpm, 2300 strokes (Surf-surf), monitor, dead. Displace well f/10.4 ppg mud to 8.6 ppg seawater. Recip pipe while circ @ 5 bpm wI 2300 psi to 5.66 bpm wI 2000 psi. Circ total of 200 bbls seawater. Blow down top drive. Monitor well. Flush surface lines. POOH wI liner running tool, UD 120 joints 2 7/8" Weatherford DP. RIH wI remaining 31 stands DP fl derrick. 15 stands in hole @ midnight. RIH wI remaining 31 stands Weatherford rental 2 7/8 DP fl derrick. 15 stands in hole @ midnight. POOH, UD 2 7/8" DP. UD 138 joints. Break and UD Baker liner running tool. Indication on shear pin that liner is set. RU floor to run 31/2" completion equipment. RIH slow w/15 stands of 31/2" 9..3# L-80 EUE tubing fl original well. POOH UD 45 joints of 3 1/2" tubing. Carefully pick up joints fl box. Pull FMC wear bushing. Slip and cut drilling line. Check brass on deadman. inspect brakes, tighten nuts on breakbands, grease brake linkage, grease crown and blocks, reset and check crown-o-matic. PJSM on PU 3 1/2" completion. PUlMU 3 1/2" completion seal assembly. Torque on rig tong guage does not appear correct. Match torque to known value (Baker machine MU torques to 2975 ftIlb.Using rig tongs known value collars move @ approx 1800-1900 ftIlb on rig guage. Torque connections wI rig tongs to 2000 ftIlb.) Change out seal rings in boxes, Drift all stands fl derrick to 2.867". Clean and inspect all threads. All tubing above 2.875" DS nipple is tubing fl KCS warehouse. All tubing above 2.875 "DS" nipple were drifted to 2.91" Liner top @ 5259' by tubing tally measurement. 1.25 CMPL TN CIRC CMPL TN Circ wI seal assembly 2' away fl tie back extension @ 4 bpm & 800 psi. Circ wI mule shoe @ 5257' tubing tally measurement. 2.00 CMPL TN SOHO CMPL TN Space out and land 3- 1/2" 9.3#/ft, L-80, EUE mod completion assembly. Land tubing @ 2222 hrs. FMC torque LDS to 450 ftIlb.165 joints in hole, no space out pups, pup under FMC hangerw/3 1/2" EUE top & bottom connection (not modified). PU wt 62K, SO wt 45k. RKB to upper LDS = 26.3' Tubing tail @ 5272'. 1.00 CMPL TN DEaT CMPL TN RU to test 31/2" tbg and 3 1/2" liner, with 5 1/2" x 31/2" annulus open. 5/17/2004 15:30 - 16:00 16:00 - 17:00 17:00 - 17:30 0.50 CEMENTOTHR PROD 17:30 - 18:00 0.50 CEMENT PULD PROD 18:00 - 18:30 0.50 CEMENTCIRC PROD 18:30 - 19:15 0.75 CASE CIRC PROD 19:15 - 20:00 0.75 DRILL OBSV PROD 20:00 - 23:30 3.50 DRILL TRIP PROD 23:30 - 00:00 0.50 DRILL TRIP PROD 5/18/2004 00:00 - 01 :00 1.00 DRILL TRIP PROD 01 :00 - 05:00 4.00 DRILL TRIP PROD 05:00 - 05:30 0.50 DRILL TRIP PROD 05:30 - 06:00 0.50 CMPL TN RURD CMPL TN 06:00 - 09:30 3.50 CMPL TN TRIP CMPL TN 09:30 - 10:00 0.50 CMPL TN OTHR CMPL TN 10:00 - 12:00 2.00 RIGMNT RSRV CMPL TN 12:00 - 12:30 0.50 CMPL TN SFTY CMPL TN 12:30 -19:15 6.75 CMPLTN RUNT CMPL TN 19:15 - 20:30 20:30 - 22:30 22:30 - 23:30 Printed: 5/26/2004 3:58:39 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-345 2N-345 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 5/3/2004 Rig Release: 5/19/2004 Rig Number: Spud Date: 717/1998 End: Group: 5118/2004 23:30 - 00:00 0.50 CMPL TN DEOT CMPL TN Test 31/2" tubing and 31/2" liner to 3500 psi f/30 min. Chart test. Good test, lost 50 psi. 5/19/2004 00:00 - 01:15 1.25 CMPL TN DEOT CMPL TN Test 5 1/2" x 3 1/2" annulus to 3500 psi f/30 min. Chart test. Lost 10 psi. Good test. 01:15 - 02:00 0.75 CMPLTN DEOT CMPL TN RId testing equipment. UD landing joint, set TWC. 02:00 - 05:00 3.00 CMPL TN NUND CMPL TN Change bottom pipe rams to 4", NID BOPE. 05:00 - 07:00 2.00 CMPL TN NUND CMPL TN NU WKM 3 1/8" 5K tree. 07:00 - 09:30 2.50 CMPL TN OTHR CMPL TN Pressure test hanger void to 5000 psi f/1 0 min, OK. RU to test tree test. Wing valve leaking. Valve shop came out and service valve. 09:30 - 10:15 0.75 CMPL TN OTHR CMPL TN Test WKM 3 1/8" 5000 tree to 250 psi low and 5000 psi high. RID test equipment. Chart test. 10:15 - 10:45 0.50 CMPL TN FRZP CMPL TN RU Little Red to pump 45 bbls diesel down 5 1/2" x 3 1/2" annulus, taking returns through tubing. 10:45 - 11 :30 0.75 CMPLTN FRZP CMPL TN Little Red pump 45 bbls diesel down 5 1/2' x 3 1/2' annulus @ 1.3 bpm wI 1400 psi. taking returns through tubing. 11 :30 - 12:30 1.00 CMPL TN FRZP CMPL TN Put tubing and tubing annulus in communication to swap fl annulus to tubing. 12:30 - 13:00 0.50 CMPL TN OTHR CMPL TN Blow down lines. RID hoses. 13:00 - 14:00 1.00 CMPL TN OTHR CMPL TN Set BPV. Secure well. Dress tree. RID Handi-berm. Rig released fl 2N-345A to move to 2N306. 450' move down well line. Printed: 5/26/2004 3:58:39 PM e 2N-345A Well Events Summary e Date Summary 05/22/04 DUMMY GUN DRIFT TO 8053' SLM. 1" SOV NOT IN GLM #3. SET 1" DGLV. PT TBG/CSG TO 2500 PSI. GOOD TEST. [Fish, GLV] 05/25/04 ATTEMPTED TO FISH SHEAR OUT VALVE. SAT DOWN AT 8055' SLM. ABLE TO BEAT DOWN TO 8070'. STILL MAKING HOLE BUT TOOLS GETTING HEAVY. POOH WITHOUT VALVE. 05/27104 PERFORMED A FCO DOWN TO 8385' CTD. INITIAL TAG @ 8213' CTD, ABLE TO WASH THROUGH. FREEZE PROTECTED WITH DIESEL.D [FCO] 05/30104 CORRELATED TO BAKER HUGHES MWD RESISTIVITY I GR LOG. RUN #1: HEAD I GR I CALIPER I SLDT I BOWSPRING (2.5" X 32'). LOGGED CHFD FROM 8385' TO 7500'. MADE TWO PASSES AT 900 FPH. RUN #2: HEAD I WEIGHT I GR I CCL I SCMT (2.5" X 45'). 06/04/04 ATTEMPT TO FISH 1" SOV UNSUCESSFULL, IN PROGRESS.D [Fish] 06/12/04 DRIFT TBG WI 23' X 2.63" DUMMY GUN, PASS DOWN TO 8384' WLM, OBTAINED SMALL SAMPLE OF FILL @ 8384' WLM VERY HARD BTM, RECOVERED 1" SOV @ 8384' WLM, COMPLETE [Tag] 06/13/04 PERFORATE THE INTERVAL 8120-8135 USING 2.5" HSD GUNS LOADED 6SPF, 60 DEG PHASED WI 2506 HYPERJET RDX CHARGES. INCREASE WHP TO 2400 PSI PRIOR TO FIRING SHOTS. LOST 200 PSI IMMEDIATELY. API CHARGE SPECS: 13.1" PENETRATION. 0.43" ENTRANCE HOLE. TAGGED TD AT 8392'. 06/16/04 LOADED IIA WI DIESEL, REPLACED DV WI OV @ 5155' RKBD [GLV] 06/25/04 TAGGED FILL @ 8397' RKB, EST. 262' RATHOLE. PULLED OV @ 5155' RKB. DISPLACED TBG & IA WI SW & DSL CAP. SET DV. TESTED CSG 3500 PSI, GOOD.D [Pressure Data, Tag, GLV] 06/30104 PUMP FRACTURE TREATMENT USING 50# DELAYED X-LINK GEL AT 30 BPM. SCREENED OUT AFTER PUMPING 67,184# OF 16/20 CERAMIC PROPPANT WITH 6.3 PPA ON PERFS AND 49,952# BEHIND PIPE. [Frac-Refrac] 07101/04 CLEAN OUT POST FRAC PROPPANTIGEL TO TO 8379' CTMD USING SLICK DIESEL WITH GEL DIESEL SWEEPS. WASH ACROSS GLM'S ON WAY OUT OF HOLE. 0 [FCO] Conocri'Phillips . ConocoPhillips Alaska, Inc.,slot #345 Pad 2N, Tarn ,North Slope, Alaska . Well bore: 345A Wellpath: MWD w/Sag <5569- 8557'> Date Printed: 8-Jul-2004 ::ltJJ.f-03/f "~i. BAKER HUGHES INTEQ Wellbore Name 345A I Created i 5-May-2004 Last Revised 18-MaY..:~94 _.1· Name 345 I Government ID I Last Revised . 5-May-2004 ·SJøt Name slot #345 I Grid Northing I Grid Easting 15911865.8084 1460479.3851 I Latitude I N70 Longitude 10 12.5460 W150 I North 195.0249 143.18S I Name Pad 2N Easting 461593.3157 Northing 5912003.3237 Coord System Name AK-4 on NORTH AMERICAN DATUM 1927 datum North Alignment True Name Tarn Easting 461651.5943 Northing 5927841.6325 Coord System Name AK-4 on NORTH AMERICAN DATUM 1927 datum North Alignment True All data is in Feet unless otherwise stated Coordinates are from Slot MDos are from Rig and TVD's are from Rig ( Nordic 3 151.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 269.17 degrees Bottom hole distance is 5959.21 Feet on azimuth 270.25 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ¥ ConocoPhillips . ConocoPhillips Alaska, Inc.,slot #345 Pad 2N, Tarn ,North Slope, Alaska . Wellbore: 345A Wellpath: MWD w/Sag <5569- 8557'> Date Printed: 8-Jul-2004 "i. BAKER HUGHES INTEQ IÖðmments All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Nordic 3 151.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 269.17 degrees Bottom hole distance is 5959.21 Feet on azimuth 270.25 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated y ConocoPhillips . ConocoPhillips Alaska, Inc.,slot #345 Pad 2N, Tarn ,North Slope, Alaska . Wellbore: 345A Wellpath: MWD w/Sag <5569- 8557'> Date Printed: 8-Jul-2004 r&l. BAKER HUGHES INTEQ WeI'liIlh (GridJ rc.,øort MO[ft] Inc[deg] Azi[deg] TVO[ft] North[ft] East[ft] Oogleg Vertical Easting Northing [deg/10OO] 8ection[f t] 5450.00 52.20 i 266.09 3832.56 433.888 3330.66W 0.00 3336.59 457146.84 5911449.37 5569.74 61.64 272.04 3897.88 435.248 3430.79W 8.91 3436.74 457046.71 5911448.54 5664.46 64.61 : 271.38 3940.70 432.728 3515.24W 3.20 3521.14 456962.29 5911451.49 5760.21 63.21 275.25 3982.82 427.778 3601.06W 3.91 3606.88 456876.50 5911456.89 5853.49 58.08 279.27 4028.54 417.578 3681.67W 6.66 3687.33 456795.95 5911467.51 5947.91 57.68 281.32 4078.75 403.288 3760.34W 1.89 3765.79 456717 .36 5911482.21 6043.76 60.45 280.91 4128.02 387.448 3841.01W 2.91 3846.22 456636.79 5911498.47 -_.~._-~-_.~_._- 6139.06 57.69 281.36 4177.00 371.668 3921.21W 2.92 3926.19 456556.68 5911514.67 6233.01 59.55 281.53 4225.92 355.748 3999.82W 1.99 4004.56 456478.16 5911530.99 - -~~-_.~- 6329.00 55.67 281.85 4277 .32 339.338 4079.18W 4.05 4083.67 456398.90 5911547.82 6422.87 57.97 282.12 4328.69 323.018 4156.03W 2.46 4160.27 456322.14 5911564.54 6518.38 59.94 281.80 4377.95 306.068 4236.08W 2.08 4240.07 456242.19 5911581.91 6613.42 56.01 280.73 4428.34 290.308 4315.08W 4.24 4318.83 456163.28 5911598.07 6704.22 57.81 279.81 4477.91 276.758 4389.93W 2.16 4393.48 456088.51 5911612.01 6797.84 56.40 280.87 4528.75 262.648 4467.26W 1.78 4470.60 456011.26 5911626.52 6893.71 58.95 280.56 4580.01 247.598 4546.86W 2.67 4549.97 455931.75 5911641.99 6985.41 57.76 280.43 4628.12 233.378 4623.62W 1.30 4626.51 455855.08 5911656.61 7078.41 60.17 279.14 4676.07 219.848 4702.14W 2.85 4704.83 455776.64 5911670.55 7174.26 57.57 279.87 4725.62 206.308 4783.05W 2.79 4785.54 455695.80 5911684.51 7270.14 59.32 280.09 4775.79 192.138 4863.52W 1.84 4865.79 455615.42 5911699.09 7363.76 61.81 279.60 4821.80 178.208 4943.84W 2.70 4945.91 455535.17 5911713.44 7458.92 58.87 281.16 4868.88 163.328 5025.17W 3.40 5027.01 455453.93 5911728.75 7553.88 60.27 280.88 4916.98 147.678 5105.54W 1.50 5107.14 455373.66 5911744.81 7649.13 58.00 281.83 4965.84 131.588 5185.69W 2.53 5187.06 455293.59 5911761.32 7756.96 60.57 280.82 5020.91 113.398 5276.59W 2.52 5277.67 455202.81 5911779.98 7847.49 60.77 279.79 5065.26 99.278 5354.24W 1.02 5355.11 455125.24 5911794.51 7941.92 61.32 280.30 5110.97 84.868 5435.60W 0.75 5436.25 455043.97 5911809.34 8035.88 60.07 280.45 5156.96 70.108 5516.19W 1.34 5516.63 454963.46 5911824.52 8131.80 59.71 281.05 5205.08 54.638 5597.71W 0.66 5597.91 454882.03 5911840.42 8225.63 60.30 281.78 5251.99 38.548 5677 .36W 0.92 5677.33 454802.47 5911856.91 8320.56 60.63 282.94 5298.79 20.868 5758.04W 1.12 5757.74 454721.89 5911875.01 8415.01 60.78 283.37 5345.00 2.128 5838.25W 0.43 5837.67 454641.79 5911894.18 8499.81 1 61.04 283.01 5386.23 14.79N 5910.40W 0.48 5909.56 454569.74 5911911.46 8557.00 i 61.04 283.01 5413.92 26.06N 5959.15W 0.00 5958.15 454521.05 5911922.98 All data is in Feet unless otherwise stated Coordinates are from 810t MO's are from Rig and TVO's are from Rig ( Nordic 3 151.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 269.17 degrees Bottom hole distance is 5959.21 Feet on azimuth 270.25 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~ ConocoPhillips . ConocoPhillips Alaska, Inc.,slot #345 Pad 2N, Tarn ,North Slope, Alaska . Wellbore: 345A Wellpath: MWD w/Sag <5569- 8557'> Date Printed: 8-Jul-2004 r&ií. BAKER HUGHES INTEQ Comments MD[ft] I TVD[ft] 5450.00 i 3832.56 i 8557.00 i 5413.92 North[ft] 433.88S 26.06N East[ft] I Comment 3330.66W ! Tie-In to Previous Survey 5959.15V'Li Projected Data - NO SURVEY Diameter [in] HoleSectloas . Start MD[ft] 43/4 5450.00 Start TVD[ft] 3832.56 Start North[ft] 433.88S Start East[ft] 3330.66 W End MD[ft] 8557.00 End TVD[ft] 5413.92 End North[ft] 26.06N Start Wellbore East[ft] 5959.15 345A W CâSi"å$ Name Top MD[ft] 3 1/2" Liner 5252.00 Top TVD[ft] 3716.01 Top North[ft] 423.74S Top East[ft] 3170.93 W Shoe MD[ft] 8556.00 Shoe TVD[ft] 5413.44 Shoe North[ft] 25.86N Shoe Wellbore East[ft] 5958.30 345A W All data is in Feet unless otherwise stated Coordinates are from Slot MOts are from Rig and TVD's are from Rig ( Nordic 3 151.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 269.17 degrees Bottom hole distance is 5959.21 Feet on azimuth 270.25 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated · , r ! i I FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. ORAND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy· Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk 2N-345A ConocoPhillips Alaska, Inc. Permit No: 204-034 Surface Location: 144' FNL, 1113' FEL, SEC. 3, T9N, R7E, UM Bottornhole Location: 130' FNL, 1712' FEL, SEe. 4, T9N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you ITom obtaining additional permits or approvals required by law ITom other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to ·tness any required test. Contact the Commission's North Slope petroleum field· ctor at 59- 607 (pager). BY ORDER OF THE COMMISSION DATED tbi~day of February, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoc~hillips . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com February 19, 2004 RECEfVED FE82 02004 Alalia OÐ & Gas Cons. Commission Anchorage Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Tarn producer 2N-345A Dear Commissioners: v" ./ ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for an onshore production well in the Bermuda sands of the Tarn oil pool to be sidetracked from well 2N-345. Please find attached for the review of the Commission Form 10-401 and the information required by 20 ACC 25.005 for this well. The expected spud date is March 4,2004 If you have any questions or require any further information, please contact Philip Hayden at 265-6481. Sincerely, \<$. ..J~ . Randy Thomas Greater Kuparuk Area Drilling Team Leader 1a. Type of Work: Drill 0 Re-entry D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RedrillU 1b. Current Well Class: Stratigraphic Test D P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 144' FNL, 1113' FEL, Sec. 3, T9N, R7E, UM / Top of Productive Horizon: 224' FNL, 1208' FEL, Sec. 4, T9N, R7E, UM :, Total Depth: 130' FNL, 1712' FEL, Sec. 4, T9N, R7E, UM ! 4b. Location of Well (State Base Plane Coordinates): Surface: x- 460479'" y- 16. Deviated wells: Kickoff depth: 5480 · 18. Casing Program Size Hole 42" 97/8" 6 3/4" 4 3/4" Casing 16" 7 5/8" 5.5" 3.5" 19 Total Depth MD (It): Casing Structural Conductor Detailed Operations Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee Property Plat I 5911866 Zone- J ft. Maximum Hole Angle: 59.55° Specifications Weight Grade Coupling Length 62.5# H-40 Weld 80 29.7# L-80 BTC 2761 15.5# L-80 BTCM 5420 9.3# L-BO HYD511 3163 PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Length Size o D BOP SketchD Diverter Sketch D 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature R. Thomas ~~> kif£ Ct~ ExploratoryU Development Oil ~ Multiple Zone D Service D Development Gas D Single Zone 0 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 2N-345A 6. Proposed Depth: 12. FieldlPool(s): MD: 8463' ' TVD: 5372' / Kuparuk River Field 7. Property Designation: 151' AMSL feet 17. Anticipated Pressure (see 20 AAC 25.035) Max. Downhole Pressure: 3300 psig / Max. Surface Pressure: 2849 psig ./ Setting Depth Quantity of Cement Bottom c. f. or sacks TVD (including stage data) 110' Preinstalled 2307 Existing 3833 Existing 5372 100 sx GasBLOK ADL 375074'~ 8. Land Use Permit: L31961 9. Acres in Property: 2560 10. KB Elevation 4 Top MD TVD 30.3' 30.3' 30.3' 3744 MD 110' 2791' 5450 8463 Commission Use Only Permit to Drill , / I API Number.. . / I Permit Approval Number: 2OC-f'......ó3ý 50-/ò3 - 2D2.b'f-ð/ Date: ~S-~ y Conditions of approval: Sample quired DYes þ,(fNo Mud log required Hydr en ulfide measures DYes JKf No Directional survey required (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (ft): Effective Depth TVD (It): Junk (measured) Cement Volume MD I Perforation Depth TVD (ft): Drilling Program~ Time v. Depth Plot D Seabed Report D Drilling Fluid Program 0 Date: Other: 30.3' 30.3' 30.3' 5300 Tarn Oil Pool 13. Approximate Spud Date: 3/4/2004 14. Distance to Nearest Property: 130' @ TD 15. Distance to Nearest Well within Pool: 2N-329,17oo k"'(~I-I~1 ) FEB 2 02004 ~~CA1&GMCœa.Co~ M::OI'IfJ Shallow Hazard Analysis D 20 MC 25.050 requirements 0 Contact Philip Hayden 265-6481 Title Kuparuk Drilling Team Leader Phone l<i.f'b'lt '0 Date t./ '11'0 If PreDared bv PhiliD Havden ~\""'-~~ ~\7 ~~\- COMMISSIONER BY ORDER OF THE COMMISSION Isee cover letter for other requirements ø~:: ~ ~: ... Bfl Date: Form 10-401 Revised 3/2003 . ORIGINAL · APPI. for Permit to Drill, Well 2N-345A Revision No.O Saved: 19-Feb-04 Permit It - Meltwater Well #2N-345A Application for Permit to Drill Document M(lJ:imiz$ Well IJglue Table of Contents 1. Well Name .......... ............... ........ ...... ..... .......... ... .................. ...... ............ ............... ..... 2 Requirements of 20 AAC 25.005 (f)..... ....................................... ........ ...... ..... ........................ ..... ..... .......2 2. Location Sum mary ........ ...... ....... ...... .... ............... ......... ....... ...... ............. .............. .... 2 Requirements of 20 AAC 25.005(c)(2) .......... .......................... ..... ............. ........ ................... ..................2 Requirements of 20 AAC 25.050(b).... ..................................................... .......... .... ............ ............. ........ 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ... ............. ................... .......................... ........... ................ ....... .... 3 4. Drilling Hazards Information ...................................................................................3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program............................................................................. 4 Requirements of 20 AAC 25.005(c)(6) ...... ......... ................................ ........ ...... ......... ..... ....... ........ ......... 4 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25.005(c)(7) ............. .... ................. .................................... .............................4 8. Dri II i ng FI uid Program ......... ....... .......... ..................... ...... ...... ............ ......... ....... ...... 4 Requirements of 20 AAC 25.005(c)(B) ... ............... ....... .......... ............... ............... .......... .... .................... 4 Production Hole Mud Program (LSND) .............. ............ .................. ............................... .......................5 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5 10. Seismic Analysis... ........ .... ......... ............ .................... ..... ....... ............... ................ .... 5 Requirements of 20 AAC 25.005 (c)(1 0) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................5 12. Evidence of Bonding ...............................................................................................5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................5 ORIGINAL 2N-345A PERMIT IT. doc Page 10f6 Printed: 19-Feb-04 · APP. for Permit to Drill, Well 2N-345A Revision No.O Saved: 19-Feb-04 13. Proposed Drilling Program .....................................................................................5 Requirements of 20 MC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments .......... ................. ............ ......... ............ ........ ... ..... ..... ...... ...... ................ 6 Attachment 1 Directional Plan (11 pages) .............................................................................................. 6 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................. 6 Attachment 3 Cement Loads and CemCADE Summary (1 page) ......................................................... 6 Attachment 4 Well Schematic (1 page) .................................................................................................. 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identitied by a unique name designated by the operator and a unique API number as..çigned by the commission under 20 MC 25.040(b). For a well with multiple well branches,. each branch must slinilarly be identitied by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2N-345A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Pem¡it to Drill must be accompanied by each of the following items,. except for an item already on tile with the commission and identitied in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration;" (C) the proposed depth of the well at the top of each objective formation and at total depth;" Location at Surface I NGS Coordinates./ ./ Northings: 5,911,866 Eastings: 460,479 144' FNL, 1113' FEL, Section 3, T9N, R7E, UM I RKB Elevation I 151' AMSL Pad Elevation 121' AMSL Location at KOP (Bottom of Whipstock) 579' FNL, 835' FWL, Section 3, T9N, R7E, UM NGS Coordinates Northings: 5,911,448 Eastings: 457,122 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 5,480 3,851 3,700 Location at Top of Productive Interval (Bermuda Sand) NGS Coordinates Northings: 5,911,816 224' FNL, 1208' FEL, Section 4, T9N, R7E, UM Eastings: 455,105 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 7,869 5,071 4.920 ORIGINAL 2N-345A PERMIT IT.doc Page 2 of 6 Printed: 19-Feb-04 · APP. for Permit to Drill, Well 2N-345A Revision No.O Saved: 19-Feb-04 Location at Total Depth NGS Coordinates Northings: 5,911,913 Eastings: 454,602 130' FNL, 1712' FEL, Section 4, T9N, R7E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: ./ 8,463 5,372 5,221 and (D) other information required by 20 MC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviateli the application for a Permit to Drill (Form 10-401) must (1) include a plat drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been fumished a copy of the application by certified mail,' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following Items, except for an item already on tile with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.035, 20 MC 25.036, or 20 MC 25.037, as applicable; An API 11" x 5,000 psi BOP stack (RBRRA) will be utilized to drill and complete well 2N-345A. Please see information on the Nordic 3 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of t!le following items, except for an item already on file with the commission and identified in the application: (4) infomlation on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to detemline it and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the Bermuda sands in the 2N-345A area vary from 0.47 to 0.65 ,./ psi/ft, or 9.1 to 12.5 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from existing wells on the field together with reservoir model forecasts. The highest pressure case is based on encountering injection fluid in the reservoir at bottom hole injection v - "- pressure. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the Bermuda sand formation is 2849 psi, calculated as follows: MPSP = (5276 ft)(0.65 - 0.11 psi/ft) = 2849 psi 0/ (B) data on potential gas zones; No potential gas zones are expected. ,. and ORIGINAL 2N-345A PERMIT IT.doc Page 3 of 6 Printed: 19-Feb-04 · APPI. for Permit to Drill, Well 2N-345A Revision No.O Saved: 19-Feb-04 (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zone~ and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 MC 25.030(f); After setting the whipstock and milling the window and rat hole a leak off test will be performed in accordance with the "Leak Off Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25. 030, and a description of any slotted liner; pre- perforated liner; or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm CsgfTbg Size Weight Length MOffVO MOffVO 00 (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 16 42 62.5 H-40 Welded 80 30 / 30 110 / 110 Preinstalled 7 5/8 97/8 29.7 L-80 BTC 2761 30 / 30 2791 / 2307 Existing 5 V2 6% 15.5 L-80 BTCM 5420 30 / 30 5450 / 3833 Existing 31/2 43/4 9.3 L-80 HYD511 3163 5300 / 3744 8463/ 5372 100 sx 15.8 PP9 GasBLOK slurry, TOC 7350' MD / 4808' TVD 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); A diverter is not planned to be used on this well as the sidetrack will occur beneath the surface casing shoe. ../' 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and desCliption ofthe drilling fluid system, as required by 20 MC 25.033,: Drilling will be done with muds having the following properties over the listed intervals: ORIGINAL 2N-345A PERMIT IT.doc Page 4 of 6 Printed: 19-Feb-04 · APP'. for Permit to Drill, Well 2N-345A Revision No.O Saved: 19-Feb-04 Production Hole Mud Program (LSND) KOP to TD Initial Value Final Value 10.0 11.0 10-14 20 Density (ppg) Plastic Viscosity (cp) Yield Point (/b11 00ft2) pH API Filtrate (cc I 30 min)) ./ 16-22 9-9.5 4-5 <15 9-9.5 4 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Nordic 3. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items; except for an item already on file wIth the commission and Identified in the application: (9) for an exploratory or stratigraphic test wel¿ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An applicatJon for a Permit to Drill must be accompanied by each of the following items; except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test wel¿ a seismic refractIon or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structur~ jack-up rig, or floating drilling vesse¿ an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items; except for an Item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met' Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items; except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Move in / rig up Nordic 3. Remove X-mas tree and install 11" x 5,000 psi BOP's. Test to 5000 psi (annular preventer to 3500 psi). Notify AOGCC 24 hrs before test. 2. Rig up handling equipment and pull the completion string. ORIGINAL 2N-345A PERMIT IT. doc Page 5 0'6 Printed: 19-Feb-04 · APPI. for Permit to Drill, Well 2N-345A Revision No.O Saved: 19-Feb-04 ../ 3. Rig up wireline. Run a gauge ring to the whipstock setting depth. Run and set a bridge plug at the chosen depth for setting the whipstock. Rig down wireline. ,...,.' 4. RIH with the whipstock and milling assembly. Set the whipstock at approximately 5480 ft MD. Mill the window and drill the rathole. Perform a LOT at the window. POOH and LD the whipstock milling assembly. ..' 5. PU 4 3/4" bit and 3 1/8" drilling assembly, with MWD and LWD (GR and resistivity). RIH, orientate through the window and directionally drill to the 3 V2" casing point at 8463' MD / 5372' ND. 6. Run 3 V2", 9.3# L-80, HYD511 liner to TD on 2 7/8" DP. Pump cement and displace with water and mud. Set and test the liner hanger and packer. \......, \' 'c-."",,- -\.o~ \\'i (..b-~_K\- \.'\~, 7. Make up completion string as required and RIH to depth. Locate seal bore extension, space out and land completion. Pressure test completion and production casing to 3500 psi for 30 minutes and record results. Shear RP shear valve in gas lift mandrel. 8. Install BPV, nipple down stack, nipple up and test tree to 5,000 psi. Pull BPV 9. Freeze protect well with diesel by pumping into the annulus, taking returns from tubing and allowing to equalize. Sweep the outer annulus with water and freeze protect. 10. Set BPV and move rig off. 11. Rig up wire line unit. Pull BPV. Set dummy valve in place of RP shear valve in gas lift mandrel. Perform MIT pressure tests of tubing and annulus (Tubing and annulus to 3500 psi). Perforate well and rig down wire line unit. 12. Carry out fracture stimulation. 13. Freeze protect well and turn well over to production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mastc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of dlilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids ,- into a permitted annulus on 2N Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 2N Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on the pad in accordance with a permit from the State of Alaska. At the end of drilling operations, an application may be submitted to permit 2N-345A.for annular dIsP.osal~. of fluids occurring as a result of future drilling operations on 2N pad. ~ '.. . "- 15.Attachments t\ \) Q\V....N \ao::.\, t).. Attachment 1 Directional Plan (11 pages) Š~Q:-- "\. "'" )("'1 . Attachment 2 Drilling Hazards Summary (1 page) a \ l ~ -q, ç¡r Attachment 3 Cement Loads and CemCADE Summary (1 page) t'\.D \<"'.cl\c..u...1? D f'-. CkJ ~. Attachment 4 Well Schematic (1 page) \ f'-: ¡\¡ t) \)0..) C>- <s. Q:.1i.,) Q \' ~ '. 1B1W1~lð\ ORIGINAL 2N-345A PERMIT IT.doc Page 6 of 6 Printed: 19-Feb-04 Scale 1 ::;80 ft -6240 -6060 ConocoPhillips Alaska, Inc. Slot: slot #345 Well: 345 Weilbon¡: 345A North Slope, Alaska rarn Installation: Pad 2N Created by' Planner Date plotted: 13-Feb-2004 Piot reference is 345A. is 345A Ver#1 A True Vertical Depths are reference Rig Datum. Measured Depths [¡re reference Rig Datum, Datum: Nordic lit Est RKB sea ievei: 151.00 ft. is aligned to TRUE North, -> -5760 -5600 -5260 -5120 -4960 -4800 -4640 -4460 -4320 -4160 -4000 -3640 -3680 -3520 -3360 -3200 -3040 -2880 I TARGET LQCATION: I 345A ?-- . 0e~ ,;þ~ r;, ,,\'1-\) <Ç#' ,0, ~# ,'1- I KOPLOCATiON:1 579' FNL. 835' FWL· SEC. 3, T9N, R7E (l,e\ ",,-<..ø ¿S'.p f('?! '\"'(\~ ,r;,. " ,/>'. 640 480 320 160 o ^ . -160 -320 -480 -640 ¢:: 3400 0 0 II 3600 E u () 3800 (ii u (j) 4000 4200 4400 4600 C!:! 4800 (J t! ~ 5000 (,) ::::s ... ¡... 5200 . V KOP 5400 5600 5800 6000 6200 ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Tarn Installation: Pad 2N Slot: slot #346 Well: 346 Wellbore: 346A inips Created by Planner Date plotted: 13-Feb-2004 Plot referellce is 345A. Ref wellpath is 345A Ver#1.A. Coordinates are in feet reference slot #345< True Vertical Depths are reference Datum, Measured are reference Rig Rig Datum: III Est RKB Rig Datum to mean sea level: 151.00 ft. Plot North is aligned to TRUE North. WELL PROFILE DATA Tie on I MD Ilnc Az! TVD North East degftOOft V. Sect I 5450.00 I 52.20 26609 383256 -433.88 -3330.66 End of BuildfTurn 5462.50 53.50 267.02 3840.11 -43448 -3340.60 I 5480.50 53.50 267.02 3850.81 -435.23 -3355 05 I 5694.19 59.55 280.60 396901 -422.70 -3532.11 KOP End of BuildfTurn Target 2N-245A Top Ber 7868.60 59.55 280.60 5071.00 -77.88 -5374.59 End of Hold 8273.10 59.55 280.60 527600 -1374 -5717.34 TO & End of Hold 8463.10 59.55 280.60 5372.29 16.39 -5878.34 T4.1 T3.1 T3 Bermuda) Target T2 (Base Bermuda) TO, 3 1/2 Liner Pi 3000 3200 3400 3600 3800 4000 4200 4400 Seale 1 em:::: 100 ft Azimuth 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 (feet) -> N, 0.00 E slot #345 0.00 3336.59 12.00 3346 54 0.00 3361.00 600 353786 000 537515 0.00 5716.94 0.00 587749 270 ConoeoPhìllips Alaska, ·Inc" I Installation: Pad 2N Wellbore: 345A TRUE NORTH 350 o 10 340 20 290 280 90 260 250 200 160 190 170 180 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ¡¡:: Scale 1 em = 80 ft -6400 -6240 -6080 -5920 -5760 800 ConoeoPhillips Alaska, Ine.. North Slope, Alaska Field: Tarn Installation: Pad 2N Slot: slot #345 Well: 345 Wellbore: 34M -5600 (feet) ~> -4640 -4480 -4160 -4000 -5440 -5280 -5120 -4960 -4320 iUips -3840 -3680 -3520 -3360 -3200 -3040 -2880 800 480 3600 3300 3000 2400 160 ^ , 0 4800 -160 -320 -320 -480 -640 ,640 . ConocJ'Phillips ConocoPhillips Alaska, Inc.,slot #345 Pad 2N, Tarn ,North Slope, Alaska . PROPOSAL LISTING Page 1 Wellbore: 345A Wellpath: 345A Ver#1.A Date Printed: 13-Feb-2004 "ii. BAKER HUGHES INTEQ I Northino Coord SYStem Nam& ·1 North Alionment 461593.3151 5912003.323 AK-4 on NORTH AMERICAN DATUM 1927 datum True Field Name Tarn I Eastino 461651.5943 I Coord SYStem Name North AIionment AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Nordic III Est. RKB 151.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 269.17 degrees Bottom hole distance is 5878.36 Feet on azimuth 270.16 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . eonoa')Ã,illips ConocoPhillips Alaska, Inc.,slot #345 Pad 2N, Tarn ,North Slope, Alaska . PROPOSAL LISTING Page 2 Wellbore: 345A Well path: 345A Ver#1.A Date Printed: 13-Feb-2004 r,.. BAKER HUGHES INTEQ 5450.00 52.20 266.09 3832.56 5911449.37 457146.84 N70 10 8.2716 W150 20 41.5077 3336.59 5462.50 53.50 267.02 3840.11 5911448.82 457136.90 N70 10 8.2656 W150 20 41.7958 3346.54 5480.50 53.50 267.02 3850.81 5911448.15 457122.44 N70 10 8.2582 W150 20 42.2144 3361.00 5500.00 53.99 268.34 3862.35 5911447.59 457106.73 N70 10 8.2519 W150 20 42.6695 3376.72 5600.00 56.70 274.85 3919.24 5911450.39 457024.61 N70 10 8.2747 W150 20 45.0492 3458.83 5694.19 59.55 280.60 3969.01 5911461.60 456945.47 N70 10 8.3806 W150 20 47.3435 3537.86 5700.00 59.55 280.60 3971.95 5911462.55 456940.56 N70 10 8.3897 W150 20 47.4861 3542.77 5800.00 59.55 280.60 4022.63 5911478.85 456855.92 N70 10 8.5452 W150 20 49.9409 3627.26 5900.00 59.55 280.60 4073.31 5911495.15 456771.27 N70 10 8.7008 W150 20 52.3957 3711.76 6000.00 59.55 .280.60 4123.99 5911511.44 456686.63 N70 10 8.8564 W150 20 54.8506 3796.25 6100.00 59.55 280.60 4174.67 5911527.74 456601.99 N70 10 9.0119 W150 20 57.3055 3880.75 6200.00 59.55 280.60 4225.35 5911544.04 456517.35 N70 10 9.1674 W150 20 59.7604 3965.25 6300.00 59.55 280.60 4276.03 5911560.34 456432.70 N70 10 9.3230 W150 21 2.2152 4049.74 6400.00 59.55 280.60 4326.71 5911576.64 456348.06 N70 10 9.4785 W150 21 4.6701 4134.24 6500.00 59.55 280.60 4377.39 5911592.94 456263.42 N70 10 9.6340 W150 21 7.1251 4218.74 6600.00 59.55 280.60 4428.07 5911609.24 456178.78 N70 10 9.7895 W150 21 9.5800 4303.23 6700.00 59.55 280.60 4478.75 5911625.53 456094.13 N70 10 9.9450 W150 21 12.0349 4387.73 6800.00 59.55 280.60 4529.43 5911641.83 456009.49 N70 10 10.1004 W150 21 14.4899 4472.23 6900.00 59.55 280.60 4580.11 5911658.13 455924.85 N70 10 10.2559 W150 21 16.9448 4556.72 7000.00 59.55 280.60 4630.79 5911674.43 455840.21 N70 10 10.4114 W150 21 19.3998 4641.22 7100.00 59.55 280.60 4681.47 5911690.73 455755.56 N70 10 10.5668 W150 21 21.8547 4725.72 7200.00 59.55 280.60 4732.15 5911707.03 455670.92 N70 10 10.7222 W150 21 24.3097 4810.21 7300.00 59.55 280.60 4782.83 5911723.33 455586.28 N70 10 10.8777 W150 21 26.7647 4894.71 7400.00 59.55 280.60 4833.51 5911739.62 455501.63 N70 10 11.0331 W150 21 29.2197 4979.21 7500.00 59.55 280.60 4884.19 5911755.92 455416.99 N70 10 11.1885 W150 21 31.6747 5063.70 7600.00 59.55 280.60 4934.87 5911772.22 455332.35 N70 10 11.3439 W150 21 34.1298 5148.20 7700.00 59.55 280.60 4985.55 5911788.52 455247.71 N70 10 11.4993 W150 21 36.5848 5232.69 7800.00 59.55 280.60 5036.23 5911804.82 455163.06 N70 10 11.6547 W150 21 39.0398 5317.19 7868.60 59.55 280.60 5071.00 5911816.00 455105.00 N70 10 11.7613 W150 21 40.7240 5375.15 7900.00 59.55 280.60 5086.91 5911821.12 455078.42 N70 10 11.8101 W150 21 41.4949 5401.69 8000.00 59.55 280.60 5137.59 5911837.42 454993.78 N70 10 11.9654 W150 21 43.9499 5486.18 8100.00 59.55 280.60 5188.27 5911853.72 454909.14 N70 10 12.1208 W150 21 46.4050 5570.68 8200.00 59.55 280.60 5238.95 5911870.01 454824.49 N70 10 12.2761 W150 21 48.8601 5655.18 8273.10 59.55 280.60 5276.00 5911881.93 454762.62 N70 10 12.3897 W150 21 50.6547 5716.94 8300.00 59.55 280.60 5289.64 5911886.31 454739.85 N70 10 12.4315 W150 21 51.3152 5739.67 8400.00 59.55 280.60 5340.31 5911902.61 454655.21 N70 10 12.5868 W150 21 53.7703 5824.17 8463.10 59.55 280.60 5372.29 5911912.90 454601.80 N70 10 12.6848 W150 21 55.3195 5877.49 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Nordic III Est. RKB 151.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 269.17 degrees Bottom hole distance is 5878.36 Feet on azimuth 270.16 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . ConocÓPhillips ConocoPhillips Alaska, Inc.,slot #345 Pad 2N, Tarn ,North Slope, Alaska . PROPOSAL LISTING Page 3 Well bore: 345A Wellpath: 345A Ver#1.A Date Printed: 13-Feb-2004 r&ii. BAKER HUGHES INTEQ 5450.00 3832.56 433.888 3330.66W Top Whipstock Face 5462.50 3840.11 434.48S 3340.60W Base WhiDstock Face 5480.50 3850.81 435.23S 3355.05W End Milled Ooenhole. KOP 5694.19 3969.01 422.70S 3532.11W EOC 5707.99 3976.00 420.518 3543.80W C40 6003.97 4126.00 373.57S 3794.59W C37 7197.73 4731.00 184.27S 4806.13W T7 7779.81 5026.00 91.96S 5299.35W T4.1 7819.27 5046.00 85.70S 5332.79W T3.1 7868.60 5071.00 77.88S 5374.59W T3 (Top Bermuda) TarQet 8273.10 5276.00 13.74S 5717.34W T2 (Base Bermuda) 8463.10 5372.29 16.40N 5878.34W TD. 3 1/2 Liner pt. 5 1/2in Casino 3 1/2in CasinQ 2.00 5450.00 2.00 3832.56 433.888 3330.66W 5450.00 8463.10 3832.56 5372.29 433.88S 16.40N 3330.66W 345A 5878.34W 345A 2N-245A Top Bern 77.88S 5374.59W 5071.00 TGT RVSD05Feb04 N70 10 11.76 W150 2140.n 455105.00 5911816.00 30-Jan-2004 All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Nordic III Est. RKB 151.00 above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 269.17 degrees Bottom hole distance is 5878.36 Feet on azimuth 270.16 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . Con~illips ConocoPhillips Alaska, Inc.,slot #345 Pad 2N, Tarn ,North Slope, Alaska . PROPOSAL LISTING Page 1 Wellbore: 345A Wellpath: 345A Ver#1.A Date Printed: 13-Feb-2004 If&ii. BAKER HUGHES INTEQ I Grid NorthinQ Grid Eastirn:¡ 5911865.8084 '" 460479.3851 Coord SYStem NameNorth Alianment AK-4 on NORTH AMERICAN DATUM 1927 datum True..... Field Name Tarn I Coord SYstem Name North Alionment AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Nordic III Est. RKB 151.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 269.17 degrees Bottom hole distance is 5878.36 Feet on azimuth 270.16 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . ConocJ'Phillips ConocoPhillips Alaska, Inc.,slot #345 Pad 2N, Tarn ,North Slope, Alaska PROPOSAL LISTING Page 2 Wellbore: 345A Wellpath: 345A Ver#1.A Date Printed: 13-Feb-2004 J&i. BAKER HUGHES INTEQ 5450.00 52.20 266.09 3832.56 433.88S 3330.66W 0.00 3336.59 Top Whipstock Face, 5 1/2in Casina. Tie on 5462.50 53.50 267.02 3840.11 434.48S 3340.60W 12.00 3346.54 Base Whipstock Face, End of BuildlTum 5480.50 53.50 267.02 3850.81 435.23S 3355.05W 0.00 3361.00 End Milled Openhole, KOP, 30J .... Kick off Point 5500.00 53.99 268.34 3862.35 435.86S 3370.76W 6.00 3376.72 5600.00 56.70 274.85 3919.24 433.50S 3452.91W 6.00 3458.83 5694.19 59.55 280.60 3969.01 422.70S 3532.11W 6.00 3537.86 EOC. End of BuildlTum 5700.00 59.55 280.60 3971.95 421.78S 3537.03W 0.00 3542.77 5707.99 59.55 280.60 3976.00 420.51S 3543.80W 0.00 3549.52 C40 5800.00 59.55 280.60 4022.63 405.92S 3621.76W 0.00 3627.26 5900.00 59.55 280.60 4073.31 390.068 3706.50W 0.00 3711.76 6000.00 59.55 280.60 4123.99 374.208 3791.23W 0.00 3796.25 6003.97 59.55 280.60 4126.00 373.57S 3794.59W 0.00 3799.61 C37 6100.00 59.55 280.60 4174.67 358.35S 3875.97W 0.00 3880.75 6200.00 59.55 280.60 4225.35 342.498 3960.70W 0.00 3965.25 6300.00 59.55 280.60 4276.03 326.638 4045.44W 0.00 4049.74 6400.00 59.55 280.60 4326.71 310.778 4130.17W 0.00 4134.24 6500.00 59.55 280.60 4377.39 294.918 4214.91W 0.00 4218.74 6600.00 59.55 280.60 4428.07 279.068 4299.64W 0.00 4303.23 6700.00 59.55 280.60 4478.75 263.20S 4384.38W 0.00 4387.73 6800.00 59.55 280.60 4529.43 247.348 4469.11W 0.00 4472.23 6900.00 59.55 280.60 4580.11 231.48S 4553.85W 0.00 4556.72 7000.00 59.55 280.60 4630.79 215.62S 4638.58W 0.00 4641.22 7100.00 59.55 280.60 4681.47 199.76S 4723.32W 0.00 4725.72 7197.73 59.55 280.60 4731.00 184.278 4806.13W 0.00 4808.29 T7 7200.00 59.55 280.60 4732.15 183.91S 4808.05W 0.00 4810.21 7300.00 59.55 280.60 4782.83 168.05S 4892.79W 0.00 4894.71 7400.00 59.55 280.60 4833.51 152.19S 4977.52W 0.00 4979.21 7500.00 59.55 280.60 4884.19 136.338 5062.26W 0.00 5063.70 7600.00 59.55 280.60 4934.87 120.478 5146.99W 0.00 5148.20 7700.00 59.55 280.60 4985.55 104.628 5231.73W 0.00 5232.69 7779.81 59.55 280.60 5026.00 91.96S 5299.35W 0.00 5300.13 T4.1 7800.00 59.55 280.60 5036.23 88.76S 5316.46W 0.00 5317.19 7819.27 59.55 280.60 5046.00 85.70S 5332.79W 0.00 5333.47 T3.1 7868.60 59.55 280.60 5071.00 77.888 5374.59W 0.00 5375.15 T3 (Top Bermuda) Target, 2N-245A Top Berm TGT ",. RVS005Feb04, End of Hold 7900.00 59.55 280.60 5086.91 72.908 5401.20W 0.00 5401.69 8000.00 59.55 280.60 5137.59 57.048 5485.93W 0.00 5486.18 8100.00 59.55 280.60 5188.27 41.198 5570.67W 0.00 5570.68 8200.00 59.55 280.60 5238.95 25.33S 5655.40W 0.00 5655.18 8273.10 59.55 280.60 5276.00 13.74S 5717.34W 0.00 5716.94 T2 (Base Bermuda\. End of Holç 8300.00 59.55 280.60 5289.64 9.47S 5740.14W 0.00 5739.67 8400.00 59.55 280.60 5340.31 6.39N 5824.87W 0.00 5824.17 8463.10 59.55 280.60 5372.29 16.40N 5878.34W 0.00 5877.49 TO, 3 1/2 Liner Pt., 3 1/2in Casinq, End of Hold All data is in Feet unless otherwise stated Coordinates are from 810t MO's are from Rig and TVO's are from Rig ( Nordic III Est. RKB 151.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 269.17 degrees Bottom hole distance is 5878.36 Feet on azimuth 270.16 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . Con<>cJPt,illipS ConocoPhillips Alaska, Inc.,slot #345 Pad 2N, Tarn ,North Slope, Alaska '&rí8 BAKER HUGHES INTEQ PROPOSAL LISTING Page 3 Wellbore: 345A Well path: 345A Ver#1.A Date Printed: 13-Feb-2004 5450.00 5462.50 5480.50 5694.19 5707.99 6003.97 7197.73 7779.81 7819.27 7868.60 8273.10 - 8463.10 .J9Tfll 3832.56 3840.11 3850.81 3969.01 3976.00 4126.00 4731.00 5026.00 5046.00 5071.00 5276.00 5372.29 ./ NoffftfftJ 433.88S 434.48S 435.23S 422.70S 420.51S 373.57S 184.27S 91.96S 85.70S 77.8BS 13.74S 16.40N ëástff'tJ 3330.66W 3340.60W 3355.05W 3532.11W 3543.80W 3794.59W 4806.13W 5299.35W 5332.79W 5374.59W 5717.34W 5878.34W COníment Top Whipstock Face Base Whipstock Face End Milled Openhole. KOP EOC C40 C37 T7 T4.1 T3.1 T3 (Top Bermuda) TarQet T2 (Base Bermuda) TO. 3 1/2 Liner Pt. 5 1/2in Casina 3 1/2in CasinQ 2.00 5450.00 2.00 3832.56 433.88S 3330.66W 5450.00 8463.10 3832.56 5372.29 433.88S 16.40N 3330.66W 345A 5878.34W 345A T arQets Name 2N-245A Top Berrr 77.88S TGT RVSD05Feb04 10 11.761~ W150 21 5911816.00 647800 Planned 8463.10 ISCWSA MWD E1îTòr Basic MWD - ISCWSA - 28 JAN 030JH MWD+SAG - ISCWSA - 28 Jan . 03 OJH 5372.29 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig (Nordic III Est. RKB 151.0ft above mean sea level) Vertical Section is from O.OON a.aOE on azimuth 269.17 degrees Bottom hole distance is 5878.36 Feet on azimuth 270.16 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL · . Baker Hughes Incorporated Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 5450.00 to 8463.10 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Survey Program for Definitive Well path Date: 2/17/2004 Validated: No Planned From To Survey ft ft 108.00 5450.00 MWD (108.00-7431.00) (0) 5450.00 8463.10 Planned: 2N-345A Vers#1a V2 Version: 0 Toolcode Tool Name MWD MWD+SAG MWD - Standard MWD + Sag correction Summary Tam #2 Tam#2 Tarn#2 VO Out of range Tam #3 Tam#3 Tarn#3 V1 Out of range Tam #3 T arn#3 Tarn#3A VO Out of range Tam #4 T arn#4 Tarn#4 VO Out of range Tarn Drillsite 2N 302 2N-302 V1 Out of range Tarn Drillsite 2N 303 2N-303 V1 Out of range Tarn Drillsite 2N 304 2N-304 V1 Out of range Tarn Drillsite 2N 304 2N-304PB1 V1 Out of range Tarn Drillsite 2N 305 2N-305 V1 Out of range Tarn Drillsite 2N 307 2N-307 V1 Out of range Tarn Drillsite 2N 308 2N-308 V1 Out of range Tarn Drillsite 2N 309 2N-309 V1 Out of range Tarn Drillsite 2N 311 2N-311 V1 Plan: 2N-311 Out of range Tarn Drillsite 2N 313 2N-313 V1 Out of range Tarn Drillsite 2N 314 2N-314 V1 5965.47 7250.00 4901.58 307.84 4593.74 Pass: Major Risk Tarn Drillsite 2N 315 2N-315 V1 Out of range Tarn Drillsite 2N 316 2N-316 V1 5965.28 6875.00 4239.12 307.13 3931.99 Pass: Major Risk Tarn Drillsite 2N 317 2N-317 V1 5886.11 6700.00 3639.44 339.81 3299.62 Pass: Major Risk Tarn Drillsite 2N 318 2N-318 V1 5878.94 6475.00 3168.99 353.13 2815.85 Pass: Major Risk Tarn Drillsite 2N 319 2N-319 V1 5775.38 6575.00 3047.64 278.98 2768.65 Pass: Major Risk Tarn Drillsite 2N 320 2N-320 V1 5798.61 5975.00 1904.87 337.42 1567.46 Pass: Major Risk Tarn Drillsite 2N 321 2N-321 V2 5913.26 6275.00 3303.63 278.61 3025.02 Pass: Major Risk Tarn Drillsite 2N 321 2N-321A V1 5915.48 6300.00 3350.84 294.89 3055.95 Pass: Major Risk Tarn Drillsite 2N 323 2N-323 VO 5847.97 5900.00 2542.97 350.03 2192.94 Pass: Major Risk Tarn Drillsite 2N 325 2N-325 VO 5751.26 5975.00 1848.70 244.20 1604.50 Pass: Major Risk Tarn Drillsite 2N 326 2N-326 VO 5860.56 5850.00 2458.73 282.41 2176.32 Pass: Major Risk Tarn Drillsite 2N 329 2N-329 VO 8457.28 8400.00 1189.99 391.52 798.47 Pass: Major Risk Tarn Drillsite 2N 331 2N-331 VO 5738.01 5625.00 1349.29 195.82 1153.47 Pass: Major Risk Tarn Drillsite 2N 332 2N-332 VO 5808.49 5725.00 1876.29 251.93 1624.36 Pass: Major Risk Tarn Drillsite 2N 332 2N-332PB1 VO 5808.49 5725.00 1876.29 251.93 1624.35 Pass: Major Risk Tarn Drillsite 2N 335 2N-335 VO 5465.15 6225.00 930.82 272.91 657.90 Pass: Major Risk Tarn Drillsite 2N 337 2N-337 V1 5450.00 6150.00 1968.25 296.90 1671.34 Pass: Major Risk Tarn Drillsite 2N 337 2N-337PB1 V1 5450.00 6150.00 1968.25 296.91 1671.34 Pass: Major Risk Tarn Drillsite 2N 339 2N-339 V1 5455.88 5650.00 1119.74 255.98 863.76 Pass: Major Risk Tarn Drillsite 2N 341 2N-341 VO 5481 .42 5650.00 1378.71 121.84 1256.87 Pass: Major Risk Tarn Drillsite 2N 343 2N-343 V1 5482.56 5475.00 800.55 163.60 636.95 Pass: Major Risk Tarn Drillsite 2N 345 2N-345 VO 5450.00 5450.00 0.00 210.32 -210.32 FAIL: Major Risk Tarn Drillsite 2N 347 2N-347 VO 5733.37 5475.00 1616.85 172.63 1444.22 Pass: Major Risk Tarn Drillsite 2N 348 2N-348 VO 5776.67 5675.00 1585.19 222.98 1362.22 Pass: Major Risk Tarn Drillsite 2N 349 2N-349 VO Out of range Tarn Drillsite 2N 349 2N-349A V2 5456.24 5825.00 1832.72 131.64 1701.08 Pass: Major Risk Tarn Drillsite 2N 350 2N-350 VO 5479.06 5550.00 1389.36 131.40 1257.96 Pass: Major Risk ORIGiNAL . . Tarn 2N-345A - DRILLING HAZARDS SUMMARY 4 %" Open Hole & 3 Vi' Production Liner Interval Event Insufficient or undetermined LOT High ECD / Tight hole on trips/ Swabbing Differential sticking Barite sag Lost circulation Stuck liner Risk Level Low Moderate Moderate Low High Moderate Mitigation Strategy I Contingency Importance of LOT communicated to all parties, all parties familiar with LOT procedure. Condition mud & clean hole prior to trips. Use MI Virtual Hydraulics to simulate & monitor ECDs. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets) Keep hole clean, periodic wiper trips, keep pipe moving/rotating with pumps on whenever possible Good drilling practices as documented in well plan Pretreat mud before drilling reservoir section, keep hole clean, reduce pump rates and mud rheology, proactively use LCM Clean the hole before running liner, pump high density high viscosity sweeps, wiper trip. Communicate liner running tool limitations. Tarn 2N-345A Drilling Hazards Summary Prepared by Philip Hayden 2/1912004 ORIG\NAl Rig: Doyon 141 Location: Tarn Client: ConocoPhillips Alaska Revision Date: 2/18/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < Liner Top at 5,330' MD Previous Csg. _ 51/2", 15.5# casing at 5,480' MD Volume Calculations and Cement Systems Volumes are based on 75% excess. Displacement is calculated with a 2.9"-10.4# drill string. Tail Slurry Minimum thickening time: 110 min. (pump time plus 90 min.) ~~" ...,.... 15.8 ppg Class G + 2.0 gps D600G + 0.03% B155 + 0.4% D65 + 0.2 gps D47 1.17 ft3/sk Liner Gag: 0.0886 ft 1ft x 0' x 1.00 (no excess) = Liner Lap..: 0.0668 ft3Jft x (5480' - 5480') x 1.00 (no excess) = Annular Volume: 0.0562 ft3/ft x (8463' - 7350') x 1.75 (75% excess) = Shoe Volume: 0.0488 ft31ft x 120' x 1.00 (no excess) = Totals: o ft3 + 0 ft3 + 109.5 ft3 + 5.9 ft3 = 115.4 ft3/1.17 ft3/sk = Round up to 100 sks Preliminary Job Design based on limited input data. For estimate purposes only. o ft3 o ft3 109.5 ft3 5.9 ft3 115.4 ft3 98.6 sks BHST = 12rF, Estimated BHCT = 109°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 4.0 20.0 5.0 5.0 Pressure test lines 0.0 0.0 10.0 15.0 < 31/2",9.3# casing MudPUSH II 4.0 20.0 5.0 20.0 in 4 3/4" OH GasBLOK 4.0 20.6 5.1 25.1 Drop wiper plug 0.0 0.0 5.0 30.1 Top ofTail at Water 4.0 24.0 6.0 36.1 < 7,350' MD Slow @ XO, PU 2.0 4.0 2.0 38.1 Plug Water 4.0 16.1 4.0 42.1 Slow & Bump plug 2.0 6.0 3.0 45.1 TD at 8,463' MD (5,372' TVD) Mark of Schlumberger MUD REMOVAL Recommended Mud Properties: 10.2 ppg. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.5 ppg MudPUSH* II, Pv ? 21-23, Ty ? 32-34 Centralizers: Recommended for effieceint mud removal 1 per joint from 7300 - 7383' MD 1 % per joint from 7383 - 8343' MD 2 per joint from 8343 - 8463' MD ORIGINAL 2N-345A SIDETAcK COMPLETION (Producer) . CQnQc~ilU,. f -y-I i I '- ~ I ~ I I~ ~ ~ ! .J~ ~ i I ~ ~ ~ ~ ~ ~ I I ~ ~ I ~ ~ ~ ~ ~ I , 75/8" 29.7# L80 casing @ 2791' MD I 2307' TVD I ~ ~ J. ~ ~ ~ ~ ~ ~ ~ I I '- I ~ ~ Baker "K-1" CIBP @ ~ +1- 5480' MD I '- '- I ~ ~ '- '- '- '- ~ KOP I Bottom of whipstock @ +1- 5480' MD, +- 3851" TVD 5 y." x 3 y." XO @ 6764' MD Cement Retainer r ~ ~ 5W'x3W'TD@ .oM. 7257' MD ""T'"" i ~ ~ ~ ~ ~ I ~ ~ I i :¡i ~ ~ ~ ¡ I ~ ¡ i ~ ~ ~ .i! , ¿ , ~ ~ ~ ~ -Ll f ~ '- ~ ~ , ~ '- ~ i I I ~ I ~ , ~ .. 3 y.n 5M FMC Gen V tubing hanger with 3 y." L-80 EUE8RD Mod pin down 3 y.", 9.3#, L-80 EUE8RD Mod tubing to surface, drifted to 2.91" 3 y." Camco 'DS' landing nipple with 2.875" ID No-Go profile set at +1-500' MD 3 y." 9.3# L-80 EUE8RD Mod tubing to GLM 2 x 3 y." x 1" Camco 'KBG-2-9' mandrels 3 y.n x 6' L-80 handling pups installed above and below, EUE8RD Mod 3 y." x 1" Camco 'KBG-2-9' mandrel wI shear valve, pinned for 3000 psi shear (casing to tubing differential), 3 y." x 6' L-80 handling pups installed above and below, EUE8RD Mod 3 y.n Baker 'eMU' sliding sleeve wI 2.813" Camco "DS" profile, EUE8RD Mod box x pin. 3 y." x 6' L-80 EUE8RD Mod handling pup installed above 3 y.n Camco 'D' landing nipple with 2.75" ID No-Go profile and 12 ft handling pup installed above and 6 ft handling pup installed below, EUE8RD Mod One Joint 3 y.n 9.3# L-80 EUE8RD Mod tubing Baker 15 ft. 4 1/8" Bullet Seal Assembly w/3 W' EUE8RD Box up and 6 ft. Handling Sub LINER ASSEMBLY 5 y.n ZXP Liner Hanger Packer w/15 ft. Tieback Extension (4.125" Tieback ID) 3 y." X 5 y.n HMC Hydraulic Liner Hanger 3 y.n HYD511 Liner as needed 3 y.n Landing Collar wI HYD511 box x pin One Joint 3 y." HYD511 Tubing 3 y." Float Collar wI HYD511 Box x Pin Two Joints 3 W' HYD511Tubing 3 y.n Float Shoe wI HYD511 box x pin 3 y." 9.3# L-80 HYD511 TD @ 8463' MD I 5372' TVD 02-16-2004 ORIG\NAL N ~ B . . . -4~~L · q 0 ? q 2 ? b II- . 0 ~ b I . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME KK¿¿ 2/{fr-3Y5'/I PTD# 2or/-a3 c/ l/ Development / ~ () I L Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) PILOT (PH) Exploration Stratigraphic ~'CLUEn The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number. stated above. HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated In both name (name on permit plus PH) and API Dum ber (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fuD compliance with 20 AAC 25.0SS~ Approval to perforate and produce is contingent upon issuance of;¡ conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to tbe spacing exception that may occur. All dry ditcb sample sets submitted to the Commission must be in no greater 'than 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals through target ZOnes. Field & Pool KUPARUK RIVER, TARN OIL - 490165 Well Name: KUPARUK RIV U TARN 2N-345A Program DEV Well bore seg 0 PTD#: 2040340 Company CONOCOPHILLlPS ALASKA INC Initial ClassfType DEVlEEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal 0 Administration 1 P.!3rmit fee attached - - ~ - - - - Y.!3S _ - - -- 2 _Leas.!3 _numberapprop,riate _ _ Yes - - - - -- 3 _U_niqUe weltn_arn.!3_and Ol.!mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ Y.!3s__ - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - . - -- 4 WelUQcat.!3d in a_ defil1ep PPQI_ _ Y.!3S tŒU,_MeJtwaterQitF='o_ot CO_No, 430A - - - - - - 5 WellJQcat.!3d proPer rlistance from driJling ul1itboul1d_al"Y_ _ _ Y.!3S - - - - -- - - - - - - 6 Well JQcat.!3d prOPer _distance. from otber welJs_ _ - - - -- Y.!3S _ lJomil1é!1 spa_cing uoits within th_eppol is_ to_a_cœs._ _ 7 Sutficientacreage_ayailable in_driIJiog unit _ _ - - -- Y.!3s_ - - - - -- - - - - - 8 Jtd.!3viated, is weJlbQre plç¡UncJu_ded . . . Y.!3S_ - - - - - - - - - - -- - - - - 9 _Oper_ator only é!ftected party _ _ - - - -- Y.!3S_ - - - - - 10 _Oper_ator has_apprppriate_ bond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ Y.!3S__ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - -. - - - . - - -- 11 P.!3rmit c_an be iSSl.!ed wjtbQut co_nservatioo order _ _ Yes - - - - - - - . Date 12 P.!3rmit can be issued wjtbQut administrati\(e_approvaJ _ _ _ - - - - Y.!3S_ - - - - - - -- - - - - 2/23/2004 13 Can permit be approved before 15-day wait Yes 14 WeJUQcat.!3d withil1 area alld_strç¡taauthorized by Injectipo Ord.!3r # (Put 10# in_ comments) (For_ _NA _ - - - -- - - - - - - 15 _AJlwel!s_withiJ1Jl4_mile_area_ofreyiewjd.!3otified(Fpr~erviC.!3wellonly)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA __ - - - - - - . - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - -. - - - -- - - -- 16 Pre-produ.ced injectQr; duratiQnof pre-production tes~ thall3 mooths_ (for_service well onJy) . NA _ - - - - -- - - - - - - - - 17 ACMP filldjng _of Con_sistenGY.h<3s bee_n jssued_ for_ this pr_oiect NA WelJ drilled frQm existiog pad, . . Engineering 18 _C_onduct9r $triIlQ_prQvided _ . - - - ~ - - Y.!3S tnstç¡lled wjth origjn<31 welk . - - - -- 19 SurfaC.!3_C<l~iog_prQtect~ all_known. USDW$ _ _ - - - - NA. 811 aquifers ex.ernpt.!3d 4Q CFR H7. t02(b){3), _ . _ . 20 _CMT v_ol adeQl.!ate_ to circulate o_n .cOl1ductor_ & surt csg _ . Xes_ Cement was_ c.irCl.!lated on oJiginal W.!3U. _ _ _ _ _ _ _ _ _ _ 21 _CMT v.ol adeQl!ateJo tie-inJQng _string to surf ~g_ _ _ . _ . No - - -- - - - - -- - - - - -- - - - - 22 _CMT_will coyer_all koowJ1_productiye hQri~Qn_s_ _ _ _ _ _ _ _ Yes - - - -- 23 _C<3sioQ design~ ad_equate for C._T, B&pemJé!frost _ _ _ . _Y.!3S - - - - - -- - - - - - - - -- 24 _Adequ<3teJan_kageßJ re_serve pit _ - - -- _Y.!3S Rig is_ euipped_ with_ste.!31 p,it~k lJQ reserve pit pJanned.Waste to _ao apprQved ç¡l1n_ulus or_ dispP$aJ welt 25 JtaJe-drilt has_a_ toA03 fQr <3bandon.ment be.!3O approved. _ . Y.!3S 304~041.apprpved _211}Q4 26 _Mequ<3teJ¡\I:ellbore $eparatjo_npropo~ed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y.!3s The_original jNeljboreJ~ tI1e POly weltpJQxjmate. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jfdjvecter required, dQes jtmeet reQuJatipos_ _ - - - - - - NA Sidetrack out ofPJod_uction.casjn.Q, - - - - - - - - -- - - - - . Date 28 Drillil1g flujd_ p,rogram sc;hematic& eQ.uip JistadeQ.uale _ _ . . _ Yes Mç¡ximunJ BHP ra_nge,9, 1- J 2.5 £MW {wors_t casel. J'lanned MW 11 ,0_ with _ability tojocrease._ 2/24/2004 29 _BOPEs,_dothey JTleetreguJation . . . Y.!3S - - - - - - - - - - - - - - - - - - - - - - -- Jft"W( 30 _BOPE_pres$ raJil1g appropriate; test to .(put p$ig iJ1 q)'Tlmeots). _ . . _Y.!3S Worst case MASP .calcuJated_at 285.0 pst 35QOp,si appropriate. CF='Allikelyto tesUo 5QOO_psi, 31 CMkemanjfold cQmplie$ w/API RF='-53 (May 64) - - - - Y.!3S - - - - - - 32 WQrk will occ_ur withputoperation _shutdow_n_ _ Y.!3S - - -- 33 J~ pre~ence Qf H2S gas_ p,rob_able _ - - -- No_ Mud ~h_ould pœclude 1i2_S Qntbe_ rig, Rig is eQujpped with. sen~ors_ and alarms.. . 34 Me.chaniC<llcpodjt¡on of wells within 80R verified (Fpr s_erviCj3 W.!31J only) . .NA - - - - - - - - - Geology 35 P.!3rmit c.al1 be issued w!Q hydrogen_ s_ulfide measures. _ . Y.!3S lJo H2S listeMorMeJtwaterF='ads in20Q4 KRU H2S report toCommjssioo._ . 36 D_ata_ preseoted Qn_ pote_ntial pveJpre~sure .ZOnes _ _ Y.!3S Expected r.!3servoir pre_ssuresrç¡ngeJrorn9, 1 -_ 12,5_ppg (worsJ cas.!3l EMW; will be drilled with_ Appr Date 37 _S.!3ismicanç¡lysjs Qf sbaJlow gaszooes . _NA 1 1.Q PP.Q_mud, - - -- SFD 2/23/2004 38 S.!3ç¡bedcondjtioo sl.!rvey{if off-~hJ)[e) . . NA 39 . CQnta.ct oamelphOllefor_we.!3kly progre$s.reports [expIQrç¡tpl"Y0nly] . _ NA Geologic Engineering Public Date Commissioner: 1;1/4- Commissioner: Date Commissioner D'r5 e e 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. **** REEL HEADER **** LDWG 04/07/14 AWS 01 **** TAPE HEADER **** LDWG 04/07/14 01 *** LIS COMMENT RECORD *** e e~:;2() f- (..1.3 Ý /2~X7/ !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! !! !! !! ! !! !! !! ! ! ! !! Extract File: LISTAPE.HED TAPE HEADER TARN UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 4 G. SUTING G. WHITLOCK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 2N-345A 501032026401 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 14-JUL-04 MWD RUN MWD RUN 34 ION 7E 151.00 121.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 5.500 110.0 5445.0 8557.0 4.750 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE e e GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. SURFACE LOCATION: LAT: N 70 DEG 10' 12.546" LONG: W150 DEG 19' 05.025" LOG MEASURED FROM D.F. AT 151 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ run 1 utilized a directional only tool in a milling assembly to set a whipstock in the 5.5" casing of the 2N-345 well and drill to 5460 feet MD (3839' TVD). (2) Baker Hughes INTEQ run 2 utilized an Ultra Slim Multiple Propagation Resistivity (USMPR) tool to drill from 5460 - 5534 feet MD (3839 - 3880' TVD). Data from this run is not presented. (3) Baker Hughes INTEQ run 3 utilized a directional only tool from 5534 - 7750 feet MD (3880 - 5018' TVD). (4) Baker Hughes INTEQ run 4 utilized an Ultra Slim Multiple Propagation Resistivity (USMPR) tool to drill from 7750 - 8557 feet MD (5018 - 5414' TVD). REMARKS: (1) Top of Whipstock: 5428 feet MD (3819' TVD) Bottom of Whipstock: 5445 feet MD (3829' TVD) (2) The interval from 5460 to 7750 feet MD (3839 - 5018' TVD) was drilled with a directional only tool. No logging while drilling was done in this section. (3) The interval from 7526 to 7750 feet MD (4903 - 5018' TVD) was logged with a MAD pass on run 4. (4) The interval from 8522 to 8557 feet MD (5397 - 5414' TVD) was not logged due to sensor-bit offset at TD. $ Tape Subfile: 1 76 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE001.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 7479.0 STOP DEPTH 8557.0 # BASELINE CURVE FOR SHIFTS: e e CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ BIT RUN NO MERGE TOP 4 7479.0 MERGE BASE 8557.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 2n-345a 5.xtf 150 ConocoPhillips Alaska, Inc. 2N-345A Tarn North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPCLM 0.0 RPS RPS RPCHM 0.0 ROP ROP ROPA 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPS MWD 68 1 OHMM 4 4 4 ROP MWD 68 1 FPHR 4 4 e e 5 6 FET MWD MTEM MWD 68 68 1 1 HR DEGF 4 4 4 4 ------- 24 Total Data Records: 60 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7479.000000 8556.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 100 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 log header data for each bit run in separate files. 4 .2500 START DEPTH 7479.0 STOP DEPTH 8557.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 14-MAY-04 MSB 18704 3.125 USR MEMORY 8557.0 7479.0 8557.0 o 59.7 61. 0 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR USR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RESIST. TOOL NUMBER 31893 USR 23579 14041 e # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # e 4.750 5445.0 LSND 10.20 .0 .0 2000 .0 .000 .000 .000 .000 130.0 .0 .0 .0 .00 .000 .0 o BIT RUN 1RR2 (MWD Run 4). GR/USMPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 2n-345a.xtf LCC 150 CN ConocoPhillips Alaska, I WN 2N-345A FN Tarn COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPCH RACL RACH 0.0 0.0 0.0 0.0 0.0 GRAM RPCL RPCH RACL RACH GRAM RPCLM RPCHM RACLM RACHM e e ROPS RPTH TCDM ROPS RPTH TCDM ROPA RPTHM TCDM 0.0 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 154 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7479.000000 8556.000000 0.250000 feet **** FILE TRAILER **** Tape Sub file: 3 244 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 04/07/14 01 **** REEL TRAILER **** LDWG " oil¡. 04/07/14 AWS 01 Tape Sub file : 4 Minimum record length: Maximum record length: e e 2 records... 132 bytes 132 bytes