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Home My WebLink About201-204 STATE OF ALASKA AL�CA OIL AND GAS CONSERVATION COSIGN ` REPORT OF SUNDRY W OP d 1. Operations Performed: Abandon r Repair w ell ,r Plug Perforations r Perforate r APR ` �y Oth'er 17 Alter Casing r Rill Tubing Stimulate - Frac r Waiver ‘ ;sk � i° nS ;r?rs?mi c i n Change Approved Program r Operat. Shutdown r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development )" Exploratory r 201 -204 3. Address: 6. API Number: [ Stratigraphic r Service r P. 0. Box 100360, Anchorage, Alaska 99510 - 50 029 - 23047 - 60' - 0 0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25649 — - 1C-109L1 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): `' none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 7525 feet Plugs (measured) None true vertical 3734 feet Junk (measured) None Effective Depth measured 7525 feet Packer (measured) none true vertical 3734 feet (true vertucal) Casing Length Size MD TVD Burst Collapse CONDUCTOR 120 16 158 158 SURFACE 4898 7.625 4938 3808 D -SAND LINER 3019 4.5 7512 3734 Perforation depth: Measured depth: 4593' - 7453' True Vertical Depth: 3766' - 3736' , R APR ° Tubing (size, grade, MD, and TVD) 3.5, L - 80, 4396 MD, 3700 TVD Packers & SSSV (type, MD, and TVD) NO PACKER NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 ■ Service r Stratigraphic r 16. Well Status after work: ,, Oil W Gas r WDSPL r Daily Report of Well Operations XXX GSTOR f WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer @ 265 -6845 Printed Name Brett Packer Title Wells Engineer Signature / 4∎r // Phone: 265-6845 Date ef ( 3 �' ^ Form 10 -404 Revised 11 AP� // Submit Original Only Ide%(.� STATE OF ALASKA ~~~ ®~ ~~~~ ALASKA O1L AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA ~ ~~~ ~~r~~;• ~o~rlm;ssion 1. Operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ i~9tli~i':~ii~8~6^ Alter Casing ^ Pull Tubing Q Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, InC. Development ^~ Exploratory ^ 201-204 / ` 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23047-60 r 7. KB Elevation (ft): 9. Well Name and Number: RKB40' 1C-109L1 ' 8. Property Designation: 10. Field/Pool(s): ADL 25649 Kuparuk River Field /West Sak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 7525' feet true vertical 3734' feet Plugs (measured) Effective Depth measured 7525' feet Junk (measured) true vertical 3734' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 158' 16" 158' 158' SURFACE 4898' 7-5/8" 4938' 3808' PRODUCTION 3019' 5-1/2" 7512' 3734' Perforation depth: Measured depth: slotted liner perts 4593'-7453' MD rti t l d th ' ' a ~ ' ~y ~°; ~ i rue ve ca ep : 3766 -3736 :., - ~ • ~ ~ .~ . ~. JU{3 Tubing (size, grade, and measured depth) 4-1/2", L-80, 4315' MD . Packers 8~ SSSV (type 8~ measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 182 7 9 -- 211 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nia, if C.O. Exempt: none contact Cody Gauer @ 263-4802 Printed Name Co G uer Signature Title Phone: 263-4802 Wells Engineer aC~/~ >f~ ~,p, L~ Date / S/ !~ \ Pre a ~ b Sharon All u -Dr k 263-4612 ~~ ~~ Form 10-404i~tl ~4~0~ /~' s'~°$ _, ~ .,~;~ Sao Submit Original OnIY~/ ~~ (~ KUP • 1C-109L1 ConocoPhillips Well Attributes Max Angle & NM ;TO kV In Wellbore API /UWI Field Name Well Status !noi (°) MD (ftKB) Act Btm (ftKB) a 500292304760 WEST SAK PROD 98.10 4,719.62 7,525.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date wenconeq- lc- losu,3rzsrz01z4s6:3oFM SSSV: NONE 0 7/10/2009 Last WO: 8/21/2008 45.45 11/10/2001 Schemati Actual Annotation Depth (ftKB) End Date Annotation Last Mod... End Date Last Tag: Rev Reason: WORKOVER ninam 3/25/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd HANGER, 36 1 st D - SAN D LINER 4 1/2 3.958 4,493.5 7,512.5 3,734.3 12.60 L -80 BTC 6 1 Li ner Details Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 4,493.5 3,739.7 68.07 HANGER BAKER FLANGED HOOK HANGER 4.500 4,516.4 3,747.8 69.81 SWIVEL BAKER SWIVEL SUB 3.958 4,558.5 3,760.3 76.68 SLEEVE BAKER SLIDING CMD SLEEVE 3.430 4,563.1 3,761.5 77.60 XO Reducing 4.000 CONDUCTOR, _ 4,595.5 3,765.9 84.06 XO Enlarging 4.500 38 - 158 7,456.9 3,735.7 91.42 XO Reducing 4.000 I 7,490.3 3,734.9 91.42 XO Reducing 3.500 Perforations & Slots Shot I I I Top (TVD) Btm (TVD) Dens GAS LIFT, Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date Oh— Type Comment 2,052 4,593 7,453 3,765.9 3,735.8 WS D, 1C -109L1 11/10/2001 99.0 SLOTS Slotted Liner Notes: General & Safety End Date Annotation 1 1/10/2001 NOTE: MULTI - LATERAL WELL: 1C -109 (B- SAND), 1C -109L1 (D -SAND) 8/30/2008 NOTE: View Schematic w/ Alaska Schematic9.0 PACKER, 2.176 II GAS LIFT, 2.289 GAUGE, 4,306 INTAKE, 4,364 W SEAL, 4,368 Bei Reduction, 4,382 it MOTOR, 4,384 - GAUGE, 4,392 Centralizer, 4,394 WINDOW L1, ill .4 4.494-4.525 D -SAND LINER LEM, 4U PRODUCTION, 41 -0,938 ll Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (!n) Sery Type Type tin) (psi) Run Date Corn... 1 2,051.8 1,901.2 42.34 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 3/9/2012 SLOTS. 2 2,289.1 2,077.3 41.34 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 3/9/2012 4,593 - 7,453 5 It D -SAND LINER, 4,493 -7,513 TD(1C- 109L1), Ill 7,525 • DATE SUMMARY 1C-109 Pre -Rig Well Work • 12/28/11 PRE RWO T -POT BONNET( PASSED ), T -PPPOT BONNET ( PASSED ), T -POT UPPER BODY ( PASSED ), T -PPPOT UPPER BODY ( PASSED ), T -POT LOWER BODY ( PASSED ), T -PPPOT LOWER BODY ( PASSED ), GLS TEST ( PASSED ), GLS -PP TEST ( PASSED ), FT -LDS, LDS © 6:00 FROZEN REST ALL NORMAL. 2/9/12 PULLED 4 1/2 SLIPSTOP @ 4199' SLM, SET 4 1/2 CATCHER @ 4197' SLM, REPLACED SOV @ 4168' RKB w /DV, RDMO TO SPOOL NEW ,125 WIRE, IN PROGRESS. 2/10/12 PULLED 41/2 CATCHER @ 4194' SLM, PULLED 4 1/2 D &D PACK OFF ASSY', KOBE SHEARED @ 4199' SLM, PULLED 4 1/2 TTCESP P- 18,G42, VORTEX GAS SEPARATOR, 37'9 "OAL ) COMPLETE. LITTLE RED PUMPED 225 HOT DIESEL DOWN IA AND 67 HOT DIESEL DOWN TUBING. CALLED IN FOR BPV. • • • ConocoPhillips Time Log & Summary Webview Web Reporting Report Well Name: 1C -109 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 3/4/2012 10:00:00 AM Rig Release: 3/11/2012 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/04/2012 24 hr Summary Move Rig over 1C -109. Rig accepted at 10:00 hrs. Berm, level, and shim up Rig. MIRU support equipment. Fill Pits with Sea Water. RU and PT Lines. Circulate well. Shot Fluid level. Install BPV 08:00 15:00 7.00 MIRU MOVE RURD P Shuffle rig mats from 1C -102 to 1C -109. Move in and set rig down over 1C-109. Berm up and spot auxiliary equipment. Accepted Nordic Rig 3 at 10:00 hrs on 3-4 -12 15:00 16:00 1.00 MIRU MOVE OTHR P Load Pits with kill wt fluid 16:00 17:00 1.00 COMPZ WHDBOMPSP P PU and RU lubricator. Pull4 "'H' BPV and lay down lubricator. 17:00 17:30 0.50 COMPZ WHDBO PRTS P MU kill line to rig and PT at 250 / 3,000 psi. 17:30 19:30 2.00 COMPZ WELCTL KLWL P Open up well 0 psi TBG and 600 psi IA. Notify DSO and Security prior to venting gas and vent gas as planned from IA. Bleed IA down to 80 psi. 19:30 21:30 2.00 COMPZ WELCTL KLWL P PJSM- Circulate down IA 160° seawater w/ 3% KCI, 6 bpm, 150 psi ICP, 60 bbls away down IA and getting diesel returns to surface, 220 bbls down IA, 56 bbls return < 80 %, pump 95 bbls down TBG 6 bpm, 150 ICP, 220 FCP, no returns, Pump 25 BBLS down IA 6 bpm, 220 ICP, 300 FCP, 18 bbls clean returns, shut in and monitor for flow, TBG / IA both on vac. 21:30 22:30 1.00 COMPZ WELCTL KLWL P Monitor for flow, TBG / IA both static 22:30 22:45 0.25 COMPZ WELCTL KLWL P PJSM with Well Integrity Rep. shooting fluid level. 22:45 23:30 0.75 COMPZ WELCTL KLWL P TBG / IA 0 psi. Shoot first fluid level at 720 -ft MD, monitor well for 30 minutes, shoot second fluid level at 780 -ft MD, well taking fluid at 5.5 bph. confer with town engineer. 23:30 00:00 0.50 COMPZ WHDBO THGR P PJSM- Lubricate and set 4" Type "H" BPV. 03/05/2012 ND Tree. Install blanking plug. NU BOPE. Preform initial BOPE test 250/3000. Pull Blanking plug and BPV. Install isolation sleeve. Shoot fluid levels. Pre for de- complete. MU landing joint. 00:00 00:15 0.25 COMPZ WHDBO SFTY P PJSM- Discuss hazards to nipple down tree and NU BOPE 00:15 01:15 1.00 COMPZ WHDBO NUND P ND Tree. Inspect threds, install blanking plug Page 1 of 6 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 04:00 2.75 COMPZ WHDBO NUND P NU 13 -5/8" BOPE. 2 -3/8" Solids UPR, 2 -7/8 "- 5 -1/2" variable LPR's. 04:00 12:30 8.50 COMPZ WHDBO BOPE P Conduct Initial BOP test at 250 / 3,500 psi with 2 -3/8 ", 3 -1/2" and 4 -1/2" Test joint. Test 3 -1/2" 8rd and 4 -1/2" NSCT FOSV and associated BOP equipment. Test upper and lower kelly valve 250/3500, good test all alarms checked, koomey draw down tested good, rig down test equipment. Went off Cold Weather Restriction at 09:00 hrs - Continue loading equipment on rig 12:30 18:00 5.50 COMPZ RPCOM OTHR P Loading Pipe shed with 31/2 Recompletion string and 2 3/8 clean out string, Rack and Tally. Baker tools and Centrilift ESP equipment. Shoot fluid level on IA at 1,124 -ft, RU circulating hoses. 18:00 19:30 1.50 COMPZ RPCOM THGR P Pull blanking plug and BPV, set isolation sleeve, MU landing joint to TBG hanger. RU circulating hoses. 19:30 20:00 0.50 COMPZ RPCOM CIRC P Circulate 78 bbls filtered KWF down IA, no returns, TBG and IA both on vac 20:00 22:00 2.00 COMPZ RPCOM OWFF P Monitor well for flow, TBG 0 psi and static, IA on vac, shoot fluid level on IA at 53 -ft and TBG at 863 -ft, let IA go static (1 hr 20 min) shoot IA fluid level at 786 -ft, TBG fluid level at 909 -ft. Confer with town engineer, 20 bph hole fill, triple displacement every 5 stands pulled. Cold weather restriction in effect as of 23:00 hrs. -37 amb. 22:00 00:00 2.00 COMPZ RPCOM OTHR P RD circulating equipment. RU floors for de- completion. Spot Heat Trace spool. RU ESP spool safety devices. 03/06/2012 BOLDS. Pull TBG hanger to Floor. RU Cable to spooler. Pull 4 -1/2" ESP completion standing 4 -1/2" tubing back. Clean and clear floors. Load out ESP de- completion. MU and TIH with 7 -5/8" casing scraper / clean out assembly BHA #1. 00:00 00:15 0.25 COMPZ RPCOM SFTY P PJSM- Discuss procedures and hazards for pulling ESP completion. 20 bph hole fill and triple displacement every 5 stands pulled. 00:15 01:30 1.25 COMPZ RPCOM THGR P BOLDS. un -land tubing hanger with 190k, pull tubing hanger to floor, up • wt 110k, lay down tubing hanger. Page 2 of 6 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 12:30 11.00 4,315 0 COMPZ RPCOM TRIP P POOH w/ 4-1/2" tubing. Run ESP cable and heat trace cable over sheaves to spools. Stand back tubing in derrick for work string. Continue to POOH w/ 4 -1/2" ESP completion standing back 4 -1/2" tubing in derrick, keeping accurate account of clamps / bands recovered, spooling ESP / Heat Trace and I -TEC wire. Found water and oil in Tandem seals and motor sections. Scale build up on ESP components. Clamp count recovered: 460 -5 -ft Mid Joint Dual Channel 3 -4 -ft Mid Joint Dual Channel 13 -3 -ft Mid Joint Dual Channel 1 End Shoe Clamp 100 Dual Channel 26 Single Channel 8 SS Bands 2 Flat Guards 3 Protectolizers 12:30 18:30 6.00 0 0 COMPZ RPCOM OTHR P Clean and clean Floor. Off load ESP components, Clamps, Heat trace and I -Tec wire. Change over to 2 3/8 TBG handling equipment. Re -load ESP Completion components. Set wear ring. 18:30 20:00 1.50 0 0 COMPZ WELLPF SFTY P PJSM with Crane Operator. Discussed the planned ESP Spool swap -out. Perform ESP Spool exchange with out any problems. 20:00 20:30 0.50 0 0 COMPZ WELLPF RURD P Rig up floor to handle 2 3/8" Tubing. 20:30 00:00 3.50 0 2,571 COMPZ WELLPF PUTB P PJSM. Make -up Mule Shoe. Single in with 2 3/8" Tubing from the Pipe Shed to 2,571 -ft. Up Weight = 50K. down Weight = 50K. 03/07/2012 Continue to pick -up Clean -out BHA. Clean out the B -Sand Lateral down to 7,480 -ft. TOOH. PU and beginTlH with Test Packer and Retrievable Bridge Plug. 00:00 00:30 0.50 2,571 3,080 COMPZ WELLPF PUTB P Finished picking up the 2 3/8" Tubing from the Plpe shed (96 jts). 00:30 02:00 1.50 3,080 3,109 COMPZ WELLPF PULD P Change floor equipment to make -up the the 7 5/8" Casing Scraper, 4 3/4" Bumper Sub, 4 3/5" Oil Jar section of BHA #1. 02:00 03:00 1.00 3,109 3,570 COMPZ WELLPF PUTB P Continue to single in with 4 1/2" NSCT Tubing from Plpe shed (15 Jts). Page 3 of 6 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 06:30 3.50 3,570 4,667 COMPZ WELLPF TRIP P Continue tripping in with 4 1/2" NSTC Tbg stands from the Derrick. Passed through the ZXP Packer at 4,423 -ft with no problems. continue easing through the LEM Liner compountants. Tagged up at 4,588 -ft. Bring Pump on line 3.0 bpm /450 psi. Got returns, being washing through fill from 4,588 -ft. to 4,667 -ft 06:30 11:00 4.50 4,667 7,475 COMPZ WELLPFTRIP P RIH f/ 4,667 -ft to 4,760 -ft, Reverse Circulate @ 5 bpm at 240 psi for 3 TBG Volumes. Continue to RIH to 7,475 -ft and Tag up. PU 10 -ft off tag. 11:00 13:00 2.00 7,465 7,465 COMPZ WELLPF CIRC P Clear TBG at 3 bpm at 500 psi. Reverse circulate 235 bbls at 5 bpm at 180 ICP 400 FCP Returning 1 bbl for 5 bbls pumped. 13:00 15:00 2.00 7,465 7,465 COMPZ WELLPF OWFF P Blow down top drive. Monitor well for 1 hr. Shhot fluid level twice - FL @ 282 -ft. 15:00 17:00 2.00 7,465 3,108 COMPZ WELLPF TRIP P POOH w/ 4 1/2" 12.6# NSCT TBG from 7,465 -ft to 3,108 -ft. 17:00 22:30 5.50 3,108 0 COMPZ WELLPF PULD P lay down 7 5/8 CSG Scraper assy and 96 jts of 2 3/8 PH -6 Clean -out String. Off -load Plpe Shed as needed. Clear and clean Floor. 22:30 00:00 1.50 0 305 COMPZ WELLPF TRIP P PJSM. Make -up BHA #2, Baker • Retrievable Bridge Plug and Retrievamatic Packer. Begin to trip in with 4 1/2" Tubing from the Derrick to 305 -ft. Up and Down Weight = 43K. X3/08/2012 Continue to TIH with Test Packer and Retrievable Bridge Plug. Test Casing. TOOH and single down the 4 1/2" Tubing in the Pipe Shed. Pick -up and service the ESP Assembly. Start picking up the 3 1/2" Completion as designed. 00:00 04:30 4.50 305 4,410 COMPZ WELLPFTRIP P Finish trip in with the test Packer and Retrievable Bridge Plug from 305 -ft... Set RBP at 4,410 -ft. Fill hole (27 bbls, fluid lever was 1,750 -ft). 04:30 07:30 3.00 4,410 4,358 COMPZ WELLPF PRTS P Perform a quick visual test against the RBP to 500 psi. Good. Set Packer at 4,358 -ft. Pressure test down the Tubing against the RBP at 1,500 psi x 15 minutes. - good test. Pressure test IA at 3,000 psi for 30 minutes. Good test. Release test packer and RIH, engage RBP and release same. 07:30 12:30 5.00 4,358 0 COMPZ WELLPF PULD P POOH laying down 41/2 12.6 #, L -80 NSCT Tubing, Test packer and RBP. 12:30 13:30 1.00 0 0 COMPZ WELLPF OTHR P Change over to 31/2 TBG equipment and RU to PU ESP equipment Page 4 of 6 M • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 00:00 10.50 0 2,117 COMPZ RPCOM RCST P PJSM. MAke -up ESP Motor, Seal Section. Service same. Make -up TECH Wire and attach ESP Cable. Test same. Good. Begin to single in the Completion with 3 1/2", 9.3 lb /ft, L -80, EUE 8rd Tubing from the Pipe Sled to 2,117 -ft. Up Weight = 61K. Down Weight = 59K. Install Clamps per procedure. Check ESP Cable every 1,000 -ft. X3/09/2012 Continue to single in the 3 1/2" ESP Completion. MU and Land Tbg Hanger. RU S -Line. Set WRP. Load IA w /Gel Diesel. Set and test Pkr. Pull DV. Freeze Tbg. Set DV. PT Tbg. RD S -Line. 00:00 00:30 0.50 2,117 2,180 COMPZ RPCOM RCST P Continue to pick =up the 3 1/2" Completion. Pick -up the Lower GLM w /Dummy Valve. Pick -up the Weatherford Hydrow II Dual- String Packer. 00:30 04:00 3.50 2,180 2,180 COMPZ RPCOM OTHR P Make the bottom and top ESP Splice through the Feed -Thru Packer. Test ESP Cable. Good. 04:00 08:30 4.50 2,180 4,318 COMPZ RPCOM RCST P Install the Upper GLM w /Dummy Valve. Continue to single in with the 3 1/2" Completion as designed from 2,180 -ft to 4,318 -ft 92K up wt, 72k do wt. 08:30 13:00 4.50 4,318 4,400 COMPZ RPCOM THGR P MU hanger and make Final splicew/ ESP Cable - Good test. Land hanger with Centralizer at 4,400 -ft. and Run in lock down screws. Pressure test pack offs at 250/5,000 psi good test. Drifted TBG,GLMS & hanger to 2.867 ". Use Jet Lube to each joint end. Torque TBG to 2250 ft -lbs. Installed (4) Seal Clamps across Tandem Seal Section Assembly. Installed (3) SS Flat Bands on DGU. Installed (81) 3500A Single Channel & (1) 4500 Cross Coupling Cannon Clamp on every other joint from MLE splice to surface. 13:00 19:00 6.00 0 0 COMPZ RPCOM SLKL P PJSM with Slick line crew. Load lubricator and surface control equipment in pipe shed. RU Slick line and mu blind box on kick over tool. PT lubricator at 500 psi. Rih and locate lower GLM at 2,282 -ft SLM. POOH and MU DGU and WFT WRP. RIH to 2,324 -ft, load TBG w/ 30 ± bbls Neat diesel. Wait for DGU timer to fire and set WRP. POOH MU and Rih w/ 30" catcher sub and set on top of WRP, 2,302 -ft SLM. POOH and RD slick line. Page 5 of 6 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 20:30 1.50 0 0 COMPZ RPCOM PACK P Pump 78 bbls of Gelled Diesel down the 7 5/8" x 3 1/2" Annulus. Pump stright diesel down the Tubing (1 bb) and begin the Packer setting sequence. Set the Feed -Thru Weatherford Hydrow II Packer in 500 psi steps up to 3,000 psi. Hold the 3,000 psi x 15 minutes. Good. Bleed pressure to ")" psi. Pressure up on the 7 5/8" x 31 /2" Annulus to 1,550 psi x 30 minutes. (lost —100 psi in 30 minutes). Good. Record tests on Chart. 20:30 00:00 3.50 0 0 COMPZ RPCOM OTHR P Begin the bleeding down the 7 5/8" x 3 1/2" Annulus following the decompression schedule as per program. 03/10/2012 Nipple down BOP Stack. Nipple up Tubing Adaptor and Tree.Test Tree. Perform final ESP Cable check. Pull TWCV and Install BPV. Secure Cellar. Prep to release Rig. 00:00 01:00 1.00 0 0 COMPZ WHDBO MPSP P PJSM. Set Back Pressure valve. 01:00 10:00 9.00 0 0 COMPZ WHDBO NUND P Remove Ram Blocks from the 13 3/8" BOP. Inspect and prep for storage. Nipple down BOP Stack. and prep for setting on Skid. 10:00 11:00 1.00 0 0 COMPZ WHDBO OTHR P Meg ESP cable pre nipple up of bonnet 11:00 11:30 0.50 0 0 COMPZ WHDBO NUND P NU Vetco Gray 41/16" 5M x 13 5/8" 5M TBG Bonnet. Test Bonnet at 250/5,000 psi. 11:30 12:30 1.00 0 0 COMPZ WHDBO MPSP P Pull BPV / Run TWC with dry rod 12:30 13:15 0.75 0 0 COMPZ WHDBO PRTS P Test tree at 250 / 5,000 psi, 13:15 14:15 1.00 0 0 COMPZ WHDBO MPSP P Pull TWC / Run BPV with dry rod 14:15 15:00 0.75 0 0 COMPZ WHDBO OTHR P Meg ESP cable Post nipple up of bonnet 15:00 21:30 6.50 0 0 COMPZ MOVE RURD P Prep for moving rig off well. 21:30 22:00 0.50 0 0 COMPZ MOVE RURD P Move off of Well. (Note: Pad Operator was present)'. 22:00 00:00 2.00 0 0 COMPZ MOVE RURD P Load out 13 5/8" 5K BOP Stack on skid. Secure and clean Cellar. X3/11/2012 Install the 13 5/8" BOP Stack on transport skid. Install the 11" BOP Stack on Sub - Structure Stump. Wait on Power Company to de- energize an electrical line. Wait on Snow Removal to open access road leaving C -Pad. Release Rig. 00:00 06:00 6.00 0 0 COMPZ MOVE RURD P Complete loading out the 13 5/8" 5K BOP Stack onto the transport skid. Load the 11" 5 K BOP Stack on the Sub- Structure Stump. Nordic 3 released 06:00 hrs on 3- 11 -12. • Page 6 of 6 • • Car~d~oP~~ps Time Log & Summary. YYe!lvlew Yreb Repartirrg - ~ \e p o r~ Well Name: 1C-109 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: .8/18/2008 12:00:00 PM Rig Release: 8/21/2008 12:00:00 PM ~ Time Logs Date From To Dur S. Depth E Depth Phase Code Subcode T Comment _ _ _ _ ___ - -- - - - - 8/06/2008 24 hr Summary Release Nordic Rig 3 from 1C-135 @ 23:59 hrs oh 8-5-08. Move Nordic rig3to 1C-109. MIRU andberm up: Accept rig. and Pull BPV. Open up well and Circ w/ seawater and kill well, no losses. Install BPV and ND Tree and NU BOPE. Test BOPE 00:00 01:30 1.50 MLRU MOVE MOB P Set Mats and Move Nordic Rig 3 in to 1 C-109.. MIRU MOVE Accept Nordic Rig 3 @ 01:30 hrs on 8-6-08 _ 01:30 02:30 1.00 MIRU MOVE RURD P Spot rig over well and Set down on mats. Berm u . 02:30 04:30 2.00 COMPZ RPCOM OTHR P Lubricate out BPV, Tie in circulating lines to Tree. Open up well SITP 450 _ 04:30 i I ! 05:00 0.50 COMPZ RPCOM SFEQ P si; SIIAP_500 sp i. ~__ PTsurfa^e lines. 05:00 08:00 3.00 COMPZ WELCTL CIRC P Circulate well w/ 285 bbl of 6% KCL SW, 2 b m 280 psi. No losses 08:00 09:00 1.00 COMPZ RPCOM OWFF P Monitor well for 30 min. Blowdown _ lines. _ 09:00 11:00 2.00 COMPZ RPGOM PULD P PJSM, load ESP equipment with crane 11:00 12:00 1.00 COMPZ RPCOM OTHR P RD cellar lines, set BPV 12:00 18:00 6.00 COMPZ RPCOM NUND P ND tree, install test plug into ha^.ger. I PJSM, NU ROPE. CO upper pi :e rams to 2-7/8" x 5-1,2" variables. 18:00 00:00 6.00 CONIPZ WELCTL BOPS P PJSM, pressure test ROPE 250/3000 psi, annular 250/2500 psi. 24 hr Notification was giveri @ 1900 hrs and return call was @ 1910 hrs on 8-5-08. Jeff Jones asked for 2 hr notice prior to conducting BOPE Test. Update was given @ 1600 hrs on 8-6-08. Test was not witnessed b AOGCC Re . 8/07/2008 Continue to pressure test BOPE 250/3000 psi, annular 250/2500 psi. 24 hr Notification was given @ 1900 hrs and return call was @ 1910 hrs on 8-5-08. Jeff Jones asked for 2 hr notice prior to conducting ROPE Test. Update was given @.1600 hrs on 8-6-08. Test was not witnessed by AOGCC Rep. Pull blanking plug and BPV. Install ISO sleeve and Landing jt. Unland hanger -Pull allowable Maxon 4.5 _ tbg, Circ. 50 bbls of hot diesel followed by 160?seawater, no losses. Work stuck pipe free. RU ESP equip. and POOH w/ ESP decom letion, `Page 1 af'3 • • Time Logs - - - __ _ _ __ _- Date.. , From Te ._ Dur S. De th E De ±h Phase . .Code ~'„bcode T Comment 00:00 01.:00 .1.00 _ _ _ COMPZ WELCTL BOPE P PJSM, pressure test BOPE 250/3000 psi, annular 250/2500-psi. 24 hr Notification was given @ 1.900 hrs. and return call was @ 1910 hrs on 8-5-08. Jeff Jones asked for 2 hr notice prior to conducting BOPE Test. Update was given @ 1600 hrs on 8-6-08. Test was. not witnessed b AOGCC Re . 01:00 02:30 1.50 COMPZ RPCOM OTHR P Pull Blankirig plug, Pull BPV, Install. .Isolation sleeve. MU Landin Jt. 02:30 03:00 0:50 COMPZ RPCOM SFTY P Held PJSM w/ rig crew, LRS, Vetco Gra and Centrilift. 03:00 03:30 0.50 COMPZ RPCOM SFEQ P PT Tine to Tiger Tank to 1,000 psi. PT CMT line and LRS to 2,500 si. 03`.30 04:00 0.50 COMPZ RPCOM OTHR P ' Upland hanger @ 180kand pull to 200k w/ 44" of stretch. Continue to - maintain 200k while circulating, no losses. 04:00 07:00 3.00 COMPZ RPCOM CIRC P Circulate w/ 50 bbls 130? Diesel @ 2 bpm @ 620 psi followed by 160? seawater @ 2 bpm - w/ 18 bbls seawater away pressure declining. Continue to circulate diesel from wel( bore to tiger tank, no losses. RD hoses, blow down kill tank lines. 07:00 08:30 1.50 COMPZ RPCOM OTHR P PJSM. Pull up 200K, establish circulation down the tbg and up the IA 6 bpm @ 340 psi. Stop pumping, close annular, pump down the tbg and pressure. up tubing and fA to 2000 psi. Dump pre-sure from the ~ IA side. Open annular and pull up 15', a wt 110K. 08:30 00:00 15.50 4,297 0 COMPZ RPCOM PULD P Monitor well. RU ESP cable arid heat trace sheaves; Pull hanger to the floor and lay down. POOH with. 4-1/2" completion. Stand. back 4-1/2" completion. Clamp count pulled: 18 x Single .Channel xcplg clamps, 96 x Dual Channel xcplg clamps, 46 x 2' Mid jt Dual Channe(xcplg clamps, 27 x 3' Midjt DuaLChannel xcplg clamps, 25 x 4' Mid jt Dual Channel xcplg clamps, 445 x 5' Mid jt Dual Channel xcplg clamps, 3 x ESP Protectrolizers, 2 x Flat Guards. ESP Feild' report -Top pump spun, Bottom 2 did not. Tandem seal section was pressurized, ESP Cable Checked good. Motor was grounded w/good oil in bottom and no oil @ to . Page 2 of 9 • • Time Logs I--_ ___ ~ Cate From To Dur S Depth E. Death Ph ase Code b ~l~c~da T '~ ~zTnent- - - - 8/08/2008 24 hr Summary _ Clear and clean rig floor and pipe shed. PU and Rih w/ 3 1/2 mule shoe on 3 1/2 IBT and xo to 3 1/2 IFDC's followed by 3 1/2 DP to 4,252' and begin washing down @ 6 bpm @ 570 psi and reverse circulating @ 5 bpm 480 psi: Wash down to 4;628': and reverse circulate and sweep hole w/ hi vise sweep to clean well bore of :fine silt sands. Total losses to well bore toda was 847 bbls. Total losses to date 847 bbls: 00:00 03:30 3.50 0 0 COMPZ RPCOM OTHR P Box and send out all cannon clamps,. wrap spools w/absorb and shrink wrap,- prep for shipping:.. Clean and clear rig floor. Prep for mule. shoe clean out run: 03:30 05:00 1.50. 0 477 COMPZ RPCOM RURD P PJSM w/.rig crew on picking up and Rih w/Mule shoe clean out string, set wear bushin . CO floor to DP 05:00 10:30 5..50 477 3,481 COMPZ RPCOM TRIP P PU drill collars and RIH'to 47T. RIH with 3:5" DP from 47T to 3481'. Up wt= 75K, do wt = 65K. 10:30 12:30 2.00 3,481 3,481 COMPZ RPCOM RURD P Crane arrived PJSM, remove ESP cables ooler/e ui merit. 12:30 13:30 1.00 3,481 4,252 COMPZ RPCOM TRIP P Continue RIH w/ 3.5" DP from 3481' to 4252'. Up wt = 100K; do wt = 75K. 13:30 ~ 16:30 3.00 4,252 4,478 COMPZ RPCOM FCO P Wash down from 4252' to 4478'. Up wt = 100K, do wt = 75K. Girc at 6 ' ~ bpm @ 570 psi, rev circ at 5 bpm @ 480 si. 16:30 18:00 1.50 4,478 4,513 COMPZ RPCOM FCO P Tagged at 4478'; washed thru from 4478' tr, 4481', start losing fluids. rev circ at 5 bpsn @ 170 psi, no returns. RIH, wash down to 4513' at 6 bpm. Returns back to surface at 1:2 ratio. Circulate bottoms up to circ out gas. Return ratio,gradually _ ircreased from 50% to about 90%. _ ___ _ 18:OU 00:00 6.00 4;513 -4,628 COMPZ RPCOM FCO ~ ~ P Continue to wash down f/ 4,513' to 4,455' and set down in CMU in "D" Lat. Pull up above Hook @.4;493'. Wash down and entered Mother bore and wash to 4,628'..31' inside "B" Lat. liner. Circulating @ 6 bpm @ 580 psi and reverse circulating @ 6 bpm @ 550 psi. Reverse circulate, Pump and chase hi vise sweep to assisfin cleaning fine sands from well bore. Total losses to well bore today was 847 bbls. Total losses to date 847 bbls: 8/09/2008 Blow down TD and. Pooh w! C/O assy: RIH w/ Lateral nozzle assy and wash to 4,635'-and POOH.. RIH w/ LEM Dummy assy to 4,280'. Total losses to well bore toda was 716 bbls. Total losses to date 1,563 bbis. 00:00 02:30 2.50 4,628 478 COMPZ RPCOM TRIP. P Pooh f/ 4,628' to 478'. 02:30 03:30 1.00 478 0 COMPZ RPCOM PULD P Stand back DC's and lay down 3 1/2 - IBTM mule shoe ass . Page3of9 ~ i Time Logs ~ - - - _ _ - Dale From To Dur 5. Derath E. ~De ftE Phase C~~e Subco~e T Coromenf __ _ _ _ ~~ 03:30 04:00 0.50 - COMPZ RPCOM OTHR P Load and bring BHA equipment to rig floor - 04:00 04:30 0:50 COMPZ RPCOM BFTY P Held PJSM w/ Baker and Rig crews 04:30 08:00 3.50 0 470 COMPZ RPCOM PULD P PU and MU Lat nozzle asst'. Swap floor equipment. ,RIH with Nozzle, SB locator, lateral wash nozzle, Jars, DC and um out sub. 08:00 10:00 2.00 470 4,490 COMPZ RPCOM TRIP P RIH w/ 3-1/2" DP to 4490'. Up vrt = 105K, do wt = 75K. Pump DP volume. 10:00 12:00 -2.00 4,490 ' 4,590 COMPZ RPCOM FCO P . Wash down to 4603' pumping 5 bprn @ 420 psi. Pressure increased to 500 psi (nozzle inside the SCR): Pumping 2 bpm @ 140 psi, wash down to 4635' pressure increased to 500 psi .(seal assembly into SCR). Sit down 10K at 4640' (seal locator on top of SCR). Circulating 5 bpm, PUH 12' got hung up. Needed to rotate DP to free pipe. POOH tp 4590'. 112:~~~ _ 13:30 1.50 4,590 4,590 COMPZ RPCOM CIRC P Circulate 2 annular vol. Bull head 40 ` ! ~ btal down the IA. 13:30 16:30 3.00 4,590 4,538 COMPZ RPCOM OTHR P POOH and hang up at 4538'. Try td rotate .and work DP, could not work free. Pumped 70 bbl of Safelube down the IA and spot accross the BHA: Able to rotate the DP free. 16:30 18:30 2.00 4,538 470 COMPZ RPCOM TRIP P POOH with 3-1/2" DP workstrin9 td . 470'. 18:30 19:00 0:50 470 0 COMPZ _ FtPCOM PULD P PGOH laying down Nozzle BHA 19:00 19:30 0.50 COMPZ RPCOM IS~TY rP~ Hefd PJSM w/ Sperry, Eaker and Rig crew on PU and MU of LEM dummy ass w/ MWD Tools. 19:30 2030 1.00 0 115 COMPZ RPCOM PULD P Load LEM tools to for LEM Dummy run and PU and MU the same. 20:30 21:00 0.50 115. 115 COMPZ RPCOM DHEQ P Shallow test MWD @ 50 spm @ 120 - 480 si. 21:00 00:00 3.00 115 4,280. COMPZ RPCOM TRIP P RIH w/ LEM dummy asst' to 4,280'. Total losses to well bore today was 716 bbls. Total losses to date 1,563 bbls. 8/10/2008 Continue to Rih w/ LEM dummy asst' -not able to latch. up as of fill, Pooh and change tail length: Parted below orient lug. Rih and fish out Parted TBG. RIH w/ string mill asst'. Total losses to well bore toda was 594 bbls. Total losses to date 2,157 bbls. 00:00 02:00 2.00 4,280 4,582 COMPZ RPCOM TRIP P Continue toRIH w/singles f/ 4,280' to 4,582', Unable to get down w/ LEM, Bullhead 22 bbls @ 5 bpm @ 360 psi and attempt to work through. Unable to et down to latch u . 02:00 04:30 2.50 4,582 115 COMPZ RPCOIVI TRIP P Pooh f/ 4,582' to 11:5' .Page 4 of 9 • • Time Logs __ ~~Gate From To Dur 5:, De th E. De th Phase Cuc7e SuGcooe ~ T Comrnant __ _ --- - - - - _ 04:30 .05:30 1.00 1.15 0 COMPZ RPCOM PULD P .Pooh w/ LEM BHA found o have parted last 7.79` of LEM below lug, 1 jt. 4.5" IBT 12.6# TBG, 1- 4.5" 16T 12.6# Bent jt w/ mule shoe: Leaving- 71' offish in thehole. Estimated'. TOF @ 4,511'. Top of,Hook Hanger 4,493', Bottom 4,511'. 05:30 09:00 3.50 0 0 COMPZ FISH WOEQ T Call out fishing tools to spear 4.5" 12.6 #IBT TBG. Clean floor, W.O.O., service T.D. W.O.T. 09:00 '11:D0 2.00 0 0 COMPZ FISH PULD P Load fishing tools. MU fishing BHA/S ear. 11:00 13:00 2.00 0 4,438 COMPZ FISH TRIP P RIH to to 4438'. Up wt = 93K, do wt 75K. 13:00. 16:00 3.00 4,438 4,470 COMPZ FISH FISH P RIH to 4540, sat down 10K to latch fish. PUH, up wt = 98K. PUH to 4512', hang up, worked free. PUH to 4501' and hang up. Unable to work ~ free. Pumped 70 bbl of Safelube and spot it across the fish. Worked free ar.d PUH to 4410' and hang up. ! I i Attempted to work free, but could not. Plt:..~:d'he strEn^ °nta '~~K ' tension and rotated to the right grid came free. POOH with u wt of 98K: 16:00 18:00 2.00 4,470 76 COMPZ FISH TRIP P POOH with 3-1/2" workstring. i 18:00 18:30 0.50 76 0 COMPZ hISH PULL P POOH laying down fish. All ~ recovered. _ ____ _ _ 18:30 19:30 1.00 0 66 COMPZ FISH PULD P Prepare to RIH w/ 5.5".Smooth OD string mill- PU and RIH w/ milling I BHA. -._ I { ___ _ _ "9:30 20:30 1.00 ' : 66 837 COMPZ ~=1SH _ STRIP i (P RIH to 83T _ - - ._._~.M_~_ 20:30 22:30 2.00 837 837 COMPZ~ ZIGMNT SVRG P PJSM, Cut and wlip Driil line, and service ri . 22:30 00:00 1.50 837 4,525 COMPZ FISH TRIP P Continue to RIH w/ milling asst'. 8/11 /2008 Dress Hook hanger, POOH. RIH w/ LEM Dummy #2, latch in & out to verify Top of Hook. POOH. RIH w/ LEM Completion asst'. Total losses to well bore toda was 537 bbls. Total losses to date 2,694 bbls. 00:00 02:00 2.00. 4,494 4,556 COMPZ FISH. MILL P Tag and Rotate through f/4,499't/ 4;503' and f/ 4,503' t/ 4,524' and ream back thru @ 50 rpm @2,220 to 5,100 ft/Ibs. @ 2 bpm @ 60 to 80 psi, Rot wt 83k @ 2,220.ft/Ibs free torque. up wt 95k do wt 73k Slide thru w/ 2k dra . 02:00 -04:00 2.00 4,556 66 COMPZ FISH TRIP P - Pooh w/dressing BHA. 04:00 05:00 1.00 66 0 COMPZ FISH PULD P POOH laying down dressing BHA. 05:00 06:00 1.00 0 0 COMPZ FISH OTHR P Unload all Baker fishing tools from i e shed and ri floor. 06:00 08:00 2.00 0 0 ' COMPZ RPCOM RURD P C/O muleshoe off bent joint, MU . straight joint, MU LEM and MWD tool. Swa handlin a ui ment. Page 5 of 9 • • Time Lo s ~ _ _ _ __ Date From Tu Dur 5: Ge Ur E De ih Pf~ase Code Subcoue T Cani~r~ent _- -- - __ 08:00 10:00 2.00 0 4,593 COMPZ RPCOM TRIP. P RIH to w/ 3-112" DP, shallow pulse test MWD at 850': Cont RIH to 4494', tagged top of hanger, PUH and rotate and work through. Up wt = 93K; do wt = 73K. Continue in hole. 10:00 12:00 2.00 4,593 4,443 COMPZ RPCOM TRIP P BHA depth at 4539",orientation 125R (pumping 3 bpm @ 400 psi). - - LEM tagged hooked with bottom of BHA at 4552 ;sat down 20K, orientation changed to 101 R. PUH (no over pull) to 4520' and rotate to 145L. RIH to 4552', sit down 24K, orientation changed to 25R. PUH 25K over pull) to 4519".and rotate to 112L. RIH to 4552', sit down 25K, orientation changed to 27R. PUH i 15K over ul! to 4443'. i 12:00 _ r ~ 30 2.50 4,443 470 COMPZ RPGOM TRIP P POOH with 3-1/2" DP, standing i back. _ __ ' 14:301 15.30 1.00 470 0 COMPZ RPCOM RURD P RD MV'dC~ tool, LEM and straight ioint. _ ---------_- . , ---_.~a _~ i5:30 17:30 2.00 0 0 COMPZ -- ' RPCOM __ _ ---- OTHR ~ P --_.- Lead pipe shed with LEM carnpletion 17:30 18:00 0.50 0 0 COMPZ RPCOM OTHR P Remove 4.5 bent joint from 18:00 20:30 2.50 0 190 COMPZ RPCOM PUI_D ~ ~ __ P com letion string _ _ PU and MU 4.5 completion string ~ below LEM. PUancMt.' LEM w! inner MWD stria . 20:30 .21:00 0.50 190 190 COMPZ RPCOM OTHR P~ Change over to I?P Equarrient. --- ~" ?.1:00 00:00 3.00 190 4,375 COMPZ RPCOn/1 TRIP ' P' RiH w! LEM Completion to 4,375' I ~___-- ~___ L~ __-__ 1 i 90k up wt 75k do wt. ~W- 8/12i'2008 Orient and latch in to hook and verify latch up: Set ZXP PKR and PT to 500 psi. Release off LEM completion and POOH LD DP. 00:00 01:30 1.50 4,375 4,604 COMPZ RPCOM PACK P Latch. LEM w/ 75k do wt and un latch f/hook w! 120k up wt. 20kosw. Set ZXP packer w/ 3,500 psi. Top PBR on Packer set @ 4,422', PT to 500 psi on IA. Seals stabbed into SCR-1 PKR 4,600'. 01:30 08:00 6.50 4,422 0 GOMPZ RPCOM TRIP P POOH laying down DP 08`00 10:00 2.00 0 0 COMPZ RPCOM RURD P C/O floor equipment, LD MWD and running tool, pull wear bushing,. unload i eshed 10:00 11:00 1.00 0 0 COMPZ RPCOM PULD P PU MU seals and completion e ui meat. 11:00 13:00 2.00 0_ 4,425 COMPZ RPCOM RCST P RIH o 4425' with seals and 4-1/2" tubing completion: Up wt = 82K, do wt = 72 K. Page 6 of 9 • • Time Log s _- Da#e From To Dur 5. De tla l=. D ih :Phase Code Subcudc T Con~nzer,t 13:00 16:30 -- - - 3.50 4,425 COMPZ RPCOM HOSO P Tag-at 442T:(ihside the ZXP packer). - -- Needed to rotate string several times and bump down to get past the ag. No go at 4444'. PUH o 4415', RiH and tag again at 4427 and worked through. No go at 4444`, sit down 20K Pressure up IA to 500 psi, strip up through the annular 11' before IA pressure dropped' off. PUH arid run s ace out u PU MU han er: 16:30 22:30 6.00 ` COMPZ RPCOM FRZP P Circ 115 bbl of diesel down the 1A-for freeze protect prior to landing the hanger for freeze protect. Bullhead _ 65 bbl of diesel down the tubing to balance the well and far freeze protect: Needed to allow'the IA and tubin to u-tube and bled ressure. 22:30 00:00 1.50 COMPZ RPCOM HOSO P Set seal assembly in SBE, rigged up ( and tested IA x tbg at 00 psi for 10 f minutes. Test good. Drained stack ~ and landed 4-1/2" completion, RILDS. U^ wt 82K, dwn wt 72K. 8/13/2008 ~.. -- __ _ ND BO's, NU tree and tested, installed BPV, released Nordic 3 rig at 12:00 hrs 8-13-G$, RUMO 1C-109. 00:00 00:30 0.50 COMPZ RPCOM SFEO P Tested upperand lower hanger seals of 250 and 5;000 si. Test ood. 00:30 1, 09:00 i 8.50 COMPZ RPCOM NUND~ P instal; TWG ND 135/8" ROPE. NU -- ~-- ~ tree _ ~ v~: (? 10:00 1.00 COMPZ RPCOM SFEQ ~ P Test void to SUOJ psi, test tree to ~ 5000 si 10:00 12:00 2.00 COMPZ RPCOM __ RURD P Lubricate out TWC. Install BPV. Release rig at 12:00 hrs. Tbg press = i ~s/1~/20~8 S ~\ S~r~cc~~pp ~~~ 7 ' d , set BPV, 6 r Rig 3 onto 1C-109 on 8/18/200 @ 12:00 noon, pulled SOV fr m GLM#1 @ 43 Accepted Nor removed scaffolding, layed liner, double-stacked rig mats on 1C-109, positioned rig overwell, bermed up cellar, RlJ lubricator and pulled BPV, RU hardline to kill tank, tested same at 120psi air and 500 psi water, loaded its with 8.8 6% KCL sea water. 12:00 20:00 8.00 0 0 COMPZ RPCOM WOEQ X Accepted Nordic 3 rig @ 12:00 hrs 8-18-2008. Waiting on concentric coil to mob off well location, slickline to pull SOV from GLM#1 @ 4376', set .BPV, remove scaffolding, lay liner,: _ double stack ri mats on 1 C-109. 08:.00 10:00 2.00 0 0 COMPZ RPCOM OTHR P Ramp up'and position rig over"well, berm u cellar. 10:00 11:00 1,00 0_ 0 COMPZ RPCOM OTHR P RU lubricator and pull BPV." 11:00 12:00 1.00 0 0 _ COMPZ RPCOM RURD P RU hardline to kill tank, test-same at 120 psi with air and 500psi with - water, load pits with 8.8 pP9 6% KCL sea water. 8/19/2008. ND tree, NU and tested BOP, start decompletion 4 1/2" service string. 00:00 01:00 1:00 COMPZ RPCOM CIRC P RU circ lines and pumped.220 bbls down lA taking Yeturns through tbg, 8.8 ppg 6% KCL seawater at 5 bpm. - ICP 210 si, FCP 130 si. Pa~~ 7 of 9 • • Time Logs _~ Da#s From To Dur S._De_th_E._De th Phase_ Code _ -Suucoie T _ Coaunent -- _ _ P ~ G 1:00 - 01:30- _ 0.5'1 _ COMPZ RPCOM OWFF P Shut in and monitor well: No pressure; flushed hardline with°10 bbls fresh waterand-blew down hardline to kill tank,.RD circlines. 01:30 .02:00 0.50 COMPZ RPCOM OTHR P Installed BPV. 02:00 03:00 1.00 COMPZ RPCOM NUND P ND tree and hang off in Cella[. 03:00 "11:00 8.00 COMPZ RPCOM NUND T Dressed inner hanger-neck, installed 4:909" test dart, NU 13 5/8" BOP and function test. Leaking around wellhead flan e. 11:00 14:30 3.50. COMPZ WELCTL BOPE T- ND stack at wellhead flange. Inspect ring gasket and found wo bad spots. Inspected wellhead groove and spool groove. Cleaned and replaced BX 160 rin asket. NU BOPE a ain. 14:30 19:00 4.50 COMPZ WELCTL BOPE P Test BOPE 250/3000 psi. Testing withessed by John Crisp (AOGCC), remove test dart and BPV. 19:00 120:00 1.00 COMPZ RPCCUM RURD P Install isolation sleeve in hanger, MU landin ~nt and head in, BOLD's. 20:00 j 21:00 1:00 COMPZ ~ RPCOM CIRC P .Pull hanger to floor, 82K up wt, and i i break circ staging up to 3 bpm 60 psi, never got returns, after hole fill and attempted circ -lost 133 bbls, shut down um s. ~ 21:00 22:00 1:00 COMPZ RPCOM RURD P RD circ lines and head pin, LD ~ 22:00 00`00 2.00 4,372 1,491 COMPZ RPCOM TRIP P landing jnt and hanger. POOH with 49/2" NSCT service string from 4,372' to 1,491' standing back tubing. Drifted and strapped ~ while standing back. Total fluid loss = 249 bbls for last 24 hrs. - __ ~8i20/2008 RU and RIH with 4 1/2" ESP completion to 4;272', cut cables and spliced to connectors. 00:00 02:00 2.00 1,491 0 COMPZ RPCOM TRIP P font POOH with 4 1/2".service sfring standing back and drifting NSCT, LD IBT, mandrel arid seal assembl . 02:00 03:30 1.50 0 0 COMPZ RPCOM RURD P Ru to run ESP on 4 1/2" NSCT, load um com a onents. 03:30 D9:30 6.00 0 3,032 COMPZ RPCOM RCST P PU motor centralizer, Guardian _ sensor, and motor Serviced motor. PlJ Tandem Seal Section and service, RU cable over sheave ahd secure motor lead. MU TTC Xover/intake. RIH with 4 1/2" - completion, installling Phoenix MS-2 gauge and splice into TEC wire, as . per procedure & tally, performing electrical inspectionsltests on cable 8ve 1000'. 09:30 21:00- - 11.50 3,032 4,240 COMPZ RPCOM RCST P Start Heat Trace. @ approximately 3032'. Continue RIH w/ESP Completion, performing electrical inspections/tests on cable every 1000': Page 8 of 9 • • Time Logs _ _ _ =Date i=€oiz~ To Dur S. Dzpth Suhcodo `a Rhase Code E_>De~t~ T Gcr,ment - .21:00 .22:00 _ 1.00. 4;240... - .4,273 COMPZ RPCOM OTHR P PU and MU hanger and landing joint,. orient hanger and RIH, install enetrators: 22:00 00:00 2.00 4,273 4,273 ' COMPZ RPCOM OTHR P Cut cables and splice to pigtails, finish installin clam s. 8/21 /2008 RDMO 1C-109 and move rig onto well 1C-184. 00:00 01:30. 1.50 4,273 4,315. COMPZ RPCOM RCST P Install.cable ends onto penetrators, land hanger up wt 105K - down wt 75K, RILD's, test upper and lower body seals at 5,000 psi. for 90 minutes. 01:30 02:00 0.50 4,315 4,315 COMPZ RPCOM PULD P LD landing jnt, remove isolation sleeve, set TWC. 02:00 04:30 2:50 4,315. 4,315 COMPZ RPCOM NUND P PJSM, ND 135/8" BOP and check cable integrity, phase to phase and phase to ground resistivity, and me er heaY trace to 2500 Vdc. 04:30 07:00 2.50 C.OMPZ RPCOM NUND P PJSM, NU tree and test 250 / 5000 si 07:00 08:30 1.50 COMPZ RPCOM NUND P PU Lubricator and pull TWC. 08:30 ~ 10:00 1.50 COMPZ RPCOM' FRZP P RU LRS & freeze protect w/ 96 bbls diesel dawn IA & 53 bbls diesel down tubin . 10:00 12:00 2.00 COMPZ WELCTI OTHR P RU Lubricator and set H-BPV. Clean location. RDMO. Released Nordic 3 h 1200 hrs on 8-21-08. Page 9 cif 8 • • Well Service Report 10228966 BJSvcs ~ RICHARDSON !Initial ~ iINITIAL T/U0= 0\0\0 ~ Final Field: WEST SAK ;Pressures: FINAL T/I/0= 0\0\0 ~ j Move to 1C. MIRU. BOPE test. Install BHA • • Well Service Report ;7-.. a -~i'~; ~ is ~i 1 C-109 Drilling Support - Exp WO Freeborn, Mike 8/16/2008 ! 195 `, ,,~~.~ „~q t.~ ~ ~, ~ ~, - ~ t ~ ~ ~ ' .,~~ , ~~- . ~,. t ®- - a~~; ~ -~ m~ ~s f~ s o - ~~ .. _ - 10228966 ; BJSvcs RICHARDSON jlnitial8~ (T11\O 0\0\200 T\I\O ~~ ~ ~~~ ~ ~~ ~~ ~ Final ~ `Field: WEST SAK "Pressures: 0\0\200 Removed solids to 6,130' CTMD at which point coil became detained. POOH to change out BHA. Solids to surface have been minimal with fluid B ® 0 0 12:00 AM Continue to rig up on well. PT all surface equip to 2,500 PSI. RIH. SIWHP = 0 PSI. DWN WT = -2,000#. Bring pumps on line to .6 BPM to 01:45 AM ensure sandvac is operational. Once confirmed lowered rate to 3.3 BPM for RIH. Divert all returns to opentop tank due to diesel in well bore. 02:45 AM Current depth = 4,000'..48 BPM @ 4,748 PSI CTP. RIH @ 9 FPM until we enter liner. Up WT = 14K. DWN WT = 7,200#. Continue to RIH for FCO. WT CK @ 4,700' CTMD Up WT = 18,000# .5 BPM @ 4,639 PSI CTP. 0 WHP. 03:45 AM DWN WT = 8,500#. PUH 100'. RBIH taking 100' BITES. Heavy gas in returns ith no sand 11.9 sec bucket. 04:45 AM Currently @ 4,900'CTMB, pump rate .48 WHP 0 psi CTP 4860 psi. Bucket test 12 seconds with no sand or gas in returns. 06:00 AM Crew change & TGSM Currently @ 5,300'CTMD. Conttnue to take 100' bites. Up weight 23,000# Dn 06:30 AM eight 8,500#. Over last five hours bucket test between 12-14 seconds. Increased pump rate to .53 BPM WHP 0 psi CTP 5,300 psi. Very little sand in returns. Bucket test rate starting to creep up to 15-17 seconds. Currently @ 5,750"CTMD. Pump rate .53 BPM WHP 0 psi CTP 5350 psi. 11:30 AM Bucket test remain 15-17 seconds. Return rate .42 BPM, very little sand in retairn.~, screen~u maybe plugging ofF. 02:30 PM ttempt to troubleshoot low return rate. 03:30 PM Continue in hole. Currently @ 5845'CTMD tagged up. PUH heavy (31,000#) • • Well Service Report 1 C-109 'Drilling Support - Exp WO Freeborn, Mike . .. _ . ,~, ~ F~` ~•~a ~F~~ ~ a~ ,~ , s µ r: 8/17/2008 ! - ~ 195 - ~-- -- - a ~ s. ~ 10228966 I. BJSvcs RICHARDSON Initial ~ - ;r- .~_ - -~-- IFina1 ! ~Fieid: ;WEST SAK Pressures: !Pulled OOH to change BHA. No damage to tools witnessed. Struggled with ;return rate earlier in the day. Currently at 6,800' CTMD making progress. Solids content mild. a ® a a ~; 12:00 AM Continue to POOH for tool swap. OOH with leak on HP side of reel. Repair. Pull off well inspect BHA. BHA 01:00 AM packed full of fine sand paste. Intake still clear, but rest of screan packed off. Swap BHA after purging coil at high rate. Currently struggling to latch hydro con. Installation of new bottom hole 04:00 AM assembly is complete along with function test. PT all surface equipment of 2,500 PSI. Prepare to RIH. 06:00 AM Crew change & TGSM 06:30 AM Start in hole at 30' FPM. Weight check @ 3,100'CTMD 15,000#. Currently @ 4,720'ctm, pump rate .50 BPM WHP 0 psi CTP 5430 psi. Bucket 08:30 AM test started out at 12-13 seconds, but last few have been 18-20 second bucket est. Spent last three hours trouble shooting plugged intake screens, cut pump rate 10:00 AM o min. rate, till loss of returns occurred, fluid would fall out of annulus and clear intake screens, but only temporarily. Tried this several times at different depth with only temporary success. Shut down pump and shift tool to jet mode. Start in hole to 5,100' CTMD then 01:00 PM PUH to 4,800'CTMD. Shift BHA back to sand vac mode, same results, emporarily able get 12-13 second bucket test, then back to 20 second tests. Increase pump rate to .58 BPM, start back in hole. Currentiy @ 6170'CTMD. Over cast three hours, increased pump rate to .58 02:30 PM BPM WHP 0 psi. CTP 5950 psi. Bucket test 16-17 seconds with trace to 2tbls sand per test. Up weight 24,000# Dn 5,850#. Continue in hole @ 1-2 FPM • • 10,000# over last weight check. Pump rate .52 BPM WHP 0 psi CTP 5430 psi. Bucket test bouncing around from 13-18 seconds. Very little to no sand in returns. 05:30 PM Crew change & TGSM 06:00 PM 5,960' CTMD DWN WT = 5,000#..5 BPM @ 5,890 PSI. Up WT = 24,000#. Was able to make to 6,153' before becoming detained. Up WT went as high as 40K. PUH to 4000' to purge coiled tubing. At 2355 hrs. informed BJ to 08:00 PM POOH for tool change. Do not feel good with fluid loss at this time. Well appears to be drinking water assisting in differential sticking. Will see with new ool. ~ • Welt Service Report ~,. ®. ~~ Tagged TD at 7,480.1' CTMD in 100' increments @ 04:12AM..57 BPM @ 12:00 AM 5,853 PSI 15 SEC bucket checks. lil to no sand. 0 PSI WHP. Prepare to PUH at 10 FPM UP WT = 20,233# Plan is to puh @ 10 fpm TO 7,100' ctmd then pick up speed to 100 FPM to. 04:00 AM Currently at 4,600' CTMD comming OOH at 10 FPM to 4,200' Then let er rip! 06:00 AM Crew Change & TGSM 06:30 AM On surface with coil. Pump 70 bbls diesel down tubing for freeze protectioon. Close swab. Rack back injector/lubricator, lay down BHA, purge coil, remove BOPE from 08:15 AM ellhead and rack back. Note: During BHA disassembly metal shavings were removed from screen,sand intake, and throat. 10:00 AM Secure wellhead. Rig down BJ/MI surface equipment for move to 1C-135. Notified DSO of well status and departure. End ticket. , , ~ A o @.1 ~g P7. 3 ~° ,~ SEAWATER. SLICK 100 FRW-14 DIESEL 70 TBG ~ A aking 50' bites. 05:30 PM Crew change & TGSM Currently at 6,800' CTMD. DWN WT = 4K. Pump Rate = .59 BPM @ 5,995 06:00 PM PSI CTP. Bucket checks = 14-15 sec. 0 WHP. Up WT normal so far. Light sand in returns. Just not enough toget excited about. Up WT = 23K. e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc fí k, DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Permit to Drill 2012040 Well Name/No. KUPARUK RIV U WSAK 1 C-1 09L 1 Operator CONOCOPHILLlPS ALASKA INC j'r~ II aJr N-H.J API No. 50-029-23047-60-00 MD 7525 ..- TVD 3734 ,- Completion Date 11/10/2001'- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~-(::-~'-~- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) ~-""1 Log/ Data Type "'lED Electr Digital Dataset Med/Frmt Number Name C ¿"'-11412 k~ C~ ~ il 'i It Log Log Run Scale Media No 1 Interval Start Stop 120 7525 OH/ CH Received Comments Open 12/6/2002 Digital WeilLogging-Oata-i '1 Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity +eï) D í ~ '-1"6643 120 0 7470 Open 3/4/2002 10466 Open 3/19/2003 Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments Well Cored? ADDITIONAL INFORMATION yQ £""-. Daily History Received? 0/N {JJ/N Chips Received? ~ Formation Tops Analysis Received? ~ Comments: ~ Date: --~ ia -ij~~~~-ò=:-/n (' aO/"dOC¡ t ('lId WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 22,2001 RE: MWD Formation Evaluation Logs: 1C-109 L1, AK-MM-11171 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 lC-109 Ll: Digital Log Images 1 CD Rom RECEIVED DEC 06 2002 Alaska OH & Gas Cons. Commission Anchorage i ( ( WELL LOG TRANSMITIAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 26, 2002 RE: MWD Fonnation Evaluation Logs lC-l09 Ll, AK-NlM-11171 1 LDWG fonnatted Disc with verification listing. API#: 50-029-23047-60 a 0 ¡...aoLJ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speay-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Signa 'ú.. QpQ~ RECEIVED r. ~ ~ r) ("t . r'\f\O? . : ,:.. ~.. U ¡: " "II h \. ... "¡~.., '-a. Alaska Oil & Gas Cons. Commission Anchorage I" . ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil 0 Gas D 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Sox 100360, Anchorage, AK 99510-0360 4. location of well at surface Suspended D Abandoned D Service D .- tOeA ftö"ÑŠ- Y~f II2£) ~.--~ ~u~ ~'. ~ A'!Iln~ . .~~ 7. Permit Number 201-204 8. API Number 50-029-23047-60 9. Unit or lease Name 1487' FNL, 699' FWL, Sec. 12, T11N, R10E, UM At Top Producing Interval . " 1378' FNL, 220' FEL, Sec. 11, T11N, R10E, UM ~ ..LL::j~"..()(, (ASP: 560786, 5968848) ~~:~:~~P:O, FEL, Sec. 11, T11N, R10E, UM L'~-=-=.: (ASP: 560803, 5965821) 5. Elevation in feet (indicate KB, DF, etc.) 6. lease Designation and Serial No. RKS 40' ADL 25649 ALK 467 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. October 17, 2001 November 1,2001 November 10, 2001 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 7525' MD 1 3734' TVD 7525' MD 1 3734' TVD YES 0 No D 22. Type Electric or Other logs Run GR/Res, CCL 23. , ' (ASP: 561706, 5968747) Kuparuk River Unit 10. Well Number 1 C-1 09L 1 11. Field and Pool West Sak Oil Pool Kuparuk River Field 15. Water Depth, if offshore 16. No. of Completions NI A feet MSL 1 20. Depth where SSSV set 21. Thickness of Permafrost N/A feet MD 1905' ,. -r- / Jft/ "., .i.r-,ù V'I9.( Mð CASING SIZE 16" WT. PER FT. 62.5# 29.7# 12.6# GRADE H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 158' Surface 4938' 4493' 7512' HOLE SIZE 24" CEMENTING RECORD 282 sx AS 1 519 sx AS III Lite, 262 sx Class G wI GasBlok Slotted screen AMOUNT PUllED 4.5" 9.875" 6.75" 7.625" 4.5" TUBING RECORD DEPTH SET (MD) 4306' PACKER SET (MD) N/A 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE Open Hole 4.5" Slotted Liner Completion from 7453' - 4593' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 12/10/2001 5 hours Flow Tubing Casing Pressure press. 326 psi not available 28. Production for Test Period> Calculated 24-Hour Rate> PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing - sharing production volumes from 1C-109L 1 Oll-BBl GAS-MCF WATER-BBl CHOKE SIZE 147 1 10 100 Oll-BBl GAS-MCF WATER-BBl Oil GRAVITY - API (corr) 676 24 47 not available CORE DATA GAS-Oil RATIO 35 27. Date First Production December 4, 2001 Date of Test Hours Tested Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A JAN 0 9 2002 Alaska Oil & Gas Cons. Commission - Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate OR\G\NALRBDMS BFl "~JAN 10 2002 29. .' ~. GEOLOGIC MARKERS 30. ( FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME West Sak D West Sak Base 4486' 7525' 3737' 3734' Annulus left open - freeze protected with diesel. 31. LIST OF A IT ACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. S;gned ~ wfl2-'-v\, T~e Drimna Ene;neerina Suaerv;sar C. Mallary 11 V Questions? Call Steve McKeever 265-6826 Date 9 F4L- 0;;2.., 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 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate IInonell. RECEiVED Form 10-407 JAN 0 9 200Z (JF~lG¡I\~AL Alaska on & Gas Cons. CommisSion Äncnoraqe (" ( Page 1 of 10 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 1 C-1 09 Common Well Name: 1 C-1 09 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 245 Date From - To Hours Code Sub Phase Code 10/16/2001 22:00 - 00:00 2.00 MOVE MOVE MOVE 10/17/2001 00:00 - 03:30 3.50 MOVE OTHR MOVE 03:30 - 12:00 8.50 WELCTL NUND SURFAC 12:00 - 13:00 1.00 WELCTL SFTY SURFAC 13:00 - 14:00 1.00 WELCTL NUND SURFAC 14:00 - 15:00 1.00 WELCTL BOPE SURFAC 15:00 - 16:30 1.50 WELCTL OTHR SURFAC 16:30 - 17:00 0.50 DRILL PULD SURFAC 17:00 - 19:30 2.50 DRILL PULD SURFAC 19:30 - 20:00 0.50 WELCTL SFTY SURFAC 20:00 - 21 :00 1.00 DRILL CIRC SURFAC 21 :00 - 00:00 3.00 DRILL DRLG SURFAC 10/18/2001 00:00 - 01 :00 1.00 DRILL DRLG SURFAC 01 :00 - 01 :30 0.50 DRILL SURV SURFAC 01 :30 - 04:00 2.50 DRILL DRLG SURFAC 04:00 - 05:00 1.00 RIGMNT OTHR SURFAC 05:00 - 06:00 1.00 DRILL TRIP SURFAC 06:00 - 08:00 2.00 RIGMNT OTHR SURFAC 08:00 - 10:30 2.50 RIGMNT OTHR SURFAC 10:30 - 11 :00 0.50 DRILL TRIP SURFAC 11 :00 - 15:00 4.00 DRILL DRLG SURFAC 15:00 - 00:00 9.00 DRILL SURFAC 10/19/2001 00:00 - 13:30 13.50 DRILL DRLG SURFAC 13:30 - 15:00 1.50 DRILL CIRC SURFAC 15:00 - 18:30 3.50 DRILL TRIP SURFAC 18:30 - 19:00 0.50 DRILL OTHR SURFAC 19:00 - 19:30 0.50 RIGMNT RSRV SURFAC 19:30 - 00:00 4.50 DRILL TRIP SURFAC 10/17/2001 Spud Date: 10/17/2001 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations Prepare and move rig from 1C-125 to 1C-109 ML. 240' away from CPM. Level rig. Align utility module with drill mod ule. Remove # 4 Lampson fl service. NU 13 5/8" diverter for multilateral well. Pre spud safety meeting with both crews and Company rep and tool pusher. Finish nipple up in cellar. Hook up cellar pu mp. Install valves on 4" on conductor. PU 7 5/8" landing joint, MU hanger and mark landing joint depth. Function test diverter system. PU wear ring and run in hole. Check setting depth. Function test accumulator. PU drilling tools to rig floor. PJSM. PU and MU BHA. Diverter Drill. Fill conductor. Check for leaks. Drill 9 7/8" surface hole fI 158'-280'. (122') Drill 9 7/8" surface hole fl 280' to 296' (16') ART=.25 hrs Run Gyro survey wI rig wireline machine. Drill 9 7/8" surface hole from 296' to 530' ( 234') ART 1.25 hrs. Work on discflo tank and pump. Trying to ge t pump to pump rocks and mud. Suction of p ump possibly plugged w/ gravel. Work to unp lug suction and get pump to pickup. Work dr ill string while trying to free up. Trip out to inside of conductor pipe to conti nue working on discflo tank/pump. Working on discflo tank/pump. Rocks pluggi ng up suction. Trip in hole, then trip out of hole to change sheave on Discflo pump, to run faster. Trip in hole to continue drilling 9 7/8" surfa ce hole. Directional drill 9 7/8" surface hole fl 530' t 0 1000'. (470') (TVD= 996') ART = .25 hrs AST= 2.85 hrs D ire c t ion a.1 d rill 9 7 I 8" sur f ace h 0 I e f I 1 0 0 0 ' to 1851'. (851') (TVD=1746') ART=1.45 hr s. AST = 3.75 hrs. Directional drill 9 7/8" hole fl 1851' to 3458 , (1607') (TVD = 3080') ART = 3.27 hrs. AST = 6.57 hrs. CBU, Monitor well, pump dry job. POOH. Check MWD. LID UBHA sub. Blow down top drive. Service rig and top drive. Trip back in hole wI bit # 1 RR & BHA # 2. W ork through hole fI (8xx-14 stands dp)1916' Printed: 12/12/2001 9:31 :38 AM (' .... ...... ~ (PHILLIPS) IW í Page 2 of 10 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: 1 C-1 09 Common Well Name: 1 C-1 09 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 245 Date From - To Hours .Code Sub Phase Code 10/19/2001 19:30 - 00:00 4.50 DRILL TRIP SURFAC 10/20/2001 00:00 - 12:00 12.00 DRILL DRLG SURFAC 12:00 - 20:30 8.50 DRILL DRLG SURFAC 20:30 - 22:00 1.50 DRILL CIRC SURFAC 22:00 - 00:00 2.00 DRILL TRIP SURFAC 10/21/2001 00:00 - 03:00 3.00 DRILL TRIP SURFAC 03:00 - 04:00 1.00 DRILL OTHR SURFAC 04:00 - 05:00 1.00 DRILL TRIP SURFAC 05:00 - 06:00 1.00 DRILL TRIP SURFAC 06:00 - 09:30 3.50 DRILL SURFAC 09:30 - 13:00 3.50 DRILL CIRC SURFAC 13:00 - 16:00 3.00 DRILL TRIP SURFAC 16:00 - 18:00 2.00 DRILL OTHR SURFAC 18:00 - 18:30 0.50 WELCTL OTHR SURFAC 18:30 - 20:00 1.50 CASE RURD SURFAC 20:00 - 00:00 4.00 CASE RUNC SURFAC 10/22/2001 00:00 - 04:00 4.00 CASE RUNC SURFAC 04:00 - 09:30 5.50 CASE CIRC SURFAC 09:30 - 11 :30 2.00 CEMEN~ PUMP SURFAC 11 :30 - 12:30 1.00 CEMEN~ DISP SURFAC 12:30 - 14:30 2.00 CEMEN~ RURD SURFAC 14:30 - 16:30 2.00 WELCTL OTHR SURFAC 16:30 - 19:00 19:00 - 21 :30 21 :30 - 23:00 2.50 WELCTL NUND SURFAC 2.50 WELCTL OTHR SURFAC 1.50 WELCTL OTHR SURFAC 10/17/2001 Spud Date: 10/17/2001 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations to 2421'. Rotate and circ through 2862+-'. Directional drill 9 7/8" hole fl 3458' to 4402 , (944') (TVD= 3704') ART = 3.52 hrs. AS T = 5.25 hrs. Directional drill 9 7/8" hole f/ 4402' to 4950 , (548') (TVD= 3808') ART = 3.23 hrs. AS T = 2.87 hrs. Circulate and condition mud and hole @ TD( 4950' MD=3808' TV D) fI 7 5/8" casing. PJSM. Monitor well, Pump dry job. POOH fl 9 7/8" hole opener. Tight @ 4,000' 3818' 3683' 3583'. Continue POOH wI BHA # 3 & Bit # 1 RR @ T D of 4950' MD (TVD=3808') SLM no correctio n. Download Sperry MWD. LID motor, bit, and MWD tools. MU 9 7/8" hole opener assmebly. BHA #3. RIH wI BHA # 3 (9 7/8" hole opener) for clea nout run prior to running 7 5/6" casing. Tigh thole @ 3844' to 3875'. Wash 115' to botto m. Circulate and condition mud and hole fl 7 51 8" casing. POOH wI hole opener. LID hole opener assembly. Pull wear bushing. PJSM. RU GBR to run 7 5/8" surface casing. PJSM. Run 7 5/8",29.7 #/ft, L-80, BTC Mod casing. %* joints in hole @ midnight = 2495' Run 55 joints 7 5/8" casing (58-113) to 493 8'. LID frank's fillup tool/, PU/MU hangr and landing joint. Circ and condition mud and hole for cement job. Recip pipe approx 8'. PJSM. Pressure test lines to 3500 psi. Ceme nt per program. Displace cement @ 6 BPM and 600 psi. Slow pumps to 3 bpm for last 20 bbls. Pump 232 5 strokes. Did not bump plug. Floats held. C IP @ 1225 hrs 10-22-2001 Rig down cement equip &, landing joint, Was h out stack. Rig up drilling bales and elevators. PU stan d of 4" HWDP. Attempt to set packoff. Bolts holding upper and lower parts together she are d. NID BOPE. Remove packoff through bottom of wellhead. Clean extended neck of 7 5/8" hanger, Exam ine packoff, clean inside of wellhead, Notic , Printed: 12/12/2001 9:31 :38 AM ( ( Page 3 of 10 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 09 1 C-1 09 ROT - DRILLING Nabors Nabors 245 Date Sub From - To Hours Code Code Phase 1.50 WELCTL OTHR SURFAC 10/22/2001 21 :30 - 23:00 23:00 - 00:00 1.00 WELCTL NUND SURFAC 10/23/2001 00:00 - 03:30 3.50 WELCTL NUND PROD 10/24/2001 10/25/2001 10/26/2001 03:30 - 06:30 3.00 WELCTL OTHR PROD 06:30 - 07:30 1.00 WELCTL OTHR PROD 07:30 - 13:30 13:30 - 15:00 15:00 - 19:30 6.00 WELCTL NUND PROD 1.50 WELCTL BOPE PROD 4.50 WELCTL BOPE PROD 19:30 - 20:30 20:30 - 21 :00 21 :00 - 21 :30 21 :30 - 00:00 00:00 - 04:00 1.00 WELCTL OTHR PROD 0.50 WELCTL OTHR PROD 0.50 RIGMNT RSRV PROD 2.50 DRILL PULD PROD 4.00 DRILL PULD PROD 04:00 - 06:00 06:00 - 07:30 07:30 - 13:00 2.00 DRILL TRIP PROD 1.50 DRILL TRIP PROD 5.50 DRILL DRLG PROD 13:00 - 13:30 0.50 DRILL CIRC PROD 13:30 - 14:00 0.50 DRILL OTHR PROD 14:00 - 15:30 1.50 DRILL OTHR PROD 15:30 - 19:00 3.50 DRILL DRLG PROD 19:00 - 20:30 1.50 DRILL CIRC PROD 20:30 - 22:00 1.50 DRILL FIT PROD 22:00 - 00:00 2.00 DRILL OTHR PROD 00:00 - 13:00 13.00 DRILL DRLH PROD 13:00 - 15:00 2.00 DRILL CIRC PROD 15:00 - 17:00 2.00 DRILL WIPR PROD 17:00 - 17:30 0.50 RIGMNT RSRV PROD 17:30 - 18:30 1.00 DRILL WIPR PROD 18:30 - 21 :00 2.50 DRILL CIRC PROD 21 :00 - 21 :30 0.50 DRILL CIRC PROD 21 :30 - 00:00 2.50 DRILL DRLH PROD 00:00 - 07:00 7.00 DRILL DRLG PROD 10/17/2001 Spud Date: 10/17/2001 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations ed gouges from flutted hanger being recip. 0 n off drill side of wellhead. Nipple down wellhead. Arrange for another w ellhead from warehouse. Nipple down wellhead. Remove from cellar. Check new packoff over extended neck of ha nger. Fit fine. Check fit of packoff in new w ellhead. Fit fine. Assemble new wellhead onto starting head. Torque lockdown screws. Test to 1000 psi. OK. Attempt to install packoff. Would only g 0 down 2.00" below top of wellhead with run ning tool. Calculated need to go to 2.90" to be on top of flutted hanger. loosen all lockdown bolts. Install pack off i n wellhead. NU BOP. RU BOP test equipment. Test BOP and choke manifold to 250 psi and 3000 psi. Install wear bushing. RD test equipment. Service top drive. PU BHA. MU bit. Orient. Upload MWD. PU BHA. Sh allow test MWD. RIH Run real-time GR log. Tag cement at 4336'. Drill hard cement to 4 835'. Continue running real time logs to 45 50' . Circ bottoms up. RU test equipment PJSM. MIT casing to 3000 psi for 30 min. Drill out through float equipment and shoe. Drill 30' new hole to 4980'. Circ hole clean. Change mud to Baradril-N system. Perform FIT. Max pressure 650 psi. Bled b ack to 400 psi. FIT MW=11.0 ppg Clean mud pits. DRLG F/ 4980' TO 6468' ART = 6.95, AST = 1 .5 Circ, Pump sweep around, Cond for wiper tri p. POOH to Shoe, No problems with trip. Service Rig & Top Drive RIH to bottom, No trouble. Circ Bottoms up, Change over to new mud. Perform PWD baseline test with new mud in h 0 Ie. DRLG f/ 6468' to 6752' ART = 2.55 hrs. Drill ahead from 6752' to TD at 7510' MD (3 Printed: 12/12/2001 9:31:38 AM ~' (l PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 1 C-1 09 Common Well Name: 1 C-1 09 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 245 Date From - To Hours Code Sub Phase Code 10/26/2001 00:00 - 07:00 7.00 DRILL DRLG PROD 07:00 - 09:30 2.50 DRILL CIRC PROD 09:30 - 10:00 0.50 DRILL SFTY PROD 10:00 - 13:30 3.50 DRILL WIPR PROD 13:30 - 14:00 0.50 RIGMNT RSRV PROD 14:00 - 15:00 1.00 RIGMNT RURD PROD 15:00 - 16:30 1.50 DRILL WIPR PROD 16:30 - 19:30 3.00 DRILL CIRC PROD 19:30 - 00:00 4.50 DRILL TRIP PROD 10/27/2001 00:00 - 00:30 0.50 DRILL TRIP PROD 00:30 - 02:00 1.50 DRILL TRIP PROD 02:00 - 03:30 1.50 DRILL PULD PROD 03:30 - 05:00 1.50 DRILL PULD PROD 05:00 - 06:00 1.00 CASE PULR PROD 06:00 - 06:30 0.50 CASE SFTY PROD 06:30 - 10:30 4.00 CASE PULR PROD 10:30 - 11 :00 0.50 CASE PULR PROD 11 :00 - 11 :30 0.50 CASE SFTY PROD 11 :30 - 12:00 0.50 CASE PULR PROD 12:00 - 12:30 0.50 CASE SFTY PROD 12:30 - 17:30 5.00 CASE PULR PROD 17:30 - 18:00 0.50 CASE RURD PROD 18:00 - 22:30 4.50 CASE RUNL PROD 22:30 - 23:30 1.00 CASE CIRC PROD 23:30 - 00:00 0.50 CASE RUNL PROD 10/28/2001 00:00 - 03:00 3.00 CASE RUNL PROD 03:00 - 04:30 1.50 CASE PTCH PROD 04:30 - 08:00 3.50 LOG RURD PROD Page 4 of 10 10/17/2001 Spud Date: 10/17/2001 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations 793' TVD). Pump 30 bbl Hi Vis sweep at 74 20' MD ART=2.25 AST=2.25 Pump 30 bbl Hi Vis sweep. Circulate and co ndition mud. PJSM - pulling pipe. Monitor well. Pump dr y job. Short trip to 4900' Service top drive. Slip and cut 80' drilling line. RIH to TD. CBU. Pump 30 bbl Hi Vis sweep. Change h ole over to new mud. Pump dry job. Trip out of hole and strap pipe. Drop rabbit Continue POOH to BHA. Strap pipe. Recov er rabbit. LID jars. Stand back DC's. Drain motor. B reak out bit. Bit grading is on 10/26/01 rep 0 r t. Download MWD. Stand back in derrick. LD motor. PJSM - Discuss pick up procedures. 24 jts 4-3/4" DC and 12 jts 4" HWDP. RU to run liner. PJSM - discuss liner running procedures. PU and run 4-1/2" slotted liner as per proce d u r e. PU sliding sleeve and 2 jts blank liner. Ver ify sliding sleeve is open. PJSM - discuss inner string running procedu res. PU and run 2-78" inner string and wash cups Tour change. Conduct PJSM wi new crew an d discuss inner string running procedures. Run 2-7/8" inner string and wash cups. Spa ce out cups inside 4" blank joints. MU Pack er assembly on inner string and liner. RD liner and tubing handling equipment. RU to run drill pipe. RIH wI liner on drill pipe, DC's, and HWDP at 3 minI stand. Fill pipe every stand. Bre ak circulation every 5 stands. Circulate bottoms up (72' above casing shoe ). Good clean returns. Continue RIH wI liner. RIH wI liner, 3 min's per std. std. Shoe @ 7 483' PT lines to 4000 psi. Set packer & release f I same. LID single & BID Top Drive. Hold PJSM. Rig up SWS to run GR/CCL. Part ed wI while picking up tools fI V-door. Aehe ad wireline. Rig up lubricator. Printed: 12/12/2001 9:31 :38 AM (' ( Page 5 of 10 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 1 C-1 09 Common Well Name: 1 C-1 09 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 245 Date From - To Hou rs Code Sub Phase Code 10/28/2001 08:00 - 10:30 2.50 LOG ELOG PROD 10:30 - 14:30 4.00 CMPLT CIRC PROD 14:30 - 23:00 8.50 CMPLTN TRIP PROD 23:00 - 23:30 0.50 RIGMNT RSRV PROD 23:30 - 00:00 0.50 WINDO PULD PROD 10/29/2001 00:00 - 03:30 3.50 WINDO PULD PROD 03:30 - 07:30 4.00 WINDO PROD 07:30 - 08:30 1.00 WINDO SETW PROD 08:30 - 09:00 0.50 WINDO 09:00 - 10:30 1.50 WINDO 11 :30 - 12:30 1.00 WINDO CIRC PROD 12:30 - 15:00 2.50 WINDO RIP PROD 15:00 - 16:30 1.50 WINDO RIP PROD 16:30 - 17:00 0.50 RIGMNT RGRP PROD 17:00 - 20:00 3.00 WINDO RIP PROD 20:00 - 20:30 0.50 WINDO 20:30 - 00:00 3.50 WINDO 10/30/2001 00:00 - 00:30 0.50 WINDO 00:30 - 02:00 1.50 WINDO 02:00 - 03:00 03:00 - 03:30 03:30 - 07:30 PROD PROD 07:30 - 09:00 09:00 - 09:30 09:30 - 12:00 0.50 WELCTL OTHR PROD 2.50 WELCTL BOPE PROD 12:00 - 15:30 3.50 WELCTL BOPE PROD 10/17/2001 Spud Date: 10/17/2001 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations Run GR/CCL with SWS (RA sub @ 4517' WLM ). POOH wI W.L. & rig down SWS. Displace well wI 3% KCL, pump between Ann ulus & liner 300 bbls. @ 10 BPM. P/U & dis place between wash string & liner @ 10 BPM . Packing off around upper cups, lost approx .100 bbls. Pull up to clear liner top w. top cups. circ 200 bbls @ 6 -8 bpm wI full retur ns until returns clean. Monitor well, POOH. Close sliding sleeve @ 4683', Continue POOH, LID liner running too Is. Rig up GBR & LID inner wash string 2-71 8" Fox tubing. Service Rig & Top Drive. P/U Whip stock assy. PJSM. P/U whipstock assy, M/U MWD & chan ge out internal components, orient tools, Up load data to MWD. RIH wI whipstock assy. Test MWD @ HWDP. Break circ, Orient whipstock (19 deg to left of HS). Sting into Liner top, Set anchor & s hear off bolt. Top of window @ 4494'. Finish displacing hole wI Baradril-N mud. Mill window 1/ 4494' to 4498' wI starting mill Pump sweep around. Monitor well, PJSM on t ripping, Pump dry job. POOH wI starting mill assy. Change out mills, PJSM, RIH w, 2nd mill ass y. Repair air hose on Top Drive Continue RIH, Take MWD surveys @ 4330',4 355' ,4380' ,4405'. Ream fl 4494' to 4498' Milling window 1/ 4498' to 4519' Mill window 1/ 4519' to 4525' Ream window, pump sweep, circ out metal c uttings. Perform FIT, Mud wt. 9.0 ppg., 4525' MO, 37 51' TVD. 600 psi, bled to 505 psi. (11.6 ppg emw) Monitor well, Pump dry job. POOH to HWDP, monitor well, Continue POO H. LID Mill assy. D.L. LWD info. P/U stack washing tool & wash stack cavitie s. Pull wear bushing. PJSM. Rig up test equipment. Break dart va Ive & inspect same. Reassemble dart valve. Test Bop's complete to 250/3000 psi. Prform accumulator test. AOGCC rep. Chuck Schev Printed: 12/12/2001 9:31 :38 AM l' \ PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 1 C-1 09 Common Well Name: 1 C-1 09 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 245 Date From - To Hours Code Sub Phase Code 10/30/2001 12:00 - 15:30 3.50 WELCTL BOPE PROD 15:30 - 16:30 1.00 WELCTL BOPE PROD 16:30 - 19:30 3.00 DRILL TRIP PROD 19:30 - 23:30 4.00 DRILL TRIP PROD 23:30 - 00:00 0.50 RIGMNT RSRV PROD 10/31/2001 00:00 - 01 :00 1.00 DRILL TRIP PROD 01 :00 - 18:00 17.00 DRILL DRLG PROD 18:00 - 19:00 1.00 DRILL CIRC PROD 19:00 - 20:30 1.50 DRILL WIPR PROD 20:30 - 21 :00 0.50 RIGMNT RSRV PROD 21 :00 - 22:30 1.50 DRILL WIPR PROD 22:30 - 00:00 1.50 DRILL CIRC PROD 11/1/2001 00:00 - 01 :30 1.50 DRILL CIRC PROD 01 :30 - 02:00 0.50 DRILL DRLG PROD 02:00 - 03:00 1.00 WELCTL OBSV PROD 03:00 - 03:30 0.50 WELCTL CIRC PROD 03:30 - 16:30 13.00 DRILL DRLG PROD 16:30 - 20:00 3.50 DRILL CIRC PROD 20:00 - 20:30 0.50 DRILL SFTY PROD 20:30 - 00:00 3.50 DRILL TRIP PROD 11/2/2001 00:00 - 02:00 2.00 DRILL TRIP PROD 02:00 - 02:30 0.50 DRILL SURV PROD 02:30 - 03:30 1.00 DRILL PULD PROD 03:30 - 03:45 0.25 DRILL SFTY PROD 03:45 - 04:30 0.75 DRILL PULD PROD 04:30 - 07:00 2.50 DRILL TRIP PROD 07:00 - 08:00 1.00 DRILL URM PROD 08:00 - 08:30 0.50 DRILL URM PROD 08:30 - 16:00 7.50 DRILL URM PROD 16:00 - 17:30 1.50 DRILL CIRC PROD Page 6 of 10 10/17/2001 Spud Date: 10/17/2001 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations e witnessed test. Rig down test equip. & Install wear bushing. PSJM, P/U BHA. Reset adjustable bent housi ng, (1.8), Orient tools. Program LWD tools. RIH wI Drilling assy, Shallow test MWD @ 3 76' . Service Rig & Top Drive. Pump survey @ 4455'. Orient motor. Conti nue RIH to 4525'. Drill ahead from 4525' to 6060' MD (TVD 374 1'). ART=5.3 AST=4.5 Circulate and condition mud. Short trip to window. Lubricate rig and service top drive. Trip in hole. Condition mud. Circulate bottoms up. Chan ge hole over to new mud. Continue changing hole over to new mud. P ump survey. Drill ahead 6060' to 6165' (TVD 3742'). AR T=0.25 AST=0.25 Flow check. Saw pit gain and increased flo w. Shut in well. Monitor pressure. 0 psi c asing and DP. Open well. Monitor pressure. Circ bottoms up. Mud is slightly aerated. Blow down top d r i v e. Drill ahead from 6165' to TD at 7525' MD (T VD 3733' ART=5.5 AST=1.0 Total for the u pper lateral: ART=11.05 AST=5.75 Condition mud. Circ bottoms up. Pump swe ep. Pump 2.5 hole volumes. Displace well with new mud. Monitor well. PJSM - discuss procedure for pulling out of hole. Pump dry job. POOH. Monitor well at window. SLM out of h 0 Ie. Continue POOH. SLM out of hole. No corre c t ion. Download MWD. LD BHA. PJSM - Discuss procedures for picking up n ew bit and BHA. PU hole opener and BHA. RIH wI hole opener to top of window at 4494 , MD. Fill pipe and slide through window to 4550' MD Ream from 4572' to 4972' MD. Tight spot at 4972' . Ream through tight spot at 4972'. Ream from 4972' to TD at 7525'. Circulate and condition mud. Pump hi vis s Printed: 12/12/2001 9:31 :38 AM (" ..... ........ ..... l'" PH nups) IW) ~ ( PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 1 C-1 09 Common Well Name: 1 C-1 09 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 245 Date From - To Hours Code Sub Phase Code 11/212001 16:00 - 17:30 1.50 DRILL CIRC PROD 17:30 - 19:30 2.00 DRILL WIPR PROD 19:30 - 20:00 0.50 RIGMNT RSRV PROD 20:00 - 21 :30 1.50 DRILL WIPR PROD 21 :30 - 00:00 2.50 DRILL CIRC PROD 11/3/2001 00:00 - 04:30 4.50 DRILL TRIP PROD 04:30 - 05:30 1.00 DRILL PULD PROD 05:30 - 08:30 3.00 FISH PULD PROD 08:30 - 09:00 0.50 FISH PULD PROD 09:00 - 10:00 1.00 FISH OTHR PROD 10:00 - 12:00 2.00 FISH OTHR PROD 12:00 - 13:00 1.00 FISH CIRC PROD 13:00 - 15:00 2.00 FISH OTHR PROD 15:00 - 17:00 2.00 FISH PULD PROD 17:00 - 18:00 1.00 RIGMNT RSRV PROD 18:00 - 20:00 2.00 CASE RURD PROD 20:00 - 23:30 3.50 CASE PULR PROD 23:30 - 00:00 0.50 CASE RURD PROD 11/4/2001 00:00 - 00: 15 0.25 CASE SFTY PROD 00:15 - 01:00 0.75 CASE PUTB PROD 01 :00 - 04:00 3.00 CASE PUTB PROD 04:00 - 04:30 0.50 CASE PUTB PROD 04:30 - 06:00 1.50 CASE DEQT PROD 06:00 - 07:30 1.50 CASE DEQT PROD 07:30 - 10:00 10:00 - 11 :30 2.50 CASE RUNL PROD 1.50 CASE RUNL PROD Page 7 of 10 10/17/2001 Spud Date: 10/17/2001 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations weep. Circ bottoms up. Monitor well. Pump dry job. Blow down top drive. POOH above window. Lubricate rig. Service top drive. RIH to TD. No tight spots encountered. Circulate and condition mud. Pump hi vis s weep. Circulate until returns are clean. Ch ange hole over to new mud. POOH wI hole opener to top of window at 44 94' MD. Monitor well. POOH to BHA. Monitor well. PJSM. LD BHA. PU MWD in derrick and lay down. PU whipstock retrieving tool and BHA. RIH wI HWDP. LD both sets of drilling jars. Test MWD. Blow down top drive. RIH to stand 39. MU top drive. Pump surve y. Orient retrieving tool. Attempt to latch whipstock. Latched up at 1 200. Up weight @ 4400'=138K Dn weight @ 4400'=120K Circ bottoms up. Monitor well. Pump pill. Blow down top drive. POOH to fishing tools. PJSM. LD Fishing tools and whipstock. Service rig and top drive. CIO strip-o-matic RU GBR. PJSM. Load tools onto floor. RIH wI 4.5" slotted liner. RU to run 2-7/8" inner wash string. PJSM - discuss inner string running procedu reo PU CMD shifting tool and lower cup assembl y. RIH wI 2-7/8" inner wash string and cups. T ag shoe and space out cups. PU flanged hook hangerlrunning tools. MU t 0 inner wash string. MU flanged hook hange r to 4-1/2" liner. PU MWD orienting sub. Orient sub 180 deg from hook hanger. PU 4-3/4" drill collar an d MWD flow sub. Load MWD tools and land i n orienting sub. RIH wI 2 stands DP. Surfa ce test MWD. MWD not pulsing. POOH 2 stands DP. Pull MWD tools. Repla ce 2 components. Load MWD tools and land in orienting sub. RIH wI 1 stand of DP. Su rfaèe test MWD. Good. RIH to top of window at 4494' MD. Attempt to slide through window. Tag packe r for lower lateral. PU above window and ro tate 90 deg. Work torque down. RIH and ta g packer. PU above window and rotate 120 deg. PU 30' and RIH. Tag packer. PU to t Printed: 12/12/2001 9:31 :38 AM t' ~ ~ 1'PHILLlPS~. IW (' Page 8 of 10 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 1 C-1 09 Common Well Name: 1 C-1 09 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 245 Date From - To Hours Code Sub Phase Code 11/4/2001 10:00 - 11 :30 1.50 CASE RUNL PROD 11 :30 - 12:00 0.50 CASE RUNL PROD 12:00 - 16:00 4.00 CASE RUNL PROD 16:00 - 18:00 2.00 CASE RUNL PROD 18:00 - 21 :30 3.50 CASE OTHR PROD 21 :30 - 23:30 2.00 CASE OTHR PROD 23:30 - 00:00 0.50 CASE OTHR PROD 11/5/2001 00:00 - 00:15 0.25 CASE SFTY PROD 00:15 - 01 :30 1.25 CASE CIRC PROD 01 :30 - 03:00 1.50 CASE CIRC PROD 03:00 - 03:30 0.50 CASE SFTY PROD 03:30 - 04:30 1.00 RIGMNT RURD PROD 04:30 - 12:00 7.50 CASE RUNL PROD 12:00 - 13:00 1.00 CASE RUNL PROD 13:00 - 13:30 0.50 CASE RUNL PROD 13:30 - 16:30 3.00 CASE RUNL PROD 16:30 - 16:45 0.25 DRILL SFTY PROD 16:45 - 17:00 0.25 DRILL PULD PROD 17:00 - 23:30 6.50 DRILL PULD PROD 23:30 - 00:00 0.50 WELCTL BOPE PROD 11/6/2001 00:00 - 03:00 3.00 WELCTL BOPE CMPL TN 03:00 - 07:30 4.50 WELCTL BOPE CMPL TN 07:30 - 08:30 1.00 WELCTL BOPE CMPLTN 10/17/2001 Spud Date: 10/17/2001 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations op of window. Rotate 180 deg. PU 30' and RIH. Liner slid into upper lateral. RIH wI slotted liner on DP to 4896' and pum p survey. MWD working well. Up wt 160K Dn wt 135K RIH wI slotted liner on DP. Stop wI hanger 50' above window. Up wt 195K, Dn wt 115K. Orient hanger. RIH and set down in window w/20K. Attempt to set down more weight. Run in hole 6' more to get total of 40K set 0 n hook hanger. Pump survey. hanger is 20 deg right of expected orientation. Hook han ger is 6' deeper that expected. RU HES slickline unit. RIH and retrieve MW D tools. RD slickline unit. Drop ball. Ball did not seat. Circ and surg e trying to get ball on seat with no success. Release HR liner running tool wI left hand r otation. PJSM - discuss liner wash procedures Pump 30 bbl hi vis sweep. Displace wI 250 bbls 9.0 ppg brine at 9 bpm and 3500 psi. Good returns during circulation. Pump out of hole laying down to 7235'. Con tinue pumping brine at 9 bpm at 3100 psi. T op cups are in 7-5/8" casing. Goods returns during circulation. Pumped 450 bbls. Ret urns are clean. 150 NTU turbidity. Monitor well. PJSM - discuss cutting drillin g Ii n e Slip and cut 112' drilling line. POOH laying down drill string. LD MWD equ ipment. Check orienting sub. Orienting lug is tight and has not moved since RIH. Lay down liner running tools. Drill string has been pulling wet. RU and p ump down 2-7/8" tubing. Shear out ball sea t with 4000 psi. POOH laying down 2-7/8" inner wash string. PJSM - discuss running and laying down dril I pipe out of derrick. RU floor to LD drill pipe out of derrick. RIH wI drill pipe out of derrick and POOH la ying down. Clean up floor and load floor with tools for BOP test joint. RU , pull wear bushing, set test plug, RU to weekly test BOPE. Test BOPE to 300 psi low and 3000 psi high. Test witness waived by AOGCC rep. John C r is p. RID test equipment, clear floor. Blow down t Printed: 12/12/2001 9:31 :38 AM ( """- ....... .... ~'PH I LLiPS). ~) ( PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 09 1 C-1 09 ROT - DRILLING Nabors Nabors 245 Date Sub From - To Hours Code Code Phase 11/6/2001 07:30 - 08:30 08:30 - 09:30 09:30 - 15:00 1.00 WELCTL BOPE CMPL TN 1.00 CMPL TI\ RURD CMPL TN 5.50 CMPL TI\ RUNT CMPL TN 15:00 - 19:00 4.00 CMPLTN OTHR CMPLTN 19:00 - 22:00 3.00 CMPL TN SOHO CMPL TN 22:00 - 00:00 2.00 CMPL TN SUN CMPL TN 1117/2001 00:00 - 00:30 0.50 CMPL TN SUN CMPLTN 00:30 - 02:00 1.50 CMPL TN SUN CMPL TN 02:00 - 03:00 1.00 CMPL TN SUN CMPL TN 03:00 - 04:00 1.00 CMPL TN PULD CMPL TN 04:00 - 05:30 1.50 CMPLTN RUNT CMPL TN 05:30 - 06:30 1.00 CMPLTN CIRC CMPLTN 06:30 - 11 :00 4.50 CMPL TN PULD CMPLTN 11 :00 - 12:00 1.00 CMPL TN PULD CMPL TN 12:00 - 15:30 3.50 CMPLTN OTHR CMPLTN 15:30 - 19:00 3.50 CMPLTN OTHR CMPL TN 19:00 - 00:00 5.00 CMPL TN RURD CMPL TN 11/8/2001 00:00 - 01 :00 1.00 CMPL TN RURD CMPL TN 01 :00 - 06:00 5.00 CMPL TN RUNT CMPL TN 06:00 - 09:00 3.00 CMPLTN SUN CMPLTN 09:00 - 11 :00 2.00 CMPL TN SUN CMPL TN 11 :00 - 17:00 6.00 CMPL TN RUNT CMPL TN Page 9 of 10 10/17/2001 Spud Date: 10/17/2001 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations op drive and kill and choke lines. RU to run 4 1/2" completion string. Run 4 1/2" completion string with bullplug 0 n bottom to attempt to get to lower lateral. Attempt to get into lower lateral. Rotate pip e past 4508' to 4515'. Slack off to 4560'. Ta gged up at 4560' (CMD sliding sleeve depth of upper lateral) Space out to have x-o @ 4300', MU two pie ce hanger, Land, Run in lockdown screws. RU halliburton wireline to run centralift dum my pump (3.80" OD). Finish Ru Halliburton WL to run 3.80" drift d ummy pump. Run dummy pump drift 3.80" to 4300'. No pr oblems. RD halliburton WL. POOH w/ tubing hanger and pups. RIH wI 4 1/2" tubing. Got past "V" in hook h anger, went to 4602' bullplug depth( = 4493' fl 6" OD: top of hook wall hanger) LID single, RU to circ 400 bbls filtered brin e. Pump 10 bpm @ 950 psi. Final NTU's 18. POOH wI 4 1/2" tubing. Rack back in derrick for ESP completion run. LID 2 7/8" tools, clear rig floor. RU Halliburton video to run in well and obse rve hook wall hanger. RIH w/ halliburton 2 1/8" camera to observe hook hanger. Cuttings bed @ 4396'. Did not reach hook wall hanger. POOH, RD WL. RU to run production tubing/ESP. Splicing pi g tail for pump. RU to run 4 1/2" ESP completion. Splice mot or lead connection. PU/MU Centralift motor centralizer, Phoenix guage, centralift 190HP motor, tandem seal section, TTC crossover/screen. Fill mtr wit h oil, check rotation, check continuity, meg ger mtr, PU 2 joints(jt # 1 & # 2) 4 1/2" NSTC 12.6#/ ft tubing and Phoenix pressure sub. PJSM to set ESP with Halliburton slickline. Run pu mp assembly, run packoff, set pressure test tool. Test packoff to 1000 psi for 15 min. OK. R / D H all i bur ton s I i c k I i n e. Pre par e to run E S P assembly wI pump in tubing. PJSM with te am members. RIH wI 4 1'2" ESP completion string. Run 3 joints(jt # 3-#5) 4 1/2" tubing, Camco GLM 0 n pups, then jts #6-#40, continue and start heat trace on jt # 41 (10' down from box), c Printed: 12/12/2001 9:31 :38 AM (. (' PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 1 C-1 09 Common Well Name: 1 C-1 09 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 245 Date From - To Hours Code Sub Phase Code 11/8/2001 11 :00 - 17:00 6.00 CMPL T RUNT CMPL TN 17:00 - 20:00 3.00 CMPLT OTHR CMPL TN 20:00 - 00:00 4.00 CMPL TN RUNT CMPL TN 11/9/2001 00:00 - 00:30 0.50 CMPLTN SFTY CMPLTN 00:30 - 12:00 11.50 CMPL TN RUNT CMPLTN 12:00 - 15:00 3.00 CMPLTN OTHR CMPL TN 15:00 - 18:00 3.00 CMPL TN OTHR CMPL TN 18:00 - 19:00 1.00 CMPL TN SOHO CMPLTN 19:00 - 19:30 0.50 WELCTL OTHR CMPL TN 19:30 - 21 :00 1.50 CMPL TN OTHR CMPL TN 21 :00 - 00:00 3.00 WELCTL NUND CMPL TN 11/10/2001 00:00 - 04:00 4.00 WELCTL NUND CMPL TN 04:00 - 06:00 2.00 WELCTL NUND CMPL TN 06:00 - 12:00 6.00 WELCTL OTHR CMPLTN 12:00 - 14:30 2.50 CMPL TN FRZP CMPL TN 14:30 - 16:30 2.00 CMPL TN FRZP CMPL TN 16:30 - 18:30 2.00 WELCTL OTHR CMPL TN 18:30 - 20:30 2.00 CMPL TN OTHR CMPL TN Page 10 of 10 10/17/2001 Spud Date: 10/17/2001 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations ontinue to jt # 45. Heat trace line pinched @ rotary table. Install clamps as recommend ed. Splice Centralift heat trace cable @ jt # 45 , 3'-5' below box of joint # 45. Check cable, OK. RIH wI 4 1/2" ESP completion assembly. Run joints #46- #75. Depth @ midnight 2350' In stall clamps as recommended. PJSM with team members on running 4 1/2" ESP completion. Continue to run 4 1/2" completion assembly. Install clamps as reccomended. Megger as recommended. Run from 2350' to 4270'. Splice pig tail on heat trace line to tubing h anger. Splice pig tail on ESP cable to tubing hange r . Orient, land tubing. Run in lockdown screws Test hanger to 5000 psi on upper and lower "0" rings. LID landing joint. Finish laying down central ift equipment from rig floor. PJSM. Change pipe rams, both top and botto m pipe rams to 4 1/2" X 7" VBR. Nipple down BOPE. Nipple up christmas tree. Test tree to 250 & 5000 psi.Test hanger pac koff to 5000 psi. Had to redress two way ch eck. Check electrical connections by Centra lift and Phoenix. RU to freeze protect. Reverse circ 170 bbls 9 ppg KCL taking returns to CPM. Follow wit h 110 bbls diesel- final pressure 900 psi. "u" tube diesel from annulus to tubing. Final pressure 251 psi. Set BPV with lubricator. Rig down cellar equ ipment. Clean up cellar area after rig is moved off h ole. Rig released @ 2030 hrs 11/10101 for m ove to 1 R-35. Pad to pad move 8 miles from well to well. Printed: 12/12/2001 9:31 :38 AM Date 11/04/01 11/07/01 11/08/01 12/02/01 ( { 1 C-1 09 Event H ¡story ( Comment PULLED MWD TOOL F/4458' RKB, COMPLETE. [OTHER STIM] RUN ESP DRIFT SET ESP 4. X 41' ESP PUMP, SET 4. X 6' PACK-OFF, TESTED PACK-OFF TO 1000#, SET 411 SLIP STOP. [ESP WORK] PULLED 4.5n BPV F/TBG HANGER, PULLED DV F/4090' RKB, SET SOV (SHEAR OUT AT 2000 PSI) PERFORMED SBHP SURVEY, @ 4190' WLM, COMPLETE. [PRESSURE DATA] Page 1 of 1 12/12/2001 ( ( 20-Nov-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Surveys Re: Distribution of Survey Data for Well 1 C-1 09L 1 a OJ - ¿;bLJ Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 4,434.57' MD , MD (if applicable) 7,525.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager )-:.) _./~ RECEI\/ED NOV 2 9 2001 Attachment(s) .Alaska Oil & Gas Cons, Commission Ancl;urage Kuparuk River Unit North Slope, Alaska Kf!paruk 1 C, Slot 1 C-1 09 1C-109L 1 Job No. AKMMI1171, Surveyed: 26 October, 2001 SURVEY REPORT 21 November, 2001 Your Ref: API- 500292304760 Surface Coordinates: 5968746.59 N, 561706.13 E (700 19' 30.5440" N, 149029' 58.6776" W) Surface Coordinates relative to Project H Reference: 968746.59 N, 61706.13 E (Grid) Surface Coordinates relative to Stucture Referance: 229.60 N, 664.05 W (True) Kelly Bushing: 102.04ft above Mean Sea Level spe""""v-sul1 DRILLING seRVices A Halliburton Company ~ ' DEFINITIVE -~ ..--..\ Survey Ref: svy9709 Sperry-Sun, Drilling Services DE FIN IT IV' Survey Report for 1 C-1 09L 1 Your Ref: API- 500292304760 Job No. AKMM11171, Surveyed: 26 October, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct Azim. Depth Depth Northlngs . Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) .' 4434.57 65.780 179.520 3614.63 3716.67 156.74 N 920.13 W 5968895.76 N 560784.74 E -164.45 Tie-on Point 4494.00 68.110 178.380 3637.90 3739.94 102.07 N 919.12 W 5968841.10 N 560786.20 E 4.299 -109.77 Window Point 4532.25 71.020' 180.510 3651.26 3753.30 66.24 N 918.78 W 5968805.27 N 560786.83 E 9.225 -73.93 4572.62 79.490 182.640 3661.53 3763.57 27.25 N ~ 919.87 W 5968766.28 N 560786.07 E 21.591 -34.96 4619.09 88.770 187.940 3666.28 3768.32 18.71 S 924.14 W 5968720.28 N 560782.17 E 22.961 10.97 4665.41 95.610 187.670 3664.51 3766.55 64.54 S 930.42 W 5968674.40 N 560776.27 E 14.778 56.74 4719.63 98.100 187.690 3658.04 3760.08 117.88S 937.62 W 5968621.00 N 560769.51 E 4.593 110.02 4762.55 97.660 187.090 3652.15 3754.19 160.04 S 943.09 W 5968578.80 N 560764.39 E 1.723 152.14 4817.76 93.440 183.320 3646.81 3748.85 214.75 S 948.06 W 5968524.05 N 560759.87 E 10.227 206.80 4857.56 89.320 180.390 3645.85 3747.89 254.50 S 949.35 W 5968484.29 N 560758.91 E 12.700 246.54 4904.40 89.010 179.540 3646.54 3748.58 301.34 S 949.32 W 5968437.46 N 560759.32 E 1.931 293.37 4952.44 88.710 179.080 3647.49 3749.53 349.36 S 948.74 W 5968389.44 N 560760.29 E 1.143 341.40 4996.75 91.170 179.760 3647.54 3749.58 393.67 5 948.29 W 5968345.14 N 560761 .11 E 5.760 385.71 5047.31 93.140 182.000 3645.64 3747.68 444.18 S 949.07 W 5968294.62 N 560760.75 E 5.897 436.21 5090.41 90.370 181.040 3644.32 3746.36 487.24 S 950.21 W 5968251.55 N 560759.96 E 6.802 479.26 5142.16 90.250 180.890 3644.04 3746.08 538.98 S 951.08 W 5968199.81 N 560759.51 E 0.371 531.00 5187.96 90.620 180.060 3643.69 3745.73 584.78 S 951.46 W 5968154.01 N 560759.51 E 1.984 576.79 5237.02 91.410 177.620 3642.82 3744.86 633.82 S 950.47 W 5968104.98 N 560760.90 E 5.227 625.83 5280.52 90.490 175.120 3642.1 0 3744.14 677.22 S 947.72 W 5968061.60 N 560764.02 E 6.123 669.26 5331.84 90.180 174.860 3641.80 3743.84 728.34 S 943.23 W 5968010.52 N 560768.92 E 0.788 720.42 -- 5373.95 90.430 173.720 3641.57 3743.61 770.24 S 939.04 W 5967968.65 N 560773.45 E 2.771 762.35 5425.68 90.550 172.320 3641.13 3743.17 821.59 5 932.76 W 5967917.36 N 560780.16 E 2.716 813.74 5467.67 89.140 174.930 3641.25 3743.29 863.31 S 928.10 W 5967875.68 N 560785.1f E 7.065 855.51 5520.71 90.550 177.050 3641.39 3743.43 916.22 5 924.39 W 5967822.80 N 560789.31 E 4.800 908.44 5566.58 90.620 176.550 3640.92 3742.96 962.01 S 921.83 W 5967777.03 N 560792.24 E 1.101 954.26 5q15.10 90.250 176.130 3640.55 3742.59 1010.435 918.73 W 5967728.64 N 560795.74 E 1.154 1002.70 5658.78 89.010 179.270 3640.83 3742.87 1054.07 S. 916.98 W 5967685.02 N 560797.85 E 7.729 1046.35 5710.19 89.630 180.830 3641.44 3743.48 1105.47 S 917.02 W 5967633.61 N 560798.23 E 3.265 1097.75 5750.18 89.820 180.330 3641.64 3743.68 1145.46 S 917.43 W 5967593.62 N 560798.15 E 1.338 1137.74 5805.22 90.180 178.410 3641.64 3743.68 1200.50 S 916.82 W 5967538.60 N 560799.21 E 3.549 1192.77 ----- ------- 21 November, 2001 - 10:57 Page2of5 DrillQuest 2.00.09.003 Sperry-Sun, Drilling Services . Survey Report for 1 c~ 1 09L 1 . Your Ref: API- 500292304760 Job No. AKMM11171, Surveyed: 26 October, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100lt) 5848.32 90.250 178.580 3641 .48 3743.52 1243.58 S 915.69 W 5967495.52 N 560800.70 E 0.427 1235.87 5900.10 90.800 177.400 3641.00 3743.04 1295.33 S 913.87 W 5967443.79 N 560802.94 E 2.514 1287.62 5945.54 91.050 177.100 3640.27 3742.31 1340.71 S 911.69 W 5967398.43 N 560805.49 E 0.859 1333.02 -..", 5990.26 91.660 179.390 3639.21 3741.25 1385.39 S 910.32 W 5967353.76 N 560807.23 E 5.298 1377.72 6039.72 90.310 178.420 3638.36 3740.40 1434.83 S 909.38 W 5967304.33 N 560808.58 E 3.361 1427.16 -- 6086.73 89.450 177.220 3638.46 3740.50 1481.81 S 907.59 W 5967257.37 N 560810.75 E 3.140 1474.15 6133.61 89.690 177.380 3638.81 3740.85 1528.63 S 905.38 W 5967210.56 N 560813.35 E 0.615 1521.00 6182.92 89.140 1 82.580 3639.31 3741.35 1577.92 S 905.37 W 5967161.27 N 560813.77 E 10.604 1570.28 6233.44 89.450 185.640 3639.94 3741.98 1628.30 S 908.99 W 5967110.87 N 560810.56 E 6.088 1620.63 6277.85 90.680 186.340 3639.88 3741.92 1672.47 S 913.62 W 5967066.66 N 560806.29 E 3.187 1664.76 6326.17 90.980. 186.570 3639.18 3741.22 1720.48 S 919.05 W 5967018.61 N 560801.26 E 0.782 1712.72 6372.52 90.680 185.110 3638.51 3740.55 1766.58 S 923.77 W 5966972.47 N 560796.92 E 3.215 1758.78 6424.44 90.120 182.780 3638.15 3740.19 1818.37 S 927.34 W 5966920.65 N 560793.77 E 4.615 1810.54 6465.44 89.450 180.260 3638.30 3740.34 1859.36 S 928.43 W 5966879.66 N 560793.02 E 6.360 1851.51 6516.35 91.720 180.710 3637.78 3739.82 1910.26 S 928.86 W 5966828.76 N 560793.01 E 4.546 1902.41 6560.71 92.530 179.070 3636.14 3738.18 1954.59 S 928.77 W 5966784.43 N 560793.46 E 4.121 1946.74 6602.77 92.640 179.830 3634.24 3736.28 1996.60 S . 928.37 W 5966742.42 N 560794.21 E 1.824 1988.75 6655.68 88.890 179.620 3633.54 3735.58 2049.50 S 928.12 W 5966689.53 N 560794.90 E 7.099 2041.65 6701.32 88.830 177.420 3634.44 . 3736.48 2095.11 S 926.94 W 5966643.93 N 560796.45 E 4.821 2087.27 6751.06 88.950 177.710 3635.41 3737.45 2144.79 S 924.82 W 5966594.26 N 560798.97 E 0.631 2136.97 ~ 6794.24 89.940 177.140 3635.83 3737.87 2187.93 S 922.88 W 5966551.15 N 560801.27 E 2.646 2180.12 6845.11 90.920 178.080 3635.44 3737.48 2238.75 S 920.76 W 5966500.34 N 560803.81 E 2.669 2230.96 6887.65 89.880 180.810 3635.15 3737.19 2281.28 S 920.35 W 5966457.82 N 560804.51 E 6.867 2273.49 6940.56 90.550 182.320 3634.95 3736.99 2334.17 S 921.80 W 5966404.92 N 560803.56 E 3.122 2326.37 6997.40 88.030 181.840 3635.65 3737.69 2390.97 S 923.86 W 5966348.11 N 560801.96 E 4.513 2383.14 7035.37 88.650 180.470 3636.75 3738. 79 2428.91 S 924.62 W 5966310.16 N 560801.51 E 3.959 2421.08 7077.68 88.650 181.190 3637.75 3739.79 2471.20 S 925.24 W 5966267.86 N 560801.25 E 1.701 2463.37 7128.62 89.320 180.190 3638.65 3740.69 2522.13 S 925.85 W 5966216.93 N 560801.05 E 2.363 2514.29 7173.07 89.940 181.080 3638.94 3740.98 2566.58 S 926.34 W 5966172.48 N 560800.92 E 2.440 2558.73 7224.58 92.340 181.560 3637.92 3739.96 2618.06 S 927.53 W 5966120.99 N 560800.16 E 4.752 2610.20 21 November, 2001 - 10:57 Page30f5 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for 1C-109L 1 Your Ref: API- 500292304760 Job No. AKMM11171, Surveyed: 26 October, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs . Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) . (ft) (ft) (ft) (ft) (o/100ft) 7267.36 91.230 180.750 3636.58 3738.62 2660.81 S 928.39 W 5966078.24 N 560799.65 E 3.211 2652.94 7319.20 90.370 180.830 3635.86 3737.90 2712.64 S 929.11 W 5966026.40 N 560799.36 E 1.666 2704.76 7365.21 90.680 179.800 3635.44 3737.48 2758.64 S 929.36 W 5965980.40 N 560799.49 E 2.338 2750.76 -", 7414.04 91 .170 179.670 3634.65 3736.69 2807.47 S 929.13 W 5965931.58 N 560800.12 E 1.038 2799.59 7455.59 91.420 179.160 3633.71 3735.75 2849.00 S 928.71 W 5965890.04 N 560800.88 E 1.367 2841.12 7525.00 91.420 179.160 3631.99 3734.03 2918.39 S 927.69 W 5965820.67 N 560802.4 7 E 0.000 2910.51 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates ðre relative to True North. Vertical depths are relative to AKB = 1û2.04' MSL. Northings and Eastings are relative to 1487' FNL & 699' FWL. Magnetic Declination at Surface is 26.098° (15-0ct-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1487' FNL &699' FWL and calculated along an Azimuth of 179.520° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7525.000., The Bottom Hole Displacement is 3062.28ft., in the Direction of 197.634° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment -. 4434.57 4494.00 7525.00 3716.67 3739.94 3734.03 156.74 N 102.07 N 2918.39 S 920.13 W 919.12 W 927.69 W Tie-on Point Window Point Projected Survey ~ ' .- -- -- - ._-- --.-- -- . 21 November, 2001 - 10:57 Page 4 of5 DrlllQuest 2.00.09.003 . Kuparuk River Unit Survey tool program for 1 C-1 09L 1 From Measured Vertical Depth Depth. (ft) (ft) 0.00 201.00 0.00 200.99 '-.-' 21 November, 2001- 10:57 To Measured Vertical Depth Depth (ft) (ft) 201.00 7525.00 Sperry-Sun Drilling Services. Survey Report for 1C-109L 1 . Your Ref: API- 500292304760 Job No. AKMM11171, Surveyed: 26 October, 2001 Survey Tool Description 200.99 Tolerable Gyro (1C-109 Gyro) 3734.03 MWD Magnetic (1 C-1 09) ----- ------ Page50f5 . North Slope, Alaska Kuparuk 1 C --... --, ~ I DrlllQuest 2.00.09.003 w i- ( ( ~1f~VŒ (ll~ ~~fÆ~~~ / ! I / ALASKA OIL AND GAS /1 CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. "'fTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Unit 1 C-l 09Ll Phillips Alaska, Inc Permit No: 201-204 Sur Loc: 1487' FNL, 699' FWL, Sec. 12, TIIN, RI0E, UM Btmhole Loc. 969' FSL, 216' FEL, Sec. 11, TIIN, RIO E, UM Dear Mr. Mallary: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The permit is for a new wellbore segment of proposed welllC-109, Permit No 201-203, API 50- 029-20347-00. Production should continue to be reported as a function of the original API number stated above. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on 1 C Pad must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels . through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. . '\ PTD: 201-204 October 16, 2001 Page 2 of2 ( ( Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test ofBOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (n~L ,~~. ¥ ~~ChSli Taylor Chair BY ORDER OF THE COMMISSION DATED this.l.lJl\day of October, 2001 jj cÆnc10sures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. (' ( Á ( °1, to STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work: Re-entry 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1487' FNL, 699' FWL, Sec. 12, T11 N, R1OE, UM At top of productive interval 1405' FNL, 230' FEL, Sec. 11, T11N, R1OE, UM At total depth 969' FSL, 216' FEL, Sec. 11, T11 N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well 969 @ TD feet 1C-109 16. To be completed for deviated wells Kickoff depth: 4601 MD 18. Casing program size 1b. Type of well. Exploratory Stratigraphic Test Service 0 Development Gas 0 Single Zone B,' p 5. Datum elevation (DF or KB) RKB = 102 feet AMSL feet 6. Property Designation ADL 25649 ALK 467 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) Kuparuk River Unit Statewide 8. Well number Number ~~Gt1,~ifl. #59-52-180 9. Approximate spud date Amount October 14, 2001 $200,000 14. Number of acres in property 15. Proposed depth (MD and lVD) 2560 7508' MD 13746' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 1330 psig At total depth (TVD) 1748 psig Settin De th Development Oil .¡ Multiple Zone 0 10. Field and Pool Kuparuk River Field West Sak Oil Pool Maximum hole angle 910 Hole Casin 9.875" 7.625" 6" 4.5" MD Bottom TVD 29.7# 12.6# L-80 L-80 BTCM NSCT 6640' 2907' 41.2' 4601' 41.2' 3734' 5017' 7508' 3804' 3746' 530 sx AS Lite & sx Class G slotted screen 2~o 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: measured true vertical feet feet Junk (measured) Casing Conductor Surface 0 Length Size Cemented Measured depth True Vertical depth RECEIVED OCT 11 2001 Perforation depth: measured Alaska Oil & Gas Cons. Commission Anchorage true vertical Signed Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 0 Time vs depth plot DRefraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 is true and r. to the best of my knowledge Questions? Call Steve McKeever 265-682t Date I' oct o( Title: Drilling Engineering SupeNisor 20. Attachments Permit Number/ . ~ ;:zo - 2.0 ~ Conditions of approval Samples required Hydrogen sulfide measures 0 Yes Required working pressure for BOPE D2M; Other: Commission Use On' API number Q. -:::J:r-....c.J I Approval date 50- 02:;, - 2 :.J-)-' 7'" (00 0 Yes ŒI No ~ No 0 3M; 0 5M; Mud log required Directional survey required 0 10M;D See cover letter for other requirements 0 Yes ~ No [8] Yes 0 No 1iI ~5öD ~~\ ~~~~~Ñ""'(Y'.\)~ Commissioner by order of the commission Form 10-401 Rev. 12/1/85. Submit in triplicate (" Ap( ion for Permit to Drill, Well 1 C-109L 1 Revision No.O Saved: 11-0ct-01 Permit It - West Sak Well #1 C-1 09L 1 Application for Permit to Drill Document M()ximizE W~II VClI,-!~ 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.oo5(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25. o50(b).................. .... ................. .............. .................. ...... ............. ...... ........3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.oo5(c)(3) ...................................................................................................3 4. Dri II i ng Hazards I nformati on ............. ...................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casi ng and Cementing Program ...................................................... ............ ...........4 Requirements of 20 AAC 25.oo5(c)(6) ........................,.......................................................................... 4 7. Diverter System Information................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ...................................................................................................4 8. Dri II i ng FI u id Program ............................................................................................. 4 Requirements of 20 AAC 25.oo5(c)(B) ................................................................................................... 4 Lateral Mud Program.............................................................................................................................. 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5 10. Seism ic 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 Bond i ng................................................................................................ 5 Requirements of 20 AAC 25.005 (c)(12) .................................................................. .............................. 5 1C-109L 1 PERMIT IT. doc Page 1 of 7 0 HTG Iff/AI ( A 1='( ion for Permit to Drill, We1l1C-109L 1 Revision No.O Saved: 11-0ct-01 13. Proposed Dri II ing Program.. .............................. .......... ............ ................................5 Requirements of 20 AAC 25.005 (c)(13) ................................. .............. ....................... ............... ........... 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................7 15. Attachments .... ..................... .... ...... ............ ........ .......... ... ........ ..... .................... ........ 7 Attachment 1 Directional Plan................................................................................................................ 7 Attachment 2 Diagrams of the BOP / Diverter System........................................................................... 7 Attachment 3 Drilling Hazards Summary.. ........ ...... .... .................... ................. .................. .............. ....... 7 Attachment 4 Well Schematic ..... .......... ......... ... ................ ..... .... .... .... """"" ..... ........ .... .... ..................... 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name de!>ignated by the operator and a unique API number a_s:.c,~qned by the commiS'sion under 20 AAC 2S.040(b). For a well with multiple well brancheS'¡ each branch muS't !>imilady be identified 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 as"Signed to the well by the commission. The well for which this Application is submitted will be designated as \~i?,~@~ttij¡\.;;. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the f'ollowing item~ except f'or an item already 0/7 tHe with the commi::,-sion and Identified i/7 the application: (2) a plat identifying the property and the property~'S owners and showin.9 (A)the coordinates of the propO!!ied location of the well at the $tJdaæ/ at the top of each o/~jectjve formation and at total dept/7, referenced to govemmental s'ection lines-. (8) the coordl;Jates of the proposed location of the well at the surt.'1ce, relerenæd to the state plane coordinate system for thiS' state as maintained by the National Geodetic Survey 1Ì7 the National Oceanic and Atmosphelic AdminiS'tratio!7/' (C) the proposed depth of the well at the top of each objective formatio!7 and at total depth; Location at Surface (lC-109 is the parent bore of the 1487' FNL, 699' FWL, Section 12, TllN, Rl0E, UM iC-i09L1 Lateral) NGS Coordinates I RKB Elevation I 101.9' AMSL Northings: 5,968,746 Eastings: 561,706 I Pad Elevation I 60.7' AMSL Location at Top of Productive Interval West Sak "D" Sand NGS Coordinates Northings: 5,968,821 1405' FNL, 230' FEL, Section 11, TllN, Rl0E, UM Eastings: 560,776 4601 3734 3632 Location at Total De th NGS Coordinates Northings.' 5,965,916 Eastings: 560,816 and (D) other information required by 20 MC 25',05'O(b); 1C-109L 1 PERMIT IT.doc Page 2 of 7 0 FrIG ìWA L ( Ap( ;on for Permit to Drill, Well 1 C-109L1 Revision No.O Saved: 11-0ct-01 Requirements of 20 AAC 25. 050 (b) If a well is to be intentionally deviateft 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 tl7e proposed we/~' 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 tho:;,tl names are known or discoverable in public records, and show that each named operator has been fumished a copy of the application by certified mai~' 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 far a Permit to Drill mlJ!it be accompanied by each of the following items¡ except for an item already on tHe with ttle cammis--sion and Identified in the application: (3) a diagram and dt."Scriptian of the blowout prevention equipment (BOPE) as requ/Ì'ed by 20 AAC 25.03~ 20 MC 25.036; or 20 MC 25.03~ as applicable; An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete welllC-l09. Please see "Diagram and Description of the Blowout Prevention Equipment for Nabors Rig 245e", placed on file with the Commission. One of the spacer spools used in the stack arrangement is a combination diverter spool and spacer spool. Please see Attachment 2. 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 the tollowing Jtems~ except tÓr an item already on file with t!Je commission and identified in the application: (4) information on drilling hazards~ including (A) the maximum downhole pressure that may be encounterec!, aitena used to deten71ine iç and maximum potential sur/ace preSSllf?:? based on a methane gradìent; The expected reservoir pressures in the West Sak sands in the lC pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight). These are pressures obtained from actual well test data from the nearby WS1-0l well. 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 West Sak B sand formation is 1330 psi, calculated thusly: MPSP =(3800 ft)(0.46 - 0.11 psi/ft) =1330 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data cvnceming potential causes olhole problems such as abnormally f¡eO-pres:sï.lred stratal lost circulation zones~ and zones that have a prvpensity for ditf'erentìal sticking; Please see Attachment 3: 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 fOllowìng item::,~ except for an item already 0/7 file with the commission and Identified in the applicc-Jtion: (.5) a description of the procedure for conductli7g formation inttvnty testsl as requiœd under 20 AAC 25:03{)(f); 1C-109L 1 PERMIT IT. doc Page 3 of 7 Printed: 11-0ct-01, U j:' I Vi j . ~ i"~ 1- ( AP{ 'ion for Permit to Drill, Well 1 C-1 09L 1 Revision No.O Saved: 11-0ct-01 1C-109L1 will be sidetracked from the 1C-109 wellbore, exiting 7-5/8" surface casing landed in the West Sak B-Sand. Once the window is milled and new formation drilled, a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that Phillips 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 AAC 25.030, and a description of any slotted liner, pre- perforated linel; or screen to be installed," Casing and Cementing Program (16" conductor and 7-5/8" casing are also part of 1C-109) Hole Top Btm Csgrrbg Size Weight Length MOrrVO MOrrvO 00 (in) (in) (lb/ft) Grade Connection (fi) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 120 41/41 161 / 161 Cemented to surface with 225 cf ArcticSet 1 7-5/8 9-7/8 29.7 L-80 BTCM 4976 41/41 5017/3804 Cemented to Surface with 530 sx ASLite Lead, 240 sx Class G Tail 4-1/2 6" 12.6 L-80 NSCT 2907 4601/ 3734 7508 / 3745 Slotted- no slotted Upper cement Lateral 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a PermIt to Dn!1 must be accompanied by each of the following Item5~ eXŒpt for an item already on file with the commi.'ision and identified in the application: (7) a diagram and desaiption of the dive/ter sY!:1Tem as required by 20 MC 25. 035; unless thi.'i requirement is waived by the commi.'ision under 20 AAC 25:035(17)(2); No diverter system will be used in the drilling of 1C-109L1. The combination Diverter / BOPE system will be utilized only in the BOP mode, with the diverter outlet blinded off. 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 fol/owing items, except for an item already on file with tile commission and Identified i/7 the application: (8) a dlillil7g fluid program/ including ð diagram and description ot'the dn/ling fluid sY!:1Tem, as required by 20 AAC 2/), 033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program Sidetrack interval 1(-13 shale onl Initial Value Final Value 9.0-9.1 9.0-9.1 40-55 40-55 20-27 20-27 D sand laterals Initial Value Final Value 8.9-9.0 8.9-9.0 45-60 45-60 18-25 18-25 1C-109L 1 PERMIT IT. doc 0 F1tdfí~t ( Ap( ion for Permit to Drill, Well 1 C-1 09L 1 Revision No.O Saved: 11-0ct-01 Sidtrack interval J'K-13 shale only) BID sand laterals Initial Value Final Value Initial Value Final Value Plastic Viscostiy (lb/l00 sf) 11-19 11-19 8-14 8-14 Tau 0 4-7 4-7 4-7 4-7 Chlorides 13-15K 13-15K 13-15K 13-15K DH 8-9 8-9 8-8.5 8-8.5 API filtrate <6 <6 <6 <6 **HTHP filtrate <10 <10 <10 <10 MBT <11 <11 <2.5 <2.5 ***Solids DDb <12 <12 <12 <12 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. This drilling fluid system of Nabors Rig 245e consists of: (3) Continental Emsco FB-1600 Mud Pumps¡ Steel Mud pits with 1100 barrel capacity¡ Pill Pit¡ Trip Tank¡ (3) Derrick Flo-line Shale Shakers (rated at 600 gpm)¡ Brandt Model SRS-2 Desander¡ Derrick Model 58S Mud Cleaner¡ (2) Alpha-Laval Model 418-VT- 5 Centrifuges¡ Degassers¡ PVT System with visual and audio alarms¡ Trip Tank¡ Flow Sensor¡ and Fluid Agitators. Please see "Diagram of Mud System¡ Nabors Rig 245e"¡ placed on file with the Commission. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a PermIt to Onll mtJst be accompanied by each of the following Item.s~ except for an item already on flle with the commt:'ision and identified in the application: (9) for an exploratory or st7'atigrapl1ic test well, a tabulation setting out the depths of predicted abnormally geopres.5ured stre:;!'a as required Öy 20 MC25~033(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 application for a Pem7/t to Dnll must be accvmpanied by each of the following ¡[em5~ except lor an Item already on HIe with the commi85io/7 and icfentifïed in the app/ic{~tion: (10) for an exploratory or stratigrr:-:¡phic test well a sei8mic rekaction or reflection analyst:'i as required by 20 MC 25.061(8)': 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 8 Permit to Drill must be accompanied by each of the fallowing item~ except for an item already on file with the commiS5ion and identified in the application: (1.1) for a well dr/lIed from an off.;;l7ore platform/ mobile bottom-founded st7'ucture/ )ack-'up r~q/ or floating dr/lling vesse¿ an analysis olseabed conditions as' required by 20AAC25~06.l{b)/ Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An applkëJtion for a Permit to Drill must be accompanied by each of the following item!;.~ except tar an item already on file wIth the commission and Identitied in the application: (12) eVIdence showing that the requirements of 20 MC 2.5.02.5 {Bonding}have been met; Evidence of bonding for Phillips 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 ot'the following Item.~ except fÒr an item already 0/7 file with the commt:'isiol7 and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4¡ Well Schematic. 1C-109L 1 PERMIT IT. doc 0 f1rGYfv~ L i ff ~() j1 (' AP( 'ion for Permit to Drill, We1l1C-109L 1 Revision No.O Saved: 11-0ct-01 Note: Steps 1-14 are to be permitted as lC-l02 and are included here for information only 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 158' RKB. Weld landing ring on conductor. Install Vetco Gray Gen II wellhead. 2. Move in / rig up Nabors 245e. Install Diverter / BOPE and function test. 3. Spud and directionally drill 9-7/8" hole to casing point at +/- 5017' MD / 3804' 1VD as per directional plan. Run MWD, LWD tools as required for directional monitoring and data gathering. 4. Run and cement 7-5/8", 29.7#, L-80, BTC Mod casing to surface. Displace cement with mud and perform stage job or top job if required. Note: Port collar to be run @ +/- 1000' MD. 5. Remove 16" Diverter line, install blind flange, activate and test BOP's to 2500 psi (annular preventer to 1500 psi) Notify AOGCC 24 hrs before test. 6. PU 6-3/4" PDC Bit and directional BHA. RIH, clean out cement to top of float equipment, pressure test casing to 3000 psi for 30 minutes and record results. 7. Drill out cement and between 20' and 50' of new hole. Perform FIT not to exceed 12.0 ppg EMW and record results (ECD's estimated not to exceed 11.5 ppg) 8. Directionally drill 6-3/4" hole to TD at +/- 7,513' MD / 3,800' 1VD as per directional plan. 9. POOH and lay down MWD, LWD and PWD tools. 10. Pick up and rack back weight pipe as needed for liner running. 11. RIH with 6-3/4" hole opener and ream entire open hole. 12. Circulate and condition hole to run liner. 13. PU and run 4-1/2" Slotted Liner (run liner with 2-7/8" inner wash string). . Land liner, set liner packer @ +/- 4,693' MD / 3736' 1VD and displace drilling mud with 30/0 KCL brine weighted to 8.9 ppg, mixed with seawater and previously weighted brine. POOH. ... Note: Remaining operations are part of this lC-l09 Ll Application for Permit to Drill. 1. Run and set Baker 2-trip whipstock system, 30 degrees to left of high side at window point of 4,601' MD / 3,734' 1VD 2. Displace wellbore to used Baradril'N fluid from the lower lateral. 3. Mill starting window in D-sand. POOH. 4. Polish and complete window with finishing mill and 2 watermelon mills. 5. Pick up 6" drilling assembly, RIH, and drill 20-50 feet of new hole. 6. Change over to clean BaraDril'N drilling mud. 7. Perform Formation Integrity Test to 12.0 ppg EMW. 8. Continue to directionally drill to TD of D sand lateral at 7,508' MD / 3,746' 1VD. POOH. 9. POOH and lay down MWD, LWD and PWD tools. 10. RIH with 6" hole opener and ream entire open hole. 11. Circulate and condition hole to run liner. POOH and lay down hole opener assembly. 12. RIH with whipstock retrieval tool to whipstock. Retrieve whipstock and POOH. 13. PU 4" Liner with flanged hook hanger, CMD, and 4-1/2" slotted liner and 2-7/8" inner wash string. 1C-109L 1 PERMIT IT. doc 0 RrGrfij~ L ( Ap( ion for Permit to Drill, Well 1 C-109L 1 Revision No.Q Saved: 11-0ct-0 1 14. RIH, until Hook Hanger is just above window. Orient hook hanger to window with MWD tool and land hanger. 15. Release hanger running tool and POOH. 16. Make up diverter on GS running tool and RIH. Set diverter in Hook Hanger and POOH. 17. Make up 2-7/8" cup tool assembly and inner wash string and RIH to TO. 18. Displace drilling mud from outside the liner with 3% KCL brine weighted to 8.9 ppg. Pick up and disengage from pack off bushing and displace mud from inside the liner with 3% KCL brine weighted to 8.9 ppg. POOH. 19. RIH with GS running tool on 4-1/2" completion tubing. Circulate the main bore with clean brine at 8.9 ppg. at a high rate. Run dummy ESP through tubing string on wireline. Latch into diverter and unsnap diverter from Hook Hanger. POOH, standing back tubing. 20. Make up ESP and components as required and RIH. Run heat trace on tubing through permafrost zone. 21. Land tubing with ESP above window. Install SPY, nipple down stack, nipple up and test tree. Pull SPY. Freeze protect well with diesel by pumping into annulus, taking returns from tubing and allowing to equalize. 22. Set SPV and move off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for ð PermIt to Drill mustc be accompanÙ:;d by each of the following Itern~ except for an Item already on file with the commission and identlfìed 1Ì7 the applìG1tion: (14) a general descriptìon of how the operator plans to di!.>f)ose of drilling mud and cutt1i7gS and a statemt?l7t of whether the operator lntend,,; to request authorìzatìon under 20 MC 25:080 {'Or an annular di.,,;pos'81 operation in the wel/,/ Waste fluids generated during the drilling proce.ss ~inbß..d.ispq~~d. of either by pumping authorized fluids into a permitted annulus 9f.l .~'c--Pad; 'O'fiby'.haÜnrl'çfthe fh,i¡dstô"ë1 K'Rü' Class 'II' disposal well. All cuttings generated will be disposed of either down a permitted annulus on lC Pad or hauled to the Prudhoe Say Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. Phillips Alaska does not intend to request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Diagrams of the BOP / Diverter System Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic 1C-109L 1 PERMIT IT. doc rr !1'" Faae 7 of 7 V Ft!G11q A L Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 1 C Pad 1 -1 09( I i) ( 01) Reference is True North Well: Current Well Properties Plan: 1C-109 Horizontal Coordinates: Ref. Global Coordinates : Ref. Stucture Referance : Ref. Geographical Coordinates: 5968746.59 N, 561706.13 E 229.60 N, 664.05 W 70° 19' 30.5440' N, 149" 29' 58.6776' W (1487' FNL & 699' FWL, Sec 12-T11N-R10E) 1 01.9Oft above Mean Sea Level True North Feet (US) RKB Elevation: North Reference: Units: Scale: 1 inch = 400ft Þ4 H~fFíburt!Qfl ¡Q~iBf1¡; 3400 DrillQuesl 2.00.09.003 Top of Whipstock (7-518" Csg) Begin Dir @ 15.9"/100ft: 4601.0011 MD, 3733.83ftTVD Begin Ralhole (6' Hole) @ 79.65" : 4613.ooft MD, 3736. 16ft TVD Begin Dir @ 12.0°/10011: 4631.OOIt MD, 3739.40ftTVD End Dir, Start Sail @ 90.87° ; 4730.15ft MD, 3747.58ftTVD Begin Dir @ 5.0"i1ooft: 4937.47ft MD, 3744.43ft TVD 400 1200 800 ..... - 0 0 to II .!: g -600 T""" Q) CtS 0 (f) -1200 en g> ~-1800 -2400 1600 0 -1200 -1200 1C-109D (wp01) 2000 Eastings 0 600 -600 0 Top of Whipstock (7-518" Csg) Begin Dir @ 15.9"/10011: : 4601.0011 MD. 3733.8311 TVD : Begin ~athole (6' Hole) @ 79.65" : 461,3.00ft MD, 3736.16ft TVD I I Begin Dir @ 12.00/10fft: 4631.0011 MD. 3739.4011 TVD .. \ End Dir, Start Sail @ 90.87J: 4730.15ft MD, 3747.5811 TVD \ I 3744,3 \ Begin Dir @ 5.0°/10011: 4937.47'1 MD. 3744.4311 TVD rU(6~Ä~;;i'-'Ë:~~~uÖ,~:si:;;!<;,¡i;iÔ:),'i::::":'Aij;''i.:i.i ¡ ¡f;i6.';¡7t.:; ::;., i ¡':, ',ii; i._._------------_5.~~-~~'-~.~¡- &. ~: 11:' FEi... ~~t.::.':1 1 L T 11 i'i - f~ 1(~Ej I ¡ ¡ -600 -1200 3744.6 3744.g -1 800 Õ 0.. ,~ CO a- 0 ~ c; 0.. ¿ 0 m 0 0 3745.6 -2400 -- -600 0 600 -----~---_.._-~ . , . ./~--,~y,-.-:!)!t ~JL;. T;,~~, ::(;')I~ TVI) '~,.: ". Till." H IOf', , T----_n - + 4-1/2" lirer 7507.8ft MD 3745.9ft TVD lC-l09B (",,-pOl) 2400 2800 3200 c::> :::c - ~ -- :æ: )::::.. r-- Kuparuk River Uni~ North Slope, Air Kuparuk 1 C, $Iot Plan: 1C-109ì'j¡¡1C-10 Revised: 10 C1~tQ~f3r, 2001 -.. OSAL REPORT 10 October, 2001 Your Ref: per Prelim Plan version #3 Surface Coordinates: 5968746.59 H, 561706.13 E (70019' 30.5440" H, 149029' 58.6776" W) Surface Coordinates relative to Project H Reference: 968746.59 N, 61706.13 E (Grid) Surface Coordinates relative to Stucture Referance: 229.60 H, 664.05 W (True) Kelly Bushing: 101.9Oft above Mean Sea Level -. SuY~5L1 . arf1',¡;.t:;tÑèft.i'~"'''ÆWHV'~:C';;:. Amtfkitt-~ eu~~f Proposal Ref: pr09645 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-109 -1C-109D (wp01) Your Ref: per Prelim Plan version #3 Revised: 10 October, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northin9s Eastin9s Northin9s Eástinas Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) 4601.00 77.941 181.282 3631.93 3733.83 82.06 N 929.45 W 5968821 E -82.06 Top of Whipstock (7-5/8" Csg) Begin Dir @ 15.9°/100ft : 4601.00ft MD, 3733.83ft TVD 7-5/8" Casing - 4601.33 77.988 181.258 3632.00 3733.90 81.74 N ~~~ti~,.~'. 5968820.69 N 560776.03 E 15.900 -81.74 Top West Sak D 4613.00 79.650 180.416 3634.26 3736.16 70.29 N 5968809'123 N 560775.96 E 15.900 -70.29 Begin Rathole (6" Hole) @ 79.65° : 4613.00ft MD, 3736.16ft TVD 4631.00 79.650 180.416 3637.50 3739.40 929175 W 5968791.53 N 560775.98 E 0.000 -52.58 Begin Dir @ 12.0o/100ft: 4631.00ft MD, 3739.40ft TVD 4700.00 87.456 177.635 3645.24 928.58 W 5968723.04 N 560777.72 E 12.000 15.91 4730.15 90.870 176.437 3645.68 927.02 W 5968692.96 N 560779.52 E 12.000 46.01 End Dir, Start Sail @ 90.87° : 4730.1 MD, 3747.58ft TVD 4800.00 90.870 176.437 922.68 W 5968623.29 N 560784.44 E 0.000 115.72 4900.00 90.870 176.437 916.46 W 5968523.55 N 560791.47 E 0.000 215.51 4937.47 90.870 176.437 914.14 W 5968486.18 N 560794.10 E 0.000 252.90 Begin Dir @ 5.00/100ft : 4937.47ft M 3744.43ft TVD 5000.00 315.39 S 911.90 W 5968423.71 N 560796.85 E 5.000 315.39 5011.72 327.10 S 911.85 W 5968412.00 N 560797.00 E 5.000 327.1 0 (D-Heel) End Dir, Start Sail @ 89.95° 5011.72ft MD, 3743.90ft TVD Target - 1 C-1 09 (D-Heel), Current Target 5100.00 89.954 180.035 3642.07 3743.97 415.39 S 911.90 W 5968323.72 N 560797.67 E 0.000 415.39 ~~ 5200.00 89.954 180.035 3642.15 3744.05 515.39 S 911.97W 5968223.72 N 560798.43 E 0.000 515.39 5300.00 89.954 180.035 3642.23 3744.13 615.39 S 912.03 W 5968123.72 N 560799.19 E 0.000 615.39 5400.00 89.954 180.035 3642.31 3744.21 715.39 S 912.09 W 5968023.73 N 560799.96 E 0.000 715.39 5500.00 89.954 180.035 3642.39 3744.29 815.39 S 912.15 W 5967923.73 N 560800.72 E 0.000 815.39 5600.00 89.954 180.035 3642.47 3744.37 915.39 S 912.21 W 5967823.73 N 560801.48 E 0.000 915.39 5700.00 89.954 180.035 3642.55 3744.45 1015.39 S 912.27 W 5967723.74 N 560802.24 E 0.000 1015.39 C) 5800.00 89.954 180.035 3642.63 3744.53 1115.39 S 912.33 W 5967623.74 N 560803.00 E 0.000 1115.39 ::0 5900.00 89.954 180.035 3642.71 3744.61 1215.39S 912.39 W 5967523.74 N 560803.76 E 0.000 1215.39 -- Ç':) - :z ):::a. r--tõ October, 2001 - 7:49 Page 2 of5 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-109 -1C-109D (wp01) Your Ref: per Prelim Plan version #3 Revised: 10 October, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings §~§U.,g~ Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (Q) (°/1 OOft) 6000.00 89.954 180.035 3642.79 3744.69 1315.39 S 912.45 W 560804.52 E 0.000 1315.39 6100.00 89.954 180.035 3642.87 3744.77 1415.39S 912.52 W 560805.28 E 0.000 1415.39 6200.00 89.954 180.035 3642.95 3744.85 1515.39S 912.58 W 560806.05 E 0.000 1515.39 - 6300.00 89.954 180.035 3643.03 3744.93 1615.39S 912.64 W 560806.81 E 0.000 1615.39 6400.00 89.954 180.035 3643.11 3745.01 1715.39 S W 560807.57 E 0.000 1715.39 6500.00 89.954 180.035 3643.19 3745.09 5966923.76 N 560808.33 E 0.000 1815.39 6600.00 89.954 180.035 3643.27 3745.17 5966823.76 N 560809.09 E 0.000 1915.39 6700.00 89.954 180.035 3643.35 3745.25 5966723.77 N 560809.85 E 0.000 2015.39 6800.00 89.954 180.035 3643.43 3745.33 5966623.77 N 560810.61 E 0.000 2115.39 6900.00 89.954 180.035 3643.51 3745.41 5966523.77 N 560811.37 E 0.000 2215.39 7000.00 89.954 3643.59. . 913.07 W 5966423.77 N 560812.13 E 0.000 2315.39 7100.00 89.954 3643.67 913.13 W 5966323.78 N 560812.90 E 0.000 2415.39 7200.00 89.954 364;3."?5 913.19 W 5966223.78 N 560813.66 E 0.000 2515.39 7300.00 89.954 3643;83 913.25 W 5966123.78 N 560814.42 E 0.000 2615.39 7400.00 89.954 3643:91 . 913.31 W 5966023.79 N 560815.18 E 0.000 2715.39 7500.00 3745.89 2815.39 S 913.37 W 5965923.79 N 560815.94 E 0.000 2815.39 7507.79 3745.90 2823.17 S 913.38 W 5965916.00 N 560816.00 E 0.000 2823.17 Total Depth (D-Toe) : 7507.79ft MD, 3745.90ft TVD 4-1/2" Liner Target - 1 C-1 09 (D-Toe), Current Tar .-.., All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 101.9' MSL. Northings and Eastings are relative to 1481' FNL & 699' FWL. Magnetic Declination at Surface is 26.104° (08-0ct-01) The Dogleg Severity is in Degrees per 100 feet (US). c:)ertical Section is from 1481' FNL & 699' FWL and calculated along an Azimuth of 180.000° (True). ~ased upon Minimum Curvature type calculations, at a Measured Depth of 7507.79ft., ðe Bottom Hole Displacement is 2967.25ft., in the Direction of 197.928° (True). - :æ:: )::.. ~ 10 October, 2001 - 7:49 Page 3 of 5 DrillQuest 2.00.09.003 Kuparuk River Unit Comments Measured Depth (ft) Sperry-Sun Drilling Services Proposal Report for Plan: 1C-109 -1C-109D (wp01) Your Ref: per Prelim Plan version #3 Revised: 10 October, 2001 4601.00 3733.83 82.06 N 4613.00 3736.16 70.29 N 4631.00 3739.40 52.58 N 4730.15 3747.58 46.01 S 4937.47 3744.43 252.91 S 5011.72 3743.90 327.11 S 7507.79 3745.90 2823.17 S Formation Tops Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment North Slope, Alaska Kuparuk 1 C ~'- 929.45 W 929.63 W Top of Whipstoc Begin Rathole (6' r @ 15.9°/1 OOft: 4601.00ft MD, 3733.83ft TVD .00ft MD, 3736.16ft TVD Begin Dir @ 12.0(!¥100ft:~631.00ft MD, 3739.40ft TVD End Dir, Start Sail'@ 90;87° : 4730.15ft MD, 3747.58ft TVD Begin Dir @ 5.0"/100ft: 4937.47ft MD, 3744.43ftTVD (D-Heel) End Dir, Start Sail @ 89.95° : 5011.72ft MD, 3743.90ft TVD Total Depth (D-Toe) : 7507.79ft MD, 3745.90ft TVD Formati on Plane (Below Well Origil1). .... . Sub-Sea Dip' ...Dip Dir. (ft) Deg.. .... Deg.... 1669.00 2199.00 3068.00 3352.00 3391.00 0.000 0.000 0.000 0.000 0.000 3540.00 3632.00 3673.00 3694.00 0.000 0.000 0.000 0.000 C:'> =c --- ç:) - ==== :t::=. r 10 October, 2001 - 7:49 . <0.471 0.471 0.471 0.471 0.471 1905.71 2601.27 3569.67 3953.76 4019.83 0.471 0.471 0.471 0.471 4332.24 4601 .33 1770.90 2300.90 3169.90 3453.90 3492.90 3641.90 3733.90 Penetration Poi n t Sub-Sea Depth Northings Eastings Formation Name (ft) (ft) (ft) 1669.00 440.19 N 216.93 W Base Permafrost 2199.00 842.78 N 418.87W Top K-15 ~ 3068.00 887.21 N 739.80 W Top Ugnu C 3352.00 653.27 N 840.59 W Top Ugnu B 3391.00 601.70 N 854.11 W Top Ugnu A 3540.00 332.14 N 904.56 W K-13 Shale 3632.00 81.74 N 929.46 W Top West Sak D Top West Sak C Top West Sak B Page 4 of 5 DrillQuest 2.00.09.003 Kuparuk River Unit Casing details From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) <Surtace> <Surtace> 4400.00 3671.63 4601.00 7507.79 3733.83 3745.90 Targets associated with this wel/path Target Name 1 C-1 09 (B-H eel) 1 C-1 09 (B-Toe 1 C-1 09 (D-Heel) 1 C-1 09 (D-Toe) c -=--, ! ..-. '- Sperry-Sun Drilling Services Proposal Report for Plan: 1C-109 -1C-109D (wp01) Your Ref: per Prelim Plan version #3 Revised: 10 October, 2001 Casing Detail 7-5/8" Casing 4-1/2" Liner Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3803.90 326.90 S 936.85 W Mean Sea Level/Global Coordinates: 3702.00 5968412.00 N 560772.00 E Geographical Coordinates: 70° 19' 27.3281" N 149030' 26.0245" W 3799.90 2822.97 S 938.38 W Mean Sea Level/Global Coordinates: 3698.00 5965916.00 N 560791.00 E Geographical Coordinates: 70° 19' 02.7771" N 149° 30' 26.0599" W 3743.90 327.10 S 911 .85 W Mean Sea Level/Global Coordinates: 3642.00 5968412.00 N 560797.00 E Geographical Coordinates: 70° 19' 27.3261" N 149030' 25.2947" W 3745.90 2823.17 S 913.38 W Mean Sea Level/Global Coordinates: 3644.00 5965916.00 N 560816.00 E Geographical Coordinates: 70° 19' 02.7751" N 1490 30' 25.3304" W North Slope, Alaska Kuparuk 1 C Target Target Shape Type Point Current Target Point Current Target Point Current Target ~"-. Point Current Target r 10 October, 2001 - 7:49 DrillQuest 2.00.09.003 Page 50f5 Company: Field: Reference Site: Reference Well: Reference Wellpath: Phillips Alaska Inc. Kuparuk River Unit Kuparuk 1 C Pad Plan: 1 C-1 09 Plan: 1C-109D ( Sperry-SUD Anticollision Report (' Date: 10/10/2001 Page: Time: 14:26:53 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan: 1C-109, True North 1 C1 091 N245-1 01.9' RKB 101.9 Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cyfinder North Ellipse + Casing GLOBAL SCAN APPLIED: All wellpaths ",ithin 200'+ 100/1000 of reference Interpolation Method: MD Interval: 50.00 ft Depth Range: 4600.80 to 7507.80 ft Maximum Radius: 946.66 ft Reference: Error Model: Scan Method: Error Surface: SUr\'ey Program for Definitive Well path Date: 10/10/2001 Validated: No Planned I<'rom To Survey ft ft 41.20 900.00 900.00 4600.80 4600.80 7507.80 Planned: 1C-109D WP01 V1 (0) Planned: 1C-109D WP01 V1 (0) Planned: 1C-109D WP01 V1 Version: TooIcode Tool Name CB-GYRO-MS MWD MWD Camera based gyro multishot MW D - Standard MW D - Standard Casing Points MD TVD ft ft 4600.80 3733.80 7507.80 3746.11 Diameter in 7.625 4.500 Hole Size in Name 9.875 6.000 7 -5/8" 4-1/2" Summary <-".........--...-......-.... Offset Wellpath.. -.........--............--> Site Well Wellpath -----______0____- Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad 1 C-03 1 C-04 1 C-05 1 C-06 1 C-07 1 C-08 1 C-09 1 C-1 0 1 C-1 02 1 C-1 02 1 C-111 1 C-11 1 C-117 1 C-119 1 C-121 1 C-12 1 C-123 1 C-127 1 C-13 1 C-16 1 C-17 1 C-18 Plan: 1 C-129 Plan: 1C-109 Plan: 1C-125 1 C-03 V1 1 C-04 V1 1 C-05 V1 1 C-06 V1 1 C-07 V1 1 C-08 V1 1 C-09 V1 1C-10V1 1 C-1 02 'B' Lateral VO 1 C-1 02 'D' Lateral V2 1C-111VO 1C-11 VO 1C-117 V1 1C-119 VO 1C-121 V1 1C-12 VO 1C-123 V5 1C-127 V5 1C-13 VO 1C-16VO 1C-17VO 1C-18 VO 1C-129 VO Plan: C-Sand 1C-109B (WP01) V1 Plan 1C-125 V2 Plan: 1C-125 Reference Offset Ctr-(!tr No~Go Allowable MD MD Distance Area Deviation Warning ft ft ft ft ft 5826.84 4150.00 686.70 140.15 568.99 Pass: Major Risk 4889.98 4050.00 162.21 118.75 48.45 Pass: Major Risk Out of range Out of range Out of range Out of range 4613.86 3950.00 802.23 126.00 682.14 Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 5966.76 4100.00 591.11 165.92 433.42 Pass: Major Risk 4600.80 4600.00 0.80 0.86 -0.02 FAIL: No Errors Out of range ----- ORIGINAL WB.L DEI' AlL'> ."-''-.''TI.COLLISION SETTINGS SURVEY PROGRAM ro~wA.'J''f DEL"-Il.\) Wf']JJ'.-\1111)f:I^II-~ '""" +Nf-S +EI-W Nordling Ea~tmg L1Iitude Longitude Slot Depth Fm lJep"' To Surw)'lPlan Ttwl ,,,...,. l\h.t.l [n:, 'lurIC'.n-JI) Interpolation MethodMD Interval: 50.00 1:rp,."'In.~ ~'If"VÚ<. 1.<f'"1:11W,-I."LIJL ('. IIJ-JB!\\"'f1) Ian: 1C-109 229,68 --664, iO 5%874659 56lï06.13 71r19'305I4N t49"2'l58.678W NJA Depth Range From: 4600.80 To: ï507.80 .(,oo.oo 7507.00 Plam1<Xl: lC-tfJ9DWPOI VI MWD li'IfI:\m: (.{(ò.:m Maximum Range: 946.66 Reference: Plan: IC-I09D WPOI C:s:.."tIl¡¡,;' ~kdlld: ~h"'I1":III( 'UI\;;J/~.: rlfl'l"S;~'m ''''("ws/\ k!:; J-'Iql}. I SI"AI' ~1.."lhxl; Tr,'.-()in!..1 :-;."ftJ.¡ H,'f. I'.~UI~I I{'I('}/ :\.I,",~.IOI.'r HKL! WI.'X~ Enll( SI,J'{;k--.;: l:1froti.ll... C'.a..it: V'it',IPn OI"ÇII Orr.:ß SI..:1"t~ . 0-10 1 C-08 \\."w1I~ ~kdm: Rui'.' [\,)........1 ''".:l' ..:\i_"i ...I:¡.W r,,'ndV) '9 (1 0 l'/ï.'J'\" o,w r,W iJ,9-) 0-109 i53 'lJ(Ùh-. ~ 1 C-07 ID 50 -40 -30 -20 10 0 '--10 20 --"'30 4601 4700 4700 - 4800 4800 4900 4900 - 5000 5000 5100 5100 - 5200 5200 ~-~ 5400 5400 - 5600 5600 5800 5800 - 6000 6000 6200 6200 - 6400 6400 - 6600 6600 - 6800 6800 - 7000 7000 - 7200 7200 - 7400 7400 7600 -." 90 LEGEND IC-03 (JC-03). Major Risk IC-04 (lC-04). Major Risk I C-05 (J C-OS), Major Risk IC-06 (JC-06). Major Risk I C-07 (J C-07), Major Risk I C-08 (I C-OS), Major Risk I C-09 (I C-09), Major Risk IC-IO (IC-IO), Major Risk IC-102 (IC-I02 'H' Lateral). rvlaj' IC-102 (IC-102 'I)' Lateral). Maj IC-III (lC-III), Major Risk IC-II (IC-II), Major Risk I C- J 17 (I C-I ) 7), Major Risk IC-119 (lC-119), Major Risk I C- J 21 (J C-121), tv1ajor Risk IC-12 (JC-12), Major Risk I C- J 23 (I C-123), Major Risk I C-I27 (J C-127), Major ~ IC-13 (JC-13), Major R; ~ IC-16 (lC-16), Major Rl. I C-17 (I C-17). Major Risk I C-18 (J C-lS), Major Risk Plan: I C-129 (I C- J 29), Major R Plan: I C- J 09 (I C- J 09B (WPO I », . . --.- ...... ~. Plan: J C-I 09D IC-109D WPOI lC-109 (wpO.l) IfJ9D WPOI (plan: iC-lfJ9lPlan: IC-IfJ9D) "<"Ied ~< EgedaW 0.,<: )01101200] .:::~.t~-~- SI'CllON DI.,T""$ S.x MD II>': ,\I'Î TVIJ +NJ.,\ ./:I.W /)/.cF 'If""," YSf(' T ;u,d 41;00,80 77. Y4 lKI.29 \7>:'.30 :-ï2.2~ -1)19.41 O,m o,m '::07.1N 4613,70 79.6.'; ISO,13 :t7VdO (n,(,1 .9~IJ.:¡¡¡ 15.1)2 .~2ri:.1 211J.9X ~ó30.80 7Y.f,5 IXO,n J7.IY.JK 51.ï9 -1)29.(,) 1),(1) I)"~I 2.':i.Y) 472'>,(,1) 9O.S3 17(.54 J747.4X -4-1.4cj ."2(,.'.C¡ 12.1;.1 :;'12.07 .'17.1-.4 49.N.OO 90,~3 176.54 .\74,1.-12 -2..'i~.Oh .1)14.02 n.tX) O.(O 52,1.111 5011.70 K9.95 ISO.fH ~74:;.9.' '27,11 .IJun 5.HI IfH.IO <;1'1.97 7:1û7.XO RIJ.95 IXO,OI :<7,16,11 -2X~.~,21 IJU.hl om 0,00 2¡jI,7.Y, -.,... 1 C-09 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [20ft/in] Dalc:- Date:- 13-5 Diverter I ~~p System Elevations(' \labors Rig 245e West Sak Multilateral Wells ... ø Top of annular preventer WHEN I I RAISED TO MAXIMUM HEIGHT 31.85 ft. POSSIBLE WITH BOP CRANE ~ .. L:ti~~ :;op t matts under cellar box When measurements were made, Drill Module was on one set of matts. I----ç--------------~Ll '..., ,,' '''"", ".' ... ø Elevation of top of annular preventer, nippled up Top of kill line window. ø I 31 .26 ft. I I 22.99 ft. I Top of drilling spool 1 23.34 ft. I ... ø 1 22.16 ft. I ~ . Centerline of Kill line. ~ 122.16 ft. 1 ... ø Centerline of choke line. r---- , . " I I I I L___- ¡ 21.01 ; I Bottom of kill line window. ø Top of Spacer Spool Top of Vetco Gray 13-5K Diverter Spool, 8.51 ft. (102.12") ~ ~ Top of diverter line window in cellar wall, ~ 7.34 ft. 3 ø ~ Center Line of 16" Diverter Line ~ 6.58 ft. Top of Vetco Gray 13-5K Well Head, 4.67 ft. (56.12") 2 All Measurements are from Pad Level - i.e. Bottom of Matts = 0.00 ft. ø Pad Level 0.00 ft. KEY: 1. Landing Ring, 16" x 13-5/8", Vetco Gray, with 7-5/8" Casing Landed, Vetco Gray. 2. Well Head, 10-3/4" Vetco Gray Quick Connect Bottom x API 13-5/8" 5000 psi Flange Up, Vetco Gray. 3. Diverter Spool, 13-5/8" x 13-5/8" 5000 psi top and bottom with API 16-3/4",5,000 psi side outlet, Vetco Gray. 4. Spacer Spool(s), 13-5/8" 5000 psi x 13-5/8" 5000 psi,9.5 ft long, Nabors. 5. Single Ram BOP, 13-5/8" x 5000 psi, with pipe rams, Nabors Top of choke line window. 23.34 ft. I . ----1 . . ., I I , I ____03 ~ . 21.01ft. Bottom of Choke line window. . ----1 . . ., I , , I ____03 . Bottom of Diverter line window in cellar wall. 4.15 ft. 6. Drilling Spool, 13-5/8" x 5000 psi, w/2 Side Outlets, Nabors 7. Double Ram BOP, 13-5/8" x 5000 psi, with Pipe Rams on Top and Blind Rams on Bottom, Nabors 8. Annular BOP, 13-5/8" x 5000 psi, Hydril GK, Nabors 9. Choke Valve, Manual Operation, 4-1/16" x 5,000 psi, Nabors 10. Choke Valve, Hydraulically Operated, 4-1/16" x 5,000 psi, Nabors 11. Kill Line Valve, Manual Operation, 3-1/8" x 5,000 psi, Nabors 12. Kill Line Valve, Hydraulically Operated, 3-1/8" x 5,000 psi, Nabors ( ( r--- EFSO 16-3/4" 5,000# 8X162 LIì f'. f'. 0 ill 0 N ROTATING FLANGE 13-5/8" 5,000# ax 160 (2 PLACES) 0 0 ~ N EFSO 3-1/8" 5,000# R35 (2 PLACES) r Ø26.50 l 0 0 f'. QUOTE: 1976 ORIGINAL DATE: 01/05/01 DWG. UPDATE AS PER CUST. RQST.: 06/01/01 ACADEMY PETROLEUM INDU~TRIE~ EDMONTON, ALBERTA, CANADA TEL: (780) 466 6360 FAX: (780) 466 6380 DWG. NAME: DRilLING SPOOL 13.63-5,DOD# ROT, MAIN LAYOUT FILE: DRSP RT 13 CW EFSOS DATE: 06/01/01 ABB Vetco Gray ORIGINAL ( ( iC-l09 Li Drilling Hazards Summary (SEE WELL PLAN FOR DETAILED DISCUSSION OF THESE RISKS) 6" 0 en Hole Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low Low Miti ation Strate Stripping drills, Shut-in drills, Increased mud wei ht. Good hole cleaning, PWD Tools, Hole 0 ener Decreased mud wei ht Reduced urn rates Mud rheolo LCM Trip speeds, Proper hole filling (use of trip sheets, Pum in out Lost Circulation Hole Swabbing on Trips Low Moderate 1 C-1 09 L 1 Drilling Hazards Summary prepareõ RÎ ffiÑ A L Well # 1 C-1 09, ( FE #AK0209 West Sak Multilateral Well Planned Completion Schematic Sheet 1 of 4: Casing String Details Tubing Head Assy, (497-0055) Vetco-Gray Gen II for Single Completio~ API 13-5/811 5000 psi Flange up x Vetco 13-5/811 Female Overshot Bottom Casing Head: ~ Vetco-Gray, 1611 Weld on Bottom x 13-5/811 Male Overshot Top 1611 Conductor ~ @ +/-158' MD Centralization: Weatherford 7-5/8" x 10-1/2" Bowspring (1) on each collar from 4000' to Float Collar (1) on a stop collar in the middle of the joint below the float collar (1) on a stop collar in the middle of the joint above the float shoe (1) on each of the three collars above and below the port collar \ø( î~ø(~ ~ ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Nabors Rig 245 R KB @ 0' Eastings: 561 ,706.13 Northings: 5,968,746.59 Elevation: 101.9' AMSL Casing Hanger: (49ï-0030) Vetco-Gray, with 7-5/811,29.7#, BTC pin down x Acme box up Port Collar: (485-7080)TAM, 7-5/8", 29.7#, L-80, BTC Pin Set @ +/- 1000' MD / 988' TVD (x) Pup Joints Casing: ~ 7-5/8",29.7#, L-80, BTCM, as ------ required to space out window joint. (498-6805)4 foot pup (498-6800)6 foot pup (498-6795)10 foot pup ~ {477-8475)20 foot pup ------ (x) Joints Casing: (463-4825)7-5/8",29.7#, L-80, BTCM ~ <II( Float Collar: Weatherford Model 402, 7-5/8", 29.7#,BTCM (463-4827)Joint with Float Shoe (2) Joints Casing: 7-5/811,29.7#, L-80, BTCM (463-4828)Joint with Thread Locked Box ~ ~ Float Shoe: ~ Weatherford Model 303, 7-5/8", 29.7#, BTCM TD 9-7/811 Hole: (463-4826)Joint with Float Shoe 5,017 MD / 3,804' TVD 1C-109 Planned Completion Schematic rmmmAíiEi Well # 1C-109, AFE #AK0209 West Sak Multilateral Well PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Planned Completion Schematic Sheet 2 of 4: Lower Lateral Liner Details See Sheet 1 for Casing Details ~~J" ~"C~l-, -~~~,~ ~- ("""=-1--'" Liner Top Packer Set @ +/- 4,693' MD / +/-3,736' TVD Surface / Production Casing 7-5/811 29.7# L-80 BTC Mod Set @ 5,017' MD /3,804' TVD (1) Set Shoe Assembly, consisting of: (1) Set Shoe, Baker Model 'GPV', 5.56011 Max OD, 511, 18# SLHT Box (492-1550) (1) Crossover, 4" SLHT Box x 511 SLHT Pin (PAl supplied, 492-1915) (1) Joint Tubing, 4",9.5#, L-80, SLHT (PAl supplied, 492-1220) (1) Crossover, 4-1/2",12.6#, NSCT Box x 4",9.5#, SLHT Pin (PAl supplied, 500-3030) ---.. (x) Joints 4-1/2" Slotted Pipe, 4-1/2", 12.6#, L-80, NSCT (PAl supplied, ---) (1) Crossover Sub, 411, 9.5#, SLHT box x 4-1/2", 12.6#, NSCT Pin (PAl supplied, 500-3040) (1) Joint Tubing, 4", 9.5#, L-80, SLHT (PAl supplied, 492ø1220) (1) Crossover, 4-1/2", 11.6#, SLHT Box x 4",9.5#, SLHT Pin (PAl supplied, 492-1915) (1) Sliding Sleeve, Baker Model 4-1/2" 'CMD', w/3.43" ID, 4-112",11.6# SLHT Box x Pin (492-1510) (2) Joints 4-1/2" Blank Pipe, 4-1/2", 11.6#, L-80, SLHT (PAl supplied, -----> (1) Crossover Sub, 5-1/2",17#, SLHT Box x 4-1/2",11.6# SLHT Pin (PAl supplied, ---) (1) Packer Assembly (496-9670), Baker, consisting of: (1) Mill Out Extension, Baker, 3' Long, 5-1/2", 23# SLHT pin x pin (1) Packer, Baker Model 'SC1-R' (76B2-40), 7-5/8", 24-29.7#, wI 5-1/2", 17#, SLHT box down. -,. 611 Open Hole TD: 7,513' MD /3,800' TVD ----------------------------------------- ----------------------------------------. ----------------------------------------- ---------------------------------------- Centralizers: 4-1/2" x 5-3/4" Rigid Straight Blade on every other joint in open hole 1 C-1 09 Planned Completion Schematic Sheet 2 of 4: Lower Lateral Liner Details prepared by Steve McKeever October 10, 2001 See Sheet 1 for Casing Details Well # 1C-109, AFE #AK0209 West Sak Multilateral Well Planned Completion Schematic Sheet 3 of 4: Upper Lateral Liner Details PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY (1) Set Shoe, 3-1/2", Baker Model 'GPV', (4.50" Max 00), 3-1/2", 9.2#, SLHT Box. (496-fJ685) (1) Joint 3-1/2" Bent Pipe, Baker, 3-1/2", 9.2#, L-80, SLHT, Length 18.5'. (496-9695) (1) Crossover Sub, 4", 9.5#, SLHT Box x 3", 9.2#, SLHT Pin (Phillips supplied, 500-3050) (1) Joint Tubing, 4", 9.5#, L-80, SLHT (PAl supplied, .192-1220) (1) Crossover, 4-1/2", 12.6#, NSCT Box x 4",9.5#, SLHT Pin (PAl supplied, fJOO<Kno ) .,-.." (x) Joints 4-1/2" Slotted Pipe, 4-112", 12.6#, L-80, NSCT (PAl supplied, -----> (1) Crossover Sub, 4",9.5#, SLHT box x 4-1/2", 12.6#, NSCT Pin (PAl supplied, 500-3040) (1) Joint Tubing, 4",9.5#, L-80, SLHT (PAl supplied, 492-1220) (1) Crossover, 4-1/2",11.6#, SLHT Box x 4", 9.5#, SLHT Pin (PAl supplied, '1f!2-1915) (1) Sliding Sleeve, Baker Model 4-1/2" 'CMD', wI 3.43" 10, 4-1/2",11.6# SLHT Box x Pin (492-1510) (2) Joints Tubing, 4-1/2", 11.6#, L-80, SLHT (PAl supplied, --~ Top of Window at +1- 4,619' MD, 3,735' TVD (1) Crossover, 4-1/2",11.6#, Casing Butress Box x 4-1/2", 11.6#, SLHT Pin (PAl supplied, 500-3060) (1) Swivel Sub, Baker, 4-1/2", 11.6#, Casing Buttress Box x Pin (BOT supplied) (1) Liner Hanger, Baker Flanged Hook Hanger, Size 7-518" x 4-1/2",4-1/2",11.6#, BTC Pin Down (49f:i-8360} Liner Top Packer Set @ +/- 4,799' MD / 3,736' TVD - Centralizers: 4-1/2" x 5-1/2" Rigid Straight Blade on every other joint in open hole ------------------------- ------------------------- -------------------------- ------------------------- Surface I Production Casing 7-5/8" 29.7# L-80 BTC Mod Set @ 5,013' MD / 3,804' TVD 6" Open Hole TD: 7,503' MD I 3,742' TVD See Sheet 2 for Lower Lateral Liner Details 1 C-1 09 Planned Completion Schematic Sheet 3 of 4: Upper Lateral Liner Details prepared by Steve McKeever August 18,2001 ------- ----------- ----------- ------------ ----------- (' Well # 1 C-1 09, AFE #AK0209 West Sak Multilateral Well (' Planned Completion Schematic Sheet 4 of 4: Tubing String Details PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Tree Assembly, (49ì-0080) Vetco Gray Gen II, API 13-518 - 5000 psi Flange Down x 4-1/16" 5000 Studded Top, wnh Penetrators Tubing Hanger, (493-3005) 4-1/2", Vetco Gray wI 4.909" WCA Top Connection, 4-1/2" L- 80 NSCT full Joint Down ESP Power Cable Penetrator (49"1-6860) Heat Trace Penetrator {497 -9275} Nabors Rig 245 RKB @ 0' Eælings: 561 ,706.13 Northings: 5,968,746.59 Elevation: 101.9' AMSL Tubing Head Assembly, Vetco Gray (1) Joint Tubing ....-:-~::~ . .: (x) Pup Joints Tubing, as required to spaceout heat trace. 16" Conductor: +1- 158' MD f' \,:. ì ~ *'( \G ::~=~~:::~:~:::~::::~:::~) (x) Joints Tubing sc~. (1) Gas Lift Mandrel, CAMCO 4-1/2" x 1" Model KBG-2 (481-9620), with dummy valve installed. 4-11 2" IBT Pin x Pin, with 6 foot 4-1/2" XO Pups, top and bottom. Tubing String: 4-11211, 12.6#, L-80, NSCT (463-4970) Port Collar: +/- 1000' MD / 988' TVD (3) Joint Tubing (1) Joint Tubing (1) Sub, Phoenix Discharge Temperature and Pressure (1) Pup Joint Tubing, 10ft length (1) Pup Joint Tubing, 10ft length (1) Through Tubing Conveyed Electric Submersible Pump (TTCESP) Assembly, Centrilift, consisting of: 7-5/8" Shoe: +1- 5,017' MD / 3,804' TVD (1) Slotted Nipple, Centrilift, 4-1/2" (1) Crossover, CentrUift, 4-1/2", TTC (1) Tandem Seal Section, Centrilift Model GST3 DB HL PFS (497-6510) (1) ESP Assembly, Centrilift Model 21 FCNPSH / 140FC2700 (conveyed through tubing) (497-6515) (1) Motor, Centrilift, 190 HP KMH 2415/48 (49"1-6f;OÖ) (1) Gauge, Phoenix, Model, MS-l Gauge (497-6500) (1) Centralizer, Motor, Centrilift, 6.25" 00 to be spaced out +1- 4560/ MD above Hook Hanger (497-6550) Top of Window: +/- 4,601' MD / 3,734' TVD Top of Lower Lateral Liner: +/- 4,693' MD 13,736' TVD ------------------------ ------------------------ ------------------------ ------------------------ ------------------------ D-Sand Lateral 6" Open Hole TD: 7,508' MD 13,746' TVD ------------------------ ------------------------ ------------------------ ------------------------ ------------------------ B-Sand Lateral 6" Open Hole TD: 7,513' MD I 3,800' TVD 1 C-1 09 Planned Completion Schematic Sheet 4 of 4: Casing String Details prepared by Steve McKeever October 10 2001 OR """'-'" . /'/' ( ( American Expresse Cash Advance Draft 169 DATE (JL- þí.,¡/ / ~ 2f;o! ID~"ro , C(/" $1100, L;t) I PAY TO THE ORDER OF DOLLARS Issued by Integrated Payment System. Inc. Englewood. Colorado Payable at Norwest Bank of Grand Junction - Downtown, NA Grand Junction. Colorado PERIOD ENDING 'C ~-(O 'ft.-I I: ~ 0 2 ¡. DOl. 0 0 I: :l 5 III 0 ¡. ? 50'00 5 :l bill 0 ¡. b g .. CHECK 1 STANDARD LETTER DEVELOPMENT / DEVELOPMENT REDRILL EXPLORA TION INJECTION WELL INJECTION WELL RED RILL (' ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERlPARAGRAPHS TO BE INCLUDED IN TRANSNDTTAL LETTER I (2--- ICJ9 L ( WELL NAME 1<:/2/ ¿ (If api number last two (2) digits are between 60-69) v/' PILOT HOLE (PH) ANNULAR DISPOSAL 4L> NO ANNULAR DISPOSAL L-J YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS <..J¿j YES + SP ACING EXCEPTION "CLUE" The permit is for a new wellbore segment 0 e . . ----' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. ' In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . pleas,note,' tha.t an dJJrosal o~ flu);s ~~ner,.ted... .J ,? !~f,4-1 t ~ t-{t $tJÖ~iLJ(t,)/ .~ (.1-1"<DVtLf..;' ¡::>.&rIJ Ú I-JJ C'-~ n n Lt.1 q 50 0''1'''\ I C. ~'-I:'~d ~ /.)c..~? 6/,') " I ' ~ 5 ~;.,. cJ./ hI'} , (J. fè.- "1. Enclosed is the approved appli ion for rmit to drill the above referenced well. The permit is approved' ,subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (ComDanv Name) will assume the liability of any protest to the spacing exception that may occur. IC.- /~:)\::: ~ì ":~) (Jr '.'II!¡"! ~",,,..~, "",,,,~,, ., L'~) t, .¡I.~";'\<:~ ~~~~r .,' \-.C'-' ~. ,to ~ I 't' .1 ~~ d- -Iz, ~ F ~~I) ~ Templates are located m drive\jody\templates , tl. WELL PERMIT CHECKLIST ~ WELL NAME I (l-Ib'1L/PROGRAM: exp - dev ~ redrll- serv - wellbore seg FIELD & POOL ao ( Q L. GEOL AREA UNIT# "') ..,) ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . . N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . N. 8. If deviated, is wellbore plat induded.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N AP R DA~E I 12. Permit can.be issued without administrative approval.. . . . . - N . ..!Q:!.!..:. 6 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y' N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . Y N ~ 15. Surface casing protects all known USDWs. . . . . . . . . . . Y N ~ \ - - \ (' \ , 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N ~, ~~')\'\ f\., ~(t \, 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y J::l.. ~ 18. CMT will cover all known productive horizons. . . . . .. . . . . ~ QQN ~~........... ~\ ~~~~...... ~''''' NC\D- r'1 19. Casing designs adequate for C, T, B & permafrost. . . . . . . \.11 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . <!> N t:......\ ,~'\.""(' r"\ ~ 1 f'b ~ ~ <'c..~(;t ~\ ~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . ~N ~ b.. ~ ::> 22. Adequate wellbore separation proposed.. . . . . . . . . . . . ~ N 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling .fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ~lc~ 26. BOPE press rating appropriate; testto ~:<;oì:) psig. Y N ~b.""" "? It....~ ~ ,"l.:>" ~~ i, t c . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . ,. <ID 30. Permit can be issued w/o hydrogen sulfide measures. . . .. (,Y:) N 31. Da~a ~resente~ on potential overpressure zones. . . . . . . ~ . 32. SeIsmic analysIs of shallow gas zones. . . . . . . . . . . . . ~NIl.,/ý N A~..f3 DATE 33. Seabed condition survey (if off-shore). . . . . . . . . '" Y N W 10./1. D J 34. Contact name/phone for weekly progress reports [ex ratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . ~'-.')~~ * (....~~",.,....~ ~ '-.\.c:.>"'~ ~ ~\ \ t)'r~~~'-3~~ ~~~\"",oY'- \ ~ (A) will contain waste in a suitable receiving zone; . . . . . . . Y N (8) will not contaminate freshwater; Qr cause drilling waste. .. Y N to surface;. ' (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing fonnation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: let WM9& /0 ¡ ~ c 0 Z 0 -t ~ ~ (' ~~ -to m GEOLOGY Z -t J: en :Þ ~ m » ( -- APPR DATE -- -- Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ( 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. ( Spe;:ry-Sun r>r:il1in'J S(~n::i('e:" LIS Scan UtiLity ~;Revisi'2,n: .3 ': LisLib $Revision: 4 $ Wed Feb 20 :5:02:1~ 2002 Reel Header Service name.............LISTPE Da 1: e. . . . . . . . . . . . . . . . . . . . . 02/ (J 2 I := \: Oriqin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UN1<NOlr'JI'j C:ontinuation Number...... 01 Previous Reel Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Tape Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02/02/2 I) Oriqin. . . . . . . . . . . . . . . . . . . 31'S Tape Name................UNKNOWN Continuation Number......01 Pr:evious Tape Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . .3TS LIS Physical EOF Comment Record TAPE HEADER Kuparuk River Unit ¡V¡WD/MAD LOGS # WELL NAME: , API NUMBER: OPERATOR: LOGGING CO¡V¡PANY: TAPE CREATION DATE: # O'OB DATA - West Sak LTOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 J-\K-MM-11l'71 A. WEAVER D. WESTER # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: rEi.: FWL: ELEVATION (FT fROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services lC-109 Ll 5002923047 60 PHILLIPS Alaska, Inc. Sperry Sun 20-FEE¡-02 MWD RUN 3 AK-MM-11171 J. BOBBITT F. HERBE1=<'T MWD RUN 4 AK-MM-lll71 J. BOBBITT F. HERBERT 12 111'1 10E 1478 699 .00 102.04 60.70 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 158.0 7.625 4494.0 9.880 # REMARKS: 1. .ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 & ;~ ARE DIRECTIONAL IÑITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUEl,LER TUBE DETECTORS AND ELECTROMAGNETIC WAVE do )...aot/ (' ~' RESISTIVITY PHASE ~ (ET\lR4) . - . >n,'JD RUN 3 IS L'IRECTIOìL"'.L ONLY FOR SSTT:=':;':; \':!--:!E'S~O'-_:;: AND MILLING. SROP ONLY IS PRESENTED FOR THIS RUN. '-I. MND DAT."'. IS PDC PER THE GKF. GEOSIENCE GROUP (E-I'.'I."'.IL FROM D. SCHWARTZ OF PHILLIPSALASK"'., INC. DATED 01/04/0::::). Dp.3."'. NOT SHIFTED TO PARENT WELL THIS ¡¡¡ELl, J';}C]';S OFF FROÌ'1 lC-109 ,"'.T 4'J94' ¡'m, 374 ' TVD (TOP OF WHIPSTOCK) . ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 4. tvlWD RUNS 1 & 4 REPRESENT ¡!'JELL lC-109Ll WITH API # 50-029-23047-60. THIS WELL REACHED A TOTAL DEPTH OF 7525' MD, 3734' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) S8MP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SCDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l. 0.0 Date of Generation.......02/02/20 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted ami DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX ROP FET $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 120.5 148.0 148.0 1 4f.L 0 14B. Ü 158.5 158.5 STOP DEPTH 7470.0 7477.0 7477.0 7477.0 7477.0 7525.0 7477.0 # BASELINE CURVE FOR SI:-II FTS: CURVE SHIFT DATA (MEASURED DEP1'H) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASEI,INE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 120.5 3 4494.5 4 4525.5 MERGE BASE 4494.0 4525.0 7525.0 # REMARKS: MERGED MAIN PASS. $ II: Data Format Spe(:if~catiorl Recl~rd Data Re,:::e,rÖ T)''I-,e.................. Data Spe\:i~ic3:ic~ Sl':lc~: Tj~e. ....~~ Logging Direction.................Down Optical log depth units...... .....Feet Data Reference Point........ ... ...Undefined Frame Spacinq.....................60 .1IN Max frames per record.. ..... ......Undefined Absent value..................... .-99~' Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Sp'2cificatie,n Blc,,::,f: sub-type.. J' Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 GR ¡V¡WD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPI'1 ¡V¡WD 0 ¡'¡MM 4 1 68 20 6 RPD ]v!'V\] 0 0 [-[MM 4 1 6fj 2"1 FET ¡V¡WD HR 4 1 68 28 0 First Last Name Service Unit Min Max Mean Nsam Readinq Reading DEPT FT 120.5 7525 38:22. '75 14810 120.5 7525 ROP ¡V¡WD FT/!-l 0 594.23 214.688 14'734 158.5 7525 GR ¡V¡WD APT 1:? ~)9 114.85 67 . 05~)4 14700 120.5 7470 RPX MWD OH¡V¡¡V¡ 0.24 2000 54.9063 14659 148 7477 RPS ¡V¡WD OHMtvI 0.25 2000 79.9855 14 65 9 148 7477 RP¡V¡ ¡V¡WD OHMM 0.38 2000 ~n . 9661 146t,)9 148 7477 RPD MWD OH¡V¡¡V¡ 0.24 2000 134.964 14659 148 7477 FET ¡V¡WD HR 0.09 59. :)5 O.T79701 1463f3 158.5 7477 First Reading For Entire File..........120.5 Last Readinq For Entire File...........7525 File Trailer Service name............. STSLIB. 001 Service Sub Level Name... Version Numbe:c.......... .1.0.0 Date of Generation.......02/02/20 ¡V¡aximum Physical Record..65535 File Tyr:\e............... .LO Next File Name...........STSL1B.002 Physical EOf' File Header Service name. .... ""'" .STSL1B.00:2 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......02/02/20 ¡V¡aximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW ¡V¡WD Curves and log BIT RUN NU¡V¡BER: DEPTH INCREMENT: # FILE SU¡V¡¡V¡ARY VENDOR TOOL CODE GR RPX 2 header data for each bit run in separate files. 1 . :iOOO ST]-\RT DE PTH 120.5 148.0 STOP DEPTH 4494.0 4494.0 Ri='D RPS RH! F:::T R.O~' 1 '1 8 . (! 14 8.0 148.0 158.5 158.5 4494.(1 ~ 4 9 ~ . 1'~ 449,1- ~ 40.:J .. ( ~ oJ 9~ .. '. " LOG HE.;;DER OAT,;; DPITE LOGGED: SOFTí'JARE SURFACE SOrTI'JARE VERSION: D011\¡'NHOLE SOFT1,'JARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'I'D DRILLER (F'T): TOP LOG INTERVAL (F'T): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM PINGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): ¡V¡UD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) 1-\'1' TEMPERATURE (DEGF) ¡VIUD AT ¡VIEASURED TEMPERATURE (MT): MUD AT MAX CIRCULA'nNG 'l'ERMPERA'I'URE: MUD FILTRATE .AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MArCRIX DENSI'I'Y: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units.. .........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 20-0CT-02. Insit.e i.:J6.16 4..05..:;, Jv1emory 4494.0 .0 87.7 TOOL NUMBER PB02231 FHRG6 PB02231FHRG6 9.880 4494.0 Water 9.00 1~,)0. 0 9.2 .~ 00 5.8 Based 4.500 3.415 5.000 4.000 65.0 87.8 65.0 65.0 Name Service Order Unit:" Size Nsarn Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWDOIO FT/H 4 1 68 4 ,-) GR MWDOlO API 4 1 68 8 ') ..J RPX MWDOIO OHMM <1 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RP]VI MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 ( í.'~ri' ì'H',JD Ci 1 (, HR ()S (C, fi rSl. Lasl- >iame Service Unit Min Ha:.: rlean Nsam Reading Readinq JEPT FT 120.5 4494 2307.25 8748 120.5 4494 ;\0[- !'-1TtJD010 FT/H 1.13 431. 53 176.922 8672 158.5 4.:1 94 '~ì f-..:. MWD010 API 12.59 114 .85 66.2313 8748 120.5 4.:1 9,~ RPX ¡.l\<JD01 (I OHMM 0.24 2000 56.9911 ::::693 148 4 4 ~Lj RPS r!l'i1DO 10 OH1-'\1-1 0.25 201)0 86. ,OF' 8693 148 .:1.:1 94 RPH 1'¡T';¡DC)10 OH!'-1!v1 0.38 2000 101 . 0135 86':U 1'18 ,; ,19'; RPD MIo,JDO 10 OHMM 0.24 .::>000 177.514 fj693 148 4.:1 94 FET 1-1WDOlO HR 0.15 11.08 0.67084G 8672 158.5 4.:1 94 First Reading For Entire File........ ..120.5 Last Reading For Entire File.......... .4494 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/20 Maximum Physical Record..65535 Fil e Type................ l,O Next File Name...........STSLIB.003 Physical EOF File Header Service name... ..........STSLIB.003 Service Sub Level Name... Version Number.. .........1.0.0 Date of Generation.......02/02/20 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.002 Comment Record rILE HEADER FILE NUMBER: F\AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER.: DEPTH INCREMENT: # FILE SUMM.ARY VENDOR TOOL CODE START DEPTH ROP 4494.5 3 :3 .5000 STOP DEPTH 4525.0 " ,,? 11 LOG HEADEF\ DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWAF\E VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DF\ILLER (FT): TOP LOG INTERVAL, (FT): BOTTOM LOG INTERVAL, (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINn--IUM ANGLE: MAXIMUM .ANGLE: 30-0CT-01 Insite 4.05.5 66.16 Memory 4525.0 .0 .0 TOOL STRING (TOP TO BO'I"I'OM) VENDOR TOOL CODE TOOL TYPE $ TOOl, NUMBEF\ BOF\EHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.000 JRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS >íUD TYPE: ì'¡UD DENSITY (LE/G): MUD VISCOSITY (SI: HUD PH: MUD CHLORIDES (2FM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) [-'1UD ;r:".T I'1EJ\SURED TEI'1PERATURE (MT): [-,IUD AT HAX CIRCULATING TERHPERATURE: MUD FILTRATE AT MT: MUD CAKE AT HT: IlJater Based 9.0C' "¡"7. (I 8.::' 1350C' 3..9 .000 .000 .000 .000 . I] . I] .0 . (I NEUTRON TOOL 1'1ATRD':: HATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ if Data Format Specification Record Data Record Type..................O Data Spec:Lf.ication Block Type..... 0 Logging Direction.................Down Optical log depth units...........Feet Data Reference Point............. .Undefined Frame Spacing................... ..60 .111'1 Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT F'T' 1 68 0 1 ROP MWD030 FT /11 1 68 .1 First Last Name Service Unit Min ¡v! a x Mean Nsam Reading Reading DEPT FT 4494.t') 4525 4509.75 62 4494.5 4525 ROP ~1WD030 FT/H 2.04 22.65 10.6056 62 4494.5 4525 First Reading For Entire File..........4494.5 Last Reading For Entire File...........4525 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation.......02/02/20 Maximum Physical Record..65535 FU e Type................ LO Next File Name...........STSLIB.OO4 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number.. ... ......1.0.0 Date of Generation.......02/02/20 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.003 ':,=,mment Record ?::: L2 iìEr-.DER ?I LE NUlv!BER: ?"jIJ HI'J0 ( (~u.!.-\"'es 3nd 1'-::><;1 header dat.a f"c¡r e.3l~h bj, t run in se!:=\ar,3t.e :i les. ::::1'1' RUN NUHBER: 4 DEPTH INCREMENT: .5000 FILE SUHHARY VENDOR TOOL CODE RPD RPM RPS RPJ: GR FET ROP START DE PTH 'i 4 94.5 STOP DEPTH 7477.0 7477.0 7477.0 4494.5 4494. S 4494. 5 <1494.5 4494.:) <J525.5 7477.0 7470.C' 7477.0 75:25 . CI " .;> # LOG HEADER DATA DATE LOGGED: SOFTlrJARE SURFACE SOFTWARE VERSION: DOWNHOLE SOF'I'WARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG I'1INIMUM ANGLE: MAX I I'1UtVI ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE 'rOOL 'TYPE DGR DUAL GAMMA HAY EWR4 ELECTROMAG. RESIS. 4 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESIS'l'IVI'ry (OHMM) ]-\'1' 'T'EMPERA'rurŒ (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEH.MPERA'I'URE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON '1'001., MA'l'RIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification H.ecord Data Record Type... ...............0 Data Specification Block 'I'ype.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing......... ............60 .1IN Ol-NOV-Ol Insite 4.05.5 66.16 Memory 7525.0 71.0 98.1 '1'OOL NUMBER PB02229HAGR4 PB02229HAGR4 6.750 LSND 9.00 47.0 8.5 13500 3.9 .200 .153 .240 .180 65.0 87.0 65.0 65.0 Max frames per record..... ..... ...UndetJnec Absent value.......... .... ......- .-990 De!--~,th Uni 'LS. . . . . . . . . . . . . . . . . . . . . . . D~~um Specification Block sub-t~~e...\- ì,.[,:;¡me Ser~v"ìce Order Urìi ts S.ize Nsam Rep Code Offset DCPT FT 1 68 0 S:OP !vf[ÑD040 FT/H 1 68 4 CR 1'--1\ÑOO 40 .Il..PI 1 68 8 Kt<.: ìv1\rJDI) 40 OHM)"! 1 68 .l -- RPS .1\ÑDO.:J 0 OHJ.11'1 1 {) E: ló RPM 1''11-;'004 (I OHìV!Jvl 1 68 ::::1:1 EPO HiÑ DC1.:J 0 OHM1'1 68 ::::4 FET I-1HD040 HE 1 68 '')ú Channel 1 3 5 " u first Last Name Service Unit Min Max Mean Nsam Eeading Eeadin'J DEPT FT 4494.5 7525 6009.75 606¿~ 4494.5 7 52~J ROP MWD040 FT/H 0 594.23 271.382 6000 4525.5 757:~~ GR MIÑOO 4 0 API 42.08 96.24 6tJ.2666 5952 4494.5 747(1 RI?X MW0040 OHMM 0.45 1716.26 51.8685 5966 4494.5 7477 RPS MWD040 OHMM 0.68 1883.33 70.1946 5966 4494.5 7477 RI?M MW0040 OHMH 8.69 1832.93 68.8792 5966 4494.5 7477 RPO MW0040 OHMH 12.01 2000 72.9642 5966 4494.5 7477 FET MWD040 !-IR 0.09 59. ~)5 0.93793 5966 4494.5 7477 First Reading For Entire File..........4494.5 Last Reading For Entire Fi1e...........7525 File Trailer Service name.............STSLIB.OO4 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/20 Maxinunß Physical Record..65535 Fil e Type................ LO Next File Name...........STSLIB.005 Physical EOr 'rape Trailer Service name. .... ........LISTPE Oa t e . . . . . . . . . . . . . . . . . . . . . 02/02/20 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Nex't Tape Name........... UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS ¡'¡¡r:Lting LihraL-Y. Scientific Technical Services Reel Trailer Service name.............LISTPE Oa t e. . . . . . . . . . . . . . . . . . . . . 02/02/20 Origin. . . . . . . . . . . . . . . . . . . S1'S Reel Name................UNKNOWN C:ontinuation Number...... 01 Next Reel Name...........UNKNOWN Comments................. STS I,IS 1i\ìriting Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File